WO2008061071A2 - Système, appareil et procédé de coupe au jet de fluide abrasif - Google Patents

Système, appareil et procédé de coupe au jet de fluide abrasif Download PDF

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Publication number
WO2008061071A2
WO2008061071A2 PCT/US2007/084472 US2007084472W WO2008061071A2 WO 2008061071 A2 WO2008061071 A2 WO 2008061071A2 US 2007084472 W US2007084472 W US 2007084472W WO 2008061071 A2 WO2008061071 A2 WO 2008061071A2
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WIPO (PCT)
Prior art keywords
fluid
jet
jetting
shoe
nozzle
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Application number
PCT/US2007/084472
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English (en)
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WO2008061071A3 (fr
Inventor
Wesley Mark Mcafee
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Alberta Energy Partners
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Filing date
Publication date
Application filed by Alberta Energy Partners filed Critical Alberta Energy Partners
Publication of WO2008061071A2 publication Critical patent/WO2008061071A2/fr
Publication of WO2008061071A3 publication Critical patent/WO2008061071A3/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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/11—Perforators; Permeators
    • E21B43/112—Perforators with extendable perforating members, e.g. actuated by fluid means

Definitions

  • the present disclosure relates to drilling and cutting systems and their methods of operation and, more particularly, to a system and apparatus for jet- fluid cutting nozzle.
  • This disclosure relates to the cutting of computer programmed shape and window profile(s) through a well bore casing whose inside diameter is three inches or larger, and more particularly, to the controlled and precise use of a jet- fluid and nozzle configuration to cut a predefined shape or window through a well bore casing, thereby facilitating and providing access to the formation structure beyond the cemented casing.
  • Many wells today have a deviated bore drilled extending away from a generally vertical axis main well bore. The drilling of such a side-track is accomplished via multiple steps.
  • the disclosed apparatus is a perforator having two expandable arms. Each arm having an end with a perforating jet disposed at its distal end with a cutting jet emitting a jet stream.
  • the cutting function is disclosed as being accomplished by longitudinally oscillating, or reciprocating, the perforator. By a sequence of excursions up and down within a particular well segment, a deep slot is claimed to be formed.
  • a perforator is comprised of a telescopic and a double jet nozzle means for cutting slots.
  • the perforator centered about the longitudinal axis of the well bore during the slot cutting operation.
  • the perforator employs a stabilizer means, which restricts the perforator, thus not allowing any rotational movement of the perforator, except to a vertical up and down motion. Additionally, the lifting means of the perforator was not shown or described.
  • U. S. Pat. No. 5,381,631 which is hereby incorporated by reference as if fully set forth herein.
  • the disclosed apparatus provides for a rotational movement in a substantially horizontal plane to produce a circumferential cut into the well bore casing.
  • the apparatus drive mechanism is disposed down hole at the location near the cut target area.
  • the prior art reference is deficient in that the apparatus requires multi-hoses to be connected from the surface to the apparatus for power and control.
  • the prior art methods are also deficient in that often the cutting line established by the cutting nozzle creates a pie or fanned shape cut as it penetrates the casing. This causes difficulty in removing the pieces cut out by conventional means, due to the fact the rear face of the piece is larger than the opening cutout by the cutting tool. This necessitates either additional cutting of the target or the angling of the line of cutting to compensate for this problem and thus yield a rear face of smaller dimensions than the front face of the work area.
  • the present disclosure has been made in view of the above circumstances and has as an aspect a down hole jet- fluid cutting apparatus capable of cutting a shape or profile window into a well- bore casing by the application of coherent high pressure abrasive fluid mixture.
  • a further aspect of the present invention is a novel nozzle and nozzle configuration creating a vortex in the region directly in front of the nozzle and thereby generating additional cutting and penetrating capabilities.
  • the present disclosure can be characterized according to one aspect of the present disclosure as comprising a down hole jet- fluid cutting apparatus, the apparatus including a jet- fluid nozzle and a high pressure pump, wherein the high pressure pump is capable of delivering a fluid abrasive mixture at high pressure to the jet-fluid nozzle.
  • An abrasive fluid mixing unit wherein the abrasive fluid mixing unit is capable of maintaining a coherent abrasive fluid mixture and a high pressure conduit for delivering the coherent high pressure jet- fluid abrasive mixture to the jet- fluid nozzle.
  • a jet- fluid nozzle jetting shoe is employed, wherein the jetting shoe is adapted to receive the jet- fluid nozzle and direct the coherent high pressure jet- fluid abrasive mixture towards a work piece, wherein the jetting shoe controlling unit further includes at least one servomotor for manipulating the tubing and the jetting shoe along a vertical and horizontal axis.
  • a central processing unit having a memory unit, wherein the memory unit is capable of storing profile generation data for cutting a predefined shape or window profile in the work piece.
  • the central processing unit further includes software, wherein the software is capable of directing the central processing unit to perform the steps of: controlling the jetting shoe control unit to manipulate the jetting shoe along the vertical and horizontal axis to cut a predefined shape or window profile in the work piece.
  • the jetting shoe control unit controls speed feed and the vertical and horizontal axial movement of the tubing and jetting shoe to cut a predefined shape or window profile in the work piece.
  • the software controls the percentage of the abrasive fluid mixture to total fluid volume and also controls pressure and flow rates of the high pressure pump.
  • the present disclosure can be further characterized according to one aspect of the present disclosure as a method for computer assisted milling of a well-bore structure, the method comprising the steps of setting a bottom trip anchor into a well-bore at a predetermined depth below a milling site and inserting into the well-bore a directional gyro, wherein the directional gyro is positioned such that it rests on top of the inserted bottom trip anchor.
  • Milling of the site via an abrasive-jet fluid from the jetting-shoe assembly is performed, wherein the computer implements a predefined shape or window profile at the milling site by controlling the vertical movement and horizontal movement through a 360 degree angle of rotation of the jetting-shoe assembly.
  • FIGURE 1 is a two dimensional cutaway view showing an embodiment of the programmable abrasive-jet- fluid cutting system of the present disclosure
  • FIGURE 2 is a two dimensional cutaway view depicting an embodiment of the jack of the present disclosure
  • FIGURE 3 is a three-dimensional cutaway view of an embodiment of a jetting-shoe of the present disclosure
  • FIGURES 4A and 4B are three dimensional cutaway views of a rotator of the present disclosure
  • FIGURE 5 is a exploded view of a nozzle assembly of an aspect of the present disclosure
  • FIGURE 6 is perspective of an assembled nozzle configuration of an aspect of the present disclosure.
  • FIGURE 7 is an expanded view of FIGURE 1 depicting an aspect of the present disclosure in operation. DETAILED DESCRIPTION OF THE DISCLOSURE
  • the present disclosure generally relates to methods and apparatus of abrasive-jet- fluid cutting through a well bore casing or similar structure.
  • the method generally is comprised of the steps of positioning a jetting-shoe and jet-nozzle adjacent to a pre-selected portion of a length of casing in the annulus, pumping fluid containing abrasives through the jetting-shoe and attached jet-nozzle such that the fluid is jetted there from, moving the jetting-shoe and jet-nozzle in a predetermined programmed vertical axis and 360 degree horizontal rotary axis.
  • the vertical and horizontal movement pattern(s) are capable of being performed independently of each or programmed and operated simultaneously.
  • the abrasive-jet- fluid there from is directed and coordinated such that the predetermined pattern is cut through the inner surface of the casing to form a shape or window profile(s), allowing access to the formation beyond the casing.
  • a profile generation system simultaneously moves a jetting-shoe in a vertical axis
  • a coiled tubing for delivering a coherent high pressure abrasive-jet- fluid through a single tube and a jet-nozzle for ejecting there from abrasive-jet- fluid under high pressure from a jetting-shoe is contemplated and taught by the present disclosure.
  • the jetting-shoe apparatus and means are programmable to simultaneously or independently provide vertical axis and 360-degree horizontal rotary axis movement under computer control.
  • a computer having a processor and memory and operating pursuant to attendant software, stores shape or window profile(s) templates for cutting and is also capable of accepting inputs via a graphical user interface, thereby providing a system to program new shape or window profile(s) based on user criteria.
  • the memory of the computer can be one or more of but not limited to RAM memory, flash memory, ROM memory, EPROM memory, EEPROM memory, registers, hard disk, a removable disk, a CD-ROM, floppy disk, DVD-R, CD-R disk or any other form of storage medium known in the art.
  • the storage medium may be integral to the processor.
  • the processor and the storage medium may reside in an ASIC or microchip.
  • the computer of the present disclosure controls the profile generation servo drive systems as well as the abrasive mixture percentage to total fluid volume and further controls the pressure and flow rates of a high pressure pump and pump drive.
  • the computer further controls the feed and speed of the coiled tubing unit and the coiled tubing injector head and the simultaneous jacking and the directional rotation of the tubing in an annulus. Telemetry is broadcast and transmitted after scanning of the cut shape or window profile(s) after the casing has been cut by a sensor or probe located in proximity to the jet-nozzle head.
  • the abrasive -jet- fluid method and apparatus is capable of cutting into the underlying substructure, such as rock or sediment.
  • the cutting apparatus can be directed to cut or disperse impediments in found or lodged in the well bore casing. Impediments such as measuring equipment, extraction tools, drill heads or pieces of drill heads and various other equipment utilized in the industry and readily recognizable by one skilled in the art, periodically become lodged in the well bore and must be removed before work at the site can continue.
  • multiple jet heads can be employed to form simultaneous shapes or window profiles in the well bore casing or underlying substructure as the application requires.
  • This type of application can be employed to disperse impediments in the well bore or to severe the well bore casing at a desired location so that it can be extracted. Additionally, this embodiment can be employed where a rock formation or other sub-structure is desired to be shaped symmetrically or asymmetrically to assist in various associated tasks inherent to the drilling or extraction process.
  • the vertical axis of the cutting apparatus is capable of being manipulated off the plane axis to assist in applications wherein the well bore is not vertical, as is the case when directional drilling is employed.
  • the jetting-shoe is attached to a tubing string and suspended at the wellhead and is moved by the computer, central processing unit or microchip (hereinafter collectively called the computer) controlled servo driven units.
  • Software in communication with sub-programs gathering telemetry from the site directs the computer, which in turns communicates with and monitors the down hole cutting apparatus and its attendant components, and provides guidance and direction simultaneously or independently along the vertical axis and the horizontal axis (360-degrees of movement) of the tubing string via servo driven units.
  • the shape or window profile(s) that are desired is programmed by the operator on a program logic controller (PLC), or personal computer (PC), or a computer system designed for this specific use.
  • PLC program logic controller
  • PC personal computer
  • GUI graphical user interface
  • the rotational computer controlled axis servo motor such as a Fanuc model
  • D2100/150is servo provides 360-degree horizontal rotational movement of the tubing string using a tubing rotator such as R and M Energy Systems heavy duty model RODEC RDII, or others, that have been modified to accept a mechanical connection for the servo drive motor.
  • the tubing rotator supports and rotates the tubing string up to 128,000 pounds. Heavier capacity tubing rotators may be used if necessary as will be apparent to those skilled in the art.
  • the vertical axis longitudinal computer controlled servo axis motor such as Fanuc
  • D2100/150is servo provides up and down vertical movement of the tubing string using a jack assembly attached to the top of the wellhead driven by said servo drive motor.
  • the jack preferably will use ball screw(s) for the ease of the vertical axis longitudinal movements, although other methods may be employed.
  • the jack typically will be adapted for use with 10,000-PSI wellhead pressures, although the present disclosure is by no means limited to wellhead pressures below or above 10,000-PSI.
  • the jack typically will have means for a counter balance to off set the weight of the tubing string to enhance the life of the servo lifting screw(s) or other lifting devices such as Joyce/Dayton model WJT 325WJ3275 screw jack(s). [0047]
  • the servos simultaneously drive the tubing rotator and jack, providing vertical axis and
  • the abrasive-jet- fluid in one embodiment of the present disclosure is delivered by a coiled tubing unit through a fluid-tube to the jetting-shoe through the inner bore of the tubing string, or the abrasive-jet- fluid can be pumped directly through the tubing string, with the jet-nozzle being attached to the exit of the jetting-shoe.
  • the abrasive-jet- fluid jet-nozzle relative position to the casing is not critical due to the coherent stream of the abrasive-jet- fluid.
  • the jet-nozzle angle nominally is disposed at approximately 90 degrees to the inner well bore surface, impediment or formation to be cut, but may be positioned at various angles in the jetting-shoe for tapering the entry hole into the casing and formation by the use of different angles where the jet-nozzle exits the jetting-shoe.
  • Empirical tests have shown that employing 10,000-PSI and a 0.7 mm nozzle orifice with 1.9 gallons per minute of the coherent abrasive jet fluid, is sufficient to cut through a steel well bore casing and multi cemented conductors in a reasonable period of time.
  • PSI with varying orifice sizes and water flow rates will provide sufficient energy and abrasion to cut through the well bore casing or formation, but at a cost of additional time to complete the project.
  • variations in the nozzle orifice size or the abrasive component utilized in the cutting apparatus fluid slurry will generally necessitate an increase or decrease in the fluid slurry flow rate as well as an increase or decrease in the pressure required to be applied to the coherent abrasive-jet fluid (slurry).
  • the time constraints attendant to the specific application will also impinge upon the slurry flow rate, pressure and orifice size selected for the specific application undertaken.
  • One advantage of the present disclosure over the prior art is that the attendant costs of cutting through the well bore casing or formation will be relatively nominal as compared to the total drilling costs. In addition, the present disclosure provides that any additional costs of operation of the cutting apparatus may be significantly offset by the decreased site and personnel down time. [0052]
  • the methods and systems described herein are not limited to specific sizes or shapes.
  • a method for cutting user programmable shapes or window profile(s) through down hole casing, cement, and formation rock using abrasive-jet- fluid flowing from a jet-nozzle includes an electric line unit inserted into the annulus.
  • the electric line unit is operated topside and is keyed to a bottom trip anchor at a predetermined depth, which is a known distance below the bottom elevation depth where the shape or window profile(s) are to be cut.
  • the bottom trip anchor is anchored to the well-bore casing and the electric line is removed and an electrical line operated directional gyro is inserted into the annulus.
  • the directional gyro is seated onto the top keyed bottom trip anchor, so the direction of the top key is known at the surface and this information is inputted into the surface computer, which controls the directional reference of the top keyed bottom trip anchor as well as two axis drive servos.
  • the directional gyro is then removed from the annulus and a profile generation system is secured onto the well head or on top of a blow out preventer stack.
  • a work-over- rig or a drill rig is then utilized to attach a jetting-shoe to the end of a tubing string, which are inserted into the annulus of the cased well bore to a point down hole in the annulus, where a user programmable shape or window profile(s) are to be abrasive-jet- fluid cut through the casing and cement, to expose formation rock.
  • Rotating centralizers on the outer diameter of the tubing string are employed to keep the tubing string centered in the annulus as further feeding of jetting- shoe onto the top keyed bottom trip anchor is commenced if a specific rotational direction is required.
  • the jetting-shoe rotational direction is then established and data is inputted into the surface computer regarding the known depth established by the placement of the jetting-shoe onto the top keyed bottom trip anchor.
  • the tubing string is then sufficient to allow setting air or other slips around the tubing string in the tubing rotator to suspend and hold the tubing string.
  • the method for cutting user programmable shapes or window profile(s) through down hole casing further includes inserting a fluid-tube, that is fed from a coiled tubing unit and tubing injector head, into the bore of the tubing string which is suspended by the rotator and jack of the profile generation system, so the jet-nozzle attached to the end of the fluid-tube is fed through the jetting-shoe to face the inner surface of the casing.
  • An operational cycle of the computer control unit is then commenced, which positions the jetting-shoe and jet-nozzle into the proper location for cutting the user programmable shapes or window profile(s), which in turn engages the high pressure pump and drives the two-axis programmable computer servo controller unit at the surface to generate the user programmable shape or window profile(s) to cut through the casing or through a plurality of metal casings of varying diameters stacked within each other and sealed together with concrete grout.
  • the computer further controls the coiled tube unit and the feed speed of the tubing injector and depth location of the jet-nozzle attached to the end of the fluid-tube.
  • a co-ordinate measuring of the cut shapes or window profile(s) is performed by scanning with a magnetic proximity switch on the jetting-shoe that faces the inner surface of the annulus.
  • the cutting apparatus and its attendant components are rotated and raised and lowered by the profile generation system under computer control.
  • the magnetic proximity switch senses the casing in place, or the casing that has been removed by the abrasive -jet- fluid, and activates a battery operated sonic transmitter mounted in the jetting-shoe, which transmits a signal to a surface receiver, that is coupled to the computer control unit containing the data of the originally programmed casing cut shapes or window profile(s) for comparison to the user programmed shape or window profile(s).
  • FIGURE 1 depicts a well bore lined with a casing 1.
  • Casing 1 is typically cemented in the well bore by cement bond 2, wherein cement bond 2 is surrounded by a formation 3.
  • a jetting-shoe 5 is illustrated in FIGURE 1 with a jet nozzle 4 attached to the end of fluid-tube 9.
  • the jetting shoe 5 is depicted with a threaded joint 33 attached at a lower end of a string of drill or tubing string 6. Drill or tubing string 6 and jetting shoe 5 are lowered into annulus 24 of the well at or near a location where a shape or window profile(s) is to be cut and is suspended by tubular adaptor flange 7 in by tubing rotator 8.
  • FIGURE 1 further depicts jetting shoe 5 in position with a fluid-tube 9 being fed into the drill or tubing string 6 by a coil tubing injector head (not shown) from a coil tubing reel 13 through the jetting-shoe 5.
  • the fluid-tube 9 is transitioned from a vertical to horizontal orientation inside of the jetting-shoe 5 such that the jet-nozzle 4 is in disposed in proximity to casing 1 that is to be cut.
  • the reader should note that although the drawings depict a well casing being cut into, the work piece could very well be an impediment such as a extraction tool or other equipment lodged in the casing.
  • the shape or window profile(s) are programmed into the computer 11 via a graphical user interface (GUI) and the high-pressure pump 19 is initiated when the operator executes the run program (not shown) on the computer 11.
  • GUI graphical user interface
  • the computer 11 is directed by sub-programs and parameters inputted into the system by the user. Additionally, previous cutting sessions can be stored on the computer 11 via memory or on a computer readable medium and executed at various job sites where the attendant conditions are such that a previously implemented setup is applicable.
  • Fluid 21 to be pumped is contained in tank 22 and flows to a high pressure pump 19 through pipe 20.
  • the high pressure pump 19 increases pressure and part of the fluid flows from the high pressure pump 19 is diverted to flow pipe 18 and then into fluid slurry control valve 17 and into abrasive pressure vessel 16 containing abrasive material 15.
  • a 10% flow rate is directed via flow pipe 18 and fluid slurry control valve 17 to the abrasive pressure vessel 16.
  • the flow rate is capable of being adjusted such that the abrasive will remain suspended in the fluid 21 utilized.
  • the base line flow was modulated to provide an abrasive concentration to fluid ratio of 18%.
  • the maintaining of an abrasive to concentration fluid ratio is an important element in the present disclosure as well as the type of abrasive, such as sand, Garnet, various silica, copper slag, synthetic materials or Corundum are employed.
  • the volume of fluid directed to the abrasive pressure vessel 16 is such that a fluid, often water, and abrasive slurry are maintained at a sufficient velocity, such as 2.4 to 10 meters per second through fluid-tube 9, so that the abrasive is kept in suspension through the jet-nozzle 4.
  • a velocity too low will result in the abrasive falling out of the slurry mix and clumping up at some point, prior to exiting the jet-nozzle 4. This ultimately results in less energy being delivered by the slurry at the target site.
  • a velocity too high will result in similarly deleterious effects with respect to the energy being delivered by the slurry at the target site.
  • the application of the present disclosure uses up or renders inoperable some of the equipment employed in the cutting process. For instance, if the slurry mix is not properly maintained or the abrasive material 15 is not of a uniform grade or resiliency to perform adequately, the jet nozzle 4 and jet-nozzle orifice may be consumed at a faster rate than normal, ultimately resulting in additional down time, costs and expense.
  • the abrasive material 15, such as sand garnet or silica is mixed with the high pressure pump 19 fluid flow at mixing valve 14.
  • Mixing valve 14 further includes a ventura 36, which produces a jet effect, thereby creating a vacuum aid in drawing the abrasive water (slurry) mix.
  • a ventura 36 which produces a jet effect, thereby creating a vacuum aid in drawing the abrasive water (slurry) mix.
  • the coherent abrasive-jet- fluid then flows through coiled tubing reel 13 and down fluid- tube 9 and out jet-nozzle 4 cutting the casing 1 and the cement bond 2 and the formation 3.
  • an abrasive with the properties within or similar to the complex family of silicate minerals such as garnet is utilized.
  • Garnets are a complex family of silicate minerals with similar structures and a wide range of chemical compositions and properties.
  • the general chemical formula for garnet is AB(SiO), where A can be calcium, magnesium, ferrous iron or manganese; and B can be aluminum, chromium, ferric iron, or titanium.
  • garnet group of minerals shows crystals with a habit of rhombic dodecahedrons and trapezohedrons. They are nesosilicates with the same general formula, A 3 B 2 (SiOz I ) 3 . Garnets show no cleavage and a dodecahedral parting. Fracture is conchoidal to uneven; some varieties are very tough and are valuable for abrasive purposes. Hardness is approximately 6.5 - 9.0 Mohs; specific gravity is approximately 3.1 - 4.3.
  • Garnets tend to be inert and resist gradation and are excellent choices for an abrasive.
  • Garnets can be industrially obtained quite easily in various grades. In the present disclosure, empirical tests performed utilized an 80 grit garnet with achieved superior results.
  • abrasive material 15 is an important consideration in the cutting process and the application of the proper abrasive with the superior apparatus and method of the present disclosure provides a substantial improvement over the prior art.
  • the cutting time of the abrasive-jet- fluid is dependant on the material and the thickness cut.
  • the computer 11 processes input data and telemetry and directs signals to servomotor 10 and servomotor 12 to simultaneously move tubing rotator 8 and tubing jack 25 to cut the shapes or window profile(s) that have been programmed into the computer 11.
  • Predetermined feed and speed subprograms are incorporated into the software to be executed by computer 11 in the direction and operation of the cutting apparatus.
  • Any excess fluid is discharged up annulus 24 through choke 23.
  • the steel that is cut during the shaping or cutting process drops below the jetting shoe 5 and can be caught in a basket (not shown) hanging below or be retrieved by a magnet (not shown) attached to the bottom of the jetting shoe
  • Tubing jack 25 is driven in the vertical axis by a worm gear 27, depicted in FIGURE 2, which is powered by a servo motor (not shown) that drives a ball screw 28.
  • the tubing jack 25 is bolted on the well-head 37 at flange 30.
  • the tubing jack 25 is counterbalanced by the hydraulic fluid 29 that is under pressure from a hydraulic accumulator cylinder under high pressure 31.
  • the rotator is attached on the top of the tubing jack 25 at flange 26.
  • the jetting shoe 5, as illustrated in FIGURE 3 is typically made of 4140-grade steel or similarly resilient material and heat treated to Rockwell 52 standard.
  • the jetting-shoe 5 is connected to the tubing string 6 with threads 33.
  • Stabbing guide 35 a part of the jetting-shoe 5, is disposed inside of tubing string 6 that supports the guiding of the flow-tube 9 into the jetting shoe 5.
  • the flow-tube 9 transitions from a vertical axis to a horizontal axis inside of the jetting-shoe 5.
  • the jet-nozzle 4 is coupled to the fluid-tube 9 and disposed such that it faces the surface face of the well-bore casing and the coherent abrasive-jet- fluid exits the jet-nozzle 4 and cuts the casing 1.
  • a battery operated sonic transmitter and magnetic proximity switch are installed in bore-hole 34 of the jetting-shoe 5 to allow scanning of the abrasive-jet- fluid cuts through the casing 1. Telemetry is transmitted via a signaling cable to computer 11.
  • the signaling cable may be of a shielded variety or optical in nature, depending on the design constraints employed.
  • the nozzle 4 is made of 416 heat-treated stainless steel or similarly resilient material and has either a carbide or sapphire orifice such as a NLB Corp model SA designed for abrasive -jet-fluids.
  • the casing material to be cut is a variable, as well as the diameter of the casing.
  • the diameter of the casing could be 12 inches and another 4 inches.
  • the depth of the cutting or shaping site will vary and if the predicted pressure loss is 0.5 lbs/ft the resultant pressure at the jet-nozzle may be lower.
  • FIGURES 4A and 4B depict a rotator casing bowl 8, such as R and M Energy Systems heavy duty model RODEC RDII, secured on top of tubing jack 25.
  • the tubing string 6 is inserted through (see FIGURE 4B) tubular adaptor flange 7, which is further disposed on top of pinion shaft 32.
  • Pinion shaft 32 is adapted to secure and suspend the tubing string 6 within the annulus 24.
  • the 360- degree rotary movement of the tubing string 6 is accomplished by the pinion shaft 32, which is powered by servomotor 10.
  • the present disclosure may be embodied in other specific forms without departing from its spirit or essential characteristics.
  • An exploded view of the novel nozzle configuration of an aspect of the present disclosure is depicted in FIGURE 5.
  • a helix or spring 40 is placed in a high pressure hose 49 (See FIGURE 6) and creates a vortex as the cutting fluid passes from the proximate end 41 to the distal end 42 of the helix 40.
  • the helix or spring 40 can be of any configuration that increases the pressure of the cutting fluid as it pass from the proximate end 41 to the distal end 42 of the helix 40.
  • the term helix is not meant to limit the invention in any sense.
  • a helix is contemplated by the present invention to be any structure that is capable of being inserted into the high pressure hose 49 and provide a pressure increase as stated above.
  • the helix or spring 40 can be comprised of a single piece of metal resembling a drill bit or be a wire coiled into a spring. It may also be of a star or hexagonal configuration, but is not limited to these configurations. A person of ordinary skill in the art will appreciate that based on the principles of fluid mechanics that varying the helix shape may be necessitated to provide superior efficiencies and energy transfer based on the cutting fluid involved and the desired working cutting pressures. An aspect of the present invention is to determine the optimum parameters necessary to produce such results and to vary the components and their dimensions and compositions to achieve the desired yield. [0085]
  • the helix or spring 40 can be comprised of any hard metal, metal alloy, composite material or ceramic material. Typically, the helix 40 is comprised of, but not limited to, stainless steel, titanium, carbide steel or boron carbide steel or similar material.
  • the helix 40 is approximately 8 inches in length, but this length is variable to maximize the energy transfer to the nozzle end. Furthermore, since the high- pressure-hose 49 size can vary and the working environment can change, i.e. well bore size changes from a larger to smaller bore diameter, the length and composition of the helix may necessitate changes to accommodate them down the bore-hole.
  • the ratio is determined based on the cutting fluid utilized and the desired exit cutting fluid pressure. For instance in a cutting fluid slurry including garnet the ratio may range from a 1 : 1 starting to a 1 :2 ending turns ratio. In a cutting fluid comprised solely of water the 1 :2 ending turns ratio may promote excessive turbulence and thus decrease the energy delivered to a target due to the losses of turbulence.
  • the guiding principle behind the turns ratio of the helix is to create a vortex thereby increasing the pressure of the fluid passing by the helix 40, but the spinning up of the cutting fluid should take place in a controlled manner and not spin up too fast and create excessive turbulence.
  • a person of ordinary skill in the art places water in a tub and starts to stir it, after first slowly and then gradually faster they could reach a maximum circulating speed with minimal water loss. But on the other hand, if a person of ordinary skill started the stirring process abruptly there would be spillage of the water and the creation of violent swirling vortexes in the water. In this example the same top circulating speed would theoretically never be reached because of the turbulence losses created by the excessive stirring action.
  • the hose 49 is attached to a nozzle holder 46 via a Ferrell 47
  • a nozzle 46 comprised of a hard material, such as but not limited to stainless steel, tungsten, titanium, carbide steel or boron carbide steel or similar material, is inserted into the nozzle holder assembly 44 and secured.
  • a nozzle end retainer 48 is then placed over the distal end of the nozzle 46 and secured in place.
  • FIGURE 6 illustrates an assembled view of the hose-nozzle assembly.
  • Hose 49 is a high-pressure type hose, typically having an inner-metal lining.
  • the hose 49 is a red snake hose produced by Paraflax.
  • the hose 49 is capable of sustaining high-pressure fluid at psi in the 10**5 range.
  • the cutting-fluid traverses the hose 49 and engages the proximal end
  • helix 40 begins to rotate the helix 40.
  • the rotation of helix 40 increases.
  • the resultant rotation of helix 40 creates a vortex and increases the pressure of the cutting- fluid.
  • the increase in the cutting fluid pressure is increased multiple times and theoretically to one order of magnitude higher if not more.
  • the fluid enters into a chamber just prior to the nozzle 46.
  • the fluid is further compressed and the pressure further increases as the fluid passes through nozzle 46.
  • the distal end of nozzle 46 is tapered to at least match the slope 50 of the nozzle end retainer.
  • This tapering is determined such that the maximum amount of energy is transferred across the exit point of the nozzle 46 to a target 58 via the cutting-fluid 56.
  • the tapering 54 of the distal end of is machine to approximately 30 degrees. This 30-degree beveling of the distal end of nozzle 46 is configured to impedance match the cutting-fluid and therefore transfer the maximum amount of energy to the target 58.
  • this is analogous to resistance matching in a resistive circuit, i.e. the ohmage between a speaker and an amplifier.
  • the tapering 54 of the nozzle is changed to effectuate maximum energy transfer, i.e. increase the cutting fluid pressure/velocity.
  • the cutting-fluid 56 exiting the nozzle 46 expands to approximately a 30-degree fan or pie slice configuration.
  • a void 52 is created in area 52 between the fan and the nozzle end retainer 48. This void 52 creates an additional vortex and aids in the cutting of the target.
  • the vortex creates a cutting action that creates an opening in the target 58 of a diameter greater than the cutting fluid diameter exiting the nozzle 46.
  • a cutting hole of the diameter of the cutting fluid stream 56 is achieved and therefore necessitates cutting at an angle from a center line to create a pie type slice, wherein the back of the piece cut from the target is narrower than the front of the target.
  • the cyclonic action produces a backpressure on the rear of the target and assists in the removal of any pattern cut from the target material, i.e. well bore casing.
  • FIGURE 7 depicts an exemplary view of the novel cutting nozzle in operation.
  • a cutout design is depicted, wherein the control system has mapped out and cut the predetermined design, here a rectangular pattern, in the well casing bore.
  • the edges are clean as if machined and are substantially perpendicular to the cut.
  • the cyclonic action of the cutting fluid as produce by the novel nozzle configuration produces a back surface that is clean of debris and is easily remove from the remain bore casing.
  • the cutting continues in the rock or substrate region extending further into the rock or substrate formation. Without and additional lateral movement the present invention can cut approximately a 50 foot pattern into the surrounding strata in 3 minutes or less, depending on the strata composition. In the exemplary view and case the strata was a standard rock formation encountered typical in oilfields.
  • An aspect of the present invention contemplates any determined turns ratio from the proximate end 41 to the distal end 42 of the helix 40 that increases cutting fluid pressure and aides in delivering the maximum amount of cutting energy to the target.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Perforating, Stamping-Out Or Severing By Means Other Than Cutting (AREA)
  • Earth Drilling (AREA)

Abstract

La présente invention concerne un système, un appareil et un procédé pour la coupe au jet de fluide abrasif. Un ensemble de buse de coupe au jet de fluide abrasif comprend un tuyau (49) destiné à recevoir un fluide abrasif de coupe au jet, une hélice/un ressort (40) attaché en rotation à l'intérieur du tuyau à haute pression (49) et une buse (46) reliée au tuyau (49). L'helice/le ressort (40 ) est biseautée de telle sorte que le rapport de tour de l'hélice (40 ) varie de l'extrémité proximale vers l'extrémité distale. La rotation de l'hélice (40) crée un tourbillon et augmente la pression d'un fluide abrasif de coupe au jet à mesure qu'il passe de l'extrémité proximale à l'extrémité distale. La présente invention concene en outre un système et un procédé d'utilisation de l'ensemble de buse de coupe au jet de fluide abrasif.
PCT/US2007/084472 2006-11-13 2007-11-13 Système, appareil et procédé de coupe au jet de fluide abrasif WO2008061071A2 (fr)

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US60/865,638 2006-11-13

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WO2015153947A1 (fr) * 2014-04-03 2015-10-08 Weatherford/Lamb, Inc. Outil de coupe de fond de trou
CN106285577A (zh) * 2016-10-27 2017-01-04 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 一种带有螺旋芯轴的旋流式水力喷射器
WO2018040139A1 (fr) * 2016-08-30 2018-03-08 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 Rame discontinue et à double spirale à étages limités pour mélange de sable et de liquide en fond de puits
CN109594922A (zh) * 2018-10-23 2019-04-09 中国石油天然气集团有限公司 水射流钻径向井作业的方法
CN109594921A (zh) * 2018-10-23 2019-04-09 中国石油天然气集团有限公司 射流可钻性来评价径向井适用地层工作参数的方法
CN111042735A (zh) * 2018-10-15 2020-04-21 西南石油大学 一种切入式直旋混合射流自进式喷嘴
WO2021097972A1 (fr) * 2019-11-19 2021-05-27 中国石油大学(华东) Trépan fournissant un effet combiné de charge induite et de jet abrasif, et procédé de forage de puits

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WO2015153947A1 (fr) * 2014-04-03 2015-10-08 Weatherford/Lamb, Inc. Outil de coupe de fond de trou
WO2018040139A1 (fr) * 2016-08-30 2018-03-08 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 Rame discontinue et à double spirale à étages limités pour mélange de sable et de liquide en fond de puits
CN106285577A (zh) * 2016-10-27 2017-01-04 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 一种带有螺旋芯轴的旋流式水力喷射器
CN106285577B (zh) * 2016-10-27 2019-09-24 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 一种带有螺旋芯轴的旋流式水力喷射器
CN111042735A (zh) * 2018-10-15 2020-04-21 西南石油大学 一种切入式直旋混合射流自进式喷嘴
CN109594922A (zh) * 2018-10-23 2019-04-09 中国石油天然气集团有限公司 水射流钻径向井作业的方法
CN109594921A (zh) * 2018-10-23 2019-04-09 中国石油天然气集团有限公司 射流可钻性来评价径向井适用地层工作参数的方法
WO2021097972A1 (fr) * 2019-11-19 2021-05-27 中国石油大学(华东) Trépan fournissant un effet combiné de charge induite et de jet abrasif, et procédé de forage de puits

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