EP3492691A1 - Générateur d'impulsions de pression d'écoulement complet régulé pour dispositif de mesure en forage (« measure while drilling » ou mwd) - Google Patents

Générateur d'impulsions de pression d'écoulement complet régulé pour dispositif de mesure en forage (« measure while drilling » ou mwd) Download PDF

Info

Publication number
EP3492691A1
EP3492691A1 EP19150555.1A EP19150555A EP3492691A1 EP 3492691 A1 EP3492691 A1 EP 3492691A1 EP 19150555 A EP19150555 A EP 19150555A EP 3492691 A1 EP3492691 A1 EP 3492691A1
Authority
EP
European Patent Office
Prior art keywords
pilot
flow
fluid
pressure
main
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.)
Withdrawn
Application number
EP19150555.1A
Other languages
German (de)
English (en)
Inventor
Benjamin JENNINGS
Robert Macdonald
Gabor Vecseri
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Teledrill Inc
Original Assignee
Teledrill Inc
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
Priority claimed from US13/336,981 external-priority patent/US9133664B2/en
Priority claimed from US13/368,997 external-priority patent/US9309762B2/en
Application filed by Teledrill Inc filed Critical Teledrill Inc
Publication of EP3492691A1 publication Critical patent/EP3492691A1/fr
Withdrawn legal-status Critical Current

Links

Images

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/10—Valve arrangements in drilling-fluid circulation systems
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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 current invention includes an apparatus and a method for creating a pulse within the drilling fluid, generally known as drilling mud, that is generated by selectively initiating flow driven bidirectional pulses within a bore pipe.
  • the device include operating a flow throttling device (FTD) that operates without a centrally located valve guide within a newly designed annular flow channel, such that the annular flow channel provides an increased area for the flow of the drilling fluid and also allows for the addition of an intelligent computerized control system using a combination of hardware and software tools with downlink capability.
  • the downlink tools may be located above or below a positive displacement motor.
  • the intelligent control system provides and maintains several parameters that effect drilling or other downhole activity efficiency (i.e.
  • the pulse received "up hole" from the tool down hole includes a series of dynamic pressure changes that provide pressure signals which can be used to interpret inclination, azimuth, gamma ray counts per second, etc. by oilfield personnel. These dynamic pressure changes and resulting signals are utilized to further increase yield in oilfield operations.
  • the system according to the preamble part of claim 1 is disclosed in US 2005/0260089 A1 .
  • US 2005/0260089 A1 discloses a method of transmitting pressure pulses from a downhole location through a flowing fluid in a wellbore.
  • a linear actuator is used to controllably move a reciprocating member axially back and forth between a first position and a second position to at least partially obstruct flow of the flowing fluid to generate the pressure pulses.
  • a reciprocating pulser for generating pressure pulses in a fluid flowing in a wellbore comprises a fluid passage that allows flow of the fluid through the pulser, and a reciprocating member.
  • a linear actuator is coupled to the reciprocating member, such that the linear actuator moves the reciprocating member in a first axial direction and then in a reverse direction to at least partially obstruct flow of the fluid through the pulser to generate pressure pulses in the flowing fluid.
  • An important advantage of the present disclosure and the associated embodiments is that it decreases sensitivity to fluid flow rate or pressure within easily achievable limits, does not require field adjustment, and is capable of creating recognizable, repeatable, reproducible, yet controlled, clean (i.e. noise free) fluid pulse signals using minimum power due to a unique flow throttling device (FTD) with a pulser that requires no guide, guide pole or other guidance system to operate the main valve, thus reducing wear, clogging and capital investment of unnecessary equipment as well as increasing longevity and dependability in the down hole portion of the MWD tool.
  • This MWD tool still utilizes battery, magneto-electric and/or turbine generated energy. The mostly unobstructed main flow in the main flow area enters with full flow into the cone without altering the main flow pattern.
  • the pulser can be programmed to operate intelligently responding based on measured sensor parameters using preprogrammed logic. Being able to control and determine pulse size, timing, and shape without ambiguity provides the user with reproducible, reliable data that results in reduced time on the rig for analysis and more reliable and efficient drilling.
  • the present disclosure involves the placement of a Measurement-While-Drilling (MWD) pulser device including a flow throttling device located within a bore pipe in a wellbore incorporating drilling fluids for directional and intelligent drilling.
  • MWD Measurement-While-Drilling
  • the pilot channel location is very different than in any prior application in that the channel is now located on the outside annulus.
  • the device include operating a flow throttling device (FTD) that operates without a centrally located valve guide within a newly designed annular flow channel, such that the annular flow channel provides an increased area for the flow of the drilling fluid and also allows for the addition of an intelligent computerized control system using a combination of hardware and software tools with downlink capability.
  • the downlink tools may be located above or below a positive displacement motor.
  • the intelligent control system provides and maintains several parameters that effect drilling or other downhole activity efficiency (i.e. Weight on Bit, Rate of Penetration, Pulse Amplitude, Axial Vibration, Borehole Pressure, etc.) by utilizing a feedback control loop such that the pressure differentials within the collar and associated annulus of the FTD inside a bore pipe provide information for properly guided, reproducible pressure pulses that exhibit little or no associated signal noise.
  • the pulse received "up hole" from the tool down hole includes a series of dynamic pressure changes that provide pressure signals which can be used to interpret inclination, azimuth, gamma ray counts per second, etc. by oilfield personnel. These dynamic pressure changes and resulting signals are utilized to further increase yield in oilfield operations.
  • the present invention also discloses a novel device for creating pulses in drilling fluid media flowing through a drill string.
  • Past devices currently in use, require springs or solenoids to assist in creating pulses and are primarily located in the main drilling fluid flow channel.
  • US Patents 7,180,826 and US Application Number 2007/0104030A1 to Kusko, et. al. disclose a fully functional pulser system that requires the use of a pulser guide pole to guide and define the movement of the main valve together with a different hydraulic channel designs than that of the present application and associated invention.
  • the pilot flow for the present invention without the guide pole allows for more efficient repair and maintenance processes and also allows for quickly replacing the newly designed apparatus of the present disclosure on the well site as there is at least a 15-20 percent reduction in capital costs and the costs on the maintenance side are drastically reduced.
  • guide pole failures accounted for 60-70 percent of the downhole problems associated with the older versions of the MWD. With the guide pole elimination, reliability and longer term down hole usage increases substantially, providing a more robust tool and much more desirable MWD experience.
  • previous devices also required onsite adjustment of the flow throttling device (FTD) pulser according to the flow volume and fluid pressure and require higher energy consumption due to resistance of the fluid flow as it flows through an opened and throttled position in the drill collar.
  • FTD flow throttling device
  • the elimination of the centralized guide pole and pilot channel allows, in the current design, larger pressure differential to be created between the pilot flow and the main flow at the main valve thus increasing the control and calibration and operation of the pulser.
  • the ability to precisely control the pulser and thus the pressure pulse signals is directly related to cleaner, more distinguishable and more defined signals that can be easier detected and decoded up hole.
  • Additional featured benefits of the present inventive device and associated methods include having a pulser tool above and/or below the PDM (positive displacement motor) allowing for intelligence gathering and transmitting of real time data by using the pulser above the motor and as an efficient drilling tool with data being stored in memory below the motor with monitored borehole pressure, acceleration, as well as downhole WOB control, among other drilling parameters.
  • Drilling parameter control is accomplished by using a set point and threshold for the given parameter and adjusting based on effects provided by the shock wave generated using the FTD. Master control is provided uphole or downhole with a feedback loop from the surface of the well or from intelligent programming incorporated in the pulsing device in the BHA above and/or below the PDM.
  • the device provided by the current invention allows for the use of a flow throttling device that moves from an initial position to an intermediate and final position in both the upward and downward direction corresponding to the direction of the fluid flow.
  • the present invention still avoids the use of springs, the use of which are described in U.S. Pat. No's 3,958,217 , 4,901,290 , and 5,040,155 .
  • the pulser assembly 400 device illustrated produces pressure pulses in drilling fluid main flow 110 flowing through a tubular hang-off collar 120 and includes a pilot flow upper annulus 160.
  • the flow cone 170 is secured to the inner diameter of the hang off collar 120.
  • Major assemblies of the MWD are shown as provided including aligned within the bore hole the pilot flow screen assembly 135 and main valve actuator assembly 229 and pilot actuator assembly 335.
  • FIG. 1 starting from an outside position and moving toward the center of the main valve actuator assembly 226 comprising a main valve 190, a main valve pressure chamber 200, a main valve support block 350, main valve seals 225 and flow guide seal 240.
  • the same figure shows the main valve feed channel 220, the pilot orifice 250, pilot valve 260, pilot flow shield 270, bellows 280 and the anti-rotation block 290, as well as a cylindrical support shoulder 325 and tool face alignment key 295 that exists below the pilot flow shield 270 for keeping the pulser assembly centered within the bore hole.
  • This figure also shows the passage of the main flow 110 past the pilot flow screen 130 through the main flow entrance 150, into the flow cone 170, through the main orifice 180 into and around the main valve 190, past the main valve pressure chamber 200, past the main valve seals 225 through the main valve support block 350, after which it combines with the pilot exit flow 320 to become the main exit flow 340.
  • the pilot flow 100 flows through the pilot flow screen 130 into the pilot flow screen chamber 140, through the pilot flow upper annulus 160, through the pilot flow lower annulus 210 and into the pilot flow inlet channel 230, where it then flows up into the main valve feed channel 220 until it reaches the main valve pressure chamber 200 where it flows back down the main valve feed channel 220, through the pilot flow exit channel 360, through the pilot orifice 250, past the pilot valve 260 where the pilot exit flow 320 flows over the pilot flow shield 270 where it combines with the main flow 110 to become the main exit flow 340 as it exits the pilot valve support block 330 and flows on either side of the rotary magnetic coupling 300, past the drive shaft and the motor 310.
  • the pilot actuator assembly 335 includes a magnetic pressure cup 370, and encompasses the rotary magnetic coupling 300.
  • the magnetic pressure cup 370 and the rotary magnetic coupling 300 may comprise several magnets, or one or more components of magnetic or ceramic material exhibiting several magnetic poles within a single component.
  • the magnets are located and positioned in such a manner that the rotatry movement or the magnetic pressure cup 370 linearly and axially moves the pilot valve 260.
  • the rotary magnetic coupling 300 is actuated by the adjacent drive shaft 305.
  • Figure 2 provides details of the pulser assembly in the open position; the pilot flow 100 and main flow 110 both flow through the pilot flow screen assembly 135 and pilot flow screen 130 where a portion of the main flow 110 flows through the pilot flow screen 130.
  • the pilot flow 100 flows through the pilot flow screen chamber 140 and into the pilot flow upper annulus 160. Pilot flow 100 and main flow 110 within the pilot flow screen assembly 135 flows through the main flow entrance 150 and through the flow cone 170 and into the main orifice 180 to allow for flow within the main valve feed channel 220.
  • Figure 3 describes the main valve actuator assembly 229 and illustrates the flow of the pilot flow 100 and main flow 110 areas with the main valve 190 in open position.
  • the main flow 110 passes through openings in the main valve support block 350 while the pilot flow 100 flows through the pilot flow lower annulus 210, into the pilot flow inlet channel 230 and into the main valve feed channel 220 which puts pressure on the main valve pressure chamber 200 when the pilot valve 260 is in closed position.
  • the pilot flow 100 then flows out through the pilot flow exit channel 360, through the pilot orifice 250 and over the pilot valve 260. Also shown are the seals 225, 226, 227, 228 &240 of the main valve actuator assembly.
  • pilot valve 260 When pilot valve 260 closes, pressure increases through the main valve feed channel 220 into the main valve pressure chamber 200.
  • the upper outer seal 227, upper inner seal 225, lower inner seal 226, lower outer seal 228 and flow guide seal 240 keep the pilot flow 100 pressure constrained and equal to the pressure that exists in main flow entrance 150 area.
  • Upper outer seal 227 and lower outer seal 228 exclude large particulates from entering into the space where the upper inner seal 225 and lower inner seal 226 reside.
  • the upper outer seal 227 and lower outer seal 228 do not support a pressure load and allow a small amount of pilot flow 100 to bypass while excluding particulates from entering the area around the upper inner seal 225 and lower inner seal 226. This eliminates pressure locking between the inner seals 225, 226 and the outer seals 227, 228.
  • the seals are protected and the clearances of the inner seals 225, 226 can be reduced to support high pressure loads.
  • Very small particulates can bypass the outer seals 227, 228, but the particulates must be very small in relative to the clearances of the inner seals 225, 226 to penetrate the space between the outer seals 227, 228 and inner seals 225, 226.
  • the Main exit flow 340 flows parallel along each side of the rotary magnetic coupling 300 which is contained within the magnetic pressure cup 370, past the drive shaft and parallel along each side of the motor 310 down toward the cylindrical support shoulder 325 that includes a tool face alignment key 295 below the pilot flow shield 270.
  • the magnetic pressure cup 370 is comprised of a non-magnetic material, and is encompassed by the outer magnets 302.
  • the outer magnets 302 may comprise several magnets, or one or more components of magnetic or ceramic material exhibiting several magnetic poles within a single component.
  • the outer magnets 302 are housed in an outer magnet housing 303 that is attached to the drive shaft.
  • Within the magnetic pressure cup 370 are housed the inner magnets 301 which are permanently connected to the pilot valve 260.
  • outer magnets 302 and the inner magnets 301 are placed so that the magnetic polar regions interact, attracting and repelling as the outer magnets 302 are moved about the inner magnets 301
  • the relational combination of magnetic poles of the moving outer magnets 302 and inner magnets 301 causes the inner magnets 301 to move the pilot valve 260 linearly and interactively without rotating.
  • the use of outer magnets 302 and inner magnets 301 to provide movement from rotational motion to linear motion also allows the motor 310 to be located in an air atmospheric environment in lieu of a lubricating fluid environment. This also allows for a decrease in the cost of the motor 310, decreased energy consumption and subsequently decreased cost of the actual MWD device. It also alleviates the possibility of flooding the sensor area of the tool with the drilling fluid like in the use of a moving mechanical seal.
  • the information flow on the Pulser Control Flow Diagram in Fig. 5 details the controllable pulser operation sequence.
  • the drilling fluid pump known as the mud pump 500 is creating the flow with a certain base line pressure. That fluid pressure is contained in the entirety of the interior 510 of the drill string, known as the bore pressure.
  • the bore pipe pressure sensor 420 is sensing this pressure increase when the pumps turn on, and send that information to the Digital Signal Processor (DSP) 540 which interprets it.
  • the DSP 540 also receives information from the annulus pressure sensor 470 which senses the drilling fluid (mud) pressure 520 as it returns to the pump 500 in the annulus 520 (outside) of the drill pipe.
  • the DSP 540 determines the correct pulser operation settings and sends that information to the pulser motor controller 550.
  • the pulser motor controller 550 adjusts the stepper motor 310 current draw, response time, acceleration, duration, revolution, etc. to correspond to the pre-programmed pulser settings 530 from the DSP 540.
  • the stepper motor 310 driven by the pulser motor controller 550 operates the pilot actuator assembly 335 from Fig. 1 .
  • the pilot actuator assembly 335 responding exactly to the pulser motor controller 550, opens and closes the main valve 190, from Fig. 1 , in the very sequence as dictated by the DSP 540.
  • the main valve 190 opening and closing creates pressure variations of the fluid pressure in the drill string on top of the bore pressure which is created by the mud pump 500.
  • the main valve 190 opening and closing also creates pressure variations of the fluid pressure in the annulus 520 of the drill string on top of the base line annulus pressure because the fluid movement restricted by the main valve 190 affects the fluid pressure downstream of the pulser assembly 400 through the drill it jets into the annulus 520 of the bore hole.
  • Both the annulus pressure sensor 470 and the bore pipe pressure sensor 420 detecting the pressure variation due to the pulsing and the pump base line pressure sends that information to the DSP 540 which determines the necessary action to be taken to adjust the pulser operation based on the pre-programmed logic.
  • the motor 310 rotates the rotary magnetic coupling 300 which transfers the rotary motion to linear motion of the pilot valve 260 by using an anti-rotation block 290.
  • the mechanism of the rotary magnetic coupling 300 is immersed in oil and is protected from the drilling fluid flow by a bellows 280 and a pilot flow shield 270.
  • pilot fluid flow is blocked and backs up as the pilot fluid in the pilot flow exit channel 360, pilot flow inlet channel 230 and in the pilot flow upper annulus 160 all the way back to the pilot flow screen 130 which is located in the lower velocity flow area due to the larger flow area of the main flow 110 and pilot flow 100 where the pilot flow fluid pressure is higher than the fluid flow through the main orifice 180.
  • the pilot fluid flow 100 in the pilot flow exit channel 360 also backs up through the main valve feed channel 220 and into the main valve pressure chamber 200.
  • the fluid pressure in the main valve pressure chamber 200 is equal to the main flow 110 pressure, but this pressure is higher relative to the pressure of the main fluid flow in the main orifice 180 in front portion of the main valve 190.
  • This differential pressure between the pilot flow flow in the main valve pressure chamber 200 area and the main flow through the main orifice 180 into the main orifice 180 causes the main valve 190 to act like a piston and to move toward closure still upward in Figure 1 causing the main orifice 180 to stop the flow of the main fluid flow 110 causing the main valve 190 to stop the main fluid flow 110 through the main orifice 180.
  • pilot flow lower annulus 210 extends to the bore pipe pressure inlet 410 located in the pilot valve support block 330 the pressure change in the pilot fluid flow reaches the bore pipe pressure sensor 420 which transmits that information through the electrical connector 440 to the pulser control electronics DSP 450.
  • the pulser controlling electronics DSP 450 together with pressure data from the annulus pressure sensor 470 adjusts the pilot valve operation based on pre-programmed logic to achieve the desired pulse characteristics.
  • the velocity of the fluid flow increases.
  • the fluid flow velocity is increased (reducing the pressure and increasing the velocity) and the pressure of the fluid is decreased relative to the entrance flows (main area vs. the orifice area) 180.
  • the pilot valve 260 is in the opened position
  • the main valve 190 is also in the opened position and allows the fluid to pass through the main orifice 180 and around the main valve 190, through the openings in the main valve support block 350 through the pilot valve support block 330 and subsequently into the main exit flow 340.
  • the information flow on the Pulser Control Flow Diagram in Fig. 5 details the controllable pulser operation sequence.
  • the drilling fluid pump known as the mud pump 500 is creating the flow with a certain base line pressure. That fluid pressure is contained in the entirety of the interior 510 of the drill string, known as the bore pressure.
  • the bore pipe pressure sensor 420 is sensing this pressure increase when the pumps turn on, and sends that information to the Digital Signal Processor (DSP) 540 which interprets it.
  • the DSP 540 also receives information from the annulus pressure sensor 470 which senses the drilling fluid (mud) pressure 520 as it returns to the pump 500 in the annulus 520 (outside) of the drill pipe.
  • the DSP 540 determines the correct pulser operation settings and sends that information to the pulser motor controller 550.
  • the pulser motor controller 550 adjusts the stepper motor 310 current draw, response time, acceleration, duration, revolution, etc. to correspond to the pre-programmed pulser settings 530 from the DSP 540.
  • the stepper motor 310 driven by the pulser motor controller 550 operates the pilot actuator assembly 335 as shown in Fig. 1 .
  • the pilot actuator assembly 335 responds directly to the pulser motor controller 550, and opens and closes the main valve 190, again shown in Fig.
  • the main valve 190 opening and closing creates pressure variations of the fluid pressure in the drill string in addition to the bore pressure which is created by the mud pump 500.
  • the main valve 190 opening and closing also creates pressure variations or fluctuations of the fluid pressure in the annulus 520 of the drill string in addition to the base line annulus pressure because the fluid movement restricted by the main valve 190 affects the fluid pressure downstream of the pulser assembly 400 through the drill as the fluid jets into the annulus 520 of the bore hole.
  • Both the annulus pressure sensor 470 and the bore pipe pressure sensor 420 detect the pressure variations exhibited by the pulsing pressures and the pump base line pressure. These variations provide signals that are sent as data information to the DSP 540 that determines the necessary action to be taken to adjust the pulser operation based on any pre-programmed logic provided.
  • the device illustrated produces pressure pulses for pulsing of the pulser within a main valve actuator assembly of the flow throttling device (FTD) in the vertical upward and downward direction using drilling fluid that flows through a tubular rental collar and an upper annulus which houses the pilot flow.
  • FTD flow throttling device
  • the passage of the main flow of the drilling fluid flows through the pilot flow screen into the main flow entrance then into the flow cone section and through the main orifice and main valve past the main valve pressure chamber, past the seals, and finally into and through the main valve support block with the flow seal guide.
  • the initial drilling fluid combines with the pilot exit fluid and together results in the exit flow of the main fluid.
  • the pilot fluid flow continues flowing through the pilot flow screen and into the pilot flow screen chamber then through the pilot flow upper annulus section, the pilot flow lower annulus section and into the pilot flow inlet channel where the fluid flows upward into the main valve feed channel until it reaches the main valve pressure chamber causing upward motion of the pulser.
  • the fluid flows back down the main valve feed channel through the pilot flow exit channel and through the pilot orifice and pilot valve at which point the fluid exits the pilot area where it flows over the pilot flow shield and combines with the main flow to comprise the main exit flow as it exits the pilot valve support block and flows down both sides of the rotary magnetic coupling, outside the magnetic pressure cup and eventually past the drive shaft and the motor.
  • the motor rotates the rotary magnetic coupling transfers rotary motion to linear motion of the pilot valve by using an anti-rotation block.
  • the mechanism of the rotary magnetic coupling is protected from the fluid flow by the use of a bellows and a pilot flow shield.
  • the pilot valve blocks and backs up the pilot fluid in the pilot flow exit channel, the pilot flow inlet channel, and in the pilot flow upper annulus, such that the fluid back up and reaches all the way back to the pilot flow screen (which is located in the lower velocity flow area due to the geometry of the larger flow area of the main flow and pilot flow sections such that the pilot flow fluid pressure is higher than the fluid flow through the main orifice).
  • the pilot fluid flow in the pilot flow exit channel also backs up through the main valve feed channel and into the main valve pressure chamber.
  • the fluid pressure in the main valve pressure chamber is now equal to the main flow pressure but the fluid pressure is higher relative to the pressure of the main fluid flow in the main orifice in the front portion of the main valve.
  • the differential pressure between the pilot flow and the main flow through the main orifice causes the main valve to act like a piston and moves toward closure of the main orifice (upward direction in the Figures provided), thereby causing the main valve to provide a stoppage of the flow of the main fluid flow within the main orifice.
  • the MWD device utilizes a turbine residing near and within the proximity of a flow diverter.
  • the flow diverter diverts drilling mud in an annular flow channel into and away from the turbine blades such that the force of the drilling mud causes the turbine blades and turbine to rotationally spin around an induction coil.
  • the induction coil generates electrical power for operating the motor and other instrumentation mentioned previously.
  • the motor is connected to the pilot actuator assembly via a drive shaft.
  • the pilot actuator assembly comprises a magnetic coupling and pilot assembly.
  • the magnetic coupling comprises outer magnets placed in direct relation to inner magnets located within the magnetic pressure cup or magnetic coupling bulkhead. The magnetic coupling translates the rotational motion of the motor, via the outer magnets to linear motion of the inner magnets via magnetic polar interaction.
  • the linear motion of the inner magnets moves the pilot assembly, comprising the pilot shaft, and pilot valve, linearly moving the pilot into the pilot seat. This action allows for closing the pilot seat, pressurizing the flow throttling device, closing the flow throttling device orifice, thereby generating a pressure pulse. Further rotation of the motor, drive shaft, via the magnetic coupling, moves the pilot assembly and pilot away from the pilot seat, depressurizing the flow throttling device sliding pressure chamber and opening the flow throttling device and completing the pressure pulse.
  • Identical operation of the pilot into and out of the pilot seat orifice can also be accomplished via linear to linear and also rotation to rotation motions of the outer magnets in relation to the inner magnets such that, for example, rotating the outer magnet to rotate the inner magnet to rotate a (rotating) pilot valve causing changes in the pilot pressure, thereby pushing the FTD (flow throttling device) up or down.
  • Unique features of the pulser include the combination of middle and lower inner flow channels, flow throttling device, bellows, and upper and lower flow connecting channels possessing angled outlet openings that helps create signals transitioning from both the sealed (closed) and unsealed (open) positions. Additional unique features include a flow cone for transitional flow and a sliding pressure chamber designed to allow for generation of the pressure pulses. The flow throttling device slides axially on a pulser guide pole being pushed by the pressure generated in the sliding pressure chamber when the pilot is in the seated position. Additional data (and increased bit rate) is generated by allowing the fluid to quickly back flow through the unique connecting channel openings when the pilot is in the open position.
  • Bi-directional axial movement of the poppet assembly is generated by rotating the motor causing magnets to convert the rotational motion to linear motion which opens and closes the pilot valve.
  • the signal generated provides higher data rate in comparison with conventional pulsers because of the bi-directional pulse feature. Cleaner signals are transmitted because the pulse is developed in near-laminar flow within the uniquely designed flow channels and a water hammer effect due to the small amount of time required to close the flow throttling device.
  • the method for generating pressure pulses in a drilling fluid flowing downward within a drill string includes starting at an initial first position wherein a pilot (that can seat within a pilot seat which resides at the bottom of the middle inner flow channel) within a lower inner flow channel is not initially engaged with the pilot seat. The pilot is held in this position with the magnetic coupling. The next step involves rotating the motor causing the magnetic fields of the outer and inner magnets to move the pilot actuator assembly thereby moving the pilot into an engaged position with the pilot seat.
  • This motion seals a lower inner flow channel from the middle inner flow channel and forces the inner fluid into a pair of upper connecting flow channels, expanding the sliding pressure chamber, causing a flow throttling device to move up toward a middle annular flow channel and stopping before the orifice seat, thereby causing a flow restriction.
  • the flow restriction causes a pressure pulse or pressure increase transmitted uphole.
  • fluid remains in the exterior of the lower connecting flow channels, thus reducing the pressure drop across the, pilot seat. This allows for minimal force requirements for holding the pilot in the closed position. In the final position, the pilot moves back to the original or first position away from the pilot orifice while allowing fluid to flow through the second set of lower connecting flow channels within the lower inner flow channel.
  • An alternative embodiment includes the motor connected to a drive shaft through a mechanical device such as a worm gear, barrel cam face cam or other mechanical means for converting the rotational motion of the motor into linear motion to propel the pilot actuator assembly.
  • a mechanical device such as a worm gear, barrel cam face cam or other mechanical means for converting the rotational motion of the motor into linear motion to propel the pilot actuator assembly.
  • the main flow and pilot flow enters the main flow entrance and flows through into the flow cone area where the velocity of the fluid flow increases such that the fluid reaches the main orifice and the fluid flow velocity is increased (reducing the pressure and increasing the velocity of the fluid).
  • the pressure of the fluid is decreased relative to the entrance flows (main area vs. the orifice area).
  • the pilot valve When the pilot valve is in the opened position, the main valve is also in the open position and allows the fluid to pass through the main orifice and around the main valve and through the openings in the main valve support block allowing for the fluid to flow through the opening of the pilot and through the pilot valve support block. Subsequently the fluid flows into the main exit flow channel.
  • the device illustrated produces pressure pulses in drilling fluid flowing through a tubular drill collar and upper annular drill collar flow channel.
  • the flow cone is secured to the inner diameter of the drill collar.
  • the centralizer secures the lower portion of the pulse generating device and is comprised of a non-magnetic, rigid, wear resistant material with outer flow channels.
  • the present invention allows for several sized FTD's to be placed in a drilling collar, thereby allowing for different flow restrictions and/or frequencies which will cause an exponential increase in the data rate that can be transmitted up hole.
  • the linear motion of the flow throttling device axially is both up and down (along a vertical axial and radial direction without the use of a guide pole).
  • the signal provided in conventional technology is by a pulse that can be received up hole by use of a pressure transducer that is able to differentiate pressure pulses (generated downhole). These uphole pulses are then converted into useful signals providing information for the oilfield operators, such as gamma ray counts per second, azimuth, etc.
  • Another advantage of the present invention is the ability to create a clean (essentially free of noise) pulse signal that is essentially independent of the fluid flow rate or pressure within the drill collar. The present invention thereby allows for pulses of varying amplitudes (in pressure) and frequencies to significantly increase the bit rate.
  • An additional embodiment of the present invention includes a system comprising a controllable pulser that operates sequentially within a downhole assembly such as a drill pipe, that enhances operational efficiency in the removal of hydrocarbon deposits, where the system comprises; a fluid, fluid flow, and a fluid drilling pump which when combined creates fluid flow into a bore pipe annulus such that a base line bore pipe pressure is created and such that fluid flow and bore pipe pressure is contained entirely within a drill string and wherein bore pipe pressure increases and is measured with one or more pressure sensors for sensing bore pipe pressure such that pressure sensor(s) send information to a digital signal processor (DSP) that receives information in the form of digital data from said pressure sensor(s), and wherein pulser utilize computerized instructional software and hardware components included in the digital signal processor (DSP) so that controllable sequential operation of the pulser is obtained utilizing one or more pressure sensors located within a bore pipe annulus located within an outer annular portion of the drill pipe.
  • DSP digital signal processor
  • the pre-programmed logic is embedded within the software components of the DSP such that the input data supplied to the DSP by one or more pressure sensors correctly determines pulser operation settings allowing for the sending of data that is subsequently received and interpreted by the DSP for controlling a pulser motor controller, wherein the motor controller controls adjustment of a stepper motor's current draw, response time, acceleration, duration, and revolutions corresponding with pre-programmed pulser settings provided by the software components of the DSP and wherein pulses are developed with a pilot actuator assembly that identically match the pulses of the pulser motor controller and operates the opening and closing of a main valve in a sequence dictated by the DSP, thereby creating pressure variations of the fluid pressure resulting from fluid flowing within the drill string and within the bore pipe.
  • the main valve opens and closes, thereby creating pressure variations of the fluid pressure in the annulus of the drill string in addition to the base line bore pipe pressure due to fluid flow movement restricted by the main valve, wherein the fluid pressure is also affected downstream of the pulser assembly as the fluid flows through a drill bit and jets within said bore hole pipe annulus.

Landscapes

  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics (AREA)
  • Remote Sensing (AREA)
  • Acoustics & Sound (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)
EP19150555.1A 2011-12-23 2013-02-08 Générateur d'impulsions de pression d'écoulement complet régulé pour dispositif de mesure en forage (« measure while drilling » ou mwd) Withdrawn EP3492691A1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US13/336,981 US9133664B2 (en) 2011-08-31 2011-12-23 Controlled pressure pulser for coiled tubing applications
US13/368,997 US9309762B2 (en) 2011-08-31 2012-08-21 Controlled full flow pressure pulser for measurement while drilling (MWD) device
PCT/US2013/025323 WO2013148005A1 (fr) 2011-12-23 2013-02-08 Générateur d'impulsions de pression d'écoulement complet régulé pour dispositif de mesure en forage (« measure while drilling » ou mwd)
EP13769354.5A EP2815063B1 (fr) 2011-12-23 2013-02-08 Générateur d'impulsions de pression d'écoulement complet régulé pour dispositif de mesure en forage (« measure while drilling » ou mwd)

Related Parent Applications (1)

Application Number Title Priority Date Filing Date
EP13769354.5A Division EP2815063B1 (fr) 2011-12-23 2013-02-08 Générateur d'impulsions de pression d'écoulement complet régulé pour dispositif de mesure en forage (« measure while drilling » ou mwd)

Publications (1)

Publication Number Publication Date
EP3492691A1 true EP3492691A1 (fr) 2019-06-05

Family

ID=49260987

Family Applications (2)

Application Number Title Priority Date Filing Date
EP13769354.5A Active EP2815063B1 (fr) 2011-12-23 2013-02-08 Générateur d'impulsions de pression d'écoulement complet régulé pour dispositif de mesure en forage (« measure while drilling » ou mwd)
EP19150555.1A Withdrawn EP3492691A1 (fr) 2011-12-23 2013-02-08 Générateur d'impulsions de pression d'écoulement complet régulé pour dispositif de mesure en forage (« measure while drilling » ou mwd)

Family Applications Before (1)

Application Number Title Priority Date Filing Date
EP13769354.5A Active EP2815063B1 (fr) 2011-12-23 2013-02-08 Générateur d'impulsions de pression d'écoulement complet régulé pour dispositif de mesure en forage (« measure while drilling » ou mwd)

Country Status (3)

Country Link
EP (2) EP2815063B1 (fr)
CA (1) CA2896287C (fr)
WO (1) WO2013148005A1 (fr)

Families Citing this family (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9673891B2 (en) 2014-05-09 2017-06-06 Telefonaktiebolaget Lm Ericsson (Publ) Code division multiple access (CDMA) overlay to other multiplexing scheme
CN105672992A (zh) * 2014-05-29 2016-06-15 中国石油集团钻井工程技术研究院 一种用于实现钻井全过程的环空压力测量方法
US12049819B2 (en) * 2019-07-08 2024-07-30 Halliburton Energy Services, Inc. Direct drive for a reservoir fluid pump
CN110318669B (zh) * 2019-08-06 2024-02-27 吉林大学 一种用于冰架底部的仰孔热水钻进系统
CN112627806B (zh) * 2019-10-08 2023-09-26 中国石油天然气股份有限公司 一种移动式电点火器出井检测装置及其使用方法

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3958217A (en) 1974-05-10 1976-05-18 Teleco Inc. Pilot operated mud-pulse valve
US4901290A (en) 1987-05-09 1990-02-13 Eastman Christensen Company Apparatus for the generation of pressure pulses in drilling mud compositions
US5040155A (en) 1989-08-16 1991-08-13 Baker Hughes Incorporated Double guided mud pulse valve
US20050260089A1 (en) 2001-03-13 2005-11-24 Baker Hughes Incorporated Reciprocating pulser for mud pulse telemetry
US7180826B2 (en) 2004-10-01 2007-02-20 Teledrill Inc. Measurement while drilling bi-directional pulser operating in a near laminar annular flow channel
US20100157735A1 (en) * 2006-11-02 2010-06-24 Victor Laing Allan Apparatus for creating pressure pulses in the fluid of a bore hole

Family Cites Families (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE69425008T2 (de) * 1993-03-26 2000-11-02 Halliburton Energy Services, Inc. Digitale Schlammpulstelemetrieanordnung
US6002643A (en) * 1997-08-19 1999-12-14 Computalog Limited Pulser
RU2186210C2 (ru) * 2000-09-29 2002-07-27 Закрытое акционерное общество Научно-производственная фирма "Самарские Горизонты" Телеметрическая система, использующая для передачи информации положительные импульсы давления промывочной жидкости

Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3958217A (en) 1974-05-10 1976-05-18 Teleco Inc. Pilot operated mud-pulse valve
US4901290A (en) 1987-05-09 1990-02-13 Eastman Christensen Company Apparatus for the generation of pressure pulses in drilling mud compositions
US5040155A (en) 1989-08-16 1991-08-13 Baker Hughes Incorporated Double guided mud pulse valve
US20050260089A1 (en) 2001-03-13 2005-11-24 Baker Hughes Incorporated Reciprocating pulser for mud pulse telemetry
US7180826B2 (en) 2004-10-01 2007-02-20 Teledrill Inc. Measurement while drilling bi-directional pulser operating in a near laminar annular flow channel
US20070104030A1 (en) 2004-10-01 2007-05-10 Teledrill Inc. Measurement while drilling bi-directional pulser operating in a near laminar annular flow channel
US20100157735A1 (en) * 2006-11-02 2010-06-24 Victor Laing Allan Apparatus for creating pressure pulses in the fluid of a bore hole

Also Published As

Publication number Publication date
EP2815063B1 (fr) 2019-01-09
WO2013148005A1 (fr) 2013-10-03
EP2815063A1 (fr) 2014-12-24
CA2896287C (fr) 2020-03-24
EP2815063A4 (fr) 2016-03-23
CA2896287A1 (fr) 2013-10-03

Similar Documents

Publication Publication Date Title
US9013957B2 (en) Full flow pulser for measurement while drilling (MWD) device
US9309762B2 (en) Controlled full flow pressure pulser for measurement while drilling (MWD) device
EP2106559B1 (fr) Impulseur pour mesures en cours de forage a turbine generatrice de courant
CA2609922C (fr) Mesure en cours de forage de pulseur bidirectionnel fonctionnant dans un canal d'ecoulement quasi laminaire annulaire
US10689976B2 (en) Hydraulically assisted pulser system and related methods
US7836948B2 (en) Flow hydraulic amplification for a pulsing, fracturing, and drilling (PFD) device
US20090114396A1 (en) Wellsite measurement and control while producing device
EP2148975B1 (fr) Amplification hydraulique d'écoulement pour un dispositif d'émission d'impulsions, de fracturation, et de forage (pfd)
US20190316465A1 (en) Controlled Pressure Pulser for Coiled Tubing Measurement While Drilling Applications
EP2815063B1 (fr) Générateur d'impulsions de pression d'écoulement complet régulé pour dispositif de mesure en forage (« measure while drilling » ou mwd)
WO2015174951A1 (fr) Procédé et appareil de génération d'impulsions dans une colonne de fluide
CA2952909C (fr) Generateur d'impulsions de pression controlee pour mesures de tubages enroules dans des applications de forage
US10633968B2 (en) Controlled pressure pulser for coiled tubing measurement while drilling applications
WO2020198278A1 (fr)

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE APPLICATION HAS BEEN PUBLISHED

AC Divisional application: reference to earlier application

Ref document number: 2815063

Country of ref document: EP

Kind code of ref document: P

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: REQUEST FOR EXAMINATION WAS MADE

17P Request for examination filed

Effective date: 20191204

RBV Designated contracting states (corrected)

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: EXAMINATION IS IN PROGRESS

17Q First examination report despatched

Effective date: 20200622

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: EXAMINATION IS IN PROGRESS

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE APPLICATION IS DEEMED TO BE WITHDRAWN

18D Application deemed to be withdrawn

Effective date: 20210303