WO2016083582A1 - Downhole swivel sub and method of running a string in a wellbore - Google Patents

Downhole swivel sub and method of running a string in a wellbore Download PDF

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Publication number
WO2016083582A1
WO2016083582A1 PCT/EP2015/077939 EP2015077939W WO2016083582A1 WO 2016083582 A1 WO2016083582 A1 WO 2016083582A1 EP 2015077939 W EP2015077939 W EP 2015077939W WO 2016083582 A1 WO2016083582 A1 WO 2016083582A1
Authority
WO
WIPO (PCT)
Prior art keywords
section
coupling member
swivel sub
string
casing
Prior art date
Application number
PCT/EP2015/077939
Other languages
French (fr)
Inventor
Mike Wardley
Thomas Marr Graeme
Original Assignee
Tercel Ip Limited
Tercel Oilfield Products Belgium Sa
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Tercel Ip Limited, Tercel Oilfield Products Belgium Sa filed Critical Tercel Ip Limited
Publication of WO2016083582A1 publication Critical patent/WO2016083582A1/en

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/20—Driving or forcing casings or pipes into boreholes, e.g. sinking; Simultaneously drilling and casing boreholes
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/02—Couplings; joints
    • E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/05—Swivel joints
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
    • E21B33/14—Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells

Definitions

  • the present invention relates to a downhole swivel sub for insertion in a string to be run in a wellbore. More particularly, the downhole swivel sub comprises a coupling member for selectively locking the rotation of a first body relative to a second body. According to a second aspect of the invention, the present invention relates to a method wherein the downhole swivel sub is included in a casing while drilling string for cementing the casing string in a wellbore.
  • the mandrel and the housing comprise a set of coupling splines arranged on their external surface.
  • a locking sleeve is arranged around the mandrel and the housing. The locking sleeve can be moved between a first and a second position around the mandrel and the housing.
  • the locking sleeve comprises a set of coupling splines arranged in its internal surface and adapted to mate with the coupling splines of the mandrel and the housing. In the first position, the locking sleeve is secured to the housing by a shear pin and allows rotation of the housing relative to the mandrel.
  • This downhole swivel sub is used for example in a method of running a string in a wellbore, wherein the bottom of the string comprises fragile elements that are not suitable for rotating. Such elements can be for example a liner, a screen or gravel pack assembly.
  • the string including such elements is deployed into the wellbore in a first step wherein the portion of the string above the downhole swivel sub is rotated while the portion of the string under the downhole swivel sub is not rotated. Rotation of the string breaks the friction between the string portion above the swivel and the wall of the wellbore, allowing the string to be deployed in deeper areas without damaging the fragile elements under the downhole swivel sub.
  • a hydraulic mechanism is actuated to release that string section.
  • a backup release mechanism provided under the downhole swivel sub is operated by rotating the string to a reverse direction.
  • a pressure differential is applied between the bore of the downhole swivel sub and the annulus for moving the sliding sleeve to its second position, so that the downhole swivel sub gets locked and the string section under the swivel is allowed to rotate with the upper string section to allow the operation of the backup release mechanism.
  • Document US2014/299379 of the applicant discloses another downhole swivel sub which comprises a first tubular body and a second tubular body partially included in the first tubular body.
  • a clutch is arranged between an inner shoulder in the first body and the end of the second tubular body which is inside the first body. The clutch allows the first body to rotate independently from the second body or to provide a reduction in torque from the first body to the second body.
  • a sliding sleeve is positioned around the first tubular body and around the second tubular body.
  • the sliding sleeve comprises teeth arranged at the inner surface of the sleeve and adapted to mate with teeth provided at the outer surface of the first tubular body and second tubular body.
  • the sliding sleeve is set up in a first position against an abutment at the outer surface of the second body, and around the second body, wherein the teeth of the sliding sleeve are disengaged from the teeth of the first tubular body, such that the first body can rotate independently from the second body or with a reduction in torque from the first body to the second body.
  • the sliding sleeve is locked to the second body by a shear pin and biased by a spring arranged around the first tubular body.
  • a cover surrounds the spring, a portion of the first body and a portion of the sliding sleeve.
  • a downhole tool or a liner that is not wished to rotate or a workstring portion comprising such downhole tool or liner is connected to the second body.
  • a differential pressure is induced within the sub which induces an upwards movement of the sliding sleeve to a second position with sufficient force to break the shear pin.
  • the teeth of the sliding sleeve mate with the teeth of the first body and second body, and a locking dog provided in the sliding sleeve expands in a recess provided at the outer surface of the second body, to prevent further movement of the sliding sleeve back to its first position.
  • Document US patent 7011162 discloses a swivel apparatus comprising a top body, a bottom body and a hydraulically shiftable member that selectively allows the top body to be rotated with the bottom body when the shiftable member is in a first position and to rotate freely with respect to each other in one direction and rotate together in a second direction when the shiftable member is in a second position.
  • the shiftable member is arranged around the top body and around the bottom body, with a portion of the shiftable member arranged inside a housing connected to the top body, and with a second portion of the shiftable member arranged outside of the housing.
  • the swivel apparatus disclosed in that document is used in a method of completing a wellbore, and arranged in a running assembly including an expander tool and a running tool.
  • the running assembly is enclosed in a liner, with the running tool mechanically connected to the liner.
  • the running tool is located below the expander tool and the swivel apparatus is arranged between the running tool and the expander tool.
  • the swivel apparatus is operated to move the shiftable member towards its second position, allowing the expander tool to rotate for expanding a portion of the liner to put the liner in contact with a preinstalled casing therearound, while the liner mechanically connected to the running tool is not rotating.
  • the running tool has to be disconnected from the liner and the running assembly including the expander tool, the swivel apparatus and the running tool is removed from the wellbore.
  • the release mechanism for removing the running tool from the liner fails, and in that case, the string including the running assembly can be rotated to the left so that the torque is transferred through the swivel apparatus to the running tool for releasing the running tool from the liner.
  • the major portion of the shiftable member is easily accessible from the outside of the tool, for facilitating maintenance and resetting the shiftable member towards its first position when the running assembly has been removed from the wellbore. Also, the shiftable member is protected from accidental tripping since it is surrounded by the liner.
  • the pressure in the annulus between the drill string and the wellbore may significantly vary from a first formation zone to a second formation zone. If a pressure drop occurs while drilling through a new formation zone, some formation zone may collapse on the drill string and stuck the drill string. Some methods are available for freeing the drill string, such as jarring methods, but they are less preferred as they are time consuming and may damage the drill string.
  • the present invention is related to a downhole swivel sub for insertion in a string, the downhole swivel sub comprising: a first tubular body comprising a first end and a second end;
  • a coupling member which, in a first position, engages the first body with the second body, and in a second position, disengages the second body from the first body; the said coupling member being fully enclosed in the second body and forming a chamber with the inner surface of the second body, said chamber being in fluidic communication with the external of the downhole swivel sub through a vent in the second body for allowing the movement of the coupling member from its first position towards its second position.
  • the said coupling member is configured to be moved to the second position by a differential of pressure between the inside of the downhole swivel sub and the outside of the downhole swivel sub.
  • the said coupling member (107) comprises: a first coupling section mating with a first complementary coupling section (110) on the second end of the first body,
  • the coupling member in the first position of the coupling member, the first coupling section and the second coupling section are maintained in engagement with the first complementary coupling section and second complementary coupling section, respectively, and, in the second position of the coupling member, the first coupling section and the second coupling section are maintained disengaged from the first complementary coupling section and second complementary coupling section, respectively.
  • the coupling member is locked in said first position by a shear pin, and locked in said second position by a latching mechanism.
  • the said coupling member (107) comprises: - a first coupling section which is a set of teeth forming castellation adapted to mate with a complementary set of teeth provided on the second end of the first body, and; a second coupling section which is a set of teeth forming castellation adapted to mate with a complementary set of teeth provided inside the second body.
  • the downhole swivel sub comprises a second coupling member that, while the first coupling member is set in its second position, allows rotation of the first body relative to the second body when the first body is rotated in a first direction and
  • the said second coupling member is a freewheel.
  • the present invention is related to a method of casing while drilling a wellbore by running a string comprising a casing section with a first end directed towards the bottom of the wellbore and a second end directed towards the entrance of the wellbore, the method comprising a step of connecting a first end of a downhole swivel sub as presented above, to a lower casing string portion of the casing section and a second end of the said downhole swivel sub to an upper casing string portion of the casing section.
  • the casing section extends in the wellbore from the surface of the wellbore.
  • the said first end of the string is provided by a drill bit, and the said coupling member forming the said chamber is kept in said first position during a step of the drilling of the wellbore.
  • the said coupling member forming the said chamber is kept in said first position during a step of the drilling of the wellbore.
  • the method comprises a fu rther step of lowering a second string in the so cemented casing section, drilling the said first end of the string being provided with a d rillable drill bit, and drilling a second wellbore section.
  • the casing section is a casing or liner connected to a workstring through a release mechanism, said workstring being disconnected with the said release mechanism from the said casing section or liner after cementation of the said casing section or liner in the wellbore.
  • the said release mechanism includes a backup release mechanism
  • the said downhole swivel sub (100) comprises: a second coupling member that, while the first coupling member is set in its second position,
  • Fig. 1A represents a longitudinal cross sectional view of a downhole swivel sub according to an embodiment of the present invention.
  • Fig. 2 represents an enlarged cross sectional view of a portion of the downhole swivel sub according to an embodiment of the present invention.
  • Fig. 3 represents a longitudinal cross sectional view of a coupling member of the downhole swivel sub according to an embodiment of the present invention.
  • Fig. 4 represents a longitudinal cross sectional view of a bottom portion of a second body of the downhole swivel sub, the portion being adapted for receiving a coupling member.
  • Figures 5a to 5c represent top views of various possible embodiments of a coupling member of the downhole swivel sub according to the present invention.
  • Fig. 6 represents a schematic view of an embodiment of a string including a first embodiment of the downhole swivel sub.
  • Fig. 7a represents a partial longitudinal cross sectional view of a second embodiment of a downhole swivel sub according to the present invention, wherein the downhole swivel sub further comprises a freewheel.
  • Fig. 7b represents a partial longitudinal cross section view of complementary to the view of the second embodiment of the downhole swivel sub presented in Fig. 7a.
  • Fig. 8 represents a schematic view of a string including a second embodiment of the downhole swivel sub.
  • Figure 1 shows a first embodiment of a downhole swivel sub 100 according to the present invention.
  • the downhole swivel sub 100 of the present invention is a multi-use tool that can be used in a method for drilling, in a method wherein two portions of a string have to be rotated relative to each other, in a step of cementation, and in a step of running a casing.
  • the top half of figure 1 presents the downhole swivel sub in a first configuration (with the coupling member in its first, engaged, position), and the bottom half of figure 1 presents the downhole swivel sub in a second configuration (with the coupling member in its second, disengaged, position).
  • the downhole swivel sub 100 comprises: a first body 101 comprising a first end 103 and a second end 104;
  • a second body 102 disposed coaxially to the first tubular body and enclosing the second end 104 of the first body 101, the first body 101 and the second body 102 enclosing a bore 106;
  • a coupling member 107 which, in a first position as presented in the top half of figure 1, engages the first body 101 with the second body 102 (such that the second body 102 rotates relative to the longitudinal axis of the downhole swivel sub together with the first body 101 upon rotation of the first body 101), and in a second position as presented in the bottom half of figure 1, disengages the second body 102 from the first body 101 (such that the first body 101 can rotate independently from the second body 102).
  • the coupling member 107 is fully enclosed in the second tubular body 102.
  • Such a downhole swivel sub comprises a limited number of pieces, and is therefore cheap and easier to assemble.
  • the first end 103 of the first body is destined to be connected to an upper casing portion extending from the surface of the wellbore.
  • the downhole swivel sub 100 according to the present invention can be advantageously connected between two casing portions and can be permanently cemented in a wellbore with the casing.
  • the coupling member 107 is fully arranged inside the second body 102.
  • Such an arrangement is made possible because the downhole swivel sub according to the present invention is advantageously destined for a single use.
  • the downhole swivel sub 100 is used in a method of casing a casing string in a wellbore wherein the downhole swivel sub is cemented with the casing string. Therefore there is no need to reset the coupling member 107 to its initial position and the accessibility of the coupling member 107 from the outside of the apparatus is not desirable.
  • the design of the downhole swivel sub according to the present invention advantageously provides an external surface substantially regular and devoid of any axially moving parts. Such a downhole swivel sub is more suitable for being run into a wellbore and to be cemented in the wellbore.
  • a longitudinal cross sectional view of a first end portion 130 of the second body 102 including the first body 101 and the coupling member 107 is represented in figure 2.
  • a longitudinal cross sectional view of the coupling member 107 is represented more in detail in figure 3, and the first end portion 130 of the second body 102 without the coupling member 107 and the first body 101 is represented in figure 4.
  • the coupling member 107 is initially in a first position as presented on the top side of figure 1 and of the right side of figure 2.
  • the coupling member 107 has a first end comprising a first coupling section 109 mating with a first complementary coupling section 110 on the second end 104 of the first body 101, and a second coupling section 109' mating with a second complementary coupling section 110' provided inside the second body 102.
  • the first coupling section 109 and the second coupling section 109' are maintained in engagement with their respective first complementary coupling section 110 and second complementary coupling section 110'.
  • Figures 2 and 3 shows longitudinal cross sectional view of a preferred embodiment of the coupling member 107.
  • Figures 5a, 5b show top views of two possible embodiments of the coupling member, wherein: the first coupling section 109 is a set of teeth forming castellation adapted to mate with a complementary set of teeth 110 provided on the second end 104 of the first body 101, and; the second coupling section 109' is a set of teeth forming castellation adapted to mate with a complementary set of teeth 110' provided inside the second body 102.
  • each of the teeth of the first coupling section 109 and each of the teeth of the second coupling section 109' forms a single tooth as presented in figure 5a.
  • This embodiment is easier to manufacture and provides better resistance to torque.
  • the teeth of the first coupling section 109 are offset from the teeth of the second coupling section 109'.
  • Figure 5c shows a top view of another alternative embodiment of a coupling member 107 wherein the first coupling section 109 is a set of teeth forming castellation adapted to mate with a complementary set of teeth provided on the second end 104 of the first body 101 and wherein the second coupling section is a polygonal coupling section 124 adapted to mate within a polygonal bore made in the second body 102.
  • the coupling member 107 is realized with a first coupling section 109 and a second coupling section 109' arranged side by side.
  • the torque is transmitted from the first body 101 to the second body 102 through a limited zone of the coupling member 107, ensuring the robustness of the coupling member 107, allowing arrangement of seals over a spread area between the external surface of the coupling member 107 and the internal surface 125 of the second body 102, and preserving those seals from rotation.
  • the coupling member 107 comprises a portion 152, for example a sleeve portion, connected to the second body by a sheer pin 122 and arranged such as to maintain the coupling member in its first position with the first coupling section 109 engaged with the first complementary coupling section 110 of the first body 101 and with the second coupling section 109' engaged with the second complementary coupling section 110' of the second body.
  • the coupling member 107 can be maintained against the first body 101 by a biasing mechanism such as a spring or Belleville washers.
  • the coupling member 107 In its first position, the coupling member 107 forms a chamber 120 with the inner surface 125 of the second body 102, the chamber 120 being in fluidic communication with the external of the downhole swivel sub 100 through a vent 121 in the second body 102 for allowing the movement of the coupling member 107 from its first position towards its second position.
  • the coupling member 107 can be moved to its second position by a differential of pressure between the inside of the downhole swivel sub and the outside of the downhole swivel sub, for example by dropping a dart or a ball that get captured by a dart catcher assembly or a ball seat (not shown) arranged below the downhole swivel sub as well known in the art, or simply by increasing the fluid flow pressure and pushing the piston differential area 111.
  • the man skilled in the art can imagine a system wherein the coupling member is moved to the second position by a motor actuated upon detection of a signal, for example a RFID signal, by a detector.
  • a signal for example a RFID signal
  • the chamber 120 In the second position of the coupling member 107, the chamber 120 has a decreased volume and the coupling member 107 is further locked on its second position by a latching mechanism 123, for example a latching ring or a set of latching pins that enter into a cavity 134 formed at the external surface of the coupling member 107.
  • a latching mechanism 123 for example a latching ring or a set of latching pins that enter into a cavity 134 formed at the external surface of the coupling member 107.
  • the coupling member 107 comprises a first portion 112 of larger external diameter, a second portion 113 of intermediate external diameter forming a first shoulder 126 with the first portion 112, and a third portion 114 of smaller external diameter forming a second shoulder 127 with the second portion 113.
  • a tubular sealing member 135 overlaps a part of the first portion 112 of the coupling member 107, the first shoulder 126 and a part of the second portion 113 of the coupling member 107.
  • the first portion 112 is provided with a first external sealing surface 112' formed by the part of the tubular sealing member 135 overlapping the first portion 112, and two spring energized seals 136, 136'arranged on both sides of a first annular ridge 137 protruding from the first portion 112.
  • the first annular ridge 137 comprises a recess including a seal 138, preferably a rubber energized ring with a low friction contacting surface, such as for example a glyd ® ring.
  • the second portion 113 is provided with a second external sealing surface 113' formed by the part of the tubular sealing member 135 overlapping the second portion 113 and by two other spring energized seals 139, 139' arranged on both sides of a second annular ridge 140 protruding from the second portion 113.
  • the second annular ridge 140 comprises also a recess including a seal 141, preferably a rubber energized ring with a low friction contacting surface, such as for example a glyd ® ring.
  • the first end portion 130 of the second body 102 comprises three inner wall portions 115, 116, 117, of inner diameter mating with the coupling member 107.
  • a first inner wall portion 115 in tight contact with the first sealing surface 112' of the coupling member 107, a second inner wall portion 116 in tight contact with the second sealing surface 113' of the coupling member 107, and a third inner wall portion 117 is in contact with the third portion 114 of the coupling member 107.
  • the first inner wall portion 115 forms a first shoulder 128 with the second inner wall portion 116 that forms a second shoulder 129 with the third inner wall portion 117.
  • the chamber 120 is formed between the first inner wall portion 115 of the second body 102, the first shoulder 128 of the second body 102, the sealing surface 113' of the coupling member 107 and the part of the tubular sealing member 135 covering the first shoulder 126 of the coupling member.
  • the vent 121 is arranged besides the first shoulder 128 and extends from the inner wall portion 115 of the second body towards the external surface of the second body.
  • the seal arrangement described above ensures the tightness of the chamber 120 from the bore 106 of the downhole swivel sub for any position of the coupling member 107.
  • the second body 102 comprises a second end portion 131 with an inner cavity 143 enclosing an annular ridge 142 protruding from the first body 101 and a set of thrust bearings 144 arranged on both sides of the annular ridge 142 of the first body 101.
  • the second end portion 131 of the second body 102 comprises a seal 145, for example an O-ring or a rubber energized plastic faced seal in tight contact with the first body 101.
  • the second body further comprises an intermediate portion 132 adjacent to the second end portion 131.
  • the first intermediate portion 132 comprises a set of inner grooves each one including a seal 146, preferably a rubber energized ring with a low friction contacting surface, such as for example a glyd ® ring.
  • This set of seals ensures the tightness of the first body 101 against the second body 102, with reduced friction since the first body 101 is destined to rotate within the second body 102.
  • Figure 7A and figure 7B show two complementary parts of a second embodiment of a downhole swivel sub 100 according to the present invention.
  • the downhole swivel sub of the second embodiment comprises similar features as the downhole swivel sub of the first embodiment described above.
  • the downhole swivel sub 100 of the present invention is a multiuse tool that can be used in a method for drilling, in a method wherein two portions of a string have to be rotated relative to each other, in a step of cementation, in a step of running a casing or a liner, and/or in a step of disconnection of an upper portion of a string.
  • the right side of both figures 7A and 7B presents the downhole swivel sub in a first configuration
  • the left side of both figures 7A and 7B presents the downhole swivel sub in a second configuration.
  • the downhole swivel sub 100 comprises: a first body 101 comprising a first end 103 and a second end 104;
  • a second body 102 disposed coaxially to the first tubular body and enclosing the second end 104 of the first body 101, the first body 101 and the second body 102 forming a bore 106;
  • a first coupling member 107 which, in a first position as presented in the right side of figure 7B, engages the first body 101 with the second body 102, and in a second position as presented in the left side of figure 7B, disengages the second body 102 from the first body 101;
  • the said first direction is advantageously the same direction of rotation as for d rilling, and the said second direction is the direction opposite to the said first direction.
  • the first coupling member 107 is similar to the coupling member described for the first embodiment of the swivel sub herein above.
  • the second body 102 is subdivided in: a first end portion 130 comprising the coupling member 107 and the end 104 of the first body,
  • first intermediate portion 132 adjacent to the second end portion 131, and a second intermediate portion 133 between the first intermediate portion 132 and the first end portion 130.
  • the first end portion 130 is similar to the one described for the first embodiment described above.
  • the second end portion 131 of the second body 102 comprises a with an inner cavity 143 enclosing an annular ridge 142 protruding from the first body lOland a set of thrust bearings 144 arranged on both sides of the annular ridge 142 of the first body 101.
  • the second end portion 131 of the second body 102 comprises a seal 145, for example an O-ring or a rubber energized plastic faced seal in tight contact with the first body 101.
  • the second body further comprises a first intermediate portion 132 adjacent to the second end portion 131.
  • the first intermediate portion 132 comprises a set of inner grooves each one including a seal 146, preferably a rubber energized ring with a low friction contacting surface, such as for example a glyd ® ring. This set of seals ensures the tightness of the first body 101 against the second body 102, with reduced friction since the first body 101 is destined to rotate within the second body 102.
  • the second body 102 comprises a second intermediate portion 133 between the first intermediate portion 132 and the first end portion 130.
  • the second intermediate portion 133 comprises an inner cavity 147 including the second coupling member 108 arranged between the second body 102 and the first body 101 to selectively allow rotation of the first body 101 relative to the second body 102 when the first body 101 rotates according to a first direction while the first coupling member 107 is disengaged from the first body 101, and to transmit the torque of the first body 101 to the second body 102 when the first body 101 rotates according to a second direction while the first coupling member 107 is disengaged from the first body 101.
  • the second coupling member 108 is a freewheel.
  • a first one-way clutch body 148 is fixed around the first body 101 and the second coupling member 108 is a second one-way clutch body that is biased against the first one-way clutch body 108 by a spring 151.
  • the second clutch body or in other words the second coupling member 108 comprises a coupling section 149 for transmitting the torque of the first body to the second body which also comprises an inner coupling section 150.
  • the coupling section 149 of the second coupling member 108 can be a polygonal coupling section mating with an inner coupling portion 150 of the second body 102 having a polygonal inner cross section, or alternatively, a set of splines or teeth mating with a complementary set of splines or teeth arranged at on the inner surface of the second body 102.
  • the first one-way clutch body 148 and the second one-way clutch body 108 both comprise a saw tooth profile mating with each other.
  • a sprag clutch is arranged in the cavity between the first body 101 and the second body 102.
  • Other freewheel alternatives as known by the man skilled in the art are possible.
  • the present invention relates to a method of casing while drilling by running a string 200 in a wellbore comprising a downhole swivel sub as disclosed herein above.
  • the downhole swivel sub comprising only one coupling member 107 according to the first embodiment disclosed herein above is connected between a first portion or top portion 202a of a casing string and a second portion or bottom portion 202b of the said casing string.
  • Figure 6 shows a schematic representation of a casing string including a first embodiment of the downhole swivel sub 100 wherein a top end (i.e. the first end of the first body) 103 is connected to an upper string portion 202a and a bottom end of the sub (i.e. the bottom end of the second body) 105 is connected to a lower string portion 202b.
  • the string 200 comprises advantageously a casing section 202 with a first end 205 directed towards the bottom of the wellbore, and a second end 206 directed towards the surface of the wellbore.
  • the string is a casing string extending from to surface of the wellbore.
  • the string While running the string including these two casing portions in the wellbore, the string is advantageously rotated for breaking the friction and the coupling member 107 of the downhole swivel sub 100 is set in its first position such that the lower casing portion 202b rotates with the whole string.
  • the transmission of torque from the upper string portion to the bottom string portion through the coupling member 107 of the downhole swivel sub 100 is needed to drill the formation.
  • the method of the present invention comprises the further steps of: drilling through a reservoir;
  • the packer 207, stage collar 208 are devices well known by the man skilled in the art.
  • the first end 205 of the casing 202 comprises a drilling tool 203, for example a drilling shoe or a drill bit that can be partially drilled, destroyed or removed.
  • a drilling tool 203 for example a drilling shoe or a drill bit that can be partially drilled, destroyed or removed.
  • the lower casing portion 202b is immobilized after a step of drilling through a depleted reservoir, wherein loss of drilling fluid causes a pressure drop in the annulus that collapse the formation upwards to the reservoir. Then, the step of moving the coupling member 107 to its second position, the step of cementation of the casing are performed as disclosed herein above.
  • a good cementation of an upper casing portion in a wellbore can be realized when the bottom portion of the casing portion has been immobilized for example by collapsing formation in the wellbore after drilling in a depleted reservoir.
  • the downhole swivel sub 100 is designed with an external surface devoid of moving parts which avoid accidental tripping of the apparatus and provides a good cementation around the downhole swivel sub.
  • the downhole swivel sub is further designed to provide a good tightness between the inside of the downhole swivel sub and the outside of the downhole swivel sub, which allows such a downhole swivel sub to be left in a wellbore during all the lifetime of the wellbore exploitation.
  • the first embodiment of the downhole swivel sub of the present invention could not be connected between two portions of a liner to be used in a method for cementing a liner.
  • a liner is generally connected to a work string through a release mechanism. Once the liner is cemented, the release mechanism is set up to release the work string from the liner. If the release mechanism fails to release the work string, a safety mechanism allows disconnection of the work string from the liner upon left hand rotation of the work string, i.e. the opposite direction of rotation than while the liner is run into the wellbore.
  • the first embodiment of the downhole swivel sub of the present invention is therefore destined for cementation of casings extending from the surface of the wellbore, wherein the downhole swivel sub should be simple to manufacture and wherein the movement of the coupling member back to its first position is prevented, such as to provide an efficient tightness of the casing.
  • a downhole swivel sub comprising a first coupling member and a second coupling member as described in the second embodiment of the downhole swivel sub presented herein above is connected between a first portion or top portion 202a of a casing string or liner and a second portion or bottom portion 202b of said casing string or liner.
  • Figure 8 shows a schematic representation of a string 200 comprising advantageously a casing section or a liner section 202 with a first end 205 directed towards the bottom of the wellbore, and a second end 206 directed towards the surface of the wellbore.
  • the second end 206 of the casing or liner 202 is connected to a workstring 201 by a release mechanism 204 that comprises a backup release mechanism (not shown) that can be actuated by rotating the string towards the reverse direction in case of failure of the primary release mechanism.
  • a release mechanism 204 that comprises a backup release mechanism (not shown) that can be actuated by rotating the string towards the reverse direction in case of failure of the primary release mechanism.
  • the string While running said string including these two casing portions or liner portions in the wellbore, the string is advantageously rotated for breaking the friction and the first coupling member 107 of the downhole swivel sub 100 is set in its first position such that the lower casing portion or the lower liner portion 202b rotates with the whole string.
  • the bottom of the string is terminated by a drill bit 203, the transmission of torque from the upper string portion to the bottom string portion through the first coupling member 107 of the downhole swivel sub 100 is needed to drill the formation.
  • the method of the present invention comprises the further steps of: drilling through a reservoir;
  • the packer 207, stage collar 208 and the release mechanism 204 including a backup release mechanism are devices well known by the man skilled in the art.
  • the release mechanism comprises a backup release mechanism (not shown) that can be actuated by rotating the string towards the reverse direction. While rotating the string towards the reverse direction, the second coupling member 108 of the downhole swivel sub engages the first body 101 of the swivel with the second body 102 which is immobilized in the wellbore, thereby preventing rotation of the upper casing portion or liner portion 202a and allowing disconnection of the workstring 201 from the casing or liner 202.
  • the first end 205 of the casing or liner 202 comprises a drilling tool 203, for example a drilling shoe or a drill bit that can be partially drilled, destroyed or removed.
  • the lower casing portion or the lower liner portion 202b is immobilized after a step of drilling through a depleted reservoir, wherein loss of drilling fluid causes a pressure drop in the annulus that collapse the formation upwards to the reservoir. Then, the step of moving the first coupling member 107 to its second position, the step of cementation of the casing or liner and the step of disconnection of the workstring 201 from the casing or liner 202 are performed as disclosed herein above.
  • the downhole swivel sub of the present invention and the method of casing while drilling by using such a downhole swivel sub allows a good cementation of an upper casing portion or liner portion in a wellbore when the bottom portion of the casing portion or liner portion has been immobilized for example by collapsing formation in the wellbore after drilling in a depleted reservoir.
  • the downhole swivel sub 100 is designed with an external surface devoid of moving parts which avoid accidental tripping of the apparatus and provides a good cementation around the downhole swivel sub.
  • the downhole swivel sub is further designed to provide a good tightness between the inside of the downhole swivel sub and the outside of the downhole swivel sub, which allows such a downhole swivel sub to be left in a wellbore during all the lifetime of the wellbore exploitation.

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Abstract

The present invention relates to a downhole swivel sub (100) for insertion in a string, the downhole swivel sub comprising : • - a first body (101) comprising a first end (103) and a second end (104); • - a second tubular body (102) enclosing the second end of the first body, the first body and the second body forming a bore (106); • - a coupling member (107) which, in a first position, engages the first body with the second body, and in a second position, disengages the second body from the first body; the said coupling member being fully enclosed in the second body and forming a chamber with the inner surface of the second body, said chamber being in fluidic communication with the external of the downhole swivel sub through a vent in the second body for allowing the movement of the coupling member from its first position towards its second position.

Description

Downhole swivel sub and method of running a string in a wellbore
Technical field
According to a first aspect, the present invention relates to a downhole swivel sub for insertion in a string to be run in a wellbore. More particularly, the downhole swivel sub comprises a coupling member for selectively locking the rotation of a first body relative to a second body. According to a second aspect of the invention, the present invention relates to a method wherein the downhole swivel sub is included in a casing while drilling string for cementing the casing string in a wellbore.
State of the art
In oil and gas field, the realization of a wellbore requires some steps wherein it is advantageous to rotate a first portion of a string relative to a second string portion. For example, the applicant has developed and commercialized a downhole swivel sub described in US patent 8511392 and a method using a downhole swivel sub for some operation in a wellbore as disclosed in US patent 8191639. Applicant's downhole swivel sub disclosed in US patent 8511392 comprises a mandrel connectable to a lower portion of a string and a housing surrounding a portion of the mandrel, the housing being connectable to an upper portion of the string. The mandrel and the housing comprise a set of coupling splines arranged on their external surface. A locking sleeve is arranged around the mandrel and the housing. The locking sleeve can be moved between a first and a second position around the mandrel and the housing. The locking sleeve comprises a set of coupling splines arranged in its internal surface and adapted to mate with the coupling splines of the mandrel and the housing. In the first position, the locking sleeve is secured to the housing by a shear pin and allows rotation of the housing relative to the mandrel. By applying a pressure differential between the bore of the downhole swivel sub and the annulus formed by the string and the wellbore, the locking sleeve moves to the second position and its coupling splines engages the coupling splines of the housing and the coupling splines of the mandrel so that the torque provided on the housing is transmitted to the mandrel. This downhole swivel sub is used for example in a method of running a string in a wellbore, wherein the bottom of the string comprises fragile elements that are not suitable for rotating. Such elements can be for example a liner, a screen or gravel pack assembly. Therefore, the string including such elements is deployed into the wellbore in a first step wherein the portion of the string above the downhole swivel sub is rotated while the portion of the string under the downhole swivel sub is not rotated. Rotation of the string breaks the friction between the string portion above the swivel and the wall of the wellbore, allowing the string to be deployed in deeper areas without damaging the fragile elements under the downhole swivel sub. When it is needed to disconnect a string section located under the downhole swivel sub, a hydraulic mechanism is actuated to release that string section. It can happen that such a release mechanism fails to operate, and in that case, a backup release mechanism provided under the downhole swivel sub is operated by rotating the string to a reverse direction. A pressure differential is applied between the bore of the downhole swivel sub and the annulus for moving the sliding sleeve to its second position, so that the downhole swivel sub gets locked and the string section under the swivel is allowed to rotate with the upper string section to allow the operation of the backup release mechanism.
Document US2014/299379 of the applicant discloses another downhole swivel sub which comprises a first tubular body and a second tubular body partially included in the first tubular body. A clutch is arranged between an inner shoulder in the first body and the end of the second tubular body which is inside the first body. The clutch allows the first body to rotate independently from the second body or to provide a reduction in torque from the first body to the second body. Optionally, a sliding sleeve is positioned around the first tubular body and around the second tubular body. The sliding sleeve comprises teeth arranged at the inner surface of the sleeve and adapted to mate with teeth provided at the outer surface of the first tubular body and second tubular body. The sliding sleeve is set up in a first position against an abutment at the outer surface of the second body, and around the second body, wherein the teeth of the sliding sleeve are disengaged from the teeth of the first tubular body, such that the first body can rotate independently from the second body or with a reduction in torque from the first body to the second body. In this first position, the sliding sleeve is locked to the second body by a shear pin and biased by a spring arranged around the first tubular body. A cover surrounds the spring, a portion of the first body and a portion of the sliding sleeve. A downhole tool or a liner that is not wished to rotate or a workstring portion comprising such downhole tool or liner is connected to the second body. When the rotation of the downhole tools or liner is required, a differential pressure is induced within the sub which induces an upwards movement of the sliding sleeve to a second position with sufficient force to break the shear pin. In this second position, the teeth of the sliding sleeve mate with the teeth of the first body and second body, and a locking dog provided in the sliding sleeve expands in a recess provided at the outer surface of the second body, to prevent further movement of the sliding sleeve back to its first position.
Some other steps of realization of a wellbore require rotating the whole string before unlocking the rotation of an upper string section from a lower string section. Document US patent 7011162 discloses a swivel apparatus comprising a top body, a bottom body and a hydraulically shiftable member that selectively allows the top body to be rotated with the bottom body when the shiftable member is in a first position and to rotate freely with respect to each other in one direction and rotate together in a second direction when the shiftable member is in a second position. The shiftable member is arranged around the top body and around the bottom body, with a portion of the shiftable member arranged inside a housing connected to the top body, and with a second portion of the shiftable member arranged outside of the housing. The swivel apparatus disclosed in that document is used in a method of completing a wellbore, and arranged in a running assembly including an expander tool and a running tool. The running assembly is enclosed in a liner, with the running tool mechanically connected to the liner. The running tool is located below the expander tool and the swivel apparatus is arranged between the running tool and the expander tool. When the liner is deployed into the wellbore, the whole string is rotated with the shiftable member in its first position. Then, after activation of the expander tool, the swivel apparatus is operated to move the shiftable member towards its second position, allowing the expander tool to rotate for expanding a portion of the liner to put the liner in contact with a preinstalled casing therearound, while the liner mechanically connected to the running tool is not rotating. After the liner portion has been expanded against the preinstalled casing therearound, the running tool has to be disconnected from the liner and the running assembly including the expander tool, the swivel apparatus and the running tool is removed from the wellbore. It can happen that the release mechanism for removing the running tool from the liner fails, and in that case, the string including the running assembly can be rotated to the left so that the torque is transferred through the swivel apparatus to the running tool for releasing the running tool from the liner. In the swivel apparatus disclosed in that document, the major portion of the shiftable member is easily accessible from the outside of the tool, for facilitating maintenance and resetting the shiftable member towards its first position when the running assembly has been removed from the wellbore. Also, the shiftable member is protected from accidental tripping since it is surrounded by the liner.
The development of the extended reach drilling requires new techniques for completing deviated wellbores extending over several kilometers. It is known that rotation of the casing string or liner during cementation is beneficial for the quality of the cementation and thus for the quality of the sealing of the wellbore. A method of cementation while rotating an upper casing string attached by a swivel to a lower casing string is presented in document US patent 4869323.
However, this document doesn't disclose any practical embodiment of a swivel for enabling the realization of this method. Particular requirements of tightness have to be met since the swivel is destined to be cemented in the wellbore and to hold high pressures during the lifetime of exploitation of the wellbore.
While drilling through different formation zones, the pressure in the annulus between the drill string and the wellbore may significantly vary from a first formation zone to a second formation zone. If a pressure drop occurs while drilling through a new formation zone, some formation zone may collapse on the drill string and stuck the drill string. Some methods are available for freeing the drill string, such as jarring methods, but they are less preferred as they are time consuming and may damage the drill string.
There is a need for a tool and method that could ensure a successful cementation of a casing above the casing section immobilized by the collapsed formation.
There is also a need for a swivel that can be used for various steps of realization of a wellbore including the steps of drilling and cementing a string portion while rotating the string portion. Summary of the invention
According to a first aspect, the present invention is related to a downhole swivel sub for insertion in a string, the downhole swivel sub comprising: a first tubular body comprising a first end and a second end;
- a second tubular body enclosing the second end of the first body, the first body and the second body forming a bore;
a coupling member which, in a first position, engages the first body with the second body, and in a second position, disengages the second body from the first body; the said coupling member being fully enclosed in the second body and forming a chamber with the inner surface of the second body, said chamber being in fluidic communication with the external of the downhole swivel sub through a vent in the second body for allowing the movement of the coupling member from its first position towards its second position.
Preferably, the said coupling member is configured to be moved to the second position by a differential of pressure between the inside of the downhole swivel sub and the outside of the downhole swivel sub.
Preferably, the said coupling member (107) comprises: a first coupling section mating with a first complementary coupling section (110) on the second end of the first body,
- -a second coupling section mating with a second complementary coupling section provided inside the second body.
Preferably, in the first position of the coupling member, the first coupling section and the second coupling section are maintained in engagement with the first complementary coupling section and second complementary coupling section, respectively, and, in the second position of the coupling member, the first coupling section and the second coupling section are maintained disengaged from the first complementary coupling section and second complementary coupling section, respectively. Preferably, the coupling member is locked in said first position by a shear pin, and locked in said second position by a latching mechanism.
Preferably, the said coupling member (107) comprises: - a first coupling section which is a set of teeth forming castellation adapted to mate with a complementary set of teeth provided on the second end of the first body, and; a second coupling section which is a set of teeth forming castellation adapted to mate with a complementary set of teeth provided inside the second body.
Preferably, the downhole swivel sub comprises a second coupling member that, while the first coupling member is set in its second position, allows rotation of the first body relative to the second body when the first body is rotated in a first direction and
engages the first body with the second body when the first body is rotated in a second direction. Preferably, the said second coupling member is a freewheel.
According to a second aspect, the present invention is related to a method of casing while drilling a wellbore by running a string comprising a casing section with a first end directed towards the bottom of the wellbore and a second end directed towards the entrance of the wellbore, the method comprising a step of connecting a first end of a downhole swivel sub as presented above, to a lower casing string portion of the casing section and a second end of the said downhole swivel sub to an upper casing string portion of the casing section.
Preferably, in the method, the casing section extends in the wellbore from the surface of the wellbore.
Preferably, in the method, the said first end of the string is provided by a drill bit, and the said coupling member forming the said chamber is kept in said first position during a step of the drilling of the wellbore. Preferably, in the method:
(i) the said coupling member is moved to said second position for disengaging the first body from the second tubular body while the lower casing portion is immobilized; and
(ii) the upper casing string section is rotated relative to the lower casing string section, for facilitating cement circulation during a further step of cementation.
Preferably, the method comprises a fu rther step of lowering a second string in the so cemented casing section, drilling the said first end of the string being provided with a d rillable drill bit, and drilling a second wellbore section. Preferably, in the method, the casing section is a casing or liner connected to a workstring through a release mechanism, said workstring being disconnected with the said release mechanism from the said casing section or liner after cementation of the said casing section or liner in the wellbore.
Preferably, the said release mechanism includes a backup release mechanism, and the said downhole swivel sub (100) comprises: a second coupling member that, while the first coupling member is set in its second position,
o allows rotation of the first body relative to the second body when the first body is rotated in a first direction and
o rotatably engages the first body with the second body when the first body is rotated in a second direction; in which method, if the said release mechanism fails to disconnect the said workstring from the casing section or liner section, the workstring is rotated according to the said second direction so as to actuate the said second coupling member and to engage the first body with the second body, thereby preventing rotation of the upper casing portion or liner portion and allowing disconnection of the workstring from the casing or liner by actuation of the backup release mechanism. Brief description of the drawings
Fig. 1A represents a longitudinal cross sectional view of a downhole swivel sub according to an embodiment of the present invention.
Fig. 2 represents an enlarged cross sectional view of a portion of the downhole swivel sub according to an embodiment of the present invention.
Fig. 3 represents a longitudinal cross sectional view of a coupling member of the downhole swivel sub according to an embodiment of the present invention.
Fig. 4 represents a longitudinal cross sectional view of a bottom portion of a second body of the downhole swivel sub, the portion being adapted for receiving a coupling member.
Figures 5a to 5c represent top views of various possible embodiments of a coupling member of the downhole swivel sub according to the present invention.
Fig. 6 represents a schematic view of an embodiment of a string including a first embodiment of the downhole swivel sub.
Fig. 7a represents a partial longitudinal cross sectional view of a second embodiment of a downhole swivel sub according to the present invention, wherein the downhole swivel sub further comprises a freewheel.
Fig. 7b represents a partial longitudinal cross section view of complementary to the view of the second embodiment of the downhole swivel sub presented in Fig. 7a.
Fig. 8 represents a schematic view of a string including a second embodiment of the downhole swivel sub.
Description of the invention
Figure 1 shows a first embodiment of a downhole swivel sub 100 according to the present invention. The downhole swivel sub 100 of the present invention is a multi-use tool that can be used in a method for drilling, in a method wherein two portions of a string have to be rotated relative to each other, in a step of cementation, and in a step of running a casing. The top half of figure 1 presents the downhole swivel sub in a first configuration (with the coupling member in its first, engaged, position), and the bottom half of figure 1 presents the downhole swivel sub in a second configuration (with the coupling member in its second, disengaged, position). The downhole swivel sub 100 comprises: a first body 101 comprising a first end 103 and a second end 104;
a second body 102 disposed coaxially to the first tubular body and enclosing the second end 104 of the first body 101, the first body 101 and the second body 102 enclosing a bore 106;
a coupling member 107 which, in a first position as presented in the top half of figure 1, engages the first body 101 with the second body 102 (such that the second body 102 rotates relative to the longitudinal axis of the downhole swivel sub together with the first body 101 upon rotation of the first body 101), and in a second position as presented in the bottom half of figure 1, disengages the second body 102 from the first body 101 (such that the first body 101 can rotate independently from the second body 102).
The coupling member 107 is fully enclosed in the second tubular body 102.
In this first embodiment of the downhole swivel sub, there is only one coupling member
107 for selectively coupling or uncoupling the rotation of the first body relative to the second body. Such a downhole swivel sub comprises a limited number of pieces, and is therefore cheap and easier to assemble. The first end 103 of the first body is destined to be connected to an upper casing portion extending from the surface of the wellbore.
The downhole swivel sub 100 according to the present invention can be advantageously connected between two casing portions and can be permanently cemented in a wellbore with the casing. Instead of having coupling members arranged at the external surface of the downhole swivel sub like in the downhole swivel subs of prior art, wherein the coupling members could be accidentally tripped or blocked by any irregular shape or collapsing formation in the borehole, the coupling member 107 is fully arranged inside the second body 102. Such an arrangement is made possible because the downhole swivel sub according to the present invention is advantageously destined for a single use.
According to a second aspect of the invention that will be discussed later herein below, the downhole swivel sub 100 is used in a method of casing a casing string in a wellbore wherein the downhole swivel sub is cemented with the casing string. Therefore there is no need to reset the coupling member 107 to its initial position and the accessibility of the coupling member 107 from the outside of the apparatus is not desirable. The design of the downhole swivel sub according to the present invention advantageously provides an external surface substantially regular and devoid of any axially moving parts. Such a downhole swivel sub is more suitable for being run into a wellbore and to be cemented in the wellbore.
A longitudinal cross sectional view of a first end portion 130 of the second body 102 including the first body 101 and the coupling member 107 is represented in figure 2. A longitudinal cross sectional view of the coupling member 107 is represented more in detail in figure 3, and the first end portion 130 of the second body 102 without the coupling member 107 and the first body 101 is represented in figure 4.
The coupling member 107 is initially in a first position as presented on the top side of figure 1 and of the right side of figure 2. The coupling member 107 has a first end comprising a first coupling section 109 mating with a first complementary coupling section 110 on the second end 104 of the first body 101, and a second coupling section 109' mating with a second complementary coupling section 110' provided inside the second body 102. In the first position of the coupling member 107, the first coupling section 109 and the second coupling section 109' are maintained in engagement with their respective first complementary coupling section 110 and second complementary coupling section 110'. In the second position of the coupling member 107, such as presented on the bottom side of figure 1 and on the left side of figure 2, the first coupling section 109 and the second coupling section 109' are maintained disengaged from their respective first complementary coupling section 110 and second complementary coupling section 110'.
Figures 2 and 3 shows longitudinal cross sectional view of a preferred embodiment of the coupling member 107. Figures 5a, 5b show top views of two possible embodiments of the coupling member, wherein: the first coupling section 109 is a set of teeth forming castellation adapted to mate with a complementary set of teeth 110 provided on the second end 104 of the first body 101, and; the second coupling section 109' is a set of teeth forming castellation adapted to mate with a complementary set of teeth 110' provided inside the second body 102.
Advantageously, each of the teeth of the first coupling section 109 and each of the teeth of the second coupling section 109' forms a single tooth as presented in figure 5a. This embodiment is easier to manufacture and provides better resistance to torque. Alternatively as presented in figure 5b, the teeth of the first coupling section 109 are offset from the teeth of the second coupling section 109'.
Figure 5c shows a top view of another alternative embodiment of a coupling member 107 wherein the first coupling section 109 is a set of teeth forming castellation adapted to mate with a complementary set of teeth provided on the second end 104 of the first body 101 and wherein the second coupling section is a polygonal coupling section 124 adapted to mate within a polygonal bore made in the second body 102.
Other alternatives in the aim to transmit the torque from the first body 101 to the second body 102 through the coupling member 107 can be envisaged by the man skilled in the art. Advantageously, the coupling member 107 is realized with a first coupling section 109 and a second coupling section 109' arranged side by side. In this manner, the torque is transmitted from the first body 101 to the second body 102 through a limited zone of the coupling member 107, ensuring the robustness of the coupling member 107, allowing arrangement of seals over a spread area between the external surface of the coupling member 107 and the internal surface 125 of the second body 102, and preserving those seals from rotation.
The coupling member 107 comprises a portion 152, for example a sleeve portion, connected to the second body by a sheer pin 122 and arranged such as to maintain the coupling member in its first position with the first coupling section 109 engaged with the first complementary coupling section 110 of the first body 101 and with the second coupling section 109' engaged with the second complementary coupling section 110' of the second body.
Alternatively, the coupling member 107 can be maintained against the first body 101 by a biasing mechanism such as a spring or Belleville washers.
In its first position, the coupling member 107 forms a chamber 120 with the inner surface 125 of the second body 102, the chamber 120 being in fluidic communication with the external of the downhole swivel sub 100 through a vent 121 in the second body 102 for allowing the movement of the coupling member 107 from its first position towards its second position.
The coupling member 107 can be moved to its second position by a differential of pressure between the inside of the downhole swivel sub and the outside of the downhole swivel sub, for example by dropping a dart or a ball that get captured by a dart catcher assembly or a ball seat (not shown) arranged below the downhole swivel sub as well known in the art, or simply by increasing the fluid flow pressure and pushing the piston differential area 111.
Alternatively, the man skilled in the art can imagine a system wherein the coupling member is moved to the second position by a motor actuated upon detection of a signal, for example a RFID signal, by a detector.
In the second position of the coupling member 107, the chamber 120 has a decreased volume and the coupling member 107 is further locked on its second position by a latching mechanism 123, for example a latching ring or a set of latching pins that enter into a cavity 134 formed at the external surface of the coupling member 107.
As presented in figure 2 and more in detail in figure 3, the coupling member 107 comprises a first portion 112 of larger external diameter, a second portion 113 of intermediate external diameter forming a first shoulder 126 with the first portion 112, and a third portion 114 of smaller external diameter forming a second shoulder 127 with the second portion 113. A tubular sealing member 135 overlaps a part of the first portion 112 of the coupling member 107, the first shoulder 126 and a part of the second portion 113 of the coupling member 107. The first portion 112 is provided with a first external sealing surface 112' formed by the part of the tubular sealing member 135 overlapping the first portion 112, and two spring energized seals 136, 136'arranged on both sides of a first annular ridge 137 protruding from the first portion 112. The first annular ridge 137 comprises a recess including a seal 138, preferably a rubber energized ring with a low friction contacting surface, such as for example a glyd® ring. The second portion 113 is provided with a second external sealing surface 113' formed by the part of the tubular sealing member 135 overlapping the second portion 113 and by two other spring energized seals 139, 139' arranged on both sides of a second annular ridge 140 protruding from the second portion 113. The second annular ridge 140 comprises also a recess including a seal 141, preferably a rubber energized ring with a low friction contacting surface, such as for example a glyd® ring.
As presented in figure 2 and more in detail in figure 4, the first end portion 130 of the second body 102 comprises three inner wall portions 115, 116, 117, of inner diameter mating with the coupling member 107. A first inner wall portion 115 in tight contact with the first sealing surface 112' of the coupling member 107, a second inner wall portion 116 in tight contact with the second sealing surface 113' of the coupling member 107, and a third inner wall portion 117 is in contact with the third portion 114 of the coupling member 107. The first inner wall portion 115 forms a first shoulder 128 with the second inner wall portion 116 that forms a second shoulder 129 with the third inner wall portion 117.
The chamber 120 is formed between the first inner wall portion 115 of the second body 102, the first shoulder 128 of the second body 102, the sealing surface 113' of the coupling member 107 and the part of the tubular sealing member 135 covering the first shoulder 126 of the coupling member. The vent 121 is arranged besides the first shoulder 128 and extends from the inner wall portion 115 of the second body towards the external surface of the second body.
The seal arrangement described above ensures the tightness of the chamber 120 from the bore 106 of the downhole swivel sub for any position of the coupling member 107.
As presented in Figure 1, the second body 102 comprises a second end portion 131 with an inner cavity 143 enclosing an annular ridge 142 protruding from the first body 101 and a set of thrust bearings 144 arranged on both sides of the annular ridge 142 of the first body 101. The second end portion 131 of the second body 102 comprises a seal 145, for example an O-ring or a rubber energized plastic faced seal in tight contact with the first body 101.
The second body further comprises an intermediate portion 132 adjacent to the second end portion 131. The first intermediate portion 132 comprises a set of inner grooves each one including a seal 146, preferably a rubber energized ring with a low friction contacting surface, such as for example a glyd® ring. This set of seals ensures the tightness of the first body 101 against the second body 102, with reduced friction since the first body 101 is destined to rotate within the second body 102. Figure 7A and figure 7B show two complementary parts of a second embodiment of a downhole swivel sub 100 according to the present invention. The downhole swivel sub of the second embodiment comprises similar features as the downhole swivel sub of the first embodiment described above. The downhole swivel sub 100 of the present invention is a multiuse tool that can be used in a method for drilling, in a method wherein two portions of a string have to be rotated relative to each other, in a step of cementation, in a step of running a casing or a liner, and/or in a step of disconnection of an upper portion of a string. The right side of both figures 7A and 7B presents the downhole swivel sub in a first configuration, and the left side of both figures 7A and 7B presents the downhole swivel sub in a second configuration. The downhole swivel sub 100 comprises: a first body 101 comprising a first end 103 and a second end 104;
a second body 102 disposed coaxially to the first tubular body and enclosing the second end 104 of the first body 101, the first body 101 and the second body 102 forming a bore 106;
a first coupling member 107 which, in a first position as presented in the right side of figure 7B, engages the first body 101 with the second body 102, and in a second position as presented in the left side of figure 7B, disengages the second body 102 from the first body 101; and
a second coupling member 108 that, while the first coupling member 107 is set in its second position:
o allows rotation of the first body 101 relative to the second body 102 when the first body is rotated in a first direction and
o engages the first body 101 with the second body 102 when the first body 101 is rotated in a second direction.
The said first direction is advantageously the same direction of rotation as for d rilling, and the said second direction is the direction opposite to the said first direction.
The first coupling member 107 is similar to the coupling member described for the first embodiment of the swivel sub herein above.
As presented in Figure 7A and 7B, the second body 102 is subdivided in: a first end portion 130 comprising the coupling member 107 and the end 104 of the first body,
a second end portion 131 opposite to the first end portion 130,
a first intermediate portion 132 adjacent to the second end portion 131, and a second intermediate portion 133 between the first intermediate portion 132 and the first end portion 130.
The first end portion 130 is similar to the one described for the first embodiment described above. The second end portion 131 of the second body 102 comprises a with an inner cavity 143 enclosing an annular ridge 142 protruding from the first body lOland a set of thrust bearings 144 arranged on both sides of the annular ridge 142 of the first body 101. The second end portion 131 of the second body 102 comprises a seal 145, for example an O-ring or a rubber energized plastic faced seal in tight contact with the first body 101.
The second body further comprises a first intermediate portion 132 adjacent to the second end portion 131. The first intermediate portion 132 comprises a set of inner grooves each one including a seal 146, preferably a rubber energized ring with a low friction contacting surface, such as for example a glyd® ring. This set of seals ensures the tightness of the first body 101 against the second body 102, with reduced friction since the first body 101 is destined to rotate within the second body 102.
The second body 102 comprises a second intermediate portion 133 between the first intermediate portion 132 and the first end portion 130. The second intermediate portion 133 comprises an inner cavity 147 including the second coupling member 108 arranged between the second body 102 and the first body 101 to selectively allow rotation of the first body 101 relative to the second body 102 when the first body 101 rotates according to a first direction while the first coupling member 107 is disengaged from the first body 101, and to transmit the torque of the first body 101 to the second body 102 when the first body 101 rotates according to a second direction while the first coupling member 107 is disengaged from the first body 101.
Preferably, the second coupling member 108 is a freewheel. According to an embodiment of the present invention represented in figures 7A and 7B, a first one-way clutch body 148 is fixed around the first body 101 and the second coupling member 108 is a second one-way clutch body that is biased against the first one-way clutch body 108 by a spring 151. The second clutch body or in other words the second coupling member 108 comprises a coupling section 149 for transmitting the torque of the first body to the second body which also comprises an inner coupling section 150. The coupling section 149 of the second coupling member 108 can be a polygonal coupling section mating with an inner coupling portion 150 of the second body 102 having a polygonal inner cross section, or alternatively, a set of splines or teeth mating with a complementary set of splines or teeth arranged at on the inner surface of the second body 102.
The first one-way clutch body 148 and the second one-way clutch body 108 both comprise a saw tooth profile mating with each other.
Alternatively, a sprag clutch is arranged in the cavity between the first body 101 and the second body 102. Other freewheel alternatives as known by the man skilled in the art are possible.
According to a second aspect, the present invention relates to a method of casing while drilling by running a string 200 in a wellbore comprising a downhole swivel sub as disclosed herein above.
In a first embodiment of the method, the downhole swivel sub comprising only one coupling member 107 according to the first embodiment disclosed herein above is connected between a first portion or top portion 202a of a casing string and a second portion or bottom portion 202b of the said casing string. Figure 6 shows a schematic representation of a casing string including a first embodiment of the downhole swivel sub 100 wherein a top end (i.e. the first end of the first body) 103 is connected to an upper string portion 202a and a bottom end of the sub (i.e. the bottom end of the second body) 105 is connected to a lower string portion 202b. The string 200 comprises advantageously a casing section 202 with a first end 205 directed towards the bottom of the wellbore, and a second end 206 directed towards the surface of the wellbore. Preferably, in this first embodiment, the string is a casing string extending from to surface of the wellbore.
While running the string including these two casing portions in the wellbore, the string is advantageously rotated for breaking the friction and the coupling member 107 of the downhole swivel sub 100 is set in its first position such that the lower casing portion 202b rotates with the whole string. In a preferred embodiment of the method, wherein the bottom of the string is terminated by a drill bit 203, the transmission of torque from the upper string portion to the bottom string portion through the coupling member 107 of the downhole swivel sub 100 is needed to drill the formation.
Preferably, the method of the present invention comprises the further steps of: drilling through a reservoir;
plugging the bottom of the lower casing portion 202b;
inflating a packer 207 in the lower casing portion 202b to seal the annulus formed between the wellbore and the string from the reservoir;
opening a stage collar 208 arranged upwards from the packer 207;
moving the coupling member 107 of the downhole swivel sub 100 towards its second position;
flowing cement through the bore of the string, the port of the stage collar 208 and the annulus while rotating the part of the string located upwards the downhole swivel sub 100;
closing the ports 209 of the stage collar 208.
The packer 207, stage collar 208 are devices well known by the man skilled in the art.
Preferably, the first end 205 of the casing 202 comprises a drilling tool 203, for example a drilling shoe or a drill bit that can be partially drilled, destroyed or removed.
Preferably the lower casing portion 202b is immobilized after a step of drilling through a depleted reservoir, wherein loss of drilling fluid causes a pressure drop in the annulus that collapse the formation upwards to the reservoir. Then, the step of moving the coupling member 107 to its second position, the step of cementation of the casing are performed as disclosed herein above.
With the first embodiment of the downhole swivel sub of the present invention and the first embodiment of the method using such a downhole swivel sub, a good cementation of an upper casing portion in a wellbore can be realized when the bottom portion of the casing portion has been immobilized for example by collapsing formation in the wellbore after drilling in a depleted reservoir. The downhole swivel sub 100 is designed with an external surface devoid of moving parts which avoid accidental tripping of the apparatus and provides a good cementation around the downhole swivel sub. The downhole swivel sub is further designed to provide a good tightness between the inside of the downhole swivel sub and the outside of the downhole swivel sub, which allows such a downhole swivel sub to be left in a wellbore during all the lifetime of the wellbore exploitation.
The first embodiment of the downhole swivel sub of the present invention could not be connected between two portions of a liner to be used in a method for cementing a liner. A liner is generally connected to a work string through a release mechanism. Once the liner is cemented, the release mechanism is set up to release the work string from the liner. If the release mechanism fails to release the work string, a safety mechanism allows disconnection of the work string from the liner upon left hand rotation of the work string, i.e. the opposite direction of rotation than while the liner is run into the wellbore. Since the downhole swivel sub is set up in a configuration allowing the rotation of the first body relative to the second body, there is no torque available for allowing disconnection of the work string from the liner. The first embodiment of the downhole swivel sub of the present invention is therefore destined for cementation of casings extending from the surface of the wellbore, wherein the downhole swivel sub should be simple to manufacture and wherein the movement of the coupling member back to its first position is prevented, such as to provide an efficient tightness of the casing.
In a second embodiment of the method, a downhole swivel sub comprising a first coupling member and a second coupling member as described in the second embodiment of the downhole swivel sub presented herein above is connected between a first portion or top portion 202a of a casing string or liner and a second portion or bottom portion 202b of said casing string or liner. Figure 8 shows a schematic representation of a string 200 comprising advantageously a casing section or a liner section 202 with a first end 205 directed towards the bottom of the wellbore, and a second end 206 directed towards the surface of the wellbore. Preferably, the second end 206 of the casing or liner 202 is connected to a workstring 201 by a release mechanism 204 that comprises a backup release mechanism (not shown) that can be actuated by rotating the string towards the reverse direction in case of failure of the primary release mechanism.
While running said string including these two casing portions or liner portions in the wellbore, the string is advantageously rotated for breaking the friction and the first coupling member 107 of the downhole swivel sub 100 is set in its first position such that the lower casing portion or the lower liner portion 202b rotates with the whole string. Preferably, the bottom of the string is terminated by a drill bit 203, the transmission of torque from the upper string portion to the bottom string portion through the first coupling member 107 of the downhole swivel sub 100 is needed to drill the formation.
Preferably, the method of the present invention comprises the further steps of: drilling through a reservoir;
plugging the bottom of the lower casing portion 202b;
inflating a packer 207 in the lower casing portion 202b to seal the annulus formed between the wellbore and the string from the reservoir;
- opening a stage collar 208 arranged upwards from the packer 207;
moving the first coupling member 107 of the downhole swivel sub 100 towards its second position;
flowing cement through the bore of the string, the port of the stage collar 208 and the annulus while rotating the part of the string located upwards the downhole swivel sub 100;
closing the ports 209 of the stage collar 208;
actuating the release mechanism 204 to disconnect the workstring from the liner section or casing section.
The packer 207, stage collar 208 and the release mechanism 204 including a backup release mechanism are devices well known by the man skilled in the art.
In the case wherein the release mechanism 204 fails to disconnect the workstring from the liner section or casing section, the release mechanism comprises a backup release mechanism (not shown) that can be actuated by rotating the string towards the reverse direction. While rotating the string towards the reverse direction, the second coupling member 108 of the downhole swivel sub engages the first body 101 of the swivel with the second body 102 which is immobilized in the wellbore, thereby preventing rotation of the upper casing portion or liner portion 202a and allowing disconnection of the workstring 201 from the casing or liner 202. In a preferred embodiment of the method of the present invention, the first end 205 of the casing or liner 202 comprises a drilling tool 203, for example a drilling shoe or a drill bit that can be partially drilled, destroyed or removed.
Preferably the lower casing portion or the lower liner portion 202b is immobilized after a step of drilling through a depleted reservoir, wherein loss of drilling fluid causes a pressure drop in the annulus that collapse the formation upwards to the reservoir. Then, the step of moving the first coupling member 107 to its second position, the step of cementation of the casing or liner and the step of disconnection of the workstring 201 from the casing or liner 202 are performed as disclosed herein above.
The downhole swivel sub of the present invention and the method of casing while drilling by using such a downhole swivel sub allows a good cementation of an upper casing portion or liner portion in a wellbore when the bottom portion of the casing portion or liner portion has been immobilized for example by collapsing formation in the wellbore after drilling in a depleted reservoir. The downhole swivel sub 100 is designed with an external surface devoid of moving parts which avoid accidental tripping of the apparatus and provides a good cementation around the downhole swivel sub. The downhole swivel sub is further designed to provide a good tightness between the inside of the downhole swivel sub and the outside of the downhole swivel sub, which allows such a downhole swivel sub to be left in a wellbore during all the lifetime of the wellbore exploitation.

Claims

Claims
Downhole swivel sub (100) for insertion in a string, the downhole swivel sub comprising : a first body (101) comprising a first end (103) and a second end (104);
a second tubular body (102) enclosing the second end (104) of the first body (101), the first body (101) and the second body (102) forming a bore (106);
a coupling member (107) which, in a first position, engages the first body (101) with the second body (102), and in a second position, disengages the second body (102) from the first body (101); the said coupling member (107) being fully enclosed in the second body (102) and forming a chamber (120) with the inner surface (120) of the second body (102), said chamber (120) being in fluidic communication with the external of the downhole swivel sub (100) through a vent (121) in the second body (102) for allowing the movement of the coupling member (107) from its first position towards its second position.
Downhole swivel sub according to claim 1, wherein the said coupling member (107) is configured to be moved to the second position by a differential of pressure between the inside of the downhole swivel sub and the outside of the downhole swivel sub.
Downhole swivel sub according to claim 1 or 2, wherein the said coupling member (107) comprises:
a first coupling section (109) mating with a first complementary coupling section (110) on the second end (104) of the first body (101),
-a second coupling section (109') mating with a second complementary coupling section (110') provided inside the second body (102).
Downhole swivel sub according to any one of the preceding claims, wherein, in the first position of the coupling member (107), the first coupling section (109) and the second coupling section (109') are maintained in engagement with the first complementary coupling section (110) and second complementary coupling section (110'), respectively, and, in the second position of the coupling member (107), the first coupling section (109) and the second coupling section (109') are maintained disengaged from the first complementary coupling section (110) and second complementary coupling section (110'), respectively.
Downhole swivel sub according to any one of the preceding claims, wherein the coupling member (107) is locked in said first position by a sheer pin (122), and locked in said second position by a latching mechanism (123).
Downhole swivel sub according to any one of the preceding claims, wherein the said coupling member (107) comprises : a first coupling section (109) which is a set of teeth forming castellation adapted to mate with a complementary set of teeth (110) provided on the second end (104) of the first body 101, and;
a second coupling section (109') which is a set of teeth forming castellation adapted to mate with a complementary set of teeth (110') provided inside the second body (102).
Downhole swivel sub according to any one of the preceding claims, comprising a second coupling member (108) that, while the first coupling member (107) is set in its second position,
allows rotation of the first body (101) relative to the second body (102) when the first body is rotated in a first direction and
engages the first body (101) with the second body (102) when the first body (101) is rotated in a second direction.
8. Downhole swivel sub according to claim 7, wherein the said second coupling member (108) is a freewheel.
9. Method of casing while drilling a wellbore by running a string (200) comprising a casing section (202) with a first end (205) directed towards the bottom of the wellbore and a second end (206) directed towards the entrance of the wellbore, the method comprising a step of connecting a first end (105) of a downhole swivel sub (100) according to any one of the claims 1 to 8, to a lower casing string portion (202b) of the casing section (202) and a second end (103) of the said downhole swivel sub (100) to an upper casing string portion (202a) of the casing section (202).
10. Method according to claim 9, wherein the casing section (202) extends in the wellbore from the surface of the wellbore.
11. Method according to claim 9 or 10, wherein the said first end (205) of the string is provided by a drill bit (203), and wherein the said coupling member (107) forming the said chamber (120) is kept in said first position during a step of the drilling of the wellbore.
12. Method according to any one of the claims 9 to 11, wherein:
(i) the said coupling member (107) is moved to said second position for disengaging the first body (101) from the second tubular body (102) while the lower casing portion (202b) is immobilized; and
(ii) the upper casing string section (202a) is rotated relative to the lower casing string section (202b), for facilitating cement circulation during a further step of cementation.
13. Method according to claim 12, comprising a further step of lowering a second string in the so cemented casing section, drilling the said first end of the string being provided with a drillable drill bit, and drilling a second wellbore section.
14. Method according to any one of claims 9 to 13, wherein the casing section (202) is a casing or liner connected to a workstring th rough a release mechanism (204), said workstring being disconnected with the said release mechanism from the said casing section or liner after cementation of the said casing section or liner in the wellbore.
15. Method according to claim 14, wherein the said release mechanism (204) includes a backup release mechanism, and wherein the said downhole swivel sub (100) comprises : - a second coupling member (108) that, while the first coupling member (107) is set in its second position,
o allows rotation of the first body (101) relative to the second body (102) when the first body is rotated in a first direction and
o rotatably engages the first body (101) with the second body (102) when the first body (101) is rotated in a second direction; in which method, if the said release mechanism (204) fails to disconnect the said workstring (201) from the casing section or liner section (202), the workstring (201) is rotated according to the said second direction so as to actuate the said second coupling member (108) and to engage the first body (101) with the second body (102), thereby preventing rotation of the upper casing portion or liner portion (202a) and allowing disconnection of the workstring (201) from the casing or liner (202) by actuation of the backup release mechanism.
PCT/EP2015/077939 2014-11-28 2015-11-27 Downhole swivel sub and method of running a string in a wellbore WO2016083582A1 (en)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
EP14195546.8 2014-11-28
EP14195546 2014-11-28
EP15155271 2015-02-16
EP15155271.8 2015-02-16

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WO2018122558A1 (en) * 2016-12-28 2018-07-05 Sudelac Limited Downhole swivel tool
US10781665B2 (en) 2012-10-16 2020-09-22 Weatherford Technology Holdings, Llc Flow control assembly

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US6082457A (en) * 1997-02-25 2000-07-04 Shell Oil Company Method of using a drill string tool
US7011162B2 (en) 2002-11-14 2006-03-14 Weatherford/Lamb, Inc. Hydraulically activated swivel for running expandable components with tailpipe
US8191639B2 (en) 2005-04-15 2012-06-05 Tercel Oilfield Products Uk Limited Downhole swivel sub
US20140196900A1 (en) * 2013-01-13 2014-07-17 Weatherford/Lamb, Inc. Method and apparatus for sealing tubulars
US20140299379A1 (en) 2011-07-15 2014-10-09 Tercel Oilfield Products Uk Limited Down-Hole Swivel Sub

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US4869323A (en) 1988-02-12 1989-09-26 Standard Alaska Production Company Cementing and rotating an upper well casing attached by swivel to a lower casing
US6082457A (en) * 1997-02-25 2000-07-04 Shell Oil Company Method of using a drill string tool
US7011162B2 (en) 2002-11-14 2006-03-14 Weatherford/Lamb, Inc. Hydraulically activated swivel for running expandable components with tailpipe
US8191639B2 (en) 2005-04-15 2012-06-05 Tercel Oilfield Products Uk Limited Downhole swivel sub
US8511392B2 (en) 2005-04-15 2013-08-20 Tercel Oilfield Products Uk Limited Downhole swivel sub
US20140299379A1 (en) 2011-07-15 2014-10-09 Tercel Oilfield Products Uk Limited Down-Hole Swivel Sub
US20140196900A1 (en) * 2013-01-13 2014-07-17 Weatherford/Lamb, Inc. Method and apparatus for sealing tubulars

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10781665B2 (en) 2012-10-16 2020-09-22 Weatherford Technology Holdings, Llc Flow control assembly
WO2018122558A1 (en) * 2016-12-28 2018-07-05 Sudelac Limited Downhole swivel tool
US11401764B2 (en) 2016-12-28 2022-08-02 Sudelac Limited Downhole swivel tool

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