A well construction method in which a drilled bore (106) is lined with a plurality of successively smaller diameter sections of bore-lining tubing including casing sections (108, 110, 112) and a liner section (120). A liner (120) is provided with an inner string (140) extending to a distal end of the liner (120). The liner (120) and the inner string (140) are run into a distal section of a drilled bore (106). Settable material (126a) is pumped from surface through the inner string (140) and through the distal end of the liner (120) to partially fill an outer annulus (124) surrounding the liner (120). Fluid displaced from the outer annulus (124) and a portion of the settable material (126a) is permitted to flow from the outer annulus (124) through a port (132) in the liner (120) and into an inner annulus (152) between the inner string (140) and the liner (120).
DOWNHOLE SEALING APPARATUSDownhole sealing apparatus (10) for location in a downhole tubular (16) comprises a ball (12) and a downhole seat (14). The ball (12) may comprise a rigid core (28) and a deformable covering (30). The ball (12) is translatable downhole towards the seat (14), the ball and the seat having an open first configuration and a sealing second configuration. In the open first configuration the ball and seat are spaced apart such that fluid may flow through the seat (14). In the sealing second configuration the ball and the seat are in sealing engagement and the ball (12) is deformed to maintain the sealing engagement with the seat (14) in response to a differential pressure acting in a first axial direction and in response to a differential pressure acting in an opposite second axial direction.
An offshore method comprises providing an elongate support string (18) for extending between a mobile offshore drilling unit (10) and a seabed location (19). The string has an upper portion (40a) and a lower portion (40b), and an articulated joint (200) is provided between the upper portion (40a) and the lower portion (40b). The provision of the articulated joint (200) maintains the lower portion (40b) of the elongate support string in a substantially vertical orientation and increases the safe operating radius of the mobile offshore drilling unit (10) or increases the speed at which the unit may transit through the sea with objects suspended via the elongate support string (18).
E21B 19/09 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods specially adapted for drilling underwater formations from a floating support using heave compensators supporting the drill string
An offshore method comprises providing an elongate support string (18) for extending between a mobile offshore drilling unit (10) and a seabed location (19). The string has an upper portion (40a) and a lower portion (40b), and an articulated joint (200) is provided between the upper portion (40a) and the lower portion (40b). The provision of the articulated joint (200) maintains the lower portion (40b) of the elongate support string in a substantially vertical orientation and increases the safe operating radius of the mobile offshore drilling unit (10) or increases the speed at which the unit may transit through the sea with objects suspended via the elongate support string (18).
E21B 19/09 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods specially adapted for drilling underwater formations from a floating support using heave compensators supporting the drill string
A coupling (126) connects an inner string (124) to a lower end of a bore-lining tubing, such as a liner (118). The coupling (126) includes a catcher (160) and may be provided in combination with at least one member for translating through the inner string (124) and landing in the catcher (160). The member may be an occluding member, such as a ball (136) for 10 occluding a flow passage through the coupling (126).
E21B 43/10 - Setting of casings, screens or liners in wells
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes using plugs for isolating cement chargePlugs therefor
E21B 41/00 - Equipment or details not covered by groups
A coupling (126) connects an inner string (124) to a lower end of a bore-lining tubing, such as a liner (118). The coupling (126) includes a catcher (160) and may be provided in combination with at least one member for translating through the inner string (124) and landing in the catcher (160). The member may be an occluding member, such as a ball (136) for 10 occluding a flow passage through the coupling (126).
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes using plugs for isolating cement chargePlugs therefor
E21B 43/10 - Setting of casings, screens or liners in wells
A method of locating bore-lining tubing, such as a liner (120), in a drilled bore (106) comprises selecting a buoyant material, such as air (138), having a density lower than the density of an ambient fluid, such as well fluid (180, 182). The buoyant material (138) and an inner tubing (140) are located within the bore-lining tubing (120) with the inner tubing (140) extending from a distal end of the bore-lining tubing to a proximal end of the bore-lining tubing. The inner tubing (140) is sealed to the distal end of the bore-lining tubing (120) and to a portion of the bore-lining tubing (120) spaced from the distal end to define an inner annulus (152) between the inner tubing (140) and the bore-lining tubing (120). A volume of the buoyant material (138) is retained within the inner annulus (152). An assembly (168) comprising the inner tubing (140) and the bore-lining tubing (120) and containing the volume of buoyant material (138) is run into a drilled bore (106). Fluid (126a) may be flowed through the inner tubing (140) and into an outer annulus (124) surrounding the bore-lining tubing (120).
A method of locating bore-lining tubing, such as a liner (120), in a drilled bore (106) comprises selecting a buoyant material, such as air (138), having a density lower than the density of an ambient fluid, such as well fluid (180, 182). The buoyant material (138) and an inner tubing (140) are located within the bore-lining tubing (120) with the inner tubing (140) extending from a distal end of the bore-lining tubing to a proximal end of the bore-lining tubing. The inner tubing (140) is sealed to the distal end of the bore-lining tubing (120) and to a portion of the bore-lining tubing (120) spaced from the distal end to define an inner annulus (152) between the inner tubing (140) and the bore-lining tubing (120). A volume of the buoyant material (138) is retained within the inner annulus (152). An assembly (168) comprising the inner tubing (140) and the bore-lining tubing (120) and containing the volume of buoyant material (138) is run into a drilled bore (106). Fluid (126a) may be flowed through the inner tubing (140) and into an outer annulus (124) surrounding the bore-lining tubing (120).
A well construction method, and corresponding apparatus, in which a drilled bore (106) is lined with a plurality of successively smaller diameter sections of bore-lining tubing includes at least one casing (108, 110, 112) and at least one liner (120). The well construction method comprises: drilling a final section of a bore (106) to intersect a hydrocarbon-bearing formation (130); providing a shoe (134) at a distal end of a liner and a running tool (150) at a proximal end of the liner, and coupling an inner string (140) between the shoe (134) and the running tool (150); running the liner (120) into the final section of the bore (106) such that the liner extends into the hydrocarbon-bearing formation (130); pumping a settable material (116) from surface (104), through the inner string (140), and through the shoe (134) to at least partially fill an outer annulus (114) surrounding the liner (120); and retrieving the inner string (140) and the running tool (150).
A method of conditioning a well bore featuring an annulus (50) between a bore-lining tubing (20) and a surrounding bore wall (110) comprises pumping conditioning fluid through an inner tubing (10) located within the bore-lining tubing (20) and into a portion of the well bore containing the bore-lining tubing to affect the temperature of the portion of the well bore containing the bore-lining tubing. The annulus (50) between the bore-lining tubing (20) and the surrounding bore wall (110) is at least partially filled with settable material (54). The affected temperature of the portion of the well bore containing the bore-lining tubing influences the setting of the settable material. For example, heating the bore may accelerate setting of the material, while cooling the bore may retard setting of the material.
Downhole apparatus comprises: a tubular body for mounting on an inner tubing string (10); a first flow port (24); a second flow port (12a); and a connector (68) associated with the tubular body (10) and operable to at least one of engage with and disengage from a lower end (22) of a bore-lining tubing string (20). The apparatus has a first configuration in which the first flow port (24) is open and the second flow port (12a) is closed, whereby a settable material (54) may be pumped in a first direction (56) downwards through the tubular body, through the connector, and through the first flow port, and a second configuration in which the first flow port (24) is closed and the second flow port (12a) is open, whereby a fluid may be pumped in the first direction (58) downwards through the tubular body (10), exit the tubular body through the second flow port (12a), and then flow in a second direction upwards and externally of the tubular body.
A method of conditioning a well bore featuring an annulus (50) between a bore-lining tubing (20) and a surrounding bore wall (110) comprises pumping conditioning fluid through an inner tubing (10) located within the bore-lining tubing (20) and into a portion of the well bore containing the bore-lining tubing to affect the temperature of the portion of the well bore containing the bore-lining tubing. The annulus (50) between the bore-lining tubing (20) and the surrounding bore wall (110) is at least partially filled with settable material (54). The affected temperature of the portion of the well bore containing the bore-lining tubing influences the setting of the settable material. For example, heating the bore may accelerate setting of the material, while cooling the bore may retard setting of the material.
Downhole apparatus comprises: a tubular body for mounting on an inner tubing string (10); a first flow port (24); a second flow port (12a); and a connector (68) associated with the tubular body (10) and operable to at least one of engage with and disengage from a lower end (22) of a bore-lining tubing string (20). The apparatus has a first configuration in which the first flow port (24) is open and the second flow port (12a) is closed, whereby a settable material (54) may be pumped in a first direction (56) downwards through the tubular body, through the connector, and through the first flow port, and a second configuration in which the first flow port (24) is closed and the second flow port (12a) is open, whereby a fluid may be pumped in the first direction (58) downwards through the tubular body (10), exit the tubular body through the second flow port (12a), and then flow in a second direction upwards and externally of the tubular body.
An apparatus for transferring rotational torque from a work string to a subsea infrastructure, said apparatus comprising a first connection (1) for receiving the work string; a second connection (6) for receiving the subsea infrastructure tooling; a joint seat (5) located between the first connection (1) and the second connection (6); a joint body (3) provided on the joint seat (5), wherein the joint body (3) is connected to the second connection (8) and wherein the joint body (3) can articulate freely within the joint seat (5); and means for transferring rotational torque from the first connection (1) to the joint body (3) and subsequently to the second connection (6).
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