• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    APPARATUS AND METHOD TO PROVIDE AUTOMATIC DETECTION AND CONTROL A drilling control system monitors and compares drilling and completion operation values and acts independently in response to conditions such as an intrusion of formation fluids or emergence. Sensors in various combinations can monitor return fluid flow rate, fluid inlet flow rate, wellhead bore pressure, return fluid temperature, torque, penetration rate and column weight change. The control system has corresponding control logic to monitor, alert and act based on the sensor inputs. Actions may include alerting support personnel, closing a ring set of blowout preventers, cutting the drill pipe using a cutting drawer, pumping heavier fluid (kill) and choke lines , disconnect the riser or several other actions
    公开号:BR102012009708B1
    申请号:R102012009708-7
    申请日:2012-04-25
    公开日:2020-11-17
    发明作者:Eric L. Milne；Joseph P. Ebenezer
    申请人:Hydril Usa Manufacturing Llc；
    IPC主号:
    专利说明:

    FIELD OF THE INVENTION
    [001] This disclosure refers in general to the drilling of offshore wells and in particular to an automated method for controlling an underwater well during drilling procedures. BACKGROUND OF THE INVENTION
    [002] The future of oil and gas exploration lies in deep waters and greater depths under the seabed. This presents the subsea equipment to increasingly severe conditions such as higher pressures and higher temperatures. These more severe conditions can cause an increase in the number of intrusions of formation fluids and consequently decrease the efficiency and safety of a given operation. This leads to the design of a control system for this expanded high pressure and high temperature wrap. A control system that is capable of logically monitoring and controlling equipment and tools can lead to more reliable, safe and efficient subsea operation.
    [003] An improved control system that provides a more reliable, safe and more efficient underwater drilling operation is sought. DESCRIPTION OF THE INVENTION
    [004] The drilling system of this invention has characteristics to automatically detect and control an intrusion of the formation fluids or emergence without requiring decisions to be made by the operating personnel. The invention consists of sensors and an automatic control system that monitors and performs actions autonomously based on the sensor inputs. In a given embodiment there may be a variety of sensor combinations depending on the needs of the particular drilling operation. For example, in one mode there may be a sensor to monitor the rate of return flow. The signals from the return flow rate sensor can be transmitted conventionally, such as through wire and fiber optic sensors that can be part of the umbilical carrying the platform. Ideally, the return flow rate sensor will indicate the flow rate that exists within the wellhead assembly at all times. An increase in the flow rate detected by the return flow rate sensor may indicate an intrusion of the formation fluids. Additional sensor inputs such as inlet flow rate, temperature, wellhead bore pressure, column weight change, penetration rate, torque, and several other sensors can all be monitored for additional indications and an intrusion condition of the formation or emergence fluids. Certain sets of condition sensors can cause the control system to perform autonomous actions to decrease or stop the intrusion of formation fluids. For example, an indicated condition of intrusion of training fluids can cause the control system to alert operating personnel and subsequently initiate emergency procedures. These procedures may include an emergency shutdown sequence or the initiation of a well closure sequence.
    [005] The foregoing and other objectives and advantages of the present invention will be evident to those skilled in the art, in view of the following detailed description of the present invention, taken in conjunction with the attached claims and drawings. BRIEF DESCRIPTION OF THE FIGURES
    [006] Figure 1 is a schematic view that illustrates a well drilling control system according to this disclosure.
    [007] Figure 2 is a schematic flowchart that identifies steps used by the control system in Figure 1. DESCRIPTION OF ACCOMPLISHMENTS OF THE INVENTION
    [008] Figure 1 illustrates an underwater well being drilled or completed. The well was at least partially drilled, and has a subsea wellhead assembly 11 installed on the seabed 13. At least one casing column (not shown) will be suspended in the well and supported by the wellhead assembly 11.0 well can have an open hole part still uncoated, or it may be completely coated, but the completion of the well is not yet finished.
    [009] A hydraulically actuated connector 15 reliably attaches a stack of eruption preventers (BOP) 17 to the wellhead housing assembly 11. The BOP stack 17 has several drawer preventers 19, some of which are tube drawers and at least one of which is a blind drawer. The drawers have cavities sized to close around and seal against the tube that extends down through the wellhead housing 11. The blind drawers are capable of cutting the tube and simulating a total closure. Each of the drawers 19 has a door 21 located below the closing element for pumping fluid into or out of the well while the drawer 19 is closed. The fluid flow is through high pressure lines (kill) and choke (choke) (not shown).
    [010] A hydraulically actuated connector 23 connects a package of lower risers (LMRP) 25 to the upper end of the BOP stack 17. Some of the elements of the LMRP 25 include one or more ring BOPs 27 (two are shown). Each annular BOP 27 has an elastomeric element that closes around tubes of any size. Also, BOP 27 can complete the closure without a tube that extends through it. Each annular BOP 27 has a port 29 located below the elastomeric element for pumping fluid into or out of the well below the elastomeric element while BOP 27 is closed. The flow of fluid through port 29 is handled by the high pressure (kill) and choke (choke) lines. Ring BOPs 27 can alternately be a part of the BOP stack 17, instead of being connected to the BOP stack 17 with a hydraulically actuated connector 23.
    [011] The LMRP 25 includes a flexible joint 31 capable of pivoting movement relative to the common axis of LMRP 25 and a stack of BOP 17. A hydraulically actuated riser connector 33 is mounted above the flexible joint 31 to connect the lower end of the column riser 35. The riser 35 is made up of tube joints 36 attached together. Auxiliary ducts 37 are circumferentially spaced around central tube 36 of rising column 35. Auxiliary ducts 37 are smaller in diameter than central tube 36 of rising column 35 and serve to communicate fluids. Some of the auxiliary ducts 37 serve as high pressure (kill) and choke (choke) lines. Others provide hydraulic fluid pressure. Flow ports 38 at the upper end of LMRP 25 connect some of the auxiliary conduits 37 to the various actuators. When the riser connector 33 is disconnected from the center riser tube 36 and the riser 35 is raised, flow ports 38 will also be disconnected from auxiliary ducts 37. At the upper end of riser 35, auxiliary ducts 37 are connected to hoses (not shown) that extend to various equipment on a floating ship or drilling platform 40.
    [012] Electrical lines and optionally fiber optics extend downward within an umbilical to the LMRP 25. The electrical, hydraulic, and fiber optic lines lead to one or more control modules (not shown) mounted on the LMRP 25. The control module controls the various stack actuators of BOP 17 and LMRP 25.
    [013] The rising column 35 is supported in tension by platform 40 by hydraulic tensioners (not shown). The tensioners allow the platform 40 to move a limited distance relative to the rising column 35 in response to waves, wind and current. The platform 40 has equipment at its upper end to deliver fluid flowing upward from the central riser tube 36. This equipment can include a flow diverter 39, which has an outlet 41 that leads away from the central riser tube 39 to platform 40. Diverter 39 can be mounted on platform 40 for movement with platform 40. A telescopic joint (not shown) can be located between diverter 39 and riser 35 to accommodate this movement. The diverter 39 has a hydraulically driven seal 43 which, when closed, forces all the upward fluid in the central riser tube 36 out of the outlet 41.
    [014] Platform 40 has a probe floor 45 with a rotating table 47 through which tube is lowered into the rising column 35 and into the well. In this example, the tube is illustrated as a drill pipe column 49, but it may alternatively comprise another well tube, such as a liner or liner. The drill pipe 49 is shown connected to an upper actuator 51, which supports the weight of the drill pipe 49 as well as provides torque. The upper drive 51 is lifted by a set of blocks (not shown), and to move a drilling tower up and down while engaged with a torque transfer rail. Alternatively, the drill pipe 49 can be supported by the blocks and rotated by the rotary table 47 using wedges (not shown) that support the drill pipe 49 in rotating engagement with the rotary table 47.
    [015] Mud pumps 53 (only one illustrated) mounted on platform 40 pump fluids down into drill pipe 49. During drilling, the fluid will normally be drill mud. Mud pumps 53 are connected to a line leading to a mud hose 55 that extends to the drilling tower and into the upper end of the upper driver 51. Mud pumps 53 pull the mud from the mud tanks 57 ( only one illustrated) through the inlet lines 59. The outlet of the riser 41 is connected via a hose (not shown) to mud tanks 57. Drilling cuttings are separated from the drilling mud by mud screens (not shown) before reaching the inlet lines of the mud pump 59.
    [016] An intrusion of formation fluids, defined as an unscheduled entry of formation fluids into the well bore, can occur during drilling or during well completion. Basically, the intrusion of the formation fluids occurs when a land formation has a higher pressure than the hydrostatic pressure of the fluid in the well. If the well has an uncoated or open part, the hydrostatic pressure that acts on the formation of the earth is that of the drilling mud. Operating personnel control the weight of the drilling mud so that it provides sufficient hydrostatic pressure to form an intrusion of the formation fluids. However, if the weight of the mud is excessive, it can flow into the formation of the earth, damaging the formation and causing loss of circulation. Consequently, operating personnel balance the weight to provide sufficient weight to prevent intrusion of the formation fluids, but to prevent fluid loss.
    [017] An intrusion of the formation fluids can occur during drilling, during maneuvering the drill pipe 49 out of the well or running the drill pipe 49 into the well. An intrusion of the formation fluids can also occur while lowering profiling instruments on the steel cable into the well to measure the formation of the earth. An intrusion of the formation fluids can occur even after the well has been coated, such a branch by a leak through or around the liner or between a top of a top of the liner and liner column. In this case, the fluid in the well may be water, instead of drilling mud. If not mitigated, an intrusion of the formation fluids can result in high pressure hydrocarbon flowing to the surface, possibly pushing up the drilling mud and any pipe in the well. The hydrocarbon can be gas, which can be ignited inadvertently.
    [018] Normally, intrusions of formation fluids are controlled by personnel on platform 40 by detecting the intrusion of formation fluids in advance by taking remedial actions. Various techniques are used by personnel based on experience to detect an intrusion of training fluids. Also, a variety of remedial actions are taken. For example, detecting that more drilling mud is returning than being pumped can indicate an intrusion of the formation fluids. Remediation actions may include closing ring BOP 27 and pumping heavier fluid into the high pressure (kill) and choke lines to port 21, which directs fluid into the well. If drilling mud continues to flow upward from riser 35 and out of outlet 41, operating personnel can close diverter 39 and direct the flow to a burner line. If remediation actions are not working, operating personnel can close drawers 19 and cut the drill pipe 49, thereby disconnecting the rising column 35, as in connector 23 or connector 33. Platform 40 can then be moved, bringing the ascending column 35 along with it. The detection and remediation steps require decisions to be made by the operating personnel on platform 40.
    [019] The drilling system shown in Figure 1 has features to automatically detect and control an intrusion of formation fluids without requiring decisions to be made by operating personnel. The drilling system in Figure 1 has many sensors, of which only a few are illustrated. The sensors intended to provide early detection of an intrusion of the formation fluids, and more or less can be used. Some of the sensors may be useful only when drilling, but not when maneuvering the drill pipe or performing other operations, such as cementing.
    [020] A return flow rate sensor 67 will detect the flow rate of the drilling mud returning, or the flow rate of any fluid flowing upwards. The return flow rate sensor 67 can be located at outlet 41 as shown or at the BOP stack connector 15. An inlet flow sensor 69 can be located at the outlet of mud pumps 53 to determine the flow rate of fluid being pumped into the well. If the return flow rate detected by sensor 67 is greater than the input flow rate detected by sensor 69, there is an indication that an intrusion of the formation fluids is occurring. If the return flow rate is less than the inlet flow rate, there is an indication that fluid losses into the earth formation are occurring. However, differences in flow rates between sensors 67, 69 can occur due to other factors. For example, some lost circulation may be occurring in the formation of the land at the same time as an intrusion of the formation fluids into another formation is taking place.
    [021] A wellhead bore pressure sensor 61 will preferably be located just above the wellhead assembly 11 within the BOP stack 17 below the lower drawer 19. Signals from the wellhead pressure sensor well 61 are transmitted conventionally, such as through wire and fiber optic sensors that can be part of the umbilical that leads to platform 40. The wellhead 61 hole pressure sensor will indicate the pressure at all times inside the well wellhead assembly 11. While drilling mud flows down through drill pipe 49, the perceived pressure will be the pressure of the drilling mud that returns out of drill pipe 49 at that point. That pressure depends on the hydrostatic pressure of the drilling mud above sensor 61, which is proportional to the depth of the sea. If the drilling mud is not being circulated, the pressure detected will be the hydrostatic pressure of the fluid in the central tube of the riser 36. An increase in pressure detected by sensor 61 may indicate an intrusion of the formation fluids. However, an intrusion of the formation fluids may be occurring even if sensor 61 is detecting only a normal pressure range. For example, upward migration of gas in rising column 35 should alleviate the drilling mud column above sensor 61, causing it to either not show an increase in pressure or to show a drop in pressure. Also, the pressure monitored by sensor 61 is affected by the pressure of mud pumps 53. However, when in conjunction with other parameters being detected, sensor 61 provides valuable information that may indicate an intrusion of the formation fluids.
    [022] Preferably one or more temperature sensors 65 are employed to detect the temperature of the fluid flowing upwards. The temperature sensor 65 is also preferably located in the wellhead connector 15 to detect the fluid temperature in the wellhead assembly 11 hole. The temperature may change if an intrusion of the formation fluids is occurring. When combined with other data regarding the upstream fluid in the upstream column 35, an indication of an intrusion of the formation fluids can be accurately determined.
    [023] A column weight sensor 71 is mounted on the upper actuator 51, or on the blocks, to detect the weight of the column tube being supported by the drilling tower. During drilling, the weight of drill pipe 49 detected depends on how much weight of drill pipe 49 is applied to the drill bit. If operating personnel apply more brake, the detected weight will increase since less weight is being transferred to the drill. If operating personnel release some of the brakes, more weight is applied to the drill, and sensor 71 detects less weight. If there is an intrusion of the formation fluids of sufficient magnitude to start pushing the drill pipe 49, the detected weight will decrease.
    [024] Connecting the signal from the column 71 weight sensor to a penetration rate (ROP) 73 sensor will assist in determining whether less weight being detected is due to more brake being applied or an intrusion of the formation fluids. The ROP 73 sensor measures how quickly the drill pipe 49 is moving down, so it is an indication of the amount of brake being applied. The ROP 73 sensor will also determine when a very soft formation is being punctured, suggesting that lost circulation may be occurring.
    [025] Additionally, a torque sensor 75 provides useful information regarding intrusions of formation fluids. The torque sensor 75 is mounted on or near the upper driver and detects the amount of torque being imposed during drilling. If an intrusion of the formation fluids is tending to lift the drill pipe 49, the torque must drop. The torque also decreases for other reasons, such as deliberately reducing the weight of the drill or finding a smooth formation. When coupled with other data, the torque detected by the torque sensor 75 during drilling can help to accurately predict the anticipated occurrence of an intrusion of the formation fluids.
    [026] A BOP 77 control system on platform 40 receives signals from sensors 61, 65, 67, 69, 71, 73 and 75 and possibly others. The BOP 77 control system processes these signals to detect whether an intrusion of the formation fluids is occurring and emits control signals in response. Also, the drill pipe 49 can have downhole detection devices that determine conditions such as weight on the drill, torque on the drill, pressure of the drilling mud in the drill and the temperature of the drilling mud in the drill. The signals from these sensors can be transmitted to the well through mud pulse or other known techniques. These signals can also be fed to the BOP 77 control system.
    [027] With reference to Figure 2, data from the various sensors are provided for a BOP 77 control system processor. Step 79 indicates that the processor determines whether any of the sensors 69, 67, 65, 61, 71, 73 and 75 are outside a predetermined normal range. If so, in step 81 it then compares the sensor out of range with the data received from other sensors. For example, if the output flow rate of sensor 67 exceeds the input flow rate of sensor 69 beyond a specified value, control system 77 will search the data from other sensors to determine if there is an explanation, according to step 83. Possibly, the other sensors will confirm that there is a problem or provide data that indicates a reasonable explanation. If the explanation is reasonable, control system 77 may take no action, depending on how it is programmed.
    [028] If the various comparisons indicate that an intrusion of the formation fluids is occurring, the control system 77 can be programmed to initially provide a visual and optionally audible alert to operating personnel, as indicated by step 85. operation can then try to remedy the problem, such a branch by closing ring BOP 27. Control system 77, however, will continue to monitor the data detected by the sensors, as indicated by step 87. If it determines after a selected time interval that the condition of intrusion of the formation fluids still exists, it will move to a second alert or another stage. The other step can be a first step by starting an emergency disconnect sequence. That step depends on the programming of control system 77. It can be closing ring BOP 27 by step 89, if this has not already been done by the operating personnel. Control system 89 should also send an alert to operating personnel that it has closed ring BOP 27. That alert should enable operating personnel to begin pumping drilling mud through the high pressure lines (kill) and choke into the well, preferably with a heavier drilling mud.
    [029] Regardless of what steps operating personnel take, if any, control system 77 will continue to monitor the sensors, process the data and determine the hazardous condition still exists, as indicated in step 91. If after a selected interval, the hazard condition is not decreasing, control system 77 will take another step 93 towards an emergency disconnect. Step 93 may be to close drawers 19 and cut the drill pipe 49, or it may be a provisional step. Control system 77 should provide an alert to operating personnel that this has occurred. Control system 77 can continue to monitor the sensors, as in step 95. If the condition still exists after step 93, for whatever reason, control system 77 can then trigger each connector 23 or 33 to release rising column 35 of the wellhead assembly 11. The BOP stack 17 remains connected to a subsea wellhead assembly 11.0 operating personnel must then proceed to move platform 40 from their station, bringing the riser 35 along with it.
    [030] The automated mechanism for initiating an emergency shutdown sequence can also be applied and used to initiate a well closure sequence. This step depends on the programming of control system 77. It can be closing ring BOP 27 by step 89, if this has not already been done by the operating personnel. Control system 89 should also send an alert to operating personnel that it has closed ring BOP 27. This alert should allow operating personnel to start pumping drilling mud through the high pressure (kill) and choke into the well, preferably with a heavier drilling mud. Regardless of what steps operating personnel take, if any, control system 77 will continue to monitor the sensors, process the data and determine whether the hazardous condition still exists, as indicated in step 91. If after a selected interval, the the danger condition is not decreasing, the control system 77 will take another step and open the internal and external drain valves, signaling the completion of the well.
    [031] The control system can also track the existing stack configuration mode in which the control system is currently being used to monitor signals from sensors 61, 65, 67, 69, 71, 73 and 75 and possibly others. Depending on the stack configuration mode, the control system can alert operating personnel with configuration to proceed with the existing stack configuration mode or change the stack configuration mode to ensure that the BOP stack is brought into a mode. of security. After a stipulated period of time, if there is no confirmation from the operating personnel, based on current battery conditions and the functions involved, the emergency disconnect sequence or the well closure sequence is initiated.
    [032] Although not necessarily related to formation fluid intrusions, a 99 riser inclination sensor (Figure 1) provides information on a serious problem. The rising column 35 will tilt when platform 40 moves from directly above wellhead assembly 11. Platform 40 typically has thrusters that are connected to a global positioning system (GPS). The GPS receives satellite signals and controls the thrusters to keep platform 40 at the desired station. Sometimes the satellite signal is interrupted or a GPS defect occurs. If not detected in time, platform 40 may drift too far from the station. The riser 35 has a maximum angle that it can reach and still be disconnected at connector 23 or 33. In addition to this angle, connectors 23 or 33 may not be able to disconnect riser 35, and damage is likely to occur from this to the ascending column 35.
    [033] Ascending column tilt sensor signals 99 can be fed to the BOP 77 control system, which determines whether the tilt is outside a selected range. If so, the BOP 77 control system can proceed through the same steps as shown in Figure 2, eventually disconnecting the rising column 35, if necessary.
    权利要求:
    Claims (13)
    [0001]
    1. APPLIANCE, which provides automatic detection and control of an intrusion of the formation fluids during drilling operations and completion of the well with a drilling platform (40) connected to a subsea wellhead assembly (11) through an ascending column (35) and an eruption preventer (27), comprising: a plurality of sensors (61, 65, 67, 69, 71, 75) to produce current sensor values for operations in progress in the well; a control system (77) which has a processor containing a database of known sensor values indicative of a formation fluid intrusion event, wherein the processor has the means to receive the current sensor values from the sensors (61 , 65, 67, 69, 71, 75) and compare the current sensor values with the known sensor values; and where the control system (77) has an automated alert component that alerts operations personnel if the comparison indicates an intrusion event of the training fluids; characterized by the plurality of sensors (61.65, 67, 69, 71, 75) being adapted to be coupled to the wellhead assembly (11) and the control system (77) being configured to close the eruption preventer (27 ) if the control system (77) determines that after a selected time interval the intrusion event of the formation fluids still exists; and the control system (77) being configured to take a step towards an emergency disconnection if after a selected interval the intrusion event of the forming fluids is not decreasing.
    [0002]
    2. APPLIANCE, according to claim 1, characterized by the fact that at least one of the sensors (61, 65, 67, 69, 71.75) comprises: a return flow rate sensor (67) adapted to be coupled to a fluid return line from the drilling platform (40).
    [0003]
    3. APPLIANCE according to claim 1, characterized by the fact that at least one of the sensors (61, 65, 67, 69, 71.75) comprises: a fluid temperature sensor (65) that flows upwardly adapted to be coupled to the wellhead assembly (11).
    [0004]
    4. APPLIANCE according to claim 1, characterized by the fact that at least one of the sensors (61, 65, 67, 69, 71.75) comprises: a wellhead bore pressure sensor (61) adapted to be coupled to the wellhead assembly (11).
    [0005]
    5. APPLIANCE, according to claim 1, characterized by the fact that at least one of the sensors (61, 65, 67, 69, 71.75) comprises: an input flow rate sensor (69) adapted to be coupled to an inlet fluid port of the drilling platform (40).
    [0006]
    6. APPLIANCE, according to claim 1, characterized by the fact that at least one of the sensors (61, 65, 67, 69, 71.75) comprises: a column weight sensor (71) adapted to be coupled to an upper driver (51) of the drilling platform (40).
    [0007]
    7. APPLIANCE, according to claim 1, characterized by the fact that at least one of the sensors (61, 65, 67, 69, 71.73, 75) comprises: a penetration rate sensor (73) adapted to be coupled to an upper driver (51) of the drilling platform (40).
    [0008]
    8. APPLIANCE, according to claim 1, characterized by the fact that at least one of the sensors (61, 65, 67, 69, 71.73, 75) comprises: a torque sensor (75) adapted to be coupled to an upper driver (51) of the drilling platform (40).
    [0009]
    9. Apparatus according to claim 1, characterized in that it includes a pressure sensor (61) adapted to be coupled to the wellhead assembly (11) and a return flow rate sensor (67) adapted to be coupled a fluid return line from the drilling platform (40); the control system processor (77) having a database with known wellhead pressure intervals and return flow rates indicative of a formation fluid intrusion event, where the processor has the means to receive and compare signal values of the pressure sensor (61) and the return flow rate sensor (67) with known intervals; and the control system (77) being connected to the eruption preventer (27) to close the eruption preventer (27) autonomously in response to indications of an intrusion event of the formation fluids.
    [0010]
    Apparatus according to claim 9, characterized in that: the eruption preventer (27) has a riser connector (23, 33); and the control system (77) being connected to the connector (23, 33) to autonomously disconnect the rising column (35) from the eruption preventer (27) in response to the indication of an intrusion of the formation fluids.
    [0011]
    11. Apparatus according to claim 9, characterized in that the sensors (61, 65, 67, 69, 71, 73, 75) additionally comprise: a fluid temperature sensor (65) which flows upwardly adapted to be coupled to the set wellhead (11); an inlet flow rate sensor (69) adapted to be coupled to an inlet fluid conduit of the drilling platform (40); and wherein the control system (77) receives a signal from the upwardly flowing fluid temperature sensor (65) and the inlet flow rate sensor (69) for processing.
    [0012]
    12. Apparatus according to claim 9, characterized in that the sensors (61, 65, 67, 69, 71, 73, 75) additionally comprise: a column weight sensor (71) adapted to be coupled to an upper actuator ( 51) of the drilling platform (40); a penetration rate sensor (73) adapted to be coupled to the upper driver (51) of the drilling platform (40); a torque sensor (75) adapted to be coupled to the upper driver (51) of the drilling platform (40); and wherein the control system (77) receives a signal from the column weight sensor (71), the penetration rate sensor (73), and the torque sensor (75) for processing.
    [0013]
    13. METHOD TO PROVIDE AUTOMATIC DETECTION AND CONTROL of an intrusion of the formation fluids during subsea drilling and completion operations with a platform (40) connected to a subsea wellhead assembly (11) through a rising column (35 ) and set of eruption preventers (27), characterized by comprising: coupling sensors (61, 65, 67, 69, 71, 73, 75) to the wellhead assembly (11) and various platform components (40) to indicate conditions inside the well; provide a control system (77) with a database of known sensor values that may be indicative of an intrusion of the formation fluids, and connect the control system (77) to the sensors (61.65, 67, 69, 71.73, 75); with the control system (77), determine the existence of an intrusion event of the formation fluids by comparing the known sensor values to current sensor values received from the sensors (61, 65, 67, 69, 71.73, 75) ; automatically alert operations personnel when a training fluids intrusion event is detected; autonomously close the set of eruption preventers (27) with the control system (77) to control the intrusion of the formation fluids; and autonomously disconnect the rising column (35) from the set of preventers (27) with the control system (77).
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    公开号 | 公开日
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    EP2518261A2|2012-10-31|
    SG10201406569TA|2014-12-30|
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    CN102758619B|2016-12-21|
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    法律状态:
    2014-05-27| B03A| Publication of an application: publication of a patent application or of a certificate of addition of invention|
    2018-12-18| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2019-09-03| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-04-14| B09A| Decision: intention to grant|
    2020-11-17| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 25/04/2012, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US201161479203P| true| 2011-04-26|2011-04-26|
    US61/479,203|2011-04-26|
    US13/328,486|US9019118B2|2011-04-26|2011-12-16|Automated well control method and apparatus|
    US13,328,486|2011-12-16|
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