US20010023765A1 - Lubricator for underbalanced drilling - Google Patents
Lubricator for underbalanced drilling Download PDFInfo
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- US20010023765A1 US20010023765A1 US09/789,227 US78922701A US2001023765A1 US 20010023765 A1 US20010023765 A1 US 20010023765A1 US 78922701 A US78922701 A US 78922701A US 2001023765 A1 US2001023765 A1 US 2001023765A1
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- Prior art keywords
- lubricator
- valve
- sleeve
- pressure
- response
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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
- E21B23/00—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells
- E21B23/004—Indexing systems for guiding relative movement between telescoping parts of downhole tools
- E21B23/006—"J-slot" systems, i.e. lug and slot indexing mechanisms
-
- 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
- E21B21/085—Underbalanced techniques, i.e. where borehole fluid pressure is below formation pressure
-
- 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/10—Valve arrangements in drilling-fluid circulation systems
-
- 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
-
- 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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
- E21B34/101—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for equalizing fluid pressure above and below the valve
-
- 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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
- E21B34/102—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for locking the closing element in open or closed position
-
- 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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
- E21B34/108—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with time delay systems, e.g. hydraulic impedance mechanisms
-
- 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
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/04—Ball valves
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T137/00—Fluid handling
- Y10T137/8593—Systems
- Y10T137/86928—Sequentially progressive opening or closing of plural valves
- Y10T137/86936—Pressure equalizing or auxiliary shunt flow
- Y10T137/86944—One valve seats against other valve [e.g., concentric valves]
Definitions
- the invention relates to a lubricator for underbalanced drilling.
- overbalanced drilling fluid in an annulus of a well is used to exert a pressure that is greater than the formation pressure.
- the pressure that is exerted by the annulus fluid keeps formation fluids from exiting the well.
- a drawback to this technique is that mud particles typically are added to the annulus fluid to increase its weight (and thus, increase its downhole pressure), and these mud particles tend to clog up openings in the formation.
- the formation may be damaged by overbalanced drilling, and after drilling, cleanup of the well may be needed before production begins.
- the well may also need to be tested after overbalanced drilling to check for formation damage.
- underbalanced drilling typically does not damage the formation damage and typically maximizes reservoir inflow.
- heavy annulus fluid is not used to suppress the formation pressure.
- a blowout preventer, or snubbing unit is used to seal off the drill string at the surface of the well.
- this arrangement may also present difficulties. For example, when drilling at shallow depths or retrieving the drill string, the upward force from the formation pressure may exceed the weight of the drill string and thus, may force the drill string out of the borehole. As a result, retrieving the drill string may consume a considerable amount of time and present a significant danger.
- a system usable with a subterranean well includes a tubing and a lubricator.
- the tubing is adapted to receive a drill string in a passageway of the tubing, and the lubricator is located downhole and is connected to the tubing.
- the lubricator is adapted to be remotely operable from a surface of the well to control fluid communication between the passageway located above the lubricator and a formation located beneath the lubricator.
- the controller selectively moves the sleeve into the passageway to protect a portion of the downhole tool from a downhole fluid.
- FIG. 1 is a schematic diagram of a subterranean well according to an embodiment of the invention.
- FIG. 2 is a cross-sectional view of a lubricator according to an embodiment of the invention.
- FIGS. 3 and 4 are cross-sectional views of a lubricator according to an embodiment of the invention.
- FIG. 5 is a cross-sectional view of the lubricator of FIGS. 3 and 4 taken along line 5 - 5 of FIG. 3.
- FIG. 6 is a schematic diagram of a J-slot of the lubricator of FIGS. 3 and 4.
- FIGS. 7, 8, 9 , 10 , 11 , 12 , 13 , 14 , 15 and 16 are schematic diagrams illustrating different operational states of the lubricator of FIGS. 3 and 4.
- FIGS. 17 and 18 are cross-sectional views of a lubricator according to an embodiment of the invention.
- FIG. 19 is a cross-sectional view of a lubricator according to an embodiment of the invention.
- FIGS. 20 and 21 are schematic diagrams of wells according to different embodiments of the invention.
- FIG. 22 is a cross-sectional view of a lubricator according to an embodiment of the invention.
- FIG. 23 is a flow diagram depicting an algorithm to close a ball valve of the lubricator according to an embodiment of the invention.
- FIG. 24 is a flow diagram depicting an algorithm to open a ball valve of the lubricator according to an embodiment of the invention.
- FIG. 25 is a cross-sectional view of a portion of a lubricator valve according to an embodiment of the invention.
- an embodiment 20 of a downhole lubricator in accordance with the invention may be used for underbalanced drilling.
- a drill pipe, or string 10 When a drill pipe, or string 10 , is inserted through a central passageway of the lubricator 20 , the lubricator 20 forms a seal between an annulus 19 that is formed from the exterior surface of the string 10 and the interior surface of a concentric tubing 16 .
- the lubricator 20 may be remotely operated from the surface of the well 5 to selectively seal off its central passageway.
- the lubricator 20 may either be open to allow the drill string 10 to be inserted downhole through the central passageway of the lubricator 20 (as depicted in FIG. 1) or closed to seal off the formation(s) below the lubricator 20 from the portion of the well 5 that is located above the lubricator 20 .
- the lubricator 20 may be advantageous for shallow drilling or for retrieval of the drill string 10 from the borehole.
- the lubricator 20 may be used to seal off the formation that is beneath the drill string 10 before the drill string 10 is otherwise shallow enough to cause the formation pressure to overcome the weight of the drill string 10 and thus, force the drill string 10 out of the borehole.
- the lubricator 20 may be selectively opened or closed by manipulating the pressure of fluid in an annulus of the well or by varying a pressure on a pressure control line. Safety features that accompany these controls are also described below. As examples of these features, the lubricator may include redundant inline ball valves (described below) to minimize the risk of potential seal failure and a hold close mechanism to prevent accidental opening of the lubricator.
- the borehole of the subterranean well 5 may be partially cased by a casing 12 that is formed from telescopic sections, such as sections 12 a and 12 b, as examples.
- the tubing 16 may also be formed from telescopic sections, such as sections 16 a and 16 b, as examples, and be inserted into the central passageway of the casing 12 .
- An annular seal, or packer 23 may form a seal between the exterior of the drill pipe 10 and the interior of the tubing 16 and form an annulus 21 .
- a drill bit 14 of the drill string 10 may extend beyond the tubing 16 into the formation being currently drilled.
- FIG. 2 generally depicts one-half of the lubricator 20 .
- the lubricator 20 may include an operator mandrel 34 that may be actuated by annulus fluid pressure to operate an upper inline ball valve 30 and a lower inline ball valve 32 , both of which are situated in a central passageway 27 of the lubricator 20 .
- the ball valves 30 and 32 may be closed when no pressure is applied to the fluid in the annulus 21 (see FIG. 1).
- the fluid in the annulus 21 may (via a radial port 38 ) contact a lower surface 48 of a piston head 46 of the operator mandrel 34 , and an upper surface 50 of the piston head 46 may contact a spring 40 .
- the downward force of the spring 40 on the piston head 46 counters the upper force that is produced by the column of fluid in the annulus 21 .
- the operator mandrel 34 may be connected to the ball valves 30 and 32 in a manner that causes the ball valves 30 and 32 to both be open when no surface pressure is applied to the fluid in the annulus 21 and cause both ball valves 30 and 32 to be closed when surface pressure is applied to the annulus 21 .
- An alternative embodiment 70 described in conjunction with FIGS. 3 and 4 below includes a hold close mechanism to prevent unintentional opening of the ball valves 30 and 32 due to a temporary release, or bleeding off, of annulus pressure (due to a failure at the surface of the well, for example).
- the lubricator 20 may include an outer housing 42 that includes a generally cylindrical upper section 50 that has threads for connecting the lubricator 20 inline with the tubing 16 .
- a mandrel 52 of the housing 42 is threadably coupled to the bottom of the upper section 50 between the upper section 50 and a generally cylindrical middle section 54 of the housing 42 .
- the mandrel 52 in combination with the exterior of the operator mandrel 34 and the interior of the middle section 54 , forms a chamber 60 for housing the spring 40 .
- the chamber 60 may be filled with a gas, such as Nitrogen (for example), that aids in pressurizing the chamber 60 and thus, contributing to the force that is exerted against the operator mandrel 34 .
- a gas such as Nitrogen (for example)
- the chamber 60 may include the spring 40 and not contain a pressurized gas.
- the chamber 60 may contain a pressurized gas and not include the spring 40 .
- annulus pressure may be used in the balancing, and as yet another example, two pressure conveying control lines may be extended from the surface of the well for purposes of controlling the operator mandrel 34 .
- Other pressure balancing arrangements are possible that may be used with the lubricator 20 or with the lubricators described below.
- Another mandrel 55 of the housing 42 is coupled between the middle section 54 and a generally cylindrical lower section 56 of the housing 42 .
- the mandrel 55 in combination with the exterior of the operator mandrel 34 and the interior of the middle section 54 , forms a chamber 44 for receiving the annulus fluid that contacts the lower surface 48 of the piston head 46 .
- the radial port 38 may be formed in the middle section 54 .
- the lubricator 20 may also include O-rings to establish seals for the chambers 44 and 50 and to generally seal off the annulus 21 from the central passageway 27 of the lubricator 70 .
- a lubricator 70 may be used in place of the lubricator 20 .
- the lubricator 70 has a hold close mechanism that keeps the ball valves 30 and 32 closed (for example) after pressure in the annulus 21 (see FIG. 1) is bled off, or released.
- the lubricator 70 includes an index mandrel 76 that tends to travel in an upward direction in response to pressure in the annulus 21 . In this manner, referring to FIG.
- a lower radial extension 80 of the index mandrel 76 catches a lug 78 of a lower operator mandrel 81 and causes the operator mandrel 81 to travel in an upward direction and close a lower ball valve 72 .
- an upper radial extension 98 of the index mandrel 76 pushes against a shoulder 105 of an upper operator mandrel 102 to cause the operator mandrel 102 to travel in an upward direction and close an upper ball valve 72 .
- a spring 94 exerts a downward force on a shoulder 95 of the index mandrel 76 , a force that may tend to keep the ball valves 70 and 72 open in the absence of sufficient annulus pressure if not for the hold close mechanism that is described below.
- the hold close mechanism operates in the following manner to keep the ball valves 72 and 74 closed, even if pressure is bled off of the annulus 21 .
- the index mandrel 76 travels in an upward direction to close the ball valves 72 and 74 , outward radial extensions 92 (one being shown in FIG. 3) of the index mandrel 76 slides past an index sleeve 82 that circumscribes the index mandrel 76 .
- the upward travel of the index mandrel 76 causes the index sleeve 82 to rotate and prevent the extensions 92 from passing through the sleeve 82 on the mandrel's downward path.
- the index sleeve 82 prevents the index mandrel 76 from traveling further downhole, an action that would otherwise open the ball valves 72 and 74 .
- surface pressure must be reapplied to the annulus 21 to cause the index mandrel 76 to travel uphole, an action that cause the index sleeve 82 to rotate to a position that allows the extensions 92 to pass through when pressure is subsequently bled off the annulus 21 .
- the index sleeve 82 permits the index mandrel 76 to travel downhole to open the ball valves 72 and 74 .
- the above-described open and close cycle is repeatable.
- pressure is applied to the annulus 21 to close the ball valves 72 and 74 .
- the pressure must be released, then reapplied and then released.
- the index sleeve 82 includes splines 114 that, when aligned with the extensions 92 , halt the downward travel of the index mandrel 76 .
- the index sleeve 82 also includes channels 116 that, when aligned with the extensions 92 , allow the extensions 92 to pass through.
- the index sleeve 82 rotates by a predetermined angle (30°, 60° or 90° (as depicted in FIG. 5), as examples) to align the extensions 92 with either the channels 116 or the splines 114 .
- the rotation of the index sleeve 82 is accomplished via an index pin 84 and J-slot 112 (see FIG. 6) arrangement.
- a portion 110 of the index mandrel 76 may include the slot 112 that serves as a guide for the index pin 84 that is partially disposed therein.
- the index pin 84 may be partially seated in one of the splines 114 . Because the index mandrel 76 is confined not to rotate, the travel of the index pin 84 through the slot 112 causes the index sleeve 82 to rotate, as described above.
- FIGS. 7, 8, 9 , 10 and 11 illustrate operation of the lower ball valve 72 .
- FIG. 7 depicts the scenario where the lower ball valve 72 is opened.
- the index sleeve 82 is rotated to a position where the extensions 92 of the index mandrel 76 pass through the channels 116 of the index sleeve 82 .
- the lower extension 80 of the index mandrel 76 contacts a shoulder 83 of the lower operator mandrel 81 to cause the operator mandrel 81 to open the lower ball valve 72 .
- FIG. 8 depicts a scenario when the lower ball valve 72 is closed.
- the lower extension 80 of the index mandrel 76 catches the lug 78 and pulls the operator mandrel 81 in an upward direction to close the ball valve 72 .
- the extensions 92 pass through the channels 116 of the index sleeve 82 .
- the upward travel of the index mandrel 76 causes the index sleeve 82 to rotate by a predetermined angle (30°, 60° or 90°, as examples), and as a result, the extensions 92 are aligned with the splines 114 , as depicted in FIG. 9.
- downward travel of the index mandrel 76 (and opening of the lower ball valve 74 ) is prevented, even if the applied annulus pressure is released.
- FIGS. 12, 13, 14 , 15 and 16 illustrate operation of the upper ball valve 74 .
- One half of the lubricator 72 is shown in each of these figures.
- FIG. 12 depicts the scenario where the upper ball valve 74 is opened.
- the upper extension 98 of the index mandrel 76 grabs a lug 100 of the upper operator mandrel 102 to cause the operator mandrel 102 to open the upper ball valve 74 .
- FIG. 13 depicts a scenario when the upper ball valve 74 is closed.
- the upper extension 98 of the index mandrel 76 contacts a shoulder 105 of the upper operator mandrel 102 and pushes the operator mandrel 102 in an upward direction to close the ball valve 74 .
- the above-described procedure is initiated to release the hold close mechanism that is depicted in FIG. 14.
- pressure is bled off the annulus 21 and then reapplied to cause the index mandrel 82 to move in an upward direction, as depicted in FIG. 15.
- the upward travel of the index mandrel 82 causes the index sleeve 82 to rotate by a predetermined angle (30°, 60° or 90°, as examples) to a position where the extensions 92 of the index mandrel 76 may pass through the channels 114 of the index sleeve 82 and thus, permit the upper ball valve 74 to close, as depicted in FIG. 16.
- the lubricator 70 may include an outer housing that is formed from generally cylindrical housing sections 79 , 77 , 75 , 73 and 71 that are threadly connected (for example) together.
- the housing section 75 may form a chamber for the spring 94 and a chamber 91 that communicates with a radial port 88 that is formed in the section.
- the radial port 88 establishes fluid communication between the annulus 21 and the chamber 91 that, in turn, places a shoulder 90 of the index mandrel 76 in contact with the annulus fluid.
- the lubricator 70 may also include O-rings and other seals to establish seals for the chamber 91 and generally seal off the annulus 21 from a central passageway 97 of the lubricator 70 .
- a lubricator 130 may be used in place of the lubricator 20 or 70 .
- the lubricator 130 is depicted as including a single ball valve 140 that may be operated to selectively seal off its central passageway 143 .
- the lubricator 130 may include another ball valve, similar to the arrangements described above.
- two lubricators that have single ball valves may be stacked together in some embodiments.
- the lubricator 130 may include an operator mandrel 132 that is connected to open and close the ball valve 140 .
- the operator mandrel 132 includes an annular piston head 134 that piston head 134 resides in an annular region of an outer housing section 142 and forms an upper chamber 138 above the piston head 134 and a lower chamber 136 below the piston head 134 .
- the chamber 138 Via a passageway 139 in the housing section 142 , the chamber 138 is in communication with a tubular line 141 that extends to the surface of the well 5 .
- the line 141 may be rapidly pressurized with a gas (Nitrogen, for example) to exert pressure on an upper surface 135 of the piston head 134 .
- a gas Neitrogen, for example
- the piston head 134 includes a metered communication path between the upper 138 and lower 136 chambers. However, because the flow rate of the gas through this metered path is limited, rapid pressurization of the gas in the upper chamber 138 exerts a net downward force on the piston head 134 , a force that moves the operator mandrel 132 downhole and opens the ball valve 140 (see FIG. 18).
- Closing the ball valve 140 involves a procedure that creates the opposite pressure imbalance between the two chambers 136 and 138 than that described above in conjunction with opening the ball valve 140 . In this manner, eventually after the ball valve 140 is opened, the pressures in the upper 138 and lower 136 chambers equalize due to the metered passageway that is provided by the piston head 134 . To close the ball valve 140 , the line 141 may be used to rapidly bleed off gas from the chamber 138 , an event that forces the operator mandrel 132 in an upward direction due to open the inability of the metered passageway to instantaneously equalize the pressures in the two chambers 136 and 138 .
- the lubricator 130 may include another cylindrical housing section 144 that is threadably coupled to the upper section 142 .
- the lubricator 130 may also include also include O-rings and other seals to establish seals for the chambers 136 and 138 and to generally seal off the annulus 21 from the central passageway 141 of the lubricator 130 .
- the above-described lubricators may be replaced by a lubricator 160 that is depicted in FIG. 19.
- the lubricator 160 is similar to the lubricator 130 except for the features noted below.
- the line 141 is replaced with a radial port 162 that establishes communication between the annulus 21 and a chamber 164 of the lubricator 160 .
- pressure at the surface of the well may be applied to the annulus 21 for purposes of opening and closing the ball valve 140 .
- the chamber 164 is formed in part by the annular region that establishes the chambers 136 and 138 .
- a radial port 165 establishes fluid communication between the annulus 21 and the chamber 164 .
- An unattached annular piston 166 separates the chambers 164 and 136 , and chambers 136 and 138 contain a gas, such as Nitrogen. Therefore, when pressure is rapidly applied to the annulus 21 , the fluid from the annulus 21 forces the piston 166 upwards.
- the upward travel of the piston 166 forces the operator mandrel 132 in an upward direction, as the metering passageway in the piston head 134 does not communicate the gas between the chambers 136 and 138 in a rapid enough manner to prevent the pressure imbalance.
- the upward travel of the operator mandrel 132 closes the ball valve 140 .
- the ball valve 140 may be opened by rapidly bleeding pressure from the annulus 21 to cause a pressure imbalance between the chambers 136 and 138 to force the operator mandrel 132 in a downward direction.
- a tubing 202 (that replaces the tubing 16 ) may have a stabbing connector assembly 204 connected to its downhole end.
- the assembly 204 may be used to stab a seal assembly into a polished bore receptacle (PBR) 211 that is coupled to the lubricator 130 (for example) that, in turn, is further coupled to additional tubing 214 that extends downhole.
- PBR polished bore receptacle
- the assembly 204 may include a passageway 208 that establishes fluid communication between the line 141 , a passageway 210 of the PBR 211 and the lubricator 20 .
- the tubing 202 may be removed while the lubricator 20 and the tubing 214 are left downhole.
- a lubricator (such as the lubricators 20 , 70 and 160 , as examples) that is controlled by annulus pressure may be arranged in the following manner.
- the lubricator may be permanently coupled and concentrically aligned with tubing 256 that extends downhole of the lubricator.
- the annular space between the tubing 256 and a casing 255 that surrounds the tubing 256 is sealed to form an annulus for communicating with the lubricator.
- a liner 257 may also be sealed and secured to the inside of the well casing 255 and reside below the tubing 256 .
- a production pipe 258 may be located below the liner 257 and connected to provide production fluid to the central passageway of the tubing 256 .
- an upper tubing 252 may extend to the surface of the well 250 .
- the upper tubing 252 rests and is sealed to a flange 253 that is formed in the upper end of the tubing 254 . Due to this arrangement, the upper tubing 252 may be removed from the well 250 , and the lubricator and tubing 254 remain downhole.
- a lubricator 300 may be used in place of the lubricators that are depicted above. Unlike these other lubricators, the lubricator 300 includes a protective sleeve 342 to protect a ball valve 340 of the lubricator 300 from drilling related debris, such as drilling fluid and cuttings, for example.
- the lubricator 300 moves the sleeve 342 into an up position in which the sleeve is located in the central passageway 341 of the ball valve 340 ; and before the lubricator 300 closes the ball valve 340 , the lubricator 300 moves the sleeve 342 to a down position, a position that permits the ball valve 340 to rotate and close.
- the lubricator 300 operates the ball valve 340 and sleeve 342 in response to the pressure that is applied via a control line that extends from a surface of the well to an internal passageway 308 of the lubricator 300 .
- the control line may be filled with nitrogen gas that is pressurized and de-pressurized, as described below, to control operation of the ball valve 340 and sleeve 342 .
- the lubricator 300 includes an operator mandrel 325 includes a generally cylindrical portion 323 that is aligned with the longitudinal axis of the lubricator 300 and is connected (via another cylindrical portion 327 that is aligned with the longitudinal axis of the lubricator 300 ) to the ball valve 340 . Due to this arrangement, when the operator mandrel 325 moves in an upward direction, the ball valve 340 closes to block fluid flow through the central passageway of the lubricator 300 . When the operator mandrel 325 moves in a downward direction, the ball valve 340 opens to align its central passageway with the central passageway of the lubricator 300 to permit fluid communication through the ball valve 340 .
- the operator mandrel 325 For purposes of moving the operator mandrel 325 , the operator mandrel 325 includes an annular piston head 322 that extends in a radially outward direction from the cylindrical portion 323 .
- the piston head 322 is located in an annular cavity that is formed between the cylindrical portion 323 and a generally cylindrical outer housing section 304 that circumscribes the cylindrical portion 323 .
- the annular cavity forms an upper cylinder 320 above the piston head 322 and a lower cylinder 324 (shown having no volume in FIG. 22) below the piston head 322 .
- the volumes of the upper 320 and lower 324 chambers change with the movement of the piston head 322 .
- Movement of the piston head 322 (and thus, movement of the operator mandrel 325 and ball valve 340 ) may be induced by changing the pressure level in the control line that communicates with the passageway 308 , as the control line is in communication with the passageway 308 for certain pressure levels (as described below) via an internal passageway 318 .
- the piston head 322 includes a metering passageway 326 to establish communication between the upper 320 and lower 324 chambers.
- the metering passageway 326 permits pressure equalization between the upper 320 and lower 324 chambers over time, the metering passageway 326 restricts the rate at which pressure equalization occurs, allowing sudden changes to the pressure in the upper chamber 320 to control movement of the operator mandrel 325 and thus, control operation of the ball valve 340 , as described below.
- the lubricator 300 includes a relief valve 314 that is located between the passageway 308 and the chamber 320 .
- the relief valve 314 opens to permit communicate of fluid between the passageway 308 and the chamber 320 when the pressure in the passageway 308 exceeds a predetermined threshold, such as 1500 pounds per square inch (psi), for example.
- a predetermined threshold such as 1500 pounds per square inch (psi)
- the threshold for the relief valve 314 is set slightly higher than the fluid hydrostatic pressure in the annulus. This assures that the ball valve 340 remains in its current position in case of control line failure at any depth.
- the lubricator valve 300 also includes a check valve 316 that is located between the passageway 308 and the chamber 320 and is in a parallel arrangement with the relief valve 314 .
- the check valve 316 provides a path to communicate fluid away from the upper chamber 320 to bleed off pressure from the upper chamber 320 to control movement of the operator mandrel 325 , as described below.
- the control line must first be pressurized to a pressure that is to slightly higher than the threshold of the relief valve 314 .
- the increased pressure is maintained, or held, for a holding period, such as 5 to 10 minutes, for example.
- the holding period allows sufficient time from the pressures in the two chambers 320 and 324 to equalize.
- the control line is rapidly de-pressurized to create the differential pressure across the piston 322 to cause the operator mandrel 325 to move in an upward direction and close the ball valve 340 , as described above.
- the following technique may be used to open the ball valve 340 when the ball valve 340 is currently closed.
- the pressure in the tubing above the ball valve 340 is adjusted to ensure that the pressure differential across the ball valve 340 is less than 1000 psi. If possible, the pressure across the ball valve 340 is equalized.
- the pressure in the control line is rapidly increased to a pressure that is slightly higher than the relief valve threshold pressure. For example, this increase may occur within an interval of one to two minutes, in some embodiments of the invention. In response to this increase, a pressure differential is created across the piston 322 causing the operator mandrel 325 to move and open the ball valve 340 .
- the pressure in the control line is then slowly bled off through a slow bleed port in the surface manifold, for example. Because the upper chamber 320 is slowly depressurized, the metering passageway 326 keeps the pressure differential between the upper 320 and lower 324 chambers near zero. This by itself keeps the ball valve 340 open. However, in some embodiments of the invention, at this point, the sleeve 342 is positioned inside the central passageway 341 of the ball valve 340 to lock the ball valve 340 in place to keep the ball valve from closing, as described further below.
- An advantage of using the above-described arrangement is that an operator may select the position to which the ball valve 340 defaults if the pressure integrity of the control line is lost at the surface or near the lubricator 300 . For example, if the operator wishes to keep the ball valve 340 closed even if the control line loose pressure integrity, then the operator maintains the control line pressure to keep the control line pressure within the difference (500 psi, for example) of the relief valve threshold and the pressure in the annulus. This keeps the ball valve 340 closed regardless where the control line fails.
- the operator If the operator wishes to keep the ball valve 340 open regardless if the control line looses pressure integrity at the surface or at the lubricator valve 300 , then the operator should bleed off the control line pressure so that no matter where the control line breaks, the ball valve 340 remains open.
- the sleeve 342 is part of an operator mandrel 330 that, in addition to the generally cylindrical section that forms the sleeve 342 , includes a piston 331 that extends in a radially outward direction into a cavity that is formed between the operator mandrel 330 and an outer housing section 306 of the lubricator 300 .
- the piston 331 divides this cavity into a chamber 328 that is in communication with the passageway 318 and in contact with an upper face of the piston 331 ; and a sealed chamber 332 that is in contact with a lower face of the piston 331 .
- the sealed chamber 332 is filled with a gas (nitrogen or air at atmospheric pressure, for example) that exerts an upward force against the lower surface of the piston 331 .
- the chamber 332 may include a spring to exert a force against the lower surface of the piston 331 .
- the upper face of the piston 331 receives a force that is applied by the gas that is present in the chamber 328 . Due to this arrangement, pressure may be applied to the gas in the control line to move the sleeve 342 to its down position out of the ball valve 340 , and pressure may be bled out of the control line to move the sleeve 342 to its up position inside the ball valve 340 .
- the lubricator 300 includes a gas metering device 310 (a gas metering passageway, for example) that is located between the passageway 308 and an internal passageway 307 that extends to the chamber 328 .
- a gas metering device 310 establishes a delay to permit the ball valve 340 to open before the sleeve 342 is inserted into the central passageway 341 of the ball valve 340 and a delay in the removal of the sleeve 342 from the passageway 341 to prevent the ball valve 340 from prematurely closing, as described below.
- FIG. 23 depicts a flow diagram that illustrates a control technique 380 to close the ball valve 340 and operate the sleeve 342 accordingly.
- the threshold pressure of the relief valve is approximately 1500 psi
- the sealed chamber 328 is precharged with 500 psi of gas, such as nitrogen gas, for example.
- the control line is pressurized (block 381 ) with a pressure (2000 psi, for example) that is greater than the threshold pressure (1500 psi, for example) of the relief valve 314 .
- This pressure is then held (block 384 ) for a few minutes to move the sleeve 342 to its down position and set the pressure differential between the upper 320 and lower 324 chambers to near zero.
- the gas meters through the cover sleeve gas metering device 310 and fills the chamber 328 to pull the sleeve 342 out of the ball valve 340 .
- the gas fills the upper chamber 320 and then fills the lower chamber 324 through the gas metering passageway 326 .
- the operator mandrel 325 does not move down because the mandrel 325 is already in the down position.
- the ball valve 340 remains open.
- the control line is rapidly depressurized (block 390 ) by, for example, using a fast bleed port in the surface manifold. Due to this action, the operator mandrel 325 moves to close the ball valve 340 , and the pressure in the chamber 328 slowly bleeds off due to the gas metering device 310 .
- pressure in the control line is bled off below the 500 psi level (i.e., the pressure exerted by the gas in the sealed chamber 332 for this example)
- the gas pressure in the chamber 332 forces the operator mandrel 300 in an upward direction to push the sleeve 342 against the ball valve 340 .
- the ball valve 340 acts as a stop to limit upward travel of the sleeve 342 .
- the pressure in the control line, the upper 320 and lower 324 chambers, and the chamber 328 then bleeds down to atmospheric pressure after some time.
- FIG. 24 depicts a flow diagram that illustrates a control technique 400 to open the ball valve 340 and operate the sleeve 342 accordingly.
- this technique first a determination is made (diamond 402 ) whether the control line is pressurized. If not, pressure less than the relief valve pressure threshold is applied (block 406 ), such as 1000 psi (for example) and held (block 408 ). This action moves the sleeve 342 to its down position, as the gas meters through the gas metering device 310 to push the sleeve 342 off of the ball valve 340 .
- the ball valve 340 remains closed at this point.
- the pressure in the control line is rapidly increased (block 404 ), such as increased to 2000 psi (a pressure above the relief valve pressure of 1500 psi, as an example), to induce a pressure imbalance between the upper 320 and lower 324 chambers to move the operator mandrel 325 to open the ball valve 340 .
- the upper chamber 320 , the lower chamber 324 and the chamber 328 all have the same pressure, such as a pressure near 2000 psi, for example.
- the control line is depressurized (block 405 ) through the slow bleed port in the surface manifold, for example.
- This action keeps the ball valve 340 in the open position and permits the pressure inside the sealed chamber 332 to push the sleeve 342 into the central passageway 341 of the ball valve 340 .
- the sleeve 342 rests on a shoulder 327 that is formed on the operator mandrel 325 to limit the upward travel of the sleeve 342 when the ball valve 340 is open.
- the above-described opening and closing of the ball valve 340 may be repeated as many times as required.
- the lubricator 300 may be formed from upper 302 , middle 304 and lower 306 generally cylindrical housing sections.
- the passageway 308 is formed in the upper housing section 302 , and the upper housing section 302 also encloses the pressure relief valve 314 , the gas metering device 310 and the one way check valve 316 .
- the passageway 307 extends from the gas metering device 310 through the upper 302 , middle 304 and lower 306 housing sections to the chamber 328 .
- FIG. 25 depicts a portion 540 of a lubricator of similar design to the lubricators that are described above with the following exception.
- the lubricator includes a solenoid 542 that has a shaft 544 that is connected to the operator mandrel 330 . Due to this arrangement, the solenoid 542 may be controlled (via electrical lines 546 ) to move the sleeve 342 up and down as desired.
- the electrical lines 546 may be connected to electronics of the lubricator, and the electronics, may, for example control operation of the sleeve 342 in response to pressure pulses that are communicated downhole.
- the electrical lines 546 may extend from the surface of the well to directly control operation of the operator mandrel 330 .
- Other arrangements are possible.
- the lubricator may be constructed to be remotely controlled by arrangements other than those described above. In this manner, the lubricator may be constructed to respond to tubing conveyed pressure, electrical signals (via electrical wires) and coded pressure pulses, as just a few examples of other stimuli that may be communicated downhole.
- the lubricator may use valves other than ball valves.
- the lubricator may include one or more flapper valves.
- the lubricator and any associated control line may be run downhole with the well casing. Therefore, the lubricator and control line may be cemented in place with the well casing. Thus, by using this technique, the inner diameter of the lubricator may be increased.
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Abstract
A system usable with a subterranean well includes a tubing and a lubricator. The tubing is adapted to receive a drill string in a passageway of the tubing, and the lubricator is located downhole and is connected to the tubing. The lubricator is adapted to be remotely operable from a surface of the well to control fluid communication between the passageway located above the lubricator and a formation located beneath the lubricator. The lubricator may include a sleeve and controller. The controller selectively moves the sleeve into a passageway of a valve of the lubricator to protect the valve from a downhole fluid.
Description
- This application claims the benefit, under 35 U.S.C. §119, to U.S. Provisional Patent application Ser. No. 60/143,322, entitled, “LUBRICATOR FOR UNDERBALANCED DRILLING,” filed on Jul. 12, 1999.
- The invention relates to a lubricator for underbalanced drilling.
- There are two techniques that typically are used to drill a borehole in a formation: an overbalanced drilling technique and underbalanced drilling technique. In overbalanced drilling, fluid in an annulus of a well is used to exert a pressure that is greater than the formation pressure. Thus, the pressure that is exerted by the annulus fluid keeps formation fluids from exiting the well. A drawback to this technique is that mud particles typically are added to the annulus fluid to increase its weight (and thus, increase its downhole pressure), and these mud particles tend to clog up openings in the formation. Thus, the formation may be damaged by overbalanced drilling, and after drilling, cleanup of the well may be needed before production begins. The well may also need to be tested after overbalanced drilling to check for formation damage.
- Unlike overbalanced drilling, underbalanced drilling typically does not damage the formation damage and typically maximizes reservoir inflow. In underbalanced drilling, heavy annulus fluid is not used to suppress the formation pressure. Instead, a blowout preventer, or snubbing unit, is used to seal off the drill string at the surface of the well. However, this arrangement may also present difficulties. For example, when drilling at shallow depths or retrieving the drill string, the upward force from the formation pressure may exceed the weight of the drill string and thus, may force the drill string out of the borehole. As a result, retrieving the drill string may consume a considerable amount of time and present a significant danger.
- Thus, there is a continuing need for an arrangement to address one or more of the problems that are stated above.
- In an embodiment of the invention, a system usable with a subterranean well includes a tubing and a lubricator. The tubing is adapted to receive a drill string in a passageway of the tubing, and the lubricator is located downhole and is connected to the tubing. The lubricator is adapted to be remotely operable from a surface of the well to control fluid communication between the passageway located above the lubricator and a formation located beneath the lubricator.
- In another embodiment of the invention, an apparatus that is usable with a downhole tool that has a passageway includes a sleeve and a controller. The controller selectively moves the sleeve into the passageway to protect a portion of the downhole tool from a downhole fluid.
- Advantages and other features of the invention will become apparent from the following description, drawing and claims.
- FIG. 1 is a schematic diagram of a subterranean well according to an embodiment of the invention.
- FIG. 2 is a cross-sectional view of a lubricator according to an embodiment of the invention.
- FIGS. 3 and 4 are cross-sectional views of a lubricator according to an embodiment of the invention.
- FIG. 5 is a cross-sectional view of the lubricator of FIGS. 3 and 4 taken along line5-5 of FIG. 3.
- FIG. 6 is a schematic diagram of a J-slot of the lubricator of FIGS. 3 and 4.
- FIGS. 7, 8,9, 10, 11, 12, 13, 14, 15 and 16 are schematic diagrams illustrating different operational states of the lubricator of FIGS. 3 and 4.
- FIGS. 17 and 18 are cross-sectional views of a lubricator according to an embodiment of the invention.
- FIG. 19 is a cross-sectional view of a lubricator according to an embodiment of the invention.
- FIGS. 20 and 21 are schematic diagrams of wells according to different embodiments of the invention.
- FIG. 22 is a cross-sectional view of a lubricator according to an embodiment of the invention.
- FIG. 23 is a flow diagram depicting an algorithm to close a ball valve of the lubricator according to an embodiment of the invention.
- FIG. 24 is a flow diagram depicting an algorithm to open a ball valve of the lubricator according to an embodiment of the invention.
- FIG. 25 is a cross-sectional view of a portion of a lubricator valve according to an embodiment of the invention.
- Referring to FIG. 1, in a
subterranean well 5, anembodiment 20 of a downhole lubricator in accordance with the invention may be used for underbalanced drilling. When a drill pipe, orstring 10, is inserted through a central passageway of thelubricator 20, thelubricator 20 forms a seal between anannulus 19 that is formed from the exterior surface of thestring 10 and the interior surface of aconcentric tubing 16. When thedrill string 10 is withdrawn from thelubricator 20, thelubricator 20 may be remotely operated from the surface of thewell 5 to selectively seal off its central passageway. In this manner, thelubricator 20 may either be open to allow thedrill string 10 to be inserted downhole through the central passageway of the lubricator 20 (as depicted in FIG. 1) or closed to seal off the formation(s) below thelubricator 20 from the portion of thewell 5 that is located above thelubricator 20. - Because the design of the
lubricator 20 permits thelubricator 20 to be positioned a sufficient distance (approximately one to three thousand feet, for example) downhole, thelubricator 20 may be advantageous for shallow drilling or for retrieval of thedrill string 10 from the borehole. For example, during retrieval of thedrill string 10, thelubricator 20 may be used to seal off the formation that is beneath thedrill string 10 before thedrill string 10 is otherwise shallow enough to cause the formation pressure to overcome the weight of thedrill string 10 and thus, force thedrill string 10 out of the borehole. As described further below, depending on the particular embodiment, thelubricator 20 may be selectively opened or closed by manipulating the pressure of fluid in an annulus of the well or by varying a pressure on a pressure control line. Safety features that accompany these controls are also described below. As examples of these features, the lubricator may include redundant inline ball valves (described below) to minimize the risk of potential seal failure and a hold close mechanism to prevent accidental opening of the lubricator. - As depicted in FIG. 1, the borehole of the
subterranean well 5 may be partially cased by acasing 12 that is formed from telescopic sections, such assections tubing 16 may also be formed from telescopic sections, such assections casing 12. An annular seal, orpacker 23, may form a seal between the exterior of thedrill pipe 10 and the interior of thetubing 16 and form anannulus 21. Adrill bit 14 of thedrill string 10 may extend beyond thetubing 16 into the formation being currently drilled. - FIG. 2 generally depicts one-half of the
lubricator 20. As shown, thelubricator 20 may include anoperator mandrel 34 that may be actuated by annulus fluid pressure to operate an upperinline ball valve 30 and a lowerinline ball valve 32, both of which are situated in acentral passageway 27 of thelubricator 20. In some embodiments, theball valves annulus 21 may (via a radial port 38) contact alower surface 48 of apiston head 46 of theoperator mandrel 34, and anupper surface 50 of thepiston head 46 may contact aspring 40. When no surface pressure is applied to the fluid in theannulus 21, the downward force of thespring 40 on thepiston head 46 counters the upper force that is produced by the column of fluid in theannulus 21. - However, when additional pressure is applied to the column of fluid at the surface of the
well 5, an additional upward force is applied to thepiston head 46 to cause theoperator mandrel 34 to move in an upward direction and compress thespring 40. The upward travel of theoperator mandrel 34, in turn, rotates theball valves spring 40 forces theoperator mandrel 34 back down to close theball valves operator mandrel 34 is coupled to a position of theball valve 30 that is different than a position to which a lower end of theoperator mandrel 34 is coupled. These connection differences cause bothball valves operator mandrel 34 and to close in response to the downward travel of theoperator mandrel 34. - Alternatively, in other embodiments, the
operator mandrel 34 may be connected to theball valves ball valves annulus 21 and cause bothball valves annulus 21. Analternative embodiment 70 described in conjunction with FIGS. 3 and 4 below includes a hold close mechanism to prevent unintentional opening of theball valves - Among the other features of the
lubricator 20, in some embodiments, thelubricator 20 may include anouter housing 42 that includes a generally cylindricalupper section 50 that has threads for connecting thelubricator 20 inline with thetubing 16. Amandrel 52 of thehousing 42 is threadably coupled to the bottom of theupper section 50 between theupper section 50 and a generally cylindricalmiddle section 54 of thehousing 42. Themandrel 52, in combination with the exterior of theoperator mandrel 34 and the interior of themiddle section 54, forms achamber 60 for housing thespring 40. As an example, thechamber 60 may be filled with a gas, such as Nitrogen (for example), that aids in pressurizing thechamber 60 and thus, contributing to the force that is exerted against theoperator mandrel 34. In other embodiments, other balancing techniques may be used. For example, thechamber 60 may include thespring 40 and not contain a pressurized gas. Alternatively, thechamber 60 may contain a pressurized gas and not include thespring 40. As another example, in some embodiments, annulus pressure may be used in the balancing, and as yet another example, two pressure conveying control lines may be extended from the surface of the well for purposes of controlling theoperator mandrel 34. Other pressure balancing arrangements are possible that may be used with thelubricator 20 or with the lubricators described below. - Another
mandrel 55 of thehousing 42 is coupled between themiddle section 54 and a generally cylindricallower section 56 of thehousing 42. Themandrel 55, in combination with the exterior of theoperator mandrel 34 and the interior of themiddle section 54, forms achamber 44 for receiving the annulus fluid that contacts thelower surface 48 of thepiston head 46. Theradial port 38 may be formed in themiddle section 54. Thelubricator 20 may also include O-rings to establish seals for thechambers annulus 21 from thecentral passageway 27 of thelubricator 70. - For the
lubricator 20, continuous annulus pressure must be applied to keep theball valves lubricator 70 may be used in place of thelubricator 20. Unlike thelubricator 20, thelubricator 70 has a hold close mechanism that keeps theball valves lubricator 70 includes anindex mandrel 76 that tends to travel in an upward direction in response to pressure in theannulus 21. In this manner, referring to FIG. 3, when theindex mandrel 76 travels a sufficient distance uphole, a lowerradial extension 80 of theindex mandrel 76 catches alug 78 of alower operator mandrel 81 and causes theoperator mandrel 81 to travel in an upward direction and close alower ball valve 72. Similarly, referring to FIG. 4, when theindex mandrel 76 has traveled a sufficient distance uphole, an upperradial extension 98 of theindex mandrel 76 pushes against ashoulder 105 of anupper operator mandrel 102 to cause theoperator mandrel 102 to travel in an upward direction and close anupper ball valve 72. Aspring 94 exerts a downward force on ashoulder 95 of theindex mandrel 76, a force that may tend to keep theball valves - The hold close mechanism operates in the following manner to keep the
ball valves annulus 21. When theindex mandrel 76 travels in an upward direction to close theball valves index mandrel 76 slides past anindex sleeve 82 that circumscribes theindex mandrel 76. However, the upward travel of theindex mandrel 76 causes theindex sleeve 82 to rotate and prevent theextensions 92 from passing through thesleeve 82 on the mandrel's downward path. Therefore, if the applied annulus pressure is released, theindex sleeve 82 prevents theindex mandrel 76 from traveling further downhole, an action that would otherwise open theball valves annulus 21 to cause theindex mandrel 76 to travel uphole, an action that cause theindex sleeve 82 to rotate to a position that allows theextensions 92 to pass through when pressure is subsequently bled off theannulus 21. In this manner, when pressure is removed from theannulus 21, theindex sleeve 82 permits theindex mandrel 76 to travel downhole to open theball valves annulus 21 to close theball valves ball valves - Referring to FIG. 5, in some embodiments, the
index sleeve 82 includessplines 114 that, when aligned with theextensions 92, halt the downward travel of theindex mandrel 76. Theindex sleeve 82 also includeschannels 116 that, when aligned with theextensions 92, allow theextensions 92 to pass through. Each time theindex mandrel 76 travels uphole, theindex sleeve 82 rotates by a predetermined angle (30°, 60° or 90° (as depicted in FIG. 5), as examples) to align theextensions 92 with either thechannels 116 or thesplines 114. In some embodiments, the rotation of theindex sleeve 82 is accomplished via anindex pin 84 and J-slot 112 (see FIG. 6) arrangement. In this manner, referring to FIG. 6, aportion 110 of theindex mandrel 76 may include theslot 112 that serves as a guide for theindex pin 84 that is partially disposed therein. Theindex pin 84 may be partially seated in one of thesplines 114. Because theindex mandrel 76 is confined not to rotate, the travel of theindex pin 84 through theslot 112 causes theindex sleeve 82 to rotate, as described above. - FIGS. 7, 8,9, 10 and 11 illustrate operation of the
lower ball valve 72. One half of thelubricator 72 is shown in each of these figures. FIG. 7 depicts the scenario where thelower ball valve 72 is opened. For this to occur, theindex sleeve 82 is rotated to a position where theextensions 92 of theindex mandrel 76 pass through thechannels 116 of theindex sleeve 82. As shown, thelower extension 80 of theindex mandrel 76 contacts ashoulder 83 of thelower operator mandrel 81 to cause theoperator mandrel 81 to open thelower ball valve 72. - FIG. 8 depicts a scenario when the
lower ball valve 72 is closed. In this manner, for this scenario, thelower extension 80 of theindex mandrel 76 catches thelug 78 and pulls theoperator mandrel 81 in an upward direction to close theball valve 72. As depicted in FIG. 8, theextensions 92 pass through thechannels 116 of theindex sleeve 82. However, the upward travel of theindex mandrel 76 causes theindex sleeve 82 to rotate by a predetermined angle (30°, 60° or 90°, as examples), and as a result, theextensions 92 are aligned with thesplines 114, as depicted in FIG. 9. Thus, downward travel of the index mandrel 76 (and opening of the lower ball valve 74) is prevented, even if the applied annulus pressure is released. - At this point, to open the
lower ball valve 74, pressure is bled off theannulus 21 and then reapplied to cause theindex mandrel 82 to move in an upward direction, as depicted in FIG. 10. The upward travel of theindex mandrel 82 causes theindex sleeve 82 to rotate by a predetermined angle (30°, 60° or 90°, as examples) to a position where theextensions 92 of theindex mandrel 76 may pass through thechannels 114 of theindex sleeve 82 and thus, permit thelower ball valve 74 to close, as depicted in FIG. 11. - The
upper ball valve 74 opens and closes with thelower ball valve 72. FIGS. 12, 13, 14, 15 and 16 illustrate operation of theupper ball valve 74. One half of thelubricator 72 is shown in each of these figures. FIG. 12 depicts the scenario where theupper ball valve 74 is opened. As shown, theupper extension 98 of theindex mandrel 76 grabs alug 100 of theupper operator mandrel 102 to cause theoperator mandrel 102 to open theupper ball valve 74. - FIG. 13 depicts a scenario when the
upper ball valve 74 is closed. In this manner, for this scenario, theupper extension 98 of theindex mandrel 76 contacts ashoulder 105 of theupper operator mandrel 102 and pushes theoperator mandrel 102 in an upward direction to close theball valve 74. To reopen theball valve 74, the above-described procedure is initiated to release the hold close mechanism that is depicted in FIG. 14. In this manner, to open theupper ball valve 74, pressure is bled off theannulus 21 and then reapplied to cause theindex mandrel 82 to move in an upward direction, as depicted in FIG. 15. The upward travel of theindex mandrel 82 causes theindex sleeve 82 to rotate by a predetermined angle (30°, 60° or 90°, as examples) to a position where theextensions 92 of theindex mandrel 76 may pass through thechannels 114 of theindex sleeve 82 and thus, permit theupper ball valve 74 to close, as depicted in FIG. 16. - Referring back to FIGS. 3 and 4, among the other features of the
lubricator 70, thelubricator 70 may include an outer housing that is formed from generallycylindrical housing sections housing section 75 may form a chamber for thespring 94 and achamber 91 that communicates with aradial port 88 that is formed in the section. Theradial port 88 establishes fluid communication between theannulus 21 and thechamber 91 that, in turn, places ashoulder 90 of theindex mandrel 76 in contact with the annulus fluid. Thelubricator 70 may also include O-rings and other seals to establish seals for thechamber 91 and generally seal off theannulus 21 from acentral passageway 97 of thelubricator 70. - Referring to FIGS. 17 and 18, in some embodiments, a
lubricator 130 may be used in place of thelubricator lubricator 130 is depicted as including asingle ball valve 140 that may be operated to selectively seal off itscentral passageway 143. However, in some embodiments, thelubricator 130 may include another ball valve, similar to the arrangements described above. Alternatively, two lubricators that have single ball valves may be stacked together in some embodiments. - In some embodiments, the
lubricator 130 may include anoperator mandrel 132 that is connected to open and close theball valve 140. Theoperator mandrel 132 includes anannular piston head 134 thatpiston head 134 resides in an annular region of anouter housing section 142 and forms anupper chamber 138 above thepiston head 134 and alower chamber 136 below thepiston head 134. Via apassageway 139 in thehousing section 142, thechamber 138 is in communication with atubular line 141 that extends to the surface of thewell 5. In this manner, theline 141 may be rapidly pressurized with a gas (Nitrogen, for example) to exert pressure on anupper surface 135 of thepiston head 134. Thepiston head 134 includes a metered communication path between the upper 138 and lower 136 chambers. However, because the flow rate of the gas through this metered path is limited, rapid pressurization of the gas in theupper chamber 138 exerts a net downward force on thepiston head 134, a force that moves theoperator mandrel 132 downhole and opens the ball valve 140 (see FIG. 18). - Closing the
ball valve 140 involves a procedure that creates the opposite pressure imbalance between the twochambers ball valve 140. In this manner, eventually after theball valve 140 is opened, the pressures in the upper 138 and lower 136 chambers equalize due to the metered passageway that is provided by thepiston head 134. To close theball valve 140, theline 141 may be used to rapidly bleed off gas from thechamber 138, an event that forces theoperator mandrel 132 in an upward direction due to open the inability of the metered passageway to instantaneously equalize the pressures in the twochambers - Among the other features of the
lubricator 130, thelubricator 130 may include anothercylindrical housing section 144 that is threadably coupled to theupper section 142. Thelubricator 130 may also include also include O-rings and other seals to establish seals for thechambers annulus 21 from thecentral passageway 141 of thelubricator 130. - In some embodiments, the above-described lubricators may be replaced by a
lubricator 160 that is depicted in FIG. 19. Thelubricator 160 is similar to thelubricator 130 except for the features noted below. In particular, in thelubricator 160, theline 141 is replaced with aradial port 162 that establishes communication between theannulus 21 and achamber 164 of thelubricator 160. Thus, pressure at the surface of the well may be applied to theannulus 21 for purposes of opening and closing theball valve 140. In this manner, thechamber 164 is formed in part by the annular region that establishes thechambers radial port 165 establishes fluid communication between theannulus 21 and thechamber 164. An unattachedannular piston 166 separates thechambers chambers annulus 21, the fluid from theannulus 21 forces thepiston 166 upwards. The upward travel of thepiston 166, in turn, forces theoperator mandrel 132 in an upward direction, as the metering passageway in thepiston head 134 does not communicate the gas between thechambers operator mandrel 132, in turn, closes theball valve 140. - The
ball valve 140 may be opened by rapidly bleeding pressure from theannulus 21 to cause a pressure imbalance between thechambers operator mandrel 132 in a downward direction. - Referring back to FIG. 1, in the
well 5 described above, thelubricator 20 is permanently connected to thetubing 16. Due to this arrangement, theentire tubing 16 must be removed before other operations, such as measurements, are performed. Referring to FIG. 20, in another well 200, a tubing 202 (that replaces the tubing 16) may have astabbing connector assembly 204 connected to its downhole end. In this manner, theassembly 204 may be used to stab a seal assembly into a polished bore receptacle (PBR) 211 that is coupled to the lubricator 130 (for example) that, in turn, is further coupled toadditional tubing 214 that extends downhole. Theassembly 204 may include apassageway 208 that establishes fluid communication between theline 141, apassageway 210 of thePBR 211 and thelubricator 20. Thus, due to this arrangement, thetubing 202 may be removed while thelubricator 20 and thetubing 214 are left downhole. - Referring to FIG. 21, in another well250, a lubricator (such as the
lubricators tubing 256 that extends downhole of the lubricator. The annular space between thetubing 256 and acasing 255 that surrounds thetubing 256 is sealed to form an annulus for communicating with the lubricator. Aliner 257 may also be sealed and secured to the inside of thewell casing 255 and reside below thetubing 256. Aproduction pipe 258 may be located below theliner 257 and connected to provide production fluid to the central passageway of thetubing 256. Above the lubricator, anupper tubing 252 may extend to the surface of thewell 250. Theupper tubing 252 rests and is sealed to aflange 253 that is formed in the upper end of the tubing 254. Due to this arrangement, theupper tubing 252 may be removed from the well 250, and the lubricator and tubing 254 remain downhole. - Referring to FIG. 22, in some embodiments of the invention, a
lubricator 300 may be used in place of the lubricators that are depicted above. Unlike these other lubricators, thelubricator 300 includes aprotective sleeve 342 to protect aball valve 340 of the lubricator 300 from drilling related debris, such as drilling fluid and cuttings, for example. In this manner, as described below, after thelubricator 300 opens theball valve 340, thelubricator 300 moves thesleeve 342 into an up position in which the sleeve is located in thecentral passageway 341 of theball valve 340; and before thelubricator 300 closes theball valve 340, thelubricator 300 moves thesleeve 342 to a down position, a position that permits theball valve 340 to rotate and close. - More specifically, in some embodiments of the invention, the
lubricator 300 operates theball valve 340 andsleeve 342 in response to the pressure that is applied via a control line that extends from a surface of the well to aninternal passageway 308 of thelubricator 300. In some embodiments of the invention, the control line may be filled with nitrogen gas that is pressurized and de-pressurized, as described below, to control operation of theball valve 340 andsleeve 342. - For purposes of operating the
ball valve 340, thelubricator 300 includes anoperator mandrel 325 includes a generallycylindrical portion 323 that is aligned with the longitudinal axis of thelubricator 300 and is connected (via anothercylindrical portion 327 that is aligned with the longitudinal axis of the lubricator 300) to theball valve 340. Due to this arrangement, when theoperator mandrel 325 moves in an upward direction, theball valve 340 closes to block fluid flow through the central passageway of thelubricator 300. When theoperator mandrel 325 moves in a downward direction, theball valve 340 opens to align its central passageway with the central passageway of thelubricator 300 to permit fluid communication through theball valve 340. - For purposes of moving the
operator mandrel 325, theoperator mandrel 325 includes anannular piston head 322 that extends in a radially outward direction from thecylindrical portion 323. Thepiston head 322 is located in an annular cavity that is formed between thecylindrical portion 323 and a generally cylindricalouter housing section 304 that circumscribes thecylindrical portion 323. The annular cavity forms anupper cylinder 320 above thepiston head 322 and a lower cylinder 324 (shown having no volume in FIG. 22) below thepiston head 322. Thus, as depicted in FIG. 22, the volumes of the upper 320 and lower 324 chambers change with the movement of thepiston head 322. - Movement of the piston head322 (and thus, movement of the
operator mandrel 325 and ball valve 340) may be induced by changing the pressure level in the control line that communicates with thepassageway 308, as the control line is in communication with thepassageway 308 for certain pressure levels (as described below) via aninternal passageway 318. Thepiston head 322 includes ametering passageway 326 to establish communication between the upper 320 and lower 324 chambers. Although themetering passageway 326 permits pressure equalization between the upper 320 and lower 324 chambers over time, themetering passageway 326 restricts the rate at which pressure equalization occurs, allowing sudden changes to the pressure in theupper chamber 320 to control movement of theoperator mandrel 325 and thus, control operation of theball valve 340, as described below. - To manipulate the pressure that is applied to the
upper chamber 320 for purposes of operating theball valve 340 and sleeve 342 (as described further below), thelubricator 300 includes arelief valve 314 that is located between thepassageway 308 and thechamber 320. Therelief valve 314 opens to permit communicate of fluid between thepassageway 308 and thechamber 320 when the pressure in thepassageway 308 exceeds a predetermined threshold, such as 1500 pounds per square inch (psi), for example. In some embodiments of the invention, the threshold for therelief valve 314 is set slightly higher than the fluid hydrostatic pressure in the annulus. This assures that theball valve 340 remains in its current position in case of control line failure at any depth. Thelubricator valve 300 also includes acheck valve 316 that is located between thepassageway 308 and thechamber 320 and is in a parallel arrangement with therelief valve 314. Thecheck valve 316 provides a path to communicate fluid away from theupper chamber 320 to bleed off pressure from theupper chamber 320 to control movement of theoperator mandrel 325, as described below. - The following describes a technique to close the
ball valve 340 when theball valve 340 is currently open. First, a determination is made whether the control line is pressurized. If so, then pressure in the control line is bled off through a fast bleed port in a manifold at the surface of the well so that theupper chamber 320 has near zero pressure. At this point, due to the restriction that is introduced by themetering passageway 326, thelower chamber 324 retains approximately the same pressure that existed before de-pressurization of the control line. Thus, by rapidly de-pressurizing the control line, a differential pressure is created across thepiston 322 to cause theoperator mandrel 325 to move in an upward direction and close theball valve 340. - If the
ball valve 340 is open and the control line is not pressurized, then the control line must first be pressurized to a pressure that is to slightly higher than the threshold of therelief valve 314. The increased pressure is maintained, or held, for a holding period, such as 5 to 10 minutes, for example. The holding period allows sufficient time from the pressures in the twochambers piston 322 to cause theoperator mandrel 325 to move in an upward direction and close theball valve 340, as described above. - The following technique may be used to open the
ball valve 340 when theball valve 340 is currently closed. First, the pressure in the tubing above theball valve 340 is adjusted to ensure that the pressure differential across theball valve 340 is less than 1000 psi. If possible, the pressure across theball valve 340 is equalized. Next, the pressure in the control line is rapidly increased to a pressure that is slightly higher than the relief valve threshold pressure. For example, this increase may occur within an interval of one to two minutes, in some embodiments of the invention. In response to this increase, a pressure differential is created across thepiston 322 causing theoperator mandrel 325 to move and open theball valve 340. The pressure in the control line is then slowly bled off through a slow bleed port in the surface manifold, for example. Because theupper chamber 320 is slowly depressurized, themetering passageway 326 keeps the pressure differential between the upper 320 and lower 324 chambers near zero. This by itself keeps theball valve 340 open. However, in some embodiments of the invention, at this point, thesleeve 342 is positioned inside thecentral passageway 341 of theball valve 340 to lock theball valve 340 in place to keep the ball valve from closing, as described further below. - An advantage of using the above-described arrangement is that an operator may select the position to which the
ball valve 340 defaults if the pressure integrity of the control line is lost at the surface or near thelubricator 300. For example, if the operator wishes to keep theball valve 340 closed even if the control line loose pressure integrity, then the operator maintains the control line pressure to keep the control line pressure within the difference (500 psi, for example) of the relief valve threshold and the pressure in the annulus. This keeps theball valve 340 closed regardless where the control line fails. If the operator wishes to keep theball valve 340 open regardless if the control line looses pressure integrity at the surface or at thelubricator valve 300, then the operator should bleed off the control line pressure so that no matter where the control line breaks, theball valve 340 remains open. - In some embodiments of the invention, the
sleeve 342 is part of anoperator mandrel 330 that, in addition to the generally cylindrical section that forms thesleeve 342, includes apiston 331 that extends in a radially outward direction into a cavity that is formed between theoperator mandrel 330 and anouter housing section 306 of thelubricator 300. Thepiston 331 divides this cavity into achamber 328 that is in communication with thepassageway 318 and in contact with an upper face of thepiston 331; and a sealedchamber 332 that is in contact with a lower face of thepiston 331. In this manner, the sealedchamber 332 is filled with a gas (nitrogen or air at atmospheric pressure, for example) that exerts an upward force against the lower surface of thepiston 331. Alternatively, thechamber 332 may include a spring to exert a force against the lower surface of thepiston 331. The upper face of thepiston 331 receives a force that is applied by the gas that is present in thechamber 328. Due to this arrangement, pressure may be applied to the gas in the control line to move thesleeve 342 to its down position out of theball valve 340, and pressure may be bled out of the control line to move thesleeve 342 to its up position inside theball valve 340. - More particularly, in some embodiments of the invention, the
lubricator 300 includes a gas metering device 310 (a gas metering passageway, for example) that is located between thepassageway 308 and aninternal passageway 307 that extends to thechamber 328. As described below, thegas metering device 310 establishes a delay to permit theball valve 340 to open before thesleeve 342 is inserted into thecentral passageway 341 of theball valve 340 and a delay in the removal of thesleeve 342 from thepassageway 341 to prevent theball valve 340 from prematurely closing, as described below. - FIG. 23 depicts a flow diagram that illustrates a
control technique 380 to close theball valve 340 and operate thesleeve 342 accordingly. For this example, it is assumed that the threshold pressure of the relief valve is approximately 1500 psi, and the sealedchamber 328 is precharged with 500 psi of gas, such as nitrogen gas, for example. In thetechnique 380, the control line is pressurized (block 381) with a pressure (2000 psi, for example) that is greater than the threshold pressure (1500 psi, for example) of therelief valve 314. This pressure is then held (block 384) for a few minutes to move thesleeve 342 to its down position and set the pressure differential between the upper 320 and lower 324 chambers to near zero. In this manner, during this period, the gas meters through the cover sleevegas metering device 310 and fills thechamber 328 to pull thesleeve 342 out of theball valve 340. Also, during this period, the gas fills theupper chamber 320 and then fills thelower chamber 324 through thegas metering passageway 326. During this equalization, theoperator mandrel 325 does not move down because themandrel 325 is already in the down position. Thus, at this point, theball valve 340 remains open. - Next, the control line is rapidly depressurized (block390) by, for example, using a fast bleed port in the surface manifold. Due to this action, the
operator mandrel 325 moves to close theball valve 340, and the pressure in thechamber 328 slowly bleeds off due to thegas metering device 310. When pressure in the control line is bled off below the 500 psi level (i.e., the pressure exerted by the gas in the sealedchamber 332 for this example), the gas pressure in thechamber 332 forces theoperator mandrel 300 in an upward direction to push thesleeve 342 against theball valve 340. Theball valve 340 acts as a stop to limit upward travel of thesleeve 342. The pressure in the control line, the upper 320 and lower 324 chambers, and thechamber 328 then bleeds down to atmospheric pressure after some time. - FIG. 24 depicts a flow diagram that illustrates a
control technique 400 to open theball valve 340 and operate thesleeve 342 accordingly. In this technique, first a determination is made (diamond 402) whether the control line is pressurized. If not, pressure less than the relief valve pressure threshold is applied (block 406), such as 1000 psi (for example) and held (block 408). This action moves thesleeve 342 to its down position, as the gas meters through thegas metering device 310 to push thesleeve 342 off of theball valve 340. - The
ball valve 340 remains closed at this point. Next, regardless of whether the control line was initially pressurized or not, the pressure in the control line is rapidly increased (block 404), such as increased to 2000 psi (a pressure above the relief valve pressure of 1500 psi, as an example), to induce a pressure imbalance between the upper 320 and lower 324 chambers to move theoperator mandrel 325 to open theball valve 340. After some time, theupper chamber 320, thelower chamber 324 and thechamber 328 all have the same pressure, such as a pressure near 2000 psi, for example. Next, the control line is depressurized (block 405) through the slow bleed port in the surface manifold, for example. This action keeps theball valve 340 in the open position and permits the pressure inside the sealedchamber 332 to push thesleeve 342 into thecentral passageway 341 of theball valve 340. In this manner, thesleeve 342 rests on ashoulder 327 that is formed on theoperator mandrel 325 to limit the upward travel of thesleeve 342 when theball valve 340 is open. The above-described opening and closing of theball valve 340 may be repeated as many times as required. - Referring back to FIG. 22, among the other features of the
lubricator 300, thelubricator 300 may be formed from upper 302, middle 304 and lower 306 generally cylindrical housing sections. Thepassageway 308 is formed in theupper housing section 302, and theupper housing section 302 also encloses thepressure relief valve 314, thegas metering device 310 and the oneway check valve 316. Thepassageway 307 extends from thegas metering device 310 through the upper 302, middle 304 and lower 306 housing sections to thechamber 328. - Techniques other than pressure may be used to move the
sleeve operator mandrel 330. For example, FIG. 25 depicts aportion 540 of a lubricator of similar design to the lubricators that are described above with the following exception. In this manner, the lubricator includes asolenoid 542 that has ashaft 544 that is connected to theoperator mandrel 330. Due to this arrangement, thesolenoid 542 may be controlled (via electrical lines 546) to move thesleeve 342 up and down as desired. As an example, theelectrical lines 546 may be connected to electronics of the lubricator, and the electronics, may, for example control operation of thesleeve 342 in response to pressure pulses that are communicated downhole. Alternatively, theelectrical lines 546 may extend from the surface of the well to directly control operation of theoperator mandrel 330. Other arrangements are possible. - Other embodiments are within the scope of the following claims. For example, the lubricator may be constructed to be remotely controlled by arrangements other than those described above. In this manner, the lubricator may be constructed to respond to tubing conveyed pressure, electrical signals (via electrical wires) and coded pressure pulses, as just a few examples of other stimuli that may be communicated downhole. As examples of other embodiments, the lubricator may use valves other than ball valves. For example, the lubricator may include one or more flapper valves. As yet another example, the lubricator and any associated control line may be run downhole with the well casing. Therefore, the lubricator and control line may be cemented in place with the well casing. Thus, by using this technique, the inner diameter of the lubricator may be increased.
- While the invention has been disclosed with respect to a limited number of embodiments, those skilled in the art, having the benefit of this disclosure, will appreciate numerous modifications and variations therefrom.
Claims (50)
1. A system usable with a subterranean well, comprising:
a tubing adapted to receive a drill string in a passageway of the tubing; and
a lubricator located downhole away from a surface of the well and connected to the tubing, the lubricator adapted to receive the drill string and be remotely operable from a surface of the well to control fluid communication between the passageway located above the lubricator and a formation located beneath the lubricator.
2. The system of , wherein the lubricator is located at least one thousand feet from the surface of the well.
claim 1
3. The system of , wherein the lubricator is adapted to permit an operator to select whether the lubricator defaults to an open or a closed position.
claim 1
4. The system of , wherein the lubricator comprises at least two ball valves coupled to operate in synchronization.
claim 1
5. The system of , wherein the lubricator is further adapted to respond to pressure changes in an annulus that surrounds the lubricator.
claim 1
6. The system of , wherein the lubricator is further adapted to respond to a predetermined sequence of pressure changes before isolating the passageway above the lubricator from the formation.
claim 5
7. The system of , wherein the lubricator is adapted to respond to a pressure controllable from the surface to control the fluid communication between the passageway located above the lubricator and the formation located beneath the lubricator.
claim 1
8. The system of , wherein the lubricator is adapted to close the communication in response to a decrease in the pressure.
claim 7
9. The system of , wherein the lubricator is adapted to open the communication in response to a decrease in the pressure.
claim 7
10. The system of , wherein the lubricator comprises:
claim 1
a valve positioned to control the communication; and
an operator mandrel connected to open and close the valve in response to a stimuli communicated from the surface of the well.
11. The system of , wherein the stimuli comprises a pressure change in a second fluid.
claim 10
12. The system of , wherein the operator is adapted to move to close the valve in response to the pressure in the second fluid decreasing.
claim 11
13. The system of , wherein the operator is adapted to move to open the valve in response to the pressure in the second fluid decreasing.
claim 11
14. The system of , wherein the lubricator further comprises:
claim 10
a hold close mechanism to prevent unintentional opening of the valve.
15. The system of , wherein the lubricator comprises:
claim 1
a valve adapted to open and close the communication.
16. The system of , wherein the valve comprises a ball valve.
claim 15
17. The system of , wherein the valve includes a central passageway for communicating the fluid, the lubricator further comprising:
claim 15
a sleeve adapted to selectively move inside the central passageway to protect the valve.
18. The system of , wherein the sleeve is adapted to move in the central passageway in response to the opening of the valve.
claim 17
19. The system of , wherein the sleeve is adapted to move out of the central passageway in response to the opening of the valve.
claim 17
20. The system of , wherein the lubricator further comprises:
claim 17
an operator mandrel to move the sleeve in response to a pressure stimuli controllable form the surface of the well.
21. The system of , wherein the lubricator further comprises:
claim 20
a gas metering device adapted to delay the response of the operator mandrel to prevent the sleeve from moving into the central passageway of the valve before the valve opens.
22. The system of , wherein the valve is adapted to respond to the pressure stimuli, the lubricator further comprising:
claim 20
a pressure relief valve adapted to establish a first range of pressures for controlling the valve and a second range of pressures for controlling the sleeve.
23. An apparatus usable with a well, comprising:
a sleeve;
a ball valve having central passageway; and
a controller to selectively move the sleeve into the passageway to protect at least a portion of the ball valve.
24. The apparatus of , wherein the sleeve protects the ball valve from abrasion introduced by a drilling fluid.
claim 23
25. The apparatus of , wherein the sleeve is adapted to move in the central passageway in response to the opening of the valve.
claim 23
26. The apparatus of , wherein the sleeve is adapted to move out of the central passageway in response to the opening of the valve.
claim 23
27. The apparatus of , further comprising:
claim 23
an operator mandrel to move the sleeve in response to a stimuli controllable form the surface of the well.
28. The apparatus of , wherein the stimuli comprises a pressure stimuli.
claim 27
29. The apparatus of , wherein the lubricator further comprises:
claim 28
a gas metering device adapted to delay the response of the operator mandrel to prevent the sleeve from moving into the central passageway of the valve before the valve opens.
30. The apparatus of , wherein the valve is adapted to respond to the pressure stimuli, the lubricator further comprising:
claim 28
a pressure relief valve adapted to establish a first range of pressures for controlling the valve and a second range of pressures for controlling the sleeve.
31. A method usable with a subterranean well, comprising:
providing a tubing to receive a drill string in a passageway of the tubing; and
remotely operating a downhole valve that is located away from a surface of the well to control fluid communication between the passageway located above the lubricator and a formation located beneath the lubricator.
32. The method of , wherein the valve is located a distance greater than one thousand feet downhole from the surface.
claim 31
33. The method of , wherein the operating comprises:
claim 31
communicating pressure changes to an annulus that surrounds the lubricator.
34. The method of , wherein the operating comprises:
claim 31
closing the communication in response to a decrease in the pressure.
35. The method of , wherein the operating comprises:
claim 31
opening the communication in response to a decrease in the pressure.
36. The method of , wherein the operating further comprises:
claim 35
preventing the opening of the communication before a hold close mechanism is released.
37. The method of , further comprising:
claim 31
selectively moving a sleeve inside a central passageway of the lubricator to protect the lubricator from abrasion introduced by a fluid that flows through the central passageway.
38. The method of , wherein the fluid is associated with drilling a downhole formation.
claim 37
39. The method of , wherein the moving comprises:
claim 37
moving the sleeve into the central passageway in response to the opening of the valve.
40. The method of , wherein the moving comprises:
claim 37
moving the sleeve into the central passageway in response to the opening of the valve.
41. The method of , wherein the moving comprises:
claim 37
moving the sleeve out from the central passageway in response to the opening of the valve.
42. The method of , wherein the operating comprises moving the sleeve into the central passageway in response to the opening of the valve, the method further comprising:
claim 37
delaying the movement of the sleeve into the central passageway to prevent the sleeve from moving into the central passageway of the valve before the valve opens.
43. A method usable with a subterranean well, comprising:
providing a sleeve adapted to line a passageway of a ball valve; and
selectively moving the sleeve into the passageway of the ball to protect at least a portion of the ball valve.
44. The method of , wherein the sleeve protects said at least a portion of the ball valve from abrasion caused by a drilling fluid.
claim 43
45. The method of , wherein the portion of the tool comprises a valve and the passageway comprises a central passageway of the valve.
claim 43
46. The method of , wherein the valve comprises a ball valve.
claim 43
47. The method of , wherein the moving comprises:
claim 45
moving the sleeve into the central passageway in response to the opening of the valve.
48. The method of , wherein the moving comprises:
claim 45
moving the sleeve into the central passageway in response to the opening of the valve.
49. The method of , wherein the moving comprises:
claim 45
moving the sleeve out from the central passageway in response to the opening of the valve.
50. The method of , wherein the operating comprises moving the sleeve into the central passageway in response to the opening of the valve, the method further comprising:
claim 45
delaying the movement of the sleeve into the central passageway to prevent the sleeve from moving into the central passageway of the valve before the valve opens.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US09/789,227 US6401826B2 (en) | 1999-07-12 | 2001-02-20 | Lubricator for underbalanced drilling |
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US14332299P | 1999-07-12 | 1999-07-12 | |
US09/531,945 US6250383B1 (en) | 1999-07-12 | 2000-03-21 | Lubricator for underbalanced drilling |
US09/789,227 US6401826B2 (en) | 1999-07-12 | 2001-02-20 | Lubricator for underbalanced drilling |
Related Parent Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US09/531,945 Division US6250383B1 (en) | 1999-07-12 | 2000-03-21 | Lubricator for underbalanced drilling |
Publications (2)
Publication Number | Publication Date |
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US20010023765A1 true US20010023765A1 (en) | 2001-09-27 |
US6401826B2 US6401826B2 (en) | 2002-06-11 |
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US09/789,227 Expired - Fee Related US6401826B2 (en) | 1999-07-12 | 2001-02-20 | Lubricator for underbalanced drilling |
US09/789,139 Abandoned US20010023764A1 (en) | 1999-07-12 | 2001-02-20 | Lubricator for underbalanced drilling |
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US09/531,945 Expired - Fee Related US6250383B1 (en) | 1999-07-12 | 2000-03-21 | Lubricator for underbalanced drilling |
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US09/789,139 Abandoned US20010023764A1 (en) | 1999-07-12 | 2001-02-20 | Lubricator for underbalanced drilling |
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US (3) | US6250383B1 (en) |
AU (1) | AU6069400A (en) |
GB (1) | GB2370055B (en) |
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WO (1) | WO2001004456A1 (en) |
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- 2000-03-21 US US09/531,945 patent/US6250383B1/en not_active Expired - Fee Related
- 2000-06-30 AU AU60694/00A patent/AU6069400A/en not_active Abandoned
- 2000-06-30 WO PCT/US2000/018375 patent/WO2001004456A1/en active Application Filing
- 2000-06-30 GB GB0200090A patent/GB2370055B/en not_active Expired - Fee Related
-
2001
- 2001-02-20 US US09/789,227 patent/US6401826B2/en not_active Expired - Fee Related
- 2001-02-20 US US09/789,139 patent/US20010023764A1/en not_active Abandoned
-
2002
- 2002-01-11 NO NO20020165A patent/NO325052B1/en not_active IP Right Cessation
Cited By (9)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2003100209A1 (en) * | 2002-05-23 | 2003-12-04 | Weatherford/Lamb, Inc. | Dynamic mudcap drilling and well control system |
US6732804B2 (en) | 2002-05-23 | 2004-05-11 | Weatherford/Lamb, Inc. | Dynamic mudcap drilling and well control system |
GB2404407A (en) * | 2002-05-23 | 2005-02-02 | Weatherford Lamb | Dynamic mudcap drilling and well control system |
GB2404407B (en) * | 2002-05-23 | 2005-08-24 | Weatherford Lamb | Dynamic mudcap drilling and well control system |
US20060272810A1 (en) * | 2005-06-07 | 2006-12-07 | Baker Hughs Incorporated | Downhole pressure containment system |
US7451828B2 (en) | 2005-06-07 | 2008-11-18 | Baker Hughes Incorporated | Downhole pressure containment system |
US20070227743A1 (en) * | 2006-04-04 | 2007-10-04 | Oil States Energy Services, Inc. | Method of subsurface lubrication to facilitate well completion, re-completion and workover |
US7584797B2 (en) * | 2006-04-04 | 2009-09-08 | Stinger Wellhead Protection, Inc. | Method of subsurface lubrication to facilitate well completion, re-completion and workover |
US10329878B2 (en) * | 2014-06-17 | 2019-06-25 | Halliburton Energy Services, Inc. | Maintaining a downhole valve in an open position |
Also Published As
Publication number | Publication date |
---|---|
US6250383B1 (en) | 2001-06-26 |
US6401826B2 (en) | 2002-06-11 |
GB0200090D0 (en) | 2002-02-20 |
NO325052B1 (en) | 2008-01-21 |
NO20020165D0 (en) | 2002-01-11 |
WO2001004456A9 (en) | 2002-09-06 |
NO20020165L (en) | 2002-03-11 |
GB2370055A (en) | 2002-06-19 |
US20010023764A1 (en) | 2001-09-27 |
WO2001004456A1 (en) | 2001-01-18 |
AU6069400A (en) | 2001-01-30 |
GB2370055B (en) | 2004-02-11 |
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