| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 141 | Rotating control device docking station | US12080170 | 2008-03-31 | US07926593B2 | 2011-04-19 | Thomas F. Bailey; Don M. Hannegan; James W. Chambers; Danny W. Wagoner |
| A system and method is provided for converting a drilling rig between conventional hydrostatic pressure drilling and managed pressure drilling or underbalanced drilling using a docking station housing mounted on a marine riser or bell nipple. This docking station housing may be positioned above the surface of the water. When a removable rotating control device is remotely hydraulically latched with the docking station housing, the system and method allows for interactive lubrication and cooling of the rotating control device, as needed, along with a supply of fluid for use with active seals. | ||||||
| 142 | Interlocking Low Profile Rotating Control Device | US12893391 | 2010-09-29 | US20110036638A1 | 2011-02-17 | Jonathan P. Sokol; Danny W. Wagoner; Thomas F. Bailey; Aristeo Rios, III; James W. Chambers; Don M. Hannegan |
| A system and method is provided for a low profile rotating control device (LP-RCD) and its housing mounted on or integral with an annular blowout preventer seal, casing, or other housing. The LP-RCD and LP-RCD housing can fit within a limited space available on drilling rigs. An embodiment allows a LP-RCD to be removably disposed with a LP-RCD housing by rotating a bearing assembly rotating plate. A sealing element may be removably disposed with the LP-RCD bearing assembly by rotating a seal retainer ring. Alternatively, a sealing element may be removably disposed with the LP-RCD bearing assembly with a seal support member threadedly attached with the LP-RCD bearing assembly. The seal support member may be locked in position with a seal locking ring removably attached with threads with the LP-RCD bearing assembly over the seal support member. Spaced apart accumulators may be disposed radially outward of the bearings in the bearing assembly to provide self lubrication to the bearings. | ||||||
| 143 | FLOW STOP VALVE | US12867595 | 2009-02-16 | US20110036591A1 | 2011-02-17 | Swietlik George; Large Robert |
| A flow stop valve (20) positioned in a downhole tubular (6), wherein: the flow stop valve (20) is in a closed position when a pressure difference between fluid outside the downhole tubular (6) and inside the downhole tubular (6) at the flow stop valve (20) is below a threshold value, thereby preventing flow through the downhole tubular; and the flow stop valve (20) is in an open position when the pressure difference between fluid outside the downhole tubular (6) and inside the downhole tubular (6) at the flow stop valve (20) is above a threshold value, thereby permitting flow through the downhole tubular (6). | ||||||
| 144 | Drilling with a high pressure rotating control device | US12462266 | 2009-07-31 | US20110024195A1 | 2011-02-03 | Carel W. Hoyer; Don M. Hannegan; Thomas F. Bailey; Melvin T. Jacobs; Nicky A. White |
| A Drill-To-The-Limit (DTTL) drilling method variant to Managed Pressure Drilling (MPD) applies constant surface backpressure, whether the mud is circulating (choke valve open) or not (choke valve closed). Because of the constant application of surface backpressure, the DTTL method can use lighter mud weight that still has the cutting carrying ability to keep the borehole clean. The DTTL method identifies the weakest component of the pressure containment system, such as the fracture pressure of the formation or the casing shoe leak off test (LOT). With a higher pressure rated RCD, such as 5,000 psi (34,474 kPa) dynamic or working pressure and 10,000 psi (68,948 kPa) static pressure, the limitation will generally be the fracture pressure of the formation or the LOT. In the DTTL method, since surface backpressure is constantly applied, the pore pressure limitation of the conventional drilling window can be disregarded in developing the fluid and drilling programs. Using the DTTL method a deeper wellbore can be drilled with larger resulting end tubulars, such as casings and production liners, than had been capable with conventional MPD applications. | ||||||
| 145 | METHODS FOR CUTTINGS FOR A WIRELINE DRILLING TOOL | US12742477 | 2008-11-14 | US20100294569A1 | 2010-11-25 | Walter Aldred; Iain Cooper; Paul Hammond |
| A method of removing cuttings from a workfront of a lateral borehole hole being drilled from a main borehole by a drilling tool is provided. The drilling tool comprising a tool body including a motor, an axial drive mechanism for advancing the tool body in the well, and a drill bit powered by the motor for drilling the underground formation at the workface and producing cuttings as the tool is advanced. The drilling tool is preferably connected to the surface by means of a cable extending through the lateral borehole and main borehole. The method independently comprising transporting the drilled cuttings from the workface to the part of the lateral borehole immediately behind the drilling tool. Transporting the drilled cuttings from immediately behind the drilling tool to the junction of the lateral borehole and the main well. And transporting the cuttings from the junction to a place of disposal. | ||||||
| 146 | Method of drilling a well at or under balance using a electrical submersible pump | US11661301 | 2005-08-15 | US07836977B2 | 2010-11-23 | Philip Head |
| A drilling system for use in a well bore consists of a drill string, an electrically powerable pump (8), a connector (16) for supporting the pump (8) including a through bore (32) through which fluid can flow, and a power cable (15) to provide power to the electrically powerable pump. The cuttings are pumped up through the drillpipe (3). The drill bit (4) may also be powered by the pump. Part of the cable is disposed externally to the drill string where new pipe sections are added, before passing into the drill string through a cross-over means (40) further down the drillpipe to connect to the electrically powerable pump. | ||||||
| 147 | Sub-Surface Deployment Valve | US11991857 | 2006-09-07 | US20100163309A1 | 2010-07-01 | Philip Head |
| A sub surface deployment valve which is particularly suitable for use in underbalanced drilling operations which can be installed through an existing tubular string comprises a radially expandable body (1) having an internal bore and a valve element (2) capable of closing off the internal bore. The deployment valve can be installed by passing the valve through the existing tubular and then radially expanding the radially expandable body of the deployment valve to form a connection resulting from the interference between the external surface of the deployment valve and the tubular string. | ||||||
| 148 | Particle Drilling System Having Equivalent Circulating Density | US12641720 | 2009-12-18 | US20100155063A1 | 2010-06-24 | Gordon A. Tibbitts; Greg Galloway; Adriane Vuyk, JR.; Jim Terry |
| An injection system and method is described. In several exemplary embodiments, the injection system and method may be a part of, and/or used with, a system and method for excavating a subterranean formation. The system and method include a low density material injection to lower the circulating fluid equivalent circulating density. | ||||||
| 149 | Method and device for controlling drilling fluid pressure | US10580825 | 2004-11-24 | US07677329B2 | 2010-03-16 | Roger Stave |
| A method of reducing drilling fluid pressure during subsea drilling, where drilling fluid is pumped down into a borehole and then flows back to a drilling rig via the lined and/or unlined sections of the borehole and a liner, wherein the drilling fluid pressure is controlled by pumping drilling fluid out of the liner at the seabed, and where the liner annulus above the drilling fluid is filled with a riser fluid having a density different from that of the drilling fluid. | ||||||
| 150 | CONTROLLING TRANSIENT UNDERBALANCE IN A WELLBORE | US12562862 | 2009-09-18 | US20100044044A1 | 2010-02-25 | Ashley B. Johnson; Lawrence A. Behrmann; Wenbo Yang; Fokko Harm Cornelis Doornbosch; Ian C. Walton |
| A method of perforating a well includes selecting a desired transient underbalanced condition, configuring a perforating gun string to achieve the transient underbalanced condition, deploying the perforating gun is a wellbore, and firing the perforating to achieve the transient underbalanced condition. | ||||||
| 151 | Closed loop multiphase underbalanced drilling process | US12027071 | 2008-02-06 | US07654319B2 | 2010-02-02 | Gregory H. Chitty; Jeffrey Charles Saponja; David Graham Hosie |
| The present invention provides apparatus and methods for handling fluids returning from a well. The fluids are introduced into a separator and a separated gas stream is recovered or recycled. The gas stream may comprise more than one phase. The separated gas stream is urged through a multiphase pump before it is recovered. Alternatively, the return fluids may pass through a multiphase pump before it is introduced into the separator. | ||||||
| 152 | Incremental U-tube process to retrieve of bottom hole assembly during casing while drilling operations | US12125808 | 2008-05-22 | US07604057B1 | 2009-10-20 | Erik P. Eriksen; Michael E. Moffitt; Tommy M. Warren |
| A bottom hole assembly is retrieved through a casing string by lightening the density of the drilling fluid in the casing string above the bottom hole assembly to a lesser density than the drilling fluid in the casing string annulus. The bottom hole assembly moves upward in the casing string in response to an upward force created by the different densities of fluid. While moving upward, less dense fluid being displaced by the upward movement of the bottom hole assembly flows from the casing string. When the bottom hole assembly stops moving upward, slips suspended it at that intermediate point in the casing string. The operator now lightens the density of the drilling fluid in the casing string below the bottom hole assembly, again creating an upward force on the bottom hole assembly that causes the bottom hole assembly to move upward in the casing string. | ||||||
| 153 | Drill string flow control valves and methods | US11788660 | 2007-04-20 | US07584801B2 | 2009-09-08 | Luc deBoer |
| Drill string flow control valves and more particularly, drill string flow control valves for prevention of u-tubing of fluid flow in drill strings are provided. Drill string flow control valves may comprise a valve housing, a valve sleeve axially movable within a valve housing from a closed position to an open position, a biasing mechanism for biasing the valve sleeve into the closed position, and a plurality of pressure ports for allowing a differential pressure to be exerted on the valve sleeve. The differential pressure exerted on the valve sleeve may be the result of an upstream pressure and a downstream pressure. By allowing a differential pressure resulting from a fluid flow to act on the valve sleeve, u-tubing in a drill string can be prevented or substantially reduced. Methods of use are also provided. | ||||||
| 154 | System for drilling under-balanced wells | US12069458 | 2008-02-11 | US20090200085A1 | 2009-08-13 | Danny T. Williams |
| A system and method for drilling a well bore with an under-balanced hydrostatic pressure. The system comprises a tubular containing a first port and wherein a well bore annulus is formed between the well bore and the tubular member, and a compression member disposed about the outer portion of the tubular member, the compression member having extending therefrom an internal sliding mandrel, and wherein the internal sliding mandrel contains a second port. The system further comprises an external sliding sleeve operatively associated with the internal sliding mandrel, wherein the external sliding sleeve containing a third port, and wherein in a closed position the first, second and third port are misaligned and in an open position the first, second and third port are aligned. The system also includes a compressible seal disposed about the external sliding sleeve and in contact with the internal sliding mandrel, the compressible seal responsive to a longitudinal weight transferred to the compression member. Also, a work string may be included, with the work string positioned within the tubular, with the work string having a drill bit attached at a distal end of the work string, and wherein a work string annulus is formed relative to the tubular and the work string. | ||||||
| 155 | Low profile rotating control device | US11975946 | 2007-10-23 | US20090101411A1 | 2009-04-23 | Don M. Hannegan; Thomas F. Bailey; James W. Chambers; David R. Woodruff; Simon J. Harrall |
| A system and method is provided for a low profile rotating control device (LP-RCD) and its housing mounted on or integral with an annular blowout preventer seal, casing, or other housing. The LP-RCD and LP-RCD housing can fit within a limited space available on drilling rigs. | ||||||
| 156 | Under-balanced directional drilling system | US11598555 | 2006-11-13 | US07493951B1 | 2009-02-24 | Stephen J. Kravits; Bruce D. Rusby; John K. Wood |
| A production well arrangement that includes a vertical main well extending into a gas producing strata and an access hole having a vertical portion coupled to a curved portion, which is coupled to a lateral portion. The vertical portion has an upper end defined on the ground surface and is laterally offset from the vertical main well. The lateral portion has a lateral end intersecting the vertical main well at an intersection point positioned between an upper end and lower end of the vertical main well, wherein the lateral end of the lateral portion does not extend beyond the vertical main well. One or more laterally extending holes extends from an intercepted zone defined on the access hole, which is upstream of the intersection point, wherein the one or more laterally extending holes do not intersect the vertically extending well. | ||||||
| 157 | Method and system for return of drilling fluid from a sealed marine riser to a floating drilling rig while drilling | US10807091 | 2004-03-23 | US07448454B2 | 2008-11-11 | Darryl A. Bourgoyne; Don M. Hannegan |
| A floating rig or structure for drilling in the floor of an ocean using a rotatable tubular includes a seal housing having a rotatable seal connected above a portion of a marine riser fixed to the floor of the ocean. The seal rotating with the rotating tubular allows the riser and seal housing to maintain a predetermined pressure in the system that is desirable in underbalanced drilling, gas-liquid mud systems and pressurized mud handling systems. The seal is contemplated to be either an active seal or a passive seal. A flexible conduit or hose is used to compensate for relative movement of the seal housing and the floating structure because the floating structure moves independent of the seal housing. A method for use of the system is also disclosed. | ||||||
| 158 | METHOD AND APPARATUS FOR PROGRAMMABLE PRESSURE DRILLING AND PROGRAMMABLE GRADIENT DRILLING, AND COMPLETION | US11968010 | 2007-12-31 | US20080264690A1 | 2008-10-30 | Waqar Khan; Geoff Downton |
| A method for creating a programmable pressure zone adjacent a drill bit bottom hole assembly by sealing near a drilling assembly, adjusting the pressure to approximately or slightly below the pore pressure of the well bore face to permit flow out of the formation, and, while drilling, adjusting by pumping out of, or choking fluid flow into, the drilling assembly between the programmable pressure zone and the well bore annulus to avoid overpressuring the programmable pressure zone unless required to control the well. | ||||||
| 159 | Well treatment system and method | US11609425 | 2006-12-12 | US07428921B2 | 2008-09-30 | Brenden M. Grove; Mark C. Duhon; Lawrence A. Behrmann; Claude D. Jones |
| A well treatment system of the present invention includes a housing forming a sealed surge chamber, and a surge charge disposed within the sealed surge chamber, wherein the surge charge is adapted upon activation to penetrate the housing and to not penetrate material exterior of the housing. Fluid communication is created between the surge chamber and the wellbore when the housing is penetrated by the surge charge. The penetration permits wellbore fluid to flow quickly into the surge chamber. Fluid flow into the surge chamber may enhance a surge of flow from the formation into the wellbore. | ||||||
| 160 | Drilling system and method | US11264020 | 2005-11-02 | US07367411B2 | 2008-05-06 | Christian Leuchtenberg |
| A closed-loop circulating system for drilling wells has control of the flow rates in and out of the wellbore. Kicks and fluid losses are quickly controlled by adjusting the backpressure. Kick tolerance and tripping margins are eliminated by real-time determination of pore and fracture pressure. The system can incorporate a rotating BOP and can be used with underbalanced drilling. | ||||||
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