WO2018140752A1 - Accouplement hydraulique réglable pour outils de forage et procédés associés - Google Patents

Accouplement hydraulique réglable pour outils de forage et procédés associés Download PDF

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Publication number
WO2018140752A1
WO2018140752A1 PCT/US2018/015486 US2018015486W WO2018140752A1 WO 2018140752 A1 WO2018140752 A1 WO 2018140752A1 US 2018015486 W US2018015486 W US 2018015486W WO 2018140752 A1 WO2018140752 A1 WO 2018140752A1
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WO
WIPO (PCT)
Prior art keywords
coupling
downhole
hydraulic
telemetry device
shaft
Prior art date
Application number
PCT/US2018/015486
Other languages
English (en)
Inventor
Manoj Gopalan
Original Assignee
Rime Downhole Technologies, Llc
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Rime Downhole Technologies, Llc filed Critical Rime Downhole Technologies, Llc
Priority to CA3042736A priority Critical patent/CA3042736A1/fr
Publication of WO2018140752A1 publication Critical patent/WO2018140752A1/fr

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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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/02—Couplings; joints
    • E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/07—Telescoping joints for varying drill string lengths; Shock absorbers
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/16—Drill collars
    • 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
    • E21B23/08—Introducing or running tools by fluid pressure, e.g. through-the-flow-line tool systems
    • E21B23/10—Tools specially adapted therefor
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
    • E21B47/18—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid, e.g. mud pressure pulse telemetry

Definitions

  • the present application is directed to a variable length hydraulic coupling for creating a flowpath for drilling fluid in a downhole tool, downhole tools using such couplings, and their method of use.
  • the present invention relates to a device or system capable of allowing a downhole drilling tool to be simultaneously mounted at two different axial locations to a drill string while allowing the length of the tool to vary as required to accommodate such mounting locations.
  • the present invention discloses a hydraulic coupling device that allows the top portion of the tool and the bottom portion of the tool to be mounted to the drill string at points on the drill string that are separated by an indeterminate length and still allow a mechanical and sealed fluid connection between the two portions.
  • this invention allows a drilling tool to potentially use both a top mounted telemetry or sensor system and a bottom mounted mud pulse telemetry system simultaneously.
  • This fluid circulation is used to transport the cuttings from the bottom of the bore hole to the surface where they are filtered out and the drilling fluid is re circulated as desired.
  • the flow of the drilling fluid also provides other secondary functions such as cooling and lubricating the drilling bit cutting surfaces and exerts a hydrostatic pressure against the borehole walls to help contain any entrapped gases that are encountered during the drilling process.
  • the fluid circulation system at the surface includes a pump or multiple pumps capable of sustaining sufficiently high pressures and flow rates, piping, valves and swivel joints to connect the piping to the rotating drill string.
  • MWD Measurement while drilling
  • MWD tools may transmit data in several ways, including: creating EM (low frequency radio waves or signals, currents in the earth or magnetic fields) waves to propagate signals through the earth; imparting high frequency vibrations to the drill string which can be used to encode and transmit data to the surface; and creating pressure pulses to encode and transmit data to the surface of the earth from the bottom of a borehole.
  • EM low frequency radio waves or signals, currents in the earth or magnetic fields
  • MWD tools using pressure pulses can operate in a number of ways, such as: closing or opening a valve in the drill string so as to create a substantial pressure pulse that is detectable at the surface when a particular parameter reaches a pre-selected or particular value or threshold, or creating a series or group of pulses depending upon the parameter's value, or by using the time between the pressure pulse signals in addition to the total number of pressure pulse signals to encode information. Opening and closing and sensing may be accomplished mechanically or electronically or electromechanically, or by a combination thereof.
  • MWD tools of the types described are limited in that they are non-reciprocating in nature.
  • the measurements in such devices are made when the fluid flow is stopped for a short period of time and the data is transmitted only once when the fluid flow resumed.
  • Acquiring downhole measurements while drilling with a device that can measure parameters whenever desired (not just when the fluid flow is interrupted) and can transmit these parameters to the surface continuously or when desired would be an advantage.
  • Such an MWD drilling tool may include a pulsing mechanism (pulser) coupled to a power source (e.g, a turbine generator capable of extracting energy from the fluid flow), a sensor package capable of measuring information at the bottom of a well bore, and a control mechanism that encodes the data and activates the pulser to transmit this data to the surface as pressure pulses in the drilling fluid.
  • a power source e.g, a turbine generator capable of extracting energy from the fluid flow
  • a sensor package capable of measuring information at the bottom of a well bore
  • the pressure pulses may be recorded at the surface by means of a pressure sensitive transducer and the data decoded for display and use to the driller.
  • a pulser may create pressure pulses in a number of fashions.
  • a servo mechanism opens and closes the main pulsing mechanism indirectly.
  • the fluid flow does most of the work of opening and closing the main valve to generate pulses to transmit data.
  • Other representative examples of servo driven pulser mechanisms have been proposed in U.S. Pat. Nos. 3,958,217, 5,333,686 and 6,016,288.
  • the pulse is created not by creating a restriction to the flow of drilling fluid in the hollow center of the drill string, but by opening a closing a port on the side of the drill string.
  • a negative pulser creates pressure decreases (as opposed to pressure increases) as venting fluid through a port in the drill string allows for some portion of the fluid to bypass the nozzles in the drilling bit.
  • a positive pulser one capable of creating positive pressure pulses
  • a negative pulser one capable of creating negative pulses
  • a positive pulser is coupled with a negative pulser (one capable of creating negative pulses) to provide the ability to create pressure pulses of various shapes and sizes by combining the action of both types of pulsers.
  • the "siren" type pulsing mechanism which creates positive pulses of reasonable magnitude in rapid succession and in a continuous fashion (as opposed to creating single pulses on demand).
  • Such data delivery systems whether EM, Acoustic or Mud Pulse, have particular inherent limitations which make use in all applications challenging.
  • EM systems are often limited by the depth they can be used to due to the inherent attenuation of the earth's rock formations.
  • Acoustic telemetry systems are also limited by depth due to the length of the drill string and by the attenuating effects of the friction of the drill string against the borehole, which tend to retard the transmission of the acoustic sound pulses to the surface.
  • Mud pulse telemetry tools are generally more robust and can be used in most applications; however, these tools are bandwidth limited and are generally not able to provide data at a high rate.
  • Using multiple telemetry methods may allow data to be delivered from deeper wells using one transmission device while using the second transmission device to provide faster data at shallower depths. Or in certain situations, using multiple devices may allow data to be transmitted effectively faster by utilizing both data channels to simultaneously transmit different data. It may also be desirable to have multiple transmission devices and allow one to be used in certain portions of the well while the other is used in a different portion to optimize the frequency and density of the data being sent to the surface.
  • a primary goal in the design of such multiple telemetry MWD tools is to provide technologies and methods that can be designed, manufactured and installed is such a way as to allow multiple telemetry methods to be used simultaneously.
  • Mud pulse telemetry tools are generally mounted to one extremity or the other of the downhole drilling tool because they require the porting or obstruction of the drilling fluid to create pressure pulses in the fluid flow.
  • a different or secondary telemetry device must necessarily be mounted at a different location on the drilling tool.
  • This combined drilling tool is usually many feet in length and needs to be attached to portions of the drill string where the distance between those portions may vary (even between nominally identical equipment. Moreover, such a drilling tool may need to straddle or fully pass through a single piece of non-magnetic drill string, itself of variable length, to enable proper sensor measurements.
  • an MWD tool is mounted on one end of a single non-magnetic drill collar (with, e.g., a mud pulse telemetry device at that end) and also at the opposite end (with, e.g., a second telemetry device, such as EM, at that end).
  • a single non-magnetic drill collar with, e.g., a mud pulse telemetry device at that end
  • a second telemetry device such as EM
  • An extensible or variable-length member or module in the drilling tool may allow for easy installation and usage of such multiple telemetry devices.
  • a new and improved apparatus, system, and method of use are presented that allow for the assembly of a tool incorporating multiple telemetry devices onto a drill string with the capability to adapt to varying length of the drill string components such as a nonmagnetic drill collar.
  • a method and apparatus are provided to adjust the length of a multiple telemetry-method capable drilling tool and allow a sealed fluid path through the adjustable apparatus for using in actuating a mud pulser or transmitting a signal in the fluid column.
  • a novel hydraulic coupling mechanism of adjustable length is assembled inline to a drilling tool, typically including a mud pulser telemetry device and one or more other telemetry devices.
  • the assembled apparatus or "MWD Tool” can be attached above and below a non-magnetic drill collar ( MDC) in respective hang-off or landing collars, and can span the length of the MDC while allowing portions of the tool to be mounted and fixed in space to both the top, hang off, collar and the bottom, landing, collar.
  • MDC non-magnetic drill collar
  • a system and method are provided to allow a mud pulse telemetry system to be installed at the bottom part of the MWD Tool and have a secondary telemetry system, either EM, Acoustic or a second mud pulse telemetry system, to be installed at the top portion of the MWD tool.
  • the system and method also provide a hydraulic coupling between components of a mud pulse telemetry system.
  • the bottom portion of the MWD tool is both mounted near the bottom of the NMDC to a landing collar and simultaneously the top portion of the MWD Tool is mounted to a hang-off collar above the NMDC.
  • the hang-off collar may be used to locate and mount a device other than a secondary telemetry system, and could be used instead to mount any number of sensors or devices that require a fixed mounting location above the NMDC.
  • Further obj ects of the present invention are to provide a new hydraulic coupling apparatus and method of using the same with a reasonably small cross section that minimizes the pressure drop associated with use thereof with a servo-assisted main pulser, and that does not significantly impede the flow of drilling fluid on its way to the bit during normal drilling operations and thus will significantly reduce erosion and wear that is caused due to the high flow velocities of the drilling mud.
  • a further object of the present invention is to provide a new hydraulic coupling apparatus and method of using the same that is short in length.
  • This short length may allow the MWD tool, and specifically the hydraulic coupling apparatus to be built to be stiffer and without the need for special flexible members to allow for the curvature of the bore hole.
  • This added stiffness also permits the MWD tool to have greater resilience in the presence of high vibration and shock levels that are found in the bottom of a bore hole while drilling.
  • a further object of the present invention is to provide a new hydraulic coupling apparatus and method of using the same which provides a mechanism to adequately shock isolate the internal components of the MWD Tool from the damaging effects of axial vibration imparted through the bottom landing sub, and reduce the occurrence and severity of damage caused by excessively high vibrations in the drilling environment.
  • a further object of the present invention is to provide an extensible hydraulic coupling and mounting mechanism or apparatus and method of using the same, and a MWD tool system and method of using the same, that provide a mechanism to allow for variations in the length of the drill string components between mounting points for the MWD Tool, such as the length of an MDC and allow for such variations to be accommodated rapidly, easily and effectively during the assembly of the MWD Tool into the NMDC, the hang-off collar and the landing collar.
  • a further object of the present invention to provide a hydraulic coupling apparatus and method of using the same that is able to be rapidly installed or uninstalled from the MWD Tool to minimize and eliminate valuable time and cost at the drilling rig.
  • a further object of the present invention is to provide a hydraulic coupling apparatus and method of using the same that can be manufactured in multiple different lengths to tailor effective to different ranges of lengths of the drill string components between mounting points for the MWD Tools, while still allowing a sufficient and reasonable amount of length adjustment to easily and effectively install the MWD Tool into the drill string.
  • a further object of the present invention is to provide a new hydraulic coupling apparatus and method of using the same that provides diametrically stabilizing bearings and multiple insertion and extraction features to allow the coupling apparatus to be installed and uninstalled easily and effectively in instances where the upper portion of the MWD Tool and the lower portion of the MWD Tool are not reasonably concentric.
  • a further object of the present invention is to provide a new hydraulic coupling apparatus and method of using the same that provides a robust sliding seal system that is able to accommodate the translation of the hydraulic apparatus during installation without sacrificing the quality or effectiveness of the pressure sealing between the inner and outer portion of the apparatus.
  • FIG. 1 is a representative sketch of parts of the surface and downhole portions of a drilling rig.
  • Fig. 2 is a representative sketch of various components that together may comprise the downhole portion of an MWD Tool resident inside the tubular components of the drill string.
  • Fig. 3 is a partial cutaway three dimensional view of the tubular components of the drill string inside which the MWD Tool may reside.
  • Fig. 4 is a three dimensional view of the various components that together may comprise part of the MWD Tool.
  • Fig. 5 is a partial cutaway of the lower portion of the MWD Tool resident inside the tubular components of the drill string.
  • Fig. 6 is a three dimensional view of the adjustable hydraulic coupling shown in an unassembled state.
  • Fig. 7 is a three dimensional view of the adjustable hydraulic coupling shown in its maximally extended and engaged state.
  • Fig. 8 is a three dimensional view of the adjustable hydraulic coupling shown in its minimally extended and engaged state.
  • Fig. 9 is a partial cutaway of the adjustable hydraulic coupling resident inside the non-magnetic drill collar.
  • Figs. 10A & 10B are three dimensional views of the upper portion of the MWD
  • Fig. IOC is a partial cutaway three dimensional view of the upper portion of the
  • Figs. 10D & 10E are three dimensional views of the lower portion of the MWD
  • Figs. 10F & 10G are partial cutaway three dimensional views of the upper portion of the MWD Tool mounted into a hang-off sub and inside the NMDC and the lower portion of the MWD Tools mounted into a landing sub.
  • information of use to the driller is measured at the bottom of a bore hole relatively close to the drilling bit and this information is transmitted to the surface using pressure pulses in the fluid circulation loop.
  • This information, or other information may also be transmitted using a secondary telemetry device which could be a second mud pulser transmitter, an EM telemetry device or an acoustic telemetry device.
  • Some of the data thus gathered to transmit may be acquired from sensors or systems that are mounted to the drill string near the top or bottom of the MWD Tool.
  • the command to initiate the transmission of data is sent by stopping fluid circulation and allowing the drill string to remain still for a minimum period of time.
  • the downhole tool measures at least one downhole condition, which is usually an analog signal.
  • the signal is processed by the downhole tool and readied for transmission to the surface.
  • the downhole tool waits a predetermined amount of time to allow the fluid flow to stabilize and then begins transmission of the information by repeatedly closing and then opening the pulser valve to generate pressure pulses in the fluid circulation loop.
  • the sequence of pulses sent is encoded into a format that allows the information to be decoded at the surface and the embedded information extracted and displayed.
  • a command to initiate transmission is sent by different means, including by transmitting EM signals down to the MWD Tool which may have a receiver to accept such command, or through vibrations in the drill string sent to a vibration sensitive detector included as part of the MWD Tool.
  • Such additional command methods in combination or independent of the first method, may initiate data transmission using one or both transmission methods, or may initiate any number of other functions that the downhole MWD Tool can perform.
  • FIG. 1 there is generally shown therein a simplified sketch of the apparatus used in the rotary drilling of bore holes.
  • Bore hole 10 is drilled into the earth using rotary drilling rig 11 which consists of derrick 12, drill floor 14, draw works 16, traveling block 18, hook 20, swivel joint 22, kelly joint 24 and rotary table 26.
  • Drill string 30 used to drill bore hole 10 is made up of multiple sections of drill pipe that are secured to the bottom of kelly joint 24 at the surface.
  • Rotary table 26 is used to rotate the entire drill string 30 assembly while draw works 16 is used to lower drill string 30 into bore hole 10 and apply controlled axial compressive loads.
  • the bottom of drill string 30 is attached to multiple drilling collars 32, which are used to stiffen the bottom of drill string 30 and add localized weight to aid in the drilling process.
  • a short piece of drill collar called a hang-off sub 32 (or hang-off collar) is positioned below multiple drilling collars 32.
  • a length of non-magnetic drill collar ( MDC) 36 is position below hang-off sub 34. Below MDC 36, a second short piece of drill collar called a landing sub 38 is attached.
  • a hydraulic turbine of a positive displacement type In some drilling operations, a hydraulic turbine of a positive displacement type
  • drilling tool (not shown) may be inserted below landing sub 38 to enhance the rotation of the drill string desired.
  • various other drilling tools such as stabilizers, one-way valves and mechanical shock devices (commonly referred to as jars or agitators) may also be inserted in the bottom section of drill string 30 either below or above NMDC 36. Some of these components could be used in the process of directionally drilling the well.
  • tubular component 40 is shown attached below landing collar 38. At the bottom of drill string 30, and below optional tubular component 40, drilling bit 42 is attached.
  • the drilling fluid or "mud” is usually stored in mud pits or mud tanks 50, and is sucked up by mud pump 52, which then forces the drilling fluid to flow through surge suppressor 54, then through kelly hose 56, and through swivel joint 22 and into the top of drill string 30.
  • the fluid flows through drill string 30, through drill collars 32, through hang-off sub 34, through NMDC 36, through landing collar 38, through tubular component 40 and through drilling bit 42 and its drilling nozzles (not shown).
  • the drilling fluid then returns to the surface by traveling through annular space 60 between outer diameter of drill string 30 and well bore 10. When the drilling fluid reaches the surface, it is diverted through mud return line 62 back to mud tanks 50.
  • the pressure required to keep the drilling fluid in circulation is measured by pressure sensitive transducer 70 on kelly hose 56.
  • the measured pressure is transmitted as electrical signals through transducer cable 72 to surface computer 74 which decodes and displays the transmitted information to the driller.
  • additional sensors may be placed at or near drilling rig 11 to measure any pertinent information required to receive and decode the data being sent from the downhole tool which resides inside and is substantially part of the drill string.
  • Such sensors may be electrical in nature, as shown by ground current sensing electrode 76 which is attached to the earth some distance from drilling rig 11, and whose data is sent to surface computer 74 through cable 78.
  • Other sensors may also be attached to the drilling rig itself, preferably at a location close to the center of well bore 10 and in good electrical contact with drilling rig 11.
  • Such a sensor 90 is shown attached to surface casing pipe 82 of drilling rig 11 and whose signals are transmitted to surface computer 74 through cable 80.
  • FIG. 2 generally shows a schematic representation of the various components that together make up the downhole portion of an MWD Tool.
  • Downhole MWD Tool 100 is generally installed inside and along centerline A-A of the tubular components that form part of drill string 30, specifically hang-off sub 34, MDC 36 and landing collar 38, and is generally disposed in the presence of the fluid flow from surface pumps 52 to drill bit 42.
  • the MWD Tool may include a top mounted device 102.
  • Top mounted device 102.
  • top mounted device 102 could be a secondary telemetry device such as an EM transmitter, an acoustic transmitter or a sensing device.
  • a common feature of top mounted device 102 is that it needs to be mounted to hang-off sub 34.
  • Top mounted device 102 might need to make good electrical contact with hang-off sub 34 to enable the transmission of electrical signals by an EM telemetry device, or need to make good mechanical contact with the hang-off sub 34 to enable transmission of acoustic signals by an acoustic telemetry device, or need to be connected to the hang-off sub 34 to enable taking of measurements, such examples as measuring the pressure of the annular fluid 60.
  • Top mounted device 102 may be mounted to hang-off sub 34 in such ways as bolts, or other fasteners that will withstand the forces imposed by a downhole tool.
  • MWD Tool 100 also may include one or more tubular modules.
  • Fig. 2 depicts multiple tubular modules 104 and 106 which are connected to the bottom of top mounted device 102.
  • Tubular modules 104 & 106 may provide necessary functions such as storing and providing power to MWD Tool 100 using batteries, contain other sensors or systems necessary for the measurement and transmission of data, house control electronics, power generation systems or any contain equipment for other functions required by MWD Tool 100.
  • MWD Tool 100 also includes mud pulse telemetry device 108 which is attached to the bottom of tubular modules 104 and 106.
  • the purpose of this mud pulse telemetry device is actuate a valve to impede the flow of the drilling fluid and generate pressure pulses.
  • This mud pulse telemetry device may be a servo pulser, such as one described in U.S. Pat. No. 9,133,950 (issued Sept. 15, 2015) or a direct mud pulser, such as one described as part of a measurement while drilling apparatus in U.S. Pat. No. 7,735,579, or a negative pulser. (Both preceding U.S.
  • Mud pulse telemetry device 108 may contain one or a plurality of fluid inlets 110 through which the part of the drilling fluid pumped by mud pump 52 that is present in annular space 92 may flow into mud pulse telemetry device 108. Ultimately, pressure pulses can be transmitted through the fluid column existing in annular space 60 to the surface, and used to encode and transmit data from the subterranean environment to the surface.
  • Female hydraulic coupler 112 is attached to the bottom of mud pulse telemetry device 108, and the fluid entering fluid inlet(s) 110 may flow through female hydraulic coupler 112.
  • This fluid flow through mud pulse telemetry device 108 may be intermittent as may be required for the proper operation of the system and this intermittent flow may be achieved by mud pulse telemetry device 108 opening and closing a valve (not shown) that may reside internal to the mud pulse telemetry device.
  • a representative valve of this type is described in detail in U.S. Pat. No. 9, 133,950.
  • Fig. 2 also shows male hydraulic coupler 114 partially inserted into female hydraulic coupler 112 to form hydraulic coupling system 111.
  • the depth of this insertion may vary as required and such a variation is achieved by allowing male hydraulic coupler 114 to slide in or out of female hydraulic coupler 112 to achieve the proper spacing required.
  • Main pulser valve 116 is attached to the bottom of male hydraulic coupler 1 14.
  • Main valve 116 is used to generate pressure pulses used to encode and transmit data from the bottom of the well bore to the surface, and this generation may be activated by the intermittent flow of fluid from annular cavity 92 going through fluid inlet(s) 110, entering mud pulse telemetry device 108 and then flowing through a valve (not shown) inside said mud pulse telemetry device 108, and then further on through female hydraulic coupler 112, and then through male hydraulic coupler 114 to activate main pulser valve 116.
  • Placement of male hydraulic coupler 114 and female hydraulic coupler 112 could be reversed (not shown), to have male hydraulic coupler 114 attached to mud pulse telemetry device 108 and inserted into female hydraulic coupler 112 from above.
  • main pulser valve 116 The bottom of the main pulser valve 116 is attached to main pulser mount 1 18, which in turn is mechanically connected to landing sub 38.
  • Main pulser valve 116 may be hydraulically coupled to main pulser mount 118, and main pulser mount 118 to landing sub 38.
  • Landing sub 38 may provide a port (not shown) therein to annular space 60 to permit movement of drilling fluid and transmission of pulses thereinto.
  • hang-off sub 34, NMDC 36 and landing sub 38 together as part of drill string 30 requires that they be rotated relative to each other to tighten threads joints (not shown), and such rotation cannot be accomplished if both ends of MWD Tool 100 are attached to their respective mounting locations. Sliding engagement of male hydraulic coupler 114 with female hydraulic coupler 112 is free, subject to friction between the two, and does not transmit axial loads between the connected devices (e.g. top mounted device 102 and main pulser valve 116).
  • mud pulse telemetry device 108 does not use a second telemetry device to create mud pulses in annular space 60.
  • mud pulse telemetry device 108 comprises a direct mud pulser or a negative pulser.
  • mud pulse telemetry device 108 may generate pulses by the intermittent flow of fluid from annular cavity 92 going through fluid inlet(s) 110, entering mud pulse telemetry device 108 and then flowing through a valve (not shown) inside said mud pulse telemetry device 108, and then further on through hydraulic coupling system 111.
  • Hydraulic coupling system 111 is, however, mechanically connected and hydraulically coupled to landing sub 38 via mount 118. Landing sub 38 may provide a port (not shown) therein to annular space 60 to permit movement of drilling fluid and transmission of pulses thereinto.
  • Fig. 3 generally shows a three dimensional view of the tubular components inside whom MWD Tool 100 in generally disposed.
  • Hang-off sub 34 is attached to NMDC 36 to which in turn landing sub 38 is attached.
  • Fig. 4 generally shows a three dimensional view of MWD Tool 100.
  • Top mounted device 102 is shown attached to tubular module 104, which in turn is connected to tubular module 106, and further on to mud pulse telemetry device 108.
  • Mud pulse telemetry device is shown with fluid inlet ports 110, and mud pulse telemetry device is in turn attached to hydraulic coupling system 111 at female hydraulic coupler 112.
  • Fig. 4 also shows male hydraulic coupler 114 partially engaged and inserted into female hydraulic coupler 112.
  • Male hydraulic coupler is also attached to main pulser valve 116, which in turn is attached to main pulser mount 118.
  • Fig. 4 also shows location 122 on top mount device 102, which is one possible location where top mount device 102 could be attached to hang-off sub 34.
  • location 124 is also shown on main pulser mount 118, which is one possible location where main pulser mount 118 could be attached to landing sub 38.
  • Fig. 4 also shows a plurality of centralizers 120, which are a representation of devices that may be used to hold MWD Tool 100 concentric to the inner diameter of NMDC 36.
  • These centralizers 120 could be made in many shapes and sizes, and may utilize elastomers, springs or other members to provide adequate support for MWD Tool 100 inside NMDC 36.
  • Fig. 5 shows a cross-section of a portion of MWD Tool 100 resident inside the tubular collars attached to drill string 30. Specifically, it shows a portion of the bottom section of MWD Tool 100 inside the lower end of NMDC 36 and the upper end of landing sub 38.
  • a representative mud pulse telemetry device 108 similar to one described in U.S. Pat. No. 9,133,950 is shown attached to the upper end of female hydraulic coupler 112, and in the further interest of clarity, a representative main pulser valve 116 and mount 118 are shown without any salient details.
  • Fig. 6 shows a three dimension view of hydraulic coupling system 111 in one of its embodiments, where the male hydraulic coupler 112 and the female hydraulic couple 114 are shown in an unengaged state, and displays the two portions of hydraulic coupling system 111 prior to assembly.
  • Fig. 6 also shows the plurality of radial seals 140 and radial bearing 142, and end fittings 113 and 115.
  • Fig. 7 shows a three dimension view of hydraulic coupling system 111 in one of its embodiments, where male hydraulic coupler 112 and female hydraulic couple 114 are shown in the maximally extended and engaged state.
  • Fig. 8 shows a three dimension view of hydraulic coupling system 111 in one of its embodiments, where the male hydraulic coupler 112 and the female hydraulic couple 114 are shown in their minimally extended and engaged state.
  • Fig. 9 shows a cross-section of a portion of the MWD Tool resident inside the tubular collars attached to the drill string 30. Specifically, it shows the engagement of male hydraulic coupler 112 and female hydraulic coupler 114 inside MDC 36.
  • Female hydraulic coupler 114 includes sealing surface 141 on which plurality of radial seals 140 and radial bearing 142 act. The seal created between sealing surface 141 and radial seals 140 seals hydraulic flow path 91 from annular space 92. Hydraulic flow path 91 permits hydraulic coupling system 111 to hydraulically couple devices attached at its respective end fittings 113 and 115.
  • Top mounted device 102 can be attached to hang-off sub 34 in different ways, but generally, MWD Tool 100 must be mounted inside hang-off sub 34 so as to prevent rotation between MWD Tool 100 and hang-off sub 34.
  • This need for rotational alignment is due to the need to measure and transmit the rotation position of the downhole components as measured by any inertial sensing system to enable the drilling of directional wellbores.
  • any such mounting may also need to be thus rotationally aligned to enable access to fluid ports, sensor ports or other devices or means to enable the proper measurement or transmission of data.
  • rotational alignment may also be a consequence of the need to axially align top mounted device 102 inside hang-off sub 34 for substantially the same reasons.
  • a downhole tool also needs to be mechanically coupled to a drill string to reduce the damaging effects of the shock and vibrations that are routinely encountered during the drilling of wellbores.
  • any top mounted device 102 will need to be mounted so as to prevent both axial and radial movement between it and hang-off sub 34.
  • Main pulser mount 118 will also need to be mounted inside landing sub 38 to prevent rotation between main pulser mount 118 and landing sub 38. This need for rotational alignment shares substantially the same reasons as those described above for top mounted device 102. However, in addition to the foregoing, bottom mounted main pulser valve 116 may also need said mounting to allow for proper operation of the pulser valve system to generate pressure pulses.
  • a multiple telemetry MWD Tool 100 may require that both its top and bottom extremities be mounted to components of drill string 30, specifically and respectively hang-off sub 34 and landing sub 38, in such a way as to prevent both extremities from translating axially or rotating relative thereto.
  • a hydraulic coupling device such as is described below may be used.
  • hydraulic coupling system 111 is placed between the bottom of mud pulse telemetry device 108 and main pulser valve 116. This is to enable the drilling fluid present in annular space 92 in the inner volume of NMDC 36 to enter inlet port(s) 110 of mud pulse telemetry device 108 and to be intermittently allowed to flow through the bottom of mud pulse telemetry device 108 due to the action of servo valve 130.
  • servo valve 130 When servo valve 130 is opened, fluid from annular space 92 is allowed to flow through inlet port(s) 110, through servo valve 130, and then further along cavity 134 and then into inner cavity 136 of female hydraulic coupler 112. The drilling fluid then flows through inner cavity 138 of male hydraulic coupler 114 and on to main pulser valve 116, where this fluid flow is used to activate main pulser valve 116 to generate pressure pulses in the drilling fluid in annular space 92.
  • male hydraulic coupler 112 and female hydraulic coupler 114 need to be relatively concentric to allow for easy assembly of MWD Tool 100 when its two sub sections are brought together during assembly of MDC 36 to landing sub 38.
  • male hydraulic coupler 112 and female hydraulic coupler 114 being concentric facilitates free rotational motion between the two, such that they are not rotationally coupled.
  • end fittings 113 and 115 are likewise able to freely rotate relative to one another.
  • male hydraulic coupler 114 The sealing of inner cavities 136 and 138 is accomplished by a plurality of radial seals 140 that are mounted onto male hydraulic coupler 114.
  • NMDC 36 As NMDC 36 is axially aligned to landing sub 38 during the assembly process, male upper end 146 of male hydraulic coupler 114 enters female lower end 144 of female hydraulic coupler 112, and is guided so as to allow both male hydraulic coupler 114 and female hydraulic coupler 112 to be positioned concentrically to each other before male upper end 146 fully engages into cylindrical bore 137 of female hydraulic coupler 112.
  • That engagement causes radial seals 140 to also enter cylindrical bore 137 of female hydraulic coupler 1 12, to seal with sealing surface 141 and thus create a tight seal impeding the connection of fluid between inner cavities 136 and 138, hydraulic flow path 91, and fluid column 92.
  • female lower end 144 is proved with a large smooth conical chamfered surface 145, and the male upper end is provided with a large smooth filleted surface 147 to ensure that the engagement is not impeded by the presence of mechanical discontinuities that would retard said engagement or damage radial seals 140.
  • male hydraulic coupler 114 is provided with radial bearing 142 to allow male hydraulic coupler 114 to be held relatively concentric to female hydraulic coupler 112.
  • Radial bearing 142 is preferably made in the plain bearing style and preferably uses a material with a low coefficient of friction which can sustain the chemically abrasive nature of the drilling fluids found in the wellbore. A material such a ToughMet® or PEEK may be used.
  • Radial seals 140 and radial bearing 142 also facilitate male hydraulic coupler 114 and female hydraulic coupler 112 being rotationally decoupled, and that end fittings 113 and 115 are likewise rotationally decoupled.
  • the engagement length of male hydraulic coupler 1 14 inside female hydraulic coupler 112 may vary as required to allow for the proper shouldering of NMDC 36 to landing sub 38, and to further thread NMDC 36 and landing sub 38 to be threaded together.
  • the upper end of female hydraulic coupler 112 is provided with centralizing fins 120 mounted onto MWD Tool 100 at said location.
  • Centralizing fins 120 may be formed or rubber or other materials, and may be retained using bolts 132.
  • Centralizing fins 120 may be provided at other locations along MWD tool 100. Other types of centralizing devices may also be used, such as bow springs or integrated fins as the application demands.
  • the mud pulse telemetry device and the main valve are mounted to a hang off sub mounted to the upper portion of the non-magnetic drill collar, and a bottom mounted device to be mounted to the landing sub, in which case, the final assembly step would be the threading of the hang-off sub onto the top of the non-magnetic drill collar.
  • Another possible embodiment may be one in which the fluid being connected between the mud pulse transmitter and the main valve is a hydraulic fluid instead of drilling fluid.
  • Yet another possible embodiment is one in which such an adjustable coupling is made between sealed compartments between modules of the MWD tool.
  • the interval cavity of the adjustable coupling is used to connect wires or radio signals in lieu of connecting a fluid.
  • MWD Tool 100 is described that is capable of measuring desired parameters at the bottom of a bore hole during the process of drilling, at when desired, is able to telemeter this information to the surface from such a subsurface location using a series of pressure pulses in the drilling fluid where the pressure pulses thus telemetered encode data about these desired parameters which are then subsequently measure at the surface location, detected, decoded and the telemetered information is retrieved, stored, displayed or transmitted further as required.
  • MWD Tool 100 is mounted near its bottom extremity to landing sub 38, which resides below MDC 36.
  • MWD Tool 100 also consists of a secondary telemetry device or sensor device, where said telemetry device or sensor device is a top mounted device 102 that is mounted near its top extremity inside hang-off sub 34.
  • MWD Tool 100 has disposed between its top extremity and bottom extremity hydraulic coupling system 111, which includes male hydraulic coupler 114 mounted to the bottom part of MWD Tool 100 and female hydraulic coupler 112 mounted to the top part of MWD Tool 100.
  • Hydraulic coupling system 111 has an internal cavity of variable and adjustable length and volume to allow for easy assembly and functionality of MWD Tool 100.
  • Figs. 4, 5 and 9 show portions of the MWD Tool 100 and details of the adjustable hydraulic coupling in a three dimensional view
  • Figs. 10A through 10G show the assembly process by which the invention can be used in one embodiment of the invention.
  • Fig. 10A generally depicts a three dimensional view of the upper portion of the
  • MWD Tool 100 which is shown mounted into hang-off sub 34.
  • the upper portion of MWD Tool 100 as shown in Fig. 10A consist of a top mounted device 102, tubular modules 104 and 106 attached to top mounted device 102, and mud pulse telemetry device 108. These components that make up the upper portion may contain a plurality of centralization devices 120, which preferably are built into each individual module and serve to provide radial stabilization of the upper portion of the MWD Tool 100 when it is inserted into further components described below. It should be noted that top mounted device 102 is axially and rotationally located to hang-off sub 34 using any number of possible mounting devices (not shown).
  • Fig. 10B generally depicts a three dimensional view of the upper portion of the
  • Female hydraulic coupler 112 is designed to allow fluid entering inlet port(s) 110 of mud pulse telemetry device 108 to be intermittently allowed to flow through the inner diameter of female hydraulic coupler 112 as required to allow the activation of devices described below.
  • Fig. IOC generally depicts a three dimensional view of the upper portion of
  • MWD Tool 100 substantially as described in Figs. 10A and 10B, as inserted into MDC 36, and with NMDC 36 threaded onto hang-off sub 34.
  • NMDC 36 is shown partially cut away to show the details of MWD Tool 100 resident substantially inside NMDC 36.
  • the process of inserting MWD Tool 100 into NMDC 36 and threading NMDC 36 to hang- off sub 34 positions MWD Tool 100 generally concentric to the inner diameter of NMDC 36. Such concentricity is facilitated by the plurality of centralization devices 120.
  • the lower extremity of the upper portion 148 of MWD Tool 100 female lower end 144 of female hydraulic coupler 112 at this point in the process) is thus located some distance above the lower end of NMDC 36, and substantially inside the inner diameter thereof.
  • Fig. 10D generally depicts a three dimensional view of lower portion 148 of
  • Main pulser valve 116 is mounted to landing sub 38. It should be noted that main pulser valve 116 is axially and rotationally located to landing sub 38 using any number of possible mounting devices (not shown).
  • Fig. 10E generally depicts a three dimensional view of lower portion 150 of
  • MWD Tool 100 mounted inside landing sub 38 as substantially depicted in Fig. 10D, to which male hydraulic coupler 114 is attached.
  • a plurality of radial seals 140 and a radial bearing 142 are mounted to male hydraulic coupler 114.
  • Male hydraulic coupler 114 is designed with a cavity through its entire length, including inner cavity 138 so as to allow fluid entering male upper end 146 to travel through said male hydraulic coupler 114 and enter main pulser valve 116 to activate said main pulser valve 116 which in turn creates pressure pulses which may be used to encode data for transmission to the surface.
  • Fig. 10F generally depicts a three dimensional view of upper portion 148 and lower portion 150 of MWD Tool 100, in which upper portion 150 is mounted to hang-off sub 34, and a substantial portion of MWD Tool 100 is resident inside NMDC 36, and lower portion 150 is mounted to a landing sub 38. Both those portions of MWD Tool 100 are shown concentric to each other as a depiction of their relative positions before assembly of the two parts of MWD tool 100.
  • lower portion 150 is aligned relatively concentric to upper portion 148 and lower portion 150 is inserted gently into upper portion 148, thereby inserting male hydraulic coupler 1 14 into the relatively circular hole that makes up the inner diameter of NMDC 36.
  • This act of insertion eventually causes the upper extremity of lower portion 150, male upper end 146 of male hydraulic coupler 114, to enter the lower extremity of upper portion 148, female lower end 144 of female hydraulic coupler 112. Then it causes radial seals 140 and radial bearing 142 to engage in cylindrical bore 137 of female hydraulic coupler 112.
  • female hydraulic coupler 112 to be moved concentric with male hydraulic coupler 114 and creates a sealed cavity inside male hydraulic coupler 114 and female hydraulic coupler 112.
  • the lengths of male hydraulic coupler 114 and female hydraulic coupler 114 and of cylindrical bore 137 may be varied during manufacturing to achieve the required lengths to allow for proper engagement of the female hydraulic coupler 114 into the male hydraulic coupler 114 as appropriate.
  • a hydraulic coupling system as described will allow these aforementioned three tubular components to be attached and threaded to each other, while simultaneously allowing MWD Tool 100 substantially retained inside these tubular components to be assembled, and further allow such MWD Tool to be both top mounted at hang-off sub 34 and bottom mounted at landing sub 38.
  • the invention described in this document and the method for the utilization of said invention as described above will allow MWD Tool 100 with multiple mounting locations and potentially multiple telemetry devices to be assembled and utilized for intended purpose of telemetering data from the bottom of a wellbore to the surface using mud pulses in the fluid flow and potentially utilizing other telemetry methods in conjunction.

Abstract

L'invention concerne un dispositif d'accouplement hydraulique réglable qui permet le montage simultané de différentes parties d'un outil de forage de fond de trou sur le train de tiges de forage à proximité de ses extrémités supérieure et inférieure. Ce montage supérieur et inférieur est effectué en des points sur le train de tiges de forage séparés par une longueur indéterminée. Le dispositif d'accouplement permet une liaison fluidique mécanique et étanche entre deux parties de l'outil, et permet l'assemblage des deux parties de l'outil de forage en une unité fonctionnelle, et permet à la fois une translation axiale et un mouvement de rotation entre celles-ci. Un tube en saillie cylindrique est fixé à la partie de l'outil de forage montée à son extrémité supérieure pendant qu'un tube cylindrique d'accouplement est fixé à la partie de l'outil de forage montée à proximité du fond. Pendant l'assemblage, le tube plus petit entre dans le tube plus grand et forme un trajet de fluide étanche et permet également que la longueur de mise en prise de l'ensemble varie selon les besoins.
PCT/US2018/015486 2017-01-27 2018-01-26 Accouplement hydraulique réglable pour outils de forage et procédés associés WO2018140752A1 (fr)

Priority Applications (1)

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CA3042736A CA3042736A1 (fr) 2017-01-27 2018-01-26 Accouplement hydraulique reglable pour outils de forage et procedes associes

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US201762451538P 2017-01-27 2017-01-27
US62/451,538 2017-01-27
US15/716,243 US20180216418A1 (en) 2017-01-27 2017-09-26 Adjustable Hydraulic Coupling For Drilling Tools And Related Methods
US15/716,243 2017-09-26

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WO2018140752A1 true WO2018140752A1 (fr) 2018-08-02

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6158529A (en) * 1998-12-11 2000-12-12 Schlumberger Technology Corporation Rotary steerable well drilling system utilizing sliding sleeve
FR2844574A1 (fr) * 2002-09-17 2004-03-19 Weatherford Lamb Assemblage a connexion tubulaire
US20090090508A1 (en) * 2007-10-03 2009-04-09 Tesco Corporation (Us) Liner Drilling Method and Liner Hanger
US20150159719A1 (en) * 2012-08-03 2015-06-11 Lord Corporation Isolator
US20140138157A1 (en) * 2012-11-21 2014-05-22 Gerald Heisig Drill bit for a drilling apparatus
US20140145857A1 (en) * 2012-11-26 2014-05-29 Baker Hughes Incorporated Electromagnetic Telemetry Apparatus and Methods for Use in Wellbore Applications

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CA3042736A1 (fr) 2018-08-02

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