Toolstring for setting a tubular equipment in a well tubing and method for setting the tubular equipment

Abstract

A tool string (1) comprising an engaging tool (6) configured to connect a tubular equip- ment (74) to the tool string (1), wherein: - the tool string (1) comprises in sequence from a first end (12) towards a second end (14) the engaging tool (6), a tractor (3) and a gripping tool (5); - the first end (12) is positioned uphole compared to the second end (14); and - the engaging tool (6) is configured to connect to the tubular equipment (74) in an up- hole end of the tubular equipment (74) Methods for using the tool string (1) are de- scribed as well.

Description

[0001] TOOLSTRING FOR SETTING A TUBULAR EQUIPMENT IN A WELL TUBING AND METHOD

[0002] FOR SETTING THE TUBULAR EQUIPMENT

[0003] The invention relates to a tool string comprising an engaging tool configured to connect a tubular equipment to the tool string and a method for sluicing the tool string and the tubular equipment into a wellbore or out of the wellbore.

[0004] In the oil and gas exploration and production industry, well intervention operations may be performed at various times during the lifetime of a well. In some cases, a tubular equipment needs to be installed into or removed from a deviated portion of the wellbore. A tool string is then used for conveying and installing or removing the tubular equipment inside the wellbore. The tool string connected to the tubular equipment form a string.

[0005] A sluice, often termed a "lubricator", is typically used for sluicing the string into or out of the wellbore. When the string is placed inside the sluice, pressure testing and qualification of the sluice and the pressure control equipment are performed. The string then enters the wellbore after a valve arrangement is opened to connect the inside of the sluice to the wellbore, allowing the string to safely enter the wellbore. The valve arrangement is often termed a "x-mas tree" or a blowout preventor (BOP). After completion of an operation in the wellbore, the string is brought back into the sluice before the valve arrangement is closed, and with that disconnecting the sluice from the wellbore. The length of the sluice can be a significant limitation on the total length of the string that can be accommodated. In some cases, it is required to split the tubular equipment into multiple members that need to be run into the wellbore by a plurality of runs. In other cases, it may not be possible to fit the string within the sluice therefore making it impossible to perform the operation. Sluices may in some cases have capacity for accommodating a string length of up to around 22 meters, whilst the typical tool string can be around 13 to 14 m, leaving a limited length for the tubular equipment.

[0006] In operations where the tubular equipment is a straddle, the straddle may be split into a plurality of members comprising a plurality of joints that are connected once inside the wellbore. To install or remove the straddle assembly from the wellbore, one section at the time is installed or removed from the wellbore. A disadvantage of the prior art is that all the joints are subjected to the same forces during a connect or a disconnect procedure and it may be possible to unintentionally disconnect wrong joints. The length of the sluice often restricts the length of the string. Therefore, the straddle assembly needs to be split into the plurality of members. Several runs are required to install or remove the straddle assembly.

[0007] Document W02017007331 discloses a tool string with an engaging tool positioned between a stroker and a tractor, wherein the tractor is positioned inside a tubular equipment that is to be removed from the wellbore. The length of the string is reduced and may therefore allow use of a shorter sluice. A disadvantage is that it is only possible to use the tool string for removing tubular equipment from the wellbore and all the joints in the tubular equipment are subjected to forces during the disconnect procedure.

[0008] The invention has for its object to remedy or to reduce at least one of the drawbacks of the prior art, or at least provide a useful alternative to prior art. The object is achieved through features, which are specified in the description below and in the claims that follow.

[0009] The invention is defined by the independent patent claims. The dependent claims define advantageous embodiments of the invention.

[0010] More specifically, the invention relates to a tool string comprising an engaging tool configured to connect a tubular equipment to the tool string, wherein:

[0011] - the tool string comprises in sequence from a first end towards a second end the engaging tool, a tractor and a gripping tool;

[0012] - the first end is positioned uphole compared to the second end; and - the engaging tool is configured to connect to the tubular equipment in an uphole end of the tubular equipment.

[0013] The tubular equipment may comprise a spacer pipe or a plurality of connected spacer pipes.

[0014] It can be noted that the terms "uphole" and "downhole" are used herein for indicating relative position along the wellbore trajectory, towards or away from a wellhead along the wellbore, and do not signify any particular elevation. Accordingly, the term "uphole" can be indicative of a position that is closer to the wellhead along the wellbore path than another position, but which is of the same elevation, such as for example may be the case in horizontal wellbore sections. Conversely, the term "downhole" can be indicative of a position that is a greater distance away from the wellhead along the wellbore path than another position, but which has the same elevation.

[0015] The tool string may comprise a connecting head for attaching the tool string to a flexible elongated member, a swivel for limiting torque on the flexible elongated member wherein the flexible elongated member connects the tool string to a surface equipment, a release tool for releasing a part of the tool string, a locator device for use in determining the position of the tool string within the wellbore, and a tension / compression measurement tool for sensing tension and compression forces in the tool string. The surface equipment may be a winch.

[0016] The tool string may comprise a spacer to adapt a distance from the engaging tool to the gripping tool. The effect of this is that the distance between the engaging tool, the stroker anchor and the gripping tool may be adapted to fit different tubular equipment.

[0017] The tool string may comprise a controllable "no-go" tool adapted to restrict displacement of the tool string relative to a restriction, after meeting the restriction. The "no-go" tool may be positioned in an uphole position, or a downhole position compared to the gripping tool position.

[0018] The tool string may comprise a travel joint positioned in a position between the engaging tool and the stroker anchor. The travel joint may be adapted to allow a part of the tool string that is positioned downhole of the travel joint, to be displaced relative to the tubular equipment while the engaging tool is connected in the uphole end of the tubular equipment. The travel joint may be used to position the gripping tool and the stroker anchor relative to the tubular equipment and the member. The travel joint may have an initial position prior to displacing the part of the tool string relative to the tubular equipment, and a locked position after the part of the tool string has been displaced relative to the tubular equipment.

[0019] The engaging tool may be a sliding GS pulling tool that allows a stinger to slide on a core once the stinger is disconnected from a latch in the uphole end of the tubular equipment. After the sliding GS pulling tool is unlatched from the tubular equipment, the tool string is allowed to displace within the tubular equipment while the stinger slides between a first stop and a second stop on the core. In one embodiment, the sliding GS pulling tool may have the stinger in a first position for when the tubular equipment is to be released within the wellbore, and a second position for when the tubular equipment is to be removed from the wellbore. The first position and the second position allow the tool string to adapt the position of the stroker anchor and the gripping tool for the specific operation.

[0020] The tubular equipment may be installed within a well tubing, e.g. temporarily. The tubular equipment may be configured to isolate sections of the wellbore, e.g. perforated sections of the wellbore tubing. The tubular equipment may be configured to prevent, hinder or restrict fluid leakage into an annulus behind the well tubing, and / or to prevent, hinder or restrict inflow from the annulus into the wellbore. The tubular equipment may comprise a section of tubing in the form of a straddle. The tubular equipment may comprise a straddle or part of a straddle. The straddle may comprise a section of pipe or a sleeve.

[0021] The straddle may be provided with any one of: a sliding sleeve, measuring devices, a valve for controlling production, tracer material, and corrosion resistant material. The straddle may protect parts or components in the well, which may be susceptible to weakening, or damage. For example, the straddle may provide corrosion protection.

[0022] In one embodiment, the tubular equipment may be a straddle assembly that comprises a plurality of straddle elements being connected once in the wellbore. The straddle ele- merits may be an upper straddle packer, a spacer pipe or a lower straddle packer. The connections between the straddle elements may be a commonly used connection as a GS style latch, but may also comprise other types of connections for connecting tubular equipment known in the art.

[0023] The gripping tool may comprise a plurality of gripping elements to grip an inside of a slick tubular equipment. The gripping elements may form a profile to mate with a complementary profile inside the tubular equipment, or the complementary profile may be in the uphole end of the tubular equipment. The complementary profile may be a latching profile. Whenever the gripping tool is activated, a pressure measurement, or a position measurement of the gripping elements may be used to confirm that the gripping tool has been activated.

[0024] The engaging tool may comprise a GS style pulling tool. The GS pulling tool is a tool that connects to a latching profile and remain connected until disconnected. The GS pulling tool use commonly used latching profiles allowing the tool string to connect to tubular equipment that are formed according to already established norms within wellbore equipment. The configuration of the GS pulling tool may be different when used for setting the tubular equipment into the wellbore compared to when removing the tubular equipment from the wellbore.

[0025] The tool string may comprise a stroker and a stroker anchor between the tractor and the gripping tool such that the stroker is closest to the gripping tool. The stroker is adapted to provide a linear force in the uphole direction and in the downhole direction. When the stroker is positioned between the stroker anchor and the gripping tool, the stroker applies linear forces on a connection between two subsequent tubular equipment if the stroker anchor and the gripping tool are positioned on each side of the connection.

[0026] The stroker anchor may comprise a plurality of anchoring elements to engage an inside of a slick tubular equipment. The tool string is adapted to be wireline operated, wherein the flexible elongated member is the wireline. The wireline may be used to pull the tool string in the uphole direction.

[0027] In a second aspect the invention relates more particularly to a method for sluicing a tool string and a tubular equipment into a wellbore or out of the wellbore, wherein the method comprises to:

[0028] - provide a tool string which comprises in sequence from a first end towards a second end, the first end is positioned uphole compared to the second end, an engaging tool, a tractor and a gripping tool such that on at least one of an entry into the wellbore and an exit from the wellbore, the engaging tool is fastened to an uphole end of the tubular equipment.

[0029] The method may further comprise to release the tubular equipment from the tool string within the wellbore. The tubular equipment may be fastened to a member within the wellbore prior to releasing the tubular equipment. The tubular equipment may be fastened to the member by a latching operation. The member may be the lower straddle packer, or the spacer pipe. The member may be a tubing in the wellbore. The member may be an object known in the art to which a tubular equipment may be connected to. The latching operation may be done by pushing a stinger into a latching profile.

[0030] The method may further comprise to:

[0031] - lower the tool string and the tubular equipment into the wellbore by gravity;

[0032] - deactivate and release the engaging tool from the tubular equipment when the tool string and the tubular equipment come to a halt, and displace the tool string in an uphole direction relative to the tubular equipment such that the tractor is positioned uphole of the tubular equipment;

[0033] - engage the gripping tool inside the tubular equipment;

[0034] - activate a propulsion means of the tractor and displace the tool string and the tubular equipment further into the wellbore; and

[0035] - fasten the tubular equipment to the member using a propulsion force from the tractor. The method for sluicing the tool string and the tubular equipment into the wellbore or out of the wellbore, wherein the method comprises to: provide the tool string which comprises in sequence from a first end towards a second end, the first end is positioned uphole compared to the second end, an engaging tool, a tractor and a gripping tool such that on at least one of an entry into the wellbore and an exit from the wellbore, the engaging tool is fastened to an uphole end of the tubular equipment;

[0036] - release the tubular equipment from the tool string within the wellbore. The tubular equipment may be fastened to a member within the wellbore prior to releasing the tubular equipment. The tubular equipment may be fastened to the member by a latching operation.

[0037] The method may further comprise to:

[0038] - provide the tool string with a stroker and a stroker anchor between the tractor and the gripping tool such that the stroker is closest to the gripping tool;

[0039] - lower the tool string and the tubular equipment into the wellbore by gravity;

[0040] - deactivate and release the engaging tool from the tubular equipment when the tool string and the tubular equipment come to a halt, and displace the tool string in an uphole direction relative to the tubular equipment such that the tractor and the stroker anchor is positioned uphole of the tubular equipment;

[0041] - engage the gripping tool inside the tubular equipment;

[0042] - activate a propulsion means of the tractor and displace the tool string and the tubular equipment further into the wellbore;

[0043] - displace the tool string and the tubular equipment within the wellbore until the tubular equipment reaches the member;

[0044] - activate the stroker anchor to anchor the tool string to the inside of the wellbore; and

[0045] - activate the stroker to provide a linear force on the tubular equipment away from the stroker anchor for fastening the tubular equipment to the member.

[0046] The gripping tool may engage the inside of the tubular equipment in a plurality of methods. One method for engaging the gripping tool to the inside of the tubular equipment may be that after the engaging tool has been deactivated and released from the tubular equipment but prior to displacing the tool string in the uphole direction relative to the tubular equipment, the gripping tool may be adapted to a "seek mode". The gripping tool adapted to the "seek mode" may then engage the latch in the uphole end of the tubular equipment while the tool string is being displaced in the uphole direction relative to the tubular equipment. Once the gripping tool has engaged the latch on the inside of the tubular equipment, the displacement of the tool string relative to the tubular equipment stops.

[0047] A second method for the gripping tool to engage the inside of the tubular equipment may be that after the engaging tool has been deactivated and released from the tubular equipment, the tool string may be displaced in the uphole direction relative to the tubular equipment such that the gripping tool is uphole of the tubular equipment. The gripping tool may then be adapted to the "seek mode". After the gripping tool is adapted to the "seek mode", the tool string may be displaced in a downhole direction relative to the tubular equipment where the gripping tool engage the latch in the uphole end of the tubular equipment while the tool string is being displaced in the downhole direction. Once the gripping tool has engaged the latch on the inside of the tubular equipment, the displacement of the tool string relative to the tubular equipment stops.

[0048] A third method for the gripping tool to engage the inside of the tubular equipment may be that after the engaging tool has been deactivated and released from the tubular equipment, the "no-go" tool may be adapted to restrict displacement of the tool string relative to a restriction inside the tubular equipment, after meeting the restriction. The "no-go" tool is positioned in the tool string such that when the "no-go" tool meets the restriction inside the tubular equipment, the tractor and the stroker anchor are positioned uphole of the tubular equipment. The tool string is then displaced in the uphole direction relative to the tubular equipment until the "no-go" tool meets the restriction inside the tubular equipment. After the "no-go" tool meets the restriction inside the tubular equipment, the gipping tool is activated to engage the inside of the tubular equipment. In an alternative embodiment of the tool string, the "no-go" tool may be the gripping tool adapted to allow the tool string to displace relative to the tubular equipment until meeting the restriction inside the tubular equipment. After meeting the re- striction inside the tubular equipment, the gripping tool may be adapted to engage inside the tubular equipment.

[0049] In an alternative embodiment of the tubular equipment, a second latch dedicated for the gripping tool to engage the inside the tubular equipment may be positioned downhole of the latch in the uphole end of the tubular equipment. The three above mentioned methods for the gripping tool to engage the inside of the tubular equipment may be used but where the latch in the uphole end of the tubular equipment or the slick inside of the tubular equipment is replaced by the second latch. An effect of this is that the second latch may be positioned to optimize a position of the tool string relative to the tubular equipment.

[0050] The stroker may provide a linear force in the uphole direction and in the downhole direction with a high degree of control and accuracy compared to the tractor. Measurements of the linear force and linear position may be used to confirm a successful latching operation or a successful unlatching operation. The stroker may provide a larger force for connecting the tubular equipment with the member compared to the tractor.

[0051] The method for sluicing the tool string and the tubular equipment into the wellbore or out of the wellbore, wherein the method comprises to: provide the tool string which comprises in sequence from a first end towards a second end, the first end is positioned uphole compared to the second end, an engaging tool, a tractor and a gripping tool such that on at least one of an entry into the wellbore and an exit from the wellbore, the engaging tool is fastened to an uphole end of the tubular equipment;

[0052] - release the tubular equipment from the tool string within the wellbore. The tubular equipment may be fastened to a member within the wellbore prior to releasing the tubular equipment. The tubular equipment may be fastened to the member by a latching operation.

[0053] The method may further comprise to:

[0054] - provide the tool string with a stroker and a stroker anchor between the tractor and the gripping tool such that the stroker is closest to the gripping tool; - lower the tool string and the tubular equipment into the wellbore by gravity;

[0055] - deactivate and release the engaging tool from the tubular equipment when the tool string and the tubular equipment come to a halt, and displace the tool string in an uphole direction relative to the tubular equipment such that the tractor is positioned uphole of the tubular equipment;

[0056] - engage the gripping tool inside the tubular equipment;

[0057] - activate a propulsion means of the tractor and displace the tool string and the tubular equipment further into the wellbore;

[0058] - displace the tool string and the tubular equipment within the wellbore until the tubular equipment reaches the member;

[0059] - deactivate the gripping tool and displace the tool string downhole relative to the tubular equipment such that the gripping tool is positioned inside the member and the stroker anchor is positioned inside the tubular equipment;

[0060] - engage the gripping tool inside the member;

[0061] - engage the stroker anchor inside the tubular equipment; and

[0062] - activate the stroker to provide a linear force on the tubular equipment towards the member for fastening the tubular equipment to the member.

[0063] By positioning the gripping tool inside the member, and the stroker anchor inside the tubular equipment, and providing the linear force with the stroker, only the connection to be fastened will be subjected to the linear force while any remaining connections will not be subjected to the linear force.

[0064] The method for sluicing the tool string and the tubular equipment into the wellbore or out of the wellbore, wherein the method comprises to:

[0065] - provide the tool string which comprises in sequence from a first end towards a second end, the first end is positioned uphole compared to the second end, an engaging tool, a tractor and a gripping tool such that on at least one of an entry into the wellbore and an exit from the wellbore, the engaging tool is fastened to an uphole end of the tubular equipment;

[0066] - the tubular equipment is disconnected from a member within the wellbore and thereaf- ter removed from the wellbore. The tubular equipment may be disconnected from the member by an unlatching operation.

[0067] The method may further comprise to:

[0068] - lower the tool string into the wellbore by gravity;

[0069] - activate the propulsion means of the tractor when the tool string comes to a halt, and displace the tool string further into the wellbore;

[0070] - engage the gripping tool inside the tubular equipment, after the tool string has reached the tubular equipment;

[0071] - disconnect the tubular equipment from the member;

[0072] - disengage the gripping tool; and

[0073] - displace the tool string relative to the tubular equipment to engage the engaging tool in the uphole end of the tubular equipment.

[0074] To disconnect the tubular equipment from the member, the stroker may be used to provide linear forces adapted to disconnect the connection between the tubular equipment and the member.

[0075] The method for sluicing the tool string and the tubular equipment into the wellbore or out of the wellbore, wherein the method comprises to: provide the tool string which comprises in sequence from a first end towards a second end, the first end is positioned uphole compared to the second end, an engaging tool, a tractor and a gripping tool such that on at least one of an entry into the wellbore and an exit from the wellbore, the engaging tool is fastened to an uphole end of the tubular equipment;

[0076] - the tubular equipment is disconnected from a member within the wellbore and thereafter removed from the wellbore. The tubular equipment may be disconnected from the member by an unlatching operation.

[0077] The method may further comprise to:

[0078] - provide the tool string with a stroker and a stroker anchor between the tractor and the gripping tool, such that the stroker is closest to the gripping tool;

[0079] - lower the tool string into the wellbore by gravity; - activate the propulsion means of the tractor when the tool string comes to a halt, and displace the tool string further into the wellbore;

[0080] - position the tool string such that the gripping tool is inside the member and the stroker anchor is inside the tubular equipment after the tool string has reached the tubular equipment;

[0081] - engage the gripping tool;

[0082] - engage the stroker anchor;

[0083] - activate the stroker to provide linear forces to disconnect the tubular equipment from the member;

[0084] - disengage the gripping tool; and

[0085] - displace the tool string relative to the tubular equipment to engage the engaging tool in the uphole end of the tubular equipment.

[0086] By engaging the gripping tool inside the member, engaging the stroker anchor inside the tubular equipment, and providing the linear forces required to disconnect the connection with the stroker, only the connection to be disconnected will be subjected to the linear force while any remaining connection will not be subjected to the linear force. This ensures that the correct connection is disconnected.

[0087] The linear forces required to disconnect the connection between the tubular equipment and the member may vary depending on the type of connection being used.

[0088] The tool string may be pulled out of the wellbore by spooling in a flexible elongate member coupled to the tool string. The flexible elongate member may be a wireline connected to a cable head in the uphole end of the tool string.

[0089] The tubular equipment may comprise at least one of a single spacer pipe or a plurality of connected spacer pipes. The tubular equipment may comprise a combination of the upper straddle packer, the spacer pipe, and the lower straddle packer.

[0090] The engaging tool may comprise a GS style pulling tool.

[0091] In the following is described examples of preferred embodiments illustrated in the accompanying drawings, wherein: Fig. la shows a straddle assembly known in the art;

[0092] Figs, lb-e show the working principle of a latch and a stinger in the straddle assembly;

[0093] Figs. 2a-d show how a straddle assembly is installed in a wellbore in a known method;

[0094] Fig. 3a shows a sluice connecting to a wellbore via a valve arrangement;

[0095] Figs. 3b-c show a rig-up height to fit inside the sluice of a known tool string with one spacer pipe, the rig-up height of the known tool string and two spacer pipes, and the rig-up height of a tool string according to the invention with two spacer pipes;

[0096] Figs. 4a-j show a first method for installing the straddle assembly inside the wellbore according to the invention;

[0097] Figs. 5a-e show a second method for installing the straddle assembly inside the wellbore according to the invention;

[0098] Figs. 6a-g show a third method for installing the straddle assembly inside the wellbore according to the invention;

[0099] Figs. 7a-i show a fourth method for installing the straddle assembly inside the wellbore according to the invention;

[0100] Figs. 8a-g show a method for removing the straddle assembly from the wellbore according to the invention; and

[0101] Figs. 9a-g show another method for removing the straddle assembly from the wellbore according to the invention.

[0102] Any positional indications refer to the position shown in the figures. In the figures, same or corresponding elements are indicated by same reference numerals. For clarity reasons, some elements may in some of the figures be with-out reference numerals. A person skilled in the art will understand that the figures are just principal drawings. The relative proportions of individual elements may also be distorted.

[0103] Figure la shows a known straddle assembly 7 comprising a lower straddle packer 72, two spacer pipes 74, and an upper straddle packer 76. The straddle assembly 7 is installed in a wellbore 92. The straddle assembly 7 comprises a plurality of latches 78 and a plurality of stingers 79. The stinger 79 and the latch 78 are shown in more details in figures lb-e. Each of the spacer pipes 74 comprises the stinger 79 at the downhole end. The upper straddle packer 76 comprises the stinger 79 at the downhole end. The stinger 79 is projecting in a downhole direction 98. The lower straddle packer 72 comprises the latch 78 at the uphole end. Each of the spacer pipes 74 comprises the latch 78 at the uphole end. The upper straddle packer 76 comprises the latch 78 at the uphole end. The latch 78 is projecting in an uphole direction 97 and positioned on an inside of the lower straddle packer 72, the spacer pipes 74 and the upper straddle packer 76.

[0104] Figures lb-e show the details of the stinger 79 and the latch 78 that allow connecting and disconnecting two tubulars in the wellbore 92. Figures lb-c show a latching operation connecting the latch 78 and the stinger 79. Figures ld-e show an unlatching operation disconnecting the latch 78 from the stinger 79.

[0105] Figure lb shows the stinger 79 and the latch 78 prior to connection.

[0106] Figure lc shows the stinger 79 and the latch 78 connected after the latching operation is complete. The latching operation occurs when the stinger 79 is pushed into the latch 78 and a plurality of latching fingers 792 enters a complementary profile 782 in the latch 78. The latching fingers 792 are locked in place by a locking mechanism 794. After the latching operation is complete, the stinger 79 and the latch 78 will not come apart unless disconnected with the unlatching operation.

[0107] Figure Id shows the locking mechanism 794 in an open position. This is done by pushing the stinger 79 into the latch 78 until a pre-determined number of shear pins 62 shear. After shearing of the pins 62, the locking mechanism 794 is allowed to be displaced downwards relative to the position prior to shearing the shear pins 62, and the latching fingers 792 may move inwards in a radial direction.

[0108] Figure le shows the locking mechanism 794 displaced downwards allowing the latching fingers 792 to move radially inwards and leave the complementary profile 782 when the stinger 79 is pulled out of the latch 78. The stinger 79 and the latch 78 may now be parted.

[0109] Figures 2 a-d show a known method for setting the straddle assembly 7 in a high deviation part of the wellbore 92. A known tool string 100 comprising a tractor 3 and a stroker 4 or a setting tool is used for setting the straddle assembly 7 through a plurality of runs. A run is typically defined as lowering a tool string into the wellbore 92, perform an activity within the wellbore 92, and withdraw the tool string from the wellbore 92.

[0110] Figure 2a shows a first run where the lower straddle packer 72 is set in the wellbore 92 using the known tool string 100.

[0111] Figure 2b shows a second run where a first spacer pipe 74, 741 is connected to the lower straddle packer 72 by using the known tool string 100 to push the first spacer pipe 74, 741 into the lower straddle packer 72, i.e. the stinger 79 into the latch 78.

[0112] Figure 2c shows a third run where a second spacer pipe 74, 742 is connected to the first spacer pipe 74, 741 by using the known tool string 100 to push the second spacer pipe 74, 742 into the first spacer pipe 74, 741.

[0113] The process described in figure 2c may be repeated until a desired number of spacer pipes 74 are installed.

[0114] Figure 2d shows a final run where, after the desired number of spacer pipes 74 have been installed, the upper straddle packer 76 is connected to the uppermost spacer pipe 74. The straddle assembly 7 is thereby installed in the wellbore 92.

[0115] The known method for collecting the straddle assembly 7 from the wellbore 92 is to reverse the method described in figures 2a-d and replace the latching operation with the unlatching operation. Figure 3a shows a sluice 200, often termed a "lubricator", and is typically used for sluicing tool strings and equipment in or out of the wellbore 92. A tool string and an equipment enters the wellbore 92 by being placed inside the sluice 200 before a valve arrangement 300 is opened to connect the inside of the sluice 200 to the wellbore 92, allowing the tool string and the equipment to safely enter the wellbore 92. The valve arrangement 300 is often termed a x-mas tree or a blowout preventor (BOP).

[0116] Figure 3b shows a rig-up height of the known tool string 100 and the first spacer pipe 74, 741 and the rig-up height of the known tool string 100, the first spacer pipe 74, 741 and the second spacer pipe 74, 742, where the known method is used. The rig-up height is the length of a tool string and any attached equipment and is limited by the available length within the sluice 200. To save time and cost, conveying and installing two spacer pipes 74 per run would be effective. The rig-up height for running two spacer pipes 74 simultaneously requires a longer sluice 200 compared to running one spacer pipe 74 at a time.

[0117] Figure 3c shows a tool string 1 connected to a second spacer pipe 74, 742 being connected to a first spacer pipe 74, 741 according to the invention. The tool string 1 and the second spacer pipe 74, 742 are connected to each other via a GS coupling 6 connected to the latch 78 in the uphole end of the second spacer pipe 74, 742. The GS coupling 6 is a pulling tool and comprises the stinger 79 in the downhole end. The stinger 79 faces in the downhole direction 98. The tool string 1 comprises in sequence from a first end 12 towards a second end 14 the GS coupling 6, a tractor 3, a stroker anchor 42, a stroker 4, and a gripping tool 5. The tool string 1 is connected to a wireline 96 in the first end 12. As seen, the rig-up height of the tool string 1, the first spacer pipe 74, 741, and the second spacer pipe 74, 742 according to the invention is shorter compared to the known tool string 100 connected to the first spacer pipe 74, 741 and the second spacer pipe 74, 742.

[0118] Figures 4a-4j show a run sequence according to the invention to install the straddle assembly 7 in the wellbore 92.

[0119] Figure 4a shows a first run where the lower straddle packer 72 is set according to the known method. Successfully setting of the lower straddle packer 72 is confirmed by the known tool string 100 being automatically released from the straddle packer 72 as known in the art.

[0120] Figures 4b-4i show a second run where the first spacer pipe 74, 741 is connected to the lower straddle packer 72.

[0121] Figure 4b shows the tool string 1, the first spacer pipe 74, 741, and the second spacer pipe 74, 742 have been lowered into the wellbore 92 by gravity until halting due to an inclination of the wellbore 92.

[0122] Figure 4c shows the gripping tool 5 has engaged internally the first spacer pipe 74, 741. Thereafter the GS coupling 6 is deactivated from the second spacer pipe 74, 742.

[0123] Figure 4d shows the GS coupling 6 has been disconnected from the second spacer pipe 74, 742. This is done by activating the stroker 4 such that the tool string 1 above the stroker's 4 actuator is displaced in the uphole direction relative to the gripping tool 5 and the GS coupling 6 is displaced from the latch 78 in the second spacer pipe 74, 742.

[0124] Figure 4e shows the gripping tool 5 has been deactivated and a "no-go" tool 2 has been activated. The tool string 1 may be displaced in the uphole direction relative to the first spacer pipe 74, 741 until the "no-go" tool 2 meets a restriction 746 inside the first spacer pipe 74, 741.

[0125] Figure 4f shows that the tool string 1 has been displaced in the uphole direction 97 relative to the first space pipe 74, 741 such that the tractor 3 is positioned outside the second spacer pipe 74, 742. The wireline 96 is used for pulling the tool string 1 in the uphole direction 97. In an alternative method, the tractor 3 may be activated and used for displacing the tool string 1 in the uphole direction 97. When the "no-go" tool 2 meets the restriction 746, any further displacement of the tool string 1 in the uphole direction 97 will displace the first spacer pipe 74, 741 and the second spacer pipe 74, 742 as well. An increase in a force required to displace the tool string 1 in the uphole direction 97 confirms that the "no-go" tool 2 has met the restriction 746. Figure 4g shows that the gripping tool 5 has engaged internally the first spacer pipe 74, 741. The "no-go" tool 2 is still active to prevent any relative displacement in the uphole direction 97 between the first spacer pipe 74, 741 and the tool string 1 while the gripping tool 5 is being activated.

[0126] Figure 4h shows that a propulsion means 32 of the tractor 3 is activated and the tool string 1, the first spacer pipe 74, 741 and the second spacer pipe 74, 742 are displaced in the downhole direction 98.

[0127] Figure 4i shows that the tractor 3 has performed the latching operation where the first spacer pipe 74, 741 has been connected to the lower straddle packer 72. Prior to deactivating the gripping tool 5, a force in the uphole direction 97 is applied to the tool string 1 to check that the first spacer pipe 74, 741 is firmly connected to the lower straddle packer 72. The force in the uphole direction 97 may come from the propulsion means 32 of the tractor 3 or the wireline 96.

[0128] The sequence of running the first spacer pipe 74, 741 and second spacer pipe 74, 742 in figures 4b-4i, but with the difference that the lower straddle packer 72 as described in figures 4b-i is replaced by a spacer pipe 74, may be repeated until a desirable number of spacer pipes 74 have been connected in series.

[0129] Figure 4j shows a final run where, after the desirable number of spacer pipes 74 have been installed, the upper straddle packer 76 is connected to the uppermost spacer pipe 74, by using the known tool string 100. The straddle assembly 7 is thereby installed in the wellbore 92.

[0130] Figures 5a-d show a method for using the stroker 4 and not the propulsion means 32 of the tractor 3 to connect a long spacer pipe 74, 747 with the lower straddle packer 72. The steps explained in figures 4a-h, but with the first spacer pipe 74 ,741 and the second spacer pipe 74, 742 replaced by the long spacer pipe 74, 747, are done prior to the steps explained in figures 5a-e.

[0131] Figure 5a shows the tool string 1 positioned such that the "no-go" tool 2 is adjacent to the restriction 746 in the uphole end of the long spacer pipe 74, 747 and the gripping tool 5 is engaged internally in the long spacer pipe 74, 747. The tractor 3 and the stroker anchor 42 are positioned uphole of the long spacer pipe 74, 747, and the tractor 3 has positioned the stinger 79 in the downhole end of the long spacer pipe 74, 747 adjacent to the latch 78 of the lower straddle packer 72.

[0132] Figure 5b shows that the stroker anchor 42 anchors the tool string 1 to the inside of the wellbore 92.

[0133] Figure 5c shows that the long spacer pipe 74, 747 has been connected to the lower straddle packer 72. This is done by activating the stroker 4 to provide the linear force to push the gripping tool 5 away from the stroker anchor 42, and thereby perform the latching operation between the long spacer pipe 74, 747 and the lower straddle packer 72. The latching operation is confirmed by the plurality of force measurements in the stroker 4.

[0134] Figure 5d shows that the stroker anchor 42, the "no-go" tool 2 and the gripping tool 5 have been deactivated.

[0135] The sequence described in figure 5a-5d, but with the difference that the lower straddle packer 72 as described in figures 5a-d is replaced by a spacer pipe 74, may be repeated until a desirable number of spacer pipes 74 have been connected in series.

[0136] Figure 5e shows a final run where, after the desirable number of spacer pipes 74 have been installed, the upper straddle packer 76 is connected to the uppermost spacer pipe 74, in this case the long spacer pipe 74, 747, by using the known tool string 100. The straddle assembly 7 is thereby installed in the wellbore 92.

[0137] Figures 6a-f show another method for using the stroker 4 and not the propulsion means 32 of the tractor 3 to connect the first spacer pipe 74, 741 with the lower straddle packer 72. The steps explained in figures 4a-h are therefore done prior to the steps explained in figures 6a-g.

[0138] Figure 6a shows that the tractor 3 has positioned the stinger 79 in the downhole end of the first spacer pipe 74, 741 adjacent to the latch 78 of the lower straddle packer 72. Figure 6b shows that the gripping tool 5 and the "no-go" tool 2 is deactivated. The tractor 3 is about to displace the tool string 1 in the downhole direction 98 relative to the first spacer pipe 74, 741 and the second spacer pipe 74, 742.

[0139] Figure 6c shows that the tool string 1 has been displaced by the propulsion means 32 of the tractor 3 such that the gripping tool 5 is positioned inside the lower straddle packer 72, and the stroker anchor 42 is positioned inside the first spacer pipe 74, 741.

[0140] Figure 6d shows that the gripping tool 5 has engaged the lower straddle packer 72 internally, and the stroker anchor 42 has engaged the first spacer pipe 74, 741 internally. The propulsion means 32 of the tractor 3 is active in a parking mode during activation of the gripping tool 5 and the stroker anchor 42 to prevent any displacement of the tool string 1 during activation of the stroker anchor 42 and the gripping tool 5.

[0141] Figure 6e shows that the lower straddle packer 72 and the first spacer pipe 74, 741 is connected. This is done by activating the stroker 4 to provide a linear force by pulling the gripping tool 5 towards the stroker anchor 42. Thereby the stinger 79 in the downhole end of the first spacer pipe 74, 741 is pushed into the latch 78 in the lower straddle packer 72 in the latching operation.

[0142] Figure 6f shows that the gripping tool 5 is deactivated while the stroker anchor 42 is still internally engaged to the first spacer pipe 74, 741. By pulling the tool string 1 with the wireline 96, a measurement of a pull force in the wireline 96 will confirm that the first spacer pipe 74, 741 is firmly connected to the lower straddle packer 72.

[0143] The sequence described in figure 6a-6f, but with the difference that the lower straddle packer 72 as described in figures 6a-f is replaced by a spacer pipe 74, may be repeated until a desirable number of spacer pipes 74 have been connected in series.

[0144] Figure 6g shows a final run where, after the desirable number of spacer pipes 74 have been installed, the upper straddle packer 76 is connected to the uppermost spacer pipe 74, by using the known tool string 100. The straddle assembly 7 is thereby installed in the wellbore 92. Figures 7a-i show a method where the gripping tool 5 connects to the latch 78 before connecting the long spacer pipe 74, 747 to the lower straddle 72. The method may use the propulsion means 32 in the tractor 3 or the stroker 4 to connect the long spacer pipe 74, 747 with the lower straddle packer 72. The step explained in figure 4a is done prior to the steps explained in figures 7a-i.

[0145] Figure 7a shows that the tool string 1 and the long spacer pipe 74, 747 have been lowered into the wellbore 92 by gravity until halting due to an inclination of the wellbore 92.

[0146] Figure 7b shows that the GS coupling 6 has been disconnected from the long spacer pipe 74, 747. This is done by deactivating the GS coupling 6.

[0147] Figure 7c shows that the tool string 1 has been displaced in the uphole direction 97 relative to the long space pipe 74, 747 such that the tool string 1 is positioned uphole and outside the long spacer pipe 74, 747. The wireline 96 is used for pulling the tool string 1 in the uphole direction 97. In an alternative method, the tractor 3 may be activated and used for displacing the tool string 1 in the uphole direction 97. A locator measurement confirms that the tool string 1 is uphole of the long spacer pipe 74, 747.

[0148] Figure 7d shows the gripping tool 5 and the propulsion means 32 of the tractor 3 have been activated.

[0149] Figure 7e shows the tool string 1 has displaced in the downhole direction 98 and the gripping tool 5 has engaged the latch 78 in the uphole end of the long spacer pipe 74, 747. An increase in a required propulsion force in the downhole direction 98 indicates that the gripping tool 5 is engaged with the latch 78. In an alternative method, the gripping tool 5 may after the step described in figure 7b be adapted to a "seek mode" to engage the latch 78 while the tool string 1 is being displaced in the uphole direction 97 relative to the long spacer pipe 74, 747 to position the tractor 3 and the stroker anchor 42 uphole of the long spacer pipe 74, 747.

[0150] Figure 7f shows that the tractor 3 has positioned the stinger 79 in the downhole end of the long spacer pipe 74, 747 adjacent to the latch 78 of the lower straddle packer 72. Figure 7g shows that the stroker anchor 42 anchors the tool string 1 to the inside of the wellbore 92.

[0151] Figure 7h shows that the long spacer pipe 74, 747 has been connected to the lower straddle packer 72. This is done by activating the stroker 4 to provide the linear force to push the gripping tool 5 away from the stroker anchor 42, and thereby perform the latching operation between the long spacer pipe 74, 747 and the lower straddle packer 72. The latching operation is confirmed by the plurality of force measurements in the stroker 4. In an alternative method, the anchor 42 may be released before the wireline 96 pulls the tool string 1 in the uphole direction 97 to confirm the long spacer pipe 74, 747 is firmly connected to the lower straddle packer 72. In an alternative method, the propulsion means 32 of the tractor 3 may be used for connecting the long spacer pipe 74, 747 to the lower straddle packer 72 while the stroker anchor 42 and the stroker 4 remains inactive during the latching operation.

[0152] The sequence described in figure 7a-7h, but with the difference that the straddle packer 72 as described in figures 7a-h is replaced by a spacer pipe 74, may be repeated until a desirable number of spacer pipes 74 have been connected in series.

[0153] Figure 7i shows a final run where, after the desirable number of spacer pipes 74 have been installed, the upper straddle packer 76 is connected to the uppermost spacer pipe 74, in this case the long spacer pipe 74, 747, by using the known tool string 100. The straddle assembly 7 is thereby installed in the wellbore 92.

[0154] In alternative methods to the methods described in figures 4 a-j, figures 5 a-e, figures 6a- g, and figures 7a-l, the first run comprises steps to install the spacer pipe 74 and the lower straddle packer 72. This is done by connecting the spacer pipe 74 and the lower straddle packer 72 in series, where the latch 78 of the lower straddle packer 72 is connected to the stinger 79 in the downhole end of the spacer pipe 74 prior to entering the wellbore 92. The GS coupling 6 is connected to the latch 78 in the uphole end of the spacer pipe 74. The lower straddle packer 72 and the spacer pipe 74 is then installed in the wellbore 92 together in the first run. If more than one spacer pipe 74 is to be installed in the wellbore 92, the final run for installing the upper straddle packer 76 may be done in combination with installing the uppermost spacer pipe 74. This is done by connecting the upper straddle packer 76 and the uppermost spacer pipe 74 in series, where the latch 78 in the uphole end of the uppermost spacer pipe 74 is connected to the stinger 79 in the downhole end of the upper straddle packer 76 prior to entering the wellbore 92. The GS coupling 6 is connected to the latch 78 in the uphole end of the upper straddle packer 76. The uppermost spacer pipe 74 and the upper straddle packer 76 is then installed together in the final run.

[0155] Figures 8a-g show a method for removing the straddle assembly 7 from the wellbore 92.

[0156] Figure 8a shows a first run where the known tool string 100 is connected to the upper straddle packer 76. The upper straddle packer 76 is then disconnected from the uppermost spacer pipe 74 in a known manner as explained in figures 1 d-e, and withdrawn from the wellbore 92.

[0157] Figures 8b-f show a second run where the first spacer pipe 74, 741 and the second spacer pipe 74, 742 are withdrawn from the wellbore 92.

[0158] Figure 8b shows that the propulsion means 32 of the tractor 3 has positioned the tool string 1 inside first spacer pipe 74, 741, the second spacer pipe 74, 742, and the lower straddle packer 72. Thereby the gripping tool 5 is positioned inside the lower straddle packer 72 and the stroker anchor 42 is positioned inside the first spacer pipe 74, 741.

[0159] Figure 8c shows that the gripping tool 5 is internally engaged to the lower straddle packer 72 and the stroker anchor 42 is internally engaged to the first spacer pipe 74, 741.

[0160] Figure 8d shows that the first spacer pipe 74, 741 is disconnected from the lower straddle packer 72. This is done by activating the stroker 4 to provide the linear forces required to perform the unlatching operation between the first spacer pipe 741 and the lower straddle packer 72. The unlatching operation is confirmed by a plurality of force measurements in the stroker 4.

[0161] Figure 8e shows that the gripping tool 5 and the stroker anchor 42 are deactivated. Figure 8f shows that the GS coupling 6 has engaged the latch 78 in the uphole end of the second spacer pipe 74, 742. This is done by running the tool string 1 in the downhole direction 98 relative to the second spacer pipe 74, 742 until the GS coupling 6 engages the latch 78. The tool string 1, the first spacer pipe 74, 741 and the second spacer pipe 74, 742 is then withdrawn from the wellbore 92. The tool string 1 and the first spacer pipe 74, 741 and the second spacer pipe 74, 742 are pulled in the uphole direction 97 by the wire- line 96.

[0162] If more spacer pipes 74 are needed to be withdrawn from the wellbore 92, the method described in figures 8b-f may be repeated, but with the difference that the straddle packer 72 as described in figures 8b-f is a spacer pipe 74, until all the spacer pipes 74 are withdrawn from the wellbore 92.

[0163] Figure 8g shows the known tool string 100 connected to the lower straddle packer 72. This is a final run where the lower straddle packer 72 is removed from the wellbore 92. The straddle assembly 7 is now removed from the wellbore 92.

[0164] Figures 9a-g show an alternative method for removing the straddle assembly 7 from the wellbore 92. The straddle assembly 7 comprises in this embodiment a long spacer pipe 74, 747 compared to the first spacer pipe 74, 741 and the second spacer pipe 74, 742.

[0165] Figure 9a shows a first run where the known tool string 100 is connected to the upper straddle packer 76. The upper straddle packer 76 is then disconnected from the long spacer pipe 74, 747 and withdrawn from the wellbore 92.

[0166] Figures 9b-f show the sequence for a second run where the long spacer pipe 747 is withdrawn from the wellbore 92.

[0167] Figure 9b shows the tool string 1 positioned such that the gripping tool 5 is positioned inside the long spacer pipe 74, 747 and the stroker anchor 42 is positioned outside the long spacer pipe 74, 747. The tool string 1 has been lowered into the wellbore 92 and the propulsion means 32 of the tractor 3 has been activated to displace the tool string 1 to reach the position shown in figure 9b. Figure 9c shows that the gripping tool 5 is internally engaged to the long spacer pipe 74, 747 and the stroker anchor 42 anchors the tool string 1 to the inside of the wellbore 92. In an alternative method, the gripping tool 5 may be engaged to the latch 78 in the uphole end of the long spacer pipe 74, 747.

[0168] Figure 9d shows that the long spacer pipe 74, 747 has been disconnected from the lower straddle packer 72. This is done by activating the stroker 4 to provide the linear forces required to perform the unlatching operation between the long spacer pipe 74, 747 and the lower straddle packer 72. The unlatching operation is confirmed by the plurality of force measurements in the stroker 4.

[0169] Figure 9e shows that the gripping tool 5 and the stroker anchor 42 have been deactivated and the tractor 3 is about to displace the tool string 1 relative to the long spacer pipe 74, 747 in a downhole direction 98 such that the GS coupling 6 engages the latch 78 in the uphole end in the long spacer pipe 74, 747.

[0170] Figure 9f shows that the tractor 3 has displaced the tool string 1 such that the GS coupling 6 has engaged the latch 78 in the uphole end in the long spacer pipe 74, 747. The tool string 1 and the long spacer pipe 74, 747 is thereafter withdrawn from the wellbore 92. The tool string 1 and the long spacer pipe 74, 747 are pulled in the uphole direction 97 by the wireline 96.

[0171] If more long spacer pipes 74, 747 are needed to be withdrawn from the wellbore 92, the sequence described in figures 9b-f may be repeated, but with the difference that the straddle packer 72 as described in figures 9b-f is a spacer pipe 74, until all the long spacer pipes 74, 747 are withdrawn from the wellbore 92.

[0172] Figure 9g shows the known tool string 100 connected to the lower straddle packer 72. This is a final run where the lower straddle packer 72 is removed from the wellbore 92. The straddle assembly 7 is now removed from the wellbore 92.

[0173] In alternative methods to the methods described in figures 8 a-g, and figures 9 a-g, the first run comprises steps to remove the upper straddle packer 76 and the uppermost spacer pipe 74 together. This is done by disconnecting the stinger 79 in the downhole end of the uppermost spacer pipe 74 either from the latch 78 in the adjacent spacer pipe 74 or from the latch 78 in the lower straddle packer 72. The GS coupling 6 is connected to the latch 78 in the uphole end in the upper straddle packer 76. The upper straddle packer 76 and the uppermost spacer pipe 74 is then removed from the wellbore 92 in the first run. If more than one spacer pipe 74 is to be removed from the wellbore 92, the final run for removing the lower straddle packer 72 may be done in combination with removing the lowermost spacer pipe 74. The stinger 79 in the downhole end in the lowermost spacer pipe 74 remains connected to the latch 78 in the uphole end of the lower straddle packer 72. The GS coupling 6 is connected to the latch 78 in the uphole end of the lowermost spacer pipe 74. The lower straddle packer 72 is then disconnected from the wellbore 92. The lowermost spacer pipe 74 and the lower straddle packer 76 is then removed from the wellbore 92 in the final run.

[0174] It should be noted that the above-mentioned embodiments illustrate rather than limit the invention, and that those skilled in the art will be able to design many alternative embodiments without departing from the scope of the appended claims. In the claims, any reference signs placed between parentheses shall not be construed as limiting the claim. Use of the verb "comprise" and its conjugations does not exclude the presence of elements or steps other than those stated in a claim. The article "a" or "an" preceding an element does not exclude the presence of a plurality of such elements.

[0175] The mere fact that certain measures are recited in mutually different dependent claims does not indicate that a combination of these measures cannot be used to advantage.

Claims

C l a i m s1. A tool string (1) comprising an engaging tool (6) configured to connect a tubular equipment (74) to the tool string (1), c h a r a c t e r i s e d i n that:- the tool string (1) comprises in sequence from a first end (12) towards a second end (14) the engaging tool (6), a tractor (3) and a gripping tool (5);- the first end (12) is positioned uphole compared to the second end (14); and- the engaging tool (6) is configured to connect to the tubular equipment (74) in an uphole end of the tubular equipment (74).

2. The tool string (1) according to claim 1, wherein the tubular equipment (74) comprises a spacer pipe (74).

3. The tool string (1) according to claim 1, wherein the engaging tool (6) comprises a GS style pulling tool (6).

4. The tool string (1) according to any one of the preceding claims, wherein the tool string (1) comprises a stroker (4) and a stroker anchor (42) between the tractor (3) and the gripping tool (5) such that the stroker (4) is closest to the gripping tool (5).

5. The tool string (1) according to any one of the preceding claims, wherein the tool string (1) is adapted to be wireline operated.

6. A method for sluicing a tool string (1) and a tubular equipment (74) into a wellbore (92) or out of a wellbore (92), the method comprises to: provide a tool string (1) which comprises in sequence from a first end (12) towards a second end (14), the first end (12) is positioned uphole compared to the second end (14), an engaging tool (6), a tractor (3) and a gripping tool (5) such that on at least one of an entry into the wellbore (92) and an exit from the wellbore (92), the engaging tool (6) is fastened to an uphole end of a tubular equipment (74).

7. The method according to claim 6, wherein the method comprises to release the tubular equipment (74) from the tool string (1) within the wellbore (92).

8. The method according to claim 7, wherein the tubular equipment (74) is fastened to a member (72) within the wellbore (92) prior to releasing the tubular equipment (74).

9. The method according to claim 8, wherein the tubular equipment (74) is fastened by a latching operation.

10. The method according to any one of claims 7 to 9, wherein the method comprises to:- lower the tool string (1) and the tubular equipment (74) into the wellbore (92) by gravity;- deactivate and release the engaging tool (6) from the tubular equipment (74) when the tool string (1) and the tubular equipment (74) come to a halt, and displace the tool string (1) in an uphole direction (97) relative to the tubular equipment (74) such that the tractor (3) is positioned uphole of the tubular equipment (74);- engage the gripping tool (5) inside the tubular equipment (74);- activate a propulsion means (32) of the tractor (3) and displace the tool string (1) and the tubular equipment (74) further into the wellbore (92); and- fasten the tubular equipment (74) to the member (72) using a propulsion force from the tractor (3).

11. The method according to any one of claims 8 and 9, wherein the method comprises to:- provide the tool string (1) with a stroker (4) and a stroker anchor (42) between the tractor (3) and the gripping tool (5) such that the stroker (4) is closest to the gripping tool (5);- lower the tool string (1) and the tubular equipment (74) into the wellbore (92) by gravity;- deactivate and release the engaging tool (6) from the tubular equipment (74)when the tool string (1) and the tubular equipment (74) come to a halt, and displace the tool string (1) in an uphole direction (97) relative to the tubular equipment (74) such that the tractor (3) and the stroker anchor (42) is positioned uphole of the tubular equipment (74);- engage the gripping tool (5) inside the tubular equipment (74);- activate a propulsion means (32) of the tractor (3) and displace the tool string (1) and the tubular equipment (74) further into the wellbore (92);- displace the tool string (1) and the tubular equipment (74) within the wellbore (92) until the tubular equipment (74) reaches the member (72);- activate the stroker anchor (42) to anchor the tool string (1) to the inside of the wellbore (92); and- activate the stroker (4) to provide a linear force on the tubular equipment (74) away from the stroker anchor (42) for fastening the tubular equipment (74) to the member (72).

12. The method according to any one of claims 8 and 9, wherein the method comprises to:- provide the tool string (1) with a stroker (4) and a stroker anchor (42) between the tractor (3) and the gripping tool (5) such that the stroker (4) is closest to the gripping tool (5);- lower the tool string (1) and the tubular equipment (74) into the wellbore (92) by gravity;- deactivate and release the engaging tool (6) from the tubular equipment (74) when the tool string (1) and the tubular equipment (74) come to a halt, and displace the tool string (1) in an uphole direction (97) relative to the tubular equipment (74) such that the tractor (3) is positioned uphole of the tubular equipment (74);- engage the gripping tool (5) inside the tubular equipment (74);- activate a propulsion means (32) of the tractor (3) and displace the tool string (1) and the tubular equipment (74) further into the wellbore (92);- displace the tool string (1) and the tubular equipment (74) within the wellbore (92) until the tubular equipment (74) reaches the member (72);- deactivate the gripping tool (5) and displace the tool string (1) in a downhole direction (98) relative to the tubular equipment (74) such that the gripping tool (5) is positioned inside the member (72) and the stroker anchor (42) is positioned inside the tubular equipment (74);- engage the gripping tool (5) inside the member (72);- engage the stroker anchor (42) inside the tubular equipment (74); and- activate the stroker (4) to provide a linear force on the tubular equipment (74) towards the member (72) for fastening the tubular equipment (74) to the member (72).

13. The method according to claim 6, wherein the tubular equipment (74) is disconnected from a member (72) within the wellbore (92) and thereafter removed from the wellbore (92).

14. The method according to claim 13, wherein the tubular equipment (74) is disconnected by an unlatching operation.

15. The method according to any one of claims 13 and 14, wherein the method comprises to:- lower the tool string (1) into the wellbore (92) by gravity;- activate the propulsion means (32) of the tractor (3) when the tool string (1) comes to a halt, and displace the tool string (1) further into the wellbore (92);- engage the gripping tool (5) inside the tubular equipment (74), after the tool string (1) has reached the tubular equipment (74);- disconnect the tubular equipment (74) from the member (72);- disengage the gripping tool (5); and- displace the tool string (1) relative to the tubular equipment (74) to engage the engaging tool (6) in the uphole end of the tubular equipment (74).

16. The method according to any one of claims 13 and 14, wherein the method comprises to:- provide the tool string (1) with a stroker (4) and a stroker anchor (42) between the tractor (3) and the gripping tool (5), such that the stroker (4) is closest to thegripping tool (5);- lower the tool string (1) into the wellbore (92) by gravity;- activate the propulsion means (32) of the tractor (3) when the tool string (1) comes to a halt, and displace the tool string (1) further into the wellbore (92);- position the tool string (1) such that the gripping tool (5) is inside the member (72) and the stroker anchor (42) is inside the tubular equipment (74) after the tool string (1) has reached the tubular equipment (74);- engage the gripping tool (5);- engage the stroker anchor (42);- activate the stroker (4) to provide linear forces to disconnect the tubular equipment (74) from the member (72);- disengage the gripping tool (5); and- displace the tool string (1) relative to the tubular equipment (74) to engage the engaging tool (6) in the uphole end of the tubular equipment (74).

17. The method according to any one of claims 13 to 16, wherein the tool string (1) is pulled out of the wellbore (92) by spooling in a flexible elongate member (96) coupled to the tool string (1).

18. The method according to any one of claims 6 to 17, wherein the tubular equipment (74) comprises at least one of a single spacer pipe (74) or a plurality of connected spacer pipes (74).

19. The method according to any one of claims 6 to 18, wherein the engaging tool (6) comprises a GS style pulling tool (6).

Images