MX2014012000A

MX2014012000A - Rotating and reciprocating swivel apparatus and method.

Info

Publication number: MX2014012000A
Application number: MX2014012000A
Authority: MX
Inventors: Kip Robichaux; Terry Robichaux
Original assignee: Mako Rentals Inc
Priority date: 2012-04-04
Filing date: 2013-04-04
Publication date: 2015-05-08
Also published as: AU2013243394A1; US20130264065A1; WO2013152219A1; EP2834442A1; EP2834442A4; BR112014024626A2

Abstract

What is provided is a method and apparatus wherein a rotating and reciprocating swivel of adjustable stroke length and shearable by ram blow out preventers can be detachably connected to an annular blowout preventer thereby separating the lower wellbore from the riser. In one embodiment the mandrel of the swivel being comprised of double box end joints and using double pin end subs to connect a plurality of such mandrel joints together.

Description

APPARATUS AND METHOD OF ROTARY ROTATING UNION AND OSCILLATING ROBICHAUX, Kip, M. , an American Citizen, from Houma, Louisiana EE. UU; ROBICHAUX, Terry, P., a US Citizen, from Houma, Louisiana EE. UU Cross Reference to Related Requests This is an American Provisional Patent Application Serial Number 61 / 620,207, filed on April 4, 2012, which is incorporated herein by reference and whose priority is claimed herein.

American Patent Application Serial Number 12 / 682,912, entitled Rotating and Oscillating Rotary Union Apparatus and Method, having a filing date or section 371 (c) of September 20, 2010, is hereby incorporated by reference. in this document by reference.

Background of the Invention On deepwater drilling platforms, marine pipelines that extend from a wellhead fixed on the ocean floor have been used to circulate the drilling fluid or mud back to a structure or platform. The pipe should be large enough in internal diameter to accommodate a drill string or well string that includes the largest drill bit and drill pipe that is they will use in the drilling of a drilling well. During the drilling process, fluid or drilling mud fill the riser and well.

Brief Description of the Invention The method and apparatus of the present invention solves the problems faced in the art in a simple and direct manner.

One embodiment refers to a method and apparatus for deepwater platforms. In particular, one embodiment refers to a method and apparatus for carrying out the operations of the subsoil at a time when the annular antierption device is closed.

In one embodiment the displacement is contemplated in water depths greater than about 5,000 feet (1, 524 meters).

One embodiment provides a method and apparatus having a rotating union that can be operably and / or removably connected to an annular anti-burst device to thereby separate fluid or mud in the upper and lower sections.

In one embodiment, a rotating attachment tool having a sleeve or housing that rotatably and tightly connect with a mandrel can be used. The rotating union can be incorporated in a drill string or well.

In one embodiment, the cuff or housing can be fluidly hermetic to or from the mandrel.

In one embodiment, the sleeve or housing can be fluidly sealed with respect to the external environment.

In one embodiment, the hermetic system between the sleeve or housing and the mandrel is designed to resist infiltration of fluid from the outside of the sleeve or housing into the interior space between the sleeve or housing and the mandrel.

In one embodiment, the hermetic system between the sleeve or housing and the mandrel is designed to resist infiltration of fluid from the interior space between the sleeve or housing and the mandrel to the outside.

In one embodiment, the hermetic system between the sleeve or housing and the mandrel has a substantially equal pressure rating for the pressures that tend to push fluid from the outside of the sleeve or housing into the interior space between the sleeve or housing and the mandrel and the pressures that tend to push fluid from the interior space between the sleeve or housing and the mandrel to the outside of the sleeve or housing.

In one embodiment, a rotating union having a sleeve or a housing and the mandrel having at least one projection, a latch or extension is used to restrict longitudinal movement of the sleeve or housing relative to the annular anti-rupture device. In one embodiment, a plurality of projections, hooks or enhancements are used. In one modality, the plurality of protrusions, hooks or lugs are longitudinally separated with respect to the sleeve or the housing.

The rotary union tool can be closed by means of the annular anti-bursting device ("annular BOP"). Normally, the annular BOP is located immediately above the ram BOP whose ram BOP is located immediately above the subsea bed and mounted at the wellhead. As an integral part of the string, the mandrel of the rotating and oscillating tool supports the full weight, torque and pressure of the entire string located under the mandrel.

In one embodiment, at least in part when the annular seal is closed in the sleeve of the rotating union, the drill string or well moves intermittently longitudinally during operations in the subsoil, as in hydraulic fracturing work. .

In one embodiment, the rotating speed is reduced during periods of time when the oscillation is not occurring. In U4 > to mode, the rotational speed is reduced from approximately 60 revolutions per minute to approximately 30 revolutions per minute when the oscillation is not being performed.

In one embodiment, at least in part during the time when the annular seal closes in the rotary union sleeve, the drill string or well oscillate longitudinally. In one embodiment, an oscillatory movement of approximately 65.5 feet (20 meters) is contemplated. In one embodiment, approximately 20.5 feet (6.25 meters) of movement is contemplated to allow access to the bottom of the well. In one embodiment, approximately 35, 40, 45 or 50 feet (approximately 10.67, approximately 12.19, approximately 13.72 or approximately 15.24 meters) of the movement is contemplated to allow at least one pipe joint - the length of movement during oscillation. In one embodiment, the oscillation is performed at a rate of approximately 20 feet per minute (6.1 meters per minute).

In one embodiment, one or more brushes and / or scrapers are used in the method and apparatus.

In one embodiment, a shoe is used in the method and apparatus.

Hooks The annular BOP is designed to be fluidly tight in a wide range of articles of different sizes - for example, from 0 inches to 18 3/4 inches (or 47.6 centimeters) (or more). However, when an annular BOP is fluid-tight in the rotating and oscillating tool sleeve, the fluid pressures effectively exposed on the sleeve through the sectional area exert the longitudinal forces on the sleeve. These longitudinal forces are the product of Fluid pressure in the sleeve and effective cross sectional area of the sleeve. Where there are different pressures above and below the annular BOP (which can occur at the terminations with multiple stages), a net longitudinal force will act on the sleeve that tends to push it in the direction of the lower fluid pressure. If the differential pressure is large, this net longitudinal force can overcome the frictional force applied by the closed annular BOP on the sleeve and the frictional forces between the sleeve and the mandrel. If these frictional forces are overcome, the sleeve will tend to slide in the direction of the lowest pressure and may "push" out of the closed annular BOP. In one embodiment, the hooks engaging the annular BOP are provided to prevent the sleeve from being pushed out of the closed annular BOP.

For example, the lighter sea water on the board of the Annular BOP and heavier drilling mud, or weighted frills, and / or weighted completion fluid or a combination of all these, may be below the annular BOP requiring an increase in pressure to push such fluids from below the BOP Cancel through the sealing line and on the platform (at the selected flow rate). This pressure differential (which in many cases causes an ascending net force) acts on the effective cross-sectional area of the tool defined by the outer diameter of the string (or mandrel) and the outer diameter of the sleeve. For example, the diameter External clamping of the tool sleeve can be 9 3/4 inches (24.77 centimeters) and the outer diameter of the tool mandrel can be 7 inches (17.78 centimeters) providing an annular cross sectional area of 9 3/4 inches (24.77 centimeters) ) OD and 7 inches ID (17.78 centimeters). Any pressure differential will act in this annular area producing a net force in the direction of the pressure gradient equal to the pressure differential over the effective cross sectional area. This net force produces an upward force that can overcome the frictional force applied by the closed annular BOP on the tool sleeve causing the sleeve to be pushed in the direction of the net force (or slip through the hermetic element of the annular BOP) . To resist sliding through the annular BOP, the hooks can be placed in the sleeve that prevent the sleeve from being pushed through the annular BOP seal.

In any of the various embodiments, the following pressure differentials (eg, the difference between the pressures above and below the annular BOP seal) can be located axially in the sleeve or housing against which the hooks can be used to prevent the sleeve is pushed axially out of the annular BOP (even when the annular BOP seal has been closed) - in pounds per square inch: 500, 750, 1, 000, 1, 250, 1, 500, 1, 750, 2, 000, 2,250, 2,500, 2, 750, 3,000, 3,250, 3,500, 3,750, 4,000, 4,250, 4,500, 4,750, 5,000, 10,000 or greater (3,450, 5,170, 6,900, 8,620, 10,340, 12,070, 13,790, 15,510, 17,240, 18,960, 20,690, 22, 410, 24, 1 30, 25,860, 27,700, 29,550, 31, 400, 33,240, 35,090, 36,940, 73,880 kilopascals). In addition, the intervals between two of the previously specified pressures are contemplated. In addition, the ranges above any of the pressures specified above are contemplated. In addition, the ranges below any of the pressures specified above are contemplated. These differential pressures may be greater under the annular BOP seal or above the annular BOP seal.

Quick lock / Quick unlock After the sleeve and the mandrel have moved mutually in a longitudinal direction, an under / under lock / unlock system is required to lock the sleeve in a longitudinal position relative to the mandrel (or at least to restrict relative longitudinal movement available from the sleeve and the mandrel to a satisfactory amount as compared to the linear length of the effective sealing area of the sleeve). In addition, an underwater locking / unlocking system is required which can lock or unlock the sleeve and the mandrel a plurality of occasions while the sleeve and the mandrel are submerged.

In one embodiment, a system is provided where the submarine position of the linear length of the sealed area of the The sleeve (eg, the nominal length between the hooks) can be determined with sufficient precision to allow location of the effective sealing area of the sleeve in the annular BOP to close in the sealed area of the sleeve. After the sleeve and the mandrel have moved longitudinally translated relative to each other, when the annular BOP was closed in the sleeve, it is preferred that a system be provided where the underwater position of the sleeve can be determined even where the sleeve has moved. outside the ring BOP.

In one embodiment, a quick-lock / quick-release system is provided to locate the relative position between the sleeve and the mandrel. Because the sleeve can oscillate relative to the mandrel (ie, the sleeve and the mandrel can move relative to each other in the longitudinal direction), the ability to determine the relative longitudinal position of the sleeve relative to the mandrel can be important. at some point after the sleeve has oscillated relative to the mandrel. For example, in various uses of the rotary and oscillating tool, the operator may wish to seal the annular BOP in the sleeve at some time after the sleeve has oscillated relative to the mandrel and after the sleeve has been removed from the BOP cancel.

To deal with the risk that the actual position of the sleeve relative to the mandrel will be lost while the tool is submerged, a quick release / quick release system It can detachably connect the sleeve and the mandrel. In a locked state, this quick-lock / quick-release system can reduce the amount of relative longitudinal movement between the sleeve and the mandrel (as compared to an unlocked state) so that the sleeve can be placed on the annular BOP and the annular BOP is Closing relatively easily in the longitudinal sealed area of the sleeve. Alternatively, this quick-lock / quick-release system can lock the sleeve in relation to the mandrel instead (and does not allow a limited amount of relative longitudinal movement). After changing from a locked state to an unlocked state, the sleeve can experience its unlocked amount of relative longitudinal movement.

In one embodiment, a quick release / quick release system is provided which allows the sleeve to lock and / or unlock longitudinally relative to the mandrel a plurality of times when submerged. In one embodiment, the quick block / quick unlock system can be activated using the ring BOP.

In one embodiment, the sleeve and the mandrel can rotate with respect to each other in both activated and non-activated states. In one embodiment when in a locked state, the sleeve and the mandrel can rotate relative to each other. This option can be important where the ring BOP closes in the cuff at a time when the string is broken (whose mandrel is a part). By allowing the sleeve and the mandrel to rotate relative to each other, even when in a locked state, it minimizes wear and / or damage to the annular BOP caused by a rotating locked sleeve (eg, a safety pin) that rotates in relation to a closed annular BOP. In contrast, the sleeve can be held fixed in a rotational manner by means of the closed annular BOP, and the mandrel (together with the string) rotates relative to the sleeve.

In one embodiment, when the sleeve locking system is in contact with the mandrel, locking / unlocking is performed without the relative rotational movement between the sleeve locking system and the mandrel - otherwise grooving and / or grooving may occur. the scraping of the mandrel at the location of the block. In one embodiment, this can be achieved by rotating the sleeve portion of the quick release / quick release system in a rotary fashion to the sleeve. In one embodiment, a locking bushing that rotatably connects to the sleeve is provided.

In one embodiment, a quick-lock / quick-release system can be provided on the rotating and oscillating tool that allows the operator to lock the sleeve relative to the mandrel when the rotating and oscillating tool is underground or underwater. Due to the relatively large amount of possible movement of the sleeve relative to the mandrel (ie, different possible relative longitudinal positions), it may be important to know the relative position of the sleeve relative to the mandrel. This is especially true at the time the annular BOP is closed in the sleeve. The blocking position is important in determining the relative longitudinal position of the sleeve along the mandrel (and therefore the true underwater sleeve depth) so that the sleeve can be easily located in the annular BOP and the annular BOP is closed and / or insulate in the sleeve.

During the process of moving the rotating and oscillating tool underwater and under the ground, the sleeve can be locked relative to the mandrel by means of a quick-release / quick-release system. In one embodiment, the rapid locking / quick unlocking system can, in relation to the mandrel, lock the sleeve in the longitudinal direction. In a modality, the sleeve can be locked in a longitudinal direction with the quick release / quick release system, but the sleeve can rotate relative to the mandrel for as long as it is locked in a longitudinal direction. In one embodiment, the rapid locking / quick unlocking system can simultaneously lock the sleeve relative to the mandrel, as long as a longitudinal direction as well as rotationally. In one embodiment, the rapid locking / quick unlocking system can, in relation to the mandrel, lock the sleeve in a rotating manner, but at the same time allow that the sleeve moves longitudinally.

General modalities In one embodiment, the mandrel is comprised of a plurality of pipe / tube joints that are threadedly connected to each other.

In one embodiment, a sleeve or housing is rotatably and slidably connected with the mandrel.

In one embodiment, the sleeve and / or the housing includes a pair of separate sealed units that sealingly engage the sleeve and / or housing relative to the outer surface of the mandrel during the period of time when the sleeve is connected in a manner sliding or rotary to the mandrel.

In one embodiment, the sleeve and / or housing can remain stationary while a portion of the mandrel moves longitudinally or moves relative to the sleeve.

In one embodiment, the mandrel can move or pass through the sleeve and / or the oscillating or rotary housing while the sleeve and / or housing are held immobile with respect to an annular anti-burst device and with the annular anti-burst device which maintains a seal in the hermetic area of the sleeve and / or the housing. With the joint between the sleeve and / or the housing and the mandrel, in combination with the joint between the annular anti-rupture device and the sealed area of the sleeve, a seal can be maintained between above and below the annular seal of the annular anti-rupture device even when the mandrel is moved and / or rotated. This allows any drill string, tool and / or other article to be located under the mandrel that will rotate and / or oscillate while the closed annular anti-rupture device maintains a joint in the well, and without the ring seal of the annular anti-rupture device subject to differential movement, whose differential movement can damage the annular joint.

A mode, allows the mandrel movement area to slide relative to the sleeve and / or the housing, to thereby provide the benefit of longitudinal movement and / or rotation but substantially eliminating the differential movement of any article in contact with the mandrel. the annular hermetic element closed in relation to the closed annular hermetic element. Consequently, the risk of damage to the sealed annular sealing element is substantially eliminated.

Cutting mandrel design One embodiment provides a rotary sub-floor joining tool comprising a mandrel with longitudinal interior passage, the mandrel has a sleeve and / or a housing slidably connected to the mandrel, where the mandrel can rotate and oscillate / move relative to the sleeve and wherein the sleeve and / or the housing and the mandrel are hermetically sealed in a longitudinal direction.

For a long time there has been an unattended need to have a rotary attachment tool that includes a mandrel that is shear relative to a plurality of anti-surge devices of the stacked ram type regardless of the position of the mandrel relative to the anti-burst device stack. of type ram.

In one embodiment, within the length of movement of the mandrel, the outer mandrel that closes the surface can be retained substantially at a uniform diameter to maintain a longitudinal seal with respect to the sleeve and / or the housing.

One embodiment of the rotary union tool provides a mandrel, within the length of movement of the mandrel, the outer mandrel sealing the surface is maintained to a uniform diameter substantially to maintain a longitudinal seal with respect to the sleeve and / or housing, within this movement length the mandrel has an inner axial passage, the inner axial passage has a first and a second diameter, the first diameter is larger than the second diameter, where the longitudinal separation of the mandrel sections having the first diameter to the sections having the second diameter is such that at any one point at least one ram of a plurality of stacked anti-surge arrester devices would attempt to cut a section of the mandrel having the first diameter, thus ensuring the continuous cutting capacity of the mandrel.

In one embodiment, the outer sealing surface of the closure mandrel may have one or more creased areas. In one embodiment, the sleeve and / or the housing may have a plurality of separate sealed units, such that at any time during movement and / or rotation of the mandrel relative to the sleeve at least one of the separate sealed units it maintains a hermetic seal between the mandrel and the sleeve even when the other sealed unit is located above a split area of the mandrel.

In one embodiment, one or more crevices can be used to vertically support the mandrel when they constitute or break the mandrel when a drilling platform is.

In one embodiment, one or more split zones may be located in each male joint of the mandrel whose male joints have a thicker wall thickness relative to the thickness of each female joint of the mandrel.

In one embodiment, the smallest diameter of one or more split zones may be between the diameter of the axial passage through each male joint and the axial diameter of the axial passage of each female joint.

In one embodiment, the mandrel is composed of multiple joints between female ends having thin-walled tubes and / or pipes that meet the predefined cutting requirements. for an anti-surge device of the specified ram type.

Due to the ease of manufacture, commonly the longitudinal passage through a joint of the tubular element is substantially the same size.

In the removable threaded connections (eg, male and female threads) for the joints of tubular elements, the male portion of the connection is concentric with the female portion of the connection, where the male portion is internal to the female part of said connection. connection, the largest longitudinal passage through the male portion of such connection is necessarily less than the largest longitudinal passage through the female portion of the connection.

With a joint of the tubular element having a male-to-female end, the largest possible size of the longitudinal axial passage is controlled by means of the smaller internally concentric male end connection. With a gasket of the tubular element having a female-to-female end connection, the largest possible size of the longitudinal passage is now controlled by the size of the externally concentric female end connection, and may be larger than the size of a connection of internally concentric male end coupling.

Now a mandrel assembled by such a combination of joints of the female-to-female end joints alternately connected by the male-male end joints of the tubular element, may have the thin-walled portions separated which can be easily cut by means of ram-type anti-bursting devices. The separation of the thin-walled portions may be on opposite sides of the male-to-male joints of the mandrel. The female to male female to female alternative connection may have length spacings such that at any point at least one ram of the plurality of stacked anti-surge arrester devices would attempt to cut a thin wall portion of the mandrel thereby ensuring the continuous cutting capacity of the mandrel.

The mandrel may comprise one or more joints of tubes or pipes with the female to female ends and each joint is approximately 30 feet (9.1 m) in length.

The connection of the joints with female to female ends of pipes and / or pipes can be the joints of pipes that are male-to-male connections, where each of these joints from male to male are approximately 30 inches (76.2). cm) long.

The mandrel movement area can include a linear length of the combined plurality of mandrel joints where such joints have a substantially uniform outer seal diameter.

The threading can be used to detachably connect the chuck joints to each other.

In one embodiment, a groove and / or reduced diameter area can be machined into the surface of one or more of the mandrel's movement joints. In one embodiment, the reduced diameter groove and / or area is provided in the male-to-male movement joint of the mandrel.

In one embodiment, the slot and / or the reduced diameter area can be used to raise or lower the tool together with the bottleneck elevators.

In one embodiment, an annular joint between the joints of the mandrel can be activated by rotating a chuck joint relative to a second chuck joint.

In one embodiment, the plurality of chuck joints are provided wherein the female end has a conical end flange cooperating with a conical flange of a male end coupling joint to prevent the end of the female portion from expanding or expanding. when it is squeezed. In one embodiment, the flange of the male end and the flange of the female end are conical. In one embodiment, the conical elements are substantially parallel to each other and tend to cause the female end to be compressed and / or directed towards the internal axial passage of the mandrel.

Relationship between wall thickness of male-to-male and female-to-female end joints In one embodiment, the ratio between the wall thickness of the mating coupling joints is at least 2: 1, 3: 1, 4: 1, 5: 1, 6: 1, 7: 1, 8: 1, 9: 1, 10: 1, 12: 1, 14: 1, 16: 1, 1: 18 and 20: 1 . In various modalities, the relationship can be between any of two of the specified relationships. In one embodiment, the wall thickness of the female end joints 5 to female is designed to have the shear capacity in the anti-surge devices.

In one embodiment, the different wall thicknesses can be observed in the male to male joints of the mandrel compared to the female to female joints of the mandrel In this mode, the wall thicknesses of the female-to-female end joints of the wall are designed to have the shear capacity in the anti-surge devices. Mandrel consisting of double male end joints and double female end joints In one embodiment, the mandrel may comprise a plurality of double female-to-female end joints connected by the double male-to-male end joints, where the double male end joints are at least 4, 5, 6, 7 , 8, 9, 10, 12, 14, 16, 18, 20, 25, 30, 35, 40, 0 45, 50, 55, 60, 65, 70, 75, 80, 84, 85, 90, 95 and 100 feet (1 .2-30.4 meters). In various embodiments, the male end joint doubles may be separated by any of two of the lengths specified above.

In several embodiments, the male end joints, 25 in length, may be less than 48, 46, 45, 44, 42, 40, 38, 36, 34, 32, 30, 28, 26 and 24 inches (121.9-60.96 cm). In various embodiments, the length of the double male end joints can be any of two of the lengths specified above. 5 Sleeve with two separate airtight units that treat the cleft areas of the mandrel In one embodiment, within the movement length of the outer hermetic area of the mandrel with respect to the sleeve and / or the housing includes at least one slit area on the external hermetic surface of the mandrel (whose split area is used to support the weight of the drill string and the rotary union tool during the disconnection process in the rotary union tool in the well). In one embodiment, the mandrel includes a plurality of split areas spaced apart from the linear length of the mandrel and within the length of movement of the sleeve and / or housing.

In various embodiments, such an area or split areas can cause a sealed unit in the sleeve and / or housing to lose the partial or total seal between the sleeve and the mandrel when such an airtight unit passes over the split area. In various embodiments, such partial or complete loss of the hermetic seal of an airtight unit is compensated for by the remaining hermetic seal of the other separate sealed unit (which maintains a hermetic seal between the 25 sleeve and the mandrel on the external hermetic surface of the mandril).

In various embodiments, one or more creased areas in the outer hermetic portion of the mandrel include at least one transition piece that is of a softer material than the material comprising the outer hermetic area of the mandrel, for example, Teflon as compared to the steel. Other examples include rubber, viton, plastic, and polymer.

In one embodiment, the mandrel can be moved and / or oscillated with respect to the sleeve and / or the housing which causes one or more creased areas in the outer hermetic area of the mandrel to pass through the sleeve. In one embodiment, with the sleeve having the first and the second separate seal, the mandrel moves relative to the sleeve where: (1) the first and second hermetic units keep the hermetic seal between the sleeve and the mandrel independent; (2) the first sealed unit moves through the split area of the mandrel but the second sealed unit maintains the seal between the sleeve and the mandrel; or, (3) the second hermetic unit moves through the split area of the mandrel but the first hermetic unit maintains the hermetic seal between the sleeve and the mandrel.

In one embodiment, the linear length of one or more slit areas in the mandrel can be between 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 40, 45, 50 inches (2.5-127 cm); and the spacing between the sealed hermetic units in the sleeve and / or the housing.

Hermetic inserts for thin wall sections One embodiment includes the inserts for the thin wall sections of the female to female joints of the mandrel.

One embodiment has the inserts that are slidable relative to the joint of the mandrel in which the insert is contained.

One embodiment has the inserts that have a transition of internal diameter, from the smallest to the largest passage of internal diameter flow.

One embodiment includes the insert with an annular groove to at least partially contain an internal hermetic unit.

General method to constitute the movement mandrel when it is on the platform In one embodiment, there is provided a method for determining the length of movement of a rotary and oscillating rotating joint tool in a rig or drilling platform having a floor, comprising the steps of: 20 (a) providing a rotary union tool, the rotary union tool comprises a mandrel and a sleeve, the mandrel is rotatable and oscillating relative to the sleeve and / or the housing, the mandrel has a first length of movement relative to the hose and / or housing; 25 (b) support in a substantially vertical direction the rotating union tool on the platform; (c) adding a chuck joint to the upper part of the mandrel, such additional joint increases the length of movement of the mandrel relative to the first length of movement; (d) lowering the rotary union tool and again supporting in a vertical direction the rotary union tool in a substantially vertical direction on the platform; Y (e) repeating the unit of steps "c" and "d", the final movement length of the mandrel relative to the sleeve and / or the housing is at least 100 feet (30.4 m).

In various embodiments, the steps "c" and "d" may be repeated until the final movement length may be greater than 100, 150, 200, 250, 300, 350, 400, 450, 500, 550, 600, 700, 800, 900, 1000, 1200, 1400, 1500, 1600, 1800 and 2000 feet (30.4-609.6 m), or any length of movement is between any of the two specified lengths of movement.

In various embodiments, a plurality of mandrel joints include the split areas in the outer sealing surface, and during step "c", one of these split areas is used to support the rotating attachment tool in a substantially vertical direction.

In one embodiment, the plurality of split areas may include the soft material transition sections.

In several modalities, the upper portions of the Cleft areas can be frustroconical.

In various modalities, the upper portions of the split areas may be conical.

One embodiment comprises a method for increasing the length of movement of the mandrel while it is located on the equipment or platform.

One embodiment comprises a method for forming the mandrel while on the equipment or platform.

Stages of the general method In one embodiment, the method may comprise the following steps: (a) lowering the rotary and oscillating tool to the annular BOP, the tool comprises a sleeve and a mandrel; (b) after step "a", having the annular BOP close in the sleeve; (c) after step "b", causing relative longitudinal movement between the sleeve and the mandrel; Y (d) after stage "c", perform the operations in the well.

In various embodiments, the method may include one or more of the following additional steps; (1) after step "c", move the sleeve out of the annular BOP; (2) after step "(1)", move the sleeve inside the annular BOP and have the annular BOP close in the sleeve; (3) after a step "(2)", cause the relative longitudinal movement between the sleeve and the mandrel.

In one embodiment, during step "a", the sleeve is longitudinally locked relative to the mandrel.

In one embodiment, after step "b", the sleeve is unlocked longitudinally relative to the mandrel.

In one embodiment, after step "c", the sleeve locks longitudinally relative to the mandrel.

In one modality, during stage "c", the operations were performed in the well. In one modality, during the "(3)" stage, the operations are performed in the well.

In one embodiment, during step "c", the tool is fluidly connected to a string having a hole and the fluid is pumped through at least part of the string hole.

In one embodiment, during step "(3)", the tool is fluidly connected to a string having a hole and the fluid is pumped through at least part of the hole in the string.

In one embodiment, during step "c", the tool is fluidly connected to a string having a hole and fluid 0 is pumped through at least part of the string hole and fracturing operations are performed.

In one embodiment, during step "(3)", the tool is fluidly connected to a string having a hole and the fluid is pumped through at least a portion of the hole in the string and the fracturing.

In one embodiment, longitudinally locking the sleeve relative to the mandrel shortens an effective movement length of the sleeve from a first movement to a second movement.

In one embodiment, during step "a", the mandrel can rotate freely relative to the sleeve.

In one embodiment, after step "b", the mandrel can rotate freely relative to the sleeve.

In one embodiment, after step "c", the mandrel can rotate freely relative to the sleeve.

To provide completion engineers the flexibility to: (a) using the rotary and oscillating tool while the annular BOP is hermetically sealed in the sleeve and while returning the flow to the seal line or the interruption line (ie, around the annular BOP); or (b) open the annular BOP and continue the return to the underwater riser (ie, through the annular BOP); or (c) open the annular BOP and move the conclusion string with the rotating and oscillating tool attached outside the annular BOP (as the completion engineer wishes to use a jet cleaning tool to blast the BOP stack or perform other operations that require the string of completions to rise to a point beyond where the effective movement capability of the rotating and oscillating tool can absorb the upward movement by means of the sleeve moving longitudinally relative to the mandrel) and, at a later time, hermetically close the annular BOP on the rotary tool sleeve and oscillating (surrounding the upper drive unit).

In another embodiment, the method may comprise the following steps: (a) lowering the rotary and oscillating tool to the annular BOP, the tool comprises a sleeve and a mandrel; (b) after step "a", having the annular BOP close in the sleeve; (c) after step "b", causing relative longitudinal movement between the sleeve and the mandrel; Y (d) after and / or after stage "c", perform the operations in the well.

In various embodiments, the method may include one or more of the following additional steps: (1) after step "c", move the sleeve out of the annular BOP; (2) after step "(1)", move the sleeve inside the annular BOP and have the annular BOP close in the sleeve; (3) after a step "(2)", cause the relative longitudinal movement between the sleeve and the mandrel.

In one embodiment, during stage "a", the cuff is longitudinally locked relative to the mandrel.

In one modality, during stage "c", the operations are performed in the well. In one modality, during the "(3)" stage, the operations are performed in the well. In one embodiment, after step "c", the tool is fluidly connected to a string having a hole and fluid is pumped through the BOP shutter or interruption line into the well and returned through at least a portion of the hole in the string to the platform through a right-angle rotating union fluid diverter.

In one embodiment, after step "(3)", the tool is fluidly connected to a string having a hole and the fluid is pumped through the shutter and / or interruption line of the BOP to the well and returns through at least a portion of the hole in the string to the platform through a right-angle rotating union fluid diverter.

To provide completion engineers the flexibility to: (a) using the rotary and oscillating tool while the annular BOP is hermetically sealed in the sleeve and while the fluid is being pumped through the seal or interruption line (ie, around the annular BOP), and the fluid is returned through at least a portion of the hole in the string to the platform through a right angle rotary joint diverter; or (b) open the annular BOP and continue the return to the underwater riser (ie, through the annular BOP); or (c) open the annular BOP and move the completions string with the rotating and oscillating tool attached outside the annular BOP (such as where the completion engineer wishes to use a jet cleaning tool to blast the BOP stack or perform other operations that require the completion string to rise to a point beyond where the tool's effective movement capability rotary and oscillating can absorb the upward movement by means of the sleeve moving longitudinally relative to the mandrel) and, at a later time, hermetically close the annular BOP in the rotating and oscillating tool sleeve.

The drawings constitute a part of this specification and include exemplary embodiments of the invention, which may be incorporated in various forms.

Brief Description of the Drawings For a better understanding of the nature, objectives and advantages of the present invention, reference should be made to the following detailed description, read in conjunction with the following drawings, where like similar reference numbers indicate similar elements and where: Figure 1 is a schematic diagram showing a deep water drilling platform with the riser pipe and annular anti-bursting device.

Figure 2 is another schematic diagram of a deep water drilling rig showing a rotating and oscillating connection connected in a removable manner to an annular anti-burst device, together with an anti-burst device mounted on the Christmas tree under the annular anti-bursting device .

Figure 3 is a perspective view of an annular anti-burst device conventionally available.

Figure 4 is a sectional view segmented through the annular and waterproof anti-rupture devices of figure 2 with the closed ring seal in the rotating and oscillating rotating union sleeve.

Figure 5 is a schematic view of one embodiment of a mandrel including a plurality of double female end joints connected by means of a plurality of secondary mandrel.

Figure 6 is a perspective view of an embodiment of a rotatable rotary union oscillating with the sectional mandrel having the seals incorporating the male end tip sealing configuration.

Figure 7 is a side view of the rotary and oscillating rotating union of Figure 6 where the sleeve is located in its lower position, and the center of gravity of the rotary union is identified.

Figures 8A, 8B and 8C are perspective views of the rotational and oscillating rotating union of Figure 6 where respectively the sleeve is located in its lower, partial and upper movement position.

Figure 9 is a side view of the sectional mandrel having the seals incorporating the male end tip sealing configuration of Figure 6.

Fig. 10 is a sectional view of the sectional mandrel having the seals incorporating the male end tip sealing configuration of Fig. 6.

Figure 1 1 A is a sectional view of the mandrel of Figure 6 showing the connection joints incorporating the male end tip sealing configuration.

Figure 1 1 B is an enlarged sectional view of the joint of 5 Figure 1 1 A.

Figure 12A is a sectional view of the mandrel of Figure 6 showing a joint of the mandrel having two rod ends and two connection joints incorporating the male end tip sealing configuration Figure 13 is a rear view of a seal for the chuck joints.

Figure 14 is a sectional view of the seal shown in Figure 13.

Figure 15 is an enlarged sectional view of the seal 15 of Figure 14.

Figure 16A is a sectional view of the mandrel of Figure 6 showing the upper connecting gasket incorporating the male end tip sealing configuration.

Figure 17 is a sectional view of the mandrel of Figure 6 20 showing the lower connecting gasket incorporating the male end tip sealing configuration.

Fig. 18 is a sectional view of the mandrel of Fig. 6 showing a double female end connection gasket incorporating the tip tight closure configuration 25 male end of a modality.

Figure 19 is an enlarged view of a circumferential groove for receiving the male end tip sealing configuration of a modality.

Figure 20 is an enlarged view of an end flange for limiting the movement of the slidable seal block of one embodiment.

Fig. 21 is a sectional view of the mandrel of Fig. 6 showing a double female end connection gasket for receiving the male end tip sealing configuration of one embodiment, but with the sliding slipper blocks omitted.

Figure 22 is an end view of the female end connection joints of Figure 21.

Figure 23 is a side sectional view of a slidable seal block.

Figure 24 is an end view of the slidable seal block of Figure 23.

Figure 25 is a sectional view of the joints of the mandrel having two rod ends and two connection joints incorporating the male end tip sealing configuration.

Figure 26 is an enlarged view of one of the rod ends of the mandrel joint of Figure 25.

Figure 27 is a sectional view of the upper mandrel joints of the mandrel shown in Figure 6, with the joint that has a male end seal configuration of one embodiment.

Figure 28 is an enlarged view of one of the rod ends of the mandrel seal of Figure 27.

Fig. 29 is a sectional view of the upper chuck joint of the mandrel shown in Fig. 6, with the seal having a male end sealing configuration of one embodiment.

Figure 30 is an end view of the left side of the mandrel seal of Figure 29.

Figure 31 is an end view of the right side of the mandrel seal of Figure 29.

Figure 32 is an enlarged view of the area showing a pressure release zone between the interstitial space of the inside of the sleeve and the outside of the mandrel.

Figure 33 is a sectional view of the mandrel lower mandrel seal shown in Figure 6, with the seal having a male end seal configuration of one embodiment.

Figure 34 is an enlarged view of one of the rod ends of the seal of Figure 33, which has the sealing of one embodiment.

Figures 35 to 37 show the operation of the coupling conical flanges and the ends for the female and male joints of the mandrel.

Figure 38 shows a male-to-male mandrel joint with the slit in its outer hermetic surface which is connected to two female tubular elements.

Figures 39 to 42 show various embodiments of the male-to-male mandrel joint with the slit in its outer hermetic surface.

Figure 43 is a side view of a sleeve of the mandrel shown in Figure 6.

Figure 44 is a sectional view of the sleeve shown in Figure 43, with the sealing element for the male end removed.

Figure 45 is an enlarged sectional view of one end of the sleeve shown in Figures 43 and 44.

Figures 46 to 51 schematically show the movement and sealing of the mandrel relative to the sleeve where the mandrel has at least a split area in the external hermetic surface of the mandrel.

Figure 52A is a schematic view of the upper engagement portion of the sleeve where the upper seal is hermetically sealed in the outer sealing surface of the mandrel.

Fig. 52B is a schematic view of the upper engagement portion of the sleeve where the upper seal is not hermetically sealed in the outer sealing surface of the mandrel.

Fig. 53A is a sectional view of the lower engagement portion of the sleeve where the lower seal closes hermetically on the outer sealing surface of the mandrel.

Fig. 53B is a sectional view of the lower engagement portion of the sleeve where the lower seal is not hermetically sealed in the outer sealing surface of the mandrel.

Figures 54 to 62 schematically show the steps of increasing the length of movement of the mandrel when it is on a platform.

Detailed description of the invention Detailed descriptions of one or more preferred embodiments are provided herein. It is understandable, however, that the present invention can be incorporated in several ways. Therefore, the specific details disclosed herein, should not be construed as a limitation, but rather as a basis for the claims and as a representative basis for teaching an expert in the art to employ the present invention in any system , representative structure or appropriate form.

During drilling, displacement and / or completion operations it may be desirable to perform operations in the subsoil when the annular seal of a device The annular antieruption is closed in the drill string and the rotation and / or oscillation of the drill string is desired. Such an operation may be a fracture (or fracture) operation where the pressure below the annular seal 71 is increased in an attempt to fracture the formation of the subsoil.

Figures 1 and 2 generally show the preferred embodiment of the apparatus of the present invention, generally referred to as number 10. Drilling apparatus 10 employs a drilling platform S which may be a floating platform, spar, semi-submersible or other suitable platform for the drilling of oil and gas wells in a deepwater environment. For example, the well drilling apparatus 10 of Figures 1 and 2 and the related method can be employed in deep water, eg, deeper than 5,000 feet (1,500 meters), 6,000 feet (1,800 meters), 7,000 feet (2, 100 meters), 10,000 feet (3,000 meters), or deeper.

In Figures 1 and 2, an ocean floor or a seabed 87 is shown. Wellhead 88 is shown on seabed 87. One or more anti-burst devices including stack 75 and annular anti-burst device 70 can be provided. The oil and gas well drilling platform S, therefore, can provide a floating structure S having a platform floor F supporting a derrick and other known equipment used for the drilling of oil and gas wells. The floating structure S is provided as a source of drilling fluid or drilling mud 22 contained in the mud pit MP. The equipment that can be used to recirculate and treat the drilling mud may include, for example, a mud pit MP, vibrating screen SS, separator or mud splitter MB and multiple shutter CM.

An example of a drilling rig and various drilling components are shown in Figure 1 of American Patent No. 6,263,982 (the patent of which is incorporated herein by reference). In Figures 1 and 2 the conventional sliding or telescopic joint SJ, comprising an outer cylinder OB and an inner cylinder IB with a pressure seal between them can be used to compensate for relative vertical movement or traction between the floating platform S and the fixed underwater riser pipe R. A diverter D can be connected between the inner cylinder IB of the sliding joint SJ and the floating structure or platform S to control the accumulations of gas in the rising pipe R or 20 the low pressure forming gas from the ventilation to the platform floor F. A spherical joint BJ between the diverter of the D and the riser pipe R can compensate for another relative movement (horizontal and rotary) or the inclination and the bearing of the floating structure S and the riser pipe R (that 25 is usually fixed).

The diverter D may use a diverter line DL to communicate the fluid or drilling mud from the riser pipe R to a sealing manifold CM, vibrating screen SS or other device for receiving drilling fluid or drilling mud. Previously, diverter D may be the RF flow line that can be configured to communicate with a mud pit MP. A conventional flexible sealing line CL can be configured to communicate with the shutter manifold CM. Drilling fluid or slurry may flow from manifold CM to a mud and gas separator or divider M B and a burn line (not shown). The drilling fluid or slurry can then be discharged to a vibrating screen SS and to the mud pits MP. In addition to a shutter line CL and interrupter line KL, a magnifying line BL can be used.

Fig. 2 is an enlarged view of the drill string or work string 85 extending between the platform 10 and the seabed 87 having the well mouth 88. In Fig. 2, the drill string or the work string 85 is divided into a drill or upper work string and a lower drilling or work string. The upper string is contained in the riser 80 and extends between the well drilling platform S and the rotary union 100. An upper volumetric section 90 is provided within the riser 80 and between the drilling rig 10 and the joint rotating 100. A lower volumetric section 92 is provided between the wellhead 88 and the rotary union 100. The upper and lower volumetric section 90, 92 are more specifically separated by means of the annular hermetic unit 71 which forms a seal against the sleeve 300 of the rotating union 100. The annular anti-collapse device 70 is placed at the bottom of riser 80 and above chimney 75. A wellhead 40 extends downwardly from wellhead 88 and seabed 87. Although shown in the figure 2, in many of the figures the conclusion string or bottom perforation 85 has been omitted for clarity.

Figures 1 and 2 are schematic views showing the oil and gas well drilling platform 10 connected to riser 80 and having annular anti-burst device 70 (commercially available). Figure 2 is a schematic view showing the platform 10 with the separation of the rotary union 100. The rotary union 100 is shown removably connected to the annular anti-burst device 70 through the sealing of the annular packaging unit 71.

Figure 4 includes a schematic diagram of one embodiment of a rotating union tool 100 that can rotate and / or move and / or oscillate. With such construction, the drill string or well 85 can rotate and / or move and / or oscillate while the annular anti-burst device 70 is sealed 5 around the sleeve or housing 300 of the rotating union tool 100. Figure 3 is a drawing of the exterior of the annular anti-burst device 70.

The mandrel 1 10 is contained within a hole in the sleeve 300. The rotary union 100 includes a sleeve or an outer housing 300 having a generally oriented, open-ended orifice that is occupied by the mandrel 1 10. The sleeve 300 provides the latch, the flange or the upper projection 326 and the flange or the lower projection 328.

Figure 6 is a perspective view of one embodiment of a rotating union tool 100 having a rotary and oscillating sleeve 300 with the sectional mandrel 1 10 having the seals incorporating the male end tip seal configuration. Generally, the length of movement (relative longitudinal displacement between the mandrel 15 1 10 and the sleeve 300) is equal to the length of the mandrel 1 10 (Lm) minus the length of the sleeve (Ls).

Figure 7 is a side view of the rotary and oscillating rotating union 100 where the sleeve 300 is located in its lower (and secured) position, and the center of gravity of the rotating union 100 is identified. In this embodiment, it is not they show the slits of the hermetic area (for example, 706, 906, etc.). Figures 8A, 8B and 8C are perspective views of the rotary and oscillating rotating union tool 100 where respectively the sleeve 300 is located in its lower position 25 (figure 8A), partial movement (figure 8B) and upper (figure 8C).

Without the slits of the external sealing areas, the total length of the mandrel 1 10 may be limited to the height of the derrick of the platform because the mandrel 1 10 will preferably be constituted in the tent, since the constitution in the field will probably scrape and / or damage the tight areas of mandrel 1 10.

Figure 9 is a side view of the formed mandrel 1 10 having the seals incorporating the male end tip sealing configuration of Figure 6; Figure 10 is a sectional view of mandrel 1 10 having the seals incorporating an internal diameter hermetic seal as will be described later. The mandrel 1 10 can be composed of the joints 500, 600, 700, 800, 900, 1000 and 1 100. Depending on the desired length of movement of the mandrel 1 10, the additional joints of the mandrel can be used.

Figure 12 is a sectional view of mandrel 1 10 showing the joints 600,700,800 of mandrel 1 10 having two rod ends (gasket 700) and two connection gaskets (600,800) incorporating male-to-male connections, and including the hermetic insert 1500 having an annular groove 1540 for sealing 750. Figure 1 1 A is a sectional view of a joint of the mandrel 1 10 incorporating the hermetic internal diameter configuration using the seal 750 that is contained in the Annular coupling slits 728 (from board 700) and 1540 (board 600). Figure 1 1 B is an enlarged sectional view of the joint of Figure 1 1 A.

Figure 13 is an end view of a seal 750 or 760 which can use the annular coupling grooves 728 (of mandrel joint 700) and 1540 (of the mandrel joint 600). Figure 14 is a sectional view of the seal 750. Figure 15 is an enlarged sectional view of the seal 750. The first seal 750 may comprise the first end 752, the flared area of the first seal 753, the second end first sealing 755, the conical area of the first seal 756 and the vertical area of the first seal 757. The conical areas 756.756 'can be used to assist the second end 755 of the seal 750 to enter the slot 1540 of the insert 1500 when the gasket 700 is threaded in the gasket 600. The gasket 750 can have an internal hermetic diameter 770 and an external hermetic diameter 774 (which are defined by means of the vertical walls 757).

Figure 16A is a sectional view of the mandrel 1 10 showing the upper connection seal (the gasket 600 threaded in the joint 500) incorporating the male end tip sealing configuration. The seal 550 may be of a construction similar to the seal 750 shown in FIG. 13. The flange 570 may limit the length of movement of the mandrel 1 10 relative to the sleeve 300 when the hook 326 comes into contact with the flange 570.

Figure 17 is a sectional view of the mandrel 1 10 showing the upper connecting gasket (gasket 1000 threaded in the gasket 1 100) incorporating the male end tip sealing configuration. The seal 150 may be of a construction similar to the seal 750 shown in FIG. 13. The flange 570 may limit the length of movement of the mandrel 1 10 relative to the sleeve 300 when the locking flange 1200 limits movement additional hook 328.

Figure 18 is a sectional view of a female-to-female-type gasket 600 of the mandrel 100 showing a double female end connection gasket receiving the male end tip sealing configuration of one embodiment. Figure 19 is an enlarged view of a circumferential groove 1540 'for receiving the seal (e.g., the seal 750 shown in Figures 1 and 12). Fig. 20 is an enlarged view (detail A) of an end flange 660 for limiting the movement of the slidable seal block 1500 of one embodiment.

Figure 21 is a sectional view of the gasket 600, but with the watertight sliding blocks 1500, 1500 'omitted. Figure 22 is an end view of the double female end connection gasket 600.

Figure 23 is a side sectional view of a block of slip-tight seal 1500. Figure 24 is an end view of the slidable seal block 1500. At the first end 1520, the sealing block 1500 can include the annular groove 1540, which itself can include the conical walls 1546 and the vertical section 1 544. The conical walls 1546 may be constructed to match and / or cooperate with the conical areas of the seal (such as the conical area 756 of the seal 750). The annular groove 1540 may have a nominal diameter 1550, with the outer diameter of 1552 and the inner diameter 1554 created by means of the vertical walls 1544. The insert 1500 may include an axial passage 1510 having at least a transition portion 1534 to change from the axial passages of greater diameter of the female to female joints (for example, 600, 800, 1000 and so on) to the axial passages of smaller diameter of the joints male to male (for example, 700, 900, etc.).

Figure 25 is a sectional view of the gasket 700 of the mandrel 1 10 having two male ends 720,730 and two connection joints incorporating the male end tip sealing configuration (the slits 728 and 738 respectively holding the first closure hermetic 750 and the second hermetic seal 760). Figure 26 is an enlarged view of the threads 722 of one end 720 of the double male end mandrel gasket 700.

Figure 26 is an enlarged view of one end 720 of mandrel seal rod 700 with the sealed seal 750 inserted in the annular groove 728. The seal 750 can be as described above and is attached to the annular groove 728. The seal 700 can include the axial passage. 710 (with the diameter 712) and the first threads 722 (in the upper end connection 720) with the second threads 732 (in the lower end connection 730). The annular groove 728 can include the enlarged area 729 which cooperates with and holds the enlarged area 753 of the seal 750. The annular groove 738 can be constructed in a similar manner with enlarged area 739.

It should be noted that, when the gasket 700 is threaded in the seals 600 and 800, both seals 750 and 760 of the gasket 700 will remain exterior to the projected cross section 15 of the axial passage 710 with the diameter 712, but inwardly to the cross section projected from the axial passage 610 with the diameter 612 and the axial passage 810 with the diameter of 812.

Figure 27 is a sectional view of the upper mandrel seal 500 of the mandrel 1 10 with the joint 500 having a male end 530 incorporating a seal 550 (which may be of the same configuration as the above-described seal 75). ). The joint 500 may include the flange 533 to limit longitudinal movement between the sleeve 300 and the mandrel 1 10. Figure 28 is an enlarged view of one of the male end 530. The annular groove 538 may include the area enlarged 539 for clamping the seal 550 in place. The second end 520 may include a female connection that can be attached to additional string joints unrelated to the mandrel.

Fig. 29 is a sectional view of the lower mandrel seal 100 of the mandrel 1 10, with the seal having a male end seal configuration (at the end 120) (which hermetic seal 150 can be of the Same construction as the above-described seal 75) Figure 30 is an end view of the left side of the seal 1 100. Figure 31 is an end view of the right side of the seal 1 100. Figure 32 is an enlarged view of the area showing a pressure relief area 1400 for decreasing and / or releasing the pressure between the interstitial space inside the sleeve 300 and the outside of the mandrel 1 10 (when the sleeve 300 is in the lower condition and fast locking) ). Figure 33 is a sectional view of the lower chuck seal 1 100. The seal 1 150 at the end 1 120 and placed in the slit 1 128 (which is held by the enlarged area 1 129 0 cooperating with the enlarged area 1 153 of the seal 1 150) can be used for sealing between the joint 1 100 and the female connection seal 1000. Figure 34 is an enlarged view of one end 1 120 of the seal 1 100.

Mandrel joints including conical elements for 5 to prevent widening of the female end connection Figures 35 to 37 show three sequential steps forming a connection between a female end (the end 630 of the mandrel gasket 600 to the end 720 of the chuck gasket 700).

For reasons of clarity, the insert 1500 and the seal 750 have been omitted from these drawings. The arrow 670 indicates schematically that the joints 600 and 700 are mutually connected in a threaded manner by rotation. Since the tapered flange 721 becomes close to the tapered end 621 of the end 630 of the seal 600, the conical elements 721, 621 will tend to cause the edges of the seal 600 to compress toward the axial passage 610 and not allow the ends of the seal 600 expand outwardly from the axial passage 610 when the seals 600, 700 are subjected to greater torsional stresses.

The resistance to widening of the female end connections maintains the outer sealed surface 601 of the gasket 600 flush with the outer sealing surface 701 of the gasket 700. Such flush and / or smoothness and / or leveling between the outer sealing airtight surfaces (701 and 601, and by analogy the outer sealing surfaces of other contiguous joints of the mandrel 1 10), facilitates a proper seal between the sleeve 300 and the mandrel 1 10, together with a longer seal life of the sealed units 370 , 380 of sleeve 300.

In different modalities, the coupling flanges can have a conical portion with a conicity at approximately 1, 2, 3, 4, 5, 6, 6.25, 7, 8, 9, 10, 12, 13, 14, 15 and 20 degrees from a line perpendicular to the center line longitudinal of a board. In various embodiments, the conical elements 5 may be within a range of between any two of the specified degrees. The conical elements may have the same magnitude but conical elements or opposite slopes.

Figures 38 to 42 show various embodiments of the male-to-male mandrel seal with the slit in its outer hermetic surface.

Figure 38 shows the seals 600, 700 and 800 joined with the outer sealing surfaces 601, 701 and 801. The gasket 700 includes the slit 706 in its outer hermetic surface 701. i5 Slit 706 may include upper transition area 740 and lower transition area 746.

The transition areas may include the soft transition inserts 742 and 748 as will be described later. 0 Although the inserts 1500, 1500, 1500"and 1 500"', the 750 and 760 interior seals have been omitted for clarity (but are intended for use as shown in other embodiments with the inner seal).

In addition, a single-piece male-to-male mandrel gasket 700 is shown in Figures 38 and 55, however, it is it contemplates that the male-to-male secondary joint may be two pieces (as shown in Figures 54 to 62 where the mandrel joint 700 is composed of the joint 700 'having the slit 706 and being a female-to-male joint in combination with the gasket 700"which is a male-to-male gasket in combination with a male-to-male gasket with the groove 706).

Figures 39 to 42 show the male to male mandrel gasket 700 with the slit 706. The slit 706 may include the upper transition area 740 and the lower transition area 746. The transition areas may include the soft transition inserts 742 and 748. The gasket 700 may include the conical flanges 723 and 733 as described in other embodiments.

Figure 43 is a side view of a sleeve 300. Figure 44 is a sectional view of the sleeve 300, with the sealing elements removed from their ends. Figure 45 is an enlarged sectional view (detail A) of one end of the sleeve 300.

Mandrel that can be cut by the anti-surge device regardless of the vertical position of the mandrel Wall thickness 604, 804, 1004, etc. of the female end joints 600, 800, 1000, etc. will be such that the walls can be cut by means of one of the rams 2010, 2020, 2030 and 2040 of the plurality of devices anti-surge water stack 2000.

The preferred wall thickness for 604, 804, 1004, etcetera can be selected from the set of thicknesses in inches less than 1, 15/16, 7/8, 13/16, 3/4, 1 1/16, 10/16, 9/16, 8/16, 7/16, 6/16, 5/16, 4/16, 3/16, and 1/4 (2.5-0.63 cm). In various embodiments, the wall thickness may be between any two of the specified thicknesses.

In one embodiment, the spacing between the double male link sleeves 700, 900, etc. is such that at any time, only one such link sleeve 700, 900, and / or another double male link sleeve can be aligned with a ram. of a plurality of anti-surge devices stacked.

Figure 4 is a segmented sectional view through the annular anti-burst devices 70 and the ram 2040 with the annular seal 71 closed in the sleeve of the rotary and oscillating rotary union 100. The mandrel 1 10 comprising the mandrel gaskets 600 , 800, 1000 connected together by means of the double male link sleeves 700, 900, is also shown schematically in Figure 4.

In figure 4 the separation between L2 between the link sleeves 700 and 800 is schematically shown in such a way that at any time, only one of such link sleeves 700 or 900 can be aligned with a ram of an anti-surge device 2000. The plurality of devices anti-eruption 2000 stacked ram may include the rams 2010, 2020, 2030 and 2040. The distance 2050 is between the rams 2010 and 2020. The distance 2052 is between the rams 2010 and 2030. The distance 2054 is between the rams 2030 and 2040. The distance 2056 is between the rams 2020 and 2040. The distance 2058 is between the rams 2020 and 2030.

In this mode none of the distances 2050, 2052, 2054, 2056 and / or 2058 can be located within the range of: Lj +/- (L4 + L6) (as shown in figures 4 and 5). In this way it is not possible for more than one battering ram (2010, 2020, 2030 and / or 2040) can be seated in a double male link sleeve 700, 900, etc., regardless of the amount of longitudinal movement oscillation of the mandrel 1 10 relative to the sleeve 300, or the longitudinal position of the mandrel 1 10. in relation to the anti-surge device of the ram 2000 (assuming that the sleeve 300 is not placed in the anti-surge device of the ram 2000).

In one embodiment, the length of any double female end joint 600, 800, 1000 and so on is greater than at least about 4 feet (1.2 m). In other embodiments, the length is greater than at least about 5, 6, 7, 8, 9, 10, 12, 14, 15, 16, 18, 20, 25, 30, 35 and 40 feet (12.1 -1. 5m). In other embodiments, the length is between any two of the previously specified lengths.

Wall thickness 604, 804, 1004, etc. of joints of female end 600, 800, 100, etc. will be such that the walls can be cut by one of the rams 2010, 2020, 2030 and / or 2040 of the anti-surge device of ram 2000.

The rotating unit 100 can be composed of the mandrel 1 10 and the sleeve or housing 300. The sleeve or housing 300 can be connected in a rotating, movable and / or oscillating and / or hermetic manner to the mandrel 1 10. Accordingly, when the mandrel 10 rotates and / or oscillates the sleeve or housing 300 may remain motionless for an observer in terms of rotation and / or oscillation. The sleeve or housing 300 can be adjusted on the mandrel 1 10 and can be connected in a rotatable, oscillating and hermetic manner to the mandrel 1 10.

The sleeve or housing 300 may be rotatably connected to the mandrel 10 by means of one or more bushings and / or bearings located preferably at the opposite longitudinal ends of the sleeve or housing 300.

The sleeve or housing 300 can be sealedly connected to the mandrel 10 by means of one or more seals (eg, packaging units 370 and 380) or preferably separate and located at the opposite longitudinal ends of the sleeve or housing 300. The seals can seal the gap 315 between the interior 310 of the sleeve or housing 300 and the outside of the mandrel 1 10. 5 The sleeve or housing 300 can be connected from oscillating manner with the mandrel 1 10 through the geometry of the mandrel 1 10 which can allow the sleeve or housing 300 to slide relative to the mandrel 1 10 in a longitudinal direction (such as by having a longitudinally extended distance HT of the outer surface of the mandrel 1 10 to a substantially constant diameter).

The rotating union 100 can be formed by the mandrel 1 10 to fit in the line of a drill string or working 85 and the sleeve or housing 300 with a seal and the support system to allow the drill string or work string 85 rotate and oscillate in the rotating union 100 where the annular seal unit 71 is closed in the sleeve 300. This can be achieved by placing the rotary union 100 in the annular anti-burst device 70 where the annular seal unit 71 can be closed around the sleeve or housing 300 forming a seal between the sleeve or housing 300 and the annular seal unit 71.

The amount of oscillation (or movement) can be controlled by the difference between the height HT of the mandrel 1 10 and the length Ls of the sleeve or housing 300.

As shown in Figure 6, the movement of the rotating union 100 can be the difference between the height HT of the mandrel 1 10, and the length 350 of the sleeve or housing 300.

Figures 7 and 8 show a sectional view through the sleeve 300 and the mandrel 1 10. In one embodiment, the units hermetic 370 and 380 can be the two bidirectional hermetic closures. One of the advantages of using two sets of sealed units 370 and 380, where each seal is in opposite longitudinal directions, is that the sleeve 300 and the mandrel 1 10, even where one or more of the double male link sleeves (e.g. , 700, 900, etc.) with its split portion (eg, 706, 906, etc.) is passing through the hermetic unit, the separate hermetic unit can still seal tightly against the fluid flow. This airtight backing capacity helps maintain the seal during vertical movement of the mandrel 1 10 relative to the sleeve 300.

Maintain the hermetic seal between the mandrel and the sleeve during rotation and / or movement and / or oscillation where the mandrel includes one or more creased areas in its outer hermetic surface Figures 46 to 51 illustrate schematically the movement and / or oscillating movement of the sleeve or housing 300 relative to the mandrel 1 10. In this embodiment, the mandrel 1 10 may have one or more slit areas (eg, 706, 906, etc.) on their outer hermetic surfaces (eg, 601, 701, 801, 901, 1001, etc.) but still maintain a hermetic seal between the sleeve and / or the housing 300 and the mandrel 1 10.

The seal remains in spite of the sleeve 300 (and one of the hermetic units) passing over one of the slit areas in the external hermetic surface of the mandrel 10 by means of the remaining separate hermetic unit which still maintains a hermetic seal between the sleeve 300 and the mandrel 5 1 10. In this In this embodiment, the sleeve 300 includes the separate hermetic units 370, 380 located respectively under the hooks 326, 328.

In these figures, the arrows 3000, 3001, 3002, 3003, 3004 and 3005 schematically indicate the downward movement of the mandrel 1 10 relative to the sleeve 300. In addition, the arrows 3010, 301 1, 3012, 3013, 3014 and 3015 schematically indicate the upward movement of the mandrel 1 10 relative to the sleeve 300.

The height Lm of the mandrel 1 10 as compared to the total length Ls 350 of the sleeve or housing 300 can be configured to allow the sleeve or housing 300 to move and / or oscillate (e.g., slide up and down. ) relative to the mandrel 1 10. Figures 46 to 51 are schematic dims illustrating the movement and / or oscillation 0 and / or rotation between the sleeve or the housing 300 along the mandrel 1 10 (which allows oscillation and / or the rotation between the drill string or work 85 when the seal 71 of the annular anti-bursting device 70 is hermetically sealed in the sleeve 300, and the drill string or workpiece 85, thereby sealing the hole from above- with the sleeve that is closed in the annular anti-rupture device shown in figure 2).

In figures 46 to 51 (in that order) with the arrows 3000, 3001, 3002, 3003, 3004 and 3005 schematically indicate a downward movement of the mandrel 1 10 relative to the sleeve 300 in the direction of the arrow 3000. In the figures 46 to 51 (in the reverse order of Figure 51 to Figure 46) where the arrows 3010, 301 1, 3012, 3013, 3014 and 3015 schematically indicate an upward movement of the mandrel 1 10 relative to the sleeve 300. During the movement of the mandrel 1 10 relative to the sleeve 300, the packaging units 370 and 380 maintain a seal between the sleeve 300 and the mandrel 1 10, while the annular seal 71 maintains a hermetic seal in the sleeve 300 to thereby close hermetically the well 40.

In Figures 46 and 47, the arrows 3000, 3001 schematically indicate that mandrel 1 10 moves downward relative to the sleeve or housing 300, where a double male link sleeve 900 is located above the level of the upper latch 326 ( and the upper packing unit 370) of the sleeve 300. Although the upper packing unit 370 can not maintain a seal when the double male link sleeve 900 passes through (e.g., the split area 906 causing a break in the closure tight between the packaging unit 370 and the connecting sleeve 900 as shown in Fig. 52B), the lower packaging unit 380 (in the lower latch 328) maintains a seal between the sleeve 300 and the mandrel 1 10 (as shown in Fig. 53A), while the annular seal 71 of the annular anti-rupture device 70 maintains a hermetic seal in the sleeve 300 in order to thereby seal the well 40.

In Figure 48, the arrow 3002 schematically indicates that the mandrel 1 continues the downward movement relative to the sleeve or housing 300., wherein a double male link sleeve 900 (and the slit 906) is located between the upper latch 321 (and the upper packing unit 370) and the lower latch 328 (and the lower packing unit 380). Now both packing units 370 and 380 maintain a seal between the sleeve 300 and the mandrel 1 10 (as shown in FIGS. 52 and 53A), while the annular seal 71 maintains a seal on the sleeve 300 for sealing. so close the well 40 hermetically.

In Figure 49, the arrow 3003 schematically indicates that mandrel 1 continues the downward movement relative to the sleeve or housing 328 where now a double male link sleeve 900 is located above the level of the upper latch 300 (and the lower packing 380) of the sleeve 300. Although the packaging unit 380 can not maintain a seal when the slit 906 of the double link sleeve 906 passes through (e.g. the split area 906 causes a break in the closure as shown in Fig. 53B), the lower packing unit 370 maintains a seal between the sleeve 300 and the mandrel 1 10 (as shown in Fig. 52A), while the annular seal 71 maintains a seal on the sleeve 300 to thereby seal the well 40.

Figures 50 and 51 schematically indicate the continuous downward movement of the mandrel 1 10 through the sleeve or housing where the next split joint (double male link sleeve 700 with the split area 706> will pass through the sleeve 300. The units separate seal aids 370 and 380 will jointly or individually hold a seal between the sleeve 300 and the mandrel 1 10 when one of these sealed units passes over the split area (similar to that described in Figures 46 to 49 with respect to the seal 900 and the slit 906. In Figure 50, both packing units 370 and 380 maintain a seal between the sleeve 300 and the mandrel 1 10 (as shown in Figures 52A and 53A), while the closure ring seal 71 maintains a seal on the sleeve 300 to thereby seal the well 40. In Figure 51, although the packaging unit 370, it can not maintain a seal. When the double male link sleeve 700 passes through (for example, the split area 706 causes a break in the seal as shown in Figure 52B), the package 380 maintains a seal between the sleeve 300 and the mandrel 1 10 (as shown in Figure 53A), while the annular seal 71 maintains a seal on the sleeve 300 to thereby seal the well 40.

On the other hand, a movement of upward movement of the mandrel 1 10 through the sleeve 300 is indicated schematically by the arrows 3015, 3014, 3013, 3012, 301 1 and 3010 in the reverse order of figures 51 to 46.

In the above-described manner, a seal can be maintained between the mandrel 10 and the sleeve 300 despite several slits in the sealing area of the mandrel 10 that the sleeve 300 undergoes during the movement and / or oscillating movement of the mandrel 1. in relation to the sleeve 300.

Adjusting the length of movement of the mandrel - The double male end mandrel can be of different heights which can be assembled on the platform Figure 5 shows a rotating union tool 100 with the mandrel 1 10 and the sleeve 300. Figure 5 is a schematic view of one embodiment of a mandrel 1 10 including a plurality of double female end joints (600, 800 , 1000) connected by means of a plurality of double male end link sleeves (700, 900).

The total movement height HT of the double female mandrel 1 10 can be equal to the sum of the lengths of the joints and the connecting sleeves they form. In this case the total height HT of mandrel 1 10 is equivalent to L + L2 + L3 + L4 and L6. To change the total height HT (either larger or smaller) different numbers of 5 mandrel joints 600, 800, 1000 can be used to assemble the mandrel 1 10. Another way to change the total height HT of the mandrel 1 10 is to use the joints of mandrel 600, 800, 1000 of different lengths.

The double female joint 600 may be of a length L i, and may include the longitudinal passage with a female connection at its upper end 620 together with the female connection at its lower end 630.

The double female joint 800 may be of a length L2, and may include the longitudinal passage with a female connection at its upper end 820 together with the female connection 850 at its lower end 830.

The double female end joint 1000 may be of a length L3, and may include the longitudinal passage 1010 (not shown) with a female connection at its upper end 1020 0 together with the female connection at its lower end 1030.

The double male link sleeve 700 may comprise the lower end 720, the upper end 730 together with the longitudinal passage 710. The link sleeve 700 may also include the upper rim 723, the lower rim 733 and the split area 5 706.

The split area 706 can be used to support the mandrel 1 10 after the joints 600, 800, 1000, etc. have been connected together by assembling the mandrel 1 10. The support mandrel 1 10 using one of the mandrel's creased areas without holding the sealing surfaces of the joints 600, 800, 1000, etc. so that the supports prevent such surfaces from scratching and / or damaging thereby causing problems or failure of a seal between the mandrel 1 10 and the sleeve 300 (it is say, the hermetic seal with the hermetic units 370 or 380). In addition, the support mandrel 1 10 using one of the split areas in the double link sleeves, where these link sleeves are damaged, allows the replacement of the link sleeves 700, 900, etc., while protecting (and preventing the requirement of replacement) the parts of the double female end mandrel gasket 600, 800, 1000, et cetera.

The female connection of the lower end 630 for the joint 600 can be connected in a threaded manner to the upper end 710 of the double link sleeve 700. The female connection of the upper end 820 for the chuck joint 800 can be connected in a threaded manner to the lower end 730 of the double link sleeve 700.

Figure 5 is a sectional view and schematic of the connections between three double female end joints 600, 800, 1000 and two double male end link sleeves 700, 900. Here the mandrel joints 600, 800 and 1000 are connected using the double male end link sleeves 700 and 900.

The double male link sleeve 900 may comprise the lower end 920, the upper end 930 together with the longitudinal passage 910. The link sleeve 900 may also include the upper flange 923, the lower flange 933, and the split area 906.

The female connection as well as the lower end 630 of the joint 600 can be connected in a threaded manner to the upper end 720 of the double male link sleeve 700. The female connection of the upper end 820 of the mandrel joint 800 can be connected in a threaded with the lower end 730 of the double male link sleeve 700.

The female connection of the lower end 830 of the seal 800 15 can be connected in a threaded manner to the upper end 910 of the double link sleeve 900. The female connection of the upper end 1020 of the chuck joint 1000 can be connected in a threaded manner to the lower end 930 of the double link sleeve 900 male.

Now, the split areas 706, or 906 can be used to support the assembly of the mandrel 1 10 after the joints 600, 800, 1000, etc. have been connected together by assembling the mandrel 1 10. The support mandrel 1 10 in the creased areas 706,906 (ie the non-watertight areas) without attaching on the sealed surfaces of the joints 600, 800, 1000, etc. it prevents such surfaces from being scratched or damaged thereby causing problems or failure of a seal between the mandrel 10 and the sleeve 300 (ie, the seal with the sealed units 370 or 380).

In one embodiment, the mandrel 1 10 of the rotary union tool 100 can at least partially be elongated while disconnecting from the subfloor.

Figures 54 to 62 show several steps for adjusting the length of movement of the mandrel 1 10 while on the platform. These are the schematic figures where in all cases the length of movement of the mandrel 1 10 is seen as substantially straight in the longitudinal direction although the schematic figures may have copied errors that seem to indicate a partially folded mandrel 1 10.

In one embodiment, there is provided a method for determining the length of movement of a rotary and oscillating rotating union tool 100 in a rig or drilling platform having a floor, comprising the steps of: (a) provide a rotary union tool 100, the rotary union tool 100 comprises a mandrel 1 10 and a sleeve 300, the mandrel 1 10 is rotatable and oscillating relative to the sleeve and / or the housing 300, the mandrel 1 10 has a first length of movement relative to the sleeve and / or housing (shown in Figure 54); (b) support in a substantially vertical direction the rotary attachment tool 100 on platform 10 (shown in Figure 54 where tool 100 is supported by platform lifts on the platform floor using the split a906); (c) adding a chuck joint to the upper part of the mandrel 1 10, such additional joint inces the length of movement of the mandrel 1 10 relative to the first movement length (shown in figure 55 where the chuck joint is selected of a plurality of mandrel joints as shown in Figure 56 - the assembled mandrel 1 10 'is shown in Figure 57); (d) lowering the rotary union tool and again supporting in a vertical direction the rotary union tool in a substantially vertical direction on the platform (schematically shown between figures 54 and 57 with the down arrow and, in figure 57 the mandrel 1 10 'is supported by the elevator using the slit 706); Y (e) repeating the step up to steps "c" and "d", until the final movement length of the mandrel 1 10 relative to the sleeve and / or the housing is at least 10 feet (30.4 cm).

In various embodiments, the steps "c" and "d" may be repeated until the final movement length may be ger than 100, 150, 200, 250, 300, 350, 400, 450, 500, 550, 600, 700, 800, 900, 1000, 1200, 1400, 1500, 1600, 1800 and 2000 feet (30.4-609.6 m), or any length of movement is between any of the two specified lengths of movement.

In various embodiments, a plurality of mandrel joints include the split a (e.g., 706, 906, etc.) on the outer hermetic surface, and during step "c", one of these split a is used to support the tool. rotating union in a substantially vertical direction.

In one embodiment, the plurality of split a may include the soft material transition sections.

In various modalities, the upper portions of the split a may be frustroconical.

In various modalities, the upper portions of the split a may be conical.

A method comprises a method for incing the length of movement of the mandrel while it is located on the equipment or the platform.

Well fracturing In one embodiment, the rotary union tool 100 can be used in a well fracturing process. "Hydraulic fracturing," sometimes simply referred to as "fracturing," is a common stimulus tment. A tment fluid for this purpose is sometimes referred to as a "fracturing fluid." Fracking fluid is pumped at a high flow rate and high pressure in the well. and outside of training. The pumping of the fracturing fluid is at a high flow rate and pressure that is much faster and ger than the liquid can not be filtered through the permeability of the formation. Thus, the high flow and pressure ce or improve a fracture in the underground formation.

Creating a fracture means producing a new fracture in the formation. Improving a fracture means expanding an existing fracture in the formation.

For pumping in hydraulic fracturing, a "fracture" pump is used, which is a high-pressure, high-volume pump. Commonly, a fracture pump is a positive displacement oscillating pump. These pumps are generally capable of pumping a wide range of fluid types, which include corrosive fluids, abrasive fluids and mixtures that contain relatively large particles, such as sand. Using a fracture pump, the fracturing fluid can be pumped into the well at high velocities and pressures, for example, at a rate greater than 100 barrels per minute (3, 100 gallons per minute) at a pressure greater than 5,000 pounds per inch. square ("psi") (34.47 MPa). The pumping speed and the pressure of the fracturing fluid may be even higher, for example, pressures above 10,000 psi (68.95 M Pa) are common.

To fracture an underground formation commonly hundreds of thousands of gallons (liters) of fluid are required fracturing. In addition, it is often desirable to fracture in more than one subsoil location. For various reasons, including the high volumes of fracturing fluid required, with expedited availability, and historically economic, the fracturing fluid is generally water or water based. Therefore, fracturing a well may require millions of gallons (liters) of water.

When the formation fractures or an existing fracture is improved, the fracturing fluid suddenly has a fluid flow path through the crack to flow more rapidly away from the well. As soon as the fracture is created or improved, the sudden increase in fluid flow away from the well reduces the pressure in the well. Thus, the creation or improvement of a fracture in the formation is indicated by a sudden decrease in fluid pressure, which can be observed at the wellhead.

After it is created, the newly created fracture will tend to close after the pumping of the fracturing fluid stops. To prevent the fracture from closing, a material must be placed in the fracture to keep the fracture open propped up. This material is generally in the form of an insoluble particulate material, which can be suspended in the fracturing fluid, which is present in the subsoil, and is deposited in the fracture. The particulate material keeps the fracture open while still allowing fluid flow through the permeability of the particulate material. A particulate material used for this purpose is often referred to as a "suspending agent". When deposited in the fracture, the support agent forms a "supporting agent pack" and, while keeping the fracture separate, provides the channels through which the fluids can flow into the well. For this purpose, the particles are usually selected based on two characteristics: size range and resistance.

During well fracturing operations, the annular anti-rupture device 70 is closed to maintain pressure while performing fracturing operations. However, during fracturing operations the tubing string and / or tubing and / or perforation 85 moves longitudinally and / or rotates relative to the closed annular anti-rupture device 70.

However, this vertical movement creates a problem with the extreme frictional traction involved with closing the annular anti-burst device 70 with the rubber sealing element 71 in the drill pipe 85. The reason this is a problem is that during fracturing the well, the drill pipe 85 must be pulled up through the closed seal 71, which tends to damage the annular seal 71. Damage risks increase where tool joints (ie, portions of the string with larger diameters) are removed through the seal ring closed 71.

In one embodiment, for a fracturing job, the number of zones and the lengths of each zone can be identified in order to determine the amount of movement length 5 necessary for a fracturing job. In this embodiment, the rotary union tool 100 can be used in the string 85 where the annular anti-burst device 70 is closed in the sleeve 300. In this embodiment, the length of the mandrel 10 required to achieve the required length of movement can be calculated. for the total travel of the zones of formation between the sleeve 300 and the mandrel 1 10.

For a long time there has been an unattended need to have a rotary union tool 100 that includes a mandrel 1 10 that can be adapted to a desired length 15 on the platform 10 to accommodate fracturing operations. For a long time there has been an unattended need to have a rotary attachment tool 100 that includes a mandrel 1 10 that can be cut relative to a plurality of anti-surge devices of the stacked ram type 0 2000 regardless of the position of the mandrel 1 10 with relation to the anti-surge device stack of ram 2000 type.

In one embodiment, the mandrel 1 10 can be configured for a predetermined length outside the site of the well 10 which will fracture to the length required to reach the calculated movement length, and then the mandrel 1 10 is transported to Platform 10 In one embodiment, the mandrel 1 10 can be assembled locally on the platform 10, during disconnection in the process, at a predetermined selected length of movement for the well that will fracture to achieve the calculated calculated required length of movement.

Example of fracturing work If the movement length of 1, 000 ft (304.8 m) is calculated as required for a job to cover the estimated areas, the actual travel length of the mandrel 1 10 may include a factor of 50% safety for the length of movement causing the nominal movement length to be 1, 500 feet (457.2 m). This safety factor can be used to consider possible calculation errors while separating.

In one embodiment, the rotary union tool 100 with the movement mandrel 1 10 may be partially assembled at a site remote from the platform 10. In one embodiment, the partially assembled rotary union tool 100 includes the lower piston link sleeve 1 100 and at least one moving chuck seal 1000 with the sleeve and / or housing 300 slidably connected to this mandrel 1 10 and placed in a quick lock condition for transport.

In the upper part of the mandrel 1 10 there will be a sleeve of male to female elevator link 160. A plurality of chuck joints (both female to female and male to male) are also included.

Below the rotating union the lower orifice assembly can be used to perform the sub-floor fracturing operations.

In one embodiment, the rotatable rotary swiveling tool 100 can be lowered from the platform floor F to the riser 80. In one embodiment, the sleeve and / or housing 300 are lowered in a fast locked condition relative to the mandrel. 1 10 In one embodiment, while the rotary union tool 100 is lowered, the movement length of the rotary attachment tool 100 can be increased to a desired length of movement. While lowering the rotary union tool 100, the additional joints of the mandrel 1 10 can be added to the mandrel 1 10 to obtain the desired length of movement between the sleeve and / or the housing 300 and the mandrel 1 10. After joining the number of joints of the mandrel 1 10 to obtain the desired length of movement the assembly of the rotary union tool 100 concludes upon joining the limiting link sleeve 500 (with the limiting shoulder 570) to the upper part of the assembled mandrel 1 10 creating such mode the desired length of movement.

The rotary tool 100 is continued to be reduced adding pipe joints now (eg drill pipe) Reducing the entire chain 85. After this, during the continuous process of lowering the rotary union tool 100, the joints of the tubing and / or tubing string and / or The perforation can be added while the rotary union tool 100 is being lowered to where the annular anti-burst device 70 (ie, the annular seal) is closed in the sleeve 300.

In one embodiment, the rotary union tool 100 is lowered until the sleeve and / or housing 300 has passed under the annular anti-burst device 70, and then the sealing element 71 of the annular anti-burst device 70 is at least partially closed in the mandrel 1 10 before the rotary union tool 100 rises slowly until the upper part of the sleeve and / or the housing 300 comes into contact with the lower part of the sealing element 71 of the annular anti-burst device 70.

Next, the sealing element 71 is opened and the sleeve and / or the housing 300 are lifted and positioned in such a manner that the external hermetic area (eg, the area between the hooks 326, 328) of the sleeve and / or the housing 300 is located adjacent the hermetic element 71 of the annular anti-burst device 70, and the sealing element 71 of the annular anti-burst device 70 is at least partially closed in the hermetic area of the sleeve 300.

Then, the sleeve and / or the housing 300 are raised until the base of the lower latch 328 comes into contact with the lower part of the sealing element 71. Then, the sealing element 71 is completely closed in the sealing surface of the sleeve 300.

Next, the string 85 (which includes the mandrel 1 1 0) is lowered relative to the sleeve and / or the housing 300 to unlock the sleeve and / or the housing 300 in relation to the mandrel 1 10 long.

Then, operations in the sub-floor can be started while the sealing element 71 of the annular anti-burst device 70 remains hermetically closed against the sleeve and / or the housing 300.

During these subsequent subsurface operations, the mandrel 10 (and the attached string 85) can be moved and rotated with respect to the sleeve and / or the housing 300 without the closed sealing element 71 of the annular anti-surge device 70 considering any differential movement. to thereby protect against damage to the hermetic element 71.

Once the sleeve and / or the housing 300 of the rotary union tool 1 00 is located in the closed annular anti-burst device 70, operations in the sub-floor (eg, fracturing operations) can be initiated by reduction of the length of movement of 1, 500 feet (457.2 m) from mandrel 1 1 0 from its upper moving position (where the sleeve and / or the housing 300 is in the longitudinal locking position) to either the desired lower position of the well fracturing tools or nests (up to the lower moving position of the mandrel where the handle comes in contact with the flange570). The long length movement of the mandrel 10 (and of the attached string 85) in relation to the sleeve 300 can be at the desired speed of the operator, and can include the rotation of the mandrel 1 1 0 (and of the joined string 85) in relation to the sleeve and / or the housing 300 if the operator so wishes.

Once the well fracturing tools are in place, then the zones of the formation can be isolated in relation to the fracturing tool (by conventional methods) and the fracturing pumping can begin.

Once the sand mixture (with the contained support agent) is fully pumped into the area to be fractured, the pumping can be stopped, and the well fracturing tools with the joined string 85 and the mandrel 1 10 raised on the well 40 to the next area. During this step, the movement mandrel 10 is lifted relative to the sleeve and / or the housing 300, of which the sleeve and / or the housing 300 remains hermetically sealed on the annular sealing element 70.

Once the tools are located on the next zone, then the same pumping operation is repeated for each zone moving to well 40.

The benefits of the rotary union tool 100 include but are not limited. 5 (1) there is no differential movement between the annular seal 71 and any article that is raised or lowered in the well 40 while the annular seal 71 remains closed in the sleeve and / or the housing 300. (2) no disconnection of tool joints through an annular anti-burst device 70.

Once multiple zones have been fractured, work is complete, while the seal 71 remains closed in the sleeve 300, the mandrel 110 can be lifted relative to the sleeve and / or the housing 300 15 until the sleeve and / or housing 300 enters a secured state in the upper portion of the length of movement of the mandrel 110. Then, the sealing element 71 of the annular anti-burst device 70 and the rotary attachment tool 100 with the joined string 85 can be opened or disconnected outside. of the hole of 40.

Equipment needed to operate the special drill pipe Female-to-female joints (eg, 600, 800, 1000, etc.) of the mandrel 110 of the tubular element and / or the pipe (which preferably are approximately 30 feet (9.1 m) of total length).

Joints of tubular element tool and / or male-to-male mandrel tubing (eg, 700, 900, etc. of the tubular member and / or of the tubing (which preferably are approximately 30 feet (9.1 m) in length) total and include a slit elevator slot eg, 706, 906, etc.). connecting joints (for example, gasket 21 00 in figures 54, 55, 58 and 51) for the lifting and manipulation of chuck 1 1 0 during assembly and separation on platform 1 0.

False rotation Two sets of special 5"lifts (1 2.7 cm) fifteen - . 15 - Special assembled grippers that do not leave marks Hand-operated belt pliers Guide to embouch Lime twenty - . 20 - Scourers Cleaning solvents Lubricant Although certain novel features of this invention shown and described herein are set forth in the appended claims, the invention is not It is intended to be limited to the specified details, since an expert in the relevant profession will understand that various omissions, modifications, substitutions and changes in the forms and details of the illustrated device and in its operation can be made without departing in any way from the spirit essence of the present invention. No characteristic of the invention is critical or essential unless expressly stated as "critical" or "essential".

The following is a list of parts of the reference numbers or part numbers and corresponding descriptions as used in this document: List of reference numbers Number Description from reference 10 drilling rig / well drilling rig 22 fluid or drilling mud 40 well 70 annular anti-rupture device 71 ring hermetic unit 75 fireplace 80 rising pipe 85 drill or work string 87 seabed Number Description from reference 88 wellhead 90 upper volumetric section 92 lower volumetric section 100 rotating union 1 10 mandrel 126 upper end 128 lower end 300 rotating sleeve or housing 310 interior section 315 separation 326 hitch, flange, upper ledge 328 coupling, flange, lower protrusion 350 Ls - total length of sleeve or housing with joints at the upper and lower ends 370 first hermetic seal 380 second hermetic seal 500 upper motion limiting mandrel seal 510 longitudinal passage 512 longitudinal passage diameter 520 upper end 522 threads 530 bottom end Number Description from reference 532 threads 533 conical flange 538 slit for hermetic seal 539 enlarged area of the slit for hermetic sealing 550 hermetic seal 552 first extreme 553 enlarged area of hermetic seal 555 second sealing end 556 conical sealing area 557 vertical area of the hermetic seal 570 flange 600 double female end mandrel gasket 601 external hermetic surface 602 interior surface 604 wall thickness 610 longitudinal passage 612 inside diameter 620 upper end 621 conical flange 622 threads 623 conical area Number Description from reference 630 lower end 632 threads 633 conical area 660 flange 670 arrow 672 arrow 700 double male end chuck gasket 701 outside hermetic surface 704 wall thickness 706 split area 710 longitudinal passage 712 diameter 720 upper end 721 conical flange 722 threads 723 conical flange 728 slit for the first hermetic seal 729 enlarged area of the first indentation 730 lower end 731 conical flange 732 threads 733 conical flange Number Description from reference 738 slit for the second hermetic seal 739 enlarged area of the second slit 740 top conical element 742 transition insert 746 lower transition 748 transition insert 750 first hermetic seal 752 first extreme 753 enlarged area of the first hermetic seal 755 second end of the first hermetic seal 756 conical area of the first seal 757 vertical area of the first seal 760 second hermetic seal 770 inside diameter 774 external diameter 800 double female end mandrel gasket 801 outside hermetic surface 802 interior surface 804 wall thickness 810 longitudinal passage 812 inside diameter 820 upper end Number Description from reference 830 lower end 850 hermetic seal 900 double male end chuck gasket 901 exterior hermetic surface 906 split area 910 longitudinal passage 920 upper end 923 conical flange 930 bottom end 933 conical flange 1000 double female end mandrel gasket 1001 outside hermetic surface 1004 wall thickness 1010 longitudinal passage 1012 inside diameter 1020 upper end 1030 lower end 1 100 mandrel joint with lower flange 1 1 10 longitudinal passage 1 1 12 inside diameter 1 120 upper end 1 122 threads Number Description from reference 1 128 slit for hermetic seal 1 129 elongated area of the slit for sealing 1 130 lower end 1 132 threads 1 150 airtight seal 1 153 enlarged area of the hermetic seal 1 155 second sealing end 1 156 conical area of hermetic seal 1 157 vertical area of the hermetic seal 1200 limiting edge 1300 locking flange 1400 split area for internal reduction between the sleeve and the mandrel 1500 female adjustable hermetic unit 1502 exterior surface 1510 longitudinal passage 1520 first extreme 1522 reduced entry 1530 second end 1532 elongated entry 1534 conical section Number Description from reference 1540 slit for hermetic seal 1544 vertical section 1546 conical area 1550 diameter of the slit 1552 external diameter of the slit 1554 inside diameter of the slit 1560 O-ring groove 1562 O-ring 2000 plurality of anti-surge devices 2010 first anti-surge device of the ram 2012 arrow 2020 second anti-surge device ram 2022 arrow 2030 third anti-surge device 2032 arrow 2040 fourth anti-surge device ram 2042 arrow 2050 distance between the first and second ram 2052 distance between the first and third battering ram 2054 distance between the third and fourth battering 2056 distance between the second and fourth battering 2058 distance between the second and third battering ram Number Description from reference 2100 lifting link sleeve 2500 double male end mandrel gasket 2506 split area on external hermetic surface 2600 double female end mandrel gasket 2700 double male end mandrel gasket 2706 split area on external hermetic surface 2800 double female end mandrel gasket 2900 double male end mandrel gasket 2906 split area on external hermetic surface 3000 double female end mandrel gasket 3001 arrow indicating the descending movement 3002 arrow that indicates the descending movement 3003 arrow indicating the descending movement 3004 arrow indicating the descending movement 3005 arrow indicating the descending movement 3010 arrow that indicates the upward movement 3011 arrow that indicates the upward movement 3012 arrow that indicates the upward movement 3013 arrow indicating the upward movement 3014 arrow that indicates the upward movement 3015 arrow that indicates the upward movement 3100 double male end mandrel gasket Number Description from reference 3106 split area on the external hermetic surface ABO annular anti-rupture device BJ ball joint BL augmentation line CM multiple shutter CL shutter line CM multiple shutter D diverter DL diverter line F platform floor IB inner cylinder KL interruption line M P mud pit M B Mud and gas separator or divider OB outer cylinder R rising pipe RAM anti-rupture device ram BOP RF flow line S floating structure or platform SJ sliding or telescopic joint SS vibrating screen All measurements disclosed in this document are at standard temperature and pressure, at ground level, unless otherwise indicated. All materials used or intended for use in a human being are biocompatible, unless otherwise indicated.

It will be understood that each of the elements described above, or two or more together may also have a useful application in other types of methods different from the type described above. Without further analysis, the foregoing will reveal so fully the essence of the present invention that others can, through the application of current knowledge, easily adapt it for various applications without omitting the characteristics that, from the point of view of the state of the art, constitute clearly the essential characteristics of the generic or specific aspects of this invention set forth in the appended claims. The above embodiments are presented by way of example only; the scope of the present invention will be limited only by the following claims.

Claims

CLAIMS 1 . A method for creating a rotary and oscillating rotary joint tool while located on a rig or drilling platform having a specified length of movement, comprising the steps of: (a) provide a rotary union tool, the rotary union tool comprises a mandrel and a sleeve and / or a housing, the mandrel is rotatable and oscillating relative to the sleeve and / or the housing, the mandrel has a first length of movement relative to the sleeve and / or the housing; (b) supporting in a substantially vertical direction the rotary attachment tool on the platform; (c) adding a chuck joint to the upper part of the mandrel, such additional joint increases the length of movement of the mandrel relative to the first length of movement; (d) lowering the rotary union tool and again supporting in a vertical direction the rotary union tool in a substantially vertical direction on the platform; Y (e) repeating until stages "c" and "d", until the final movement length of the mandrel relative to the sleeve and / or the housing is at least 100 feet (30 4 cm). 2. The method of claim 1, wherein the steps "c" and "d" may be repeated until the final movement length may be greater than about 150 feet (45.7 m). 3. The method of claim 1, wherein steps "c" and "d" can be repeated until the final movement length 5 may be greater than approximately 300 feet (91 .4 m). 4. The method of claim 1, wherein steps "c" and "d" may be repeated until the final movement length may be greater than about 500 feet (152.4 m). 5. The method of claim 1, wherein the steps "c" io and "d" may be repeated until the final movement length may be greater than about 1000 feet (304.8 m). 6. The method of claim 1, wherein the steps "c" and "d" may be repeated until the final movement length may be greater than about 1500 feet (457.2 m). 7. The method of claim 1, wherein in step "e" a plurality of mandrel joints include at least one slit area in the outer hermetic surface, and during step "c", one of these slit areas is used to support the rotary attachment tool in a substantially vertical direction on the platform. 8. The method of claim 7, wherein at least one of the split areas includes the transition sections of soft material. 9. The method of claim 7, wherein the upper portions of the split areas can be frustoconical. 10. The method of claim 7, wherein the upper portions of the split areas are conical. eleven . A male and female end assembly of the mandrel to join the ends of the chuck joint ends that 5 have a longitudinal flow passage therethrough which has a longitudinal axis, comprising: the first and the second joint of the mandrel, the first joint that has a male end portion at one end, ío the second joint that has a female end portion in a limb, the male end portion having a flat annular male end face, and an annular groove open to the annular flat face, the male annular groove has a longitudinal axis which is parallel to the longitudinal axis of the longitudinal flow passage; the female end portion having an annular flat face of female end, and an annular groove open to the annular flat face, the female annular groove has a longitudinal axis which is parallel to the longitudinal axis of the longitudinal flow passage; The male annular groove and the female annular groove cooperate to define an annular hermetic chamber; the hermetic annular chamber containing a cylindrical packing unit. 12. The assembly of claim 1, wherein the flat face 5 of the female end portion can move along the longitudinal axis. 13. The assembly of claim 12, wherein the flat face of the female end portion is connected to the body of the female end joint using an interference fit. 14. The assembly of claim 1, wherein the packaging unit has the decompressed and compressed states, and in an unpacked state the packaging unit has an inner radius equal to or less than the inner radius of the annular hermetic chamber. 15. The assembly of claim 1, wherein the packaging unit is elastic. 16. The assembly of claim 1, wherein the sealed chamber has a plurality of cylindrical walls that are nested with respect to each other. 17. The assembly of claim 16, wherein one of the grooves in the male or female end slot has a conical portion and a non-conical portion, where the conical portion is located farther from the flat face than the non-conical portion. . 18. The assembly of claim 1 7, wherein the walls 20 grooves are conical in the range of 1 to 10 degrees. 19. The assembly of claim 1, wherein the packaging unit is symmetric about its radial axis. 20. The assembly of claim 1, wherein the sealed chamber and the female and / or male groove is symmetrical on a 25 radial medium plane. twenty-one . The assembly of claim 1, wherein a gasket with a main body having the first and second end is contained in the male annular and female annular groove, where the main body of the gasket is compressed axially when it is 5 place in the hermetic chamber. 22. The assembly of claim 21, wherein the second end of the joint has sharp skins and the female or male slot has sharp bends adjacent to the orifice axis where fluid capture is reduced. 23. The assembly of claim 21, wherein the main body of the joint in an uncompressed state is generally rectangular in shape with rounded edges. 24. The assembly of claim 21, wherein the second end of the joint in an uncompressed state is generally rectangular in shape with the sharp corners. 25. The assembly of claim 21, wherein a radial width of the main body of the joint in an uncompressed state is substantially equal to the width of the radial hermetic chamber. 26. The assembly of claim 21, wherein a radial width of the main body of the joint in an uncompressed state is greater than the axial width of the radial hermetic chamber. 27. The assembly of claim 21, wherein a radial width 5 of the second portion of the joint in a state decompressed is greater than the axial width of the radial hermetic chamber. 28. A gasket and sealing ring assembly for joining and hermetically sealing the threaded ends of pipe or tube defining an axial flow passage therethrough, comprising: the first and the second end, each end being at a respective end of the tube ends; the axial flow passage with the first and the second internal diameter; each end has the opposite end faces with the side walls cooperating to define an annular groove comprising a sealed chamber and a circumferentially continuous groove radially inward from the chamber sealed to the axial flow passage, the radial groove being located between the first and the second internal diameter of the axial flow passage; a joint comprising a main body and a second portion radially inward in the decompressed state; and the main body of the board is located inside the hermetic chamber. 29. The assembly of claim 28, wherein the gasket is elastic. 30. The assembly of claim 28, wherein the main body of the joint in an uncompressed state has an interior radius equal to or less than the interior radius of the chamber wall tight that forms an interference fit. 31 A marine oil and gas well drilling rig, comprising: (a) a marine drilling platform; (b) a drill string extending between the marine drilling platform and a formation to be drilled, the string has a flow orifice; (c) a mandrel having the upper and lower end sections and connected to and rotating with the upper and lower sections of the drill string, the mandrel has an outer diameter and includes a longitudinal passage forming a continuation of a flow orifice of the drill string sections, the mandrel is composed of at least one joint having the female double ends with the joint that can be divided by means of anti-surge device; (d) a sleeve having a longitudinal sleeve passage and an internal diameter, the sleeve is rotatably connected to the mandrel; Y (e) an interstitial space between the internal diameter of the sleeve and the external diameter of the mandrel. 32. The apparatus of claim 31, wherein the mandrel includes two double female end joints that are connected by means of a male end link sleeve. 33. A method for using an oscillating rotating union in a drilling or working string, the method comprises the following steps: (a) lowering a rotating and oscillating tool to an annular anti-bursting device, the tool comprises a mandrel and a sleeve, the sleeve is oscillating relative to the mandrel, and the mandrel includes at least one joint having the female double ends with the joint that can be divided by means of an anti-surge device, the sleeve has two separate sealed units, the rotating union includes an interstitial space between the sleeve and the mandrel with the first and the second sealed hermetically sealed unit where each one closes the space interstitial (b) after step "a", having the annular anti-rupture device close in the sleeve; Y (c) after a step "b", cause the relative longitudinal movement between the sleeve and the mandrel. 34. The method of claim 33, wherein in step "a", the mandrel includes two double female end joints which are connected by means of a double male end link sleeve and in the "c" stage when the double end sleeve The male end is in the same longitudinal position of the first hermetic unit, the first hermetic unit loses its hermetic closure of the interstitial space, but the second hermetic seal maintains its hermetic closure of the interstitial space. 35. The method of claim 34, wherein after that the double male end link sleeve passes through the first hermetic unit, the first hermetic unit recovers its hermetic closure of the interstitial space. 36. The method of claim 35, wherein when the double male end link sleeve is in the same longitudinal position of the second sealed unit, the second sealed unit loses its sealing of the interstitial space, but the first hermetic seal maintains its closure hermetic interstitial space. 37. The method of claim 36, wherein after the double male end link sleeve passes through the second sealed unit, the second sealed unit regains its sealing of the interstitial space. 38. The method of claim 33, wherein in the step 15"a", the mandrel includes two double female end joints which are connected by means of a double male end link sleeve and in the "c" stage when the double male end sleeve is in the same longitudinal position of the second hermetic unit, the second hermetic unit loses its hermetic seal of the interstitial space, but the first hermetic seal maintains its hermetic closure of the interstitial space. 39. The method of claim 38, wherein after the double male end cap sleeve passes through the second sealed unit, the second sealed unit recovers its sealing of the interstitial space. 40. The method of claim 39, wherein when the double male end link sleeve is in the same longitudinal position of the first sealed unit, the first sealed unit loses its hermetic seal of the space 5 interstitial, but the second hermetic seal maintains its hermetic closure of the interstitial space. 41 The method of claim 40, wherein after the double male end cap sleeve passes through the first hermetic unit, the first sealed unit recovers its sealing of the interstitial space. 42. The method of claim 41, further comprising the step after step "c", moving the sleeve out of the annular anti-burst device. 43. The method of claim 42, which also 15 comprises the step of moving the sleeve inside the annular anti-rupture device and having the annular anti-rupture device closed in the sleeve. 44. The method of claim 43, further comprising the step of, after moving the sleeve in the annular anti-bursting device causing relative longitudinal movement between the sleeve and the mandrel and activating a quick-lock / quick-release system from an unlocked state to a blocked state. 45. The invention as disclosed and described Substantially.