EP2817472A1 - Turbo-foreuse à gaz orientable - Google Patents

Turbo-foreuse à gaz orientable

Info

Publication number
EP2817472A1
EP2817472A1 EP13784933.7A EP13784933A EP2817472A1 EP 2817472 A1 EP2817472 A1 EP 2817472A1 EP 13784933 A EP13784933 A EP 13784933A EP 2817472 A1 EP2817472 A1 EP 2817472A1
Authority
EP
European Patent Office
Prior art keywords
assembly
gas
turbodrill
ball
socket joint
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Withdrawn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
EP13784933.7A
Other languages
German (de)
English (en)
Other versions
EP2817472A4 (fr
Inventor
Kack J. KOLLE
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.)
Tempress Technologies Inc
Original Assignee
Tempress Technologies 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 Tempress Technologies Inc filed Critical Tempress Technologies Inc
Publication of EP2817472A1 publication Critical patent/EP2817472A1/fr
Publication of EP2817472A4 publication Critical patent/EP2817472A4/fr
Withdrawn legal-status Critical Current

Links

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
    • E21B4/00—Drives for drilling, used in the borehole
    • E21B4/02—Fluid rotary type drives
    • 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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/16—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using gaseous fluids
    • 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
    • E21B4/00—Drives for drilling, used in the borehole
    • E21B4/006—Mechanical motion converting means, e.g. reduction gearings
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes
    • E21B7/061—Deflecting the direction of boreholes the tool shaft advancing relative to a guide, e.g. a curved tube or a whipstock
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes
    • E21B7/068—Deflecting the direction of boreholes drilled by a down-hole drilling motor

Definitions

  • the present invention relates to gas turbodrills for downhole drilling operations.
  • the gas turbine motor included a single stage radial-flow turbine operating at extremely high rotary speed (i.e., at more than 100,000 rpm) and a multi-stage planetary transmission to reduce the speed and increase torque to the level needed to drive a conventional roller cone drill bit.
  • extremely high rotary speed i.e., at more than 100,000 rpm
  • multi-stage planetary transmission to reduce the speed and increase torque to the level needed to drive a conventional roller cone drill bit.
  • CTD Coiled tubing drilling
  • BHA CTD bottom hole assembly
  • DLS ft dogleg severity
  • a conventional CTD system incorporates a positive displacement motor (“PDM”) designed to operate on drilling mud.
  • This system develops significant torque and requires constant trajectory measurement using measurement while drilling tools and steering adjustment using a downhole orienter.
  • These steering systems are complex and expensive and greatly increase the length of the BHA.
  • Wire in coil systems can be required for operation on dry gas since mud pulse telemetry is not feasible when running dry gas.
  • SGTD steerable gas turbodrill
  • This approach would eliminate the need for high-cost measurement while drilling and the need for bit face orientation systems in the bottomhole assembly.
  • This tool should be relatively compact and capable of being readily steered, for example, at least through a 200 ft. lateral arc having a constant 120 ft. radius, i.e. a spur lateral.
  • a SGTD that uses dry nitrogen, and which includes a gear box, enabling operation at a high rotary speed, for efficient power conversion, and but achieving a lower rotational speed on the output of the gear box, than is possible for a gas turbine power section.
  • a gas turbodrill that includes a drill-bit section, a bearing assembly, a gearbox assembly, a gimbal assembly, a high-speed gas turbine power section and a flexible tubing string are fed downhole at the end of a string of pipe for a spur lateral drilling application.
  • the high-speed gas turbine power section in the upper section of the gas turbodrill rotates a flexible shaft that extends through a gimbal assembly.
  • the lower section of the turbodrill then contains the gearbox assembly, bearing assembly and drill-bit section.
  • the gimbal assembly serves as a flex joint for the entire gas turbodrill, which allows the drill to move at an angle away from the central wellbore, with a whipstock serving as a guide.
  • the power section is located above the gearbox which is above the gimbal section and the flexible shaft passes through the gimbal and drives the bit.
  • FIG. 1 A is a is a cross-sectional view of an exemplary openhole spur lateral drilling configuration showing the steerable gas turbodrill configured in accordance with the invention at the start of drilling the lateral;
  • FIG. IB is a cross-sectional view of an exemplary openhole spur lateral drilling configuration showing the steerable gas turbodrill in accordance with FIG. 1 A just after the spur lateral has started;
  • FIG. 1C is a cross-sectional view of an exemplary openhole spur lateral drilling configuration showing the steerable gas turbodrill in accordance with FIGS. 1 A and IB at the completion of spur lateral drilling;
  • FIG. 2A is a cross-sectional view of the exemplary steerable gas turbodrill pinch point of FIGS. 1A, IB, and 1C.
  • FIG. 2B is a cross-sectional enlarged view of the pinch point of FIG. 2A.
  • FIG. 3 is an exemplary fixed cutter bit selection chart, which is published by Dimatec Inc., for use in selecting a suitable cutter bit that can be driven by the exemplary SGTD of FIG. 1 ;
  • FIG. 4 is an exemplary graph that can be used for a gas turbodrill circulation analysis, in connection with the SGTD discussed herein;
  • FIG. 5A is a cross-sectional view of an exemplary gas turbodrill configuration
  • FIG. 5B is an enlarged cross-sectional view of the exemplary gas turbodrill configuration of FIG. 5A;
  • FIG. 5C is an enlarged cross-sectional view of a gimbal assembly of the exemplary steerable gas turbodrill configuration of FIG. 4A;
  • FIG. 5D is a side perspective view of the exemplary steerable gas turbodrill configuration of FIGS. 5A, 5B, and 5C;
  • FIG. 6A is a side-elevational view of the exemplary steerable gas turbodrill configuration.
  • FIG. 6B is a cross-sectional view of the exemplary gas turbodrill configuration of FIG. 6A.
  • Air drilling systems have advantages for borehole completion applications because this technique leaves a dry, open borehole that requires no additional cleanout and avoids water contact with the formation.
  • FIGS. 1A, IB, and 1C An exemplary embodiment of an openhole spur lateral drilling configuration for a steerable gas turbodrill ("SGTD") is shown in FIGS. 1A, IB, and 1C.
  • a wellbore 10 is shown with a liner 26 supporting a whipstock 30 using liner hanger.
  • the liner 26 and whipstock 30 may be lowered into the well and oriented using a rotary drill rig or workover rig with rotary capability which is not shown but are well known to those skilled in the arts of drilling, well completion and well intervention.
  • a drillstring 24 extends from above ground into the wellbore 10 through a liner 26 that also extends from above ground and into the wellbore.
  • the liner 26 guides the drillstring 24 through a medial portion of the wellbore 10.
  • the drillstring 24 and SGTD 28 are fed into the wellbore with the drill rig or workover rig using standard methods of handling jointed tubing.
  • the drillstring may be a continuous length of tubing that is fed into the well with a coiled tubing well service unit also well known in the art.
  • the SGTD 28 is coupled to the drillstring 24 before insertion into the wellbore 10.
  • a whipstock 30 Prior to the insertion of the SGTD 28, a whipstock 30 is run into the wellbore using liner 26.
  • the whipstock 30 can be run-in separately from liner 26 and placed with an openhole packer, not shown.
  • the whipstock 30 serves to guide the SGTD 28 and drillstring 24 at a desired angle to thereby allow access to oil and gas bearing formations that are not directly downhole from the initial wellbore 10.
  • the whipstock 30 can be directionally aligned such that the whipstock 30 will guide the SGTD 28 in a specific radial direction downhole.
  • a wireline azimuth measurement tool can be lowered into a wireline orientation shoe just above the whipstock 30 and the line can be rotated from surface to the desired azimuth of the whipstock 30.
  • the SGTD 28 has a gimbal joint 32 that allows the SGTD 28 to bend and change direction as the SGTD 28 is guided by the whipstock 30.
  • the gimbal joints 32 must allow the SGTD 28 to move through a pinch point 34 when the whipstock 30 begins changing the direction of the SGTD drill bit 36.
  • FIGS. 2A and 2B An embodiment of the pinch point 34 in FIGS. 1A-1C is shown in greater detail in FIGS. 2A and 2B.
  • the whipstock 30 incorporates a whipstock ramp 38 that guides the SGTD 28 on a lateral spur into the formation.
  • Stabilizer vanes 40 are located on the underside of the whipstock ramp 38 to hold the whipstock 30 in a position in the borehole adjacent the area intended for spur lateral drilling.
  • the stabilizer vanes 40 are sized to slide readily into the open borehole and to allow easy rotation for azimuthal orientation.
  • the vanes 40 prevent lateral motion of the whipstock 30, for example, in excess of half of an inch or a distance significant enough to prevent the drill bit 36 from kicking off from the borehole and into the formation.
  • the whipstock 30 can further have a flat spring 44 connected to a ramp 46 that pushes sideways against the SGTD as it passes through the whipstock 30.
  • the ramp 46 has gradually ramped surfaces that allow the drill bit 36 to travel up or down in the borehole and slides past the ramp 46.
  • the spring force of the flat spring 44 is chosen to overcome the frictional bending resistance of the gimbal joint 32.
  • the spring 44 has sufficient travel to allow the drill bit 36 to pass without excessively dragging on inward facing surfaces of the ramp 46.
  • a flat spring 44 is shown, springs of other types could be substituted to achieve a similar effect.
  • This system can be designed for operation off a drilling or workover rig, which can includes the following steps:
  • Cuttings are transported out of the well through the liner.
  • Air Compressor and Surface Equipment Pressure Capacity For a well at which the SGTD will initially be employed, a current available air compressor capacity is 1200 psig (8 MPa) @2500 scfm (70 scmm). The maximum pressure, consistent with safe operation on air, is 2000 psig (14 MPa). These specifications are not intended to in any way be limiting on the use or functionality of the SGTD.
  • Exemplary Bit Design The exemplary embodiment of the high-speed SGTD operates with minimal torque at high speed. The SGTD may be operated with a variety of fixed cutter or roller come bits. In a preferred embodiment of the invention surface set diamond bits are used.
  • the reactive torque from a surface set diamond bit operating at maximum rotary speed is related to the WOB, W, bit diameter, Z3 ⁇ 4, and friction, ⁇ (about 0.4 for rock drilling) according to the following equation:
  • An important requirement for the SGTD is to maintain well trajectory without any additional steering input once the drill has exited the primary wellbore.
  • Conventional PDM motors operating conventional fixed cutter bits generate enough torque to cause the drillstring to twist or wind up several revolutions so that it is not possible to predict the orientation of the SGTD bend while drilling.
  • the present SGTD invention is designed to limit the drilling torque and therefore limit the windup angle to an acceptable error level. For example if the maximum windup can be limited to less than 45 degrees, the well azimuth can be predicted to within this angle. If the drilling torque is known, the windup can be predicted and accounted for when planning the well.
  • the windup of an example SGTD BHA and drillstring makeup is provided below in Table 2.
  • the estimated torque while drilling with a 2-7/8" surface set diamond bit at about 500 lbf WOB in the Marcellus shale (15,000 psi CS) is 35 ft-lbf.
  • the analysis is shown for 3-1/2 or 2-7/8 heavy wall drill pipe. Using the larger diameter pipe cuts the windup in half and will provide more accurate azimuthal control, however the 2-7/8" drillstring may be required to accommodate return circulation. In these examples the total windup is 22 to 53 degrees.
  • This amount of windup may be acceptable or compensated for by rotating the drillstring to the right by the windup angle once the lateral is spudded, or by orienting the whipstock to the right by the same amount.
  • Table 2 Drilling Parameters and windup angle estimates.
  • FIGS. 4 A, 4B, 4C, and 4D show an exemplary embodiment of a steerable gas turbodrill ("SGTD") 40 for a spur lateral drilling application as shown in FIG. 1.
  • the gas turbodrill 40 includes a high-speed gas turbine power section 42 and a two stage planetary gearbox assembly 44 in the upper section.
  • the two-stage gearbox assembly 44 reduces the speed of turbine power section 42 output by a factor of 12: 1 and has an output shaft 46 that extends into a clamp coupling assembly 48.
  • the gearbox assembly output shaft 46 connects to a flexible shaft 50 in the clamp coupling assembly 48.
  • FIG. 4C shows an enlarged view of the gimbal assembly 54.
  • the flexible shaft 50 bends through an arc within the gimbal assembly 54.
  • the flexible shaft 50 extends through a gimbal joint 56 that enables the tool to bend through a fixed angle of up to five degrees. The precise angle and distance from the bend to the bit determines the radius of curvature of the spur lateral.
  • the gimbal joint has a ball and socket. The application of internal pressure plus the force of one or more heavy springs 58, such as Belleville washer springs acting on a lock ring with a spherical seat that presses against the ball.
  • the friction force is chosen to allow the gimbal joint to bend when subjected to side loads inside the whipstock.
  • the flexible shaft 50 couples to a bottom drill assembly 60 through a flow coupling assembly 62 that extends into a bearing assembly section 64.
  • the bottom drill assembly 60 rotates a drill bit 64.
  • the gas turbodrill 150 includes a high-speed gas turbine 152 and a clamp coupling assembly 154 in the upper section, with a gearbox 156 and a bearing assembly 158 located in the lower section of the gas turbodrill 150.
  • a flexible shaft 160 connects to the turbine output in the clamp coupling assembly 154 and extends through a gimbal 162 that enables the tool to bend through an angle of up to about 5 degrees.
  • Drill bit assembly 164 couples to the gearbox output 156 and rotates a drill bit 166.
  • Example turbine specifications are listed below, in Table 4.
  • a circulating model of the turbine in a wellbore is provided in the graph shown in FIG. 3.
  • Most of the pressure differential through the motor is developed through the bit nozzles. This approach reduces the turbine speed to a manageable level.
  • the gearbox is a conventional two-stage planetary design.
  • the output torque of the motor at maximum power is half the stall torque and this is the recommended operating condition. Operation at near the peak power will require WOB control to within 100 lbf. Over weighting the bit will cause it to stall, while underweighting will not enable it to drill.

Abstract

Cette invention concerne une turbo-foreuse à gaz présentant un boîtier incliné ajustable pour une utilisation dans une opération de forage latéral de dérivation. Ladite turbo-foreuse à gaz comprend une turbine à gaz haute vitesse, un ensemble de boîte à engrenages, un point de connexion d'arbre pivotant, une suspension à cardan comprenant un joint à rotule creux, un montage à roulement et un ensemble trépan. Ladite suspension à cardan de la turbo-foreuse à gaz admet au cours du forage une inclinaison sur un angle pouvant atteindre jusqu'à 5 degrés. L'utilisation de ressorts associée à l'application d'une pression permet de bloquer l'angle d'inclinaison quand l'opération de forage commence pour faciliter le forage latéral de dérivation.
EP13784933.7A 2012-05-04 2013-03-15 Turbo-foreuse à gaz orientable Withdrawn EP2817472A4 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201261643145P 2012-05-04 2012-05-04
PCT/US2013/032386 WO2013165612A1 (fr) 2012-05-04 2013-03-15 Turbo-foreuse à gaz orientable

Publications (2)

Publication Number Publication Date
EP2817472A1 true EP2817472A1 (fr) 2014-12-31
EP2817472A4 EP2817472A4 (fr) 2016-08-03

Family

ID=49511693

Family Applications (1)

Application Number Title Priority Date Filing Date
EP13784933.7A Withdrawn EP2817472A4 (fr) 2012-05-04 2013-03-15 Turbo-foreuse à gaz orientable

Country Status (5)

Country Link
US (1) US20130292180A1 (fr)
EP (1) EP2817472A4 (fr)
AU (1) AU2013257160A1 (fr)
CA (1) CA2868489A1 (fr)
WO (1) WO2013165612A1 (fr)

Families Citing this family (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP3209847A1 (fr) * 2014-12-29 2017-08-30 Halliburton Energy Services, Inc. Atténuation d'effets de broutage dans des outils rotatifs orientables
GB201514207D0 (en) 2015-08-11 2015-09-23 Xl Technology Ltd Directional micro lateral drilling system
CN107461151B (zh) * 2016-06-02 2019-08-30 中国石油化工股份有限公司 羽状分支井的静压侧钻装置及改造方法
US20220154536A1 (en) * 2019-03-18 2022-05-19 National Oilwell Varco, L.P. Thermal analysis of drill bits
CN110306930B (zh) * 2019-07-16 2024-01-05 乐山一拉得电网自动化有限公司 大功率变频节能钻机电控系统

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US2582403A (en) * 1945-12-17 1952-01-15 A 1 Bit & Tool Company Deflector cleansing device
US4114704A (en) * 1977-11-09 1978-09-19 Maurer Engineering Inc. Down hole well drilling tool with reversible thrust bearings
US4434862A (en) * 1981-06-04 1984-03-06 Lyons William C Downhole turbine rotary drilling device
US5004057A (en) * 1988-01-20 1991-04-02 Eastman Christensen Company Drill bit with improved steerability
US4895214A (en) * 1988-11-18 1990-01-23 Schoeffler William N Directional drilling tool
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DE3903889A1 (de) * 1989-02-10 1990-08-16 Hilti Ag Bohrvorrichtung fuer hinterschnitt
BE1003502A6 (nl) * 1989-04-28 1992-04-07 Smet Marc Jozef Maria Stuurbare boormol.
US5327961A (en) * 1992-09-25 1994-07-12 Mills Robert A R Drive head for downhole rotary pump
CA2137201A1 (fr) * 1994-12-02 1996-06-03 William Ray Wenzel Materiel pour le forage de sections courbes dans les puits
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US8607897B2 (en) * 2009-10-29 2013-12-17 Trican Well Service, Ltd. Center discharge gas turbodrill

Also Published As

Publication number Publication date
CA2868489A1 (fr) 2013-11-07
WO2013165612A1 (fr) 2013-11-07
EP2817472A4 (fr) 2016-08-03
AU2013257160A1 (en) 2014-10-30
US20130292180A1 (en) 2013-11-07

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