| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 121 | METHODS AND APPARATUS FOR WELLBORE CONSTRUCTION AND COMPLETION | US14289433 | 2014-05-28 | US20140326454A1 | 2014-11-06 | Richard L. GIROUX; Gregory G. GALLOWAY; Patrick G. MAGUIRE; Tuong Thanh LE; Albert C. ODELL, II; David M. HAUGEN; Frederick T. TILTON; Brent J. LIRETTE; David J. BRUNNERT |
| The present invention relates methods and apparatus for lining a wellbore. In one aspect, a drilling assembly having an earth removal member and a wellbore lining conduit is manipulated to advance into the earth. The drilling assembly includes a first fluid flow path and a second fluid flow path. Fluid is flowed through the first fluid flow path, and at least a portion of which may return through the second fluid flow path. In one embodiment, the drilling assembly is provided with a third fluid flow path. After drilling has been completed, wellbore lining conduit may be cemented in the wellbore. | ||||||
| 122 | Method and system for accessing subterranean deposits from the surface and tools therefor | US13965002 | 2013-08-12 | US08813840B2 | 2014-08-26 | Joseph A. Zupanick |
| According to one embodiment, a system for accessing a subterranean zone from the surface includes a well bore extending from the surface to the subterranean zone, and a well bore pattern connected to the junction and operable to drain fluid from a region of the subterranean zone to the junction. | ||||||
| 123 | RISER AUXILIARY LINE JUMPER SYSTEM FOR ROTATING CONTROL DEVICE | US14106050 | 2013-12-13 | US20140178155A1 | 2014-06-26 | Guy F. FEASEY |
| A method for deploying a marine riser includes: assembling a rotating control device (RCD) spool with the marine riser; lowering the RCD spool through a rotary table of a drilling rig and into a moonpool of an offshore drilling unit; connecting a hose to an upper and lower adapter of the RCD spool in the moonpool; and lowering the RCD spool and the connected hose through the moonpool. | ||||||
| 124 | Rotating Control Device Docking Station | US14188165 | 2014-02-24 | US20140166273A1 | 2014-06-19 | Thomas F. Bailey; 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. | ||||||
| 125 | Method and apparatus for performing wireline logging operations in an under-balanced well | US12921874 | 2009-03-16 | US08726983B2 | 2014-05-20 | Waqar Khan |
| A method and an apparatus log an underbalanced open hole well without killing the well or causing formation damage to maintain well control during the process. The installation of the well logging equipment is accomplished while holding the underbalanced open hole at its optimal pressure, then conveying the logging string on a drill string into the open hole portion to total depth and logging while removing the logging string from the total depth to be logged with a cable side entry sub. The invention also provides a unique configuration of equipment to accomplish the logging using what is normally referred to as tough logging condition techniques. | ||||||
| 126 | System for drilling a borehole | US13836569 | 2013-03-15 | US08701796B2 | 2014-04-22 | Thomas F. Bailey; James W. Chambers; Danny W. Wagoner |
| A rotating control device is remotely hydraulically latched and unlatched with a docking station housing for use and removal, respectively. 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 an active seal. A first sensor and a second sensor can be used to detect temperature, pressure and density of the supplied fluid at different locations and this data can be compared using a central processing unit (CPU). Also, a sensor can be used to detect the revolutions per minute of a rotating seal of the rotating control device and fluid can be provided to the rotating control device responsive to the detected revolutions per minute. | ||||||
| 127 | Rotating control system and method for providing a differential pressure | US13735203 | 2013-01-07 | US08636087B2 | 2014-01-28 | Don M. Hannegan; Thomas F. Bailey; Melvin T. Jacobs; Nicky A. White; Carel W. Hoyer |
| 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. | ||||||
| 128 | SYSTEMS AND METHODS FOR MANAGING PRESSURE IN A WELLBORE | US13766959 | 2013-02-14 | US20130206423A1 | 2013-08-15 | Charles W. Weinstock; Mingqin Duan |
| A method for drilling a subsea well from a rig through a subsea wellhead below the rig includes employing a single gradient or dual gradient drilling system that includes a drill string that extends from the rig into the well and surface mud pumps for pumping drilling fluid through the drill string and into a well annulus of the well. The drilling system includes a subsea rotating device for conducting the drilling fluid from the well annulus and through a solids processing unit. A subsea pump then conducts the drilling fluid from the solids processing unit to a return line back to the rig. The surface mud pump and subsea pump are staged in coordination to trap pressure and/or remove pressure in the well annulus to maintain a selected pressure gradient in the well annulus. | ||||||
| 129 | System for Drilling a Borehole | US13836569 | 2013-03-15 | US20130206386A1 | 2013-08-15 | Thomas F. Bailey; James W. Chambers; Danny W. Wagoner |
| A rotating control device is remotely hydraulically latched and unlatched with a docking station housing for use and removal, respectively. 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 an active seal. A first sensor and a second sensor can be used to detect temperature, pressure and density of the supplied fluid at different locations and this data can be compared using a central processing unit (CPU). Also, a sensor can be used to detect the revolutions per minute of a rotating seal of the rotating control device and fluid can be provided to the rotating control device responsive to the detected revolutions per minute. | ||||||
| 130 | System for drilling under balanced wells | US12930119 | 2010-12-29 | US08459376B2 | 2013-06-11 | Danny T. Williams |
| A system for drilling a well bore with an under-balanced hydrostatic pressure. The system includes a tubular member containing a first port, a compression member disposed about the outer portion of the tubular member and having an internal sliding mandrel extending therefrom with a second port, an external sliding sleeve having a third port and being in contact with the internal sliding mandrel and operatively associated with the internal sliding mandrel, and a compressible seal disposed about the external sliding mandrel that is responsive to a longitudinal weight transferred to the compression member. In a closed position the first, second and third port are misaligned and in an open position the first, second and third ports are aligned. | ||||||
| 131 | Low Profile Rotating Control Device | US13621016 | 2012-09-15 | US20130009366A1 | 2013-01-10 | Don M. Hannegan; Thomas F. Bailey; James W. Chambers; David R. Woodruff; Simon J. Harrall |
| A system and method is provided for a law 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. | ||||||
| 132 | Drilling with a high pressure rotating control device | US12462266 | 2009-07-31 | US08347983B2 | 2013-01-08 | 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 Pressured 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 facture 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. | ||||||
| 133 | Low profile rotating control device | US11975946 | 2007-10-23 | US08286734B2 | 2012-10-16 | Don M. Hannegan; Thomas F. Bailey; James W. Chambers; David R. Woodruff; Simon J. Harrall |
| A system and method are 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 outer diameter of the lateral outlet flange may be substantially the same as the height of the LP-RCD housing and bearing assembly after the bearing assembly is positioned with the LP-RCD housing. The sealing element may be aligned with the lateral outlet, and may be replaced from above. Different embodiments of attachment members for attaching the LP-RCD housing with a lower housing allow the LP-RCD housing to be rotated to align the lateral outlet with the drilling rig's existing line to mud pits or other locations. In one embodiment, the LP-RCD bearings are positioned radially inside the LP-RCD housing. In another embodiment, the LP-RCD bearings are positioned radially outside the LP-RCD housing. One embodiment allows rotation of the inserted tubular about multiple planes. In still another embodiment, an annular BOP seal is integral with a RCD housing. | ||||||
| 134 | METHODS AND APPARATUS FOR WELLBORE CONSTRUCTION AND COMPLETION | US13306592 | 2011-11-29 | US20120138298A1 | 2012-06-07 | Richard L. Giroux; Gregory G. Galloway; David J. Brunnert; Patrick G. Maguire; Tuong Thanh Le; Albert C. Odell, II; David M. Haugen; Frederick T. Tilton; Brent J. Lirette; Mark Murray; Peter Barnes Moyes |
| The present invention relates methods and apparatus for lining a wellbore. In one aspect, a drilling assembly having an earth removal member and a wellbore lining conduit is manipulated to advance into the earth. The drilling assembly includes a first fluid flow path and a second fluid flow path. Fluid is flowed through the first fluid flow path, and at least a portion of which may return through the second fluid flow path. In one embodiment, the drilling assembly is provided with a third fluid flow path. After drilling has been completed, wellbore lining conduit may be cemented in the wellbore. | ||||||
| 135 | Method and Apparatus for Detecting while Drilling Underbalanced The Presence and Depth of Water Produced from The Formation and for Measuring Parameters Related Thereto | US13358502 | 2012-01-25 | US20120119076A1 | 2012-05-17 | John Edwards; Christian Stoller; Peter Wraight; Roger Griffiths; Nicolas Renoux |
| The invention relates to methods and apparatus for determining a downhole parameter in an underbalanced drilling environment which include: selectively activating a first fluid flowing from the formation through a wellbore while under balanced drilled; detecting the activated first fluid, and determining a depth at which said fluid enters the wellbore. | ||||||
| 136 | Enhanced oil-based foam drilling fluid compositions and method for making and using same | US12167087 | 2008-07-02 | US08141661B2 | 2012-03-27 | Sarkis R. Kakadjian; Olusegun M. Falana; Edward Marshall; Michael DiBiasio; Frank Zamora |
| New oil-based foam drilling fluids for oil and/or gas wells include a base oil, a foaming agent and a polymer including at least one aromatic olefin monomer and at least one diene monomer. The polymer improves foam properties rendering a foam stable at temperatures at or above 350° F. | ||||||
| 137 | REMOTELY OPERATED ISOLATION VALVE | US13237347 | 2011-09-20 | US20120067595A1 | 2012-03-22 | Joe Noske; Roddie R. Smith; Paul L. Smith; Thomas F. Bailey; Christopher L. McDowell |
| A method of operating an isolation valve in a wellbore includes: deploying a work string into the wellbore through a tubular string disposed in the wellbore. The work string comprises a deployment string, a shifting tool, and a bottomhole assembly (BHA). The tubular string comprises the isolation valve and an actuator. The method further includes rotating the actuator using the shifting tool, thereby opening or closing the isolation valve. The isolation valve isolates a formation from an upper portion of the wellbore in the closed position. | ||||||
| 138 | Annulus pressure control drilling systems and methods | US12949170 | 2010-11-18 | US08122975B2 | 2012-02-28 | Gary Belcher; Adrian Steiner; Kevin Schmigel; David Brunnert; Darcy Nott; Richard Todd; Jim Stanley; Simon Harrall |
| In one embodiment, a method for drilling a wellbore includes an act of drilling the wellbore by injecting drilling fluid through a tubular string disposed in the wellbore, the tubular string comprising a drill bit disposed on a bottom thereof. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The drilling fluid and cuttings (returns) flow to a surface of the wellbore via an annulus defined by an outer surface of the tubular string and an inner surface of the wellbore. The method further includes an act performed while drilling the wellbore of measuring a first annulus pressure (FAP) using a pressure sensor attached to a casing string hung from a wellhead of the wellbore. The method further includes an act performed while drilling the wellbore of controlling a second annulus pressure (SAP) exerted on a formation exposed to the annulus. | ||||||
| 139 | ANNULUS PRESSURE SETPOINT CORRECTION USING REAL TIME PRESSURE WHILE DRILLING MEASUREMENTS | US13116082 | 2011-05-26 | US20110303462A1 | 2011-12-15 | James R. LOVORN; Saad SAEED; Nancy DAVIS |
| A method of controlling pressure in a wellbore can include determining a real time wellbore pressure PwbRT1 at a pressure sensor in the wellbore, calculating hydrostatic pressure Ph1 at the pressure sensor, determining a real time annulus pressure PaRT, calculating friction pressure Pf due at least to circulation of the fluid through the wellbore and depth in the wellbore, calculating a friction pressure correction factor CFPf1 equal to (PwbRT1−Ph1−PaRT)/Pf, and controlling operation of a pressure control device, based on the friction pressure correction factor CFPf1. The method can further include determining a desired wellbore pressure PwbD1 at the pressure sensor, calculating an annulus pressure setpoint PaSP1 equal to PwbD1−Ph1−(Pf*CFPf1), and adjusting the pressure control device as needed to maintain PaRT equal to PaSP1. | ||||||
| 140 | Permanent downhole deployment of optical sensors | US12631541 | 2009-12-04 | US07997340B2 | 2011-08-16 | Francis X. Bostick, III; David G. Hosie; Michael Brian Grayson; Ram K. Bansal |
| The present invention involves methods and apparatus for permanent downhole deployment of optical sensors. Specifically, optical sensors may be permanently deployed within a wellbore using a casing string. In one aspect, one or more optical sensors are disposed on, in, or within the casing string. The optical sensors may be attached to an outer surface of the casing string or to an inner surface of the casing string, as well as embedded within a wall of the casing string. The optical sensors are capable of measuring wellbore parameters during wellbore operations, including completion, production, and intervention operations. | ||||||
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