WO2001081707A1 - Appareil et procede permettant de faire osciller un train de forage - Google Patents

Appareil et procede permettant de faire osciller un train de forage Download PDF

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Publication number
WO2001081707A1
WO2001081707A1 PCT/GB2001/001791 GB0101791W WO0181707A1 WO 2001081707 A1 WO2001081707 A1 WO 2001081707A1 GB 0101791 W GB0101791 W GB 0101791W WO 0181707 A1 WO0181707 A1 WO 0181707A1
Authority
WO
WIPO (PCT)
Prior art keywords
drill string
fluid
drilling
pumps
well bore
Prior art date
Application number
PCT/GB2001/001791
Other languages
English (en)
Inventor
David William Tulloch
Original Assignee
David William Tulloch
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 David William Tulloch filed Critical David William Tulloch
Priority to AU48623/01A priority Critical patent/AU4862301A/en
Publication of WO2001081707A1 publication Critical patent/WO2001081707A1/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
    • E21B47/16—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 drill string or casing, e.g. by torsional acoustic waves
    • 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
    • E21B28/00—Vibration generating arrangements for boreholes or wells, e.g. for stimulating production
    • 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
    • E21B47/22—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 negative mud pulses using a pressure relieve valve between drill pipe and annulus
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/24—Drilling using vibrating or oscillating means, e.g. out-of-balance masses

Definitions

  • This invention relates to drilling methods for drilling well bores such as may be used for oil or gas production.
  • the invention finds a particular application in providing apparatus and methodology for reducing frictional forces on drilling apparatus, as it progresses and retracts within the well bore.
  • the geological structure may limit the depth of a well, as where the formation is unconsolidated or otherwise physically unstable, the well may not be able to support the various forces and loads imposed upon it by the drilling equipment.
  • location of the production reservoir relative to the drilling rig influences the depth and reach of any new well.
  • rheology i.e., the relevant fluid pressures and types of fluid in the vicinity of the well also bear upon the ability and desirability of the well depth.
  • there is nevertheless physical limitations to maximum reach or depth of a well which are imposed simply because of the equipment or apparatus used. Specifically, the load capacities of known drilling operation components and equipment are inevitably limited.
  • a drill string assembly consists of a bottom hole assembly and the drill string pipe.
  • the bottom hole assembly comprises a drill bit incorporating a cutting structure, a motor for driving the drill bit and further telemetry equipment.
  • the drill string pipe is usually made up of individual lengths of pipe (typically 30ft in length), called “singles”. For handling purposes during the drilling operation, three singles are conventionally joined together to form a "stand”.
  • a drilling assembly is made up to the blocks or top drive which is suspended from the drilling derrick on a drilling rig.
  • the top drive is controlled via the draw works by the driller and enable the drill string assembly to be moved up and down, as well as acting as the point where the drill string is made up to the flow lines.
  • Such flow lines come from mud pumps and return lines that typically run to the mud containment vessels, i.e., mud pits.
  • the well bore is drilled by a combination of the rotation of the drill bit and a directional or longitudinal force.
  • This directional force results from the weight on top of the drill bit imparted by the drill string. It will be appreciated that the deeper the hole, the greater the weight that is available of drill string suspended from the blocks. This weight is utilised efficiently in situations where the well bore is vertical, as the drill string is suspended free of the well bore wall and bears directly upon the drill bit. However, in situations where the well that is being drilled is deviated from the vertical, the force imparted by the drill string is significantly reduced, since the drill string is not suspended freely in the middle of the well bore, but lays on the wall of the drilled well bore.
  • chemical mixes tend to provide only a limited use solution, as they degrade over a period of time.
  • the chemicals are of course diluted by the other well fluids and absorbed by the well formation. They also may be chemically degraded by their inter-action or reaction with well fluids and the geology downhill.
  • centralisers Mechanical friction reducing devices are most conventionally provided as "centralisers", which are well known in the art.
  • the function of a centraliser is to physically keep the drill pipe away from well bore wall.
  • centralisers also are not entirely satisfactory, as while they may help to mitigate frictional drag, they can similarly induce other disadvantages.
  • the centraliser only provides a localised surface area, and in consequence at times tend to dig into the well bore as the drill string moves. Attempts have been made to mitigate this problem by reducing more expensive and sophisticated centralisers, with a friction reducing surface.
  • An object of the present invention therefore is to enable drill pipe to move cleanly through geological formations by reducing frictional drag.
  • a further object of the present invention is to allow for drilling operations with significantly reduced occurrence of the drilling string getting "stuck in hole", and increasing achievable drill depths beyond current limits, in the region of 20,000ft to 30,000ft. Accordingly, by meeting these objects, there is provided a reduction in the costs associated with drilling operations and an increased ability to reach reservoirs are that are not able to be reached due to current constraints, as described herein before.
  • apparatus for oscillating a drill string within a well bore comprising one or more pumps for introducing fluid into a drill string and a modifying means, wherein the modifying means induces a fluid pressure differential which is transmitted to the drill string via the pumps, and wherein the fluid pressure differential causes said drill string to oscillate.
  • the modifying means is mechanically operated.
  • the modifying means is hydraulically operated.
  • the one or more pumps communicate with at least one fluid containment vessel.
  • fluid containment vessels are mud pits.
  • the one or more pumps are connected to the drill string by flow lines.
  • the one or more pumps transfer fluid from the fluid containment vessels to the drill string via the flow lines.
  • the modifying means provides an oscillating mechanism.
  • the oscillating mechanism is provided by periodical expulsion of a predetermined volume of fluid from the pump.
  • the volume of fluid is expelled from the pump by a choking means.
  • the oscillating mechanism is provided by a turbine.
  • the turbine is accentrically positioned.
  • the oscillating mechanism is provided by an acentric helix.
  • the helix rotates under the influence of fluid and thereby provides a centrifugal force.
  • the oscillating mechanism is provided by one or more motors.
  • the one or more motors are connected to a piston.
  • the modifying means can be provided on the drill string, flow line or on the pumps.
  • a method for running a drill string into a well bore comprising creating a fluid pressure differential by mechanical or hydraulic means, and transmitting the fluid pressure differential to the drill string, the fluid pressure differential thereby causing the drill string to oscillate.
  • Figure 1 shows a schematic of a typical drilling package
  • FIGS. 2A, 2B and 20 show schematically a description of the drill pipe oscillation theory, in accordance with the present invention
  • Figure 3 provides a schematic of a triplex pump as used on drilling rigs
  • Figures 4A and 4B show a modification to mud pumps that would induce oscillation in accordance with a method of the present invention
  • FIGS. 5A and 5B demonstrate pictorially mechanical methods of inducing oscillation in accordance with the present invention
  • Figures 6A and 6B illustrate a hydraulic mechanism fitted onto a flow line between mud pipes and the drill string for inducing oscillation.
  • drilling fluid may be mixed and stored in holding tanks, namely the mud pits (2) .
  • the fluid is pumped by the mud pumps (3) from the mud pits (2) and pumped along the flow lines (8) .
  • These flow lines (8) join up with the drilling string (5) via the top drive (10) .
  • the drilling fluid or mud as it is more commonly known, has a multiple function of lubricating and cooling the drill bit which is carried at the end of the drill string (5), carrying away the cuttings and acting as a power source for the motor that drives the drill bit through the well bore (9) .
  • the drilling mud is a mixture of various chemicals, which aid in its functions, as well as helping to stabilise the formation that is being drilled through.
  • the mud returns up the annular space between the drilled bore a wall and drill string (5) .
  • the mud containing the cuttings returns to the mud pits (2) via the surface return lines; the drill cuttings being separated from the mud on the shakers (1).
  • the cuttings are disposed of via the OB line (6) and the mud is returned to the mud pits and treated by the return lines (7) . The process may then be repeated for as long as the drilling phase of the operation continues.
  • the mud pumps inject the drilling fluid through the flow lines and drill pipe in a smooth rhythmic pattern as graphically depicted in Figure 2a.
  • the mud pump (3) may operate as a reciprocating pump with multiple cylinders. As the pump operates, pistons draw fluid into the chamber on the up-stroke via intake valves. The drilling fluid is then directed into the flow line (8) to the drill string (5) on the downstroke through outlet valves. Each of the cylinders are operated progressively out of phase with each other, providing a smooth and continuing flow of drilling fluid.
  • the peaks in the graph shown in Figure 2a illustrate the action of the pump cylinders as they operate out of phase with each other.
  • a pressure differential is created and this is illustrated in the graph by the drop in the peak value at 11.
  • This pressure differential causes the drill string to oscillate by creating an uneven flow of fluid.
  • the oscillation agitates the formation particles that surround and adhere to the drill pipe assembly, creating the friction boundary, causing lamina movement.
  • This movement reduces surface resistance between the drilling assembly and formation.
  • the oscillating action of the drill string which reduces the surface resistance between the drilling assembly and formation, is analogous to one attempting to progress one's finger into a bucket of fine sand, whereby the progress is improved by moving one's finger.
  • the oscillation of the drill string (5) renders it much easier to overcome surface resistance and to allow more efficient progress of the drill string (5) in the formation.
  • Figure 2C shows, simply, how this oscillation affects the drill pipe in the well bore.
  • the drill string (12) will sit on the bottom (13) of the well bore (9) being drilled, as shown at (i) .
  • the oscillation of the drill string (5) will cause the surrounding particles in the well bore (9) to vibrate.
  • the lamina movement of the particles will create a gap (14) of movement around the drill string and reduce frictional resistance, as shown at (ii) .
  • FIG. 3 shows the basic functioning of a triplex mud pump, as is commonly used in the art.
  • the mud pump is a reciprocating pump with multiple cylinders (15) .
  • the pistons (16) in the cylinder (15) draw fluid into the chamber (17) on the upstroke, via the intake (13) .
  • Drilling fluid is then directed in to the flow line to the drill string on the downstroke through the discharge valve (18) .
  • Each of the cylinders (15) are operated progressively out of phase with each other, providing a smooth and continuous flow of drilling fluid.
  • a modifying mechanism (19) has been located on the mud pump (20) that allows a controlled volume of fluid to be evacuated from the mud pump chamber (17), via a choke manifold (21) and expelled via a through bore during the mud pump's (20) cycle.
  • the mud pump (20) operates as a reciprocating pump with multiple cylinders (15) .
  • the pistons (16) draw fluid into the chamber (17) on the upstroke via the intake (13) and this is controlled by valve (22) .
  • the drilling fluid is then directed into the flow line to the drill string on the downstroke through the outlet (23) , controlled by valve (24) .
  • Each of the cylinders are operated progressively out of phase with each other, providing a smooth continuous flow of drilling fluid.
  • the modifying device (19) acts as a periodic bleed, the volume of fluid being controlled by a choking device (21) .
  • the expelled fluid is returned to the mud containing vessels.
  • the loss of the small volume of fluid creates a pressure differential or a pulse of fluid. This pulse oscillates the fluid line and drill string by creating an uneven flow.
  • the location of the pump modification (19) and the return line (25) may be determined.
  • the return line (25) carries the excess volume back to the mud pits.
  • the modification may be located at one or all of the mud pumps.
  • the oscillator consists of a body (26) that is designed to be connected to and part of the drill strings by means of connections (27) and (28).
  • the body defines a through bore between the inlet and outlet (29) , (30) , wherein the through bore is of a diameter appropriate for corresponding with the through bore of the drill pipe in the drill string.
  • an ascentric turbine incorporating an impeller (31) .
  • the drilling fluid passes through the ascentric turbine (32) via the through bore (29) , (30) , causing the device and drill pipe and device attached to it to oscillate.
  • a mechanical oscillator consists of a body (31) that is designed to be connected to and be part of the drill string by means of connections (32), (33).
  • a through bore of appropriate diameter to suit the through bore of the drill pipe in the drill string is provided through the body of the mechanical oscillator.
  • there is no ascentric turbine rather drilling fluid passes through an ascentric helix (34) which, using the fluid's mass, causing the device in the drill pipe attached to it to oscillate.
  • a section of the mechanical oscillator is shown as (35), from which the ascentricity of the helix may be noted.
  • the drilling fluid passes through the helix section (39) , it rotates causing a vortex.
  • the speed of rotation creates a centrifugal force that starts to separate the fluid components according to their specific gravity.
  • the lighter fluid will move along a higher velocity and will pass through the restrictions (36) and (37) with relative ease.
  • the restriction (36) slows the heavy fluid even more as it passes into the chamber (38).
  • a back pressure forms at the inflow side. Due to the movement of the lighter fluids, a lower pressure cells forms at the outflow side (37) .
  • the through bore of the device at the outflow side (40) is ascentric to the through of the drill string. This enhances the oscillating movement already being induced at the inflow side (41) of the device, by use of the fluid' s mass as it passes through this section and back into the drill string.
  • Figure 6A shows an alternative hydraulic oscillating mechanism that is made up to and/or included in the flow line that connects the mud pumps to the drill string.
  • the hydraulic oscillating mechanism may consist of a fixed or variable speed motor (42) or motors.
  • the or each motor (42) may be connected to a piston (43) by a series of connecting rods (44) and (45) and/or drive wheels (46) .
  • the piston cylinders may be attached by any means deemed necessary to the flow line that runs between the mud pumps and the drill string.
  • Figure 6B shows the location of the mechanism (13) in relation to the rest of the drilling package.
  • the mechanism (130 is located on the flow line (8) which runs between the mud pumps (3) and drill string (5) .
  • the pistons operate by extraction and injection of a volume of the drilling fluid that is passing along the flow line (8) . This causes pulses of high and low pressure drilling fluid to be transmitted down the flow line (8) and drill string (5) . This fluid pulse causes the flow line (8) and drill string (5) to oscillate.
  • the advantage of the present invention lies in the fact that drilling operations can be carried out to depths beyond those which are possible with conventional drilling procedures. It is therefore possible to reach reservoirs which previously could not be drilled to. The degree of frictional drag on the drill string is reduced, allowing deeper drilling to be carried out and facilitating retrieval of the apparatus from a well.

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

Abstract

L'invention concerne un appareil et une méthode permettant de réduire les forces de friction sur l'appareil de forage lorsqu'il s'enfonce ou qu'il se retire d'un puits de forage. On peut parvenir à un tel résultat au moyen d'une action mécanique ou hydraulique sur le fluide de forage afin de créer un différentiel de pression hydraulique qui est transmis au train de forage par les pompes, obligeant le train de forage à osciller. Cette oscillation réduit l'interface frictionnelle entre le train de forage et le puits de forage, autorisant ainsi une profondeur ou portée accrue pour le puits de forage.
PCT/GB2001/001791 2000-04-25 2001-04-23 Appareil et procede permettant de faire osciller un train de forage WO2001081707A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU48623/01A AU4862301A (en) 2000-04-25 2001-04-23 Apparatus and method of oscillating a drill string

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GBGB0009848.3A GB0009848D0 (en) 2000-04-25 2000-04-25 Apparatus and method of use in drilling of well bores
GB0009848.3 2000-04-25

Publications (1)

Publication Number Publication Date
WO2001081707A1 true WO2001081707A1 (fr) 2001-11-01

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Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB2001/001791 WO2001081707A1 (fr) 2000-04-25 2001-04-23 Appareil et procede permettant de faire osciller un train de forage

Country Status (4)

Country Link
US (1) US20020157871A1 (fr)
AU (1) AU4862301A (fr)
GB (1) GB0009848D0 (fr)
WO (1) WO2001081707A1 (fr)

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2007113477A1 (fr) * 2006-03-30 2007-10-11 Specialised Petroleum Services Group Limited Nettoyage de puits de forage
WO2012158575A2 (fr) * 2011-05-18 2012-11-22 Thru Tubing Solutions, Inc. Dispositif de résistance à débit variable à tourbillon contrôlé et outils et procédés connexes
US9316065B1 (en) 2015-08-11 2016-04-19 Thru Tubing Solutions, Inc. Vortex controlled variable flow resistance device and related tools and methods

Families Citing this family (11)

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US7320370B2 (en) * 2003-09-17 2008-01-22 Schlumberger Technology Corporation Automatic downlink system
US7958952B2 (en) * 2007-05-03 2011-06-14 Teledrill Inc. Pulse rate of penetration enhancement device and method
WO2011035280A2 (fr) * 2009-09-21 2011-03-24 National Oilwell Varco, L. P. Systèmes et procédés d'amélioration de rendement de forage
US20120160476A1 (en) 2010-12-22 2012-06-28 Bakken Gary James Vibration tool
EP2694848B1 (fr) 2011-04-06 2020-03-11 David John Kusko Soupape de régulation hydroélectrique pour emplacements distants
US9212522B2 (en) * 2011-05-18 2015-12-15 Thru Tubing Solutions, Inc. Vortex controlled variable flow resistance device and related tools and methods
RU2598954C1 (ru) 2012-11-20 2016-10-10 Халлибертон Энерджи Сервисез, Инк. Устройство для усиления акустического сигнала и соответствующие система и способ
EP2909421A4 (fr) 2012-11-20 2016-10-26 Halliburton Energy Services Inc Appareil, systèmes et procédés de régulation d'agitation dynamique
WO2016205324A1 (fr) 2015-06-16 2016-12-22 Klx Energy Services Llc Appareil et procédé de modification de pression de colonne de forage
CA3197974A1 (en) * 2015-08-14 2017-02-23 Impulse Downhole Solutions Ltd. Fluid pulsing assembly
PL3482031T3 (pl) 2016-07-07 2022-02-07 Impulse Downhole Solutions Ltd. Przepływowy zespół impulsowy do stosowania przy wierceniach wgłębnych

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB1195862A (en) * 1967-05-30 1970-06-24 Hughes Tool Co Well Drilling Methods and Apparatus Employing Pressure Variations in a Drilling Fluid.
US4667742A (en) * 1985-03-08 1987-05-26 Bodine Albert G Down hole excitation system for loosening drill pipe stuck in a well
GB2261238A (en) * 1991-11-07 1993-05-12 Bp Exploration Operating Turbine vibrator assembly
RU2038461C1 (ru) * 1992-03-16 1995-06-27 Артамонов Вадим Юрьевич Генератор колебаний бурильной колонны труб
WO1997045622A1 (fr) * 1996-05-28 1997-12-04 Baker Hughes Incorporated Outils resonants pour puits de forage

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB1195862A (en) * 1967-05-30 1970-06-24 Hughes Tool Co Well Drilling Methods and Apparatus Employing Pressure Variations in a Drilling Fluid.
US4667742A (en) * 1985-03-08 1987-05-26 Bodine Albert G Down hole excitation system for loosening drill pipe stuck in a well
GB2261238A (en) * 1991-11-07 1993-05-12 Bp Exploration Operating Turbine vibrator assembly
RU2038461C1 (ru) * 1992-03-16 1995-06-27 Артамонов Вадим Юрьевич Генератор колебаний бурильной колонны труб
WO1997045622A1 (fr) * 1996-05-28 1997-12-04 Baker Hughes Incorporated Outils resonants pour puits de forage

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
DATABASE WPI Section Ch Week 199612, Derwent World Patents Index; Class H01, AN 1996-114875, XP002176754 *

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2007113477A1 (fr) * 2006-03-30 2007-10-11 Specialised Petroleum Services Group Limited Nettoyage de puits de forage
EA015554B1 (ru) * 2006-03-30 2011-08-30 Спешилайзд Петролеум Сервисиз Груп Лимитед Устройство, система и способ для очистки скважины
US8113285B2 (en) 2006-03-30 2012-02-14 Specialised Petroleum Services Group Limited Agitated wellbore cleaning tool and method
WO2012158575A2 (fr) * 2011-05-18 2012-11-22 Thru Tubing Solutions, Inc. Dispositif de résistance à débit variable à tourbillon contrôlé et outils et procédés connexes
WO2012158575A3 (fr) * 2011-05-18 2013-10-10 Thru Tubing Solutions, Inc. Dispositif de résistance à débit variable à tourbillon contrôlé et outils et procédés connexes
US9316065B1 (en) 2015-08-11 2016-04-19 Thru Tubing Solutions, Inc. Vortex controlled variable flow resistance device and related tools and methods

Also Published As

Publication number Publication date
US20020157871A1 (en) 2002-10-31
AU4862301A (en) 2001-11-07
GB0009848D0 (en) 2000-06-07

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