| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 101 | REFRACTURING IN A MULTISTRING CASING WITH CONSTANT ENTRANCE HOLE PERFORATING GUN SYSTEM AND METHOD | US15729939 | 2017-10-11 | US20180106136A1 | 2018-04-19 | Wenbo Yang; Philip M. Snider; David Ambler; David Cuthill; John T. Hardesty; David S. Wesson |
| A re-fracturing method using a perforating gun system in a multistring wellbore casing with an inner well casing installed in an outer well casing. The charges in the perforating system includes include a case, a liner positioned within the case, and an explosive filled within the liner. The liner shaped with a subtended angle about an apex of the liner such that a jet formed with the explosive creates an entrance hole in the inner well casing and the outer well casing; the liner having an exterior surface, the exterior surface substantially conical proximate the apex; the subtended angle of the liner ranges from 100° to 120°. The method includes covering the existing openings with the inner casing, perforating with the perforating system and creating constant diameter entrance holes in the outer casing and fracturing through the inner casing and outer casing. | ||||||
| 102 | DUAL CIRCULATION FLUID HAMMER DRILLING SYSTEM | US15550921 | 2015-11-16 | US20180044991A1 | 2018-02-15 | Ian Speer; Warren Strange |
| A dual circulation fluid hammer drilling system (10) has a fluid hammer (12) which is coupled to a drill string (14). The system (10) utilises a first fluid (16) and a second fluid (18). The first fluid (16) is delivered through the drill string (14) to drive or otherwise power the fluid hammer (12). The second fluid (18) is also delivered through the drill string (14) but in isolation of the first fluid (16) so they do not mix within the drill string (14). The second fluid (18) passes through a hammer bit (38) of the hammer drill (12) and is directed to flow out from a bit face (20). Thus when the system (10) is in use the second fluid (18) will flow across the bit face (20). The first fluid (16) also exits the drilling system (10) at the hammer drill (12). However the first fluid (16) exits upstream or up-hole of the bit face (20). | ||||||
| 103 | Fluid supply to sealed tubulars | US15132998 | 2016-04-19 | US09845653B2 | 2017-12-19 | 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. | ||||||
| 104 | Dynamic Underbalanced Drilling technique | US15519548 | 2014-10-30 | US20170254154A1 | 2017-09-07 | Mohamed Hussien Nohamed El-Neiri |
| Overbalanced drilling (OBD) is known to be cheap and simple but formation damage and reduced rate of penetration (ROP) are some of its disadvantages. However, underbalanced drilling (UBD) minimizes formation damage and achieve high ROP, but it is expensive, complex and can't be applied in many cases.This application introduces a new technique that incorporates the advantages and avoids the disadvantages of these drilling systems and is referred to as Dynamic Underbalanced Drilling (DUBD).In DUBD a pressure drop at the environ of the bit, below and around, is created that is restored to normal pressure above the bit and such conditions requires some minor modifications to the design of drill bit. Thus at the zone located below and around the bit underbalance conditions are dominated while the rest of the hole is overbalanced.The anticipated cost of this technique is nearly zero and it is expected to save much of drilling costs. DUBD is expected to provide higher ROP that may exceed ordinary UBD in some cases, so saves time, reduce formation damage, saves costs (cheaper than OBD) and enables gathering information about the reservoir while drilling. This can save some of logging and testing costs. In addition, DUBD may reduce drilling problems, particularly time sensitive problems, and overcome problems of UBD. Furthermore, it can be used safely in over pressurized shale and salt formations, where UBD is not recommended. | ||||||
| 105 | Real Time Conformance | US15300197 | 2015-07-08 | US20170183926A1 | 2017-06-29 | Christopher J. Bernard |
| Methods and systems for identifying and sealing a water zone in a formation employ underbalanced drilling techniques and injection of a conformance fluid into a wellbore drilled thereby. A method includes monitoring a return wellbore fluid in real-time utilizing a fluid analysis system in fluid communication with return wellbore fluids in order to identify the water zone in the formation. When the water zone is identified, drilling is suspended, and the wellbore may be brought to a slightly overbalanced condition. A barrier fluid pill is injected into the wellbore via a drillstring. Immediately following the barrier fluid pill injection, a conformance fluid is injected, “chasing the barrier fluid pill”. Pressures in the drillstring and the wellbore annulus are controlled in order to position the pill. The pill functions as a barrier to contain and assist injection of the conformance fluid into the water zone, thereby sealing the water zone. | ||||||
| 106 | Flow stop valve | US14302150 | 2014-06-11 | US09677376B2 | 2017-06-13 | George Swietlik; Robert Large |
| A flow stop valve positionable in a downhole tubular, and a method, in which 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 below 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, hereby permitting flow through the downhole tubular. | ||||||
| 107 | Well drilling methods with event detection | US12831716 | 2010-07-07 | US09567843B2 | 2017-02-14 | Saad Saeed; Charles M. Pool; Frank Urias; James R. Lovorn; Emad Bakri |
| A drilling method includes assigning values to behaviors of drilling parameters during a drilling operation; forming multiple parameter signatures, each of the parameter signatures comprising a respective combination of the values; comparing the parameter signatures to multiple event signatures, each of the event signatures being indicative of a respective drilling event; and controlling the drilling operation in response to at least a partial match resulting from comparing the parameter signatures to the event signatures. Another method includes defining an event signature comprising a unique combination of a behavior of each of multiple drilling parameters, the event signature being indicative of a drilling event; accessing data from each of multiple sensors which sense the respective drilling parameters during a drilling operation; determining multiple parameter signature segments from the respective sensed drilling parameters; combining the parameter signature segments, thereby forming a parameter signature; and comparing the parameter signature to the event signature. | ||||||
| 108 | METHODS FOR WELL COMPLETION | US15105111 | 2014-12-16 | US20160319651A1 | 2016-11-03 | Harvey Willimas; Jeremy P. Harvey; Andrew J. Martin; Iain Cooper; James Ernest Brown |
| A downhole tool assembly for completing or cleaning a wellbore may include a perforation gun sub, and a laser assembly sub. | ||||||
| 109 | METHOD AND APPARATUS FOR OPTIMIZED UNDERBALANCED DRILLING | US15035479 | 2013-11-27 | US20160290106A1 | 2016-10-06 | Xiaoqian HUANG; Robello SAMUEL |
| The invention concerns a computer implemented method for underbalanced drilling. In one embodiment, the method includes determining a plurality of gas injection rate versus bottom hole pressure curves for a plurality of liquid injection rates for a specified minimum and maximum gas injection rate and a minimum and maximum liquid injection rate. Next, the method determines a set of four interception curves including a minimum motor equivalent liquid rate interception curve, a minimum vertical liquid velocity intercept curve, a minimum horizontal liquid velocity intercept curve, and a maximum motor equivalent liquid rate intercept curve for a specified minimum and maximum mud motor rate range and a minimum horizontal and vertical annulus velocity. | ||||||
| 110 | CONTROL OF MANAGED PRESSURE DRILLING | US14649782 | 2013-12-05 | US20160138350A1 | 2016-05-19 | Kjetil Havre; Ashley Bernard Johnson; Maurice Ringer; Walter David Aldred |
| Method for controlling bottomhole pressure in a borehole during managed pressure drilling. In the drilling procedure fluid is circulated down a drillstring and to surface through an annulus between the drillstring and an inner-wall of the borehole. A compressor/pump is used to inject gas into the returning drilling fluid at a gas injection point. The method comprises receiving a target bottomhole pressure; determining actual bottomhole pressure during the procedure; and adjusting a variable as directed by a feedback controller, which operates to reduce the difference between the target pressure and the measured pressure. The manipulated variable may be one or any combination of: (1) pressure of drilling fluid at the entry of the fluid into the drillstring, (2) the flow rate of drilling fluid out of the drillstring into the annulus, (3) pressure of the gas exiting from the compressor, and (4) the injection rate of the gas. | ||||||
| 111 | REMOTELY OPERATED ISOLATION VALVE | US14885024 | 2015-10-16 | US20160090818A1 | 2016-03-31 | Joe NOSKE; Roddie R. SMITH; Paul L. SMITH; Thomas F. BAILEY; Christopher L. MCDOWELL |
| A shifting tool for use in a wellbore includes a tubular housing having a bore formed therethrough; a tubular mandrel disposed in the housing and longitudinally movable relative thereto; and an engagement member moveable relative to the housing between an extended position, a released position, and a retracted position, wherein: the engagement member is movable from the retracted position to the extended position in response to movement of the mandrel relative to the housing, and the engagement member is further movable from the extended position to the released position in response to movement of the mandrel relative to the housing. | ||||||
| 112 | System and method for managing heave pressure from a floating rig | US14517377 | 2014-10-17 | US09260927B2 | 2016-02-16 | Don M. Hannegan; Thomas F. Bailey; Simon J. Harrall |
| A system compensates for heave induced pressure fluctuations on a floating rig when a drill string or tubular is lifted off bottom and suspended on the rig, such as when tubular connections are made during MPD, tripping, or when a kick is circulated out during conventional drilling. The system also compensates for heave induced pressure fluctuations on a floating rig when a riser telescoping joint located below a RCD is moving while drilling. | ||||||
| 113 | APPARATUS AND METHOD FOR CONTROLLING PRESSURE IN A BOREHOLE | US14404863 | 2012-10-24 | US20150275602A1 | 2015-10-01 | Ivar Kjøsnes; Nils Lennart Rolland |
| There is described a technique for drilling and controlling the fluid pressure of a borehole (2, 102) during drilling of the borehole. In embodiments of the invention, drill pipe (5) may be arranged in said borehole, the pipe being configured to provide drilling fluid in the borehole. Sealing means (14, 18, 114, 118) may be provided and arranged to sealingly abut an outer surface of the drill pipe to separate said drilling fluid in the borehole on a first side of the sealing means from a column of fluid on a second side of the sealing means. Furthermore, a subsea pump arrangement (12, 112) may be arranged under a sea surface where it receives a flow of said drilling fluid from the borehole. The pump arrangement can operate to pump drilling fluid out of the pump arrangement, and generate a fluid pressure in said drilling fluid at a location upstream of the pump arrangement, said generated pressure being less than or equal to the hydrostatic pressure of said column of fluid on said second side of the sealing means. | ||||||
| 114 | Riser auxiliary line jumper system for rotating control device | US14106050 | 2013-12-13 | US09074425B2 | 2015-07-07 | 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. | ||||||
| 115 | Managed pressure drilling | US11254993 | 2005-10-20 | US08955619B2 | 2015-02-17 | Frederick T. Tilton; David M. Haugen; Kevin W. Smith; David J. Brunnert; Thomas F. Bailey; Tom Fuller; Roy W. Rooyakkers; Ram K. Bansal; Graham Skinner |
| Embodiments of the present invention include methods and apparatus for dynamically controlling pressure within a wellbore while forming the wellbore. In one aspect, one or more pressure control apparatus are used to maintain desired pressure within the wellbore while drilling the wellbore. In another aspect, pressure is dynamically controlled while drilling using foam to maintain a substantially homogenous foam flow regime within the wellbore annulus for carrying cuttings from the wellbore. | ||||||
| 116 | System and Method for Managing Heave Pressure from a Floating Rig | US14517377 | 2014-10-17 | US20150034326A1 | 2015-02-05 | Don M. Hannegan; Thomas F. Bailey; Simon J. Harrall |
| A system compensates for heave induced pressure fluctuations on a floating rig when a drill string or tubular is lifted off bottom and suspended on the rig, such as when tubular connections are made during MPD, tripping, or when a kick is circulated out during conventional drilling. In one embodiment, a liquid and a gas interface moves along a flow line between a riser and a gas accumulator as the tubular moves up and down. In another embodiment, a pressure relief valve or adjustable choke allows the movement of fluid from the riser when the tubular moves down, and a pump with a pressure regulator moves fluid to the riser when the tubular moves up. In other embodiments, a piston connected with the rig or the riser telescoping joint moves in a fluid container thereby communicating a required amount of the fluid either into or out of the riser annulus. The system also compensates for heave induced pressure fluctuations on a floating rig when a riser telescoping joint located below a RCD is moving while drilling. | ||||||
| 117 | Methods for increase gas production and load recovery | US12464351 | 2009-05-12 | US08946130B2 | 2015-02-03 | Frank Zamora; Sarkis R. Kakadjian; Erin Fitzgerald; Tina Garza |
| Methods are disclosed for improved sand control, fines control, load recovery and well productivity, where the compositions comprise reaction products of an amine and a phosphate-containing compound. | ||||||
| 118 | Rotating control device docking station | US14188165 | 2014-02-24 | US08939235B2 | 2015-01-27 | 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. | ||||||
| 119 | Method and apparatus for installing a wireline for logging or other operations in an under-balanced well | US13002819 | 2009-07-20 | US08899338B2 | 2014-12-02 | Salem Lotfi Elsayed; Waqar Khan |
| An improved apparatus and a method to insert a wireline through a blow out preventer to log an underbalanced open hole well without killing the well or causing formation damage while maintaining well control during the process. A dual throated blow out preventer (10) provides a moveable sealing element (1210, 1402) to allow a wireline (13) and a drill string (25) to be placed in a well for assembly, then seals off the dual throat to isolate the drill string from the wireline, thereby permitting pressure to be maintained on both the wireline through a standard packoff arrangement (1218) and on the drill string using the rams of the blow out preventer (10). | ||||||
| 120 | Managed pressure and/or temperature drilling system and method | US12278692 | 2007-02-09 | US08881843B2 | 2014-11-11 | Richard J. Todd; Don M. Hannegan; Simon J. Harrall |
| The present invention relates to a managed pressure and/or temperature drilling system (300) and method. In one embodiment, a method for drilling a wellbore into a gas hydrates formation is disclosed. The method includes drilling the wellbore into the gas hydrates formation; returning gas hydrates cuttings to a surface of the wellbore and/or a drilling rig while controlling a temperature and/or a pressure of the cuttings to prevent or control disassociation of the hydrates cuttings. | ||||||
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