WO2015160355A1 - Générateur d'impulsions de pression contrôlée pour mesures de tubages enroulés dans des applications de forage - Google Patents

Générateur d'impulsions de pression contrôlée pour mesures de tubages enroulés dans des applications de forage Download PDF

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Publication number
WO2015160355A1
WO2015160355A1 PCT/US2014/034554 US2014034554W WO2015160355A1 WO 2015160355 A1 WO2015160355 A1 WO 2015160355A1 US 2014034554 W US2014034554 W US 2014034554W WO 2015160355 A1 WO2015160355 A1 WO 2015160355A1
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WO
WIPO (PCT)
Prior art keywords
pilot
fluid
flow
pressure
main valve
Prior art date
Application number
PCT/US2014/034554
Other languages
English (en)
Inventor
Robert Macdonald
Gabor Vecseri
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
Application filed by Teledrill, Inc. filed Critical Teledrill, Inc.
Priority to PCT/US2014/034554 priority Critical patent/WO2015160355A1/fr
Priority to EP14889611.1A priority patent/EP3132113A4/fr
Priority to CA2952909A priority patent/CA2952909C/fr
Publication of WO2015160355A1 publication Critical patent/WO2015160355A1/fr

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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
    • E21B47/12—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
    • E21B47/24—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 by positive mud pulses using a flow restricting valve within the drill pipe

Definitions

  • the current invention includes a Coiled Tubing Measurement While Drilling Flow Throttling Device (CT-MWD-FTD), herein referred to as "the tool”, and a method for controlling a pulse created within drilling fluid or drilling mud traveling along the internal portion of a coiled tubing (CT) string.
  • CT-MWD-FTD Coiled Tubing Measurement While Drilling Flow Throttling Device
  • the pulse is normally generated by the use of a pulser, selectively initiating flow driven bi-directional pulses due to proper geometric mechanical designs within a pulser,
  • a telemetric pulse signal is received at the surface from the use of the tool down hole and includes information necessary for the field personnel during the well operation.
  • the telemetric pulses produced by the pulser also create momentary axial loads on the bottom hole assembly (BHA) and along the coiled tubing string, thus reducing friction and enhancing extended reach within the wellbore.
  • BHA bottom hole assembly
  • This invention relates generally to the completion of wellbores. More particularly, this invention relates to new and improved methods and devices for completion, deepening, fracing, reentering and plug milling of the wellbore. This invention finds particular utility in the completion of horizontal wells. Notwithstanding previous attempts at obtaining cost effective and workable horizontal well completions, there continues to be a need for increasing horizontal well departure to increase, for example, unconventional shale plays - which are wells exhibiting low permeability and therefore requiring horizontal laterals increasing in length to maximize reservoir contact. With increased lateral length, the number of zones fractured increases proportionally.
  • the coiled tubing is typically in a stable helical spiral in the wellbore.
  • the operator sending the additional coiled tubing (and weight from the surface) will have to overcome greater static loads leading to a longer and inconsistent transmission of load to the bit.
  • the onset of these two effects is controlled by several factors including; CT wall thickness, wellbore deviation and build angle, completion size, CT/completion contact friction drag, fluid drag, debris, and bottom hole assembly (BHA) weight and size.
  • CT with an outer diameter less than 4 inches tends to buckle due to easier helical spiraling, thus increasing the friction caused by increased contact surface area along the wall of the bore hole.
  • CT outer diameters greater than 4 inches are impractical due to weight and friction limitations. Friction drag is a function of CT wall thickness and diameter, leaving end loads as one of the variables most studied for manipulation to achieve better well completion.
  • the need to effectively overcome these challenges regarding both lateral reach and improved plug milling efficiency has led to the development of the CT-MWD-FTD tool of the present disclosure.
  • the tool allows for improved methods that provide better well completions, achieving extended reach, communicating operational information, better rate and direction of penetration with proper WOB, as well as providing for controlled pulsing in an as-needed (on demand) manner.
  • CT Coiled Tubing
  • Newer technology incorporated with CT has included the use of water hammer devices producing a force when the drilling fluid is suddenly stopped or interrupted by the sudden closing of a valve. This force created by the sudden closing of the valve can be used to pull the coiled tubing deeper into the wellbore. The pull into the wellbore is created by increasing the axial stress in the coiled tubing and straightening the tubing due to momentary higher fluid pressure inside the tubing and thus reducing the frictional drag.
  • This task - generating the force by opening and closing valves - can be accomplished in many ways - and is also the partial subject of the present disclosure. To date, there is no other positive pulse pulser for CT outside of the present disclosure.
  • the present disclosure and associated embodiments allow for providing a pulser system within coiled tubing string such that the pulse amplitude increases with flow rate or overall fluid pressure within easily achievable limits, does not require field adjustment, and is capable of creating recognizable, repeatable, reproducible, clean [i.e. noise free] fluid pulse signals using minimum power due to a unique design feature.
  • the tool utilizes battery, magneto-electric and/or turbine generated energy to provide measurement while drilling (MWD), as well as controlled rate of penetration (ROP) capabilities, telemetry and axial agitation within the CT using the CT-MWD-FTD tool of the present disclosure.
  • MWD measurement while drilling
  • ROP controlled rate of penetration
  • Additional featured benefits of the present device and associated methods include using a pulser tool above the PDM (positive displacement motor) allowing for intelligence gathering, transmitting and storing of real time data in memory such as bore and annular pressure, acceleration, temperature, torque and weight-on-bit (WOB) controls.
  • the WOB is controlled by using a set point and threshold for the axial force provided by the shock wave generated by the pulser. Master control is provided from the surface via downlinking to the tool, or with a feedback loop pre-programmed into the tool to automatically adjust its settings to adjust for specific conditions.
  • the coiled tubing industry continues to be one of the fastest growing segments of the oilfield services sector, and for good reason.
  • CT growth has been driven by attractive economics, continual advances in technology, and utilization of CT to perform an ever-growing list of field operations.
  • the economic advantages of the present invention include; pulse only when needed (on demand) and with as much amplitude as needed, increased efficiency of milling times of the plugs by intelligent down-hole assessments, extended reach of the CT to the end of the run, allowing for reduction of time on the well and more efficient well production, reduced coiled fatigue by eliminating or reducing CT cycling (insertion and removal of the CT from the well), high pressure pulses with little or no kinking and less friction as the pulses are fully controlled, and a lower overall power budget due to the use of the intelligent pulser.
  • an apparatus for generating pressure pulses in a drilling fluid that is flowing, enhancing, and completing a well bore within a coiled tubing assembly comprises: a CT-MWD-FTD tool longitudinally and axially positioned within the center of a main valve assembly including a main valve wherein the main valve assembly also comprises a main valve pressure chamber, and a main valve orifice with a main valve, such that the drilling fluid splits into both an inlet main fluid stream and a pilot fluid stream.
  • the pilot fluid stream flows through a pilot flow upper annulus, through a pilot flow lower annulus and into a pilot flow inlet channel, wherein the pilot fluid then flows into a main valve fluid feed channel until it reaches the main valve pressure chamber.
  • the pilot fluid flows into the main valve fluid feed channel through a pilot flow outlet channel and recombines with a main flow to become a main exit flow fluid such that the main exit flow fluid then passes around a coupling mechanism toward a motor housing and wherein one or more annular pressure sensors measuring the pressure of flowing fluid is located inside a sensor sub assembly enabling sensors to control flow throttling devices to generate controllable, large, rapid pulses.
  • the pulses provide for well-developed signals easily distinguished from any noise resulting from other vibrations due to nearby equipment within the borehole or exterior to the borehole, or within the coiled tubing assembly, wherein the signals also are capable of providing indications regarding dimensions of height, width and shape of the pulses.
  • annular pressure ports a mating area for electrical wiring of the annular pressure sensors exist within annular pressure ports and wherein the ports are sealed off insuring that the annular pressure sensors within the sensor sub assembly receive and sense only the annular pressure within the annular pressure ports.
  • the mating area for electrical wiring for the bore pressure sensors exist within bore pressure ports and wherein the ports are sealed off insuring that the bore pressure sensors within the sensor sub assembly receive and sense only bore pressure within the bore pressure ports.
  • the mating area for electrical wiring for weight-on-bit/axial force sensors exist within force sensor ports wherein the force sensor ports are sealed off, insuring that the force sensors within the sensor sub assembly receive and sense only a force within the force sensor ports.
  • the mating area for electrical wiring for torque sensors exist within torque sensor ports wherein the ports are sealed off insuring that the torque sensors within the sensor sub assembly receive and sense only torque within the torque sensor ports.
  • the electrical wiring for the annular pressure sensors are sealed off from flow of the main exit flow fluid and wherein the wiring is routed to and connected to an electrical connector.
  • the electrical wiring of the bore pressure sensors are sealed off from the flow of the main exit flow fluid and wherein the wiring is routed to and connected to an electrical connector.
  • the electrical wiring of the weight-on-bit/force sensors are sealed off from the flow of the main exit flow fluid and wherein the wires are routed to and connected to an electrical connector.
  • the electrical wiring of the torque sensors are sealed off from the flow of the main exit flow fluid and wherein the wires are routed to and connected to an electrical connector.
  • a pilot valve actuator assembly is provided.
  • the pilot valve actuator assembly is any one or more from the group consisting of; a pilot valve shaft, rotary seal shaft, rotary seals, a seal carrier, a cam shaft, pilot cams, a pilot sleeve, a pilot valve actuator assembly housing and the assembly has a pilot valve shaft.
  • a motor is connected to the drive shaft that has pilot cams attached to the shaft and move the pilot valve actuator assembly.
  • the pilot cams are sized and oriented within the pilot sleeve in order to allow for propelling the pilot valve actuator assembly so that pilot valve shaft can move in a bi-directional linear motion in order to seal or open inlet and outlet pilot flow channels.
  • Rotational motion of a motor connected to a rotating shaft that is connected to and moves the pilot cams causes channeling of the pilot fluid toward the main valve. This channeling of the fluid causes the main valve to close and also allows for the pilot fluid to move the main valve. Consequently, the motor can reverse rotational direction.
  • the pilot cams
  • the apparatus generates fluid pulses such that the CT-MWD-FTD tool using the pilot valve actuator assembly provides either unidirectional or bi-directional rotary movement of the pilot valve shaft within the pilot valve actuator assembly housing.
  • the apparatus provides a flow path allowing flow of the pilot fluid through the pilot valve actuator assembly, that channels the pilot fluid toward the main valve resulting in operation of the main valve bi-directionally along the moving axis.
  • differential pressure is maximized by using a flow cone.
  • the flow cone is provided within the main valve section and provides for increasing the velocity of the drilling fluid through the main valve section. This increase in velocity causes an increase in the pressure differential and also allows for better control of the energy pulses created by opening and closing of the main valve by using the pilot valve actuator assembly.
  • a system comprising an intelligent pulser operation sequence within a coiled tubing apparatus for enhanced well bore completion within a well bore comprising; (i) a fluid drilling pump creating fluid flow at a predetermined base line bore pressure contained entirely within a drill string containing a bore pipe pressure sensor for sensing pressure increases of the fluid flow;
  • an annular pressure sensor located on the outer annular portion of a drill pipe, a bore pressure sensor within an interior flow area of the drill pipe, and an axial force sensor measuring weight-on-bit load, torque sensor, casing collar locator, gamma and other sensors wherein all sensors are located within the sensor sub assembly and are sending information to a digital signal processor (DSP) , with information being sent to the DSP before, during or after pulser operation.
  • DSP digital signal processor
  • pre-programmed logic embedded in computer software controlling DSP based upon an input signal from sensors determines via processing correct pulser operation settings and sends information to a pulser motor controller that controls adjustment of a stepper motor current draw, response time, acceleration, duration, and revolutions to correspond with pre-programmed flow pulser settings from the DSP.
  • Pre-programmed logic embedded in computer software is controlling the DSP based upon an input signal to the DSP from sensors that determine via signal processing, pulser operational settings and wherein settings are manipulated by the DSP when it sends signals to a pulser motor controller that controls adjustment of stepper motor parameters according to values generated by the group consisting of motor current draw, motor response time, motor acceleration, pressure pulse duration, and motor shaft revolutions.
  • Flow pulses are developed using a pilot actuator assembly responding exactly to a pulser motor controller that operates opening and closing of a main valve located within the wellbore thereby controlling fluid flow through the pilot valve actuator assembly by a sequence dictated by computer software working with said DSP, thereby creating positive pressure variations of fluid pressure.
  • annulus pressure sensor and bore pipe pressure sensor detect pressure variations due to pulsing flow within coiled tubing apparatus that is compared with pump base line pressure and sends pressure variation information to the DSP to adjust pulser operation and avoid excessive water hammer.
  • Force sensors and torque sensors detect load variations due to pulsing flow within the coiled tubing apparatus that is compared with base line load and sends load variation information to the DSP for determining actions to adjust pulser operations and avoid excessive water hammer.
  • the DSP collects, records, and stores data in a computer memory device located within or remote from the DSP during operation and wherein the DSP allows for downloading and analyzing the data.
  • Intelligent pulser operation sequences within coiled tubing apparatus provides axial agitation allowing for friction reduction capable of logging sensor data into the computer memory device.
  • a logging tool for data logging wherein the data is down hole sensing data when no pulsing is occurring, thereby allowing for real time telemetry or when axial friction reduction agitation is required.
  • the coiled tubing operation and system includes a wireline connection that provides power and data communications to the coiled tubing apparatus.
  • a mechanical device providing for a tool that guides fluid to directly drive the pilot valve actuator assembly, actuating the main valve and creating pulses of predetermined amplitudes, rates, and duration, thereby creating axial agitation BRIEF DESCRIPTION OF THE DRAWINGS
  • Figure 1 is a cross-sectional view of the full flow CT-MWD-FTD tool.
  • Figure 2 is an enlarged cross-sectional view of the main valve section.
  • Figure 3a is an enlarged cross-sectional view of the pilot valve section in relation to the main valve section.
  • Figure 3b is a more complete view of the pilot valve section.
  • Figure 4 is a cross-sectional view of the electronics section of the CT-MWD-FTD tool.
  • Figure 5 is an illustrated view of the power unit or battery section of the CT-MWD-FTD tool.
  • the complete CT-MWD-FTD tool [100] is provided as shown.
  • the CT-MWD-FTD tool [100] has two major sections; the upper pipe portion [120] and the lower pipe portion [140].
  • Sections of the CT-MWD-FTD tool [100] assembly housed within the upper pipe portion [120] include the main valve section [122], the pilot valve section [126], and a portion of the electronics section [128] to include the motor [130].
  • the CT-MWD-FTD tool [100] connects to the coiled tubing [not shown] via the upper string connection [132]. In the direction of the fluid flow, as generally referenced, the fluid enters the tool at the top of the CT-MWD-FTD tool [100].
  • the connection of the upper pipe portion [120] and the lower pipe portion [140] is obtained.
  • Sections of the CT-MWD-FTD tool [100] housed within the lower pipe portion [140] are part of the electronics section [128] and the power unit or the battery section [142].
  • the lower string connection [150] that connects to the down hole motor driving the mill or bit.
  • Figure 2 provides an enlarged view of the upper string connection [132], which is fitted to the upper pipe [200], and the main valve section [122].
  • the main valve [206] is actuated by a spring [207] assisted main valve plunger [208] which is attached to the main valve [206].
  • the main valve [206] and the main valve plunger [208], with spring [207] are located in the main valve housing [210] within the upper pipe [200] in the main valve section [122] and further located within the main valve pressure chamber housing [213] with the conical end of the main valve extending from the main valve pressure chamber housing [213] into the main valve orifice [204].
  • Within the main valve pressure chamber housing [213] is the main valve pressure chamber [209] which fully houses the spring [207] assisted main valve plunger [208].
  • the flow inlet cone [202] has radial apertures [21 1] located along the circumferential area of the flow inlet cone [202].
  • radial apertures [21 1] located along the circumferential area of the flow inlet cone [202].
  • Pilot fluid enters the interior of the main valve housing [210] along the pulser pipe [270] through the radial apertures [211]. This pilot fluid has an increased velocity resulting in higher pressure differentials than that of the main fluid at the throat of the main valve orifice [204].
  • the fluid flowing through the interior of the CT-MWD-FTD tool [100] operates the main valve [206], positioned within the upper pipe [200] in the main valve section [122], using pilot fluid channeled through the pilot valve section [126] shown in Figure 3a.
  • the main valve [206] is operated by a hydraulic feed-back controlled by the pilot valve section [126].
  • the main components of the pilot valve section [126] are enclosed in the pilot valve actuator assembly housing [302].
  • the rotary seal shaft [304], supported by thrust bearings [306] has a front (smaller) shaft portion that functions within the seal carrier [308] and a back (larger) portion which is attached to a drive shaft [305] with a flex coupling [309].
  • the pilot fluid continuously flows through the pilot valve section [126] causing the opening or closing of the main valve [206] by using electronic controls.
  • FIG. 3b provides further detail of the pilot valve section [126].
  • the seal carrier [308] contains the rotary seals [310].
  • the pilot valve actuator assembly [302] includes a pilot outlet cam [314] and a pilot inlet cam [316] mounted to the assembly.
  • the combination of the pilot valve shaft, pilot outlet cam and pilot inlet cam (312, 314, 316) provides the pilot valve actuator assembly [317].
  • the cam valves [314, 316] rotate inside a pilot sleeve [318] which contains additional circular openings (holes) located radially over the cam valves [314, 316] allowing fluid to pass through the cam as the cam valves [314, 316] rotate over or away from the holes in the pilot sleeve [318].
  • the pilot fluid enters the pilot flow inlet channel [320] where it enters openings in the pilot sleeve [318].
  • the inlet channel is closed off by the pilot inlet cam [316] which is rotated by the pilot valve shaft [312].
  • the pilot valve shaft [312] rotates the pilot inlet cam [316] away from the opening to the pilot flow inlet channel [320]
  • the pilot fluid is able to enter into the interior of the pilot sleeve [318], which is the main valve fluid feed channel [324].
  • pilot outlet cam [314] which is rigidly attached to the pilot valve shaft [312] rotates to close off the opening in the pilot sleeve [318] to the pilot flow outlet channel [322]. This allows for capturing the higher pressure pilot fluid inside the pilot sleeve [318] and creates pressure on the main valve plunger [208] which moves the main valve [206] to close the main flow through the main valve orifice [204].
  • FIG 4 illustrates the electronics section [128] of the CT-MWD-FTD tool [100]. Power is routed in the interior of the assembly through the sensor sub assembly [402] into the electronics [404]. Based on input from the sensor sub assembly [402], the electronics [404] run the motor [130] within the motor housing [407] which in turn rotates the pilot valve shaft [312] according to coding pattern programmed in the electronics [404]. The speed and duration of the pilot inlet cam [316] opening and simultaneously the pilot outlet cam [314] closing is controlled by the electronics [404] based on preprogrammed pattern and sensor input data.
  • the motor [130] rotates the pilot valve shaft [312] through the rotary seal shaft [304] and the drive shaft [305] to move the pilot inlet cam [316] to close off the inflow of the pilot fluid into the interior chamber of the pilot sleeve [318], and simultaneously move the pilot outlet cam [314] to open to the pilot flow outlet channel [322] where the pilot fluid trapped in the interior of the pilot sleeve [318] can escape into the main fluid flow area and allows the main valve plunger [208] to retract with spring assistance.
  • the rate of opening and closing of the valves is dictated by the encoded information the CT-MWD-FTD tool [100] is sent up to the surface via mud pulses.
  • the CT-MWD-FTD tool [100] is also equipped with the necessary sensors needed for the operator to know down conditions while drilling.
  • the pressure sensors and the weight-on-bit and torque sensors are located in the Sensor sub assembly [402] and connected by wires running on the concentric center of the CT-MWD [100] tool to the electronics [404].
  • the temperature sensor and inclination sensor are also located in the electronics section [128].
  • Figure 5 provides the power unit or battery section [142] containing the battery [502], or in place of the battery [502] a down hole turbine (not pictured, but an included embodiment) to power the CT-MWD-FTD tool [100].
  • the battery [502] is located below the sensor sub assembly [402] sub and wired through the center of the sensor sub assembly [402] to provide power to the Electronics [404]. Additional sensors such as a casing collar locator (CCL) or gamma module can be added between the sensor sub assembly [402] and the battery [502] as needed.
  • CCL casing collar locator
  • gamma module can be added between the sensor sub assembly [402] and the battery [502] as needed.
  • the annulus pressure sensor measures the fluid pressure on the outside of the CT-MWD-FTD tool [100] where the drilling fluid (mud) is returning to the surface, while the bore pressure sensor is measuring the drilling fluid pumped down in the inside of the coiled tubing. These two measurements are the primary indicators for drilling/milling operation. The difference between these two pressures drives the drilling/milling operation.
  • the CT-MWD-FTD tool [100] sends this information up to the operator in real time via positive mud pulse telemetry and also records it and uses it to make adjustments in the pulse rate or amplitude mode.
  • the weight-on-bit force and torque sensors detect the drilling/milling progress which data is also sent to the operator real time via mud pulse and recorded.
  • the CT-MWD-FTD tool [100] could be programmed to adjust the pressure pulses of the main valve [200] to produce the necessary axial reaction force. This can be done by pre-programming the tool to operate automatically based on preset conditions.
  • the pulsing function, amplitude, rate or duration can also be manually adjusted during operation via down linking by altering the pump fluid pressure that the CT-MWD-FTD tool [100] detects and responds to accordingly.
  • the CT-MWD-FTD tool [100] acts as a memory only logging tool, recording the down hole conditions from all the sensor inputs for it to be downloaded from the tool memory after operation.
  • the pulsing mode can also be programmed to pulse a constant pattern without coded telemetry to provide axial agitation to the tool and the coiled tubing to reduce friction.
  • This mode could be preset or downlinked as required to the tool during operation.
  • a simple version of the CT-MWD-FTD tool [100] without the sensors having only a motor control of the pulser could provide a simpler and more economical alternative for friction reduction effect only.
  • a purely mechanical version of the tool where the main flow operates the main valve in a preset frequency is another variation of the tool that provides only axial agitation for friction reduction. Not having electronics, motor or battery this version of the tool is more economical for agitation of the coiled tubing only.
  • the main flow of the fluid can rotate the pilot valve actuator assembly either by a turbine or a screw.

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  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Remote Sensing (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
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  • Acoustics & Sound (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)

Abstract

L'invention concerne un appareil et un système pour générer des impulsions de pression pour améliorer et finir un puits de forage à l'intérieur d'un ensemble de tubage enroulé comprenant : un outil CT-MWD-FTD positionné longitudinalement et axialement à l'intérieur du centre d'un ensemble de soupape principale incluant une soupape principale. Le fluide de forage est ensuite divisé en un flux principal de fluide d'entrée et un flux de fluide pilote, le flux de fluide pilote s'écoulant par la suite de telle sorte que le fluide pilote se recombine avec le flux d'écoulement principal pour devenir un écoulement de fluide de sortie principal. L'écoulement de fluide de sortie principal se poursuit ensuite vers un carter de moteur dans lequel un ou plusieurs capteurs de pression annulaires mesurent la pression de l'écoulement de fluide avec des capteurs qui envoient des signaux à un Processeur de Signal Numérique (DSP) qui commande des dispositifs d'étranglement d'écoulement qui génèrent de grandes impulsions d'énergie rapides, réglables et mesurables.
PCT/US2014/034554 2014-04-17 2014-04-17 Générateur d'impulsions de pression contrôlée pour mesures de tubages enroulés dans des applications de forage WO2015160355A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
PCT/US2014/034554 WO2015160355A1 (fr) 2014-04-17 2014-04-17 Générateur d'impulsions de pression contrôlée pour mesures de tubages enroulés dans des applications de forage
EP14889611.1A EP3132113A4 (fr) 2014-04-17 2014-04-17 Générateur d'impulsions de pression contrôlée pour mesures de tubages enroulés dans des applications de forage
CA2952909A CA2952909C (fr) 2014-04-17 2014-04-17 Generateur d'impulsions de pression controlee pour mesures de tubages enroules dans des applications de forage

Applications Claiming Priority (1)

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PCT/US2014/034554 WO2015160355A1 (fr) 2014-04-17 2014-04-17 Générateur d'impulsions de pression contrôlée pour mesures de tubages enroulés dans des applications de forage

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Cited By (5)

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CN106285631A (zh) * 2016-09-28 2017-01-04 中国石油集团西部钻探工程有限公司 传感器内装式近钻头参数测量装置及其使用方法
CN107083942A (zh) * 2017-06-20 2017-08-22 成都华宏博达科技有限公司 一种低频脉冲解堵增注装置
WO2020198278A3 (fr) * 2019-03-25 2020-11-26 Teledrill, Inc. Générateur d'impulsions de pression contrôlée pour mesures de tubages enroulés dans des applications de forage
WO2021007483A1 (fr) * 2019-07-10 2021-01-14 Bench Tree Group, Llc Vanne d'impulsion de boue
CN114293978A (zh) * 2021-12-28 2022-04-08 北京信息科技大学 一种带有数据监测功能的钻头

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Cited By (9)

* Cited by examiner, † Cited by third party
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CN106285631A (zh) * 2016-09-28 2017-01-04 中国石油集团西部钻探工程有限公司 传感器内装式近钻头参数测量装置及其使用方法
CN106285631B (zh) * 2016-09-28 2023-07-14 中国石油天然气集团有限公司 传感器内装式近钻头参数测量装置及其使用方法
CN107083942A (zh) * 2017-06-20 2017-08-22 成都华宏博达科技有限公司 一种低频脉冲解堵增注装置
WO2020198278A3 (fr) * 2019-03-25 2020-11-26 Teledrill, Inc. Générateur d'impulsions de pression contrôlée pour mesures de tubages enroulés dans des applications de forage
WO2021007483A1 (fr) * 2019-07-10 2021-01-14 Bench Tree Group, Llc Vanne d'impulsion de boue
US11098580B2 (en) 2019-07-10 2021-08-24 Bench Tree Group, Llc Mud pulse valve
US11525355B2 (en) 2019-07-10 2022-12-13 Bench Tree Group, Llc Mud pulse valve
CN114293978A (zh) * 2021-12-28 2022-04-08 北京信息科技大学 一种带有数据监测功能的钻头
CN114293978B (zh) * 2021-12-28 2023-09-15 北京信息科技大学 一种带有数据监测功能的钻头

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CA2952909C (fr) 2021-06-22
CA2952909A1 (fr) 2015-10-22
EP3132113A4 (fr) 2018-01-03

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