CA1185228A - Well pipe jack - Google Patents
Well pipe jackInfo
- Publication number
- CA1185228A CA1185228A CA000403140A CA403140A CA1185228A CA 1185228 A CA1185228 A CA 1185228A CA 000403140 A CA000403140 A CA 000403140A CA 403140 A CA403140 A CA 403140A CA 1185228 A CA1185228 A CA 1185228A
- Authority
- CA
- Canada
- Prior art keywords
- casing
- rig
- mast
- drilling
- string
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired
Links
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
- E21B19/02—Rod or cable suspensions
- E21B19/06—Elevators, i.e. rod- or tube-gripping devices
- E21B19/07—Slip-type elevators
Abstract
Abstract of the Disclosure A jack for lowering casing from a drilling rig into a well, including a plurality of piston and cylinder mechanisms extending vertically at different sides of the well axis and supported at their lower ends from a base, a first upper structure extending between upper ends of the cylinders of those mechanisms and supported from the base through the cylinders, a second upper structure supported by and movable with the pistons, and gripping units carried by the two structures and releasably engageable with the casing to lower it in steps by relative vertical actuation of the two structures by the piston and cylinder mechanisms.
Description
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13 l 1~ l 15 ¦ Background of the_Invention 16 ¦ This invention relates to improved jacking mechanisms 17 ¦ for lowering casing or other pipe into a well.
18 ¦ In our prior copending application serial No. 377,909 19 ¦ entitled "Well Casing Jack Mechanism", we have disclosed a casing 20 ¦ jack which is adapted to be positioned in a well drilling rig 21 ¦ and which can be utilized for lowering a string of casing into 22¦ a well drilled by the rig. The jack is especially desirable for 23 ¦ U52 in connection with deep wells in which the casing string may ~41 be too heavy to be suspended and lowered by the traveling block 251 and other conventional equipment of the rig. The jack of that 26¦ prior application may be positioned in the rig at essentially the 27 locatîon at which the rotary table is mounted during drilling, 28 and preferably includes piston and cylinder mechanisms at differ-29 ent sides of the well axis for relatively vertically actuating two gripping units to progressively lower the casing.
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13 l 1~ l 15 ¦ Background of the_Invention 16 ¦ This invention relates to improved jacking mechanisms 17 ¦ for lowering casing or other pipe into a well.
18 ¦ In our prior copending application serial No. 377,909 19 ¦ entitled "Well Casing Jack Mechanism", we have disclosed a casing 20 ¦ jack which is adapted to be positioned in a well drilling rig 21 ¦ and which can be utilized for lowering a string of casing into 22¦ a well drilled by the rig. The jack is especially desirable for 23 ¦ U52 in connection with deep wells in which the casing string may ~41 be too heavy to be suspended and lowered by the traveling block 251 and other conventional equipment of the rig. The jack of that 26¦ prior application may be positioned in the rig at essentially the 27 locatîon at which the rotary table is mounted during drilling, 28 and preferably includes piston and cylinder mechanisms at differ-29 ent sides of the well axis for relatively vertically actuating two gripping units to progressively lower the casing.
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2 ¦ The present invention provides improvements in
3 ¦ a jack of the above discussed general type, and in particu-¦ lar is in certain respects especially concerned with the 5¦ manner in which the load forces exerted by the weight of the 61 string being lowered are transmitted to the ground at the 71 rig location with minimum structure and preferably without 81 applying those forces to the rig framework i-tself. These 9 ¦ results are achieved in large part by utilization of the 10 ¦ cylinders of the piston and cylinder mechanisms which power 11 the jack as load supporting members for transmitting the 12 ¦ load forces to a ground supported base. ~hes~ cylinders 13 ¦ extend vertically at dif~erent sides of the well axis, 14 ¦ preferably at diametrically opposite locations with respect 15 ¦ to that axis, and have lower portions which are supported 16 ¦ on the base. A first pipe gripping structure is supported 17 ¦ by upper portions of the power cylinders in a relation 18 ¦ transmitting load forces from that gripping structure 19 ¦ downwardly through the cylinders, and thus supporting the 20 ¦ gripping structure from the base directly through those 21 ¦ cylinders. The pistons associated with the cylinders have 22 ¦ rods projecting upwardly beyond the cylinders with a second 231 pipe gripping structure being supported by the pistons, and 24¦ with gripping means being carried by both o~ the two upper 251 structures for releasably gripping, supporting and lowering 26¦ the .asing. In assembling the jack, the two cylinders may 2~1 be inserted through openings in a locating template, which 28¦ then functions to retain the cylinders in a predetermined 29 spaced relation.
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2 ¦ The above and other features and objects of the invention 3 ¦ will be better understood from the following detailed description
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2 ¦ The above and other features and objects of the invention 3 ¦ will be better understood from the following detailed description
4 ¦ of the typical embodiment illustrated in the accompanying drawings
5 ¦ in which:
6 ¦ Fig. 1 is a fragmentary diagrammatic representation of
7 ¦ a drilling rig during a well drilling operation;
8 ¦ Fig. 2 shows the rig of Fig. 1 with the rotary table
9 ¦ removed and a jack embodying the present invention positioned in
10 ¦ the rig;
11 ¦ Fig. 3 is an enlarged fragmentary view, partially in
12 ¦ section, of the jack of Fig. 2;
13 ¦ Fig. 4 is a fragmentary side view taken on line 4-4
14 ¦ of Fig. 3;
Fig. 5 is a top plan view taken on line 5-5 of 16 ¦ Fig. 3;
17 ¦ Figs. 6 and 7 are horizontal sections taken on lines 18 ¦ 6-6 and 7-7 respactively of Fig. 3;
19 ¦ Fig. 8 is a somewhat diagrammatic vertical section 20 ¦ through one of the slip type gripping units taken on line 8-8 21 ¦ of Fig. 5; and 22 ¦ Figs. 9, 10 and 11 ~re diagrammatic views representing 23 ¦ different steps during assembly of the jack on the rig.
26 In Fig. 2, there is represented at 10 a well drilling 27 rig having a framework structure which includes an upwardly 28 projecting mast or derrick 11, a horizontal rig floor 12 at the 29 lower end of the derrick and spaced above ground level 13, and a substructure 14 supporting the floor and mast. The draw works 31 lS acts through a line 15 to raise and lower a traveling block 17 32 for suspending the drill string and other equipment in the well.
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1 FigO 2 shows the rig after completion o~ the actual drilling of 2 a well 18 into the earth, and with a jack 19 embodying the present 3 invention positioned in the rig for lowering a string of casing 4 20 into the well.
Fig. 1 shows the rig during the drilling operation, at 6 which time a conventional rotary table 21 is positioned within a 7 central recess or opening 22 in the rig Eloor 12, being supported 8 on a pair of parallel beams 23 extending across the underside of 9 recess 22. Beams 23 may be identical I beams as sho~m, and be positioned at opposite sides of the vextical axis 24 of the rig 11 and well, and be connected to the substructure 14 of the rig at 12 opposite ends of the beams. Rotary table 21 acts through the 13 usual master bushing and kelly bushing diagrammatically represented 1~ at 25 to drive a non-circular kelly 26 and connected drill pipe 27 rotativel~ about axis 24 to drill the well.
16 The jack 19 may have a load handling capacity which is 17 well in excess of the capacity of the rig framework structure, 18 including mast 11 and substructure 14, and the draw works and 19 actuated line 16, crown block 28, traveling block 17, and other related equipment. For e~ample, the draw works, rig framework, 21 and related equipment for suspending drill string 27 may be 22 capable of supporting and driving a drill string up to a weight of ~3 but not exceeding 500 tons. It is assumea that this load capacity 24 is entirely adequate for supporting the drill string to a desired depth, but cannot support the greater weight of the string of 2~ casing ~0 required to line a hole of that same depth. The jack 19, 27 therefore, has a load supporting capacity substantially greater tha ~8 the draw works, etc., say for example up to 1,000 tonst to thus a 29 dapt the rig for lowering the very heavy casing without the necess-ity for using a heavier capacity rig during the drilling operation.
31 Referring now to Fig. 3, jack 19 includes two typically 3~ identical piston and cylinder mechanisms 29 supported from their I
1 ¦ lower ends Oll a base 30 which is in turn supported from the ground.
¦ To assist in taking the heavy loads of the casing string, a 3¦ concrete foundation 31 may be formed in a cellar or recess 32 41 in the ground, with two horizontal metal plates 33 positioned 51 on the upper surface of the foundation at ground level to 6 engage and support base 30. Casing 20 extends downwardly between the two piston and cylinder mechanisms 29, and through 8 blowout preventers 34 connected to the top of the well.
9 Base 30 preferably takes the form of a rigid structure fabricated from a number of metal parts suitably bolted or other-11 wise secured together and forming two similar upwardly projecting 12 portions 35 and 36 at opposite sides of the casing and well axis, 13 with these portions 35 and 36 being rigidly connected together by 14 portions 37 and 38 (Fig. 7) located just above ground level and low enough to be received beneath laterally projecting portions 1~ 40 of the lowermost blowout preventer. The upper extremities 1~ of upwardly projecting portions 35 and 36 of base 30 may take the 18 form of hcrizontal metal plates 39 on which cylinders 29 rest.
19 The two piston and cylinder mechanisms 23 may be identi-cal, and extend vertically along two parallel vertical axes 40 and 21 41 which are parallel to and at diametrically opposite sides of and 22 spaced equal distances from the main vertical axis 24 of the rig 23 and well. The cylinder 42 of each of the piston and cylinder mech-24 anisms 29 has a tubular sidewall 43 which may be internally and externally cylindrical about axis 40 or 41, and which is closed 26 at its lower end by a horizontal bottom wall 44 engaging and 27 appropriately welded or otherwise secured to side wall 42 and 28 resting on the upper surface of the corresponding top plate 39 of base 30. The lower end of the cylinder may be reta-ined against horizontal movement from a desired position on the base 31 structure by a number of locating lugs or fingers 45 welded to 32 and projecting upwardly from plate 39 at locations to engage the 1 ¦ outer surface of -the cylillder at clrcularly spaced locations and 2 ¦ form a socket structure into which the cylinder is insertable 3 ¦ downwardly in locatlng rela-tion. As seen in Fig. 7, four such 4 ¦ lugs 45 may be provided at equally spaced locations about each of 51 the cylinders. The upper ends of these lugs 45 may have camming 61 surfaces 46 which are inclined to advance downwardly as -they 71 advance radially inwardly toward axis 40 or 41 to deflect the 8¦ cylinder to a centered position as it moves downwardly within the 9¦ socket structure.
10¦ The piston 47 of each of the piston and cylinder 11¦ mechanisms slidably engages he cylinder and is reciprocable 12 ¦ upwardly and downwardly along axis 40 or 41 relative thereto, 13 ¦ and has a piston rod 48 projecting upwardly through the upper 14 ¦ extremity 49 of the cylinder in sealed relation. Pressurized
Fig. 5 is a top plan view taken on line 5-5 of 16 ¦ Fig. 3;
17 ¦ Figs. 6 and 7 are horizontal sections taken on lines 18 ¦ 6-6 and 7-7 respactively of Fig. 3;
19 ¦ Fig. 8 is a somewhat diagrammatic vertical section 20 ¦ through one of the slip type gripping units taken on line 8-8 21 ¦ of Fig. 5; and 22 ¦ Figs. 9, 10 and 11 ~re diagrammatic views representing 23 ¦ different steps during assembly of the jack on the rig.
26 In Fig. 2, there is represented at 10 a well drilling 27 rig having a framework structure which includes an upwardly 28 projecting mast or derrick 11, a horizontal rig floor 12 at the 29 lower end of the derrick and spaced above ground level 13, and a substructure 14 supporting the floor and mast. The draw works 31 lS acts through a line 15 to raise and lower a traveling block 17 32 for suspending the drill string and other equipment in the well.
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1 FigO 2 shows the rig after completion o~ the actual drilling of 2 a well 18 into the earth, and with a jack 19 embodying the present 3 invention positioned in the rig for lowering a string of casing 4 20 into the well.
Fig. 1 shows the rig during the drilling operation, at 6 which time a conventional rotary table 21 is positioned within a 7 central recess or opening 22 in the rig Eloor 12, being supported 8 on a pair of parallel beams 23 extending across the underside of 9 recess 22. Beams 23 may be identical I beams as sho~m, and be positioned at opposite sides of the vextical axis 24 of the rig 11 and well, and be connected to the substructure 14 of the rig at 12 opposite ends of the beams. Rotary table 21 acts through the 13 usual master bushing and kelly bushing diagrammatically represented 1~ at 25 to drive a non-circular kelly 26 and connected drill pipe 27 rotativel~ about axis 24 to drill the well.
16 The jack 19 may have a load handling capacity which is 17 well in excess of the capacity of the rig framework structure, 18 including mast 11 and substructure 14, and the draw works and 19 actuated line 16, crown block 28, traveling block 17, and other related equipment. For e~ample, the draw works, rig framework, 21 and related equipment for suspending drill string 27 may be 22 capable of supporting and driving a drill string up to a weight of ~3 but not exceeding 500 tons. It is assumea that this load capacity 24 is entirely adequate for supporting the drill string to a desired depth, but cannot support the greater weight of the string of 2~ casing ~0 required to line a hole of that same depth. The jack 19, 27 therefore, has a load supporting capacity substantially greater tha ~8 the draw works, etc., say for example up to 1,000 tonst to thus a 29 dapt the rig for lowering the very heavy casing without the necess-ity for using a heavier capacity rig during the drilling operation.
31 Referring now to Fig. 3, jack 19 includes two typically 3~ identical piston and cylinder mechanisms 29 supported from their I
1 ¦ lower ends Oll a base 30 which is in turn supported from the ground.
¦ To assist in taking the heavy loads of the casing string, a 3¦ concrete foundation 31 may be formed in a cellar or recess 32 41 in the ground, with two horizontal metal plates 33 positioned 51 on the upper surface of the foundation at ground level to 6 engage and support base 30. Casing 20 extends downwardly between the two piston and cylinder mechanisms 29, and through 8 blowout preventers 34 connected to the top of the well.
9 Base 30 preferably takes the form of a rigid structure fabricated from a number of metal parts suitably bolted or other-11 wise secured together and forming two similar upwardly projecting 12 portions 35 and 36 at opposite sides of the casing and well axis, 13 with these portions 35 and 36 being rigidly connected together by 14 portions 37 and 38 (Fig. 7) located just above ground level and low enough to be received beneath laterally projecting portions 1~ 40 of the lowermost blowout preventer. The upper extremities 1~ of upwardly projecting portions 35 and 36 of base 30 may take the 18 form of hcrizontal metal plates 39 on which cylinders 29 rest.
19 The two piston and cylinder mechanisms 23 may be identi-cal, and extend vertically along two parallel vertical axes 40 and 21 41 which are parallel to and at diametrically opposite sides of and 22 spaced equal distances from the main vertical axis 24 of the rig 23 and well. The cylinder 42 of each of the piston and cylinder mech-24 anisms 29 has a tubular sidewall 43 which may be internally and externally cylindrical about axis 40 or 41, and which is closed 26 at its lower end by a horizontal bottom wall 44 engaging and 27 appropriately welded or otherwise secured to side wall 42 and 28 resting on the upper surface of the corresponding top plate 39 of base 30. The lower end of the cylinder may be reta-ined against horizontal movement from a desired position on the base 31 structure by a number of locating lugs or fingers 45 welded to 32 and projecting upwardly from plate 39 at locations to engage the 1 ¦ outer surface of -the cylillder at clrcularly spaced locations and 2 ¦ form a socket structure into which the cylinder is insertable 3 ¦ downwardly in locatlng rela-tion. As seen in Fig. 7, four such 4 ¦ lugs 45 may be provided at equally spaced locations about each of 51 the cylinders. The upper ends of these lugs 45 may have camming 61 surfaces 46 which are inclined to advance downwardly as -they 71 advance radially inwardly toward axis 40 or 41 to deflect the 8¦ cylinder to a centered position as it moves downwardly within the 9¦ socket structure.
10¦ The piston 47 of each of the piston and cylinder 11¦ mechanisms slidably engages he cylinder and is reciprocable 12 ¦ upwardly and downwardly along axis 40 or 41 relative thereto, 13 ¦ and has a piston rod 48 projecting upwardly through the upper 14 ¦ extremity 49 of the cylinder in sealed relation. Pressurized
15 ¦ hydraulic fluid is delivered selectively to either the upper ends
16 ¦ o the cylinders or their lower ends through lines represe;ltel
17 ¦ diagrammatically at 50, from a pressure fluid source 51, under
18 ¦ the control of an operator on rig floor 12 through actuation of
19 ¦ control elements on a panel 52, typically acting through an
20 ¦ appropriate pilot valve assembly. Discharge of pressure fluid
21 ¦from the lower ends of the cylinders and admission of pressure
22¦ fluid to their upper ends causes downward movemen~ of the 231 pistons relative to the cylinders, while reverse connection of 24 the fluid lines actuates the pistons upwardly. During downward movement, the discharge of fluid from beneath the pistons is pre-26 ferably regulatable to different rates by varying the extent to 27 which two adjustable choke valves 53 are opened, to thus afford 28 a precise and reliable control of the rate at which casing 20 29 is lowered by the jack.
The upper ends of cyllnders 42 are located in the 31 desired spaced relationship relative to one another by insertion 1185,'~ ' !3 1 downwardly through a cylinder positioning and anchoring frc~ne or 2 tem~late 54, which may be essentially flat and fabricated of sheet 3 metal parts appropriately welded or otherwise secured together as 4 illustrated in E`igs. 3 and 6. This frame 54 may include two similar spaced parallel rigid sheet metal strips 55 joined rigidly 6 together by transverse connectors 56 to form two spaced typically 7 square openings 57 dimensioned to closely receive cylinders 42 8 and hold their axes 40 and 41 in the proper spaced relation.
9 Intermediate these two openings 57, the frame or template 54 con-tains a typically rectangular central opening 58 dimensioned to 11 allow extension of the casing 20 downwardly therethrough. Before 12 insertion of piston and cylinder mechanisms 29 downwardly through 13 central opening 22 in the rig floor, frame 54 is placed on the 14 upper surfaces of the two horizontal flanges of rotary table supporting beams 23, to allow the piston and cylinder mechanisms 16 to be inserted downwardly through openings 57.
17 .~bove the level of locating template 54, cylinders 42 18 carry on their outer surfaces a number of evenly circularly spaced 19 connector brackets or eye lugs 59 to which there are pivotally connected by horizontal pins 60 a nu~ber of typically U-shaped 21 links 61. Screws 161 extend vertically through openings in links 22 61 and template 54 and may have heads bearing downwardly against
The upper ends of cyllnders 42 are located in the 31 desired spaced relationship relative to one another by insertion 1185,'~ ' !3 1 downwardly through a cylinder positioning and anchoring frc~ne or 2 tem~late 54, which may be essentially flat and fabricated of sheet 3 metal parts appropriately welded or otherwise secured together as 4 illustrated in E`igs. 3 and 6. This frame 54 may include two similar spaced parallel rigid sheet metal strips 55 joined rigidly 6 together by transverse connectors 56 to form two spaced typically 7 square openings 57 dimensioned to closely receive cylinders 42 8 and hold their axes 40 and 41 in the proper spaced relation.
9 Intermediate these two openings 57, the frame or template 54 con-tains a typically rectangular central opening 58 dimensioned to 11 allow extension of the casing 20 downwardly therethrough. Before 12 insertion of piston and cylinder mechanisms 29 downwardly through 13 central opening 22 in the rig floor, frame 54 is placed on the 14 upper surfaces of the two horizontal flanges of rotary table supporting beams 23, to allow the piston and cylinder mechanisms 16 to be inserted downwardly through openings 57.
17 .~bove the level of locating template 54, cylinders 42 18 carry on their outer surfaces a number of evenly circularly spaced 19 connector brackets or eye lugs 59 to which there are pivotally connected by horizontal pins 60 a nu~ber of typically U-shaped 21 links 61. Screws 161 extend vertically through openings in links 22 61 and template 54 and may have heads bearing downwardly against
23 the links and nuts bearing upwardly against the template to retain
24 the cylinders against upward movement relative to the template.
25 The cylinders are, however, free to settle slightly downwardly
26 relative to the template by virtue of the illustrated vertical
27 spacing between links 61 and the template and since the screws upon
28 such settling movement can move downwardly relative to the template
29 and within the openings in the template through which the screws
30 extend.
31 ¦ The template may be held in fixed position by attachment
32 to beams 23, as by a number of L-shaped clamps or fasteners 123 52,.t3 1 ¦ ex-tending through openings in template 54 and having lower ends 2 ¦ turned beneath the beam flanges, with clamps 123 being tigh-tened 3 ¦ against those flanges by threaded connecti.on of nuts 223 onto 41 upper ends oE elements 123.
51 Just above the connector lugs 59, each of the cylinders ~¦ carries an annular flange 62, which may be formed as a rigid ring 71 f metal or the like welded to the outside of the cylinder. Above 8 ¦ flanges 62, the two cylinders 42 carry and support a first ~rans-9 ¦ verse upper structure 63 on which a first casing gripping unit 64 10 ¦ is carried. The upper ends of piston rods 48 similarly carry and 11 ¦support, and also actuate vertically, a second upper support 12 ¦structure 65 on which a second gripping unit 66 is carried. Struc-1~ ¦ture 65 may typically have the plan view outline configuration 1~ ¦illustrated in Fig. 5, and as seen in Fig. 4 may include upper 15 ¦and lower horizontal rigid metal plates 67 secured together by 16 vertically extending mem~ers 68 configured to form a relatively 17 large central vertical opening 63 through unit 65 and centered 18 about axis 24, and two smaller openings 70 at opposite sides of 19 opening 69 and centered about axes 40 and 41 of the cylinders.
Openings 70 are dimensioned to exactly receive and closely 21 confine the reduced diameter ends 71 of piston rods 48, with upwardly facing annular shoulders 72 on the piston rods 23 engaging upwardly against bottom plate 67 of unit 65 to ~4 support the latter from the piston rods. Snap rings 73 2~ received within grooves in the upper extremities of the piston 26 rods may engage the upper plate 67 about openings 70 to lock unit 65 on the piston rods for upward and downward movement 28 therewith. Gripping unit 66 has a horizontal undersurface 74 29 engaging the upper horizontal surface of the ~op plate 67 of support structure 65, with unit 66 being centered with respect 31 to axis 24 by reception between a number of evenly circularly 32 spaced locating lugs 75 (typically four such lugs) secured to ~ 15~
1 top plate 67 and preferably having upper camming surfaces 76 2 inclined to advance downwardly as they advance radially inwardly 3 to center unit 66 on support structure 65.
4 The cylinder mounted support structure 63 may be constructed essentially the same as the above discussed structure 6 65, having a central relatively large opening 77 and two smaller 7 openings 78 at diametrically opposite locations, but with these 8 openings 78 being sufficiently larger than the corresponding 9 openings 70 of upper structure 65 to exactly receive and closely confine cylinders 42 in locating relation. Gripping unit 64 may 11 be received on the upper surface of top horizontal plate 79 of 12 structure 63, and be centered and located thereon by lugs 175 13 corresponding to the discussed lugs 75 of structure 65.
lg The two gripping units 64 and 66 may be identical and of a known type having wedge slips for releasably gripping 16 and supporting the casing. The upper of these gripping units 66 17 is illustrated somewhat diagrammatically in Fig. 8, as including 18 an outer annular rigid body 80 having inner downwardly tapering 1~ slip bowl surfaces 81 engageable with wedge slips 82 to cam them inw~rdly into gripping engagement with the casing upon downward 22 movement of the slips relative to body 80. The inner surfaces 23 8~ of the slips are formed to have gripping dies or teeth 84 24 shaped to bite into the casing surface and effectively support it.
~The slips are suspended by a ring 85, to which the slips are connected by links 86 allowing radially inward and outward move-27 ment as the slips are actuated upwardly and downwardly, with such 28 upward and downward actuation being effected by a number of circularly spaced piston and cylinder mechanisms 87 having their 29 cylinders connected to body 80 and their pistons connected to ring 85. As will be understood, when the slips are in their 33l full line active positions of Fig. 8, the casing is supported by the gripping unit, b~lt when the slips are actuated to their _g_ ~ 352~3 1 upper ~roken line retrac-ted positions oE Fig. 8 -the casing is free 2 for movement downwardly relative to the slips.
3 To recapitulate briefly a cycle oE operation of the 4 illustrated equipment, assume that the rig is first in the condi-tion of Fig. 1, with rotary table 21 positioned within recess 6 22 in rig floor 12, and with the rotary table acting to turn kelly 7 26 and the connected drill string while the string is suspended 8 and gradually lowered by traveling block 17 under the control 9 of draw works 15. The rig framework, draw wo ks, traveling block, line 16, etc., may typically have a maximum load handling 11 capacity of 500 tons, and the entire weight of the drill string 12 at maximum hole depth may be safely within that limit. If the 13 casing to be lowered into the hole is beyond that limit, rotary 1~ table 21 is removed from the rig, and jack 19 is positioned in the rig as illustrated in Fig. 2, with that jack typically having 16 a capacity up to 1,000 tons and adequate to support the very 17 neavy casing. Figs 9 through 11 illustrate diagra!~matically 18 several steps which may be followed in assembling the jack in 1~ the rig. A first such step is to position the cylinder locating frame or template 54 in the rig, by lowering template 54 down-~1 wardly into recess 22 in the rig floor to a position of support ~2 on the upper surfaces of beants 23, as seen in Fig. 9, and by then 23 attaching the template to beams 23 by elements 123. After such 24 positioning and anchoring of template 5~, the two piston and cy-linder mechanisms 29 are lowered downwaraly from above the level 26 of the rig floor and along axes 40 and ~1 respectively through ~8 openings 57 of the locating frame or template 54 and to positions of support on base 30, with the lower ends of the cylinders 29 received within the socket structures formed by lugs 45. This inserted position of the piston and cylinder mechanisms is 31 lllustrated in Fig. 9.
32 The next step is to lower the first of the upper support 1 ¦ structures 63 downwardly relative to the piston and cylinder 2¦ mechanisms, from the broken line position of Fig. 10 to the fu:Ll 31 line position of that figure in which the cylinders are received 41 wi-thin openings 78 in structure 63, and the undersurface oE
5~ bottom plate ~8 of structure 63 annularly engages the upper hori-6 ¦ zontal surfaces of flanges 62 abou-t openings 78 to effectively 7 ¦ support structure 63 through cylinders 42. Gripping unit 64 may 8 ¦ then be positioned on structure 63, and the second of the upper 9 ¦ support structures 65 may then be moved downwardly from the broken 10 ¦ line position of Fig. 11 to the ~ull line position of that figure, 11 in which the upper ends of the piston rods are received within 12 openings 70 in structure 65 and that structure is effectively 13 supported and vertically actuable by the piston rods and retained 1~ thereon by rings 73. The upper gripping unit 66 may then be placed on structure 65 to place the jack in condition for 16 operation.
17 Each length or section of casing 20 may be lowered by 18 traveling block 17 along axis 24, as illustrated in Fig. 2, to 19 a position for connection to the remainder of the casing string suspended in the well. During such lowering of a length of 21 casing pipe, the casing string already in the well is gripped by 2~ gripping unit 64, and the casing section to be added is moved 23 downwardly through the upper gripping unit 66 as seen in Fig. 2 24 and appropriately connected to the upper end of the suspended string. During or after such connection of a casing section to 26 the string, the piston and cylinder mechanisms 29 may be actuated to raise their pistons and upper support unit 65 and the carried 2~ upper gripping unit 66 to the broken line position of Fig. 2, 29 with the slips of that gripping unit in released condition, follow-ing which those slips may be actuated to cause unit 66 to effec-31 tively grip and support the casing string. Lower gripping unit 32 64 may then be released, by upward actuation of its slips, to 1 ¦ ree the casing string for downward movement under the con-trol 2 ¦ of ja~k 19. Such downward movement ls effected by actuating the 3 ¦ valve controls on panel 52 to cause discharge of pressure fluid 4 ¦ from the lower ends of cylinders 42 and admission of pressure 5 ¦ fluid to the upper ends of those cylinders, with the discharge 6 ¦ from the lower ends being regulated by choke valves 53 to lower 7 ¦ the pistons and connected parts at a controlled variable rate of 8 ¦ speed satisfying the operating conditions which are encountered.
9 ¦ After the upper gripping unit 66 and its support structure 65 have been lowered to the full line position of Fig. 2, the slips 11 of the lowering gripping unit 64 are actuated to again support 12 the string while the slip5 of the upper unit are released to 13 enable that unit to be returned upwardly to the broken line 1~ position for repetition of the lowering operation. The casing may thus be progressively lowered in steps by repeated upward 16 and downward movement of gripping unit 66 and structure 65, with 17 the ~asing string being suspended by unit 64 during upward move-18 ment of unit 66 and by unit 66 during its downward movement.
19 When during the jacking operation the weight of the casing string is suspended by gripping unit 64, the entire load 21 of the string is transmitted do~mwardly from unit 64 and its 2~ support structure 63 through the side walls 43 of cylinders 42 23 of the piston and cylinder mechanisms 29, to the supporting 24 base 30 and the underlying concrete foundation and the earth.
When the upper gripping unit 66 is supporting the string, the 26 load forces are similarly transmitted downwardly through the 28~ pi~ton d cylinder mechani~m.
51 Just above the connector lugs 59, each of the cylinders ~¦ carries an annular flange 62, which may be formed as a rigid ring 71 f metal or the like welded to the outside of the cylinder. Above 8 ¦ flanges 62, the two cylinders 42 carry and support a first ~rans-9 ¦ verse upper structure 63 on which a first casing gripping unit 64 10 ¦ is carried. The upper ends of piston rods 48 similarly carry and 11 ¦support, and also actuate vertically, a second upper support 12 ¦structure 65 on which a second gripping unit 66 is carried. Struc-1~ ¦ture 65 may typically have the plan view outline configuration 1~ ¦illustrated in Fig. 5, and as seen in Fig. 4 may include upper 15 ¦and lower horizontal rigid metal plates 67 secured together by 16 vertically extending mem~ers 68 configured to form a relatively 17 large central vertical opening 63 through unit 65 and centered 18 about axis 24, and two smaller openings 70 at opposite sides of 19 opening 69 and centered about axes 40 and 41 of the cylinders.
Openings 70 are dimensioned to exactly receive and closely 21 confine the reduced diameter ends 71 of piston rods 48, with upwardly facing annular shoulders 72 on the piston rods 23 engaging upwardly against bottom plate 67 of unit 65 to ~4 support the latter from the piston rods. Snap rings 73 2~ received within grooves in the upper extremities of the piston 26 rods may engage the upper plate 67 about openings 70 to lock unit 65 on the piston rods for upward and downward movement 28 therewith. Gripping unit 66 has a horizontal undersurface 74 29 engaging the upper horizontal surface of the ~op plate 67 of support structure 65, with unit 66 being centered with respect 31 to axis 24 by reception between a number of evenly circularly 32 spaced locating lugs 75 (typically four such lugs) secured to ~ 15~
1 top plate 67 and preferably having upper camming surfaces 76 2 inclined to advance downwardly as they advance radially inwardly 3 to center unit 66 on support structure 65.
4 The cylinder mounted support structure 63 may be constructed essentially the same as the above discussed structure 6 65, having a central relatively large opening 77 and two smaller 7 openings 78 at diametrically opposite locations, but with these 8 openings 78 being sufficiently larger than the corresponding 9 openings 70 of upper structure 65 to exactly receive and closely confine cylinders 42 in locating relation. Gripping unit 64 may 11 be received on the upper surface of top horizontal plate 79 of 12 structure 63, and be centered and located thereon by lugs 175 13 corresponding to the discussed lugs 75 of structure 65.
lg The two gripping units 64 and 66 may be identical and of a known type having wedge slips for releasably gripping 16 and supporting the casing. The upper of these gripping units 66 17 is illustrated somewhat diagrammatically in Fig. 8, as including 18 an outer annular rigid body 80 having inner downwardly tapering 1~ slip bowl surfaces 81 engageable with wedge slips 82 to cam them inw~rdly into gripping engagement with the casing upon downward 22 movement of the slips relative to body 80. The inner surfaces 23 8~ of the slips are formed to have gripping dies or teeth 84 24 shaped to bite into the casing surface and effectively support it.
~The slips are suspended by a ring 85, to which the slips are connected by links 86 allowing radially inward and outward move-27 ment as the slips are actuated upwardly and downwardly, with such 28 upward and downward actuation being effected by a number of circularly spaced piston and cylinder mechanisms 87 having their 29 cylinders connected to body 80 and their pistons connected to ring 85. As will be understood, when the slips are in their 33l full line active positions of Fig. 8, the casing is supported by the gripping unit, b~lt when the slips are actuated to their _g_ ~ 352~3 1 upper ~roken line retrac-ted positions oE Fig. 8 -the casing is free 2 for movement downwardly relative to the slips.
3 To recapitulate briefly a cycle oE operation of the 4 illustrated equipment, assume that the rig is first in the condi-tion of Fig. 1, with rotary table 21 positioned within recess 6 22 in rig floor 12, and with the rotary table acting to turn kelly 7 26 and the connected drill string while the string is suspended 8 and gradually lowered by traveling block 17 under the control 9 of draw works 15. The rig framework, draw wo ks, traveling block, line 16, etc., may typically have a maximum load handling 11 capacity of 500 tons, and the entire weight of the drill string 12 at maximum hole depth may be safely within that limit. If the 13 casing to be lowered into the hole is beyond that limit, rotary 1~ table 21 is removed from the rig, and jack 19 is positioned in the rig as illustrated in Fig. 2, with that jack typically having 16 a capacity up to 1,000 tons and adequate to support the very 17 neavy casing. Figs 9 through 11 illustrate diagra!~matically 18 several steps which may be followed in assembling the jack in 1~ the rig. A first such step is to position the cylinder locating frame or template 54 in the rig, by lowering template 54 down-~1 wardly into recess 22 in the rig floor to a position of support ~2 on the upper surfaces of beants 23, as seen in Fig. 9, and by then 23 attaching the template to beams 23 by elements 123. After such 24 positioning and anchoring of template 5~, the two piston and cy-linder mechanisms 29 are lowered downwaraly from above the level 26 of the rig floor and along axes 40 and ~1 respectively through ~8 openings 57 of the locating frame or template 54 and to positions of support on base 30, with the lower ends of the cylinders 29 received within the socket structures formed by lugs 45. This inserted position of the piston and cylinder mechanisms is 31 lllustrated in Fig. 9.
32 The next step is to lower the first of the upper support 1 ¦ structures 63 downwardly relative to the piston and cylinder 2¦ mechanisms, from the broken line position of Fig. 10 to the fu:Ll 31 line position of that figure in which the cylinders are received 41 wi-thin openings 78 in structure 63, and the undersurface oE
5~ bottom plate ~8 of structure 63 annularly engages the upper hori-6 ¦ zontal surfaces of flanges 62 abou-t openings 78 to effectively 7 ¦ support structure 63 through cylinders 42. Gripping unit 64 may 8 ¦ then be positioned on structure 63, and the second of the upper 9 ¦ support structures 65 may then be moved downwardly from the broken 10 ¦ line position of Fig. 11 to the ~ull line position of that figure, 11 in which the upper ends of the piston rods are received within 12 openings 70 in structure 65 and that structure is effectively 13 supported and vertically actuable by the piston rods and retained 1~ thereon by rings 73. The upper gripping unit 66 may then be placed on structure 65 to place the jack in condition for 16 operation.
17 Each length or section of casing 20 may be lowered by 18 traveling block 17 along axis 24, as illustrated in Fig. 2, to 19 a position for connection to the remainder of the casing string suspended in the well. During such lowering of a length of 21 casing pipe, the casing string already in the well is gripped by 2~ gripping unit 64, and the casing section to be added is moved 23 downwardly through the upper gripping unit 66 as seen in Fig. 2 24 and appropriately connected to the upper end of the suspended string. During or after such connection of a casing section to 26 the string, the piston and cylinder mechanisms 29 may be actuated to raise their pistons and upper support unit 65 and the carried 2~ upper gripping unit 66 to the broken line position of Fig. 2, 29 with the slips of that gripping unit in released condition, follow-ing which those slips may be actuated to cause unit 66 to effec-31 tively grip and support the casing string. Lower gripping unit 32 64 may then be released, by upward actuation of its slips, to 1 ¦ ree the casing string for downward movement under the con-trol 2 ¦ of ja~k 19. Such downward movement ls effected by actuating the 3 ¦ valve controls on panel 52 to cause discharge of pressure fluid 4 ¦ from the lower ends of cylinders 42 and admission of pressure 5 ¦ fluid to the upper ends of those cylinders, with the discharge 6 ¦ from the lower ends being regulated by choke valves 53 to lower 7 ¦ the pistons and connected parts at a controlled variable rate of 8 ¦ speed satisfying the operating conditions which are encountered.
9 ¦ After the upper gripping unit 66 and its support structure 65 have been lowered to the full line position of Fig. 2, the slips 11 of the lowering gripping unit 64 are actuated to again support 12 the string while the slip5 of the upper unit are released to 13 enable that unit to be returned upwardly to the broken line 1~ position for repetition of the lowering operation. The casing may thus be progressively lowered in steps by repeated upward 16 and downward movement of gripping unit 66 and structure 65, with 17 the ~asing string being suspended by unit 64 during upward move-18 ment of unit 66 and by unit 66 during its downward movement.
19 When during the jacking operation the weight of the casing string is suspended by gripping unit 64, the entire load 21 of the string is transmitted do~mwardly from unit 64 and its 2~ support structure 63 through the side walls 43 of cylinders 42 23 of the piston and cylinder mechanisms 29, to the supporting 24 base 30 and the underlying concrete foundation and the earth.
When the upper gripping unit 66 is supporting the string, the 26 load forces are similarly transmitted downwardly through the 28~ pi~ton d cylinder mechani~m.
Claims (9)
1. The method that comprises:
drilling a well utilizing a rig having a mast and a rig floor in predetermined drilling positions in which the mast projects upwardly above the well and the rig floor extends generally horizontally near the lower end of the mast, and utilizing a drill string suspended by said mast and extending downwardly along a predetermined axis relative to said mast and through said rig floor and into the well;
removing said drill string from the rig after comp-letion of the drilling operation;
then lowering along said axis and into the well, while said mast and rig floor remain in said drilling positions thereof above the well, a string of casing which, during at least a portion of the casing lowering operation, has a weight greater than the load supporting capacity of said mast used in drilling;
effecting the downward movement of said casing string, during at least said portion of the casing lowering operation when the weight of the string exceeds the capacity of the mast, and while said mast and rig floor both remain in said drilling positions thereof, by actuating a first casing supporting unit of a jacking mechanism which is accessible from above said rig floor used in drilling upwardly and downwardly relative to a second casing supporting unit of the jacking mechanism which is accessible from above said rig floor by means of a plurality of fluid pressure operated piston and cylinder mechanisms projecting downwardly beneath the level of said rig floor, with the casing string being supported alternately by the two units respectively;
transmitting load forces resulting from the weight of said casing string from each of said supporting units downwardly through said piston and cylinder mechanisms to a location spaced beneath said rig floor and to the earth at that location without transmission of said forces through said mast, but while said mast and rig floor used in drilling remain in said drilling positions thereof above the well; and suspending additional sections of casing from said mast as they are added to said casing string.
drilling a well utilizing a rig having a mast and a rig floor in predetermined drilling positions in which the mast projects upwardly above the well and the rig floor extends generally horizontally near the lower end of the mast, and utilizing a drill string suspended by said mast and extending downwardly along a predetermined axis relative to said mast and through said rig floor and into the well;
removing said drill string from the rig after comp-letion of the drilling operation;
then lowering along said axis and into the well, while said mast and rig floor remain in said drilling positions thereof above the well, a string of casing which, during at least a portion of the casing lowering operation, has a weight greater than the load supporting capacity of said mast used in drilling;
effecting the downward movement of said casing string, during at least said portion of the casing lowering operation when the weight of the string exceeds the capacity of the mast, and while said mast and rig floor both remain in said drilling positions thereof, by actuating a first casing supporting unit of a jacking mechanism which is accessible from above said rig floor used in drilling upwardly and downwardly relative to a second casing supporting unit of the jacking mechanism which is accessible from above said rig floor by means of a plurality of fluid pressure operated piston and cylinder mechanisms projecting downwardly beneath the level of said rig floor, with the casing string being supported alternately by the two units respectively;
transmitting load forces resulting from the weight of said casing string from each of said supporting units downwardly through said piston and cylinder mechanisms to a location spaced beneath said rig floor and to the earth at that location without transmission of said forces through said mast, but while said mast and rig floor used in drilling remain in said drilling positions thereof above the well; and suspending additional sections of casing from said mast as they are added to said casing string.
2. The method as recited in claim 1, including installing at least a portion of said jacking mechanism in the rig after completion of said drilling operation.
3. The method as recited in claim 1, including in-stalling said two casing supporting units and said piston and cylinder mechanisms in the rig after completion of said drilling operation.
4. The method as recited in claim 1, in which said load forces are transmitted downwardly through tubular vertically extending side walls of the cylinders of said piston and cylinder mechanisms from an upper location at which said first unit is supported by said side walls to said location spaced beneath the rig floor at which said cylinder side walls are supported by the earth.
5. The method that comprises:
drilling a well bore utilizing a drill string driven rotatively about an axis by a rotary table mounted at a predetermined active position in a rig;
removing said rotary table from said active position in the rig after the well bore has been drilled;
positioning in said rig used in drilling, after removal of the rotary table therefrom, upper and lower casing supporting assemblies each carrying slip means adapted to releasably support a casing string, with said lower assembly being located at approximately said active position of the rotary table in said rig and said upper assembly being located above said active position of the rotary table;
at some point during said method positioning in said rig at different sides of said axis a plurality of fluid operated piston and cylinder units which project downwardly to a level substantially lower than said active position of the rotary table and are connected operatively to said upper casing supporting assembly to actuate it upwardly and downwardly relative to said lower assembly, lowering a casing string heavier than said drill string into the well bore by upward and downward actuation of said upper assembly by said piston and cylinder units relative to said lower assembly while gripping the casing string alternately by said two assemblies; and transmitting load forces resulting from the weight of said casing string downwardly through said piston and cylin-der units to a location spaced beneath both of said casing supporting assemblies and to the earth at that location.
drilling a well bore utilizing a drill string driven rotatively about an axis by a rotary table mounted at a predetermined active position in a rig;
removing said rotary table from said active position in the rig after the well bore has been drilled;
positioning in said rig used in drilling, after removal of the rotary table therefrom, upper and lower casing supporting assemblies each carrying slip means adapted to releasably support a casing string, with said lower assembly being located at approximately said active position of the rotary table in said rig and said upper assembly being located above said active position of the rotary table;
at some point during said method positioning in said rig at different sides of said axis a plurality of fluid operated piston and cylinder units which project downwardly to a level substantially lower than said active position of the rotary table and are connected operatively to said upper casing supporting assembly to actuate it upwardly and downwardly relative to said lower assembly, lowering a casing string heavier than said drill string into the well bore by upward and downward actuation of said upper assembly by said piston and cylinder units relative to said lower assembly while gripping the casing string alternately by said two assemblies; and transmitting load forces resulting from the weight of said casing string downwardly through said piston and cylin-der units to a location spaced beneath both of said casing supporting assemblies and to the earth at that location.
The method as recited in claim 5, in which said rig includes a rig floor containing an opening within which said rotary table is received in said active position thereof, and includes a beam structure on which the rotary table is supported in said predetermined active position thereof, said step of positioning the upper and lower casing supporting assemblies including locating said lower assembly within said opening and above and closely adjacent said beam structure, and said step of positioning said piston and cylinder units including locating them in positions of extension downwardly beneath said floor and said beam structure.
7. The method that comprises:
drilling a well utilizing a rig having a mast pro-jecting upwardly above the well in a predetermined drilling position and having a rig floor, and utilizing a drill string suspended by said mast and extending downwardly along a predetermined axis relative to said mast and through said rig floor and into the well and driven rotatively by a rotary table;
removing said drill string and rotary table from the rig after completion of the drilling operation;
then lowering along said axis and into the well, while said mast remains in said drilling position above the well, a string of casing which, during at least a portion of the casing lowering operation, has a weight greater than the load supporting capacity or said mast used in drilling;
effecting the downward movement of said casing string, during at least said portion of the casing lowering operation when the weight of the string exceeds the capacity of the mast, by actuating a first casing supporting unit of a jacking mechanism which is accessible from above the rig floor upwardly and downwardly relative to a second casing supporting unit of the jacking mechanism which is accessible from above the rig floor by means of a plurality of fluid pressure operated piston and cylinder mechanisms projecting downwardly beneath the level of the rig floor, with the casing string being supported alternately by the two units respectively;
transmitting load forces resulting from the weight of said casing string from each of said supporting units downwardly through said piston and cylinder mechanisms to a location spaced beneath the rig floor and to the earth at that location without transmission of said forces through said mast, but while said mast used in drilling remains in said drilling position above the well; and suspending additional sections of casing from said mast as they are added to said casing string;
said method including installing at least a portion of said jacking mechanism in the rig after removal of the rotary table therefrom and at approximately the location at which the rotary table had been during drilling.
drilling a well utilizing a rig having a mast pro-jecting upwardly above the well in a predetermined drilling position and having a rig floor, and utilizing a drill string suspended by said mast and extending downwardly along a predetermined axis relative to said mast and through said rig floor and into the well and driven rotatively by a rotary table;
removing said drill string and rotary table from the rig after completion of the drilling operation;
then lowering along said axis and into the well, while said mast remains in said drilling position above the well, a string of casing which, during at least a portion of the casing lowering operation, has a weight greater than the load supporting capacity or said mast used in drilling;
effecting the downward movement of said casing string, during at least said portion of the casing lowering operation when the weight of the string exceeds the capacity of the mast, by actuating a first casing supporting unit of a jacking mechanism which is accessible from above the rig floor upwardly and downwardly relative to a second casing supporting unit of the jacking mechanism which is accessible from above the rig floor by means of a plurality of fluid pressure operated piston and cylinder mechanisms projecting downwardly beneath the level of the rig floor, with the casing string being supported alternately by the two units respectively;
transmitting load forces resulting from the weight of said casing string from each of said supporting units downwardly through said piston and cylinder mechanisms to a location spaced beneath the rig floor and to the earth at that location without transmission of said forces through said mast, but while said mast used in drilling remains in said drilling position above the well; and suspending additional sections of casing from said mast as they are added to said casing string;
said method including installing at least a portion of said jacking mechanism in the rig after removal of the rotary table therefrom and at approximately the location at which the rotary table had been during drilling.
8. The method as recited in claim 7, including installing said two casing supporting units and said piston and cylinder mechanisms in the rig after completion of said drilling operation.
9. The method as recited in claim 7, in which said load forces are transmitted downwardly through tubular vertically extending side walls of the cylinders of said piston and cylinder mechanisms from an upper location at which said first unit is supported by said side walls to said location spaced beneath the rig floor at which said cylinder side walls are supported by the earth.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US26876381A | 1981-06-01 | 1981-06-01 | |
| US6/268,763 | 1981-06-01 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1185228A true CA1185228A (en) | 1985-04-09 |
Family
ID=23024372
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000403140A Expired CA1185228A (en) | 1981-06-01 | 1982-05-17 | Well pipe jack |
Country Status (6)
| Country | Link |
|---|---|
| JP (1) | JPS582196A (en) |
| CA (1) | CA1185228A (en) |
| DE (1) | DE3219587A1 (en) |
| FR (1) | FR2506832B1 (en) |
| GB (1) | GB2099486B (en) |
| NO (1) | NO821635L (en) |
Cited By (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7832974B2 (en) | 2005-06-01 | 2010-11-16 | Canrig Drilling Technology Ltd. | Pipe-handling apparatus |
| US7958787B2 (en) | 2006-08-24 | 2011-06-14 | Canrig Drilling Technology Ltd. | Oilfield tubular torque wrench |
| US8016536B2 (en) | 2008-04-04 | 2011-09-13 | Canrig Drilling Technology Ltd. | Pipe-handling apparatus and methods |
| US8033779B2 (en) | 2008-01-31 | 2011-10-11 | Canrig Drilling Technology Ltd. | Pipe handling apparatus and methods |
| US8042432B2 (en) | 2006-08-24 | 2011-10-25 | Canrig Drilling Technology Ltd. | Oilfield tubular torque wrench |
| US8074537B2 (en) | 2006-09-08 | 2011-12-13 | Canrig Drilling Technology Ltd. | Oilfield tubular spin-in and spin-out detection for making-up and breaking-out tubular strings |
Families Citing this family (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4421175A (en) * | 1981-08-28 | 1983-12-20 | Varco International, Inc. | Method of drilling and casing a well |
| US4437515A (en) * | 1981-12-21 | 1984-03-20 | Varco International, Inc. | Positioning of well pipe jack in a rig |
| GB2152920B (en) * | 1983-08-12 | 1987-06-24 | Secr Defence | Propellant composition |
| US7107875B2 (en) * | 2000-03-14 | 2006-09-19 | Weatherford/Lamb, Inc. | Methods and apparatus for connecting tubulars while drilling |
| GB0206414D0 (en) * | 2002-03-19 | 2002-05-01 | Weatherford Lamb | A tubing injector |
| CN102627244A (en) * | 2012-03-27 | 2012-08-08 | 昆山中慈工控科技开发有限公司 | Underground electric jack boosted by liquid pressure through cable line operation |
| NO338208B1 (en) * | 2014-06-10 | 2016-08-08 | Joreka Man As | Drill tower assembly and method of using the same |
Family Cites Families (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB899463A (en) * | 1959-06-17 | 1962-06-20 | Dowty Rotol Ltd | Improvements in earth boring equipment |
| US3722607A (en) * | 1971-04-08 | 1973-03-27 | Tenneco Oil Co | Method for drilling a well |
| US4208158A (en) * | 1978-04-10 | 1980-06-17 | Franklin Enterprises, Inc. | Auxiliary offshore rig and methods for using same |
-
1982
- 1982-05-17 CA CA000403140A patent/CA1185228A/en not_active Expired
- 1982-05-18 NO NO821635A patent/NO821635L/en unknown
- 1982-05-24 FR FR8208927A patent/FR2506832B1/en not_active Expired
- 1982-05-25 GB GB8215213A patent/GB2099486B/en not_active Expired
- 1982-05-25 DE DE19823219587 patent/DE3219587A1/en not_active Ceased
- 1982-06-01 JP JP57093943A patent/JPS582196A/en active Granted
Cited By (11)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7832974B2 (en) | 2005-06-01 | 2010-11-16 | Canrig Drilling Technology Ltd. | Pipe-handling apparatus |
| US8215887B2 (en) | 2005-06-01 | 2012-07-10 | Canrig Drilling Technology Ltd. | Pipe-handling apparatus and methods |
| US7958787B2 (en) | 2006-08-24 | 2011-06-14 | Canrig Drilling Technology Ltd. | Oilfield tubular torque wrench |
| US8042432B2 (en) | 2006-08-24 | 2011-10-25 | Canrig Drilling Technology Ltd. | Oilfield tubular torque wrench |
| US8074537B2 (en) | 2006-09-08 | 2011-12-13 | Canrig Drilling Technology Ltd. | Oilfield tubular spin-in and spin-out detection for making-up and breaking-out tubular strings |
| US8490520B2 (en) | 2006-09-08 | 2013-07-23 | Canrig Drilling Technology Ltd. | Oilfield tubular spin-in and spin-out detection for making-up and breaking-out tubular strings |
| US9404324B2 (en) | 2006-09-08 | 2016-08-02 | Canrig Drilling Technology Ltd. | Oilfield tubular spin-in and spin-out detection for making-up and breaking-out tubular strings |
| US10329857B2 (en) | 2006-09-08 | 2019-06-25 | Nabors Drilling Technologies Usa, Inc. | Oilfield tubular spin-in and spin-out detection for making-up and breaking-out tubular strings |
| US8033779B2 (en) | 2008-01-31 | 2011-10-11 | Canrig Drilling Technology Ltd. | Pipe handling apparatus and methods |
| US8454296B2 (en) | 2008-01-31 | 2013-06-04 | Canrig Drilling Technology Ltd. | Pipe-handling apparatus and methods |
| US8016536B2 (en) | 2008-04-04 | 2011-09-13 | Canrig Drilling Technology Ltd. | Pipe-handling apparatus and methods |
Also Published As
| Publication number | Publication date |
|---|---|
| DE3219587A1 (en) | 1983-01-13 |
| FR2506832B1 (en) | 1985-11-08 |
| GB2099486B (en) | 1985-02-06 |
| GB2099486A (en) | 1982-12-08 |
| JPS6364594B2 (en) | 1988-12-13 |
| JPS582196A (en) | 1983-01-07 |
| FR2506832A1 (en) | 1982-12-03 |
| NO821635L (en) | 1982-12-02 |
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