WO2000022278A1 - Procede de forage - Google Patents

Procede de forage Download PDF

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Publication number
WO2000022278A1
WO2000022278A1 PCT/GB1999/003411 GB9903411W WO0022278A1 WO 2000022278 A1 WO2000022278 A1 WO 2000022278A1 GB 9903411 W GB9903411 W GB 9903411W WO 0022278 A1 WO0022278 A1 WO 0022278A1
Authority
WO
WIPO (PCT)
Prior art keywords
tubular
slips
drill string
grips
drilling
Prior art date
Application number
PCT/GB1999/003411
Other languages
English (en)
Inventor
Laurence John Ayling
Original Assignee
Coupler Developments Limited
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority to MXPA01003767A priority Critical patent/MXPA01003767A/es
Priority to DE69924629T priority patent/DE69924629D1/de
Priority to EP99949233A priority patent/EP1121508B1/fr
Priority to AT99949233T priority patent/ATE292740T1/de
Priority to US09/807,476 priority patent/US6591916B1/en
Priority to CA002346880A priority patent/CA2346880C/fr
Application filed by Coupler Developments Limited filed Critical Coupler Developments Limited
Priority to BR9914774-2A priority patent/BR9914774A/pt
Priority to AU62207/99A priority patent/AU759454B2/en
Publication of WO2000022278A1 publication Critical patent/WO2000022278A1/fr
Priority to US09/703,178 priority patent/US6688394B1/en
Priority to NO20011680A priority patent/NO317821B1/no
Priority to US10/442,548 priority patent/US7252151B2/en

Links

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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
    • 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
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/16—Connecting or disconnecting pipe couplings or joints
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
    • E21B21/085—Underbalanced techniques, i.e. where borehole fluid pressure is below formation pressure
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/01—Arrangements for handling drilling fluids or cuttings outside the borehole, e.g. mud boxes

Definitions

  • the present invention relates to a method for drilling wells, particularly drilling for hydrocarbons.
  • the drill string is rotated to drive the drill bit and mud is circulated to cool, lubricate and remove the rock bits formed by the drilling.
  • the method provides for supplying mud, at the appropriate pressure in the immediate vicinity of the tubular connection that is about to be broken such that the flow of mud so provided overlaps with flow of mud from the top drive, as the tubular separates from the drill string the flow of mud to the separated tubular is stopped e.g. by the action of a blind ram or other preventer or other closing device such as a gate valve.
  • the separated tubular can then be flushed out e.g. with air or water (if under water) depressured, withdrawn, disconnected from the top drive and removed.
  • the action of the preventer is to divide the tubular connection into two parts e.g. by dividing the pressure chamber of the connector connecting the tubular to the drill string.
  • the drill string continues to be circulated with mud at the required pressure
  • a tubular can be added using a clamping means which comprises a coupler, and the top end of the drill string is enclosed in and gripped by the lower section of the coupler, in which coupler there is a blind preventer which separates the upper and lower sections of the coupler, the tubular is then added to the upper section of the coupler and is sealed by an annular preventer and the blind preventer is opened and the lower end of the tubular and upper end of the drill string joined together.
  • the lower section of the coupler below the blind preventer will already enclose the upper end of the drill string before the tubular is lowered and when the tubular is lowered into the coupler the upper section of the coupler above the blind preventer will enclose the lower end of the tubular.
  • the tubular can be added to the drill string by attaching the lower section of the coupler to the top of the rotating drill string with the blind preventer in the closed position preventing escape of mud or drilling fluid.
  • the tubular is lowered from substantially vertically above into the upper section of the coupler and the rotating tubular is then sealed in by a seal so that all the drilling fluid is contained, the blind preventer is then opened and the tubular and the drill stand brought into contact and joined together with the grips bringing the tubular and drill string to the correct torque.
  • the lower end of the tubular and the upper end of the drill string are separated by the blind preventer such that the tubular stand can be sealed in by an upper annular preventer so that when the blind preventer is opened there is substantially no escape of mud or drilling fluid and the tubular stand and drill string can then be brought together and made up to the required torque.
  • the tubular spool or saver sub under the top drive penetrates the upper part of the pressure chamber, is flushed out with mud and pressured up; the blind ram opens allowing the top drive to provide circulating mud and the spool to connect to and to torque up the into the drill string.
  • the pressure vessel can then be depressured, flushed with air (or water if under water) and the drill string raised until the next join is within the pressure chamber, the 'slips and grips' ram closed, the pressure chamber flushed with mud and pressured up and the cycle repeated.
  • the coupler includes rotating slips which support the drill string while the top drive is raised up to accept and connect another tubular.
  • the coupler may be a static coupler connected to and above the wellhead BOP stack with a top-drive or mobile coupler handling the tubulars above the static coupler working hand-to-hand.
  • the coupler may be a mobile coupler disconnected from the wellhead BOP stack with a top-drive or second mobile coupler handling the tubulars above it working hand-to- hand and thereby allowing the string to move steadily in the vertical plane when tripping is in progress or allowing drilling to continue while a tubular stand is being added.
  • the coupler may be a mobile coupler disconnected from the wellhead BOP stack with one or more identical mobile couplers, above, which take it in turns to become the bottom coupler thereby working hand-over-hand and also facilitating steady movement of the string when tripping is in progress or drilling is continuing while a tubular is being added to the string.
  • Patent Application PCT/GB97/02815 locates the grips and slips either inside or outside the coupler pressure hull.
  • a well head assembly which comprises a
  • the Grips and Slips Function are the means of gripping the tubulars strongly enough to transfer a rotational force or torque, by friction surfaces shaped to fit the external surface of the tool joint, or the shaft of the tubular, or by powered rollers, both methods of which are common in conventional iron roughnecks.
  • the slips are the means of applying an axial force to the tubular to prevent it slipping, by wedge action and or by obstructing the passage of the upset of the tool joint, as is common in conventional slips.
  • the grips & slips combine the functions of gripping and slipping either by modifying the profile of the friction pads, rollers or slips or by integrating the separate grips and slips to operate in concert
  • the orientation of the well head assembly refers to the well head assembly when in position on a drill string.
  • the gripping mechanism with or without integrated slips may be achieved by simply altering the materials and profile of the inserts of the conventional Rotary BOP, Diverter, Preventer, or Rotating Control Head.
  • the gripping may be achieved by conventional methods of wedge, lever, motorised rollers screw or other mechanical means caused by hydraulic, electrical or mechanical means such as is currently applied within collett connectors, casing tongs rotary power slips or current iron roughnecks.
  • the invention enables a tubular to be added to a drill string when a drill string is rotating and drilling mud is flowing.
  • the lower grips and slips grip support and rotate the drill string, the circulation of tubular string continues uninterrupted and over or under balanced pressure in well bore and annulus is maintained continuously.
  • the upper preventer is open and the new tubular is positioned on the blind preventer, preferably there being a locating means so that the tubular is correctly positioned above the drill string e.g. by landing the tubular on a raised star on the blind preventer, i.e. the tubular is "zero indexed".
  • the upper preventer and upper grips and slips are then shut and the new tubular can have air (or water if the drilling is taking place underwater) replaced by the appropriate drilling fluid.
  • the blind preventer is then opened and the circulation (or reverse circulation) of tubular string continued uninterrupted from two overlapping sources and over or under balanced pressure in well bore and annulus is maintained continuously.
  • the new tubular is then brought into contact with the drill string by passing through the blind preventer and is controlled by the upper slips and grips and, when the tubular is in contact with the drill string, the new tubular turns faster than the drill string so that the new tubular is "torqued up" by the upper grips and slips acting against the lower grips and slips, whilst both continue to rotate and the new tubular is screwed to the top of the drill string.
  • the new tubular is not rotating as fast as the string when it first makes contact with the string such that the jumping of the threads can be 'felt' and the acceleration of the rotation of the tubular can be initiated immediately after a jump is felt thus eliminating any possibility of cross threading due to lack of alignment or synchronisation.
  • the upper grips and slips, if outside the Coupler pressure hull can be a top drive or the upper section of an iron roughneck, (but with limited ability to snub a tubular against an internal pressure) or manual roughnecking (with no ability to snub against an internal pressure).
  • the lower Grips & Slips if outside the pressure hull, can be a powered rotary slips, capable of supporting a tubular string, or the lower section of an iron roughneck with limited ability to support the weight of a tubular string, or a bottom drive of an unconventional type like the pipe gripping tracks used in offshore pipelaying.
  • the Upper and Lower Grips & Slips if inside the Coupler pressure hull, can be rotary slips of the type developed by Varco BJ or the gripping components of a conventional an iron roughneck, modified to support the weight of the tubular string and to rotate and torque the upper and lower boxes of the tool joint by differential gearing, thus allowing both boxes to continue rotating as they are connected or disconnected.
  • the Upper and Lower Grips & Slips if inside the Coupler pressure hull can be above or below the blind preventer or pass through it when it is open.
  • the preferred solution is to support the string with grips & slips, mounted in a large bearing in the lower section of the Coupler pressure hull and to grasp the tubular with upper grips & slips in the upper section, while it is filling with mud, and then move the tubular down through the open blind ram to make the connection.
  • both the upper and lower grips and slips located inside the pressure hull of the Coupler for several reasons, which include the following: (a) The gripping to takes place on the thicker wall of the tool joint box with its rougher surface and larger diameter, (b) The scaling takes place on the smoother surface and smaller diameter of the tubular shaft (c) The slips act positively on the upset shoulder of the box, (d) The path of the force lines is minimised, (e) The accuracy of the mating is maximised.
  • This invention allows snubbing to take place by 'pulling' the two halves of the tool joint together within the Coupler instead of, as is currently the practice, pushing the tubular with external rigging.
  • This invention allows tubulars to be added to the string even at the full pressure rating of the BOP stack.
  • the two halves of the tool joint may be moved together, or apart, with minimum force, by pressure balancing the axial motion of the upper grips and slips as shown in Figs.l and 2 which is the preferred basic coupler solution.
  • the grips and slips do no more than a conventional iron roughneck achieves but it is carried out under the pressure of the inlet mud during normal mud circulation. This is to hold the string still, while screwing in the tubular and then torquing up the connection to as much as 70,000 ft lbs.
  • This invention enables this to be done under pressure inside the Coupler up to the full discharge pressure of the mud pumps or the pressure rating of the preventers, whichever is the lower.
  • This Basic Coupler enables mud circulation to continue uninterrupted while adding, or removing tubulars, which achieves most of the advantages of the new drilling method, such as steady ECD (Equivalent Circulating Density), good formation treatment and avoidance of stuck bits and BHAs.
  • ECD Equivalent Circulating Density
  • the Basic Coupler can be assembled from proven iron roughneck and ram preventer components and requires little development. It is suitable for retrofitting onto most of the existing Rigs that employ Kelly Drilling.
  • the Basic Coupler has to be located beneath the rotary table in order that the Kelly bushing does not have to pass through the Coupler.
  • the Basic coupler therefore has to be designed to support the weight of the string during tool joint connections and disconnections. As such the sequence of Coupler Operations is as shown in Fig. 4.
  • the two sets of grips and slips both rotate while connecting and disconnecting so that the string can continue rotating.
  • the screwing and torquing of the tool is achieved by differential gearing which ensures that the torquing of the connection is independent of the torque required to rotate the string.
  • This Rotary Coupler enables mud circulation and string rotation to continue uninterrupted while tubulars are added or removed from the string, which achieves almost all of the benefits listed below.
  • the Rotary Coupler can be assembled from well proven iron roughneck, rotary power slips and rotary BOP components with a moderate amount of engineering development. It is suitable for retrofitting on most of the existing rigs that utilise Top Drive Drilling. As such the sequence of Coupler operations is as shown in Fig.6. The possibility of integrating the coupler with the BOP stack reduces the overall height still further as shown in fig. 7
  • the Kelly Saver Sub provides the gripping surface for the grips to grasp, an upset shoulder for the slips to act on and a smooth shaft for the preventer to seal on.
  • the Basic Coupler similarly enables continuity of mud circulation and drilling provided that a mud motor is used. If no mud motor is used continuous drilling is possible if a Rotary Coupler is used. In either case little modification is required to install a Coupler on a rig using Top Drive Drilling.
  • Fig. 8 In Top Drive Drilling, there is the alternative shown in Fig. 8 where the Coupler is mounted on a short hoist to follow the drill bit down during connections and eliminate the need for a bumpersub. Whereas this is a heavy mechanical feat, it eliminates the problem that bumpersubs wear out quickly and that the bit weight, during connections, has to be pre-set.
  • the invention has the advantage that the rotation of the tubing and circulation of fluids can be continuous, over or underbalanced pressure can be maintained continuously and over or underbalanced drilling is possible without interruption, the tubing string bore is never open to the environment and the method is easier than existing methods to automate.
  • the method can also eliminate the need for heavily weighted muds and the exposed well bore is less likely to collapse.
  • Drilling Coupler to casing Coupler eliminates the need to employ damaging kill fluids between drilling and casing.
  • Coupler that splits vertically and of which two can work hand-over-hand as in Fig. 11.
  • Couplers will benefit from 'weight engineering' to reduce their mass and clever engineering design for the closing and latching mechanisms but they offer the best opportunity to simplify the total rig design and achieve the fastest tripping times.
  • They can flexibly handle singles, doubles or triples or varying lengths of tubular assemblies including BHAs with large diameter components such as centralisers and under reamers and can be interchangeable and even operate hand-over-hand in threes. They eliminate all other drives, drawworks and swivels and could be mounted on the ground without any rig structure. However they are likely to be mounted on hydraulic masts.
  • Both the Basic and Rotary Drilling Couplers can handle a range of tubular diameters From below 4 inches to about 7 inches. It is intended that two or more casing couplers will handle a range of casing diameters from about 9 inches to 20 inches or more including stab, twist and squnch joints. All Couplers require the preventers to actuate far faster than is normal, which can be achieved by adding a secondary low pressure/high flow hydraulic system connected with high pressure valves that can only open under a low pressure differential. Thus the past motion actuation is achieved by the low pressure /high flow system and the high closing force is achieved by the high pressure/low flow system.
  • All Couplers require a compliant landing surface on the top of the Blind Ram blade, such that the impact of the pin of the tubular on the blade is absorbed without damage to pin or blade and that the landing surface is star shaped so that the tubular can be easily flushed out with mud, or air, or water while still in contact with the blade.
  • the casing Coupler is of significant value in Underbalanced Drilling since it is possible to leave the well, prior to casing it, in a steady and controlled pressure regime without having to introduce weighted mud to kill the well, which usually damages the exposed formation, which is to produce later.
  • Couplers require "doping" of the threads prior to connection and this may be achieved by one or more high pressure mud jets set in the Coupler body impinging on the rotating pin and box immediately before coupling.
  • the mud is required to be free of particulates or fines above a given screen mesh size and heavy weighting material is unlikely to be required when drilling with Couplers.
  • fresh mud can be specially piped under high pressure to the said jets for activation briefly as the pin and box come together.
  • Couplers assist in centralising and aligning the tubular and string axially and the stand off distance of the pin from the box is set by zeroing the pin against the blind ram blade.
  • variations in the height of the box from the upset shoulder to the top surface of the box will not matter since the tubular is inserted with only enough force to seat the threads without damaging them and the acoustic or mechanical signal of the jumping of the threads is the signal to proceed with screwing up, as explained before.
  • Coupler is able to centralise the tubular and string onto the centre line of the Coupler within reasonable accuracy as does a conventional roughneck; the centre line of the pin thread may be eccentric to its tool joint and the box thread likewise. Additionally the tubular and string may not be completely aligned axially. The initial landing of the pin threads on the box threads may therefore often cause high point loading between threads, which is the common situation with conventional drilling with Kellies or with Top Drives which often damages the threads.
  • the method of orientating the tubular relative to the string can be achieved by an anticlockwise rotation of the pin relative to the box until the threads jump, which can be detected mechanically of acoustically after which the pin and box can be made up.
  • the String is static and the tubular is rotated anticlockwise to reach the jump point.
  • the Rotary Coupler the string is rotating so the tubular is static until the jump point is found.
  • the marking of the pins and boxes to identify the best relative orientation can be carried out using a matching master pin and box and marking up the tubulars on site regardless of their source of supply.
  • the actual marking cannot be visible since the string may be totally enclosed and must be picked up mechanically or electrically.
  • the simplest method being to produce a structural change on the shaft of the tubular, within inches of the upset shoulder between the surfaces acted upon by the slips and the RBOP seal.
  • This structural change (bump, weld, or signal emitter, etc) can then be detected (for example, mechanically, acoustically, electrically or radiographically) and the upper grips and slips can orientate the tubular accordingly.
  • the finding of the jump point which is how threads are usually orientated manually, is not necessary.
  • By this method of marking the best relative orientation for the optimum landing of pin in box is achieved, which is facilitated by this mechanised approach to Coupling.
  • the combination of the Coupler's internal design and the improved method of physically inserting the pin in the box should provide much faster coupling, plus improved repeatability and reliability and therefore reduced cost and improved safety.
  • this RBOP is intended, according to the invention, to be operated at lower differential pressure, low sealing force and wet on both sides so that the rate of wear is greatly reduced. Additionally it may reduce its sealing force as a tool joint passes through whenever the RBOP above it is closed, thus increasing the life of the stack RBOP seal.
  • the wellhead drilling assembly consists of a near standard BOP stack, including a stack RBOP, on top of which is connected a coupler consisting of the lower RBOP, a lower slips and grips unit, a blind ram or diverter and an upper slips & grips unit above this is connected the upper RBOP.
  • the upper RBOP can be most easily changed out with the string supported in the lower slips and grips and sealed of by the blind ram.
  • the lower RBOP can also be changed out without difficulty, but this may only be required once during the drilling of a well and can be done when a bit or bottom hole assembly has to be inserted into the well or changed out.
  • the upper slips and grips of the coupler will have the ability to move vertically in order to connect or disconnect a tubular to or from the tubular string.
  • the upper RBOP can optionally be a double RBOP in order to have a back up seal and the ability to test the lower seal for excessive leakage.
  • the drilling coupler be removed.
  • a through bore valve or diverter is placed in the well at depth below ground level or mud line that allows a complete bit or down hole assembly to be installed, inserted or contained in the well above it. This will be required at an early stage but usually not before the 20 inch casing has been installed and it could be that the, so called, down hole diverter can be of the same bore as the largest BOP to be used during the drilling, maybe 13 3/8 in.
  • the 20 inch casing may have to be hung off, latched and locked at the level of the diverter with the next casing up, perhaps 24 in, sized at the full well pressure rating from the diverter level to the wellhead.
  • the diverter used in this application can have inserts installed to match the casing program such that, as each casing is installed the diverter internal diameter is reduced and the diverter can shut in the well at various sizes, e.g. from 13 3/8 in down to production tubing size.
  • the down hole diverter allows the lower RBOP and stack RBOP to be changed out without opening the well to the environment and without having to operate one of the BOP stack rams.
  • the down hole diverter allows the BOP stack to be changed out and the well to be completed with a production tree, without opening the well to the environment and hence there is never a need to circulate kill fluid into the well to hold it in.
  • the down hole diverter set as much as 300 ft or so down the well also provides an extra barrier to the down hole safety valve (DHSV) and is similarly a convenient cut off location, clear of seabed sloughing, iceberg scour, beam trawling and, on land, earthquakes, storm damage and the like and sabotage.
  • DHSV down hole safety valve
  • a single large diameter drilling coupler is installed above the BOP stack to allow each casing to be connected to the casing string without opening the well to the environment.
  • This drilling coupler consists of an annular RBOP with, on top of it, a lower casing slip & grips, a blind ram, an upper casing slips & grips and an upper RBOP.
  • Each stand of casing has a casing head allowing the circulation of fluid down the well and the returning fluid is contained by the stack RBOP and flows to the mud processing unit which is itself totally enclosed (as are most processing plants).
  • the casing is installed and connected the same way as the drill pipe but the need for high torque is absent and many variations to the method of connection such as stab and squnch can be handled by the casing Connector.
  • the stability of the uncased hole still benefits greatly from continuous pressure maintenance plus continuous mud circulation and continuous rotation; all of which maintains the wall of the exposed formation in the optimum steady state regime that has been established since it was first drilled. Only when the string has been fully installed and the cement has been circulated to the required location is the rotation of the casing stopped. This casing rotation assists greatly the creation of a continuous unbroken cement job.
  • casing couplers will exist for all casings up to as much as 20 inch casings, where shallow gas or shallow water may be present, down to 9 5/8 inch and possibly 7 inch liner for example, two or three casing couplers will probably encompass all casing diameters up to twenty inches.
  • either of the two drilling Couplers can be used with appropriate inserts on the slips and grips.
  • the structure of the invention is a coupler and it is a feature of the invention that the basic or rotary coupler may, with minor modification, be used in conjunction with a top-drive or bottom drive or one or more couplers to achieve hand-over-hand or hand-to-hand operations with the bottom coupler being static or mobile during the connection or disconnection of tubulars.
  • the whole purpose of the above equipment and methods is to use "off the shelf components and tried and tested methods as much as possible; but to combine these in such a way that the well bore, at least from the 20 in casing onwards, is never again opened to the environment. This then eliminates the one situation, which currently requires that an additional barrier is placed in the well, that of the heavy kill fluid, of which the reliability is naturally limited to only one pressure i.e. the static head of the mud chosen.
  • the weight of the fluid is chosen specifically to achieve the correct 'pressure gradient' from the top to the bottom of the wall of the exposed formation.
  • the actual pressure at the exposed formation is set by the inlet and outlet pressures at the wellhead and these can be set at will, changed immediately and can be kept continuous, while tubulars and tubular components of all sorts can be added or removed from the string and the strings themselves can be changed out as well, without disturbing, the optimum steady state.
  • the coupler is as short as possible to minimise the overall BOP and coupler height beneath a drilling derrick and the mobile coupler is as light as possible; the invention achieves this by integrating each slips and grips into one unit and by allowing the upper grips and slips to pass through the open blind preventer to meet up with the lower slips and grips and by combining the space required for the upper slips and grips with the space required for flushing the mud in or out.
  • All vertical motions may be carried out at an angle to the vertical as in the case of slant drilling where the wellhead is set at an angle to the vertical.
  • Safety is increased because: Identifying small variations in pressure, flow, temperature, and density are very much easier with steady state background conditions and improve well control. Continuous closure of the string improves safety and also allows the string to be run back to bottom if needed in extreme kick conditions while circulating continuously. Continuous circulation under any desired pressure, regardless of the current mud weight, allows improved and immediate response to kicks.
  • Drilling Costs per Well Because: With no interruptions to drilling when adding tubulars, with continuity of drilling at steady state optimum conditions, with longer life of the drilling bits, with much less chance of stuck bits, BHAs & drill string, with less costly mud weighting and gel components in the mud, with better downhole measurement & control and safety, the drilling costs per well should equate to a saving of several days on most wells, to weeks on extended reach wells and/or in difficult formations. Secondly, on platform rigs drilling several holes in succession, the overall additional early production is very significant to the DCF return on investment. The savings can be equated to those quoted for Coiled Tubing, to which can be added the benefits of string rotation. Additionally the assembly can be retrofitted to all current rigs that use top drive, which provides the potential for a very large saving in drilling costs to the Drilling Industry worldwide.
  • Hole Quality is improved because: by drilling continuously, with steady state down hole conditions, the exposed formation wall is subjected to less damage from
  • Fig. 1 shows an arrangement of the present invention
  • Fig. 2 shows the sequence of adding a tubular
  • Fig. 3 shows the grips and slips options
  • Figs. 4 to 11 show sequences of adding a tubular in various different applications
  • Fig. 12 shows a BOP configuration for use in conventional drilling rigs to achieve continuous pressure control whilst inserting or removing BHAs from the well or when switching couplers and
  • Fig. 13 shows thread alignments.
  • a tubular (1) having an upset shoulder (2) and pin (3) is to be connected to drill string (10).
  • the coupler of the invention has an upper RBOP of pipe ram (4), upper grips and slips (5), blind ram preventer or diverter (6), box (7), lower grips and slips (8) and lower RBOP or pipe ram (9).
  • the blind ram (6) is closed.
  • the mud, air and hydraulic fluid is circulated as shown so there is continuous circulation of the mud and rotation of the drill string.
  • the couplers and/or the top drive may be designed to move laterally to remove or fetch a tubular.
  • a separate tubular handling system removes or offers up a tubular to the coupler or top-drive and performs the link with the function of storing or stacking tubular stands.
  • the sequence 1 to 4 is followed to connect the tubular to the string and the sequence 5 to 8 followed to disengage a tubular.
  • the tubular is gripped by the upper grips and slips in 3 the blind preventer is opened and the tubular rotated, in 4 the tubular and the drill string are engaged and the tubular rotated faster than the drill string and torqued up to make the connection and the upper an lower slips and grips disengaged.
  • this process is reversed as shown in 5 to 8.
  • Drilling sequences are illustrated diagrammatically in figs.3 and options for the location of the grips and slips above, within or below the coupler pressure hull are shown diagrammatically.
  • Fig. 4 shows the sequence during "Drilling on” with Kelly drilling, in which there is one Coupler (mounted below the normal Rotary table.
  • This hand-to-hand method is applicable to most existing drilling rigs.
  • Fig. 5 shows the sequence during "Drilling on” with Kelly drilling in which there is one Coupler (mounted below an elevated Rotary table. This hand-to-hand method is applicable to most existing drilling rigs.
  • Fig. 6 shows the sequence during "Drilling on” with Top drive drilling in which there is one coupler mounted on or below the rig floor. With or without short vertical travel for continuous drilling. .
  • the top drive is (16). This hand-to-hand method is applicable for all rigs using top drives.
  • Fig. 7 shows the sequence during "Drilling on” with Top drive drilling in which there is one coupler integrated with the BOP stack. With downhole bumpersub for continuous drilling. This hand-to-hand method is applicable for all rigs using top drives.
  • Fig. 8 shows the sequence during "Drilling on” with Top drive drilling in which there is one coupler mounted on a short hoist. This hand-to-hand method is applicable for existing rigs with top drive.
  • Fig. 9 shows the sequence during "Drilling on” with Bottom drive (17) drilling in which there is one coupler mounted on a short hoist. This hand-to-hand method is applicable for a new rig design eliminating drawworks.
  • Fig. 10 shows the sequence during "Drilling on” with a mobile rotary table (18) in which there is one coupler mounted on a short or long hoist plus rotary table on a long hoist.
  • This hand-to-hand method is applicable for a new rig design eliminating drawworks.
  • Fig. 11 shows the sequence during "Drilling on” without top or bottom drives in which there are two identical couplers (A) and (B) with split bodies (mounted on long hoists). This hand-over-hand method is applicable for a new rig designs only.
  • a wellhead drilling assembly consists of a standard BOP stack (36), with a stack RBOP (35). Above this is connected the coupler (34) consisting of a lower RBOP (if considered necessary), a lower grips and slips unit (34), a blind ram (or diverter) and an upper grips and slips unit onto which is connected the upper RBOP (33). There is a downhole diverter (38) which creates the chamber (37) and the distance X can be as much as 300ft or more.
  • fig. 13 shows the position of the threads on the tubular and string when they are brought together.
  • Figs. 13 a and 13b shows the two situations to be avoided and fig. 13c indicates the range of overlap to be achieved that will produce neither too little an overlap of the teeth to avoid overstressing the teeth nor too little a clearance with the teeth above to avoid collision.
  • fig. 13a there is too little overlap to avoid high stress
  • fig. 13b there too little clearance to ensure passing when landing.
  • fig. 13c there is a safe range of overlap that will neither overstress a tooth nor collide with the tooth above on landing.

Landscapes

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

Abstract

Au cours du forage d'un puits, on ajoute et on retire des éléments tubulaires du train de tiges alors que la circulation de boue se poursuit. Un bloc obturateur (6) à mâchoire à fermeture totale est positionné entre les organes inférieurs de saisie et de retenue (8) en contact avec le train de tiges du fond de puits et les organes supérieurs de saisie et de retenue (5) en contact avec un élément tubulaire à ajouter au train de tiges. On positionne l'élément tubulaire sur le bloc obturateur à mâchoire à fermeture totale, on ouvre le bloc obturateur à mâchoire à fermeture totale, on fait passer les organes supérieurs de saisie et de retenue dans le bloc obturateur à mâchoire à fermeture totale et l'on raccorde l'élément tubulaire au train de tiges.
PCT/GB1999/003411 1996-10-15 1999-10-14 Procede de forage WO2000022278A1 (fr)

Priority Applications (11)

Application Number Priority Date Filing Date Title
DE69924629T DE69924629D1 (de) 1998-10-14 1999-10-14 Bohrverfahren
EP99949233A EP1121508B1 (fr) 1998-10-14 1999-10-14 Procede de forage
AT99949233T ATE292740T1 (de) 1998-10-14 1999-10-14 Bohrverfahren
US09/807,476 US6591916B1 (en) 1998-10-14 1999-10-14 Drilling method
CA002346880A CA2346880C (fr) 1998-10-14 1999-10-14 Procede de forage
MXPA01003767A MXPA01003767A (es) 1998-10-14 1999-10-14 Metodo de perforacion.
BR9914774-2A BR9914774A (pt) 1998-10-14 1999-10-14 Conjunto de cabeça de poço e método para perfurar poços
AU62207/99A AU759454B2 (en) 1998-10-14 1999-10-14 Drilling method
US09/703,178 US6688394B1 (en) 1996-10-15 2000-10-31 Drilling methods and apparatus
NO20011680A NO317821B1 (no) 1998-10-14 2001-04-04 Brønnhodesammenstilling og fremgangsmåte for boring av brønner
US10/442,548 US7252151B2 (en) 1998-10-14 2003-05-21 Drilling method

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB9822303.5 1998-10-14
GBGB9822303.5A GB9822303D0 (en) 1998-10-14 1998-10-14 Drilling method

Related Parent Applications (2)

Application Number Title Priority Date Filing Date
PCT/GB1997/002815 Continuation-In-Part WO1998016716A1 (fr) 1996-10-15 1997-10-14 Procede de forage a circulation continue
US09/284,449 Continuation-In-Part US6315051B1 (en) 1996-10-15 1997-10-14 Continuous circulation drilling method

Related Child Applications (4)

Application Number Title Priority Date Filing Date
US09807476 A-371-Of-International 1998-10-14
US09/807,476 A-371-Of-International US6591916B1 (en) 1998-10-14 1999-10-14 Drilling method
US09/703,178 Continuation-In-Part US6688394B1 (en) 1996-10-15 2000-10-31 Drilling methods and apparatus
US10/442,548 Continuation US7252151B2 (en) 1998-10-14 2003-05-21 Drilling method

Publications (1)

Publication Number Publication Date
WO2000022278A1 true WO2000022278A1 (fr) 2000-04-20

Family

ID=10840474

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB1999/003411 WO2000022278A1 (fr) 1996-10-15 1999-10-14 Procede de forage

Country Status (10)

Country Link
EP (1) EP1121508B1 (fr)
AT (1) ATE292740T1 (fr)
AU (1) AU759454B2 (fr)
BR (1) BR9914774A (fr)
CA (1) CA2346880C (fr)
DE (1) DE69924629D1 (fr)
GB (1) GB9822303D0 (fr)
MX (1) MXPA01003767A (fr)
NO (1) NO317821B1 (fr)
WO (1) WO2000022278A1 (fr)

Cited By (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2001066905A2 (fr) * 2000-02-25 2001-09-13 Weatherford/Lamb, Inc Appareil et procede
WO2001069034A3 (fr) * 2000-03-14 2002-03-07 Weatherford Lamb Systeme de mise en circulation de fluide pour puits de forage
WO2002036928A1 (fr) * 2000-10-31 2002-05-10 Coupler Developments Limited Procede de forage a circulation continue
WO2003060287A1 (fr) 2001-12-31 2003-07-24 Maris International Limited Appareil de manipulation de conduite
US6684737B1 (en) 1999-01-28 2004-02-03 Weatherford/Lamb, Inc. Power tong
WO2005012685A1 (fr) 2003-07-31 2005-02-10 Maris International Limited Procede de forage
WO2011093714A1 (fr) * 2010-01-26 2011-08-04 Tool-Tech As Presse-étoupe sous-marin et procédé pour faire passer un train de tiges de forage à travers le presse-étoupe
WO2012176182A2 (fr) 2011-06-23 2012-12-27 Laurence John Ayling Appareil de forage à rotation continue pendant l'ajout d'un tubulaire
NO20161762A1 (no) * 2016-11-07 2018-05-08 West Drilling Products As Anordning ved enhet for kontinuerlig borevæskesirkulasjon
KR20190044250A (ko) * 2017-10-20 2019-04-30 삼성중공업 주식회사 연속시추장치
KR20190049199A (ko) * 2017-11-01 2019-05-09 삼성중공업 주식회사 연속트리핑장치
KR20200004535A (ko) * 2018-07-04 2020-01-14 삼성중공업 주식회사 연속시추용 서브 실링장치
KR20200008311A (ko) * 2018-07-16 2020-01-28 삼성중공업 주식회사 연속시추용 리볼빙 어셈블리 및 이를 포함하는 천공장치
US10995563B2 (en) 2017-01-18 2021-05-04 Minex Crc Ltd Rotary drill head for coiled tubing drilling apparatus

Families Citing this family (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
NO333021B1 (no) * 2010-01-26 2013-02-18 West Drilling Products As Anordning og framgangsmåte for boring med kontinuerlig verktøyrotasjon og kontinuerlig borevæsketilførsel
US20190078401A1 (en) * 2017-09-14 2019-03-14 Ensco International Incorporated Tool joint positioning
EP4202178A1 (fr) * 2021-12-23 2023-06-28 Sandvik Mining and Construction Oy Système de commande, dispositif de forage de roches et procédé de commande de mesures de couplage

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB1597028A (en) 1977-08-26 1981-09-03 Tokyo Shibaura Electric Co Image-pickup apparatus
WO1998016716A1 (fr) * 1996-10-15 1998-04-23 Maris Internatinal Limited Procede de forage a circulation continue

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB1597028A (en) 1977-08-26 1981-09-03 Tokyo Shibaura Electric Co Image-pickup apparatus
WO1998016716A1 (fr) * 1996-10-15 1998-04-23 Maris Internatinal Limited Procede de forage a circulation continue

Cited By (25)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6684737B1 (en) 1999-01-28 2004-02-03 Weatherford/Lamb, Inc. Power tong
WO2001066905A3 (fr) * 2000-02-25 2002-02-07 Weatherford Lamb Appareil et procede
WO2001066905A2 (fr) * 2000-02-25 2001-09-13 Weatherford/Lamb, Inc Appareil et procede
WO2001069034A3 (fr) * 2000-03-14 2002-03-07 Weatherford Lamb Systeme de mise en circulation de fluide pour puits de forage
US6412554B1 (en) 2000-03-14 2002-07-02 Weatherford/Lamb, Inc. Wellbore circulation system
WO2002036928A1 (fr) * 2000-10-31 2002-05-10 Coupler Developments Limited Procede de forage a circulation continue
NO335857B1 (no) * 2000-10-31 2015-03-09 Coupler Dev Ltd Kopler for kontinuerlig sirkulasjon av et borefluid gjennom en borestreng under tilføyelse eller fjerning av rør
WO2003060287A1 (fr) 2001-12-31 2003-07-24 Maris International Limited Appareil de manipulation de conduite
WO2005012685A1 (fr) 2003-07-31 2005-02-10 Maris International Limited Procede de forage
US9151135B2 (en) 2010-01-26 2015-10-06 Electrical Subsea & Drilling As Underwater stuffing box and method for running a drill string through the stuffing box
WO2011093714A1 (fr) * 2010-01-26 2011-08-04 Tool-Tech As Presse-étoupe sous-marin et procédé pour faire passer un train de tiges de forage à travers le presse-étoupe
US9637995B2 (en) 2011-06-23 2017-05-02 Laurence John Ayling Drilling apparatus with continuous rotation while tubular is being added
WO2012176182A2 (fr) 2011-06-23 2012-12-27 Laurence John Ayling Appareil de forage à rotation continue pendant l'ajout d'un tubulaire
NO20161762A1 (no) * 2016-11-07 2018-05-08 West Drilling Products As Anordning ved enhet for kontinuerlig borevæskesirkulasjon
NO343013B1 (no) * 2016-11-07 2018-09-24 West Drilling Products As Anordning ved enhet for kontinuerlig borevæskesirkulasjon
US10995563B2 (en) 2017-01-18 2021-05-04 Minex Crc Ltd Rotary drill head for coiled tubing drilling apparatus
US11136837B2 (en) 2017-01-18 2021-10-05 Minex Crc Ltd Mobile coiled tubing drilling apparatus
KR20190044250A (ko) * 2017-10-20 2019-04-30 삼성중공업 주식회사 연속시추장치
KR102006695B1 (ko) 2017-10-20 2019-08-02 삼성중공업 주식회사 연속시추장치
KR20190049199A (ko) * 2017-11-01 2019-05-09 삼성중공업 주식회사 연속트리핑장치
KR102106497B1 (ko) 2017-11-01 2020-05-04 삼성중공업 주식회사 연속트리핑장치
KR20200004535A (ko) * 2018-07-04 2020-01-14 삼성중공업 주식회사 연속시추용 서브 실링장치
KR102106493B1 (ko) 2018-07-04 2020-05-04 삼성중공업 주식회사 연속시추용 서브 실링장치
KR102106503B1 (ko) 2018-07-16 2020-05-04 삼성중공업 주식회사 연속시추용 리볼빙 어셈블리 및 이를 포함하는 천공장치
KR20200008311A (ko) * 2018-07-16 2020-01-28 삼성중공업 주식회사 연속시추용 리볼빙 어셈블리 및 이를 포함하는 천공장치

Also Published As

Publication number Publication date
ATE292740T1 (de) 2005-04-15
NO317821B1 (no) 2004-12-13
GB9822303D0 (en) 1998-12-09
AU6220799A (en) 2000-05-01
EP1121508A1 (fr) 2001-08-08
DE69924629D1 (de) 2005-05-12
NO20011680D0 (no) 2001-04-04
BR9914774A (pt) 2001-07-03
AU759454B2 (en) 2003-04-17
EP1121508B1 (fr) 2005-04-06
NO20011680L (no) 2001-06-06
MXPA01003767A (es) 2002-09-18
CA2346880C (fr) 2007-04-03
CA2346880A1 (fr) 2000-04-20

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