CA3082045A1 - Elongate member handling system - Google Patents

Abstract

An elongate member handling system (1a, 1b) connected to or connectable to a mast (101) of a rig (100), said handling system (1a, 1b) comprising a travelling holding assembly (1a) for holding an elongate member (tubular or sucker rod - 102) in axial alignment with a well bore (103), and a rack and pinion drive assembly (2, 3, 4) to which is mounted the travelling holding assembly (1a) such that the travelling holding assembly (1a) travels up or down the mast (101) so as to insert the elongate member (102) into the well bore (103) or remove the elongate member (102) from the well bore (103).

Description

TITLE
Elongate Member Handling System [0001] This application claims priority of Australian provisional application number 2017904815, filed 29 November 2017, the entire contents of which are incorporated herein.
TECHNICAL FIELD

[0002] This invention relates to a handling system for a well servicing rig or drilling rig, for inserting or removing elongate members (tubulars or sucker rods) from a well bore, particularly a well bore under formation pressure.
BACKGROUND ART

[0003] Gas extraction from coal seams is a relatively new method for extracting clean gas from the earth. The process involves drilling a hole into a coal seam. The coal seam is generally flooded with water, trapping the gas inside the coal. To extract the gas from the coal a pump must be inserted into the hole to pump out the water, allowing the gas to migrate from the coal. The water and gas are pumped to surface and then separated. The subsequent product and by-product are then pumped away, to be dealt with by other means.

[0004] The pumps in the wells require servicing regularly and must be retrieved from the well utilising a well servicing rig. As wells mature, it has been identified that water depletes and the gas increases, thereby increasing the pressure in the well bore. The primary methods for safely removing tubulars from a well for servicing consist of the well bore being filled with water to hold the gas in the well. As the gas pressure increases in the well it becomes increasingly difficult to maintain a safe and cost effective fluid barrier for well entry.

[0005] In challenging wells a snubbing/stripping unit is required to be added to the well head to safely control the movement of tubulars in and out of the well whilst maintaining the security of pressure and hydrocarbon to the well bore. A conventional snubbing/stripping unit is an additional non-integrated piece of equipment to the rig carrier DESCRIPTION OF THE INVENTION

[0006] An object of the present invention is to provide an elongate member handling system for inserting or removing elongate members (such as tubulars or sucker rods) from a well bore, preferably a well bore under pressure.

[0007] An alternative object of the present invention is to provide a servicing or drilling rig (preferably mobile) that integrates an elongate member handling system to provide oil and/or gas well intervention.

[0008] An alternative object of the present invention is to provide a servicing or drilling rig that integrates a conventional draw-works hoisting system and an elongate member handling system.

[0009] An alternative object of the present invention is to provide a mobile well servicing or drilling rig that integrates a conventional draw-works hoisting system and an elongate member handling system.

[0010] An alternative object of the present invention is to supplement conventional rigs employing a conventional draw-works hoisting system with an elongate member handling system, such that there is an easy operation switch-over so as to snub/strip elongate members into/from pressurised wells using the elongate member handling system.

[0011] According to a 1s1 aspect of the present invention, there is provided an elongate member handling system connected to or connectable to a mast of a rig, said handling system comprising:

[0012] a travelling holding assembly for holding an elongate member in axial alignment with a well bore; and

[0013] a rack and pinion drive assembly to which is mounted the travelling holding assembly such that the travelling holding assembly travels up or down the mast so as to insert the elongate member into the well bore or remove the elongate member from the well bore.

[0014] According to a 2"" aspect of the present invention, there is provided an elongate member handling system connected to or connectable to a mast of a rig, said handling system comprising:

[0015] a travelling holding assembly for holding an elongate member in axial alignment with a well bore; and

[0016] a rack and pinion drive assembly comprising:

[0017] a rack assembly that is connected to or connectable to the rig;

[0018] a pinion assembly that operatively engages the rack assembly and to which is mounted the travelling holding assembly; and

[0019] a drive for moving the pinion assembly such that the travelling holding assembly travels up or down the mast so as to insert the elongate member into the well bore or remove the elongate member from the well bore.

[0020] According to a 3rd aspect of the present invention, there is provided a rig comprising the elongate member handling system according to the 1st or 2"d aspect of the present invention.

[0021] According to a 4th aspect of the present invention, there is provided a method of servicing a well, said method comprising the steps of:

[0022] optionally connecting an elongate member handling system as described according to the 1s1 or 2"d aspect of the present invention to a mast of a rig, and

[0023] operating the elongate member handling system to insert the elongate member into a well bore or remove the elongate member from a well bore.

[0024] According to a 5th aspect of the present invention, there is provided a method of inserting or removing an elongate member from a well bore, said method comprising the step of:

[0025] optionally connecting an elongate member handling system as described according to the 1 or 2nd aspect of the present invention to a mast of a rig;
and

[0026] operating the elongate member handling system so as to insert the elongate member into the well bore or remove the elongate member from the well bore.

[0027] The phrase 'elongate member' refers to a tubular or sucker rod or any other type of tube, pipe or rod that may be used when servicing or drilling a well.
'Elongate member' also refers to two or more tubulars or rods connected end to end, such as a drill string.

[0028] The travelling holding assembly can be connected to any suitable part of the mast in any suitable way. The mast can be a stiff (non-scoping) mast or a scoping mast. The travelling holding assembly can be connected or connectable to a bottom, mid or top section of a mast, for example. In some embodiments, the travelling holding assembly can be connected or connectable to a bottom section of an outer mast. In some embodiments, the travelling holding assembly can be connected or connectable to an interior region of the mast.

[0029] Preferably, the travelling holding assembly is connected or connectable within a bottom section of an outer mast.

[0030] The travelling holding assembly can be of any suitable size, shape and construction, and can be made of any suitable material or materials, such as steel.

[0031] The travelling holding assembly can hold the elongate member in axial alignment with the well bore in any suitable way. Typically this would involve temporarily clamping to the elongate member, and this can be achieved in any suitable way. Typically, the travelling holding assembly will comprise a bowl and an inverted slips assembly or hydraulic rotary slips inverted assembly capable of sustaining upward and downward forces as the travelling holding assembly moves up or down the mast.

[0032] The travelling holding assembly can comprise a bowl and inverted slips. The bowl can have a bowl body and a bowl passage extending through the bowl body.
The inverted slips assembly placed within the passage can wedge a set of dies against the bowl and the elongate member being inserted or removed from the well bore. There can be two sets of dies in the inverted slips assembly: a lower set for gripping an elongate member with forces in an upward direction, and an upper set for gripping an elongate member with downward forces.

[0033] In some embodiments the travelling holding assembly can be in the form of at least one tubing spider assembly. The tubing spider assembly can comprise a spider bowl body, a bodyguard extending from one or more opposing sides of the spider bowl body, and a passage extending through the spider bowl body to the opposing sides of the spider bowl body. The passage can be in axial alignment with the well bore when inserting or removing the elongate member from the well bore.

[0034] The rack assembly can be of any suitable size, shape and construction, and can be made of any suitable material or materials. In some embodiments the rack assembly comprises a lst rack connected to or connectable to a 1' upright of the mast, and a 2"d rack connected to or connectable to a 2"d upright of the mast. In some embodiments, 1s1 and 2nd uprights can each be in the form of a beam, such as an I-beam or U-shaped beam, having a longitudinally extending passage. In some embodiments, the 1st and 2"d uprights can correspond with sides of the mast. In some embodiments, the 1st and 2'd uprights can correspond with a spine of the mast (ie. middle of the back, rather than sides of the mast).

[0035] Each rack can comprise teeth that extend laterally relative to a length of the mast.
The teeth of each rack can extending in substantially the same plane. The 1st and 2"d racks can be of any suitable length. For example, each rack can extend the entire length of the mast (eg.
if a non-scoping mast) or less than the entire length of the mast. These can comprise one or more rack pieces connected and to end or these can be of unitary construction.

[0036] The 1s1 and 211d racks can be connected to the mast uprights in any suitable way.
Preferably the 1st and rd racks can be retrofitted to the mast of a rig and can be removed from the mast of that same rig when well servicing has ended. However, the racks can be permanently connected to the mast of the rig.

[0037] In some embodiments the 1st rack can be connected to/extend along a longitudinal side of an I-beam mast upright such that the teeth of the 1st rack and a longitudinal passage of the upright are diametrically opposed to each other. In some embodiments the 2nd rack can be connected to/extend along a longitudinal side of an I-beam mast upright such that the teeth of the 2"d rack and a longitudinal passage of the upright are diametrically opposed to each other.

[0038] Preferably the length of each of the 1st and 2"d racks is less than about 50 m and greater than about 4 m. This includes the lengths of 4, 5, 6, 7, 8, 9,10, 11, 12, 13, 14, 15, 16, 17, 18, 19, 20, 21, 22, 23, 24, 25, 26, 27, 28, 29, 30, 31, 32, 33, 34, 35, 36, 37, 38, 39, 40, 41, 42, 43, 44, 45, 46, 47, 48, 49 and 50 m, as well as all 10cm increments between 4 and 50 m.
Preferably the length of each of the 1st and 2','d racks is approximately 5-7 m (eg. -6 m or -5.5 m), such that the travelling holding assembly can move an elongate member a vertical distance of approximately 5-7 m and more preferably approximately 5.5 m. (i.e.
a 5-7 m drive range, and more preferably approximately 5.5 m drive range).

[0039] The pinion assembly can be of any suitable size, shape and construction, and can be made of any suitable material or materials. The pinion assembly can engage the rack assembly in any suitable way. The pinion assembly can have any suitable number of pinions but preferably has at least 2 pinions and more preferably at least one further pair of pinions.

Preferably the pinion assembly has 4 pinions. In some embodiments at least a 1st pair of spaced apart pinions operatively engages the 1st rack and at least a 2"(1 pair of spaced apart pinions operatively engages the 2nd rack. The pinions can rotate in substantially the same plane.

[0040] The pinion assembly can comprise a pinion carrier for holding each pinion or pinion pair relative to each rack. In some embodiments the pinion carrier together with at least one pinion or pinion pair can clamp teeth of a rack there between. The pinion carrier can be of unitary construction or discrete separate pieces. The pinion carrier can be of any suitable size, shape and construction, and can be made of any suitable material or materials.
The pinion carrier can have a pinion mounting region for each pinion. Each pinion can be pinned to a pinion mounting region, for rotation relative to the pinion carrier.

[0041] The drive for moving the pinion assembly can be of any suitable size, shape and construction, and can be made of any suitable material or materials. The drive can be hydraulic, pneumatic, electrical, but preferably hydraulic. In some embodiments the drive comprises a motor for rotating all of the pinions, or a respective motor for rotating a respective pair of pinions, or a respective motor for each pinion. Preferably, each pinion has its own motor to which it is connected by way of a drive shaft. The pinion carrier can comprise at least one motor mount for mounting at least one motor. A motor can be mounted to the pinion carrier such that the drive shaft turns the pinion. Preferably, four motors turn the four pinions individually. Preferably the motor is mounted to the pinion carrier and the drive shaft extends through the pinion carrier.

[0042] The pinion carrier can comprise a 1St rack mounting region for mounting to the 18`
rack. The pinion carrier can comprise a second rack mounting region for mounting to the second rack. These rack mounting regions can be of any suitable size, shape and construction.

[0043] In some embodiments each rack mounting region cooperates with the respective pinion or pinion pair to hold teeth of the rack there between. In some embodiments the teeth of the rack extend between a pinion or pinion pair and rack mounting region.
In some embodiments the rack mounting region extends from the pinion or pinion pair to a location behind the rack, diametrically opposite the teeth of the rack - much like in a clamping arrangement. In some embodiments the rack mounting region extends from the pinion or pinion pair to within a longitudinal passage of an I-beam mast upright to which the rack is connected or along which the rack extends.

[0044] In some embodiments each rack mounting region comprises one, two, three or more retainers that locate within a longitudinal passage of an I-beam mast upright.

[0045] The pinion carrier can comprise a first bracket and a second bracket. These brackets can extend substantially parallel with one another. The brackets can have one or more pinion mounting regions. A first pinion or a first pair of spaced apart pinions can be pinned to the first bracket at pinion mounting regions of the bracket. A
second pinion or a second pair of spaced apart pinions can be pinned to the second bracket at pinion mounting regions of the bracket.

[0046] In some embodiments the pinion carrier can comprise a first bracket associated with the first rack and a second bracket associated with the second rack. The first and second brackets can each comprise a main body extending along a respective longitudinal side of each rack. The main bodies can extend substantially parallel with one another.
Each bracket or bracket main body can comprise one or more pinion mounting regions to which the pinion or pinion pair is pinned. Likewise, each bracket or bracket main body can comprise one or more motor mounting regions for mounting one or more motors. Typically a pinion and motor will be pinned to opposite sides of a bracket or bracket main body.

[0047] Each bracket can comprise a rack mounting region that extends from the pinion or pinion pair or bracket main body to a location behind the rack, as described for previous embodiments of the invention.

[0048] The rack and pinion drive assembly can be mounted to the travelling holding assembly in any suitable way. For example, the travelling holding assembly can be fixedly mounted to the rack and pinion drive assembly or can be adjustably mounted to the travelling holding assembly.

[0049] In some embodiments, the travelling holding assembly is adjustably mounted to the rack and pinion drive assembly such that the travelling holding assembly is able to be moved relative to the mast between a retracted stored/transportable position substantially within the mast and an extended working position substantially externally of the mast such that the travelling holding assembly bowl is axially aligned with the centre of the well bore.

[0050] In some embodiments, the handling system comprises a positioning mechanism for positioning the travelling holding assembly relative to the mast. The positioning mechanism can move the travelling holding assembly between a substantially retracted stored/transportable position within the mast and a substantially extended working position externally of the mast such that the travelling holding assembly is able to clamp to an elongate member.

[0051] The positioning mechanism can be of any suitable construction. In some embodiments the pinion carrier comprises a holding assembly mounting region for mounting to the travelling holding assembly. The holding assembly mounting region can be connected to or extend from each bracket main body. The holding assembly mounting region can be of any suitable size, shape and construction. The holding assembly mounting region can be connected to any suitable part or parts of the travelling holding assembly or indirectly connected to any suitable part or parts of the travelling holding assembly.
The holding region can comprise a support table. The support table can extend from the bowl body and it can be of any suitable shape and construction. In some embodiments, opposed sides of the support table slide within or along the pair of rails.

[0052] In some embodiments the holding assembly mounting region is directly connected to the bowl or bowl body of the travelling holding assembly. In some embodiments the holding assembly mounting region is indirectly connected to the bowl or bowl body of the travelling holding assembly. In some embodiments the holding assembly mounting region is telescoping or telescopic in nature, enabling extension to the working position.

[0053] In some embodiments the holding assembly mounting region comprises a sliding rail system (similar to a sliding drawer), whereby the pinion carrier comprises a pair of rails and the travelling holding assembly is slidable relative to the pair of rails between the stored and working positions. The rails can extend substantially parallel with each other in substantially the same plane, preferably at a right angle to the longitudinal length of the racks or mast. In some embodiments opposed sides of the travelling holding assembly slide within or along the pair of rails.

[0054] In some embodiments the travelling holding assembly can comprise a support table. The support table can extend from the bowl body and it can be of any suitable shape and construction. In some embodiments, opposed sides of the support table, bowl or bowl body slide within or along the pair of rails.

[0055] In some embodiments the holding assembly mounting region comprises a telescopic sliding rail system, whereby the pinion carrier comprises a pair of rails and a pair of telescoping members that are slidable relative to the pair of rails, wherein the telescoping members are connected to the travelling holding assembly or part thereof, such as the support table, bowl or bowl body. The rails and telescoping members can extend substantially parallel with each other in substantially the same plane, preferably at a right angle to the longitudinal length of the racks or mast. The telescoping members can slide along or within the rails, and the sides of the support table, bowl or bowl body can slide along or within the telescoping members.

[0056] In some embodiments the positioning system can comprise at least one hydraulic or pneumatic cylinder connected to the pinion carrier or holding assembly mounting region, for moving the travelling holder assembly between the substantially retracted stored/transportable position within the mast and the substantially extended working position externally of the mast. A piston rod of a cylinder can be pivotally mounted to the travelling holder assembly or part thereof, eg. bowl, bowl body or support table.
Preferably, retraction of the piston rod causes the bowl body to be substantially retracted for storage or transport within the mast, and extension of the piston rod causes the bowl body to be moved externally of the mast to the working position.

[0057] In some embodiments the positioning system can comprise two, three or four hydraulic or pneumatic cylinders connected to the pinion carrier or holding assembly mounting region for moving the travelling holder assembly between the substantially retracted stored/transportable position within the mast and the substantially extended working position externally of the mast.

[0058] In embodiments where the holding assembly mounting region comprises a telescopic sliding rail system, one or two hydraulic or pneumatic cylinders can extend in a substantially parallel manner from the rails to the pair of telescoping members. Likewise, one or two additional hydraulic or pneumatic cylinders can extend in a substantially parallel manner from the rails or pinion carrier to the travelling holding assembly or part thereof, such as the support table, bowl or bowl body.

[0059] In some embodiments, a first pair of hydraulic or pneumatic cylinders is connected to the rails and to the telescoping members, and an additional hydraulic or pneumatic cylinder is connected to one of the rails and the support table of the travelling holder assembly. In this embodiment, opposed sides of the support table are able to slide within a respective longitudinal passage of each telescoping member, and each telescoping member is able to slide within a respective longitudinal passage of each rail, such that in the retracted/stored position the sides of the support table are substantially nested within the telescoping members and the telescoping members are substantially nested within the rails.

[0060] The handling system can have an approximately 9,000 kg push and pull capacity, although this may vary. For example, depending on the rig size, the capacity could be lower or higher, eg. 10,000 kg.

[0061] The handling system can comprise an inverted slip assembly fixed to a top of a BOP stack. The inverted slip assembly can contain upward and downward forces.
The inverted slip assembly can be utilised to hold the elongate member in place so the travelling holding assembly can be released from the elongate member and re-positioned as required.

[0062] The handling system can comprise a control and monitoring system to manage the operation and status of all major components of the handling system. The system can provide save control through a series of status monitoring sensors providing a programmed PLC logic control unit that can decode information and provide relevant programmed interlock output signals. The system can monitor and store parameters for historical analytics.
The system can have a fault diagnostic function and can be accessed wirelessly. The system can be controlled by a number of apparatus and monitoring can be displayed at an operator's station.

[0063] In some embodiments, the holding assembly can have at least one load sensor for sensing a load. For example, the support table or travelling holding assembly can have a load sensor for sensing a load placed on it when holding an elongate member or when inserting or removing an elongate member.

[0064] The rig can be of any suitable size, shape and construction. The rig is preferably mobile. The rig can be any suitable type of rig, such a well servicing rig or drilling rig.

[0065] The rig can be in the form of a self-propelled truck, self-propelled purpose built carrier, or it could be a trailer that can be used as a base to mount a mast, crown block, travelling block and travelling block winch (draw-works). The rig can utilise two independent systems for hoisting and handling elongate members.

[0066] The rig can have one or more features of conventional rigs. The rig can have a wire rope winching system for hoisting and lowering travelling blocks which can insert and remove elongate members from a well bore. To control the wire rope hoisting/lowering system, a direct driven winch (draw works) can be powered by either a truck diesel engine, or a hydrostatic or electric motor power. The draw works can incorporate a main and an optional sand line drum fixedly mounted to a carrier base. The draw works can hoist the travelling block vertically in the mast over a crown block sheave cluster located at a top of the mast.
The tail of the wire rope can be anchored to a rig chassis via a fixed dead man anchor.

[0067] A travelling block assembly can hoist elongate members from the well bore and lower elongate members into a well bore assembly whilst the well bore has no pressure or is in an overbalanced (greater tubing string weight vs well bore pressure) situation. The draw works can utilise a clutch assembly to transfer drive from a power unit to a hoisting drum where cable is wrapped up during the drum rotation, and the travelling block assembly can then raise in a mast section thereby removing the elongate member/drill string from the well bore. The travelling block can also be lowered for inserting elongate members into the well bore by disconnecting the clutch from the hoisting drum and releasing a set of brakes that holds the drum from rotating.

[0068] The rig can be designed to be used as a snubbing/stripping unit. The function of a stripping unit is to safely control insertion and removal of elongate members from a well bore whilst it is under natural formation pressure. Each elongate member can be approximately 9.5m in length but may vary to shorter or longer lengths. Each section of elongate member is top and bottom threaded and can be connected together whilst being inserted into the well bore to make a tubing string. The elongate member above surface can be secured and forced into the well bore under pressure. An annular BOP stack with a modified element (stripping element) can be used to seal the well bore to the elongate member so no pressure or hydrocarbons can escape during the stripping operation where the elongate member descends into the well bore.

[0069] The stripping unit can comprise three major items integrated into the rig or utilised with to move, hold and seal an elongate member being inserted or removed from the well bore. The rig can utilise a vertical mast with a handling system as described above, located in the bottom section of a telescoping single mast. The travelling holding assembly can be hydraulically extended from its storage position in the mast to over the well bore centre line, in which case it is in its working elongate member handling position.

[0070] The rig can comprise a top head drive rotating system that can be hoisted vertically in the mast using the travelling block. A top head drive unit has the ability to rotate tubing for drilling. The top head drive unit has the capability of attaching hydraulically tilting elevator links used for handling tubulars whilst inserting and removing a tubular from a well bore. The top head drive unit can also tilt for making up (threading into) tubulars in a horizontal plane. The top head drive unit has a torque reaction system for a rotating operation that is transferred into the main mast structure through a full length integral guide beam(s).

[0071] Any of the features described herein can be combined in any combination with any one or more of the other features described herein within the scope of the invention. For example, a feature or integer of a product (or product claim) can be a feature or integer of a method (or method claim) of the present invention, and vice-versa.

[0072] The reference to any prior art in this specification is not, and should not be taken as an acknowledgement or any form of suggestion that the prior art forms part of the common general knowledge.
BRIEF DESCRIPTION OF DRAWINGS

[0073] Various embodiments of the invention will be described with reference to the following drawings, in which:

[0074] Figure la is a driller's side view showing a rig in snubbing/stripping operation with a handling system having a travelling holding assembly in a working position holding a tubular, according to an embodiment of the invention.

[0075] Figure lb is a magnified view of part of figure 1.

[0076] Figure 2 depicts the travelling holding assembly in a retracted position such that a top head drive unit can handle a tubular independently of the handling system.

[0077] Figure 3 is an isometric view of part of the travelling holding assembly of figure 1, with the travelling holding assembly in an extended working position.

[0078] Figure 4 is a side view of that shown in figure 3.

[0079] Figure 5 is a front end view of that shown in figure 3.

[0080] Figure 6 is a side view of that shown in figure 3, but with the travelling holding assembly in a retracted position.

[0081] Figure 7 is an isometric view of part of the handling system of figure 1, with the travelling holding assembly in a retracted stored/transportable position within a mast of the rig.

[0082] Figure 8 is a side view of part of the handling system of figure 7 but shown holding a tubular, with the travelling holding assembly in an extended working position external of the mast.

[0083] Figure 9 is an isometric view of part of the handling system of figure 7 but shown holding a tubular, with the travelling holding assembly in an extended working position external of the mast, but not showing an inverted slips assembly.

[0084] Figure 10 is an isometric view of the handling system of figure 7, extended and holding a tubular.

[0085] Figure 11 is a front view of part of the handling system shown in figure 7, holding a tubular.

[0086] Figure 12 depicts the travelling holding assembly in a retracted stored/transportable position (within a mast ¨ not shown).

[0087] Figure 13 depicts the travelling holding assembly in an extended working position (externally of a mast ¨ not shown), as well as an inverted slips assembly normally connected to a BOP stack (not shown).

[0088] Figure 14 depicts the travelling holding assembly, part of a rack and pinion drive assembly as well as an inverted slips assembly normally connected to a BOP
stack.

[0089] Figure 15 depicts in perspective that shown in figure 14.

DESCRIPTION OF PREFERRED EMBODIMENTS

[0090] In the figures like reference numerals refer to like features.

[0091] The figures show a handling system 1 (1 a, lb) connected to or connectable to a mast 101 of a well servicing rig 100 (although it could be a drilling rig), for inserting or removing tubulars or sucker rods 102 (elongate members' 102) from a well bore 103. The handling system 1 includes a travelling holding assembly la for holding a tubular or sucker rod 102, a rack and pinion drive assembly 2, 3, 4, and an inverted slips assembly lb fixed to a top of a BOP stack 104.

[0092] The rack and pinion drive assembly 2, 3, 4 includes a rack assembly 2 that is connected to or connectable to a rear end of the mast 101, a pinion assembly 3 that operatively engages the rack assembly 2 and to which is mounted the travelling holding assembly la, and a drive 4 for moving the pinion assembly 3 and travelling holding assembly la up or down the mast 101.

[0093] The travelling holding assembly la is in the form of a tubing spider assembly la.
The tubing spider assembly la has a spider bowl body 10, a bodyguard 1 la, llb extending from each opposing side of the bowl body 10, and a passage 12 extending through the bowl body 10 to the opposing sides of the bowl body 10 (see figure 3).

[0094] The travelling holding assembly la includes an inverted slips assembly 13 (not always illustrated in the figures) capable of sustaining upward and downward forces as the tubing spider assembly la moves relative to the rack assembly 2 and mast 101.
The inverted slips assembly 13 wedges a set of dies against the bowl body 10 and the tubular or sucker rod 102 being inserted or removed from the well bore 103. There can be two sets of dies in the inverted slips assembly 13: a lower set 14a for gripping a tubular with forces in an upward direction, and an upper set 14b for gripping a tubular 102 with downward forces.

[0095] As seen in figure 9, the rack assembly 2 includes a 1st rack 20 connected to or connectable to a 1 st upright 101a of the mast 101, and a 2nd rack 21 connected to or connectable to a 2nd upright 101b of the mast 101. Uprights 101a and 101b are each in the form of an I-beam, having a longitudinally extending passage 112a, 112b. Each rack 20, 21 has teeth 20a, 21a that extend laterally relative to a length of the mast 101.
The teeth 20a, 21a are diametrically opposed to the passages 112a, 112b. The and 2' racks 20, 21 can be retrofitted to a mast 101 of a well servicing rig 100 and can be removed from the mast 101 of that same well servicing rig 100 when well servicing has ended. However, the racks 20, 21 can be permanently connected to a mast 101 of a well servicing rig 100.

[0096] The length of each of the 1 st and 2nd racks 20, 21 is approximately 6190 mm such that the tubing spider assembly la can move a tubular or sucker rod 102 a vertical distance of approximately 5.5 m (i.e. a 5.5 m stroke through the rack and pinion drive range).

[0097] The pinion assembly 3 includes a 1st pair of spaced apart pinions 30a, 30b that engage the 1st rack 20, and a 2nd pair of spaced apart pinions 31a, 31b that engage the 2nd rack 21.

[0098] The pinion assembly 3 includes a pinion carrier 33 for guiding each pinion pair 30, 31 relative to each rack 20, 21.

[0099] The pinion carrier 33 includes a first bracket 34 and a second bracket 35. Each bracket 34, 35 includes a main body 34a, 35a extending along a respective longitudinal side of each rack 20, 21. The main bodies 34a, 35a extend substantially parallel with one another.
The bracket main bodies 34a, 35a have pinion mounting regions to which the pinions 30, 31 are pinned. Each bracket main body 34a, 35a includes motor mounting regions for mounting motors 41 of the drive 4. A pinion 30, 31 and motor 41 are pinned to opposite sides of the bracket main body 34a, 35a. The pinion carrier 33 includes adjustment/retaining rods 75 for retaining the main body 34a, 35a, as seen in figure 5.

[00100] Each bracket 34, 35 includes a rack mounting region 34b, 35b that extends from the bracket main body 34a, 35a and pinions 30, 31 to a location behind the rack 20, 21 within a longitudinal passage 112a, 112b of the uprights 101a and 101b, as best seen in figures 3 and 9. Each rack mounting region 34b, 35b includes three retaining lugs 34c, 35c that are received within and slide within the longitudinal passages 112a, 112b, as best seen in figures 4 and 6.

[00101] The drive 4 is hydraulically driven and includes a motor 41 for turning each pinion 30, 31 (hydraulic hoses not shown). Each pinion 30, 31 has its own motor 41 to which it is connected by way of a drive shaft extending through the respective pinion mounting region 34b, 35b/bracket main body 34a, 35a.

[00102] The handling system 1 includes a travelling holding assembly positioning mechanism 60 for positioning the travelling holding assembly la relative to the mast 101.
The positioning mechanism 60 can move the travelling holding assembly la between a retracted stored transportable position 61 within the mast 101 (see circle 61 in figure 3) and an extended working position 62 externally of the mast 101 (see circle 62 in figure 3) such that the travelling holding assembly la is able to clamp to a tubular or sucker rod 102 and is positioned centrally of the well bore 103.

[00103] The positioning mechanism 60 or travelling holding assembly 1 a includes a support table 66 that is secured to and extends from the spider bowl body 10.

[00104] The positioning mechanism includes the pinion carrier 33 having a holding assembly mounting region 36, 37 for mounting to the travelling holding assembly I a. The holding assembly mounting region 36, 37 is connected to and extends from each bracket main body 34a, 35a.

[00105] The holding assembly mounting region 36, 37 includes a telescopic sliding rail system whereby a rail 36a, 37a extends substantially horizontally across each bracket main body 34a, 35a. Each rail 36a, 37a is in the form of a U- or C-shaped beam having a longitudinally extending passage. The holding assembly mounting region 36, 37 further includes a pair of telescoping members 36b, 37b, each of which is received within and slidable within a rail 36a, 37a. The holding assembly mounting region 36, 37 further includes the telescoping members 36b, 37b each being connected to a side 36c, 37c of the support table 66.

[00106] The positioning mechanism includes three hydraulic cylinders. A
first pair of hydraulic cylinders 64, 65 is pivotally connected to the rails 36a, 37a as well as to the telescoping members 36b, 37b. A further hydraulic cylinder 69 is pinned to rail 36a as well as to side 36c of the support table 66.

[00107] In this way, opposed sides 36c, 37c of the support table 66 are able to slide within a respective longitudinal passage of each telescoping member 36b, 37b, and each telescoping member 36b, 37b is able to slide within a respective longitudinal passage of each rail 36a, 37a, such that in the retracted/stored position the sides 36c, 37c of the support table 66 are substantially nested within the telescoping members 36b, 37b and the telescoping members 36b, 37b are substantially nested within the rails 36a, 37a.

[00108] Retraction of each piston 64, 65, 69 rod causes the spider bowl body 10 to be retracted for storage or transport within the mast 101 (as seen in figure 2, 6, 7 and 12), and extension of each piston rod 64, 65, 69 causes the spider bowl body 10 to be moved externally of the mast 101 to the working position (as seen in figures 1, 2, 3, 4, 8, 9, 10 and 15).

[00109] The holding assembly la has at least one load sensor for sensing a load. For example, the support table 66 or pinion carrier 33 can have a load sensor 70 for sensing a load placed on it when holding a tubular 102 or when inserting or removing a tubular 102.

[00110] Referring now to figures 1 and 2, these show a rig 100 in the form of a self-propelled truck/self-propelled purpose built carrier (or it could be a trailer) that is used as a base to mount a mast 101, crown block 110, travelling block 111 and travelling block winch 112 (draw-works). The rig 100 utilises two independent systems for hoisting and handling tubulars 102:

[00111] 1. A wire rope winching system 115 is utilised as the primary method to hoist and lower the travelling blocks 111 which will insert and remove tubulars 102 from a well bore 103. To control the wire rope hoisting/lowering system a direct driven winch (draw-works) is powered by either a truck diesel engine, or a hydrostatic or electric motor power. The draw-works incorporates a main and an optional sand line drum fixedly mounted to the carrier base. The draw-works hoists the travelling block 111 vertically in the mast 101 over a crown block 110 sheave cluster located at the top of the mast 101. The tail of the wire rope is then anchored to the rig chassis via a fixed dead man anchor. This method is used to insert/remove tubular 102 and sucker rods from a well bore 103.

[00112] The travelling block assembly 111 is suitable for hoisting tubulars 102 from the well bore 103 and lowering tubulars 102 into the well bore assembly 114 whilst the well bore 103 has no pressure or is in an overbalanced (greater tubing string weight vs well bore pressure) situation. The draw works utilises a clutch assembly to transfer drive from the power unit to a hoisting drum where cable is wrapped up during the drum rotation, and the travelling block 111 assembly then raises in the mast 101 section thereby removing the tubular 102 from the well bore 103 tube by tube. The travelling block 111 can also be lowered for inserting tubulars 102 into the well bore 103 by disconnecting the clutch from the hoisting drum and releasing a set of brakes that holds the drum from rotating.

[00113] 2. The rig 100 is designed to be used as a snubbing/stripping unit.
The function of the stripping unit is to safely control insertion and removal of tubulars 102 from a well bore 103 whilst it is under natural formation pressure. Each tubular 102 is approximately a 9.5m but may vary to shorter or longer lengths. Each section of tubular 102 is top and bottom threaded and is connected together whilst being inserted into the well bore 103 to make a tubing string. The tubular 102 above surface must be secured and forced into the well bore 103 under pressure. An annular BOP stack 104 with a modified element (stripping element) is used to seal the well bore 103 to the tubular 102 so no pressure or hydrocarbons can escape during the stripping operation where the tubular 102 descends into the well bore 103.

[00114] The stripping unit consists of three major items integrated into the rig 100 assembly or utilised with to move, hold and seal a tubular 102 being inserted or removed from the well bore 103. The rig 100 utilises a vertical mast 101 with a handling system 1 as described above, located in the bottom section of a telescoping single mast 101. The travelling holding assembly la can be hydraulically extended from its storage position in the mast 101 section to over the well bore 103 centre line, in which case it is in its working tubular handling position. The travelling holding assembly 1 a includes an inverted slips assembly 13 or hydraulic rotary inverted slips assembly capable of sustaining upward and downward forces as it transverses vertically along the lower section of the mast 101. The inverted slips assembly 13 wedges a set of dies against the travelling spider bowl body 10 and the tubular 102 being inserted or removed from the well bore 103.

[00115] There are two sets of dies in the inverted slips assembly 13 - a lower set 14a for gripping a tubular 102 with forces in an upward direction and an upper set 14b for gripping a tubular 102 with downward forces. It is anticipated that this design will allow a ¨5.5 m stroke through the rack and pinion range with approximately 9,000 kg push and pull capacity. The travelling holding assembly la is able to be retracted into the mast 101 into a stored/transportable position by use of the hydraulic cylinders 64, 65, 69 and slide assembly when not in use. At this point the rig 100 will function utilising its travelling block 111 and top drive assembly 114 hoisted by the draw-works.

[00116] In addition to the travelling holding assembly la, an inverted slips assembly lb is fixed to the top of the BOP stack 104. Again this assembly lb is inverted for containing upward and downward forces. This inverted slips assembly lb is utilised to hold the tubulars 102 in place so the travelling holding assembly la can be released and re-positioned as required.

[00117] A spherical BOP 104 with a sacrificial element (stripping BOP) is utilized for the stripping operation. The item will be located above the primary class 3 well control stack 114. The stripping BOP 104 is controlled by the driller at the stripping control station.
Available at the control station are controls required to run the stripping system.

[00118] The design utilizes a top head drive rotating system 116 that is hoisted vertically in the mast 101 using the travelling block 111. The top head drive rotating system 116 has the ability to rotate tubing for drilling. The top head drive rotating system 116 has the capability of attaching hydraulically tilting elevator links used for handling tubulars 102 whilst inserting and removing from well bore 103. The top head drive rotating system 116 can also tilt for making up (threading into) to tubulars 102 in a horizontal plane. The top head drive rotating system 116 has a torque reaction system for rotating operation that is transferred into the main mast structure through a full length integral guide beam(s).

[00119] Although not shown, the handling system 1 includes a control and monitoring system to manage the operation and status of all components of the handling system 1. The system provides safe control through a series of status monitoring sensors providing a programmed PLC logic control unit that can decode information and provide relevant programmed interlock output signals. The system monitors and stores parameters for historical analytics. The system has a fault diagnostic function and can be accessed wirelessly. The system is controllable by a number of apparatus and monitoring is displayed at an operator's station.

[00120] In the present specification and claims (if any), the word 'comprising' and its derivatives including 'comprises" and 'comprise' include each of the stated integers but does not exclude the inclusion of one or more further integers.

[00121] Reference throughout this specification to 'one embodiment' or 'an embodiment' means that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment of the present invention.
Thus, the appearance of the phrases 'in one embodiment' or 'in an embodiment' in various places throughout this specification are not necessarily all referring to the same embodiment.
Furthermore, the particular features, structures, or characteristics may be combined in any suitable manner in one or more combinations.

[00122] In compliance with the statute, the invention has been described in language more or less specific to structural or methodical features. It is to be understood that the invention is not limited to specific features shown or described since the means herein described comprises preferred forms of putting the invention into effect. The invention is, therefore, claimed in any of its forms or modifications within the proper scope of the appended claims (if any) appropriately interpreted by those skilled in the art.

Claims (20)

1. An elongate member handling system connected to or connectable to a mast of a rig, said handling system comprising:
a travelling holding assembly for holding an elongate member in axial alignment with a well bore; and a rack and pinion drive assembly to which is mounted the travelling holding assembly such that the travelling holding assembly travels up or down the mast so as to insert the elongate member into the well bore or remove the elongate member from the well bore.

2. The elongate member handling system of claim 1, wherein the rack and pinion drive assembly comprises:
a rack assembly that is connected to or connectable to the rig;
a pinion assembly that operatively engages the rack assembly and to which is mounted the travelling holding assembly; and a drive for moving the pinion assembly such that the travelling holding assembly travels up or down the mast so as to insert the elongate member into the well bore or remove the elongate member from the well bore.

3. The elongate member handling system of claim 2, wherein the travelling holding assembly comprises a bowl and an inverted slips assembly or hydraulic rotary slips inverted assembly capable of sustaining upward and downward forces as the travelling holding assembly moves up or down the mast.

4. The elongate member handling system of claim 2, wherein the travelling holding assembly is in the form of at least one tubing spider assembly comprising a spider bowl body, a bodyguard extending from one or more opposing sides of the spider bowl body, and a passage extending through the spider bowl body to the opposing sides of the spider bowl body, wherein the passage is in axial alignment with the well bore when inserting or removing the elongate member from the well bore.

5. The elongate member handling system of any one of the preceding claims, wherein the rack assembly comprises a first rack connected to or connectable to a first upright of the mast, and a second rack connected to or connectable to a second upright of the mast, wherein each said rack comprises teeth that extend laterally relative to a length of the mast.

6. The elongate member handling system of claim 5, wherein the first and second uprights are each in the form of a beam having a longitudinally extending passage, the teeth of the first rack and the longitudinal passage of the first upright are diametrically opposed to each other, and the teeth of the second rack and the longitudinal passage of the second upright are diametrically opposed to each other.

7. The elongate member handling system of claim 6, wherein the pinion assembly comprises a first pair of spaced apart pinions that operatively engage the first rack and a second pair of spaced apart pinions that operatively engage the second rack.

8. The elongate member handling system of claim 7, wherein the pinion assembly comprises a pinion carrier holding each said pinion pair relative to each said rack, wherein the pinion carrier together with the pinion pairs clamp teeth of the first and second racks there between.

9. The elongate member handling system of claim 8, wherein the pinion carrier comprises a first rack mounting region for mounting to the first rack, and the pinion carrier comprises a second rack mounting region for mounting to the second rack.

10. The elongate member handling system of claim 9, wherein each said rack mounting region extends from the respective pinion pair to within the respective longitudinal passage of the upright to which the rack is connected.

11. The elongate member handling system of claim 10, wherein each said rack mounting region comprises one or more retainers that locate within the longitudinal passage of the upright.

12. The elongate member handling system of claim 11, wherein the travelling holding assembly is adjustably mounted to the rack and pinion drive assembly such that the travelling holding assembly is able to be moved relative to the mast between a retracted stored/transportable position substantially within the mast and an extended working position substantially externally of the mast such that the travelling holding assembly bowl is axially aligned with a centre of the well bore.

13. The elongate member handling system of claim 12, wherein the handling system comprises a positioning mechanism for positioning the travelling holding assembly relative to the mast, between a substantially retracted stored/transportable position within the mast and a substantially extended working position externally of the mast such that the travelling holding assembly is able to clamp to an elongate member.

14. The elongate member handling system of claim 13, wherein the pinion carrier comprises a holding assembly mounting region for mounting to the travelling holding assembly.

15. The elongate member handling system of claim 14, wherein the holding assembly mounting region is telescoping or telescopic in nature, enabling extension to the working position.

16. The elongate member handling system of claim 15, wherein the holding assembly mounting region comprises a sliding rail system whereby the pinion carrier comprises a pair of rails and the travelling holding assembly is slidable relative to the pair of rails between the stored and working positions.

17. The elongate member handling system of claim 16, wherein the positioning system comprises at least one hydraulic or pneumatic cylinder connected to the pinion carrier or holding assembly mounting region, for moving the travelling holder assembly between the substantially retracted stored/transportable position within the mast and the substantially extended working position externally of the mast.

18. A rig comprising the elongate member handling system according to any one of the preceding claims.

19. A method of servicing a well, said method comprising the steps of:
optionally connecting an elongate member handling system as described according to any one of the preceding claims to a mast of a rig, and operating the elongate member handling system to insert the elongate member into a well bore or remove the elongate member from a well bore.

20. A method of inserting or removing an elongate member from a well bore, said method comprising the step of:
optionally connecting an elongate member handling system as described according to any one of the preceding claims to a mast of a rig; and operating the elongate member handling system so as to insert the elongate member into the well bore or remove the elongate member from the well bore.