| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 261 | DEPTH RANGE MANAGER FOR DRILL STRING ANALYSIS | US15109441 | 2014-01-30 | US20160326856A1 | 2016-11-10 | Matthew E. WISE |
| A depth range manager provide users with a way to run and retain multiple depth range analyses for a drill string operation, including the operational parameters for each analysis. This allows users easily to view and compare the analyses at the different drilling depth ranges. In some embodiments, instead of drilling depth ranges, users may also urn and retain multiple different models and analyses using multiple different drilling times. The operational parameters for the multiple different models and analyses may be defined and stored using a flexible one-to-many database structure that accommodates the different sets of operational parameters as well as any existing single-analysis parameters associated with legacy analyses. A graphical interface allows users easily to define and store the operational parameters in the flexible one-to-many database structure. | ||||||
| 262 | METHOD FOR CONDUCTING WELL TESTING OPERATIONS WITH NITROGEN LIFTING, PRODUCTION LOGGING, AND BUILDUP TESTING ON SINGLE COILED TUBING RUN | US15068101 | 2016-03-11 | US20160273347A1 | 2016-09-22 | Steven FIPKE; Mohannad ABDELAZIZ; Harmohan GILL; AbdulHakim ALNAHDI |
| A method for performing a pressure buildup test in an evaluation zone of a well includes the steps of perforating the well in the evaluation zone to allow the flow of hydrocarbon fluids from the reservoir, deploying a pressure buildup test system into the evaluation zone, supplying the lift fluid via the coiled tubing to lift the hydrostatic pressure to lift the hydrocarbon fluids from the evaluation zone toward the surface, moving the packer to the set position, monitoring the pressure data in the evaluation zone, closing the shut-in valve when the stable state of the pressure data is reached, and measuring a buildup pressure in the evaluation zone using the pressure monitoring device. The pressure buildup test system includes a packer, a sub port, a coiled tubing, a shut-in valve, a pressure monitoring device, and a PLT. | ||||||
| 263 | FLUID SUPPLY TO SEALED TUBULARS | US15132998 | 2016-04-19 | US20160230491A1 | 2016-08-11 | 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. | ||||||
| 264 | Control of Multiple Hydraulic Chokes in Managed Pressure Drilling | US14988008 | 2016-01-05 | US20160194927A1 | 2016-07-07 | Walter S. Dillard; Paul R. Northam |
| An assembly is used with a remote source of hydraulic power to control flow of wellbore fluid in a drilling system. At least one choke is operable to control the flow of the fluid to other portions of the system. At least one hydraulic actuator disposed with the choke actuates operation of the choke in response to the hydraulic power. At least one control valve disposed with the choke controls supply of the hydraulic power to and controls return of the hydraulic power from the actuator. An accumulator can be disposed with the choke and coupled to the supply upstream of the control valve. The control valve can couple to the actuator with a pair of pilot-operated check valves disposed in fluid communication between the control valve and the actuator. A stage tank and stage pump can be disposed with the choke. The tank receives the return from the control valve, and the stage pump can pump the return from the stage tank to the source. | ||||||
| 265 | System and method for cooling a rotating control device | US14163617 | 2014-01-24 | US09334711B2 | 2016-05-10 | 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). A sensor measures the temperature in a cavity defined by a rotating control device “RCD” first sealing element and second sealing element, an inner member and a tubular. The RCD cavity is cooled by communicating/supplying or calculating/cooling fluid to the RCD cavity. | ||||||
| 266 | Integrated geomechanics determinations and wellbore pressure control | US13144321 | 2009-10-05 | US09328573B2 | 2016-05-03 | William Bradley Standifird; Syed AiJaz Rizvi; Xiaomin Hu; James R. Lovorn; Sara Shayegi; Nancy Davis; Jeremy Greenwood |
| Well pressure control is integrated in real time with geomechanics determinations made during drilling. A well drilling method includes updating determinations of properties of a formation surrounding a wellbore in real time as the wellbore is being drilled; and controlling wellbore pressure in real time as the wellbore is being drilled, in response to the updated determinations of the formation properties. Another well drilling method includes obtaining sensor measurements in a well drilling system in real time as a wellbore is being drilled; transmitting the sensor measurements to a control system in real time; the control system determining in real time properties of a formation surrounding the wellbore based on the sensor measurements, and the control system transmitting in real time a pressure setpoint to a controller; and the controller controlling operation of at least one flow control device, thereby influencing a well pressure toward the pressure setpoint. | ||||||
| 267 | DUAL CIRCULATION DRILLING SYSTEM | US14976641 | 2015-12-21 | US20160108686A1 | 2016-04-21 | Ian Speer; Warren Strange |
| A ground drill system 10 has a drill string 14 which forms first and second mutually isolated fluid paths 16 and 18 respectively. The drill string 14 has an up hole end 20 coupled to a dual circulation rotation head 22 and a down hole end 24 which is coupled to a drilling tool 12. The drilling tool 12 is operated by the flow of fluid delivered through the first flow path 16. A second fluid outlet 26 is provided intermediate the up hole end 20 and the drilling tool 12. The outlet 26 is in fluid communication with the second fluid flow path 18 and located a constant or fixed distance from the drilling toll 12. The second fluid outlet 26 discharges a flushing fluid flowing through the flushing flow path 18 into a hole being drilled by the drilling system 10. The rotation head 22 provides torque to the drill string 14 and thus the drilling tool 12. | ||||||
| 268 | Systems and methods for managing pressure in a wellbore | US13766959 | 2013-02-14 | US09316054B2 | 2016-04-19 | 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. | ||||||
| 269 | MUD PULSE TELEMETRY WITH CONTINUOUS CIRCULATION DRILLING | US14961364 | 2015-12-07 | US20160084077A1 | 2016-03-24 | JOERG LEHR; Christian FULDA |
| A system for performing a wellbore operation while a fluid circulates in a wellbore may include a string, a fluid circulation system, a control device, The string may include at least a first tubular section and a second tubular section. The a fluid circulating system has a first fluid path and a second fluid path, wherein only one of the first fluid path and the second fluid path circulate the fluid into the string at a specified time. The control device selects one of the first or second fluid path through which to convey the fluid into the string, at least one signal generator in hydraulic communication with the circulating fluid, the at least one signal generator configured to impart at least one pressure signal into the circulating fluid, and at least one pressure transducer in pressure communication with the circulating fluid and configured to detect the imparted at least one pressure signal, wherein the at least one signal generator and the at least one pressure transducer form a communication link, the communication link configured to convey information between at least two locations along a flow path of the circulating drilling fluid, irrespective of the fluid path selected by the control device to convey the fluid into the drill string. | ||||||
| 270 | Continuous circulation and communication drilling system | US13760817 | 2013-02-06 | US09249648B2 | 2016-02-02 | Joerg Lehr |
| An apparatus for performing a wellbore operation includes a drill string having a rigid tubular section formed of a plurality of jointed tubulars and a plurality of valves positioned along the rigid tubular section. Each valve may have a radial valve controlling flow through a wall of the rigid tubular section and a signal relay device configured to convey information-encoded signals. Wellbore operations may be performed by transmitting signals using the signal relay devices. | ||||||
| 271 | USING DYNAMIC UNDERBALANCE TO INCREASE WELL PRODUCTIVITY | US14414454 | 2014-04-02 | US20150337629A1 | 2015-11-26 | Wei Zhang |
| An example underbalance pressure generator device includes a housing having a first end, a second end, and an implosion chamber between the first and second ends, one or more influx ports defined in the housing and enabling fluid communication between the implosion chamber and an exterior of the housing, at least one frangible member fixedly attached to the housing such that a pressure differential can be generated across the at least one frangible member between the implosion chamber and the exterior of the housing, and an actuation device within the housing and configured to rupture the at least one frangible member upon being triggered. | ||||||
| 272 | SYSTEM AND METHOD FOR MANAGING PRESSURE WHEN DRILLING | US14647839 | 2012-12-28 | US20150300110A1 | 2015-10-22 | Neal Gregory Skinner |
| A pressure management device of a drilling system is disclosed. The device includes a housing, a primary bearing package coupled to the housing such that the primary bearing package is not removable from the housing. The primary bearing package is further configured to rotate with respect to the housing. The device also includes a sealing package configured to automatically seal between a drill pipe and the primary bearing package in response to an insertion of the drill pipe through the housing. | ||||||
| 273 | RESERVOIR WELLBORE FLUID | US14414079 | 2013-07-09 | US20150159074A1 | 2015-06-11 | Mark Luyster; Leigh Gray; Sashikumar Mettath; Steven Young; Emanuel Stamatakis |
| In one aspect, embodiments disclosed herein relate to an oil-based wellbore fluid. The oil-based wellbore fluid may include an oleaginous liquid and a surface-modified precipitated silica, wherein the surface-modified precipitated silica comprises a lipophilic coating. In another aspect, embodiments disclosed herein relate to a method of drilling or servicing a well. The method may include circulating a wellbore fluid, such as that described in the paragraph above, into a wellbore, and recovering at least a portion of the wellbore fluid from the wellbore. | ||||||
| 274 | ROTATING CONTROL DEVICE DOCKING STATION | US14604971 | 2015-01-26 | US20150136407A1 | 2015-05-21 | 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. | ||||||
| 275 | Low profile rotating control device | US13621016 | 2012-09-15 | US09004181B2 | 2015-04-14 | Don M. Hannegan; Thomas F. Bailey; James W. Chambers; 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. | ||||||
| 276 | Drilling system and method of operating a drilling system | US13580844 | 2011-02-23 | US08973674B2 | 2015-03-10 | Christian Leuchtenberg |
| A drilling system (10) including a drill string (13) which extends from a floating drilling rig to a well bore, and a tubular riser (12) which surrounds at least part of the portion of the drill string (13) between the well bore and drilling rig, the riser (12) having a telescopic joint (20) between a first tubular portion and a second tubular portion of the riser, the first tubular portion extending down to a well head at the top of the well bore and the second tubular portion extending up towards the drilling rig, the telescopic joint (20) comprising an inner tube part (20b) which is mounted within an outer tube part (20a), the drilling system (10) further including a riser closure device (26) which is mounted in the second tubular portion of the riser (12) and which is operable to provide a substantially fluid tight seal between the riser (12) and the drill string (13) whilst permitting the drill string (13) to rotate relative to the riser (12). | ||||||
| 277 | System and Method for Accessing Subterranean Deposits | US14298520 | 2014-06-06 | US20140299311A1 | 2014-10-09 | Joseph 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. | ||||||
| 278 | Flow stop valve | US13858579 | 2013-04-08 | US08776887B2 | 2014-07-15 | Swietlik George; Large Robert |
| A flow stop valve positionable in a downhole tubular, and a method. The flow stop valve is in a closed position when a pressure difference between fluid outside the downhole tubular and inside the downhole tubular at the flow stop valve is between a threshold value, thereby preventing flow through the downhole tubular. The flow stop valve is in an open position when the pressure difference between fluid outside the downhole tubular and inside the downhole tubular at the flow stop valve is above a threshold value, thereby permitting flow through the downhole tubular. | ||||||
| 279 | Flow stop valve | US13655322 | 2012-10-18 | US08752630B2 | 2014-06-17 | George Swietlik; Robert Large |
| A flow stop valve (20) positionable in a downhole tubular (6), and a method, are provided. 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. 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). | ||||||
| 280 | METHOD AND SYSTEM FOR ACCESSING SUBTERRANEAN DEPOSITS FROM THE SURFACE AND TOOLS THEREFOR | US13965002 | 2013-08-12 | US20130340997A1 | 2013-12-26 | 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. | ||||||
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