N/A
N/A
1. Field of the Invention
This invention generally relates to subsea drilling system and method, and in particular to a system and method adapted for use with a rotating control device (RCD) to sealably control fluid flow in a riser.
2. Description of Related Art
Marine risers extending from a wellhead fixed on the floor of an ocean have been used to circulate drilling fluid back to a structure or rig. The riser must be large enough in internal diameter to accommodate the largest bit and pipe that will be used in drilling a borehole into the floor of the ocean.
An example of a marine riser and some of the associated drilling components is proposed in U.S. Pat. Nos. 4,626,135 and 7,258,171. As shown in FIG. 1 of the '171 patent, since the riser R is fixedly connected between a floating structure or rig S and the wellhead W, a conventional slip or telescopic joint SJ, comprising an outer barrel OB and an inner barrel IB with a pressure seal therebetween, is used to compensate for the relative vertical movement or heave between the floating rig and the fixed riser. A diverter D has been connected between the top inner barrel IB of the slip joint SJ and the floating structure or rig S to control gas accumulations in the marine riser R or low pressure formation gas from venting to the rig floor F. A ball joint BJ above the diverter D compensates for other relative movement (horizontal and rotational) or pitch and roll of the floating structure S and the fixed riser R.
The diverter D can use a rigid diverter line DL extending radially outwardly from the side of the diverter housing to communicate drilling fluid or mud from the riser R to a choke manifold CM, shale shaker SS or other drilling fluid receiving device. Above the diverter D is the rigid flow line RF, configured to communicate with the mud pit MP. If the drilling fluid is open to atmospheric pressure at the bell-nipple in the rig floor F, the desired drilling fluid receiving device must be limited by an equal height or level on the structure S or, if desired, pumped by a pump to a higher level. While the shale shaker SS and mud pits MP are shown schematically in FIG. 1 of the '171 patent, if a bell-nipple were at the rig floor F level and the mud return system was under minimal operating pressure, these fluid receiving devices may have to be located at a level below the rig floor F for proper operation. Since the choke manifold CM and separator MB are used when the well is circulated under pressure, they do not need to be below the bell nipple.
As also shown in FIG. 1 of the '171 patent, a conventional flexible choke line CL has been configured to communicate with choke manifold CM. The drilling fluid then can flow from the choke manifold CM to a mud-gas buster or separator MB and a flare line (not shown). The drilling fluid can then be discharged to a shale shaker SS, and mud pits MP. In addition to a choke line CL and kill line KL, a booster line BL can be used.
In the past, when drilling in deepwater with a marine riser, the riser has not been pressurized by mechanical devices during normal operations. The only pressure induced by the rig operator and contained by the riser is that generated by the density of the drilling mud held in the riser (hydrostatic pressure). During some operations, gas can unintentionally enter the riser from the wellbore. If this happens, the gas will move up the riser and expand. As the gas expands, it will displace mud, and the riser will “unload.” This unloading process can be quite violent and can pose a significant fire risk when gas reaches the surface of the floating structure via the bell-nipple at the rig floor F. As discussed above, the riser diverter D, as shown in FIG. 1 of the '171 patent, is intended to convey this mud and gas away from the rig floor F when activated. However, diverters are not used during normal drilling operations and are generally only activated when indications of gas in the riser are observed. The '135 patent proposed a gas handler annular blowout preventer GH, such as shown in FIG. 1 of the '171 patent, to be installed in the riser R below the riser slip joint SJ. Like the conventional diverter D, the gas handler annular blowout preventer GH is activated only when needed, but instead of simply providing a safe flow path for mud and gas away from the rig floor F, the gas handler annular blowout provider GH can be used to hold limited pressure on the riser R and control the riser unloading process. An auxiliary choke line ACL is used to circulate mud from the riser R via the gas handler annular blowout preventer GH to a choke manifold CM on the rig.
More recently, the advantages of using underbalanced drilling, particularly in mature geological deepwater environments, have become known. Deepwater is generally considered to be between 3,000 to 7,500 feet deep and ultra deepwater is generally considered to be 7,500 to 10,000 feet deep. Rotating control heads or devices (RCD's), such as disclosed in U.S. Pat. No. 5,662,181, have provided a dependable seal between a rotating pipe and the riser while drilling operations are being conducted. U.S. Pat. No. 6,138,774, entitled “Method and Apparatus for Drilling a Borehole into a Subsea Abnormal Pore Pressure Environment,” proposes the use of a RCD for overbalanced drilling of a borehole through subsea geological formations. That is, the fluid pressure inside of the borehole is maintained equal to or greater than the pore pressure in the surrounding geological formations using a fluid that is of insufficient density to generate a borehole pressure greater than the surrounding geological formation's pore pressures without pressurization of the borehole fluid. U.S. Pat. No. 6,263,982 proposes an underbalanced drilling concept of using a RCD to seal a marine riser while drilling in the floor of an ocean using a rotatable pipe from a floating structure. Additionally, U.S. Provisional Application No. 60/122,350, filed Mar. 2, 1999, entitled “Concepts for the Application of Rotating Control Head Technology to Deepwater Drilling Operations” proposes use of a RCD in deepwater drilling.
It has also been known in the past to use a dual density mud system to control formations exposed in the open borehole. See Feasibility Study of a Dual Density Mud System for Deepwater Drilling Operations by Clovis A. Lopes and Adam T. Bourgoyne, Jr., © 1997 Offshore Technology Conference. As a high density mud is circulated from the ocean floor back to the rig, gas is proposed in this May of 1997 paper to be injected into the mud column at or near the ocean floor to lower the mud density. However, hydrostatic control of abnormal formation pressure is proposed to be maintained by a weighted mud system that is not gas-cut below the ocean floor. Such a dual density mud system is proposed to reduce drilling costs by reducing the number of casing strings required to drill the well and by reducing the diameter requirements of the marine riser and subsea blowout preventers. This dual density mud system is similar to a mud nitrification system, where nitrogen is used to lower mud density, in that formation fluid is not necessarily produced during the drilling process.
As proposed in U.S. Pat. No. 4,813,495, a subsea RCD has been proposed as an alternative to the conventional drilling system and method when used in conjunction with a subsea pump that returns the drilling fluid to a drilling vessel. Since the drilling fluid is returned to the drilling vessel, a fluid with additives may economically be used for continuous drilling operations. ('495 patent, col. 6, ln. 15 to col. 7, ln. 24) Therefore, the '495 patent moves the base line for measuring pressure gradient from the sea surface to the mudline of the sea floor ('495 patent, col. 1, lns. 31-34). This change in positioning of the base line removes the weight of the drilling fluid or hydrostatic pressure contained in a conventional riser from the formation. This objective is achieved by taking the fluid or mud returns at the mudline and pumping them to the surface rather than requiring the mud returns to be forced upward through the riser by the downward pressure of the mud column ('495 patent, col. 1, lns. 35-40).
Conventional RCD assemblies have been sealed with a subsea housing active sealing mechanisms in the subsea housing. Additionally, conventional RCD assemblies, such as proposed by U.S. Pat. No. 6,230,824, have used powered latching mechanisms in the subsea housing to position the RCD.
Additionally, the use of a RCD assembly in a dual-density drilling operation can incur problems caused by excess pressure in either one of the two fluids. The ability to relieve excess pressure in either fluid would provide safety and environmental improvements. For example, if a return line to a subsea mud pump plugs while mud is being pumped into the borehole, an overpressure situation could cause a blowout of the borehole. Because dual-density drilling can involve varying pressure differentials, an adjustable overpressure relief technique has been desired.
Another problem with conventional drilling techniques is that moving of a RCD within the marine riser by tripping in hole (TIH) or pulling out of hole (POOH) can cause undesirable surging or swabbing effects, respectively, within the well. Further, in the case of problems within the well, a desirable mechanism should provide a “fail safe” feature to allow removal of the RCD upon application of a predetermined force.
U.S. Pat. Nos. 6,470,975; 7,159,669; and 7,258,171 propose positioning an RCD assembly in a housing positioned in a marine riser. In the '171 patent, a system and method are disclosed for drilling in the floor of an ocean using a rotatable pipe. The system uses a RCD with a bearing assembly and a holding member for removably positioning the bearing assembly in a subsea housing. The bearing assembly is sealed with the subsea housing by a seal, providing a barrier between two different fluid densities. The holding member resists movement of the bearing assembly relative to the subsea housing. The bearing assembly is proposed to be connected with the subsea housing above or below the seal.
In one embodiment of the '171 patent, the holding member rotationally engages and disengages a passive internal formation of the subsea housing. In another embodiment of the '171 patent, the holding member engages the internal formation, disposed between two spaced apart side openings in the subsea housing, without regard to the rotational position of the holding member. The holding member of the '171 patent is configured to release at predetermined force.
The holding member assembly of the '171 patent provides an internal housing concentric with an extendible portion. When the extendible portion extends, an upper portion of the internal housing is proposed to move toward a lower portion of the internal housing to extrude an elastomer disposed between the upper and lower portions to seal the holding member assembly with the subsea housing. The extendible portion is proposed to be dogged to the upper portion or the lower portion of the internal housing depending on the position of the extendible portion.
As further proposed in the '171 patent, a running tool is used for moving the rotating control head assembly with the subsea housing and is also used to remotely engage the holding member with the subsea housing.
Latching assemblies have been proposed in the past for positioning an RCD. U.S. Pat. No. 7,487,837 proposes a latch assembly for use with a riser for positioning an RCD. Pub. No. US 2006/0144622 A1 proposes a latching system to latch an RCD to a housing and active seals. Pub. No. US 2008/0210471 A1 proposes a docking station housing positioned above the surface of the water for latching with an RCD.
The above discussed U.S. Pat. Nos. 4,626,135; 4,813,495; 5,662,181; 6,138,774; 6,230,824; 6,263,982; 6,470,975; 7,159,669; 7,258,171; and 7,487,837; and Pub. Nos. US 2006/0144622 A1 and 2008/0210471 A1; and U.S. Provisional Application No. 60/122,350, filed Mar. 2, 1999, entitled “Concepts for the Application of Rotating Control Head Technology to Deepwater Drilling Operations” are all hereby incorporated by reference for all purposes in their entirety. The '181, '774, '982 and '171 patents, and the '622 and '471 publications are assigned to the assignee of the present invention.
In cases where reasonable amounts of gas and small amounts of oil and water are produced while drilling underbalanced for a small portion of the well, it would be desirable to use conventional rig equipment in combination with a RCD, to control the pressure applied to the well while drilling. Therefore, a system and method for sealing with a subsea housing including, but not limited to, a blowout preventer while drilling in deepwater or ultra deepwater that would allow a quick rig-up and release using conventional pressure containment equipment would be desirable. In particular, a system that provides sealing of the riser at any predetermined location, or, alternatively, is capable of sealing the blowout preventer while rotating the pipe, where the seal could be relatively quickly installed, and quickly removed, would be desirable.
A system and method are disclosed for positioning a RCD with a riser spool or housing disposed with a marine riser. Latching members may be disposed in the housing for positioning the RCD with the housing. An internal bypass channel or line in the housing or an external bypass line disposed with the housing may be used with a valve, such as a gate valve, to allow fluid to bypass the RCD seals and the seal between the RCD and the housing. The riser housing latching members and/or packer seal may be operated remotely, such as through the use of a remotely operated vehicle (ROV), hydraulic lines, and/or an accumulator. The housing active packer seal may be hydraulically expanded or inflated for sealing the annular space between the housing and the RCD.
In other embodiments, the RCD may have an RCD holding member with a mechanically extrudable seal for sealing the RCD with the riser housing. The RCD may be positioned in the riser housing with an RCD running tool. In some embodiments, the holding member seal is mechanically extruded or set with a downward movement of the running tool after the RCD holding member is latched in the riser housing. In other embodiments, the holding member mechanically extrudable seal is set with an upward movement of the running tool after the RCD holding member is latched with the riser housing a loss motion connection.
A better understanding of the present invention can be obtained with the following detailed descriptions of the various disclosed embodiments in the drawings, which are given by way of illustration only, and thus are not limiting the invention, and wherein:
Generally, a sealing system and method for a rotatable tubular using an RCD positioned in a marine riser is disclosed. An RCD may have an inner member rotatable relative to an outer member about thrust and axial bearings, such as RCD Model 7875, available from Weatherford International of Houston, Tex., and other RCDs proposed in the '181, '171 and '774 patents. Although certain RCD types and sizes are shown in the embodiments, other RCD types and sizes are contemplated for all embodiments, including RCDs with different numbers, configurations and orientations of passive seals, and/or RCDs with one or more active seals.
In
The RCD 2 outside diameter is smaller than the housing 12 inside diameter or straight thru bore. First retainer member 16 and second retainer member 20 have been moved from their respective first or unlatched positions to their respective second or latched positions as they are shown in
While it is contemplated that housing 12 may have a 10,000 psi body pressure rating, other pressure ratings are contemplated. Also, while it is contemplated that the opposed housing flanges (30, 32) may have a 39 inch (99.1 cm) outside diameter, other sizes are contemplated. RCD 2 may be latchingly attached with a 21.250 inch (54 cm) thru bore 34 of marine riser sections (4, 10) with a 19.25 (48.9 cm) inch inside bore 12A of housing 12. Other sizes are contemplated. It is also contemplated that housing 12 may be positioned above or be integral with a marine diverter, such as a 59 inch (149.9 cm) inside diameter marine diverter. Other sizes are contemplated. The diverter will allow fluid moving down the drill pipe and up the annulus to flow out the diverter opening below the lower stripper seal 8 and the same active seal 22. Although active seal 22 is shown below the bearing assembly of the RCD 2 and below latching members (14, 18), it is contemplated that active seal 22 may be positioned above the RCD bearing assembly and latching members (14, 18). It is also contemplated that there may be active seals both above and below the RCD bearing assembly and latching members (14, 18). All types of seals, active or passive, as are known in the art are contemplated. While the active seal 22 is illustrated positioned with the housing 12, it is contemplated that the seal, active or passive, could instead be positioned with the outer surface of the RCD 2.
In the preferred method, to establish a landing for RCD 2, which may be an 18.00 inch (45.7 cm) outer diameter RCD, the first retainer member 16 is remotely activated to the latched or loading position. The RCD 2 is then moved into the housing 12 until the RCD 2 lands with the RCD blocking shoulder 11 contacting the retainer member 16. The second retainer member 20 is then remotely activated with hydraulic fluid supplied as discussed above to the latched position to engage the RCD receiving formation 9, thereby creating a clamping force on the RCD 2 outer surface to, among other benefits, resist torque or rotation. In particular, the top chamfer on first retainer member 16 is engaged with the RCD shoulder 11. When the bottom chamfer on the second retainer member 20 moves into receiving formation 9 on the RCD 2 outer surface, the bottom chamfer “squeezes” the RCD between the two retainer members (16, 20) to apply a squeezing force on the RCD 2 to resist torque or rotation. The active seal 22 may then be expanded with hydraulic fluid supplied as discussed above to seal against the RCD 2 lower outer surface to seal the gap or annulus between the RCD 2 and the housing 12. The operations of the housing 12 may be controlled remotely through the ROV fluid supplied to the control panel 28, with hydraulic line 5 and/or accumulator 7. Other methods are contemplated, including activating the second retainer member 20 simultaneously with the active seal 22. Although a bypass channel or line, such as internal bypass channel 68 shown in
Turning to
The RCD 40 outside diameter is smaller than the housing 72 inside diameter, which may be 19.25 inches (48.9 cm). Other sizes are contemplated. While the riser housing 72 may have a 10,000 psi body pressure rating, other pressure ratings are contemplated. Retainer members (56, 60) may be a plurality of dogs or a C-shaped member, although other types of members are contemplated. Active seal 66, shown in an unexpanded or unsealed position, may be expanded to sealingly engage RCD 40. Alternatively, or in addition, an active seal may be positioned above the RCD bearing assembly and latching members (54, 58). Housing 74 is illustrated bolted with bolts (50, 52) to marine riser sections (42, 44). As discussed above, other attachment means are contemplated. While it is contemplated that the opposed housing flanges (74, 76) may have a 45 inch (114.3 cm) outside diameter, other sizes are contemplated. As can now be understood, the RCD 40 may be latchingly attached with the thru bore of housing 72. It is also contemplated that housing 74 may be positioned with a 59 inch (149.9 cm) inside diameter marine diverter.
The system shown in
In
ROV control panel 114 may be positioned with housing 98 between upper and lower shielding protrusions 112 (only lower protrusion shown) to protect the panel 114. Other shielding means are contemplated. While it is contemplated that the opposed housing flanges 120 (only lower flange shown) of housing 98 may have a 45 inch (114.3 cm) outside diameter, other sizes are contemplated. The RCD 90 outside diameter is smaller than the housing 98 inside diameter. Retainer members (106, 110) may be a plurality of dogs or a C-shaped member. Active seal 102, shown in an expanded or sealed position, sealingly engages RCD 102. After the RCD 90 is sealed as shown in
Generally, lines and cables extend radially outwardly from the riser, as shown in FIG. 1 of the '171 patent, and male and female members of the lines and cables plug together as the riser sections are joined together. Turning to
An external bypass line 186 with gate valve 188 is shown and discussed below with
In
The RCD holding member 178 for RCD 150 and the RCD running tool 184 are similar to the holding member and running tool shown in
External bypass line 186 with valve 188 may be attached with housing 152 with bolts (192, 196). Other attachment means are contemplated. A similar bypass line and valve may be positioned with any embodiment. Unlike bypass channel 68 in
Also, when the riser is raised with the RCD in place, valve 188 could be opened to allow fluid to bypass the RCD 150 and out the riser below the housing 152B and RCD 150. In such conditions when holding member extrudable seal 198 is in a sealing position (as described below in detail with
Turning to
ROV control panel 228 may be positioned with housing 200 between two shielding protrusions 230 to protect the panel 228. The RCD 200 outside diameter is smaller than the housing 202 inside diameter. Retainer members (222, 226) may be a plurality of dogs or a C-shaped member. External bypass line 232 with valve 238 may be attached with housing 202 with bolts (234, 236). Other attachment means are contemplated. Bypass line 232 with gate valve 238 acts as a check valve in well kick or blowout conditions. Valve 238 may be operated remotely.
Turning to
Holding member seal 276 may be bonded with tool member blocking shoulder 290 and retainer receiving member 288, such as by epoxy. A lip retainer formation in either or both the tool member 274 and retainer receiving member 288 that fits with a corresponding formation(s) in seal 276 is contemplated. This retainer formation, similar to formation 320 shown and/or described with
Holding member 286 is positioned with RCD running tool 270 with lower shear pins 280 and running tool shoulder 271. After the running tool is made up in the drill string, the running tool 270 and RCD 250 are moved together from the surface down through the marine riser to housing 252 in the landing position shown in
When tool member 274 moves upward, tool member blocking shoulder 290 moves upward, pulling holding member seal 290 relative to fixed retainer receiving member 288 retained by the third retainer member 264 in the latched position. The seal 290 is preferably stretched to substantially its initial shape, as shown in
Turning to
Although two upper 316, two lower 334 and two intermediate 332 shear pins are shown, it is contemplated that there may be only one upper 316, one lower 334 and one intermediate 332 shear pin or, as discussed above, that there may be a plurality of upper 316, lower 334 and intermediate 332 shear pins. Other mechanical shearing devices as are known in the art are also contemplated. Holding member seal 318 may be bonded with RCD tool member 314 and retainer receiving member 326, such as by epoxy. A lip retainer formation 320 in RCD tool member 314 fits with a corresponding formation in seal 318 to allow seal 318 to be pulled by RCD tool member 314. Although not shown, a similar lip formation may be used to connect the seal 318 with retainer receiving member 326. A combination of bonding and mechanical attachment as described above may be used.
Holding member 340 is positioned with RCD running tool 336 with lower shear pins 334, running tool shoulder 356, and concentric C-rings (352, 354). The running tool 336 and RCD 300 are moved together from the surface through the marine riser down into housing 302 in the landing position shown in
Shoulder 360 of RCD tool member 314 compresses and extrudes seal 318 against retainer receiving member 326, which is fixed by third retainer member 324. After the seal 318 is set as shown in
When RCD tool member 314 moves upward, RCD tool member blocking shoulder 360 moves upward, pulling holding member seal 318 with lip retainer formation 320 and/or the bonded connection since retainer receiving member 326 is fixed by the third retainer member 324 in the latched position. The retainer members (304, 308, 324) may then be moved to their first or unlatched positions, and the RCD 300 and running tool 336 together pulled upwards from the housing 302.
Turning to
Although two upper 422 and two lower 408 shear pins are shown for this embodiment, it is contemplated that there may be only one upper 422 and one lower 408 shear pin or, as discussed above, that there may be a plurality of upper 422 and lower 408 shear pins for this embodiment of the invention. Other mechanical shearing devices as are known in the art are also contemplated. Holding member seal 404 may be bonded with extending member 402 and retainer receiving member 416, such as by epoxy. A lip retainer formation 406 in RCD extending member 402 fits with a corresponding formation in seal 404 to allow seal 404 to be pulled by extending member 402. Although not shown, a similar lip formation may be used to connect the seal 404 with retainer receiving member 416. A combination of bonding and mechanical attachment as described above may be used. Other attachment methods are contemplated.
Holding member 436 is positioned with RCD running tool 412 with lower shear pins 408 and third C-ring 410, running tool shoulder 414, and concentric inner and outer C-rings (428, 430). The running tool 412 and RCD 380 are moved together from the surface through the marine riser down into housing 382 in the position landing shown on the right side of the break line in
On the left side of the break line in
Retainer receiving member 416 compresses and extrudes seal 404 against RCD extending member 402, which is latched with held by first retainer member 386. After the seal 404 is set as shown in
In
Turning to
Upper ratchet or lock ring 488 is disposed in groove 524 of RCD extending member 470. Although two upper 472, two lower 484 and two intermediate 474 shear pins are shown for this embodiment, it is contemplated that there may be only one upper shear pin 472, one lower shear pin 484 and one intermediate sheer pin 474 shear pin or, as discussed above, that there may be a plurality of upper 472, lower 484 and intermediate 474 shear pins. Other mechanical shearing devices as are known in the art are also contemplated. Holding member seal 480 may be bonded with seal member 476 and retainer receiving member 496, such as by epoxy. A lip retainer formation 506 in seal member 476 fits with a corresponding formation in seal 480 to allow seal 480 to be pulled by seal member 476, as will be described below in detail with
Holding member, generally indicated as 466, is positioned with RCD running tool 468 with lower shear pins 484, running tool shoulder 508, inner C-ring 498, and segments 500 with garter springs 502. The running tool 468 and RCD 444 are moved together from the surface through the marine riser down into housing 446 in the landing position shown in
RCD tool member 490 is pulled downward by intermediate shear pins 474 disposed with tool member 482. The downward movement of tool member 482 shears upper shear pins 472. As can now be understood, the shear strength of upper shear pins 472 is lower than the shear strengths of intermediate shear pins 474 and lower shear pins 484 shear pins. Tool member 482 moves downward until its downwardly facing blocking shoulder 514 contacts retainer receiving member upwardly facing blocking shoulder 516. Holding member retaining dog 478 pulls seal member 476 downward until its downwardly facing shoulder 510 contacts extending member upwardly facing shoulder 512. Dog 478 may be a C-ring with radially inward bias. Other devices are contemplated. Holding member retainer 462 is latched, fixing retainer receiving member 496. Holding member seal 480 is extruded or set as shown in
Turning to
Third retainer member 462 maintains retainer receiving member 496 and the one end of seal 480 fixed, since seal 480 is bonded and/or mechanically attached with retainer receiving member 496. Holding member retainer dog 478 moves along slot 522 of RCD tool member 490. Seal 480 is preferably stretched to substantially its initial shape, as shown in
Turning to
Although two upper shear pins 578 and two lower shear pins 558 are shown, it is contemplated that there may be only one upper shear pin 578 and one lower shear pin 558 or, as discussed above, that there may be a plurality of upper shear pins 578 and lower shear pins 558. Other mechanical shearing devices as are known in the art are also contemplated. Holding member seal 570 may be bonded with extending member 550 and retainer receiving member 554, such as by epoxy. A lip retainer formation 574 in RCD extending member 550 fits with a corresponding formation in seal 570 to allow seal 570 to be pulled by extending member 550. Although not shown, a similar lip formation may be used to connect the seal 570 with retainer receiving member 554. A combination of bonding and mechanical attachment as described above may be used. Other attachment methods are contemplated.
Holding member, generally indicated at 548, is positioned with RCD running tool 552 with lower shear pins 558 and lower shear pin segments 556, running tool shoulder 588, inner C-ring 564, and outer segments 566 with garter springs 568. Lower shear pin segments 556 are disposed on running tool surface 594, which has a larger diameter than adjacent running tool slot 596. The running tool 552 and RCD 530 are moved together from the surface through the marine riser down into housing 532 in the landing position shown in
To continue setting or extruding seal 570, the running tool 552 is further moved upwards from its position shown in
Loss motion connection or groove 592 of retainer receiving member 554 allows retainer receiving member 554 to move upward until it is blocked by the third retainer 544 contacting shoulder 590 at one end of slot 592, as shown in
Turning now to
The foregoing disclosure and description of the invention are illustrative and explanatory thereof, and various changes in the details of the illustrated apparatus and system, and the construction and the method of operation may be made without departing from the spirit of the invention.
This application is a divisional of co-pending U.S. Non-Provisional patent application Ser. No. 12/643,093, filed Dec. 21, 2009, which claims the benefit of U.S. Provisional Application No. 61/205,209, filed on Jan. 15, 2009, both of which are hereby incorporated by reference for all purposes in their entirety.
Number | Name | Date | Kind |
---|---|---|---|
517509 | Williams | Apr 1894 | A |
1157644 | London | Oct 1915 | A |
1472952 | Anderson | Nov 1923 | A |
1503476 | Childs et al. | Aug 1924 | A |
1528560 | Myers et al. | Mar 1925 | A |
1546467 | Bennett | Jul 1925 | A |
1560763 | Collins | Nov 1925 | A |
1700894 | Joyce et al. | Feb 1929 | A |
1708316 | MacClatchie | Apr 1929 | A |
1769921 | Hansen | Jul 1930 | A |
1776797 | Sheldon | Sep 1930 | A |
1813402 | Hewitt | Jul 1931 | A |
2038140 | Stone | Jul 1931 | A |
1831956 | Harrington | Nov 1931 | A |
1836470 | Humason et al. | Dec 1931 | A |
1902906 | Seamark | Mar 1933 | A |
1942366 | Seamark | Jan 1934 | A |
2036537 | Otis | Apr 1936 | A |
2071197 | Burns et al. | Feb 1937 | A |
2124015 | Stone et al. | Jul 1938 | A |
2126007 | Gulberson et al. | Aug 1938 | A |
2144682 | MacClatchie | Jan 1939 | A |
2148844 | Stone et al. | Feb 1939 | A |
2163813 | Stone et al. | Jun 1939 | A |
2165410 | Penick et al. | Jul 1939 | A |
2170915 | Schweitzer | Aug 1939 | A |
2170916 | Schweitzer et al. | Aug 1939 | A |
2175648 | Roach | Oct 1939 | A |
2176355 | Otis | Oct 1939 | A |
2185822 | Young | Jan 1940 | A |
2199735 | Beckman | May 1940 | A |
2211122 | Howard | Aug 1940 | A |
2222082 | Leman et al. | Nov 1940 | A |
2233041 | Alley | Feb 1941 | A |
2243340 | Hild | May 1941 | A |
2243439 | Pranger et al. | May 1941 | A |
2287205 | Stone | Jun 1942 | A |
2303090 | Pranger et al. | Nov 1942 | A |
2313169 | Penick et al. | Mar 1943 | A |
2325556 | Taylor, Jr. et al. | Jul 1943 | A |
2338093 | Caldwell | Jan 1944 | A |
2480955 | Penick | Sep 1949 | A |
2506538 | Bennett | May 1950 | A |
2529744 | Schweitzer, Jr. | Nov 1950 | A |
2609836 | Knox | Sep 1952 | A |
2628852 | Voytech | Feb 1953 | A |
2646999 | Barske | Jul 1953 | A |
2649318 | Skillman | Aug 1953 | A |
2731281 | Knox | Jan 1956 | A |
2746781 | Jones | May 1956 | A |
2760750 | Schweitzer, Jr. et al. | Aug 1956 | A |
2760795 | Vertson | Aug 1956 | A |
2764999 | Stanbury | Oct 1956 | A |
2808229 | Bauer et al. | Oct 1957 | A |
2808230 | McNeil et al. | Oct 1957 | A |
2846178 | Minor | Aug 1958 | A |
2846247 | Davis | Aug 1958 | A |
2853274 | Collins | Sep 1958 | A |
2862735 | Knox | Dec 1958 | A |
2886350 | Horne | May 1959 | A |
2904357 | Knox | Sep 1959 | A |
2927774 | Ormsby | Mar 1960 | A |
2929610 | Stratton | Mar 1960 | A |
2962096 | Knox | Nov 1960 | A |
2995196 | Gibson et al. | Aug 1961 | A |
3023012 | Wilde | Feb 1962 | A |
3029083 | Wilde | Apr 1962 | A |
3032125 | Hiser et al. | May 1962 | A |
3033011 | Garrett | May 1962 | A |
3052300 | Hampton | Sep 1962 | A |
3096999 | Ahlstone et al. | Jul 1963 | A |
3100015 | Regan | Aug 1963 | A |
3128614 | Auer | Apr 1964 | A |
3134613 | Regan | May 1964 | A |
3142338 | Brown | Jul 1964 | A |
3176996 | Barnett | Apr 1965 | A |
3203358 | Regan et al. | Aug 1965 | A |
3209829 | Haeber | Oct 1965 | A |
3216731 | Dollison | Nov 1965 | A |
3225831 | Knox | Dec 1965 | A |
3259198 | Montgomery et al. | Jul 1966 | A |
3268233 | Brown | Aug 1966 | A |
3282342 | Mott | Nov 1966 | A |
3285352 | Hunter | Nov 1966 | A |
3288472 | Watkins | Nov 1966 | A |
3289761 | Smith et al. | Dec 1966 | A |
3294112 | Watkins | Dec 1966 | A |
3302048 | Gray | Jan 1967 | A |
3313345 | Fischer | Apr 1967 | A |
3313358 | Postlewaite et al. | Apr 1967 | A |
3323773 | Walker | Jun 1967 | A |
3333870 | Watkins | Aug 1967 | A |
3347567 | Watkins | Oct 1967 | A |
3360048 | Watkins | Dec 1967 | A |
3372761 | van Gils | Mar 1968 | A |
3387851 | Cugini | Jun 1968 | A |
3397928 | Galle | Aug 1968 | A |
3400938 | Williams | Sep 1968 | A |
3401600 | Wood | Sep 1968 | A |
3405763 | Pitts et al. | Oct 1968 | A |
3421580 | Fowler et al. | Jan 1969 | A |
3424197 | Yanagisawa | Jan 1969 | A |
3443643 | Jones | May 1969 | A |
3445126 | Watkins | May 1969 | A |
3452815 | Watkins | Jul 1969 | A |
3472518 | Harlan | Oct 1969 | A |
3476195 | Galle | Nov 1969 | A |
3481610 | Slator et al. | Dec 1969 | A |
3485051 | Watkins | Dec 1969 | A |
3492007 | Jones | Jan 1970 | A |
3493043 | Watkins | Feb 1970 | A |
3503460 | Gadbois | Mar 1970 | A |
3522709 | Vilain | Aug 1970 | A |
3529835 | Lewis | Sep 1970 | A |
3561723 | Cugini | Feb 1971 | A |
3583480 | Regan | Jun 1971 | A |
3587734 | Shaffer | Jun 1971 | A |
3603409 | Watkins | Sep 1971 | A |
3621912 | Wooddy et al. | Nov 1971 | A |
3631834 | Gardner et al. | Jan 1972 | A |
3638721 | Harrison | Feb 1972 | A |
3638742 | Wallace | Feb 1972 | A |
3653350 | Koons et al. | Apr 1972 | A |
3661409 | Brown et al. | May 1972 | A |
3664376 | Watkins | May 1972 | A |
3667721 | Vujasinovic | Jun 1972 | A |
3677353 | Baker | Jul 1972 | A |
3724862 | Biffle | Apr 1973 | A |
3741296 | Murman et al. | Jun 1973 | A |
3779313 | Regan | Dec 1973 | A |
3815673 | Bruce et al. | Jun 1974 | A |
3827511 | Jones | Aug 1974 | A |
3847215 | Herd | Nov 1974 | A |
3868832 | Biffle | Mar 1975 | A |
3872717 | Fox | Mar 1975 | A |
3924678 | Ahlstone | Dec 1975 | A |
3926457 | Williams et al. | Dec 1975 | A |
3934887 | Biffle | Jan 1976 | A |
3952526 | Watkins et al. | Apr 1976 | A |
3955622 | Jones | May 1976 | A |
3965987 | Biffle | Jun 1976 | A |
3976148 | Maus et al. | Aug 1976 | A |
3984990 | Jones | Oct 1976 | A |
3992889 | Watkins et al. | Nov 1976 | A |
3999766 | Barton | Dec 1976 | A |
4037890 | Kurita et al. | Jul 1977 | A |
4046191 | Neath | Sep 1977 | A |
4052703 | Collins, Sr. et al. | Oct 1977 | A |
4053023 | Herd et al. | Oct 1977 | A |
4063602 | Howell et al. | Dec 1977 | A |
4087097 | Bossens et al. | May 1978 | A |
4091881 | Maus | May 1978 | A |
4098341 | Lewis | Jul 1978 | A |
4099583 | Maus | Jul 1978 | A |
4109712 | Regan | Aug 1978 | A |
4143880 | Bunting et al. | Mar 1979 | A |
4143881 | Bunting | Mar 1979 | A |
4149603 | Arnold | Apr 1979 | A |
4154448 | Biffle | May 1979 | A |
4157186 | Murray et al. | Jun 1979 | A |
4183562 | Watkins et al. | Jan 1980 | A |
4200312 | Watkins | Apr 1980 | A |
4208056 | Biffle | Jun 1980 | A |
4216835 | Nelson | Aug 1980 | A |
4222590 | Regan | Sep 1980 | A |
4249600 | Bailey | Feb 1981 | A |
4281724 | Garrett | Aug 1981 | A |
4282939 | Maus et al. | Aug 1981 | A |
4285406 | Garrett et al. | Aug 1981 | A |
4291772 | Beynet | Sep 1981 | A |
4293047 | Young | Oct 1981 | A |
4304310 | Garrett | Dec 1981 | A |
4310058 | Bourgoyne, Jr. | Jan 1982 | A |
4312404 | Morrow | Jan 1982 | A |
4313054 | Martini | Jan 1982 | A |
4326584 | Watkins | Apr 1982 | A |
4335791 | Evans | Jun 1982 | A |
4336840 | Bailey | Jun 1982 | A |
4337653 | Chauffe | Jul 1982 | A |
4345769 | Johnston | Aug 1982 | A |
4349204 | Malone | Sep 1982 | A |
4353420 | Miller | Oct 1982 | A |
4355784 | Cain | Oct 1982 | A |
4361185 | Biffle | Nov 1982 | A |
4363357 | Hunter | Dec 1982 | A |
4367795 | Biffle | Jan 1983 | A |
4378849 | Wilks | Apr 1983 | A |
4383577 | Pruitt | May 1983 | A |
4384724 | Derman | May 1983 | A |
4386667 | Millsapps, Jr. | Jun 1983 | A |
4387771 | Jones | Jun 1983 | A |
4398599 | Murray | Aug 1983 | A |
4406333 | Adams | Sep 1983 | A |
4407375 | Nakamura | Oct 1983 | A |
4413653 | Carter, Jr. | Nov 1983 | A |
4416340 | Bailey | Nov 1983 | A |
4423776 | Wagoner et al. | Jan 1984 | A |
4424861 | Carter, Jr. et al. | Jan 1984 | A |
4427072 | Lawson | Jan 1984 | A |
4439068 | Pokladnik | Mar 1984 | A |
4440232 | LeMoine | Apr 1984 | A |
4440239 | Evans | Apr 1984 | A |
4441551 | Biffle | Apr 1984 | A |
4444250 | Keithahn et al. | Apr 1984 | A |
4444401 | Roche et al. | Apr 1984 | A |
4448255 | Shaffer et al. | May 1984 | A |
4456062 | Roche et al. | Jun 1984 | A |
4456063 | Roche | Jun 1984 | A |
4457489 | Gilmore | Jul 1984 | A |
4478287 | Hynes et al. | Oct 1984 | A |
4480703 | Garrett | Nov 1984 | A |
4484753 | Kalsi | Nov 1984 | A |
4486025 | Johnston | Dec 1984 | A |
4488703 | Jones | Dec 1984 | A |
4497592 | Lawson | Feb 1985 | A |
4500094 | Biffle | Feb 1985 | A |
4502534 | Roche et al. | Mar 1985 | A |
4508313 | Jones | Apr 1985 | A |
4509405 | Bates | Apr 1985 | A |
4519577 | Jones | May 1985 | A |
4524832 | Roche et al. | Jun 1985 | A |
4526243 | Young | Jul 1985 | A |
4527632 | Chaudot | Jul 1985 | A |
4529210 | Biffle | Jul 1985 | A |
4531580 | Jones | Jul 1985 | A |
4531591 | Johnston | Jul 1985 | A |
4531593 | Elliott et al. | Jul 1985 | A |
4531951 | Burt et al. | Jul 1985 | A |
4533003 | Bailey | Aug 1985 | A |
4540053 | Baugh et al. | Sep 1985 | A |
4546828 | Roche | Oct 1985 | A |
4553591 | Mitchell | Nov 1985 | A |
D282073 | Bearden et al. | Jan 1986 | S |
4566494 | Roche | Jan 1986 | A |
4575426 | Bailey | Mar 1986 | A |
4595343 | Thompson et al. | Jun 1986 | A |
4597447 | Roche et al. | Jul 1986 | A |
4597448 | Baugh | Jul 1986 | A |
4610319 | Kalsi | Sep 1986 | A |
4611661 | Hed et al. | Sep 1986 | A |
4615544 | Baugh | Oct 1986 | A |
4618314 | Hailey | Oct 1986 | A |
4621655 | Roche | Nov 1986 | A |
4623020 | Nichols | Nov 1986 | A |
4626135 | Roche | Dec 1986 | A |
4630680 | Elkins | Dec 1986 | A |
4632188 | Schuh et al. | Dec 1986 | A |
4646826 | Bailey et al. | Mar 1987 | A |
4646844 | Roche et al. | Mar 1987 | A |
4651830 | Crotwell | Mar 1987 | A |
4660863 | Bailey | Apr 1987 | A |
4688633 | Barkley | Aug 1987 | A |
4690220 | Braddick | Sep 1987 | A |
4697484 | Klee et al. | Oct 1987 | A |
4709900 | Dyhr | Dec 1987 | A |
4712620 | Lim et al. | Dec 1987 | A |
4719937 | Roche et al. | Jan 1988 | A |
4722615 | Bailey et al. | Feb 1988 | A |
4727942 | Galle et al. | Mar 1988 | A |
4736799 | Ahlstone | Apr 1988 | A |
4745970 | Bearden et al. | May 1988 | A |
4749035 | Cassity | Jun 1988 | A |
4751965 | Cassity | Jun 1988 | A |
4754820 | Watts et al. | Jul 1988 | A |
4757584 | Pav et al. | Jul 1988 | A |
4759413 | Bailey et al. | Jul 1988 | A |
4765404 | Bailey et al. | Aug 1988 | A |
4783084 | Biffle | Nov 1988 | A |
4807705 | Henderson et al. | Feb 1989 | A |
4813495 | Leach | Mar 1989 | A |
4817724 | Funderburg, Jr. et al. | Apr 1989 | A |
4822212 | Hall et al. | Apr 1989 | A |
4825938 | Davis | May 1989 | A |
4828024 | Roche | May 1989 | A |
4832126 | Roche | May 1989 | A |
4836289 | Young | Jun 1989 | A |
4844406 | Wilson | Jul 1989 | A |
4865137 | Bailey | Sep 1989 | A |
4882830 | Carstensen | Nov 1989 | A |
4909327 | Roche | Mar 1990 | A |
4921259 | Saunders | May 1990 | A |
4949796 | Williams | Aug 1990 | A |
4955436 | Johnston | Sep 1990 | A |
4955949 | Bailey et al. | Sep 1990 | A |
4962819 | Bailey et al. | Oct 1990 | A |
4971148 | Roche et al. | Nov 1990 | A |
4984636 | Bailey et al. | Jan 1991 | A |
4995464 | Watkins et al. | Feb 1991 | A |
5009265 | Bailey et al. | Apr 1991 | A |
5022472 | Bailey et al. | Jun 1991 | A |
5028056 | Bemis et al. | Jul 1991 | A |
5035292 | Bailey | Jul 1991 | A |
5040600 | Bailey et al. | Aug 1991 | A |
5048621 | Bailey | Sep 1991 | A |
5062450 | Bailey | Nov 1991 | A |
5062479 | Bailey et al. | Nov 1991 | A |
5072795 | Delgado et al. | Dec 1991 | A |
5076364 | Hale et al. | Dec 1991 | A |
5082020 | Bailey | Jan 1992 | A |
5085277 | Hopper | Feb 1992 | A |
5101897 | Leismer et al. | Apr 1992 | A |
5137084 | Gonzales et al. | Aug 1992 | A |
5147559 | Brophey et al. | Sep 1992 | A |
5154231 | Bailey et al. | Oct 1992 | A |
5163514 | Jennings | Nov 1992 | A |
5165480 | Wagoner et al. | Nov 1992 | A |
5174376 | Singeetham | Dec 1992 | A |
5178215 | Yenulis et al. | Jan 1993 | A |
5182979 | Morgan | Feb 1993 | A |
5184686 | Gonzalez | Feb 1993 | A |
5195754 | Dietle | Mar 1993 | A |
5205165 | Jardine et al. | Apr 1993 | A |
5213158 | Bailey et al. | May 1993 | A |
5215151 | Smith et al. | Jun 1993 | A |
5224557 | Yenulis et al. | Jul 1993 | A |
5230520 | Dietle et al. | Jul 1993 | A |
5243187 | Hettlage | Sep 1993 | A |
5251869 | Mason | Oct 1993 | A |
5255745 | Czyrek | Oct 1993 | A |
5277249 | Yenulis et al. | Jan 1994 | A |
5279365 | Yenulis et al. | Jan 1994 | A |
5305839 | Kalsi et al. | Apr 1994 | A |
5307879 | Kent | May 1994 | A |
5320325 | Young et al. | Jun 1994 | A |
5322137 | Gonzales | Jun 1994 | A |
5325925 | Smith et al. | Jul 1994 | A |
5348107 | Bailey et al. | Sep 1994 | A |
5375476 | Gray | Dec 1994 | A |
5427179 | Bailey | Jun 1995 | A |
5431220 | Bailey | Jul 1995 | A |
5443129 | Bailey et al. | Aug 1995 | A |
5495872 | Gallagher et al. | Mar 1996 | A |
5529093 | Gallagher et al. | Jun 1996 | A |
5588491 | Tasson et al. | Dec 1996 | A |
5607019 | Kent | Mar 1997 | A |
5647444 | Williams | Jul 1997 | A |
5657820 | Bailey et al. | Aug 1997 | A |
5662171 | Brugman et al. | Sep 1997 | A |
5662181 | Williams et al. | Sep 1997 | A |
5671812 | Bridges | Sep 1997 | A |
5678829 | Kalsi et al. | Oct 1997 | A |
5735502 | Levett et al. | Apr 1998 | A |
5738358 | Kalsi et al. | Apr 1998 | A |
5755372 | Cimbura | May 1998 | A |
5823541 | Dietle et al. | Oct 1998 | A |
5829531 | Hebert et al. | Nov 1998 | A |
5848643 | Carbaugh et al. | Dec 1998 | A |
5873576 | Dietle et al. | Feb 1999 | A |
5878818 | Hebert et al. | Mar 1999 | A |
5901964 | Williams et al. | May 1999 | A |
5944111 | Bridges | Aug 1999 | A |
5952569 | Jervis | Sep 1999 | A |
5960881 | Allamon et al. | Oct 1999 | A |
6007105 | Dietle et al. | Dec 1999 | A |
6016880 | Hall et al. | Jan 2000 | A |
6017168 | Fraser, Jr. | Jan 2000 | A |
6036192 | Dietle et al. | Mar 2000 | A |
6039118 | Carter et al. | Mar 2000 | A |
6050348 | Richarson et al. | Apr 2000 | A |
6070670 | Carter et al. | Jun 2000 | A |
6076606 | Bailey | Jun 2000 | A |
6102123 | Bailey et al. | Aug 2000 | A |
6102673 | Mott et al. | Aug 2000 | A |
6109348 | Caraway | Aug 2000 | A |
6109618 | Dietle | Aug 2000 | A |
6112810 | Bailey | Sep 2000 | A |
6120036 | Kalsi et al. | Sep 2000 | A |
6129152 | Hosie et al. | Oct 2000 | A |
6138774 | Bourgoyne, Jr. et al. | Oct 2000 | A |
6170576 | Bailey | Jan 2001 | B1 |
6202745 | Reimert et al. | Mar 2001 | B1 |
6209663 | Hosie | Apr 2001 | B1 |
6213228 | Saxman | Apr 2001 | B1 |
6227547 | Dietle et al. | May 2001 | B1 |
6230824 | Peterman et al. | May 2001 | B1 |
6244359 | Bridges et al. | Jun 2001 | B1 |
6263982 | Hannegan et al. | Jul 2001 | B1 |
6273193 | Hermann | Aug 2001 | B1 |
6315302 | Conroy et al. | Nov 2001 | B1 |
6315813 | Morgan et al. | Nov 2001 | B1 |
6325159 | Peterman et al. | Dec 2001 | B1 |
6334619 | Dietle et al. | Jan 2002 | B1 |
6352129 | Best | Mar 2002 | B1 |
6354385 | Ford et al. | Mar 2002 | B1 |
6361830 | Schenk | Mar 2002 | B1 |
6375895 | Daemen | Apr 2002 | B1 |
6382634 | Dietle et al. | May 2002 | B1 |
6386291 | Short | May 2002 | B1 |
6413297 | Morgan et al. | Jul 2002 | B1 |
6450262 | Regan | Sep 2002 | B1 |
6454007 | Bailey | Sep 2002 | B1 |
6457529 | Calder et al. | Oct 2002 | B2 |
6470975 | Bourgoyne et al. | Oct 2002 | B1 |
6478303 | Radcliffe | Nov 2002 | B1 |
6494462 | Dietle | Dec 2002 | B2 |
6504982 | Greer, IV | Jan 2003 | B1 |
6505691 | Judge | Jan 2003 | B2 |
6520253 | Calder | Feb 2003 | B2 |
6536520 | Snider et al. | Mar 2003 | B1 |
6536525 | Haugen et al. | Mar 2003 | B1 |
6547002 | Bailey et al. | Apr 2003 | B1 |
6554016 | Kinder | Apr 2003 | B2 |
6561520 | Kalsi et al. | May 2003 | B2 |
6581681 | Zimmerman et al. | Jun 2003 | B1 |
6607042 | Hoyer et al. | Aug 2003 | B2 |
RE38249 | Tasson et al. | Sep 2003 | E |
6655460 | Bailey et al. | Dec 2003 | B2 |
6685194 | Dietle et al. | Feb 2004 | B2 |
6702012 | Bailey et al. | Mar 2004 | B2 |
6708762 | Haugen et al. | Mar 2004 | B2 |
6720764 | Relton et al. | Apr 2004 | B2 |
6725951 | Looper | Apr 2004 | B2 |
6732804 | Hosie et al. | May 2004 | B2 |
6749172 | Kinder | Jun 2004 | B2 |
6767016 | Gobeli et al. | Jul 2004 | B2 |
6843313 | Hult | Jan 2005 | B2 |
6851476 | Gray et al. | Feb 2005 | B2 |
6877565 | Edvardsen | Apr 2005 | B2 |
6886631 | Wilson et al. | May 2005 | B2 |
6896048 | Mason et al. | May 2005 | B2 |
6896076 | Nelson et al. | May 2005 | B2 |
6904981 | Jan van Riet | Jun 2005 | B2 |
6913092 | Bourgoyne | Jul 2005 | B2 |
6945330 | Wilson et al. | Sep 2005 | B2 |
7004444 | Kinder | Feb 2006 | B2 |
7007913 | Kinder | Mar 2006 | B2 |
7011167 | Ebner | Mar 2006 | B2 |
7025130 | Bailey et al. | Apr 2006 | B2 |
7028777 | Wade et al. | Apr 2006 | B2 |
7032691 | Humphreys | Apr 2006 | B2 |
7040394 | Bailey et al. | May 2006 | B2 |
7044237 | Leuchtenberg | May 2006 | B2 |
7073580 | Wilson et al. | Jul 2006 | B2 |
7077212 | Roesner et al. | Jul 2006 | B2 |
7080685 | Bailey et al. | Jul 2006 | B2 |
7086481 | Hosie et al. | Aug 2006 | B2 |
7152680 | Wilson et al. | Dec 2006 | B2 |
7159669 | Bourgoyne et al. | Jan 2007 | B2 |
7165610 | Hopper | Jan 2007 | B2 |
7174956 | Williams et al. | Feb 2007 | B2 |
7178600 | Luke et al. | Feb 2007 | B2 |
7191840 | Bailey | Mar 2007 | B2 |
7198098 | Williams | Apr 2007 | B2 |
7204315 | Pia | Apr 2007 | B2 |
7219729 | Bostick et al. | May 2007 | B2 |
7237618 | Williams | Jul 2007 | B2 |
7237623 | Hannegan | Jul 2007 | B2 |
7240727 | Williams | Jul 2007 | B2 |
7243958 | Williams | Jul 2007 | B2 |
7255173 | Hosie et al. | Aug 2007 | B2 |
7258171 | Bourgoyne et al. | Aug 2007 | B2 |
7270185 | Fontana et al. | Sep 2007 | B2 |
7278494 | Williams | Oct 2007 | B2 |
7278496 | Leuchtenberg | Oct 2007 | B2 |
7296628 | Robichaux | Nov 2007 | B2 |
7308954 | Martin-Marshall | Dec 2007 | B2 |
7325610 | Giroux et al. | Feb 2008 | B2 |
7334633 | Williams et al. | Feb 2008 | B2 |
7347261 | Markel et al. | Mar 2008 | B2 |
7350590 | Hosie et al. | Apr 2008 | B2 |
7363860 | Wilson et al. | Apr 2008 | B2 |
7367411 | Leuchtenberg | May 2008 | B2 |
7377334 | May | May 2008 | B2 |
7380590 | Hughes | Jun 2008 | B2 |
7380591 | Williams | Jun 2008 | B2 |
7380610 | Williams | Jun 2008 | B2 |
7383876 | Gray et al. | Jun 2008 | B2 |
7389183 | Gray | Jun 2008 | B2 |
7392860 | Johnston | Jul 2008 | B2 |
7413018 | Hosie et al. | Aug 2008 | B2 |
7416021 | Williams | Aug 2008 | B2 |
7416226 | Williams | Aug 2008 | B2 |
7448454 | Bourgoyne et al. | Nov 2008 | B2 |
7451809 | Noske et al. | Nov 2008 | B2 |
7475732 | Hosie et al. | Jan 2009 | B2 |
7487837 | Bailey et al. | Feb 2009 | B2 |
7513300 | Pietras et al. | Apr 2009 | B2 |
7559359 | Williams | Jul 2009 | B2 |
7559366 | Hunter et al. | Jul 2009 | B2 |
7635034 | Williams | Dec 2009 | B2 |
7650950 | Leuchtenberg | Jan 2010 | B2 |
7654325 | Giroux et al. | Feb 2010 | B2 |
7669649 | Williams | Mar 2010 | B2 |
7699109 | May et al. | Apr 2010 | B2 |
7699110 | Anderson et al. | Apr 2010 | B2 |
7708089 | Williams | May 2010 | B2 |
7712523 | Snider et al. | May 2010 | B2 |
7717169 | Williams | May 2010 | B2 |
7717170 | Williams | May 2010 | B2 |
7726416 | Williams | Jun 2010 | B2 |
7735562 | Bennett et al. | Jun 2010 | B2 |
7743823 | Hughes et al. | Jun 2010 | B2 |
7762320 | Williams | Jul 2010 | B2 |
7766100 | Williams | Aug 2010 | B2 |
7779903 | Bailey et al. | Aug 2010 | B2 |
7789132 | Williams | Sep 2010 | B2 |
7789172 | Williams | Sep 2010 | B2 |
7793719 | Snider et al. | Sep 2010 | B2 |
7798250 | Williams | Sep 2010 | B2 |
7802635 | Leduc et al. | Sep 2010 | B2 |
7819204 | Bamford | Oct 2010 | B2 |
7823665 | Sullivan | Nov 2010 | B2 |
7836946 | Bailey et al. | Nov 2010 | B2 |
7836973 | Belcher et al. | Nov 2010 | B2 |
7926593 | Bailey et al. | Apr 2011 | B2 |
7997345 | Hannegan | Aug 2011 | B2 |
8033335 | Orbell et al. | Oct 2011 | B2 |
8286734 | Hannegan et al. | Oct 2012 | B2 |
8322432 | Bailey et al. | Dec 2012 | B2 |
8347966 | Nguyen et al. | Jan 2013 | B2 |
20030106712 | Bourgoyne et al. | Jun 2003 | A1 |
20030164276 | Snider et al. | Sep 2003 | A1 |
20040017190 | McDearmon et al. | Jan 2004 | A1 |
20050000698 | Bailey et al. | Jan 2005 | A1 |
20050151107 | Shu | Jul 2005 | A1 |
20050161228 | Cook et al. | Jul 2005 | A1 |
20060037782 | Martin-Marshall | Feb 2006 | A1 |
20060108119 | Bailey et al. | May 2006 | A1 |
20060144622 | Bailey et al. | Jul 2006 | A1 |
20060157282 | Tilton et al. | Jul 2006 | A1 |
20060191716 | Humphreys | Aug 2006 | A1 |
20070051512 | Markel et al. | Mar 2007 | A1 |
20070095540 | Kozicz | May 2007 | A1 |
20070163784 | Bailey | Jul 2007 | A1 |
20080169107 | Redlinger et al. | Jul 2008 | A1 |
20080210471 | Bailey et al. | Sep 2008 | A1 |
20080236819 | Foster et al. | Oct 2008 | A1 |
20080245531 | Noske et al. | Oct 2008 | A1 |
20090025930 | Iblings et al. | Jan 2009 | A1 |
20090101351 | Hannegan et al. | Apr 2009 | A1 |
20090101411 | Hannegan et al. | Apr 2009 | A1 |
20090139724 | Gray et al. | Jun 2009 | A1 |
20090152006 | Leduc et al. | Jun 2009 | A1 |
20090166046 | Edvardson et al. | Jul 2009 | A1 |
20090200747 | Williams | Aug 2009 | A1 |
20090211239 | Askeland | Aug 2009 | A1 |
20090236144 | Todd et al. | Sep 2009 | A1 |
20090301723 | Gray | Dec 2009 | A1 |
20100008190 | Gray et al. | Jan 2010 | A1 |
20100025047 | Sokol | Feb 2010 | A1 |
20100175882 | Bailey et al. | Jul 2010 | A1 |
20110024195 | Hoyer | Feb 2011 | A1 |
20110036629 | Bailey et al. | Feb 2011 | A1 |
20110036638 | Sokol | Feb 2011 | A1 |
20120318496 | Bailey et al. | Dec 2012 | A1 |
Number | Date | Country |
---|---|---|
199927822 | Sep 1999 | AU |
200028183 | Sep 2000 | AU |
200028183 | Sep 2000 | AU |
2363132 | Sep 2000 | CA |
2447196 | Apr 2004 | CA |
2690289 | Jul 2010 | CA |
0290250 | Nov 1988 | EP |
0290250 | Nov 1988 | EP |
267140 | Mar 1993 | EP |
1375817 | Jan 2004 | EP |
1519003 | Mar 2005 | EP |
1659260 | May 2006 | EP |
1161299 | Aug 1969 | GB |
2019921 | Nov 1979 | GB |
2067235 | Jul 1981 | GB |
2362668 | Nov 2001 | GB |
2394738 | May 2004 | GB |
2394741 | May 2004 | GB |
2449010 | Aug 2007 | GB |
WO 9306335 | Apr 1993 | WO |
WO 9945228 | Sep 1999 | WO |
WO 9950524 | Oct 1999 | WO |
WO 9951852 | Oct 1999 | WO |
WO 9950524 | Dec 1999 | WO |
WO 0052299 | Sep 2000 | WO |
WO 0052300 | Sep 2000 | WO |
WO 0179654 | Oct 2001 | WO |
WO 0236928 | May 2002 | WO |
WO 0250398 | Jun 2002 | WO |
WO 03071091 | Aug 2003 | WO |
WO 2006088379 | Aug 2006 | WO |
WO 2007092956 | Aug 2007 | WO |
WO 2008133523 | Nov 2008 | WO |
WO 2008156376 | Dec 2008 | WO |
WO 2009017418 | Feb 2009 | WO |
WO 2009123476 | Oct 2009 | WO |
Entry |
---|
US 6,708,780, 03/2004, Bourgoyne et al. (withdrawn). |
U.S. Appl. No. 60/079,641, Abandoned, but Priority Claimed in above US Patent Nos. 6,203,824B1 and 6,102,673 and PCT WO 99/50524, filed Mar. 27, 1998. |
U.S. Appl. No. 60/122,530, Abandoned, but Priority Claimed in US Patent No. 6,470,975B1, filed Mar. 2, 1999. |
U.S. Appl. No. 61/205,209, Abandoned, but priority claimed in US2010/0175882A1, filed Jan. 15, 2009. |
The Modular T BOP Stack System, Cameron Iron Works © 1985 (5 pages). |
Cameron HC Collet Connector, © 1996 Cooper Cameron Corporation, Cameron Division (12 pages). |
Riserless drilling: circumventing the size/cost cycle in deepwater—Conoco, Hydril project seek enabling technologies to drill in deepest water depths economically, May 1986 Offshore Drilling Technology (p. 49, 50, 52, 53, 54 and 55). |
Williams Tool Company—Home Page—Under Construction Williams Rotating Controls Heads (2 pages); Seal-Ability for the pressures of drilling (2 pages); Williams Model 7000 Series Rotating Control Heads (1 page); Williams Model 7000 & 7100 Series Rotating Control Heads (2 pages); Williams Model IP1000 Rotating Control Head (2 pages); Williams Conventional Models 8000 & 9000 (2 pages); Applications Where Using a Williams rotating control head while drilling is a plus (1 page); Williams higher pressure rotating control head systems and Ideally suited for new technology flow and closed loop underbalanced drilling (UBD) Vertical and Horizontal (2 pages); and How to Contact Us (2 pages). |
Offshore—World Trends and Technology for Offshore Oil and Gas Operations, Mar. 1998; Seismic: Article entitled, “Shallow Flow Diverter JIP Spurred by Deepwater Washouts” (3 pages including cover page, table of contents and p. 90). |
Williams Tool Co., Inc. Rotating Controls Heads and Strippers for Air, Gas, Mud, and Geothermal Drilling Worldwide—Sales Rental Service, © 1988 (19 pages). |
Williams Tool Co., Inc. 19 page brochure © 1991 Williams Tool Co., Inc. (19 pages). |
FIG. 19 Floating Piston Drilling Choke Design: May of 1997. |
Blowout Preventer Testing for Underbalanced Drilling by Charles R. “Rick” Stone and Larry A. Cress. Signa Engineering Corp., Houston, Texas (24 pages) Sep. 1997. |
Williams Tool Co., Inc. Instructions, Assemble & Disassemble Model 9000 Bearing Assembly (cover page and 27 numbered pages). |
Williams Tool Co., Inc. Rotating Controls Heads Making Drilling Safer While Reducing Costs Since 1968, © 1989 (4 pages). |
Williams Tool Company, Inc. International Model 7000 Rotating Control Head, 1991 (4 pages). |
Williams Rotating Control Heads, Reduce Costs Increase Safety Reduce Enviormental Impact, 4 pages, ( © 1995). |
Williams Rotating Control Heads, Reduce Costs Increase Safety Reduce Enviornmental Impact (4 pages). |
Williams Tool Co., Inc. Sales-Rental-Service, Williams Rotating Control Heads and Strippers for Air, Gas, Mud, and Geothermal Drilling, © 1982 (7 pages). |
Williams Tool Co., Inc., Rotating Control Heads and Strippers for Air, Gas, Mud, Geothermal and Pressure Drilling, © 1991 (19 pages). |
An article—The Brief Jan. 1996, The Brief's Guest Columnists, Williams Tool Co., Inc., Communicating Dec. 13, 1995 (Fort Smith, Arkansas), The When? and Why? of Rotating Control Head Usage, Copyright © Murphy Publishing, Inc. 1996 (2 pages). |
A reprint from the Oct. 9, 1995 edition of Oil & Gas Journal, “Rotating control head applications increasing,” by Adam T. Bourgoyne, Jr., Copyright 1995 by PennWell Publishing Company (6 pages). |
1966-1967 Composite Catalog—Grant Rotating Drilling Head for Air, Gas or Mud Drilling (1 page). |
1976-1977 Composite Catalog Grant Oil Tool Company Rotating Drilling Head Models 7068, 7368, 8068 (Patented), Equally Effective with Air, Gas, or Mud Circulation Media (3 pages). |
A Subsea Rotating Control Head for Riserless Drilling Applications; Darryl A. Bourgoyne, Adam T. Bourgoyne, and Don Hannegan—1998 (International Association of Drilling Contractors International Deep Water Well Control Conference held in Houston, Texas, Aug. 26-27, 1998) (14 pages). |
Hannegan, “Applications Widening for Rotating Control Heads,” Drilling Contractor, cover page, table of contents and pp. 17 and 19, Drilling Contractor Publications Inc., Houston, Texas, Jul. 1996. |
Composite Catalog, Hughes Offshore 1986-87 Subsea Systems and Equipment, Hughes Drilling Equipment Composite Catalog (pp. 2986-3004). |
Williams Tool Co., Inc. Technical Specifications Model for The Model 7100, (3 pages). |
Williams Tool Co., Inc. Website, Underbalanced Drilling (UBD), The Attraction of UBD (2 pages). |
Williams Tool Co., Inc. Website,. “Applications, Where Using a Williams Rotating Control Head While Drilling is a Plus” (2 pages). |
Williams Tool Co., Inc. Website, “Model 7100,”(3 pages). |
Composite Catalog, Hughes Offshore 1982/1983, Regan Products, © Copyright 1982 (Two cover sheets and 4308-27 thru 4308-43, and end sheet). See p. 4308-36 Type KFD Diverter. |
Coflexip Brochure; 1-Coflexip Sales Offices, 2-the Flexible Steel Pipe for Drilling and Service Applications, 3-New 5 I.D. General Drilling Flexible, 4-Applications, and 5-Illustration (5 unnumbered pages). |
Baker, Ron, “A Primer of Oilwell Drilling,” Fourth Edition, Published Petroleum Extension Service, The University of Texas at Austin, Austin, Texas, in cooperation with International Association of Drilling Contractors Houston, Texas © 1979 (3 cover pages and pp. 42-49 re Circulation System). |
Brochure, Lock down Lubricator System, Dutch Enterprises, Inc., “Safety with Savings” (cover sheet and 16 unnumbered pages); see above US Patent No. 4,836,289 referred to therein. |
Hydril GL series Annual Blowout Preventers (Patented—see Roche patents above), (cover sheet and 2 pages). |
Other Hydril Product Information (The GH Gas Handler Series Product is Listed), © 1996, Hydril Company (Cover sheet and 19 pages). |
Brochure, Shaffer Type 79 Rotating Blowout Preventer, NL Rig Equipment/NL Industries, Inc., (6 unnumbered pages). |
Shaffer, A Varco Company, (Cover page and pp. 1562-1568). |
Avoiding Explosive Unloading of Gas in a Deep Water Riser When SOBM in Use; Colin P. Leach & Joseph R. Roche—1998 (The Paper Describes an Applicaton for the Hydril Gas Handler, The Hydril GH 211-2000 Gas Handler is Depicted in Figure 1 of the Paper) (9 unnumbered pages). |
Feasibility Study of Dual Density Mud System for Deepwater Drilling Operations; Clovis A. Lopes & A.T. Bourgoyne, Jr.—1997 (Offshore Technology Conference Paper No. 8465); (pp. 257-266). |
Apr. 1998 Offshore Drilling with Light Weight Fluids Joint Industry Project Presentation (9 unnumbered pages). |
Nakagawa, Edson Y., Santos, Helio and Cunha, J.C., “Application of Aerated-Fluid Drilling in Deepwater” SPE/IACDC 52787 Presented by Don Hannegan, P.E., SPE © SPE/IADC Drilling Conference, Amsterdam, Holland, Mar. 9-11, 1999 (5 unnumbered pages). |
Brochure: “Inter-Tech Drilling Solutions, Ltd.'s RBOP™ Means Safety and Experience for Underbalanced Drilling,” Inter-Tech Drilling Solutions Ltd./Big D Rentals & Sales (1981) Ltd. and Color Copy of “Rotating BOP” (2 unnumbered pages). |
“Pressure Control While Drilling,” Shaffer® A Varco Company, Rev. A (2 unnumbered pages). |
Field Exposure (As of Aug. 1998), Shaffer® A Varco Company (1 unnumbered page). |
Graphic: “Rotating Spherical BOP” (1 unnumbered page). |
“JIP's Worl Brightens Outlook for UBD in Deep Waters”by Edson Yoshihito Nakagawa, Helio Santos and Jose Carlos Cunha, American Oil & Gas Reporter, Apr. 1999, pp. 53, 56, 58-60 and 63. |
“Seal-Tech 1500 PSI Rotating Blowout Preventer,” Undated, 3 pages. |
“RPM System 3000™ Rotating Blowout Preventer, Setting a new standard in Well Control,”by Techcorp Industries, Undated, 4 pages. |
“RiserCap™ Materials Presented at the 1999 LSU/MMS/IADC Well Control Workshop”, by Williams Tool Company, Inc., Mar. 24-25, pp. 1-14. |
“The 1999 LSU/MMS Well Control Workshop: An overview,” by John Rogers Smith. World Oil, Jun. 1999. Cover page and pp. 4, 41-42, and 44-45. |
Dag Oluf Nessa, “Offshore underbalanced drilling system could revive field developments,” World Oil, vol. 218, No. 10, Oct. 1997, 1 unnumbered page and pp. 83-84, 86, and 88. |
D.O. Nessa, “Offshore underbalanced drilling system could revive field developments,” World Oil Exploration Drilling Production, vol. 218, No. 7, Color pages of Cover Page and pp. 3, 61-64, and 66, Jul. 1997. |
PCT Search Report, International Application No. PCT/US99/06695, 4 pages (Date of Completion May 27, 1999). |
PCT Search Report, International Application No. PCT/GB00/00731, 3 pages (Date of Completion Jun. 16, 2000). |
National Academy of Sciences—National Research Council, “Design of a Deep Ocean Drilling Ship,” Cover Page and pp. 114-121. Undated but cited in above US Patent No. 6,230,824B1. |
“History and Development of a Rotating Preventer,” by A. Cress, Rick Stone, and Mike Tangedahl, IADC/SPE 23931, Feb. 1992, pp. 757-773. |
Helio Santos, Email message to Don Hannegan, et al., 1 page (Aug. 20, 2001). |
Rehm, Bill, “Practical Underbalanced Drilling and Workover,” Petroleum Extension Service, The University of Texas at Austin Continuing & Extended Education, Cover page, title page, copyright page, and pp. 6-6, 11-2, 11-3, G-9, and G-10 (2002). |
Williams Tool Company Inc., “Risercap™: Rotating Control Head System For Floating Drilling Rig Applications,” 4 unnumbered pages, ( © 1999 Williams Tool Company, Inc.). |
Antonio C.V.M. Lage, Helio, Santos and Paulo R.C. Silva, Drilling with Aerated Drilling Fluid From a Floating Unit Part 2: Drilling the Well, SPE 71361, 11 pages ( © 2001, Society of Petroleum Engineers, Inc.). |
Helio Santos, Fabio Rosa, and Christian Leuchtenberg, Drilling and Aerated Fluid from a Floating Unit, Part 1: Planning, Equipment, Tests, and Rig Modifications, SPE/IADC 67748, 8 pages ( © 2001 SPE/IADC Drilling Conference). |
E.Y. Nakagawa, H. Santos, J.C. Cunha and S. Shayegi, Planning of Deepwater Drilling Operations with Aerated Fluids, SPE 54283, 7 pages, ( © 1999, Society of Petroleum Engineers). |
E.Y. Nakagawa, H.M.R. Santos and J.C. Cunha, Implementing the Light-Weight Fluids Drilling Technology in Deepwater Scenarios, 1999 LSU/MMS Well Control Workshop Mar. 24-25, 1999, 12 pages (1999). |
Press Release, “Stewart & Stevenson Introduces First Dual Gradient Riser,” Stewart & Stevenson, http:/www.ssss/com/ssss/200000831.asp, 2 pages (Aug. 31, 2000). |
Press Release: “Stewart & Stevenson introduces First Dual Gradient Riser,” Stewart & Stevenson, http:www/ssss/com/ssss/200000831.asp, 2 pages (Aug. 31, 2000). |
Williams Tool Company Inc., “Williams Tool Company Introduces the . . . Virtual Riser™,” 4 unnumbered pages, ( © 1998 Williams Tool Company, Inc.). |
“PETEX Publications,” Petroleum Extension Service, University of Texas at Austin, 12 pages, (last modified Dec. 6, 2002). |
“BG in the Caspian region,” SPE Review, Issue 164, 3 unnumbered pages (May 2003). |
“Field Cases as of Mar. 3, 2003,” Impact Fluid Solutions, 6 pages (Mar. 3, 2003). |
“Determine in the Safe Application of Underbalanced Drilling Technologies in Marine Environments—Technical Proposal,” Maurer Technology, Inc., Cover Page and pp. 2-13 (Jun. 17, 2002). |
Colbert, John W., “John W. Colbert, P.E. Vice President Engineering Bioraphical Data,” Signa Engineering Corp., 2 unnumbered pages (undated). |
“Technical Training Courses,” Parker Drilling Co., http:/www.parkerdrilling.com/news/tech.html, 5 pages (last visited, Sep. 5, 2003). |
“Drilling equipment: Improvements from data recording to slim hole,” Drilling Contractor, pp. 30-32, (Mar. 30-32, (Mar./Apr. 2000). |
“Drilling conference promises to be informative,” Drilling Contractor, p. 10 (Jan./Feb. 2002). |
“Underbalanced and Air Drilling,” OGCI, Inc., http:/www.ogci.com/course—info.asp?counsel=410, 2 pages., (2003). |
“2003 SPE Calendar,” Society of Petroleum Engineers, Google cache of http:/www.spe.org/spe/cda/view/events/eventMaster/0,1470,1648—2194—632303.00html; for “mud cap drilling”, 2 pages (2001). |
“Oilfield Glossary: reverse-circulating valve,” Schlumberger Limited, 1 page (2003). |
Murphy, Ross D. and Thompson, Paul B., “A drilling contractor's view of underbalanced drilling,” World Oil Magazine, vol. 223, No. 5, 9 pages (May 2002). |
“Weatherford UnderBalanced Services: General Underbalanced Presentation to the DTI,” 71 unnumbered pages, © 2002. |
Rach, Nina M., “Underbalanced near-balanced drilling are possible offshore,” Oil & Gas Journal, Color Copies, pp. 39-44, (Dec. 1, 2003). |
Forrest, Neil et al., Subsea Equipment for Deep Water Drilling Using Dual Gradient Mud System, SPE/IASC Drilling Conference held in Amsterdam, The Netherlands, Feb. 27. 2001 to Mar. 1, 2001, Paper SPE/IADC 67707, © 2001 SPE/IADC Drilling Conference (8 pages); particularly see. p. 3, col. 1, ¶ 4 and col. 2, ¶ 5 and FIGS. 4-6; cited in 7V below where indicated as “technical background”. |
Hannegan, D.M.; Bourgoyne, Jr., A.T.: “Deepwater Drilling with Lightweight Fluid—Essential Equipment Required,” SPE/IADC 67708, pp. 1-6 ( © 2001, SPE/IADC Drilling Conference). |
Hannegan, Don M., “Underbalanced Operations Continue Offshore Movement,” SPE 68491, pp. 1-3, ( © 2001, Society of Petroleum Engineers, Inc.). |
Hannegan, D. and Divine, R., “Underbalanced Drilling—Perceptions and Realities of Today's Technology in Offshore Applications,” IADC/SPE 74448, p. 1-9, ( © 2002, IADC/SPE Drilling Conference). |
Hannegan, Don M. and Wanzer, Glen: “Well Control Considerations—Offshore Applications of Underbalanced Drilling Technology,” SPE/IADC 79854, pp. 1-14, ( © 2003, SPE/IADC Drilling Conference). |
Bybee, Karen, “Offshore Applications of Underbalanced—Drilling Technology,” Journal of Petroleum Technology, Cover Page and pp. 51-52, (Jan. 2004). |
Bourgoyne, Darryl A.; Bourgoyne, Adam T.; Hannegan, Don; “A Subsea Rotating Control Head for Riserless Drilling Applications,” IADC International Deep Water Well Control Conference, pp. 1-14, (Aug. 26-27, 1998). |
Lage, Antonio C.V.M.; Santos, Helio; Silva, Paulo R.C.; “Drilling With Aerated Drilling Fluid From a Floating Unit Part 2: Drilling the Well,” Society of Petroleum Engineers, SPE 71361, pp. 1-11 (Sep. 30-Oct. 3, 2001)(see document BBB). |
Furlow, William; “Shell's seafloor pump, solids removal key to ultra-deep, dual-gradient drilling (Skid ready for commercialization),” Offshore World Trends and Technology for Offshore Oil and Gas Operations, Cover page, table of contents, pp. 54, 2 unnumbered pages, and 106 (June 2001). |
Rowden, Michael V.: “Advances in riserless drilling pushing the deepwater surface string envelope (Alternative to seawater, CaCl12 sweeps);” Offshore World Trends and Technology for Offshore Oil and Gas Operations, Cover page, table of contents, pp. 56, 58, and 106 (Jun. 2001). |
Boye, John: “Multi Purpose Intervention Vessel Presentation,” M.O.S.T. Multi Operational Service Tankers, Weatherford International, Jan. 2004, 43 pages ( © 2003). |
GB Search Report, International Application No. GB 0324939.8, 1 page (Jan. 21, 2004). |
MicroPatent® list of patents citing US Patent No. 3,476,195, printed on Jan. 24, 2003. |
PCT Search Report, International Application No. PCT/EP2004/052167, 4 pages (Date of Completion Nov. 25, 2004). |
PCT Written Opinion of the International Searching Authority, International No. PCT/EP2004/052167, 6 pages. |
Supplementary European Search Report No. EP 99908371, 3 pages (Date of Completion Oct. 22, 2004). |
General Catalog, 1970-71, Vetco Offshore, Inc., Subsea Systems; cover page, company page and numbered pp. 4800, 4816-4818; 6 pages total, in particular see numbered p. 4816 for “patented”Vetco H-4 connectors. |
General Catalog, 1972-73, Vetco Offshore, Inc., Subsea Systems; cover page; company page and numbered pp. 4498, 4509-4510; 5 pages total. |
General Catalog, 1974-75, Vetco Offshore, Inc.; cover page, company page and numbered pp. 5160, 5178-5179; 5 pages. |
General Catalog, 1976-1977, Vetco Offshore, Inc., Subsea Drilling and Completion Systems; cover page and numbered pp. 5862-5863; 4 pages total. |
General Catalog, 1982-1983, Vetco; cover page and numbered pp. 8454-8455, 8479; 4 pages total. |
Shaffer, A Varco Company: Pressure Control While Drilling System, http:/www.tulsaequipm.com; printed Jun. 21, 2004; 2 pages. |
Performance Drilling by Precision Drilling. A Smart Equation, Precision Drilling, © Precision Drilling Corporation; 12 pages, in particular see 9th page for “Northland's patented RBOP . . . ”. |
RPM System, 3000™ Rotating Blowout Preventer: Setting a New Standard in Well Control, Weatherford, Underbalanced Systems: © 2002-2005 Weatherford: Brochure ♯333.01, 4 pages. |
Managed Pressure Drilling in Marine Environments, Don Hannegan, P.E.; Drilling Engineering Association Workshop, Moody Gardens, Galveston, Jun. 22-23, 2004; © 2004 Weatherford, 28 pages. |
Hold™ 2500 RCD Rotating Control Devices web page and brochure, http://www.smith.com/hold2500; printed Oct. 27, 2004, 5 pages. |
Rehm, Bill, “Practical Underbalanced Drilling and Workover,” Petroleum Extension Service, The University of Texas at Austin Continuing & Extended Education, cover page, title page, copyright page and pp. 6-1 to 6-9, 7-1 to 7-9 (2002). |
“Pressured Mud Cap Drilling from A Semi-Submersible Drilling Rig,” J.H. Terwogt, SPE, L.B. Makiaho and N. van Beelan, SPE, Shell Malaysia Explosion and Production; B.J. Gedge, SPE, and J. Jenkins, Weatherford Drilling and Well Services (6 pages total); © 2005 (This paper was prepared for presentation at the SPE/IADC Drilling Conference held in Amsterdam, The Netherlands, Feb. 23-25, 2005). |
Tangedahl, M.J., et al., “Rotating Preventers: Technology for Better Well Control,” World Oil, Gulf Publishing Company, Houston, TX, US, vol. 213, No. 10, Oct. 1992, numbered pp. 63-64 and 66 (3 pages). |
European Search Report for EP 05 27 0083, Application No. 05270083.8-2315, European Patent Office, Mar. 2, 2006, corresponding to U.S. Appl. No. 10/995,980, published as US2006/0108119 A1 (now US 7,487,837 B2) (5 pages). |
Netherlands Search Report for NL No. 1026044, dated Dec. 14, 2005 (3 pages). |
Int'l. Search Report for PCT/GB 00/00731 corresponding to US :Patent No. 6,470,975 (Jun. 16, 2000) (2 pages). |
GB0324939.8 Examination Report corresponding to US Patent No. 6,470,975 (Mar. 21, 2006) (6 pages). |
GB0324939.8 Examination Report corresponding to US Patent No. 6,470,975 Jan. 22, 2004) (3 pages). |
2003/0106712 Family Lookup Report (Jun. 15, 2006) (5 pages). |
6,470,975 Family Lookup Report (Jun. 15, 2006) (5 pages). |
AU S/N 28183/00 Examination Report corresponding to US Patent No. 6,470,975 (1 page) (Sep. 9, 2002). |
NO S/N 20013953 Examination Report corresponding to US Patent No. 6,470,975 w/one page of English translation (3 pages) (Apr. 29, 2003). |
Nessa, D.O. & Tangedahl, M.L. & Saponia, J: Part 1: “Offshore underbalanced drilling system could revive field developments,” World Oil, vol. 218, No. 7, Cover Page, 3, 61-64 and 66 (Jul. 1997); and Part 2: “Making this valuable reservoir drilling/completion technique work on a conventional offshore drilling platform.” World Oil, vol. 218 No. 10, Cover Page, 3, 83, 84, 86 and 88 (Oct. 1997). |
Int'l. Search Report for PCT/GB 00/00731 corresponding to US Patent No. 6, 470,975 (4 pages) (Jun. 27, 2000). |
Int'l. Preliminary Examination Report for PCT/GB 00/00731 corresponding to US Patent No. 6,470,975 (7 pages) (Dec. 14, 2000). |
NL Examination Report for WO 00/52299 corresponding to this U.S. Appl. No. 10/281,534 (3 pages) (Dec. 19, 2003). |
AU S/N 28181/00 Examination Report corresponding to US Patent No. 6,263,982 (1 page) (Sep. 6, 2002). |
EU Examination Report for WO 00/906522.8-2315 corresponding to US Patent No. 6,263,982 (4 pages) (Nov. 29, 2004). |
NO S/N 20013952 Examination Report w/two pages of English translation corresponding to US Patent No. 6,263,982 (4 pages) (Jul. 2, 2005). |
PCT/GB00/00726 Int'l. Preliminary Examination Report corresponding to US Patent No. 6,263,982 (10 pages) (Jun. 26, 2001). |
PCT/GB00/00726 Written Opinion corresponding to US Patent No. 6,263,982 (7 pages) (Dec. 18, 2000). |
PCT/GB00/00726 International Search Report corresponding to US Patent No. 6,263,982 (3 pages (Mar. 2, 1999). |
AU S/N 27822/99 Examination Report corresponding to US Patent No. 6,138,774 (1 page) (Oct. 15, 2001). |
EU 99908371.0-1266-US99/03888 European Search Report corresponding to US Patent No. 6,138,774 (3 pages) (Nov. 2, 2004). |
NO S/N 20003950 Examination Report w/one page of English translation corresponding to US Patent No. 6,138,774 (3 pages) (Nov. 1, 2004). |
PCT/US990/03888 Notice of Transmittal of International Search Report corresponding to US Patent No. 6,138,774 (6 pages) (Aug. 4, 1999). |
PCT/US99/03888 Written Opinion corresponding to US Patent No. 6,138,744 (5 pages) (Dec. 21, 1999). |
PCT/US99/03888 Notice of Transmittal of International Preliminary Examination Report corresponding to US Patent No. 6,138,774 (15 pages) (Jun. 12, 2000). |
EU Examination Report for 05270083.8-2315 corresponding to U.S. Appl. No. 10/995,980, published as US 2006/0108119 A1 (now US 7,487,837 B2) (11 pages) (May 10, 2006). |
Tangedahl, M.J., et al. “Rotating Preventers: Technology for Better Well Control,” World Oil, Gulf Publishing Company, Houston, TX, US, vol. 213, No. 10, Oct. 1992, numbered pp. 63-64 and 66 (3 pages) XP 000288328 ISSN: 0043-8790 (see YYYY, 5X above). |
UK Search Report for Application No. GB 0325423.2; searched Jan. 30, 2004 corresponding to above US Patent No. 7,040,394 (one page). |
UK Examination Report for Application No. GB 0325423.2 (4 pages). |
Dietle, Lannie L. et al., Kalsi Seals Handbook, Document. 2137 Revision 1, © 1992-2005 Kalsi Engineering, Inc. of Sugar Land, Texas USA; front and back covers and 164 total pages; in particular forward page ii for “Patent Rights”; Appendix A-6 for Kalsi seal part No. 381-6- and A-10 for Kalsi seal part No. 432-32-. as discussed in U.S. Appl. No. 11/366,078 (now U S 7,836,946 B2) at number paragraph 70 and 71. |
FIG. 10 and discussion in U.S. Appl. No. 11/366,078, published as US2006/0144622 A1 (now U S 7,836,946 B2) of Background of Invention. |
Partial European search report R.46 EPC dated Jun. 27, 2007 for European Patent Application EP07103416.9-2315 corresponding to U.S. Appl. No. 11/366,078, published as US 2006/0144622 A1, now US Patent 7,836,946 (5 pages). |
Extended European search report R.44 EPC dated Oct. 9, 2007 for European Patent Application 07103416.9-2315 corresponding to U.S. Appl. No. 11/366,078, published as US-2006/0144622 A1, now US patent 7,836,946 (8 pages). |
U.S. Appl. No. 60/079,641, Mudlift System for Deep Water Drilling, filed Mar. 27, 1998, abandoned, but priority claimed in above US 6,230,824 B1 and 6,102,673 and PCT WO-99/50524 (54 pages). |
U.S. Appl. No. 60/122,530, Concepts for the Application of Rotating Control Head Technology to Deepwater Drilling Operations, filed Mar. 2, 1999, abandoned, but priority claimed in above US 6,470,975 B1 (54 pages). |
PCT/GB2008/050239 (corresponding to US2008/0210471 A1; now issued as US 7,926,593) Annex to Form PCT/ISA/206 Communication Relating to the Results of the Partial International Search dated Aug. 26, 2008 (4 pages). |
PCT/GB2008/050239 (corrsponding to US2008/0210471 A1; now issued as US 7,926,593) International Search Report and Written Opinion of the International Searching Authority (19 pages). |
Vetco Gray Product Information CCDE-PI-0007 dated Mar. 1999 for 59.0″ Standard Bore CSO Diverter (2 pages) © 1999 By Vetco Gray Inc. |
Vetco Gray Capital Drilling Equipment KFDJ and KFDJ Model“J” Diverters (1 page) (no date). |
Hydril Blowout Preventers Catalog M-9402 D (44 pages) © 2004 Hydrill Company LP; see annular and ram BOP seals on p. 41. |
Hydril Compact GK® 7 1/16″-3000 & 5000 psi Annular Blowout Preventers, Catalog 9503B © 1999 Hydril Company (4 pages). |
Weatherford Controlled Pressure Drilling Williams® Rotating Marine Diverter Insert (2 pages). |
Weatherford Controlled Pressure Drilling Model 7800 Rotating Control Device © 2007 Weatherford(5 pages). |
Weatherford Controlled Pressure Drilling® and Testing Services Williams® Model 8000/9000 Conventional Heads © 2002-2006 Weatherford(2 pages). |
Weatherford “Real Results Rotating Control Device Resolves Mud Return Issues in Extended-Reach Well, Saves Equipment Costs and Rig Time” © 2007 Weatherford and “Rotating Control Device Ensures Safety of Crew Drilling Surface-Hole Section” © 2008 Weatherford (2 pages). |
Washington Rotating Control Heads, Inc. Series 1400 Rotating Control Heads (“Shorty”) printed Nov. 21, 2008 (2 pages). |
Smith Services product details for Rotating Control Device—RDH 500® printed Nov. 24, 2008 (4 pages). |
American Petroleum Institute Specification for Drill Through Equipment—Rotating Control Devices, API Specification 16 RCD, First Edition, Feb. 2005 (84 pages). |
Weatherford Drilling & Intervention Services Underbalanced Systems RPM System 3000™ Rotating Blowout Preventer, Setting a New Standard in Well Control, An Advanced Well Control System for Underbalanced Drilling Operations, Brochure #333.00, © 2002 Weatherford (4 pages). |
Medley, George; Moore, Dennis; Nauduri, Sagar; Signa Engineering Corp.; SPE/IADC Managed Pressure Drilling & Underbalanced Operations (PowerPoint presentation; 22 pages). |
Secure Drilling Well Controlled, Secure Drilling™ System using Micro-Flux Control Technology, © 2007 Secure Drilling (12 pages). |
The LSU Petroleum Engineering Research & Technology Transfer Laboratory, 10-rate Step Pump Shut-down and Start-up Example Procedure for Constant Bottom Hole Pressure Manage Pressure Drilling Application (8 pages). |
United States Department of the Interior Minerals Management Service Gulf of Mexico OCS Region NTL No. 2008-G07; Notice to Lessees and Operators of Federal Oil, Gas, and Sulphur Leases in the Outer Continental Shelf, Gulf of Mexico OCS Region, Managed Pressure Drilling Projects; Issue Date: May 15, 2008; Effective Date: Jun. 15, 2008; Expiration Date: Jun. 15, 2013 (9 pages). |
Gray, Kenneth; Dynamic Density Control Quantifies Well Bore Conditions in Real Time During Drilling; American Oil & Gas Reporter, Jan. 2009 (4 pages). |
Kotow, Kenneth J.; Pritchard, David M.; Riserless Drilling with Casing: A New Paradigm for Deepwater Well Design, OTC-19914-PP, © 2009 Offshore Technology Conference, Houston, TX May 4-7, 2009 (13 pages). |
Hannegan, Don M.; Managed Pressure Drilling—A New Way of Looking at Drilling Hydraulics—Overcoming Conventional Drilling Challenges; SPE 2006-2007 Distinguished Lecturer Series presentation (29 pages); see all but particularly see Figs. 14-20; cited in 7V below where indicatied as “document cited for other reasons”. |
Turck Works Industrial Automation; Factor 1 Sensing for Metal Detection, cover page, first page and numbered pp. 1.157 to 1.170 (16 pages) (printed in Jan. 2009). |
Balluff Sensors Worldwide; Object Detection Catalog 08/09—Industrial Proximity Sensors for Non-Contact Detection of Metallic Targets at Ranges Generally under 50mm (2 inches); Linear Position and Measurement; Linear Position Transducer; Inductive Distance Sensors; Photoelectric Distance Sensors; Magneto-Inductive Linear Position Sensors; Magnetic Linear/Rotary Encoder System; printed Dec. 23, 2008 (8 pages). |
Inductive Sensors AC 2-Wire Tubular Sensores, Balluff product catalog pp. 1.109-1.120 (12 pages) (no date). |
Inductive Sensors DC 2-Wire Tubular Sensors, Balluff product catalog pp. 1.125-1.136 (12 pages) (no date). |
Inductive Sensors Analog Inductive Sensors, Balluff product catalog pp. 1.157-1.170 (14 pages) (no date). |
Inductive Sensors DC 3-/4-Wire Inductive Sensors, Balluff product catalog pp. 1.72-1.92 (21 pages). |
Selecting Position Transducers: How to Choose Among Displacement Sensor Technologies; How to Choose Among Draw Wire, LVDT, RVDT, Potentiometer, Optical Encoder, Ultrasonic, Magnetostrictive, and Other Technologies; © 1996-2010, Space Age Control, Inc., printed Jan. 11, 2009 (7 pages) (www..spaceagecontrol.com/selpt.htm). |
Liquid Flowmeters, Omega.com website; printed Jan. 26, 2009 (13 pages). |
Super Autochoke—Automatic Pressure Regulation Under All Conditions © 2009 M-I, LLC; MI Swaco website; printed Apr. 2, 2009 (1 page). |
Extended European Search Report R.61 EPC dated Sep. 16, 2010 for European Patent Application 08166660.4-1266/2050924 corresponding to U.S. Appl. No. 11/975,554, now US 2009/0101351 A1 (7 pages). |
Office Action from the Canadian Intellectual Property Office dated Nov. 13, 2008 for Canadian Application No. 2,580,177 corresponding to U.S. Appl. No. 11/366,078, published as US-2006/0144622 A1, now US Patent No. 7,836,946 B2 (3 pages). |
Response to European Patent Application No. 08719084.9 (corresponding to the present published application US2008/0210471 A1, now issued as US 7,926,593) dated Nov. 16, 2010 (4 pages). |
Office Action from the Canadian Intellectual Property Office dated Apr. 15, 2008 for Canadian Application No. 2,527,395 corresponding to U.S. Appl. No. 10/995,980, published as US-2006/0108119 A1, now US Patent No. 7,487,837 B2 (3 pages). |
Office Action from the Canadian Intellectual Property Office dated Apr. 9, 2009 for Canadian Application No. 2,527,395 corresponding to U.S. Appl. No. 10/995,980, published as US-2006/0108119 A1, now US Patent No. 7,487,837 B2 (2 pages). |
Office Action from the Canadian Intellectual Property Office dated Dec. 15, 2009 for Canadian Application No. 2,681,868 corresponding to U.S. Appl. No. 10/995,980, published as US-2006/0108119 A1, now US Patent No. 7,487,837 B2 (2 pages). |
Examiner's First Report on Australian Patent Application No. 2005234651 from the Australian Patent Office dated Jul. 22, 2010 corresponding to U.S. Appl. No. 10/995,980, published as US-2006/0108119 A1, now US Patent No. 7,487,837 B2 (2 pages). |
Office Action from the Canadian Intellectual Property Office dated Sep. 9, 2010 for Canadian Application No. 2,707,738 corresponding to U.S. Appl. No. 10/995,980, published as US-2006/0108119 A1, now US Patent No. 7,487,837 B2 (2 pages). |
Web page of Ace Wire Spring & Form Company, Inc. printed Dec. 8, 2009 for “Garter Springs—Helical Extension & Compression” www..acewirespring.com/garter-springs.html (1 page). |
Extended European Search Report (R 61 EPC) dated Mar. 4, 2011 for European Application No. 08166658.8-1266/2053197 corresponding to U.S. Appl. No. 11/975,946, published as US 2009-0101411 A1 (13 pages). |
Canadian Intellectual Property Office Office Action dated Dec. 7, 2010, Application No. 2,641,238 entitled “Fluid Drilling Equipment” for Canadian Application corresponding to U.S. Appl. No. 11/975,946, published as US 2009-0101411 A1 (4 pages). |
Grosso, J.A., “An Analysis of Well Kicks on Offshore Floating Drilling Vessels,” SPE 4134, Oct. 1972, pp. 1-20, © 1972 Society of Petroleum Engineers (20 pages). |
Bourgoyne, Jr., Adam T., et al., “Applied Drilling Engineering,” pp. 168-171, © 1991 Society of Petroleum Engineers (6 pages). |
Wagner, R.R., et al., “Surge Field Tests Highlight Dynamic Fluid Response,” SPE/IADC 25771, Feb. 1993, pp. 883-892, © 1993 SPE/IADC Drilling Conference (10 pages). |
Solvang, S.A., et al., “Managed Pressure Drilling Resolves Pressure Depletion Related Problems in the Development of the HPHT Kristin Field,” SPE/IADC 113672, Jan. 2008, pp. 1-9, © 2008 IADC/SPE Managed Pressure Drilling and Underbalanced Operations Conference and Exhibition (9 pages). |
Rasmussen, Ovle Sunde, et al., “Evaluation of MPD Methods for Compensation of Surge-and-Swab Pressure in Drilling Operations,” IADC/SPE 108346, Mar. 2007, pp. 1-11, © 2007 IADC/SPE Managed Pressure Drilling and Underbalanced Operations Conference and Exhibition (11 pages). |
Shaffer Drill String Compensator available from National Oilwell Varco of Houston, Texas, printed Mar. 23, 2010 from http://www.nov.com/ProductDispay.aspx?ID=4954&taxID=121&terms=drill+string+compensators (1 page). |
Shaffer Crown Mounted Compensator available from National Oilwell Varco of Houston, Texas, printed Mar. 23, 2010 from http://www.nov.com/ProductDisplay.aspx?ID=4949&taxID=121&terms=active+drill+string+compensator (3 pages). |
Active heave compensator available from National Oilwell Varco of Houston, Texas, printed Mar. 23, 2010 from http://www.nov.com/ProductDisplay.aspx?ID=3677&taxID=terms=active+heave+compensator (3 pages). |
Durst, Doug, et al., “Subsea Downhole Motion Compensator (SDMC): Field History, Enhancements, and the Next Generation,”IADC/SPE 59152, Feb. 2000, pp. 1-12, © 2000 Society of Petroleum Engineers, Inc. (12 pages). |
Sensoy, Taner, et al., Weatherford Secure Drilling Well Controlled Report “Surge and Swab effects d ue to the Heave motion of floating rigs”, Nov. 10, 2009 (7 pages). |
Hargreaves, David, et al., “Early Kick Detection for Deepwater Drilling: New Probabilistic Methods Applied in the Field” SPE 71369, © 2001, Society of Petroleum Engineers, Inc. (11 pages). |
HH Heavy-Duty Hydraulic Cylinders catalog, The Sheffer Corporation printed Mar. 5, 2010 from http://www.sheffercorp.com/layout—contact.shtm (27 pages). |
Unocal Baroness Surface Stack Upgrade Modifications (5 pages). |
Thomson, William T., Professor of Engineering, University of California, “Vibration Theory and Applications” 1848, 1953, 1965 by Prentice-Hall, Inc. title page, copyright page, contents page and numbered pp. 3-9 (10 pages). |
Active Heave Compensator, Ocean Drilling Program, www.oceandrilling.org (3 pages). |
3.3 Floating Offshore Drilling Rigs (Floaters); 3.3.1. Technologies Required by Floaters; 3.3.2. Drillships; 3.3.3. Semisubmersible Drilling Rig; 4.3.4. Subsea Control System; 4.4. Prospect of Offshore Production System (5 pages). |
Weatherford® Real Results First Rig Systems Solutions for Thailand Provides Safer, More Efficient Operations with Stabmaster® and Automated Side Doors, © 2009 Weatherford document No. 6909.00 discussing Weatherford's Integrated Safety Interlock System (ISIS) (1 page). |
U.S. Appl. No. 61/205,209, filed Jan. 15, 2009; Abandoned, but priority claimed in US2010/0175882A1 (24 pages). |
Smalley® Steel Ring Company, Sprirolox®; pages from website http://www.spirolox.com/what—happened.php printed Apr. 27, 2010 (5 pages). |
Extended European Search Report (R 61 EPC) dated Feb. 22, 2012 for European Application No. 1015296.9-2315/2216498 corresponding to U.S. Appl. No. 12/322,860, published as US2009-0139724 A1 on Jun. 4, 2009 (our matter 63) (7 pages). |
Extended European Search Report (R 61 EPC) dated Feb. 28, 2012 for European Application No. 10150906.5-2315/2208855 corresponding to U.S. Appl. No. 12/643,093, published as US2010-0175882 A1 on Jul. 15, 2010, now US Patent No. 8,322,432 issued Dec. 4, 2012 (our matter 64) (8 pages). |
Canadian Office Action mailed from the Canadian Intellectual Property Office on May 13, 2013 in Application No. 2,690,289, corresponding to U.S. Appl. No. 12/643,093 resulting in US 8,322,432 B2 (2 pages) (our matter 64CA). |
European Office Action mailed from the European Patent Office on May 24, 2013 in Application No. 10 150 906.5-1610, corresponding to U.S. Appl. No. 12/643,093 resulting in US 8,322,432 B2 advising that the Examining Division intends to grant a European patent based on this application (7 pages) (our matter 64EP). |
Number | Date | Country | |
---|---|---|---|
20120318496 A1 | Dec 2012 | US |
Number | Date | Country | |
---|---|---|---|
61205209 | Jan 2009 | US |
Number | Date | Country | |
---|---|---|---|
Parent | 12643093 | Dec 2009 | US |
Child | 13597881 | US |