| 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 | RISER LIFECYCLE MANAGEMENT SYSTEM, PROGRAM PRODUCT, AND RELATED METHODS | US12029376 | 2008-02-11 | US20080128138A1 | 2008-06-05 | Amin Radi |
| A system, program product, and method for monitoring and managing a plurality of marine riser assets is provided. The system can include one or more floating vessels each carrying a shipboard computer, a plurality of riser assets to be tracked and monitored, a riser asset identification sensor positioned to identify select riser assets being deployed to establish a riser string, one or more riser joint instrument modules positioned along the length of the riser string to provide riser asset load data, a centralized data warehouse to store riser asset identification and loading data for riser assets deployed at multiple remote vessel locations, and a riser lifecycle management server and riser lifecycle management program product adapted to monitor riser asset conditions, issue automated service alerts based on actual use information, maintain routine and non-routine maintenance records, manipulate and categorize riser assets, and automatically generate an accurate riser system configuration as was actually deployed for any particular drilling/completion operation. | ||||||
| 182 | Subsea intervention | US10709322 | 2004-04-28 | US07264057B2 | 2007-09-04 | Gary L. Rytlewski; Thomas H. Zimmerman; Peter A. Goode; Ashley C. Kishino; John A. Kerr; Alan Christie |
| A method and system of subsea intervention comprises lowering one or more assemblies of intervention equipment into the sea. Underwater marine units (such as remote operated vehicles or small submarines) may be employed to connect the assemblies to each other and to the subsea wellhead equipment. The subsea wellhead equipment includes a carrier line spool (e.g., coiled tubing spool, wireline spool, slickline spool) and equipment to inject a carrier line from the carrier line spool into the subsea well. The carrier line spool can be located underwater, such as on the sea floor or positioned above the subsea wellhead equipment. | ||||||
| 183 | Internal riser inspection device and methods of using same | US11496160 | 2006-07-31 | US20060260391A1 | 2006-11-23 | Larry Harthorn; Christopher Disher |
| An inspection apparatus includes an inspection unit that is lowered into vertically supported pipe filled with seawater. The apparatus includes a pipe weld location detector module carried by the inspection unit. The apparatus also includes a rotating time of flight diffusion (TOFD) module and a non-rotating wall thickness module carried by the inspection unit. The module includes a pair of rotatably mounted weld volume inspection transducers rotatable by an operator and adapted to inspect for and obtain data on weld volume defects. The TOFD module has a fluid carrier positioned within the TOFD module and contains an acoustic fluid. The non-rotating wall thickness module also contains an acoustic liquid and includes a plurality of fixedly mounted wall inspection transducers adapted to obtain data on wall thickness of a portion of the pipe. | ||||||
| 184 | Internal riser inspection device and methods of using same | US11359179 | 2006-02-22 | US07104125B2 | 2006-09-12 | Larry K. Harthorn; Christopher B. Disher |
| An inspection apparatus includes an inspection unit that is lowered into vertically supported pipe filled with seawater. The apparatus includes a pipe weld location detector module carried by the inspection unit. The apparatus also includes a rotating time of flight diffusion (TOFD) module and a non-rotating wall thickness module carried by the inspection unit. The module includes a pair of rotatably mounted weld volume inspection transducers rotatable by an operator and adapted to inspect for and obtain data on weld volume defects. The TOFD module has a fluid carrier positioned within the TOFD module and contains an acoustic fluid. The non-rotating wall thickness module also contains an acoustic liquid and includes a plurality of fixedly mounted wall inspection transducers adapted to obtain data on wall thickness of a portion of the pipe. | ||||||
| 185 | Internal riser inspection device and methods of using same | US11359179 | 2006-02-22 | US20060137441A1 | 2006-06-29 | Larry Harthorn; Christopher Disher |
| An inspection apparatus includes an inspection unit that is lowered into vertically supported pipe filled with seawater. The apparatus includes a pipe weld location detector module carried by the inspection unit. The apparatus also includes a rotating time of flight diffusion (TOFD) module and a non-rotating wall thickness module carried by the inspection unit. The module includes a pair of rotatably mounted weld volume inspection transducers rotatable by an operator and adapted to inspect for and obtain data on weld volume defects. The TOFD module has a fluid carrier positioned within the TOFD module and contains an acoustic fluid. The non-rotating wall thickness module also contains an acoustic liquid and includes a plurality of fixedly mounted wall inspection transducers adapted to obtain data on wall thickness of a portion of the pipe. | ||||||
| 186 | Apparatus and method for retroactively installing sensors on marine elements | US11265889 | 2005-11-03 | US20060115335A1 | 2006-06-01 | Donald Allen; David McMillan |
| Sensors, including fiber optic sensors and their umbilicals, are mounted on support structures designed to be retro-fitted to in-place structures, including subsea structures. The sensor support structures are designed to monitor structure conditions, including strain, temperature, and in the instance of pipelines, the existence of production slugs. Moreover the support structures are designed for installation in harsh environments, such as deep water conditions using remotely operated vehicles. | ||||||
| 187 | Method and apparatus to monitor, control and log subsea oil and gas wells | US10633045 | 2003-08-01 | US06913083B2 | 2005-07-05 | David Randolph Smith |
| A method and apparatus for logging, controlling, or monitoring a subsea well or group of wells through a path not within production tubing. Preferred embodiments allow logging tools, wire rope, optic fibers, electrical cables, monitoring and measuring instruments and other items known to those skilled in the art of oil and gas production to be disposed into the well without interfering with the flow path through the production string. A further preferred embodiment includes the mooring or tethering of an instrument pod over the subsea well. The instrument pod is designed to provide on-board data storage, data processing, data receiving, and data transmission equipment, such that data from the well can be transmitted back to a receiving network where the data may be stored and processed into useful information for reservoir operators. | ||||||
| 188 | Monitoring of a reservoir | US10499442 | 2002-12-18 | US20050061513A1 | 2005-03-24 | John Johansen; Morten Sivertsen |
| A system is described for monitoring a subsea formation, which is under development Instruments located in a completed but unconnected well are employed for providing information by a provisional monitoring unit being lowered downhole and connected to the well. Changes in the reservoir as a result of operations in other adjacent wells are an acoustic link to the surface. | ||||||
| 189 | Method and apparatus to monitor, control and log subsea oil and gas wells | US10064407 | 2002-07-10 | US06640900B2 | 2003-11-04 | David Randolph Smith |
| A method for logging, controlling, or monitoring a subsea well or group of wells through a path not within production tubing. Preferred embodiments of the present invention allow logging tools, wire rope, optic fibers, electrical cables, monitoring and measuring instruments and other items known to those skilled in the art of oil and gas production to be disposed into the well without interfering with the flow path through the production string. In another aspect of the invention, a preferred embodiment includes the mooring or tethering of an instrument pod over the subsea well. The instrument pod is designed provide on-board data storage, data processing, data receiving, and data transmission equipment, such that data from the well can be transmitted back to a receiving network where said data may be stored and processed into useful information for reservoir operators. | ||||||
| 190 | Subsea intervention system | US09921026 | 2001-08-02 | US20020040783A1 | 2002-04-11 | Thomas H. Zimmerman; John A. Kerr; Alan R. Christie |
| A system that is usable with subsea wells that extend beneath a sea floor includes a station that is located on the sea floor and an underwater vehicle. The underwater vehicle is housed in the station and is adapted to service at least one of the subsea wells. | ||||||
| 191 | Well management system and method of operation | US09613375 | 2000-07-11 | US06364021B1 | 2002-04-02 | E. Alan Coats |
| An offshore field management system which includes a composite riser, a floating buoy and a service vessel. The riser is extended from a subsea well head to the buoy. Conductors, preferably provided in the riser, are connected with a well telemetry system. The buoy has a floating or semi-submersible hull that includes a hatch covering a moonpool for receiving the riser. The buoy preferably includes satellite communication hardware and computer systems in communication with the well telemetry system via riser embedded conductors. The well environment can be remotely monitored using the buoy communication system. Servicing of the oilfield well is accomplished using the service vessel by docking the buoy in a bay formed in the service vessel. The service vessel is preferably a self-contained facility fitted with the equipment and materials necessary to carry out pre-determined well servicing operations. Service vessel personnel deploy the equipment and material into the riser via the buoy hatch after the buoy has been docked in a bay formed in the service vessel. | ||||||
| 192 | Production well telemetry system and method | US09965488 | 2001-09-27 | US20020020533A1 | 2002-02-21 | Paulo Tubel |
| A downhole production well control system is provided for automatically controlling downhole tools in response to sensed selected downhole parameters. The production well having a production tubing string therein with multiple branches, i.e., zones. Communication and transmission of power (i.e. telemetry) over the production tubing string is by way of a combination of a hardwire system in the main borehole and a short hop system at the branches or laterals. Each zone includes a downhole control system and appropriate completion devices for controlling fluid flow. An acoustic or electromagnetic transceiver is associated with each control system for communication and/or transmission of power. An electrical conductor runs from the surface downhole along the production tubing string in the main borehole for communication and/or transmission of power, hardwired systems are well known. The conductor is connected to an acoustic or electromagnetic transceiver disposed at the production tubing string in the main borehole near each branch. These transceivers communicate with and/or transfer power to corresponding transceivers at the branches (i.e., short hop communications), which is communicated and/or transferred along the production tubing string on the conductor (i.e., uphole or downhole). | ||||||
| 193 | Production well telemetry system and method | US09764690 | 2001-01-18 | US20010013412A1 | 2001-08-16 | Paulo Tubel |
| A downhole production well control system is provided for automatically controlling downhole tools in response to sensed selected downhole parameters. The production well having a production tubing string therein with multiple branches, i.e., zones. Communication and transmission of power (i.e. telemetry) over the production tubing string is by way of a combination of a hardwire system in the main borehole and a short hop system at the branches or laterals. Each zone includes a downhole control system and appropriate completion devices for controlling fluid flow. An acoustic or electromagnetic transceiver is associated with each control system for communication and/or transmission of power. An electrical conductor runs from the surface downhole along the production tubing string in the main borehole for communication and/or transmission of power, hardwired systems are well known. The conductor is connected to an acoustic or electromagnetic transceiver disposed at the production tubing string in the main borehole near each branch. These transceivers communicate with and/or transfer power to corresponding transceivers at the branches (i.e., short hop communications), which is communicated and/or transferred along the production tubing string on the conductor (i.e., uphole or downhole). | ||||||
| 194 | Fail safe downhole signal repeater | US08984382 | 1997-12-03 | US06218959B1 | 2001-04-17 | Harrison C. Smith |
| A system and method of fail safe communication of information between surface equipment and downhole equipment are disclosed. The system comprises two or more repeaters (34, 35, 36) disposed within a wellbore (38) such that two repeaters (34, 35) will receive each signal carrying information that is telemetered. The repeater (35) that is farther from the source (44) will include a memory device (292) that stores the information carried in the signal. A timer device (293) also in the repeater (35) that is farther from the source (44) will trigger the retransmission of the information after a predetermined time period unless the repeater (35) that is farther from the source (44) has detected a signal carrying the information generated by the repeater (34) that is closer to the source (44). | ||||||
| 195 | Downhole production well control system and method | US385992 | 1995-02-09 | US5732776A | 1998-03-31 | Paulo S. Tubel; Albert A. Mullins, II; Kevin R. Jones; Frank D. Richardson |
| A downhole production well control system is provided for automatically controlling downhole tools in response to sensed selected downhole parameters. An important feature of this invention is that the automatic control is initiated downhole without an initial control signal from the surface or from some other external source. This control system generally comprises downhole sensors, downhole electromechanical devices and downhole computerized control electronics whereby the control electronics automatically control the electromechanical devices based on input from the downhole sensors. Thus, using the downhole sensors, the downhole computerized control system will monitor actual downhole parameters (such as pressure, temperature, flow, gas influx, etc.) and automatically execute control instructions when the monitored downhole parameters are outside a selected operating range (e.g., indicating an unsafe condition). The automatic control instructions will then cause an electromechanical control device (such as a valve) to actuate a suitable tool (for example, actuate a sliding sleeve or packer; or close a pump or other fluid flow device). The downhole control system of this invention also includes transceivers for two-way communication with the surface as well as a telemetry device for communicating from the surface of the production well to a remote location. | ||||||
| 196 | Determination of drill bit rate of penetration from surface measurements | US98669 | 1993-07-28 | US5398546A | 1995-03-21 | Benjamin P. Jeffryes |
| A method of determining, from surface measurements, the rate of penetration .DELTA.d of a drill bit attached to a drill string suspended from a floating drilling rig by means of a suspension system and a motion compensator, the method comprising:a) determining a displacement .DELTA.s of the drill string at the surface;b) determining from the measurements a function .LAMBDA.' of drill string compliance .LAMBDA. such that .LAMBDA.'=.LAMBDA.(1-.theta.) (wherein .theta. is a contribution factor of the motion compensator to an axial force applied to the drill string at the surface);c) determining an axial force .DELTA.T in the suspension system applied at the surface;d) determining a vertical displacement .DELTA.M of the motion compensator;e) determining from the measurements a function .mu. of the motion compensator compliance .lambda..sub.M such that ##EQU1## and f) calculating the bit displacement .DELTA.d from the relationship.DELTA.d=.DELTA.s-.LAMBDA.'.DELTA.T-.mu..DELTA.M. | ||||||
| 197 | Kelly-to-riser position determining system with adjustment for uncompensated heave | US55451 | 1987-05-28 | US4852052A | 1989-07-25 | James E. Frey; William Stohrer-Hoyt |
| A system for determining kelly-to-riser position on floating drilling platforms is presented. The system removes (e.g. filters) uncompensated heave from surface sensor measurements so that bit depth can be accurately calculated. During operation, surface sensors on the drilling platform measure heave compensator action and kelly movements. Each heave sensor reading is then added to a kelly sensor reading in order to obtain a value termed kelly-to-riser. Each kelly-to-riser value is fed (inputted) into the system of the present invention and a filtered reading is returned for use in calculating bit depth and rate of penetration (ROP). The filtering system is termed a linear extrapolative filter (LEF). The LEF generates filtered readings by performing a linear regression on measurements taken over its pre-specified filter interval. It then predicts the current kelly-to-riser position from the resultant trend line. | ||||||
| 198 | Adaptive riser angle position reference system | US177667 | 1980-08-13 | US4351027A | 1982-09-21 | Tom A. Gay; Gary L. Hartman; Gunter Stein |
| An adaptive riser angle position reference system and method for determining the horizontal position of a marine vessel relative to an underwater wellhead from angular deviations from vertical of a riser between the vessel and the wellhead are disclosed. The system comprises sensors for determining deviation from vertical of the riser at positions proximate the wellhead and the vessel and a compensation filter for adaptively filtering signals indicative of the lower and upper riser angles in accordance with filter coefficients which are determined by riser parameters. The filter coefficients are established by riser parameter identification means which effectively compares riser response, as indicated by the lower and upper riser angles, with the responses of a plurality of riser models, and selects filter coefficients corresponding to the most accurate model. | ||||||
| 199 | Riser angle positioning system and process | US125804 | 1980-02-28 | US4317174A | 1982-02-23 | Q. Wayne Dean |
| A riser angle positioning system and process provides information for dynamically positioning a floating vessel having a riser extending to a wellhead on the ocean floor. The system comprises an acoustic system for generating acoustic data signals representing the position of the vessel with respect to the wellhead, top and bottom riser inclinometers for generating respective sensor signals indicating angles of deflection of the riser at the top and bottom, respectively, thereof, and a processor responsive to the acoustic data signals and the sensor signals for generating positioning information. The riser angle positioning system and process serve as a backup system and method for checking the acoustic data for large errors, and additionally provide the sole position determining system and method in case of acoustic blackout. The riser angle positioning system and process have two alternative modes of operation: a simulator mode during which the vessel position is calculated from data read from a dynamic positioning system magnetic tape log, and a real time mode during which data is read directly from analog-to-digital converters associated with the top and bottom inclinometers and the acoustic system. | ||||||
| 200 | Wireline stabilization method and apparatus | US13958 | 1979-02-22 | US4252190A | 1981-02-24 | Alfred H. Jageler; Theodore V. Lautzenhiser |
| Downhole variations in wireline cable tension are substantially reduced for offshore exploration by means of an auxiliary cable tensioning system preferably installed at the ocean floor wellhead. Part of the lifting force applied to a wireline cable is provided by the wireline stabilization tool at the wellhead so that fluctuations in wireline tension above the wellhead caused by ocean disturbances on the floating platform will be effectively filtered out and isolated from the main cable downhole from the wellhead. This downhole isolation is achieved with a moving wireline as well as with a stationary cable. | ||||||
QQ群二维码
意见反馈
意见反馈