MXPA01003767A - Drilling method. - Google Patents

Abstract

In drilling wells tubular members are added to or removed from the drill string whilst the circulation of mud continues and there is a blind preventer (6) positioned between lower slips and grips (8) engaging a downhole drill string and an upper slips and grips (5) engaging a tubular to be added to the drill string and the tubular is positioned on the blind preventer, the blind preventer opened and the upper slips and grips passed through the blind preventer and the tubular connected to the drill string.

Description

PERFORATION METHOD DESCRIPTION OF THE INVENTION The present invention relates to a method for drilling wells, in particular a drilling for hydrocarbons. In the drilling of hydrocarbon wells, in particular for oil, the bit or drill bit is rotated to drive the drill bit and mud is circulated to cool, lubricate and extract the rock cuttings formed by the drill. As the perforator penetrates the earth, more drilling tubular rods are added to the driller's upright.

This involves stopping the perforation while the tubulars are added. The process is reversed when the drilling strut is removed, for example to replace the drill bit. This interruption of the perforation means that the circulation of the mud stops and that it has to be restarted with the new beginning of the perforation, which, besides consuming a time and being expensive, can also lead to effects of deterioration on the walls of the perforation. Well that is being drilled, and can lead to problems to keep the well "open".

Ref: 128431 PCT patent application 97/02815 discloses a method for continuous rotation of the drill bit, while adding or removing tubular. In this application there is provided a method for drilling wells in which a bit of auger is rotated at the end of an upright of the perforator comprising tubular members joined together, and mud is circulated through the tubular upright of the perforator, at whose method the tubular members are added or removed from the piercer's stile while the mud circulation continues. The method provides the supply of slurry, at the appropriate pressure, in the immediate vicinity of the tubular connection to be broken, so that the mud flow thus supplied overlaps with the sludge flow from the upper actuator, as the tubular is separated from the stile of the perforator; the flow of sludge to the separate tubular is stopped, for example by the action of a blind ram or other jamming device or other closing device such as a gate valve. Then, the separated tubular can be flooded, for example, with air or with water (if underwater) depressurized, removed, disconnected from the upper actuator and removed. The action of the jamming device consists in dividing the tubular connection into two parts, for example by dividing the pressure chamber of the connector that connects the tubular to the strut of the perforator. The perforator post continues to be run through mud at the required pressure. In a preferred embodiment of the invention, a tubular can be added using a securing means comprising a coupler and the upper end of the piercer post is enclosed in and secured by the lower section of the coupler, in which coupler there is a device blind obstruction separating the upper and lower sections of the coupler, the tubular is then added to the upper section of the coupler and sealed by an annular obstructing device and the blind obstructing device is opened and the lower end of the tubular and the upper end of the Driller's stile are joined together. During use, the lower section of the coupler below the blind obstructing device will already enclose the upper end of the piercer post before the tubular is lowered and when the tubular is lowered towards the coupler, the upper section of the coupler above of the blind obstructing device will enclose the lower end of the tubular. The tubular can be added to the piercer post by securing the lower section of the coupler to the upper part of the rotary piercer post with the blind obstructing device in the closed position preventing the escape of mud or drilling fluid. The tubular is lowered from a substantially vertical position above, towards the upper section of the coupler, and the rotating tubular is then sealed by a closure so that all the drilling fluid is contained, the blind obstructing device is then opened and the tubular and the piercing post are brought into contact and they are joined to each other with the grips that lead to the tubular and the stinger of the perforator to the correct torsion.

The lower end of the tubular and the upper end of the piercer post are separated by the blind obstructing device in such a way that the tubular can be sealed by means of an upper annular impeding device so that when the blind obstructing device is opened it does not exist eustancially no leakage of mud or drilling fluid and the tubular support and the drilling post can then be joined and integrated to the required torsion. To remove another tubular from the piercer post, the tubular reel or underground guard below the upper actuator penetrates the upper part of the pressure chamber, fills with mud and pressurizes; the blind ram opens allowing the upper actuator to provide circulating mud and the reel to connect with, and apply torque on, the driller's upright. The pressure vessel can then be depressurized, filled with air (or water, if it is under water), and the uprights of the perforator raised until the next gasket is inside the pressure chamber, the ram of "rods and holds "closes, the pressure chamber is flooded with mud and pressurized, and the cycle repeats. Preferably, the coupler includes rods that support the piercer post, while the upper actuator is raised to accept and connect another tubular. The coupler can be a static coupler connected to and above the BOP (explosion prevention device) wellhead assembly with an upper actuator or mobile coupler, which handles the tubulars located above the static coupler, working hand-in-hand . The coupler can be a mobile coupler, disconnected from the wellhead BOP assembly, with an upper actuator or second mobile coupler that handles the tubulars located above it, working hand in hand, and thereby allowing the upright to move uniformly in the vertical plane, when the displacement is in progress, or allowing the perforation to continue while a tubular is being added. The coupler can be a mobile coupler disconnected from the wellhead BOP assembly, with one or more identical mobile couplers, located above it, which take it in turn to become the bottom coupler, working hand-in-hand and also facilitating the uniform movement of the upright when the displacement is in progress or the drilling is continued, while a tubular is being added to the upright. The method described in patent application PCT / GB97 / 02815, locates the grips and rods inside or outside the pressure cover of the coupler. I have now designed an improved structure and method of continuous drilling. According to the invention there is provided a wellhead assembly comprising a BOP assembly, above which are placed sequentially: (i) a lower annular impeding device (ii) lower grips and rods, adapted to fit with an upright of the perforator in the lower part of the hole (iii) a blind obstructing device (iv) upper grips and rods, adapted to fit with a tubular to be added to the drilling member and (v) an upper annular impeding device in which the upper grips and rods can pass through the blind obstructing device, when the blind obstructing device is in the open position. This is shown in Figure 1 of the accompanying drawings and the sequence of operation of adding a tubular to the upright is shown in Figure 2.

Function of the grips and rods The grips are the means to grip the tubulars sufficiently strong to transfer a rotating force or torque, by friction surfaces formed to fit the outer surface of the tool joint, or the shaft of the tubular, or by means of activated rollers, both being normal methods in conventional perforation-assist iron elements.

The rods are the means of applying an axial force to the tubular to prevent sliding, by wedging action and / or by obstructing the passage of the upper assembly of the tool joint, as is common in conventional rods. The grips and rods combine the functions of grip and slip, either by modifying the profile of the adapters, rollers or friction rods, or by integrating separate grips and rods to work together. The orientation of the well head assembly refers to the well head assembly when it is in position on an upright of the perforator. The gripping mechanism, with or without integrated rods, can be achieved by simply altering the materials and the profile of the inserts of the conventional rotating BOP, diverter, jamming device, or rotating control head. Alternatively, the grip can be achieved by conventional methods of wedge, lever, motorized nut rollers or other mechanical means operated by hydraulic, electric or mechanical means, such as are currently applied in clamp connectors, cover clamps rotating actuating rods or elements current drill aid iron. In use, the invention allows a tubular to be added to a piercer post, when a piercer post is rotating and when the piercing mud is flowing. The lower grips and clamps support and rotate the piercer post, the tubular post circulation continues without interruption and the superequilibrated or unbalanced pressure in the hole and ring of the well is continuously maintained. The upper blocking device is opened and the new tubular is placed on the blind obstructing device, preferably having an equalization means, in order that the tubular is correctly positioned above the perforator post, for example, supporting the tubular on a eetrella that stands out in the blind obstructive device, that is, the tubular one "graduates as zero". Then, the upper stabbing device and the upper grips and rods are closed and the new tubular can have air (or water, if the bore is taking place under water) replaced by the appropriate drilling fluid. Then, the blind obstructing device is opened and the circulation (or reverse circulation) of the tubular post continues without interruption from two parallel sources and the pressure, superequilibrated or unbalanced, in the well and ring of the well is continuously maintained. Then, the. The new tubular is brought into contact with the piercer's upright, passing through the blind obstructing device, and is controlled by the shanks and upper grips and, when the tubular is in contact with the driller's upright, the new tubular rotates faster than the stile of the perforator, in order that said new tubular is "twisted to the required torque" by means of the action of the grips and rods superior to the action of the grips and lower rods, while both elements continue to rotate and the new tubular Screw on the top of the perforator's upright. Preferably, the new tubular does not rotate as fast as the upright, when it is first contacted with the upright, so that the "jump" of the threads can be "felt", and the acceleration of the rotation of the tubular can be Initiate immediately after an echelon of thread is eected, eliminating in this way any possibility of damaging the rope, due to lack of alignment or synchronization. The upper annular jamming device, as well as the grips and rods, are opened, the perforator post is lowered and the process can be repeated. To extract a tubular, the sequence is inverted.

Variations on the location of rods and grabs A feature of the method of PCT / GB97 / 02815 is that either the grapples and rods superior or the lower ones, or both, can be placed on the inside or outside of the coupling's pressure cover and that, when they are outside, the operation of the upper grips and valets can be executed by an upper actuator and the operation of the lower grips and rods can be executed by means of a rotary driving table, and this is schematically indicated in fig. 3.

When they are outside the coupler pressure cover, the upper grips and rods may be an external actuator or the upper section of a drill-assist iron element (but with limited capacity to tie a tubular against an internal pressure) or a manual drill aid element (without any ability to tie against internal pressure). When they are outside the pressure cover, the lower grips and rods may be swivel rods, capable of supporting a borer of the driller, or the lower section of a drill-assist iron element with limited capacity to support the weight of a drill. tubular upright, or a lower actuator of an unconventional type such as the pipe gripping elements used in the installation of offshore tubes. When they are inside the coupler pressure cover, the upper and lower grips and rods can be rotating rods of the type developed by Vareo BJ, or the gripping components of a conventional drill aid iron element, modified to support the weight of the tubular post and to rotate and tighten the upper and lower boxes of the tool joint by differential drive, thus allowing both boxes to continue to rotate, while being connected or disconnected.

When they are inside the pressure cover of the coupler, the upper and lower grabs and rods can be above or below the blind obstructing device or pass through it when it is opened. The preferred solution is to support the stud with grips and rods, mounted on a large support in the lower section of the coupling pressure cover, and grasp the tubular with grip and upper rods in the upper section, while being filled with mud and, later, move the tubular down, through the open blind ram, to make the connection.

Operations under high internal pressure The required clamping force, against the maximum internal pressure of the mud, is much higher than that which is possible by pushing the tubular in the head of the well using external forces. Using the pair of grips and rods in close proximity, the lines of force are short and are contained within the mass body of the pressure cover. To facilitate that the threads fit without undue stress, the vertical movement of the upper grips and shanks is balanced in pressure inside the pressure cover. The preferred solution is to have both the upper and lower grips and rods located inside the coupler pressure cover, for several reasons, including the following: (a) Gripping takes place on the thickest wall of the box of tool joint, with its rougher surface and its larger diameter. (b) The reduction takes place on the smoothest surface and smallest diameter of the tubular, (c) The rods act positively on the upset projection of the box, (d) The trajectory of the lines of force is minimized, (e) The precision of the coupling is maximized. In connection with the formation and breakage of tool joints under high pressure, even up to the degree of full pressure of the closure elements, the possibility of tubular "tying" inside the well head is practically impossible. Even for fairly moderate pressures, special handling equipment is necessary to tie tubulars in a pressurized wellhead. However, this invention allows the clamping to take place by "pulling" together the two halves of the tool joint inside the coupler, instead of, as is currently practiced, pushing the tubular with external equipment. This invention allows tubulars to be added to the upright even in the full pressure range of the BOP assembly. To achieve accurate and controlled formation and breakage of tool joints, when subjected to high mud pressures, the two halves of the tool joint can be moved together or separately, with a minimum force, by pressure balancing the axial movement of the upper clamps and shanks, as shown in the fige. 1 and 2, which is the preferred solution of the basic coupler. In addition, since the two grips and rods are so close together and within a body of mass, the torque twisting of each other is simplified.

Configuration of the basic coupler In the basic coupler, the grips and rods do not do more than what is connected with a conventional iron drill aid element, but this is carried out under the pressure of the inlet mud, during the normal circulation of mud . This is to keep the upright still while the tubular is screwed in and then tighten the connection to a tightening torque of up to 70,000 ft. Lbs. This invention allows this to be effected under a pressure inside the coupler which has a value of the full pressure of the mud pumps, or the value of the pressure degree of the disposable devices, which is smaller. The basic coupler allows mud circulation to continue uninterrupted while adding or removing tubulars, thereby providing most of the advantages of the new drilling method, such as an ECD (Eguivalent Density of Circulation) uniform, good treatment of the formation and avoidance of stuck bits and BHAs. The basic coupler can be assembled from proven drilling support iron components and water hammer devices, and requires little development. It is suitable for retrofixing in most existing equipment that uses Kelly drilling. The basic coupler must be placed under the turntable, so that the Kelly bushing does not have to pass through the coupler. Therefore, the basic coupler has to be designed to withstand the pee of the upright during connections and disconnections of the tool seal. As such, the sequence of operations of the coupler ee as shown in FIG. Four.

Configuring the rotary coupler On the rotary coupler, the two sets of grips and rods rotate while the connection and disconnection is in progress, so that the upright can continue to rotate. The screwing and tightening to the specified torque of the tool is connected by differential reduction, which guarantees that the tightening torque of the connection is independent of the torque required to rotate the upright. This rotary coupler allows mud circulation and column rotation to continue without interruption while tubulars are added to the upright or tubular are removed from it, thereby achieving almost all the advantages indicated below. The rotary coupler can be assembled from well proven performance drill bit iron elements, rotating BOP vanes and components, with moderate engineering development. It is suitable for retrofixing in most existing equipment that uses drilling with an actuator euperior. In this way, the sequence of operations of the coupler is as shown in FIG. 6. The possibility of integrating the coupler with the BOP assembly reduces the overall height even more, as shown in fig. 7 Kelly Perforation In the Kelly drilling rig, when the Kelly element is connected to the stud or when it is disconnected, the Kelly element provides the gripping surface for the grips, a projection stressed to act on the studs and an axle smooth so that the jamming device can seal. In drilling Kelly, the same drilling has to be stopped while a new tubular is added to the upright, because the Kelly element has to be recovered from the well, which raises the auger, separating it from the bottom by about 30 feet or more and, therefore, it matters little that the rotation of the amount is not continuous. The majority of the advantages continue to be obtained, due to the continuous circulation of sludge, as already indicated. However, with this invention, it is possible to reposition the turntable 30 feet higher, so that the bottom of the Kelly element reaches the coupler when it is time to add another tubular to the upright. With this method, the auger can remain on the bottom, while a new tubular is added to the upright. Normally, this could cause problems, but the continuous circulation of mud prevents sedimentation of cuttings and debris around the auger and BHA. This is shown in fig. 5. • Therefore, whenever a striking element (or introducer) is included above the section of the drill collar, drilling may continue, provided the bit can rotate. If a basic coupler is used, then the continuous turning of the bit requires a mud motor that uses the continuous circulation of mud, now available. If the auger is rotated by the upright, then a rotary coupler can be used to maintain the rotation of the upright. In any form and, subject to the relocation of the rotary table and / or the Kelly casing system, the perforation with most of the elements using Kelly elements can be continuous now, with continuous rotation of the upright.

Drilling with upper actuator When drilling with an upper actuator, the basic coupler allows the continuity of mud circulation and drilling simultaneously, provided a mud motor is used. If no mud motor is used, continuous drilling is possible if a rotary coupler is used. In both cases, little modification is required to install a coupler on a type that uses a perforation with an upper actuator. In the upper actuator drilling, there is the alternative option shown in fig. 8, where a coupler is mounted on a short hoist to follow the drill bit downwards during connections and eliminate the need for an underground striking element. Although this is a heavy mechanical element, it eliminates the problem that the striking elements wear out quickly and that the weight of the bit must be prefixed during connection.

Sub-Balanced Perforation (UBD) The invention has the advantage that the rotation of the tubes and the circulation of the fluids can be continuous, the euper or eubequilibrated preemption can be maintained continuously and the super or balanced perforation is possible without interruption, the orifice of the Pipe stud is never open to the environment and the method is easier to automate than existing methods. The method can also eliminate the need for very heavy sludge and is less likely to collapse the exposed hole in the well. The ease of transition from the drilling coupler to the deck coupler eliminates the need to employ harmful plugging fluids, between drilling and covering.

Future actuator systems Future actuator systems are anticipated, where the actuator will be a "bottom actuator", probably of the type of tube tension trajectories, which are used in the installation of offshore tubes, where they are transmitted to the tube. very high axial If such a mechanism were to be rotated, then the sequence of using a coupler would be as shown in FIG. 9. The total elimination of the upper actuator and bottom actuator systems would be possible with a coupler and a rotary table mounted on long polipastoe, one above the other, as shown in FIG. 10. This requires a considerable vertical displacement, but not greater than that which is conventionally used for stacking double and triple sets. The advantage of this system is that the displacement ee can execute in a smooth uniform operation, which benefits the hydraulics of the lower part of the orifice, accelerating slowly until a speed that is much higher than what is currently possible and with a global duration which is much shorter. Once again, the minimization of the deterioration of the exposed formation will normally be more valuable than the time saved. The continuous displacement can achieve the time saving, without deteriorating the exposed formation. The future, long-term application of the coupler, as anticipated and described in PCT / GB97 / 02815, is a coupler that divides vertically and two of which can work hand over hand, as shown in FIG. . 11. Such couplers have the advantage of "engineering peeoe" to reduce eu maea, and a skilled engineering for closing and locking mechanisms, but offer the best opportunity to simplify the total design of the equipment and to achieve the times of faster displacement. These elements can flexibly handle single, double or triple or variable lengths of tubular assemblies, including BHAs, with large diameter components, such as centering and reamers, and can be interchangeable and can even work hand-in-hand in trios. Eliminate the rest of actuators, rigging maneuvers and articulacionee giratoriae, and can be mounted on the ground without any structure of equipment. However, they are likely to be mounted on hydraulic poles.

Drill and deck couplers Both basic and rotary drilling couplers can handle a range of tubular diameters ranging from less than 4 inches to approximately 7 inches. It is projected that two or more deck couplers will handle a range of tire diameters ranging from approximately 9 inches to 20 inches-or more, including torsion and drill joints. All couplers require that the jamming devices act much faster than is normal, which can be added by adding a secondary low pressure / high flow hydraulic system, connected with high pressure valves that can only be opened under a small difference of pressure. Thus, the action after movement is achieved by the low pressure / high flow flow system and the high closing force is achieved by the high pressure / low flow system. All couplers need a suitable bearing surface on top of the blade of the blind ram, so that the impact of the barrel of the tube on the blade is absorbed without deterioration for the barrel or the blade, and so that the surface of support has a star shape so that the tubular can easily be flooded with mud or air or water, while still in contact with the blade. The cover coupler has a significant value in the sub-balanced perforation, since it is possible to leave the well, before covering it, in a regime of uniform and controlled pressure, without having to introduce heavy mud to cover the well, which normally harms the the exposed formation, which is going to produce later.

Quality and doping of the mud All the couplers require a "doping" of the threads before the connection and this can be achieved by means of one or several jets of high pressure mud fixed in the body of the coupler that impinge on the rotating barrel and the box, immediately before the coupling.

The mud is required to have no particle or fine element at a specific mesh size and heavy material is not likely to be required when drilling with couplers. In the event that particles with significant sizes can not be economically filtered, the fresh sludge can be transported by tube under high pressure to the mentioned jets, for activation, briefly, when the cannon and the box are joined together.

Mechanical details All the couplers help to axially center and align the tubular and the upright, and the distance from the barrel to the box is set to zero that distance when the barrel is against the blind ram blade. However, variations in the height of the box from the upset projection to the upper surface of the box do not matter, since the tubular is introduced with a force sufficient only to seat the threads without damaging them, and the acoustic signal or mechanical jump of the threads is the signal to proceed to its threading, as explained above. Although the coupler is able to center the tubular and the upright on the centerline of the coupler, with reasonable precision, as with a conventional drill aid element; The central line of the barrel of the barrel can be eccentric with respect to the tool joint, as well as the threads of the box. In addition, the tubular and the upright may not be fully aligned axially. Therefore, the initial support of the threads of the barrel on the threads of the box can often cause high point load between thread thread, which is the common situation with conventional drilling with Kelly elements or with actuators euperiores that, frequently, deteriorate the roeca thread. In this invention, it is intended that the tubular and the upright are joined with a more controlled method that avoids the possibility of deteriorating the threads of the barrel or the box. First, this is achieved by using the upper grips and rods to introduce the barrel into the box, in a situation of balanced pressure, where the force necessary to move the tubular downwards is minimal. In addition, the hydraulic oil pressure, as shown in FIG. 1, compensates for the different diameter and tubularee differences, which would otherwise disturb the predetermined pressure balance ratio. As indicated elsewhere, the orientation method of the tubular, in relation to the upright, can be connected by a counterclockwise rotation of the barrel, in relation to the box, until the threads jump, which can be detected mechanically or acoustically, after which you can compose the barrel and the box. In the basic coupler, the upright is static and the tubular is rotated counterclockwise to reach the jump point. In the rotary coupler, the upright is rotating, so that the tubular is static until the jump point is found. By executing the connection from a small counterclockwise rotation from the jump point, any possibility of damaging the thread is minimized. However, this does not prevent the high percentages that can be produced when the cannon is initially supported in the box, and with the coupler you try to take advantage of the more automated method and improve the control of this particular activity by supporting the cannon in the box . In this invention it is planned to ensure that the tubular and the upright are oriented relatively in azimuth, so that the situation in which the tapered threads of the barrel and the box collide is avoided, with a very small eolapado of the threads of thread to absorb the shock without plastic deformation. Ineffective overlap of the threads can occur on the bearing surface, as shown in FIG. 13a, or it can occur due to impact with the upper rope, particularly when the barrel and the box are not concentric, as shown in fig. 13b. Figure 13c indicates the safe operating range, to avoid any of the above deterioration situations. It is estimated that being just in the preferred half of a turn of rotation would greatly reduce the deterioration of the threads, which is normally experienced. The fact of taking the best relative orientation will almost eliminate such deterioration. The best specific orientation will vary with the design of the thread, but all taper threaded connections will benefit from this method. The marking of the guns and the boxes, to identify the best relative orientation, can be done using a barrel and a box model and marking the tubulars in the place of installation, regardless of their source of supply. The actual marking can not be visible, since the upright can be totally enclosed and must be lifted mechanically or electrically. The simplest method is to produce a structural change in the body of the tubular, to an inch of the elevated stress between the surfaces attacked by the rods and the RBOP seal. Then, this structural change (blow, wind or signal emitter, etc.) can be detected (for example, mechanically, acoustically, electrically or radiographically) and the grip and upper rods can orientate the tubular accordingly. By this method, it is not necessary to find the jump point, which is how the roeca threads are normally oriented manually. By means of this marking method, the best relative orientation is achieved for the optimal support of the barrel in the box, which is facilitated by this mechanized approach for coupling. The combination of the internal design of the coupler and the improved method of physically introducing the barrel into the box should provide a much faster coupling, in addition to better repeatability and better reliability and, therefore, lower cost and greater safety.

Off-shore drilling and underwater drilling In off-shore drilling, in particular, using the couplers, the number of deck uprights can be reduced and / or the reach of the drilling, vertically and horizontally, can be significantly increased. In drilling executed in deep water, where conventional drilling is very expensive, talee couplers, which isolate the tubular pillar of the marine environment, can be used to great advantage in the "drilling without rising column", which is currently under development. In very deep water, where drilling is currently uneconomical, the application of these couplers in future drilling rigs, which will be located on the seabed, will be of great value.

Increasing the life of the RBOP seal In relation to the routine change of the rotating BOPs, it is preferred that the same BOP assembly is mounted above a diverter, so that the RBOP of the BOP assembly can be changed without opening the hole of the well to the environment. As explained, this RBOP is designed, according to the invention, to operate at lower differential pressure, low sealing force and wet in amboe ladoe, so that the degree of wear is markedly reduced. In addition, its sealing force can be reduced when a tool joint passes through it, provided that the upper RBOP was closed, thus increasing the life of the RBOP seal of the assembly. Preferably, the well head drilling assembly is composed of an almost normal BOP assembly, which includes a RBOP of the assembly, in the upper part of which a coupler is connected which comprises in the lower RBOP, a lower unit of vagagoe and grips, a blind ram or diverter and an upper rod unit and grips, on this, is connected to the RBOP euperior. Therefore, the RBOP euperior can be changed and removed more easily, the upright being supported on the lower grips and rods and sealed by the blind ram.

The lower RBOP can also be changed and removed without difficulty, but this can only be necessary once during the drilling of a well, and can be done when an auger or set of bottom hole must be inserted or extracted in the well. The upper rods and grips of the coupler will have the ability to move vertically, in order to connect a tubular to the tubular upright or to disconnect a tubular from the tubular upright. Optionally, the upper RBOP can be a double RBOP, in order to have a backup seal and the possibility of testing the lower seal to check for excessive leakage.

BHAs and large diameter components As both drill rig couplers require both sets of RBOP, to work mainly on drill pipe, it is economical to design the operation so that it is not necessary to go through the larger diameters of tubular components such such as drill collars, drill bits and reamers. Therefore, it is preferred that the introduction and removal of such larger diameter components be arranged without passing through the coupler. Therefore, it is preferred that when inserting or removing large diameter components, the drill coupler is removed. To do this without connecting the hole in the well in the lower part of the well to the environment above the terrain or mud pipe, it is necessary that a through-hole or diverter valve is located in the well at a depth below the level of the soil or the mud pipe, which allows a complete set of auger or lower part of the hole, introduced or contained in the well above the mole, to be installed. This will be necessary at an early stage, but usually not before the 20-inch shroud has been installed, and the so-called lower-hole derailleur may have the same gap as the larger BOP to be used during drilling., which can be 13 3/8 inches. If, due to the degree of pressure, the derailleur can not be adjusted within the 20-inch shroud, then the 20-inch shroud may have to be suspended, closed and blogged at the derailleur level with the next shroud above, 24-inch shroud. inches, sized to the full degree of well pressure, from the level of the diverter to the wellhead. The flyer used in this application may have inserts installed to fit the deck program, so that when each deck is inelacted, the inside diameter of the flyer is reduced and the flyer can close the hole to dive size, for example, from 13 3 / 8 down haeta the size of production pipe.

Only the diverter is required to work down to the inside diameter of the drill coupler. Such a diverter has already been described. The diverter of the lower part of the hole allows the lower RBOP and the RBOP of the assembly to be changed without opening the well to the environment and without having to operate only one of the rams of the BOP assembly. The low hole deviator allows the BOP assembly to be changed and the well completed with a production shaft, without opening the well to the environment and, therefore, there is never a need to circulate plug fluid in the well. for its maintenance.

In relation to safety, the lower hole deviator, fixed up to approximately 300 feet below the well, also provides an additional barrier to the bottom hole safety valve (DHSV) and is similarly a comfortable cutting location, no shedding of rocks from the seabed, dragging of icebergs, dragging of fishing elements and, on land, earthquakes, deterioration by storms and similar elements, and sabotage. In relation to the installation of covers; when you are near horizons with probable hydrocarbons with, for example, a 20-inch cover already installed and a BOP assembly of 13 3/8 in place, then, when removing the driller's upright while it is circulating and rotating continuously, as described above, the upright is removed until only the auger assembly is still inside the well; At this point, the circulation can be stopped and the diverter can be closed below the auger. The upright is held or suspended within the BOP assembly and the two RBOPs are removed from the assembly. Then, the auger assembly is removed from the well and the operation of the cover begins. Before operating the cover, instead of the drill coupler, a single large diameter drill coupler is installed, above the BOP assembly, to allow each cover to be connected to the deck pillar, without opening the well to the environment. This drill coupler consists of an annular RBOP with, in its upper part, a lower cover rod and grip, a blind ram, a rod and upper cover grip and an upper RBOP. Each deck support has a cover head that allows fluid to circulate below the well and the return fluid is contained by the RBOP of the assembly and flows to the mud processing unit, which is totally enclosed (as are the largest part of the processing plants). The cover becomes inelastic and connects in the same manner as the drill pipe but the need for high torque is absent and many variations of the connection method can be handled by the cover connector. The stability of the uncovered hole continues to benefit notably from the maintenance of continuous pressure, in addition to the continuous circulation of sludge and continuous rotation; all of which keeps the wall of the formation exposed in the optimal uniform state regime that has been established since it was drilled for the first time. Only when the pillar has been completely installed and the cement has been moved to the required place does the roof turn. This rotation of the roof significantly helps the creation of a continuous task of cemented without breaking. It is anticipated that special deck couplers will exist for all decks up to 20-inch decks, where shallow gas or shallow water may be present, up to 9 5/8 inches and possibly 7 inches, for example, two or three couplers. Cover will probably cover all deck diameters, up to twenty inches. For 7-inch and narrower posts, any of the drilling couplers can be used, with appropriate inserts on the rods and grips. There is the option, under water, to compose the complete set of auger or lower hole of one to 100 to 300 feet and lower the complete assembly into the well in one operation. Nevertheless, on land, it is assumed that this is not likely to be as preferred as composing the set at convenient lengths of 30, 60 or 90 feet, at a time, and connecting and tightening them as they pass down through of the BOP set. In this way, things have to be arranged to grip and support the upright within the BOP assembly while the upper actuator (or lateral actuator, or lower actuator) adds another section. If the BOP set is to be reserved for its traditional purpose, then, instead, a simple and almost conventional set of rods can be installed, above the BOP set to achieve this.

System engineering The structure of the invention is a coupler, and a feature of the invention is that the basic or rotary coupler, with minor modifications, can be used in conjunction with a top actuator, a bottom actuator, or one or more couplers to achieve operations hand on hand or hand by hand being the coupler of the static or mobile fund during the connection or deeconnection of tubularee. The complete objective of the equipment and methods indicated above is to use "normal fabricated" components and methods that have been tested and tested as much as possible; but combine these elements so that the hole in the well, at least from the deck of 20 inches on, never opens up again to the environment. Thus, this eliminates the only situation in which an additional barrier is normally required to be in the well, such as that of the heavy fill fluid, whose reliability is naturally limited to a single pressure, ie the static head of the mud. chosen one. On the contrary, with this new method the weight of the fluid is specifically chosen to achieve the correct "pressure gradient", from the top to the bottom of the wall of the exposed formation. The actual pressure in the exposed formation is fixed by the inlet and outlet pressures at the well head, and these pressures can be fixed at will, changed immediately and can be kept continuous, while tubular and tubular components of all Classes can be added or removed from the upright and the same uprights can also be changed, without disturbing the optimum uniform state. Preferably, the coupler is as short as possible, to minimize the overall BOP and the height of the coupler below a derrick, and the mobile coupler is as light as possible; The invention achieves this by integrating each rod and grip into a unit and allowing the upper grips and rods to pass through the blind, open, obstructing device to meet the lower and lower rods and by combining the space required for the upper rods and grips with the space required to enter or extract the mud flow.

Interpretations All vertical movements can be made at an angle with respect to the vertical, as in the case of the inclined drilling, where the well head is fixed at an angle with respect to the vertical. All references to an upright of the perforator are equally applicable to a deck upright or to a production upright or to a barrel or mooring tube, or to any other tubular composite of diecrete lengths. All references to a tubular are applied equally to a single tubular or to a set of doe or more tubular. All references to drilling mud also apply to all fluids that are pumped into the well bore, for any purpose, during drilling and well life. All references to the environment apply to drilling under water as well as to drilling in the open air.

Advantages of the coupler A feature of the invention is that: 1. A greater efficiency of perforation is achieved, because the tubulars can be added to the upright without interrupting the perforation (so that no delay occurs while a tubular is being added and while the optimal state of the perforation is being restored). The perforation proceeds uniformly and continuously with the optimum conditions, so that the greatest attention can be concentrated on adjusting for bit weight, speed of rotation, pressure of the bottom of the hole, speed of clation and composition of the mud, etc .; to improve the ROP. With uniform state drilling, small deviations in the measurements of the lower part of the hole are much easier to identify and interpret, particularly because the density and temperature of the annular mud now remains uniform and consistent. The MWD and the PWD are more efficient since they are contiguous and have a significant importance against a uniform state base. Continuous drilling under optimal uniform conditions increases the useful life of the auger and reduces the damage that frequently occurs when the auger is returned to the bottom, either because it is hit against rock, or because it is rubbed through several feet of waste. 2. There is less drilling problem, because the continuous circulation keeps the cuttings in motion, so that no sedimentation occurs around the auger or auger assemblies, and the density of cuttings is constant throughout. the ring. Without sedimentation of cuts, clogged augers, BHAS, or seizure, the need to clean the hole is almost eliminated. With continuity of the pressure regime of the lower hole, pressure variations in the wall of the exposed formation are very remarkably reduced, and are almost eliminated, which results in much less loss or wall instability. 3. Increase security pergue: the identification of glue variations of pressure, flow, temperature and density, it is much easier with uniform background conditions and well control is improved. The continuous closure of the upright improves the safety and also allows the upright to move back towards the bottom, if necessary, under extreme conditions of backward movement while driving continuously. Continuous circulation under any desired pressure, regardless of the current weight of the sludge, allows a better and immediate recoil to the setbacks. 4. There are lower drilling costs per well, because: No interruption of the drilling when added tubularee, with continuity of the drilling in optimal conditions of uniform state, with a longer service life of the borer drills, with a much lower probability of obstruction of drilling posts, BHAs and drill bits, with a mud weighing and gel components in the lower cost mud, with higher measurement and control and hole safety of the lower part of the hole, drilling costs per well should lead to a saving of several days in most wells, up to weeks in wells with extended reach and / or in difficult formations. Second, in platform equipment that drills several holes in succession, the additional global early production is very significant for the return of DCF from the investment. The savings can be matched to the above mentioned for rolled pipes, to which the advantages of the turn of the amount can be added. In addition, the assembly can be modified for all normal equipment in which the upper actuator is used, which provides the potential for great savings in drilling costs for the global drilling industry. 5. The quality of the hole is improved because: by drilling continuously, with conditions of uniform state of the lower hole, the wall of the exposed formation is subjected to less deterioration by "pumping" of cuttings, found objects and components of the mud, inside of training and the quality of production training is improved. These advantages can result in large savings for equipment from operators, particularly in wells out of the coeta and can add savings per team that reach several million dollars per year. The invention is described in relation to the accompanying drawings, which are not to scale: FIG. 1 represents an arrangement of the present invention. Fig. 2 represents the sequence of addition of a tubular. Fig. 3 represents the options of grips and rods. Figs. 4 to 11 represent addition sequences of a tubular in different applications. Fig. 12 represents a BOP configuration for use in conventional drilling rigs, to achieve continuous control of pressure while BHAs are inserted into or removed from the po, or when couplings are changed.; and Figs.13a-13c rep ^ septari thread alignments.

In relation to fig. 1, a tubular (1) having a projection (2) upset and a barrel (3) is to be connected to the upright (10) of the perforator The coupler of the invention has an upper RBOP of tube (4), grips and upper rods (5), derailleur (6) or obstruction device of blind ram, box (7), grips and rods (8) lower and ram (9) of tube or lower RBOP. In fig. l, the blind ram (6) is closed. The sludge, air and hydraulic fluid is circulated as repre sented, so that there is a continuous circulation of the sludge and a continuous rotation of the perforator upright. As you can see in fig. l, the grips and shanks (2) paean through the jamming device (3), when the jamming device (3) is open. The couplers and / or the upper actuator can be designed to move laterally or to extract or pick up and bring a tubular. Preferably, a separate tubular handling unit removes or offers a tubular to the upper actuator or coupler and executes the link with the function of storing or stacking tubularee assemblies. In relation to fig. 2, the sequence of 1 to 4 is followed to connect the tubular to the upright and the sequence 5 to 8 to disengage a tubular. At 1, the upper part of the perforator post is grasped by the lower grippers; in 2, the tubular is grasped by the upper grips and shanks; in 3, the blind obstructing device opens and the tubular is rotated; in 4, the tubular and the piling upright fit together and the tubular rotates faster than the drilling member and tightens to the proper torque to execute the connection and the upper and lower rods and grips are disengaged. To extract a tubular, this process is reversed, as shown in the sequence from 5 to 8. The perforation sequences are schematically depicted in Figs. 3, and the options for the position of the grips and rods, above, inside or below the pressure cover of the coupler, are shown schematically. Fig. 4 represents the sequence during the "drilling" with Kelly drilling, where there is a coupler (mounted below the normal rotary table). The joint (11), the element Kelly (12), the table (13) rotating bush Kelly, the coupler (14) and the set of BOP (15). This hand-to-hand method is applicable to most existing drilling equipment. Fig. 5 represents the sequence during the "drilling" with Kelly drilling, where there is a coupler (mounted under a raised turntable). This hand-to-hand method is applicable to most existing drilling equipment. Fig. 6 represents the sequence during "drilling" with upper actuator drilling, where there is a coupler mounted on, or below, the ground of the equipment. With or without vertical short displacement for continuous drilling. The upper actuator is (16). This hand-to-hand method is applicable to all equipment in which higher actuators are used. Fig. 7 represents the sequence during "drilling" with an actuator drilling, where there is a coupler integrated with the BOP assembly. With element of underground hitting of the lower part of the hole for continuous drilling. This hand-to-hand method is applicable to all equipment in which higher actuators are used. Fig. 8 represents the sequence during the "Drilling" with upper actuator drilling, where there is a coupler mounted on a short hoist. This hand-to-hand method is applicable to existing equipment with an upper actuator. Fig. 9 represents the sequence during "perforation" with lower actuator drilling (17), where there is a coupler mounted on a short hoist. This hand-to-hand method is applicable for a new equipment design that eliminates the turning lathe. Fig. 10 represents the sequence during the "drilling" with a mobile rotating table (18), where there is a coupler mounted on a hoist, short or long, in addition to a rotary table on a long hoist. This hand-to-hand method is applicable for a new equipment design that eliminates the maneuvering lathe. Fig. 11 represents the sequence during "perforation" without upper or lower actuator, where there are two identical couplers (A) and (B), with divided bodies (mounted on long poly-piles). This hand method is only applicable to new equipment designs. In relation to fig. 12, a wellhead drilling assembly consists of a set of normal BOP (36), with a RBOP (35) of the assembly. Above this is connected the coupler (34), which consists of a lower RBOP (if considered necessary), a lower unit (34) of grips and rods, a blind ram (or flier) and an upper gripping unit and stem on which the RBOP (33) is connected. There is an inferior hole deviator (38) that creates the chamber (37), and the distance X can be as much as 300 feet, or more. On top of this is the tube handling equipment (32) (if necessary) and the upper actuator (31) (or rotary table, in Kelly drilling). In relation to fig. 13, the position of the threads of the tubular and the upright is shown, when they are brought together for their union. Figs. 13a and 13b represent two situations that must be avoided and fig. 13c indicates the overlap interval to be achieved, in that it will not produce a small overlap of the thread, to avoid excessive tension on them, nor a too small clearance with respect to the threads located above, to avoid collision. In fig. 13a there is an eolapado too small to avoid excessive tension, in fig. 13b there is too small a gap to guarantee the passage when it is supported. In fig. 13c there is a safe overlapping interval with which neither the threads will be subjected to excessive stresses nor collide with the threads placed above, at the moment of support. It is stated that this date, the best method developed by the sciences to carry out the aforementioned intention, is the one that is clear from the vivid description of the event. .

Claims (23)

1. CLAIMS Having described the invention as above, the content of the following claims is claimed as property: 1. A wellhead assembly comprising a set of BOP (Explosion Prevention Device), above which they are located sequentially : (i) a lower annular obstructing device (ii) lower grips and dowels, adapted to fit with a perforator upright from the lower part of the hole (iii) a blind obstructing device (iv) upper grips and pins, adapted to fit with a tubular to be added to the perforator (v) a superior annular impeding device characterized in that the upper grips and rods can pass through the blind jamming device, when the blind jamming device is in the open position.
2. 2. A well head assembly according to claim 1, characterized in that there is a location means for a tubular to be added to the piercer post to be correctly positioned above the piercer post.
3. 3. A well head assembly according to claim 1 6 2, characterized in that there are means for replacing air or water in the new tubular by drilling fluid, when the upper closing element and the upper grips and rods are closed.
4. 4. A well head assembly according to claim 1, 2 or 3, together with an upper actuator or one or more couplers characterized in that it is to achieve hand-over-hand or hand-to-hand operations, the static or mobile bottom coupler being during the connection or disconnection of tubulars.
5. 5. A well head assembly according to any one of the preceding claims, characterized in that the upper and lower grips and rods are located inside the pressure cover of the assembly.
6. 6. A wellhead assembly according to any one of the preceding claims, characterized in that the assembly is mounted on a short hoist to follow the drill bit downwards during the connections.
7. 7. A wellhead assembly according to any one of claims 1 to 6, characterized in that the assembly and a rotary table are mounted on long hoists, one above the other.
8. 8. A wellhead assembly as claimed in the claim, wherein the coupler can be divided vertically.
9. 9. A well head assembly as claimed in, wherein the BOP assembly is mounted above a diverter, so that the RBOP of the BOP assembly can be changed without opening the hole in the well to the environment.
10. 10. A well head assembly as claimed in claim, wherein the wellhead drilling assembly consists of an almost normal BOP assembly, which includes a RBOP of the assembly, in the upper part of which a coupler consisting of a coupler is connected. in the lower RBOP, a lower unit of rods and grips, a blind ram or diverter and an upper unit of rods and grips, above which the upper RBOP is connected.
11. 11. A method for drilling wells, characterized in that a drilling auger is rotated at the end of an upright of the driller comprising tubular members, joined together, and mud is circulated through the upright of the tubular driller, in which method tubular members they are added to the drilling rig or are removed from it, while the circulation of mud continues, and in which there is a blind obstructing device located between the rods and lower grips, which fit with a strut of the perforator of the lower part of the hole, and upper rods and grips, which fit with a tubular that is to be added to the piercer's upright, and the tubular is placed on the blind obstructing device, the blind obstructing device is opened and the upper rods and grips pass through the blind obstructing device and the tubular is connected to the piercer post.
12. 12. A method for drilling wells according to claim 11, characterized by rotating a bit of the driller located at the end of an upright of the driller, comprising tubular members joined together, and mud is circulated through the tubular upright of the drilling member. perforator, in which method tubular members are added to or removed from the perforator upright, while the circulation of sludge continues, and in which there is (i) a lower annular impeding device, (ii) lower clamps and shafts that fit together with an upright piercer post, (iii) a blind obstructing device, (iv) upper handles and rods that fit into a tubular to be added to the piercer post, and (v) a superior annular impeding device, and in which method a new tubular is added to the piercer's upright, controlling the tubular through the upper rods and grabs, opening the obstructing device above, placing the new tubular on the blind obstructing device and bringing the new tubular into contact with the piercer's upright, while it is rotating, passing the tubular through the blind obstructing device and closing the upper closure element.
13. 13. A method for drilling wells according to claim 11 or 12, characterized in that the new tubular is positioned by means of location, so that said tubular is positioned correctly above the piercer's upright.
14. 14. A method for drilling wells according to claim 11, 12 or 13, characterized in that, when the blind obstructing device is opened and the circulation of drilling mud through the tubular pillar continues without interruption from two overlapping sources and the continuity is maintained continuously. superequilibrated or unbalanced pressure in the hole and ring of the well. »
15. 15. A method for drilling wells according to any one of the preceding claims, characterized in that when the tubular is in contact with the strut of the perforator, the new tubular rotates faster than the strut of the perforator, in order that the new tubular is tighten to the required torque by the action of the upper grips and rods against the lower grips and rods, while both assemblies continue to rotate and the new tubular is screwed into the upper part of the perforator strut.
16. 16. A method for drilling wells according to claim 15, characterized in that the new tubular does not rotate as fast as the strut of the perforator when it comes into contact with the upright first, so that the jump of the threads can be "feel" and, then, the acceleration of the tubular turn begins.
17. 17. A method for drilling wells according to any one of the preceding claims, characterized in that there is a top actuator, or one or more couplers to achieve hand-over-hand or hand-to-hand operations, the bottom of the coupler being static or mobile during the connection or disconnection of tubulars.
18. 18. A method for drilling wells according to any one of the preceding claims, characterized in that the two halves of the tool joint move together compensating by pressure the axial movement of the upper grips and rods.
19. 19. A method for drilling wells according to any one of the preceding claims, characterized in that the two sets of grips and rods rotate while the tubular is connected and disconnected, so that the upright continues to rotate.
20. 20. A method for drilling wells according to any one of the preceding claims, characterized in that the rotary table is raised, so that the bottom of the Kelly element reaches the assembly when it is time to add another tubular to the upright and the bit can remain substantially on the bottom of the well while a new tubular is added to the upright.
21. 21. A method for drilling wells according to claim 20, characterized in that a diverter or through-hole valve is placed in the well at a depth below the level of the soil or the mud pipe and a complete set of auger is installed. or lower part of the hole in the well above it.
22. 22. A method for drilling wells according to any one of claims 11 to 21, characterized in that the tubular and the upright are relatively oriented, when brought into contact and the tapered threads overlap in an amount that does not subject to excessive stresses to the threads neither collides with the threads from above, when it supports.
23. 23. A method according to claim 22, characterized in that a counterclockwise rotation of the barrel occurs in relation to the box, until the threads jump and, then, the connection is executed from a small counterclockwise rotation, from the point of jump.