| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 181 | Method and apparatus for determining fluid circulation conditions in well drilling operations | US751930 | 1985-07-05 | US4610161A | 1986-09-09 | George F. Gehrig; Jerry M. Speers |
| A method and apparatus for establishing the rate at which fluid is transferred between an offshore well 16 and the formations 20 surrounding the well 16 in the course of drilling the well 16 from a floating drilling rig 14. A drilling fluid handling system 31 is used to inject drilling fluid into the well 16. A marine riser 22 extending from the sea bottom 18 to the rig 14 is provided to return the drilling fluid to the rig 14. The riser 22 is provided with a slip joint 26 to accommodate wave induced heave of the rig 14. Inflow and outflow flowmeters 42,44 are provided to monitor the rates at which drilling fluid is injected into the well 16 and returned to the rig 14. The return flow rate signal is filtered to mitigate the cyclical variations resulting from extension and contraction of the slip joint 26. A signal processing system 46 is provided to maintain the time constant applied in the filtering process at an optimum level as the rate and magnitude of rig heave varies with time. The input and filtered output signals are combined to yield a differential flow signal which is compared to a preselected alarm limit to determine if excessive fluid transfer between the well 16 and surrounding formations 20 is occurring. | ||||||
| 182 | Diverter system and blowout preventer | US569780 | 1984-01-10 | US4546828A | 1985-10-15 | Joseph R. Roche |
| A system is disclosed which may alternatively be used as a diverter or as a blowout preventer for a drilling rig. The system comprises a BOP attached above a spool having a hydraulically driven sleeve/piston. An outlet passage in the spool, which may be connected to a vent line, is closed off by the sleeve wall when the spool piston is at rest.Hydraulic ports are connected above and below the BOP annular piston and above and below the spool annular piston. The ports below the BOP piston and above the spool piston are in fluid communication with each other. A hydraulic circuit is provided having two valves between a source and a drain of pressurized hydraulic fluid. | ||||||
| 183 | Deep water hydrostatic head control | US553772 | 1983-11-21 | US4495999A | 1985-01-29 | James H. Sykora |
| Hydrostatic head control in the marine riser or sub-sea BOP stack of a deep water drilling unit is maintained through use of an eductor, or similar means, connected to the sub-sea BOP stack kill line for drawing salt water from the sea or mud from the sub-sea BOP stack choke line. | ||||||
| 184 | Well control method and apparatus | US461645 | 1983-01-27 | US4478287A | 1984-10-23 | Joseph H. Hynes; Hubert L. Elkins |
| A method and apparatus is disclosed for controlling a well drilled from a floating drilling vessel during the time that the marine riser is removed and conductor casing is being lowered and cemented into the well. An annular blowout preventer having a bore substantially equal to that of the structural casing is provided in a stack above the structural casing wellhead. A kill line is provided to the drilling vessel and is connected to the wellbore conduit below the blowout preventer. A spool is attached to the top of the blowout preventer. A casing stripper is attached to the top of the spool and has a mandrel extending from its top about which a wellhead connector attached to the marine riser system is connected. The marine riser system includes a flow diverter at its top disposed on the drilling vessel.The hole to be lined with conductor casing is drilled through the marine riser to a depth of about one thousand (1000) feet below the sea bed. The annular blowout preventer is then closed, the riser system removed, and conductor casing is guided to the mouth of the mandrel atop the casing stripper. The conductor casing is then lowered into the spool and the blowout preventer is opened. The conductor casing, with a second wellhead attached to the top thereof, is stripped into the well, the second wellhead landing within the structural casing wellhead. The conductor casing is then cemented in the hole.Well pressure is monitored by means of a surface disposed pressure gauge attached to the top of the kill line. Excess well pressure is relieved by means of the kill line or by means of a vent valve provided in the structural casing wellhead housing. | ||||||
| 185 | Flow diverter seal with respective oblong and circular openings | US449377 | 1982-12-13 | US4444401A | 1984-04-24 | Joseph R. Roche; William L. Clark |
| A seal member of elastomeric material which is shaped to fit sealably within a recess of a flow diverter body. On the inside of the diverter body, a seal is effected against a slidable cylindrical valve sleeve. On the outside of the diverter body, a seal is effected against a permanent housing. The seal is constructed with an outer section having a generally circular opening, an inner section having an oblong opening and a connecting section between the outer and inner section having a bore therein connecting the circular opening with the oblong opening. A rigid support member embedded in the elastomeric material provides rigidity and strength to the seal member. | ||||||
| 186 | Deep water hydrostatic head control | US376409 | 1982-05-10 | US4427073A | 1984-01-24 | James H. Sykora |
| Hydrostatic head control in the marine riser or sub-sea BOP stack of a deep water drilling unit is maintained through use of an eductor, or similar means, connected to the sub-sea BOP stack choke line for drawing salt water from the sea or mud from the sub-sea BOP stack kill line. | ||||||
| 187 | Emergency well-control vessel | US086501 | 1979-10-19 | US4336843A | 1982-06-29 | Terry D. Petty |
| The emergency well-control vessel is capable of being moved above an offshore live oil or gas well, over which all normal controls have been lost. The vessel carries special purpose equipments and specially trained personnel for the purpose of bringing the erupted well under control, thereby stopping the pollution of the water body with the ejected formation fluids which form a so-called "plume". Such equipment is adapted to allow the vessel to move over and continue to dispel the plume while simultaneously attempting to regain control of the well. In one aspect, control of the abandoned wellhead and blowout preventers is established with divers working from the vessel or from an auxiliary craft. After control of the blowout preventer stack is confirmed and the same is fully operational, a kill string is lowered through the open blowout preventer stack and as deep down into the well as necessary. Thereafter, weighted fluid is circulated down the kill string and up through the annulus to thereby eventually overcome the formation fluid pressure with greater hydrostatic pressure. In other aspects, the flow can be sealed off with packoffs established against the well casing or against the formation. | ||||||
| 188 | Drilling using reverse circulation | US954804 | 1978-10-26 | US4223747A | 1980-09-23 | Lionel R. Marais |
| In drilling a hole using reverse circulation and the Venturi effect, drilling fluid is caused to flow through the annulus between the set of drill pipes and the hole and to rise under reduced pressure in the interior of the drill pipes to a level at which it is ejected outside the drill pipes, using a fluid diverting device connected in the set of drill pipes and which includes a Venturi tube, the device causing ejection of the fluid from the interior of the pipes, drilling fluid being pumped from the surface in the interior of the drill pipes to the device in which it is diverted into the Venturi tube to cause upward flow of fluid from the drill tool. | ||||||
| 189 | Mud flow heave compensator | US875640 | 1978-02-06 | US4135841A | 1979-01-23 | Bruce J. Watkins |
| A heave compensator is disclosed particularly adapted for use in compensating the flow through a riser pipe employed in offshore drilling apparatus for surges and ebbs produced in the flow therein by the rising and falling of the surface platform or vessel in relation to the ocean floor. A telescoping section substantially identical to that incorporated within the riser is carried by the floating platform or vessel at a location remote from the telescoping section of the riser. The compensating telescoping section is connected into the flow pipe on one end and closed at the opposite end. The two telescoping sections are disposed normal to the earth's surface whereby gravity tends to extend the compensating telescoping section. The two lower portions of the respective telescoping sections are interconnected by a flexible cable passing over a sheave carried by the platform or vessel. Such interconnection causes the compensating telescoping section to act in an equal and opposite direction to the telescoping actions of the telescoping section within the riser affording a constant compensation for changes in volume. | ||||||
| 190 | Marine structure and method of drilling a hole by means of said structure | US821059 | 1977-08-01 | US4134461A | 1979-01-16 | Everhard C. Blomsma |
| A bottom-positioned well drilling platform is provided with an enclosure in the lower part thereof which forms a chamber into which returning drilling mud and cuttings can be discharged. A pump and separate return line raise the mud alone from the chamber to the top of the platform while the cuttings remain in the chamber. | ||||||
| 191 | Gas lift system for marine drilling riser | US786529 | 1977-04-11 | US4099583A | 1978-07-11 | Leo Donald Maus |
| An improved offshore drilling method and apparatus are disclosed which are useful in preventing formation fracture caused by excessive hydrostatic pressure in a drilling riser. Gas is injected into the riser to provide the lift necessary to return the drilling fluid to the surface and to reduce the density of the drilling fluid. The rate of gas injection overlifts the drilling fluid to the extent that the pressure of the fluid is reduced to less than that of the seawater surrounding the riser. Seawater is permitted to flow into the lower end of the riser in response to the differential pressure between the drilling fluid and seawater so that the pressures of the drilling fluid and the seawater approximately equalize. | ||||||
| 192 | Artificial lift system for marine drilling riser | US786530 | 1977-04-11 | US4091881A | 1978-05-30 | Leo Donald Maus |
| An improved offshore drilling method and apparatus are disclosed which are particularly useful in preventing formation fracture caused by excessive hydrostatic pressure of the drilling fluid in a drilling riser. One or more flow lines are used to withdraw drilling fluid from the upper portion of the riser pipe. Gas injected into the flow lines substantially reduces the density of the drilling fluid and provides the lift necessary to return the drilling fluid to the surface. The rate of gas injection and drilling fluid withdrawal can be controlled to maintain the hydrostatic pressure of the drilling fluid remaining in the riser and wellbore below the fracture pressure of the formation. | ||||||
| 193 | Method for forming an underground cavity | US592169 | 1975-07-01 | US4055224A | 1977-10-25 | Richard A. Wallers |
| A caisson and connecting conductor pipe sections are lowered to a predetermined position on the ocean underwater floor. A drill stem having a combined drilling and reaming tool is positioned within the conductor pipe and caisson. Drilling mud is reversed-circulated through the annular space between the conductor pipe and caisson and the drill stem, the drilling mud returning through the drill stem. The tool mounted on the drill stem is utilized to drill to a predetermined depth whereupon one or more reaming arms open outward from the tool and are rotated, thereby cutting out a volume of the ocean floor within which the caisson may be positioned. | ||||||
| 194 | Subsea hydraulic choke | US593419 | 1975-07-07 | US4046191A | 1977-09-06 | Robert Arthur Neath |
| An improved method and apparatus used for offshore drilling operations is disclosed which is particularly useful in those operations where a floating vessel or drilling platform is situated at the surface of a body of water with a riser assembly extending between the platform and the well and a blowout preventer assembly is positioned therebetween near the lower end of the riser assembly. In the practice of this invention at least one fluid bypass conduit provides a path for high pressure fluid to flow from the wall at a point below at least one of the blowout preventers to the riser assembly at a point below the surface of the water and above the blowout preventer assembly. A means in each of said bypass conduits controls the flow of fluid through the conduit to regulate the fluid pressure in the well when the blowout preventers are in the closed position. | ||||||
| 195 | Motion compensated blowout and loss circulation detection | US50888374 | 1974-09-26 | US3910110A | 1975-10-07 | JEFFERIES ROBERT KENNEDY; WICKLINE GLENN D; WICKLINE EXECUTRIX BY BARBARA; MIRDADIAN KIAN MOHAMMED |
| A system for detecting the commencemenet of a blowout or lost circulation in a subaqueous well being drilled from a floating vessel in which drilling fluid is being utilized. The rates of flow of the drilling fluid into and out of the well are monitored, compared, and a signal is generated proportional to the difference therebetween; the electrical signal is modified to compensate substantially instantaneously for the change in volume of the flow path of the drilling fluid caused by the heaving motion of the vessel. Alternatively, the rate of flow of the drilling fluid out of the well is monitored and an electrical signal is generated proportional thereto; the electrical signal is modified to compensate substantially instantaneously for the change in volume of the flow path of the drilling fluid caused by the heaving motion of the vessel.
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| 196 | Method and apparatus for controlling hydrostatic pressure gradient in offshore drilling operations | US22684372 | 1972-02-16 | US3815673A | 1974-06-11 | BRUCE G; ILFREY W |
| An improved system for offshore drilling is disclosed which is particularly useful in those operations where a floating vessel is situated at the surface of a body of water and circulation of drilling fluid is accomplished by introducing drilling fluid into a drill string extending from the vessel into a borehole in the floor of the body of water and returning it through a separate conduit to the vessel. A surface detectable signal is generated which is proportional to the hydrostatic head exerted by the drilling fluid within the return conduit. Hydrostatic head of the drilling fluid within the return conduit is controlled in response to the signal, as by injecting gas into the conduit near its lower end, to regulate the hydrostatic head of the fluid in the borehole.
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| 197 | Method and apparatus for balancing subsea internal and external well pressures | US3603409D | 1969-03-27 | US3603409A | 1971-09-07 | WATKINS BRUCE J |
| Method and apparatus for maintaining a pressure balance between internal and external subsea well pressures during underwater drilling, entry and reentry operations conducted from a floating vessel remote from the subsea well comprising injecting gas into the wellhead apparatus in amounts sufficient to cause the density of the well fluid or mud returns below the surface of the sea to approximate the density of sea water and controlling the injection of such gas and thus the internal well fluid pressures by sea water well pressure differential and control means associated with valve means located in gas injection and return lines at the subsea well apparatus.
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| 198 | RISER DISPLACEMENT AND CLEANING SYSTEMS AND METHODS OF USE | EP12883924.8 | 2012-08-28 | EP2890861B1 | 2018-12-12 | ROGERS, Henry, Eugene; SZARKA, David, D.; ROGOZINSKI, Nicolas |
| Disclosed are systems and methods of effectively wiping and displacing a deep water riser prior to disconnection from a blowout preventer. An exemplary riser displacement system includes a mandrel coupled to a work string, a seal containment canister arranged about at least a portion of the mandrel, and a seal assembly movable between an un-deployed configuration, where the seal assembly is arranged within the seal containment canister, and a deployed configuration, where the seal assembly is arranged outside of the seal containment canister, the seal assembly including a sleeve movably arranged about the mandrel and one or more sealing elements disposed at a distal end of the sleeve. | ||||||
| 199 | Downhole swivel apparatus and method | EP12181591.4 | 2005-11-30 | EP2557266B1 | 2018-10-17 | Robichaux, Kip M.; Caillouet, Kenneth G.; Robichaux, Terry |
| What is provided is a method and apparatus which can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve can he rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment the drill or well string does move longitudinally relative to the sleeve of the swivel. | ||||||
| 200 | OFFSHORE DRILLING SYSTEM | EP10736942.3 | 2010-07-21 | EP2456947B1 | 2018-03-28 | PAYNE, Michael, L. |
| According to one or more aspects of the invention, a method for drilling an offshore wellbore into a seabed from a platform positioned proximate to the water surface comprises making-up a first tubular string with a first conveyance assembly and running the first tubular string into the wellbore with the first conveyance assembly, wherein the first tubular string enters the wellbore from the water column at an entry position proximate to the seabed; performing a wellbore task with the first tubular string; while the wellbore task is being performed with the first tubular string, making-up a second tubular string in the water column from a second conveyance assembly; withdrawing the first tubular string from the wellbore with the first conveyance assembly once the wellbore task is completed; and running the second tubular string with the second conveyance assembly into the wellbore at the entry point from the water column. | ||||||
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