WO2002075097A2 - Methods and apparatus for severing nested strings of tubulars - Google Patents
Methods and apparatus for severing nested strings of tubulars Download PDFInfo
- Publication number
- WO2002075097A2 WO2002075097A2 PCT/GB2002/001339 GB0201339W WO02075097A2 WO 2002075097 A2 WO2002075097 A2 WO 2002075097A2 GB 0201339 W GB0201339 W GB 0201339W WO 02075097 A2 WO02075097 A2 WO 02075097A2
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- casing
- assembly
- blade
- clamp
- severing
- Prior art date
Links
- 238000000034 method Methods 0.000 title claims abstract description 24
- 238000005520 cutting process Methods 0.000 claims abstract description 40
- 238000005553 drilling Methods 0.000 claims abstract description 18
- 230000014759 maintenance of location Effects 0.000 claims abstract description 10
- 238000004873 anchoring Methods 0.000 claims description 7
- 238000003780 insertion Methods 0.000 abstract description 3
- 230000037431 insertion Effects 0.000 abstract description 3
- 239000004568 cement Substances 0.000 description 13
- 230000033228 biological regulation Effects 0.000 description 4
- 239000002826 coolant Substances 0.000 description 2
- 230000007613 environmental effect Effects 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 239000011159 matrix material Substances 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 229910000831 Steel Inorganic materials 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B29/00—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
Definitions
- the present invention generally relates to plugging and abandonment of oil and gas wells. More particularly, the present invention relates to the removal of a tubular from a wellbore in order to satisfy various environmental regulations. More particularly still, the invention relates to severing nested strings of tubulars that are cemented together in order to more easily handle the tubulars as they are removed from a wellbore during or subsequent to a plugging and abandonment operation.
- boreholes are formed in the earth and thereafter are lined with steel pipe known as casing.
- An annular area formed between the outside of the casing and the wall of the borehole is typically filled with cement in order to secure the casing in the borehole and to facilitate the isolation of certain areas of the wellbore for the collection of hydrocarbons.
- concentric strings of tubulars are disposed in the wellbore with each lower string of tubulars being necessarily smaller in diameter than the previous string. In some cases, especially in offshore oil and gas wells, the strings are run in a nested fashion from the surface of the well.
- a first string of casing is cemented into the wellbore and, subsequently, a second smaller string of casing is cemented into the first string to permit the borehole to be lined to a greater depth.
- This process is typically repeated with additional casing strings until the well has been drilled to total depth.
- wells are typically formed with two or more strings of casing of an ever-decreasing diameter.
- the severed upper string of casing includes more than one set of tubulars.
- the outer casing string is 13 3/8 inches (34 cm) in diameter, and the smaller casing nested therein is 9 5/8 inches (24.4 cm) in diameter.
- a casing string is typically comprised of a series of joints that are 30 feet (9.1 m) in length.
- the pipe joints are connected by threaded male-to-female connections.
- this process is difficult where the severed string consists of outer and inner pipe strings cemented together.
- the severed casing is typically broken into smaller joints by cutting through the inner and outer strings at the surface of the well. The severed pipe sections are then recycled or otherwise disposed of.
- casing strings are severed generally as follows:
- the casing string is severed within the wellbore. Typically, severance is accomplished at a depth of around 1,000 feet (305 m). Thereafter, the severed portion of casing is "jacked" out of the wellbore and raised to the surface of the rig platform using a platform-mounted elevator. As the upper end of the severed casing section reaches the floor of the platform, it is lifted to a predetermined height above a set of slips. The slips are then set, suspending the severed string of casing above the rig floor. A drilling machine then drills a hole completely through the casing, including any cement layer and smaller diameter casing which is cemented within the larger diameter casing.
- a band saw is used to cut the severed tubular into a predetermined length.
- the band saw operates with coolant to avoid the use of high temperature cutters or the production of sparks.
- a length of approximately ten feet (3 m) is selected, with the cut being made above the retention pin.
- the newly severed, ten-foot (3 m) portion of string is then transported to a barge or other transportation means for disposal or salvage.
- the elevator With the slips disengaged, the elevator then raises the severed string of casing another length of approximately ten feet (3 m). The slips are then re-engaged and the drilling, anchoring and cutting procedure takes place again.
- an apparatus for severing casing above a wellbore comprising: a clamp assembly constructed and arranged to hold the casing in relation to the apparatus; a drill assembly constructed and arranged to form an aperture through the casing and through any inner casing string nested within the casing, the aperture being dimensioned to receive a retention member for anchoring the casing to the any nested casing string; and a cutting assembly constructed and arranged to sever the casing and the any other nested casing string by forming a through-cut through the casing.
- a method of severing casing comprising the steps of: forming an aperture through the casing and through any inner casing string nested therein, using a drill assembly; anchoring the casing and the any nested casing string together; and severing the casing using a cutting assembly, the cutting assembly comprising a blade to form a cut.
- an apparatus for positioning a tubular severing assembly comprising: a support beam; and a single cantilevered extendable structure having a first end and a second end, the extendable structure being attached to the support beam at the first end, and being attached to the tubular severing assembly at the second end.
- the apparatus includes a clamp assembly, a drill assembly and a cutting assembly.
- the clamp assembly, the drilling assembly and the cutting assembly are disposed at the end of a telescopic arm, and are remotely operated by personnel using a control panel.
- the clamp assembly is positioned adjacent a section of casing to be severed, and then clamped thereto. Thereafter, the drilling assembly is actuated so as to drill a hole completely through the casing strings. A retention pin is then inserted through the newly formed aperture. Finally, the cutting assembly, such as a band saw, is actuated so as to severe the casing above the pin. The newly severed portion of casing above the pin may then be disposed of.
- Figure 1 is a perspective view of a tubular severing apparatus in one arrangement
- Figure 2 is a side, schematic view of the tubular severing apparatus of Figure 1;
- Figure 3 is a perspective view of a cross-sectional cut of a casing section, including an outer casing string, an inner casing string and a layer of cement therebetween;
- Figure 4 is a side view illustrating a drilling assembly, shown drilling a hole through a casing section
- Figure 5 a is a top view of an alternative drill assembly
- Figure 5b presents a side view illustrating the drill assembly of Figure 5 a
- Figure 6 is a perspective view illustrating the tubular severing apparatus of Figure 1;
- Figure 7 is a perspective view illustrating the tubular severing apparatus of Figure 1;
- Figure 8 is an enlarged view of the band saw of Figure 7;
- Figure 9 is a perspective view of a control panel as might be used to control various portions of the severing apparatus.
- Figure 1 provides a perspective view of a tubular cutting apparatus 100.
- the apparatus 100 comprises a clamp assembly 130, a drill assembly 150 and a cutting assembly 120.
- the apparatus 100 is selectively movable.
- the apparatus 100 is disposed at the end of an extendable structure.
- the extendable structure is shown as a cantilevered arm 110.
- the exemplary arm 110 defines an outer barrel 110 having at least one telescoping section 112 extending therefrom.
- An intermediate telescoping section (not shown) may also be incorporated. In such an arrangement, the end telescoping section 112 is slidably mounted in the intermediate telescoping section which is, in turn, slidably mounted in the outer barrel 110.
- the arm 110 is supported by a base 114 secured to the floor of a rig platform (not shown).
- the arm 110 is disposed on a vertical support beam 116 vertically extending above the base 114.
- the outer barrel of the arm 110 may be attached to the support beam 116 by means of a clamp (not shown in Figure 1) bolted to the top of the beam 116.
- a suitable clamp is shown for example in WO 98/32947, incorporated herein by reference, with reference to a telescopic arm for supporting a tong. The clamp maintains the arm 110 in position with respect to the beam 116.
- the arm 110 is pivotally attached to the support beam 116 to permit the tubular severing apparatus 100 to pivot about a vertical axis and, alternatively or in addition, a horizontal axis.
- the clamp is releasably attached to the support beam 116.
- an additional feature of the arm 110 is that the outer barrel 110 of the arm itself may be selectively moved with respect to the support beam 116. This means that the entire arm 110 may be retracted away from the casing section 200'. When the telescoping sections 112 are fully contracted, the free end of the arm 110 lies closely adjacent the support beam 116.
- This retracting feature is shown in Figure 4 of the WO 98/32947, incorporated herein by reference, with respect to a tong, but may also be employed in the present application with respect to a tubular severing assembly 100.
- the apparatus 100 is further supported by an overhead hoisting system. Cables 160 from the hoisting system are visible in Figure 1.
- the hoisting system maneuvers the tubular severing apparatus 100, with the telescoping section 112 of the arm 110 moving in response.
- the telescoping section 112 of the arm 110 is hydraulically powered, causing the apparatus 100 and the supporting cables 160 to advance and recede in response to movement of the arm 110.
- the arm 110 and the hoisting system may be independently powered.
- casing section 200' represents an upper, severed string of casing that is being retrieved from a wellbore (not shown in Figure 1).
- the casing 200' is being further severed into smaller portions for ease of manipulation and disposal.
- the exemplary casing string 200' houses a smaller, inner string of casing 205 nested within an outer casing string 200.
- the inner string 205 has been cemented into the outer string 200 in connection with earlier wellbore completion operations.
- Figure 2 is a schematic view of the apparatus 100, adjacent a section of casing 200'. Visible again in Figure 2 is the clamp assembly 130, the drill assembly 150 and the cutting assembly 120. In this arrangement, the assembly 100 is again disposed at the distal end of the telescopic arm 110 and is suspended from above with cables 160.
- the telescopic arm 110 again has at least one telescoping section 112.
- the clamp assembly 130 is radially disposed about the section of casing 200' so as to secure the casing section 200' for severing.
- the casing 200' is shown in Figure 2 in cross-section. Visible in this view are the outer casing string 200, the inner casing string 205 and a matrix of cured cement 210 in the annular region between the two casing strings 200, 205.
- FIG 3 is a perspective view showing a cross-section of the casing 200' after it has been severed using the apparatus 100 of Figure 2.
- casing section 200' defines an outer string of casing 200 which houses a smaller diameter casing 205.
- a matrix of cement 210 is disposed in an annular area between the two casing strings 200, 205.
- inner casing string 205 is eccentric relative to the surrounding outer casing string 200, as is typical in a completed wellbore.
- the tubular string 200' is shown being held above a floor member 170 by a set of slips 172.
- the slips 172 permit the tubular string 200' to be raised from below the surface of the platform to some height.
- elevators are provided on a rig for maneuvering pipe relative to the wellbore.
- the slips 172 hold the casing 200' so that it can be clamped and severed by the apparatus 100 after positioning of the casing 200' by the elevators.
- the apparatus 100 includes a drill assembly 150.
- the purpose of the drill assembly 150 is to form an aperture through the casing strings 200, 205 for insertion of a retention member 165.
- the retention member 165 defines a pin configured to be received within the formed aperture.
- Various pin types may be used, including, for example, a cylindrical bar, a cotter pin, or a cotter and key.
- a simple tubular pin is shown.
- the pin 165 serves to anchor any nested casing string 205 and cement 210 to the outer casing string 200.
- the aperture is formed completely through both the front and back walls of the outer casing string 200, and the pin 165 is inserted completely through the outer casing string 200.
- the drill assembly 150 is disposed below the band saw 120.
- the drill assembly 150 is constructed and arranged to insert a rotating drill bit 151 essentially perpendicular to the longitudinal axis of the casing string 200'. In this way, a suitable aperture is formed. Any known drilling device may be employed for boring a through-opening into the casing section 200'.
- the drill assembly 150 of Figure 2 utilizes a rotary motor (not shown) inside of a housing 153 to rotate a single drill bit 151.
- a positioning device is further provided for selectively advancing the drill bit 151 towards and away from the casing section 200.
- FIG. 4 An enlarged perspective view of a drill assembly 150 in operation is shown in Figure 4.
- the drill bit 151 can be more clearly seen penetrating the wall of the outer section of casing 200.
- the drill assembly 150 typically operates with a source of coolant and advances forward towards the casing 200 by means of a telescoping positioning device, shown in FIG. 4 as a cylinder 156.
- the drill assembly 150 is operated remotely from a control panel 125 as is shown in Figure 2.
- the remote control panel 125 will be more fully described, infra.
- Figures 5a and 5b An alternative arrangement for a drill assembly is presented in Figures 5a and 5b.
- Figure 5a is a top view of the alternative drilling assembly.
- Figure 5b is a side view thereof.
- a pair of opposing boring devices 155 are urged inwardly towards the center of the casing section 200'.
- Any drilling assembly 150 capable of boring an aperture through the casing section 200' for insertion of an anchoring pin 165 may be employed.
- the drill assembly 150 has been actuated to form an aperture through both casings strings 200, 205.
- the pin 165 has been inserted through the formed aperture to anchor the inner casing 205 to the outer casing 200.
- FIG. 6 is a perspective view of the apparatus 100 of Figure 1.
- the clamp assembly 130 includes a frame 134 that selectively radially encompasses the casing section 200' in order to secure the apparatus 100 to the casing section 200'.
- the clamp assembly 130 further comprises at least two clamp members 140 for frictionally engaging the casing 200'.
- the clamp members 140 each define a pair of angled support blocks which are moved into contact with the casing 200'.
- other arrangements may be employed, such as a single block having a concave surface.
- the clamp assembly 130 includes a gate member 135 that swivels about a hinge 133 mounted on the frame 134.
- the hinge 133 permits the gate member 135 to be selectively opened and closed for receiving and for clamping the casing 200'.
- the gate member 135 is closed about the casing 200' while the casing section 200' is being severed.
- the gate member 135 includes at least one clamp member 140 for engaging the casing 200' in its closed position.
- the gate 135 preferably operated with hydraulic power, and is remotely operated from control panel 125.
- a hydraulic arm 136 is shown to aid in remotely opening and closing the gate 135.
- FIG 7 presents the apparatus 100 of Figure 1 in still greater detail.
- the cutting assembly 120 is more clearly seen.
- the cutting assembly 120 is shown as a band saw.
- the band saw 120 first comprises a housing 122.
- the housing 122 houses a pair of wheels (not seen in Figure 7) about which a band saw blade 121 is tracked.
- the band saw blade 121 includes a plurality of teeth.
- the blade 121 is fed through pairs of roller members 123 which guide the blade 121 to cut in a direction substantially perpendicular to the longitudinal axis of the outer casing 200.
- One pair of roller members 123 is preferably provided at the housing outlet for the blade 121. In this respect, the blade 121 is fed through this first pair of roller members 123.
- a second pair of roller members 123 is disposed at the opening in the housing 122 through which the blade 121 is received back into the housing 122.
- the roller members 123 are more clearly seen in the enlarged view of Figure 8.
- any cutting device 120 known for severing casing may be used, so long as the cutting device 120 may be adapted to operate in conjunction with a clamp assembly 130 and a drill assembly 150.
- the cutting assembly defines a band saw 120.
- the band saw 120 includes a housing 122 that is offset from the angle of cutting by the blade 121.
- the angle of the housing 122 of the band saw 120 is offset from the angle at which the teeth of the blade 121 engage the outer casing 200 during the cutting operation.
- the angle shown is approximately 30 degrees, though other angles may be used.
- an enlarged spacing 129 is provided in the housing 122 between the wheels.
- the blade 121 of the band saw 120 has been actuated.
- the blade 121 is engaging the casing section 200', and has advanced partway through the casing 200' to form a cut that is substantially perpendicular to the longitudinal axis of the outer casing 200.
- the band saw 120, the clamp assembly 130, and the drill assembly 150 are preferably controlled in an automated fashion from a control panel 125.
- Control lines 126 are provided from the control panel 125 to control the assembly 100, e.g., parts 120, 130, 150, 154, etc..
- Figure 9 is a more detailed perspective view showing a typical control panel 125 to be utilized with a tubular severing apparatus 100.
- the illustrated control panel 125 in one aspect includes separate controls to operate the clamp assembly 130, the drilling assembly 150, and the band saw 120.
- the band saw 120 and the drill assembly 150 are typically operated with similar controls.
- the drill assembly 150 and saw 120 each require an on/off control and a rotational speed control to manipulate the rotation of the saw blade 121 or the drill bit 151.
- Corresponding gauges illustrating the rotational movement of the drill bit 151 and the band saw 121 as shown in revolutions per minute may optionally be provided.
- a tool advancing control is provided to control the speed of advance of the drill bit 151 into the casing 200' and the blade 121 of the band saw 120 into the casing 200'.
- Corresponding positioning devices 126 shown in FIG. 1) and 156 (shown in FIG. 4) are provided for the band saw 121 and the drill assembly 150. These devices permit the drill bit 151 of the drill assembly 150 and the blade 121 of the band saw 120 to be independently, selectively advanced towards the casing 200' during the respective drilling and cutting operations and then withdrawn.
- both the band saw 120 and the drill assembly 150 optionally include pressure sensors to determine the amount of pressure placed upon the casing by the rotating drill bit 151 or the rotating saw blade 121.
- Gauges may be provided at the control panel 125 indicating pressures on the drill bit 151 or the rotating saw blade 121.
- the clamp assembly 130 also has controls that are located on the control panel 125.
- the clamp assembly 130 includes a panel-mounted control which opens and closes the gate 135 located on the clamp assembly 130.
- a gauge indicating pressure between the casing 200' and a clamp 140 may be provided and pressure of the clamps 140.
- a corresponding sensor is positioned on at least one of the clamp members 140 for sensing pressure of the clamp member 140 against the casing 200 when the gate 135 is closed.
- the sensor is placed on the clamp member 140 on the gate 135.
- the severing apparatus of the present invention operates as follows:
- a casing cutting means (not shown) is run into a wellbore.
- the cutting means is typically disposed on the end of a run-in string or wireline.
- the cutting means is placed in the wellbore at a predetermined depth, and then actuated. In this way, a selected length of casing is severed downhole. Thereafter, the severed portion of casing 200 is pulled or "jacked out" of the wellbore and lifted to the rig platform within an elevator.
- a predetermined amount of the severed portion of casing 200' is pulled upwards past the slip 172 located at the level of the platform floor.
- the casing 200' is held in place by the slip 172, exposing the upper portion of the casing 200' above the platform floor.
- a tubular severing apparatus 100 is moved towards the casing 200' by the telescopic arm assembly 110 with its extending and retracting sections 112.
- the clamp assembly 130 is actuated to open the gate 135 and to receive the casing 200'.
- the gate 135 is then closed around the casing 200', and the clamp assembly 130 is secured to the casing 200' by the clamping members 140. In this way, the severing apparatus 100 is properly positioned with respect to the casing 200'.
- the drill assembly 150 is operated.
- remote actuation of the drill assembly 150 is conducted through the control panel 125.
- the drill bit 151 disposed on the drill assembly 150 is rotated and advanced towards the casing 200 to form an aperture therein.
- the aperture is created through at least the front wall of the casing section 200' at an angle substantially perpendicular to the longitudinal axis of the outer casing 200.
- a retention mechanism such as a pin 165 is then inserted through the casing 200' to ensure that any inner string of casing 205 is longitudinally fixed with respect to the outer string of casing 200.
- the next step involves actuation of the band saw 120.
- actuation of the band saw 120 is performed remotely via the control panel 125.
- the blade 121 of the band saw 120 is actuated, and is advanced through the casing 200' at a point above the pin 165.
- the retention pin 165 anchors the smaller diameter casing 205 within the larger diameter casing 200.
- the severed portion of the casing section 200' is then lifted away, leaving an upper end of the lower portion of casing 200" remaining within the clamping assembly 130.
- an elevator or other lifting device works with the slips to lift the casing 200' another predetermined distance upwards.
- the slips 172 are then used to re-grasp the casing 200' for the operation to be repeated.
- the clamp assembly 130 is de- activated, and the gate 135 is reopened so that the apparatus 100 can move away from the severed piece of casing 200'.
- the pin 165 may be retained in the newly lifted section of casing 200' to be severed. A new pin 165 can then be inserted once a new aperture is formed within the casing 200'.
- the apparatus 100 of the present invention provides a safe and efficient means for severing casing during a plug and abandonment operation.
- the apparatus 100 is operated via a remotely located control panel 125.
Landscapes
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
- Punching Or Piercing (AREA)
- Perforating, Stamping-Out Or Severing By Means Other Than Cutting (AREA)
- Processing Of Stones Or Stones Resemblance Materials (AREA)
Abstract
Description
Claims
Priority Applications (5)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CA002433362A CA2433362C (en) | 2001-03-20 | 2002-03-20 | Methods and apparatus for severing nested strings of tubulars |
AU2002251182A AU2002251182B2 (en) | 2001-03-20 | 2002-03-20 | Methods and apparatus for severing nested strings of tubulars |
DE60211667T DE60211667D1 (en) | 2001-03-20 | 2002-03-20 | METHOD AND DEVICE FOR CUTTING INTERLOCKED DRILLING PIPING |
EP02720112A EP1370745B1 (en) | 2001-03-20 | 2002-03-20 | Methods and apparatus for severing nested strings of tubulars |
NO20032934A NO331324B1 (en) | 2001-03-20 | 2003-06-26 | Methods and apparatus for cutting nested pipe strings |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US27743901P | 2001-03-20 | 2001-03-20 | |
US60/277,439 | 2001-03-20 |
Publications (2)
Publication Number | Publication Date |
---|---|
WO2002075097A2 true WO2002075097A2 (en) | 2002-09-26 |
WO2002075097A3 WO2002075097A3 (en) | 2003-02-06 |
Family
ID=23060863
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/GB2002/001339 WO2002075097A2 (en) | 2001-03-20 | 2002-03-20 | Methods and apparatus for severing nested strings of tubulars |
Country Status (6)
Country | Link |
---|---|
EP (1) | EP1370745B1 (en) |
AU (1) | AU2002251182B2 (en) |
CA (1) | CA2433362C (en) |
DE (1) | DE60211667D1 (en) |
NO (1) | NO331324B1 (en) |
WO (1) | WO2002075097A2 (en) |
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10619431B2 (en) | 2013-08-09 | 2020-04-14 | Weatherford U.K. Limited | Tubular stabbing guide |
US10648255B2 (en) | 2018-03-09 | 2020-05-12 | Weatherford Technology Holdings, Llc | Tubular stabbing guide for tong assembly |
US11208857B2 (en) | 2018-03-15 | 2021-12-28 | Canrig Robotic Technologies As | Pipe guide |
Families Citing this family (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN111927369B (en) * | 2020-07-17 | 2021-05-25 | 华运隆腾机械制造有限公司 | Wellhead assembly |
NO347597B1 (en) * | 2021-12-17 | 2024-01-22 | Archer Oiltools As | A petrolium platform auxiliary rig and method of removing a well tubing from a petroleum well |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4181196A (en) * | 1977-06-23 | 1980-01-01 | Exxon Production Research Company | Method and apparatus for recovery of subsea well equipment |
US4557628A (en) * | 1981-10-14 | 1985-12-10 | Armco Inc. | Method and apparatus for remotely cutting broken underwater guidelines |
GB2285077A (en) * | 1993-12-10 | 1995-06-28 | Ocean Technical Services Ltd | Abandonment of offshore oil wells |
EP0778392A2 (en) * | 1995-12-04 | 1997-06-11 | Noordhoek Overseas Equipment B.V. | Method and apparatus for removing the uppermost part of a construction in the seabed |
GB2313859A (en) * | 1996-03-28 | 1997-12-10 | Uwg Ltd | Clearing sub-sea well risers |
-
2002
- 2002-03-20 DE DE60211667T patent/DE60211667D1/en not_active Expired - Lifetime
- 2002-03-20 WO PCT/GB2002/001339 patent/WO2002075097A2/en active IP Right Grant
- 2002-03-20 AU AU2002251182A patent/AU2002251182B2/en not_active Expired
- 2002-03-20 EP EP02720112A patent/EP1370745B1/en not_active Expired - Lifetime
- 2002-03-20 CA CA002433362A patent/CA2433362C/en not_active Expired - Lifetime
-
2003
- 2003-06-26 NO NO20032934A patent/NO331324B1/en not_active IP Right Cessation
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4181196A (en) * | 1977-06-23 | 1980-01-01 | Exxon Production Research Company | Method and apparatus for recovery of subsea well equipment |
US4557628A (en) * | 1981-10-14 | 1985-12-10 | Armco Inc. | Method and apparatus for remotely cutting broken underwater guidelines |
GB2285077A (en) * | 1993-12-10 | 1995-06-28 | Ocean Technical Services Ltd | Abandonment of offshore oil wells |
EP0778392A2 (en) * | 1995-12-04 | 1997-06-11 | Noordhoek Overseas Equipment B.V. | Method and apparatus for removing the uppermost part of a construction in the seabed |
GB2313859A (en) * | 1996-03-28 | 1997-12-10 | Uwg Ltd | Clearing sub-sea well risers |
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10619431B2 (en) | 2013-08-09 | 2020-04-14 | Weatherford U.K. Limited | Tubular stabbing guide |
US10648255B2 (en) | 2018-03-09 | 2020-05-12 | Weatherford Technology Holdings, Llc | Tubular stabbing guide for tong assembly |
US11208857B2 (en) | 2018-03-15 | 2021-12-28 | Canrig Robotic Technologies As | Pipe guide |
Also Published As
Publication number | Publication date |
---|---|
EP1370745A2 (en) | 2003-12-17 |
AU2002251182B2 (en) | 2007-08-16 |
CA2433362A1 (en) | 2002-09-26 |
WO2002075097A3 (en) | 2003-02-06 |
EP1370745B1 (en) | 2006-05-24 |
DE60211667D1 (en) | 2006-06-29 |
CA2433362C (en) | 2006-07-18 |
NO20032934D0 (en) | 2003-06-26 |
NO331324B1 (en) | 2011-11-28 |
NO20032934L (en) | 2003-08-27 |
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