• 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:
    AUTOMATIC CONTROL OF PRESSURE FOR VERTICAL PIPING IN DRILLING A method of controlling vertical pipe pressure in a drilling operation can include comparing a measured vertical pipe pressure with a desired vertical pipe pressure, and automatically adjusting a choke in response to comparison thereby reducing a difference between the measured vertical pipe pressure and the desired vertical pipe pressure. A vertical pipeline pressure control system for use in a drilling operation can include a controller, which generates an annular pressure setpoint based on a comparison of a measured vertical pipeline pressure with a desired vertical pipeline pressure, and a choke, which is automatically adjusted in response to the annular pressure set point. A well system can include a vertical pipeline line connected to a drilling column in a well hole, a sensor, which measures the pressure in the vertical pipeline line, and a controller, which generates a pressure reference value annul based, at least in part, on a difference between the measured pressure and a desired vertical pipe pressure. (...).
    公开号:BR112013024718B1
    申请号:R112013024718-5
    申请日:2011-04-08
    公开日:2020-10-27
    发明作者:Kjetil Arne Knudsen；Fedrik Varpe
    申请人:Halliburton Energy Services, Inc；
    IPC主号:
    专利说明:

    TECHNICAL FIELD
    The present description refers, in general, to the equipment used and the operations carried out in conjunction with an underground well and, in a modality described here, it provides, more particularly, for the automatic control of the pressure of the vertical drilling pipe. BACKGROUND OF THE INVENTION
    In managed pressure drilling and unbalanced drilling, pressure in the well hole is controlled precisely, for example, by controlling pressure in an annular space on or near the earth's surface. However, in certain circumstances (such as well control situations, etc.), it may be desirable to control the well pressure, by controlling the pressure in a vertical pipe connected to a drill string.
    Therefore, it will be appreciated that advances are needed in the pressure control technique of the well orifice. BRIEF DESCRIPTION OF THE DRAWINGS
    FIG. 1 is a cross-sectional view partially representative of a well system and associated method, which may encompass the principles of the present disclosure.
    FIG. 2 is a representative illustration of a process control system, which can be used with the well and method system of FIG. 1.
    FIG. 3 is a representative illustration of a vertical pipe pressure control system, which can be used with the process control system, method and well system.
    FIG. 4 is a representative illustration of a portion of the vertical pipe pressure control system. DETAILED DESCRIPTION OF THE INVENTION
    Representatively and schematically illustrated in FIG. 1 is a well 10 system and associated method, which can encompass the principles of this disclosure. In system 10, a well hole 12 is drilled by rotating a drill bit 14 at one end of a tubular drill column 16.
    Drilling fluid 18, commonly known as mud, is circulated down through the drill column 16, out of the drill bit 14 and up through an annular space 20 formed between the drill column and the well hole 12, a in order to cool the drill bit, lubricate the drill string, remove cuttings and provide a pressure control measure at the bottom of the hole. A non-return valve 21 (typically a hinged check valve) prevents the flow of drilling fluid 18 upward through the drill string 16 (for example, when connections are being made to the drill string).
    FIG. 5 pressure control at the bottom of the hole is very important in managed pressure and unbalanced drilling, and in other types of well operations. Preferably, the pressure at the bottom of the orifice is precisely controlled to prevent excessive fluid loss in the land formation 64 around the well bore 12, the unwanted fracturing of the formation, the unwanted flow of fluids in the formation in the well orifice, etc.
    In a typical managed pressure drilling, it is desired to maintain the pressure at the bottom of the orifice precisely greater than a pore pressure of formation 64, without exceeding a fracture pressure of the formation. In a typical unbalanced drilling, it is desired to keep the pressure at the bottom of the hole slightly less than a pore pressure, thus obtaining a controlled flow of liquid from the formation 64.
    Nitrogen or other gas, or another lighter weight fluid, can be added to the drilling fluid 18 for pressure control. This technique is especially useful, for example, in unbalanced drilling operations.
    In system 10, additional pressure control at the bottom of the orifice is achieved by closing the annular space 20 (for example, isolating it from communication with the atmosphere and allowing the annular space to be pressurized on or near the surface), using a device rotary control 22 (RCD). RCD 22 seals on the drill column 16 above the top of well 24. Although not shown in FIG. 1, the drill column 16 would extend upward through the RCD 22 for connection to, for example, a turntable (not shown), a vertical pipeline line 26, a drill rod (not shown), a top driver and / or other conventional drilling equipment.
    The drilling fluid 18 leaves the top of the well 24, through a side valve 28, in communication with the annular space 20 below the RCD 22. The fluid 18 then passes through the fluid return line 30 to a pressure choke. set of pipes with valves 32, which includes redundant chokes 34. Back pressure is applied to the annular space 20 by varying the flow of fluid 18 through the choke device (s) 34.
    The greater the restriction to flow through the choke 34, the greater the back pressure applied to the annular space 20. Thus, the pressure of the orifice bottom can be conveniently regulated by the variation of the back pressure applied to the annular space 20. A hydraulic system model can be used, as will be described more fully below, to determine a pressure applied to the annular space 20 on or near the surface that will result in a desired pressure at the bottom of the hole, so that an operator (or by an automatic control system) can readily determine how to regulate the pressure applied to the annular space on or near the surface (which can be conveniently measured) in order to obtain the desired pressure at the bottom of the orifice.
    It may also be desirable to control the pressure at other locations along the orifice of the well 12. For example, the pressure in a casing shoe, at an inclination of a lateral well orifice, usually in vertical or horizontal portions of the well orifice. 12, or anywhere else, can be controlled using the principles of this disclosure.
    The pressure applied to the annular space 20 can be measured at or near the surface by means of a variety of pressure sensors 36, 38, 40, each of which is in communication with the annular space. Pressure sensor 36 detects pressure below RCD 22, but above a preventive set of overflow (uncontrolled flow) safety device (BOP) 42. Pressure sensor 38 detects the pressure at the top of the well below the BOP preventive set 42 Pressure sensor 40 detects the pressure in the fluid return line 30 upstream of the pipe set choke with valves 32.
    Another pressure sensor 44 detects pressure in the vertical pipe line 26. Yet another pressure sensor 46 detects the pressure downstream of the pipe set choke with valves 32, but upstream of a separator 48, agitator 50 and mud tank 52 Additional sensors include temperature sensors 54, 56, Coriolis flow meter 58, and flow meters 62, 66.
    Not all of these sensors are necessary. For example, system 10 could include only one of flow meters 62, 66. However, input from the sensors is useful for the hydraulic model in determining which pressure should be applied to the annular space 20 during the drilling operation.
    In addition, the drill string 16 can include its own sensors 60, for example, to directly measure the pressure at the bottom of the hole. Such sensors 60 may be of the type known to those skilled in the art as perforation during pressure (PWD), perforation during measurement (MWD) and / or perforation during registration (LWD) sensor systems. These drill column sensor systems generally provide at least one pressure measurement, and can also provide temperature measurement, detection of the drill column characteristics (such as vibration, weight on the drill, slip by jerk, etc.) , formation characteristics (such as resistivity, density, etc.) and / or other measurements. Various forms of telemetry (acoustic, pressure pulse, electromagnetic, optical, wired, etc.) can be used to transmit measurements from downhole sensors to the surface. The drill column 16 could be provided with conductors, optical waveguides, etc., for the transmission of data and / or commands between the sensors 60 and the process control system 74 described below (and illustrated in FIG. 2) .
    Additional sensors can be included in system 10, if desired. For example, another flow meter 67 could be used to measure the flow rate of fluid 18, leaving the top of well 24, another Coriolis flow meter (not shown) could be connected directly upstream or downstream of a platform 68 mud pump. , etc.
    Fewer sensors could be included in system 10, if desired. For example, the outlet of the mud pump from platform 68 can be determined by counting the pump cycles, instead of using flow meter 62 or any other flow meters.
    Note that separator 48 could be a phase 3 or 4 separator, or a sludge gas separator (sometimes referred to as a "low quality degasser"). However, separator 48 is not necessarily used in system 10.
    The drilling fluid 18 is pumped through the vertical pipeline line 26 into the drilling column 16 by the platform pump mud pump 68. The pump 68 receives fluid 18 from the mud tank 52 and flows the fluid through from a set of pipes with vertical pipe valves (not shown) to the vertical pipe line 26. Fluid 18 then circulates down through the drill column 16, up through the annular space 20, through the line return of sludge 30, through the pipe set choke with valves 32, and then through separator 48 and agitator 50 to sludge tank 52 for conditioning and recirculation.
    Note that in system 10, as described above, the choke 34 cannot be used to control the back pressure applied to the annular space 20 to control the pressure in the orifice bottom, unless fluid 18 is flowing through the choke . In conventional unbalanced drilling operations, lack of circulation can occur whenever a connection is made to the drill column 16 (for example, to add another length of drill pipe to the drill column as the hole in well 12 is perforated more deeply), and the lack of circulation will require that the pressure at the bottom of the orifice be regulated only by the density of the fluid 18.
    In system 10, however, the flow of fluid 18 through the choke 34 can be maintained, even if the fluid does not circulate through the drill column 16 and the annular space 20. Thus, pressure can still be applied to the annular space 20 , restricting the flow of fluid 18 through the choke 34.
    In system 10, as shown in FIG. 1, a back pressure pump 70 can be used to supply a flow of fluid to the return line 30 upstream of the pipe set choke with valves 32 by pumping fluid into the annular space 20 when necessary (such as when connections are being made in the drill column 16). As shown in FIG. 1, the pump 70 is connected to the annular space 20 by means of the preventive assembly BOP 42, but in other examples, the pump 70 could be connected to the return line 30, or to the pipe set choke with valves 32.
    Alternatively, or in addition, the fluid can be diverted from the set of pipes with vertical pipe valves (or otherwise from the platform 68 pump), to the return line 30, when necessary, as described in International Order Serial No. PCT / US08 / 87686, as described in US Order Serial No. US 13 / 022.964, or using other techniques.
    Strangler 34 restriction of such fluid flow from the platform pump 68, and / or the back pressure pump 70 will thus induce pressure to be applied to the annular space 20. If the back pressure pump 70 is implemented, a flow meter 72 can be used to measure the pump output.
    The choke 34 and the back pressure pump 70 are examples of pressure control devices, which can be used to control the pressure within the annular space 20 close to the surface. Other types of pressure control devices (such as those described in International Order Serial No. PCT / US08 / 87 68 6, and in US Order Serial No. US 13 / 022.964, etc.) may be used, if desired .
    Referring to FIG. 2, in addition, now, a block diagram of an example of a process control system 74 is represented illustratively. In other examples, the process control system 74 may include other numbers, types, combinations, etc., of elements, and in any of the elements it may be positioned in different locations or integrated with another element, according to the scope of the present disclosure.
    As shown in FIG. 2, the process control system 74 includes a control and data acquisition interface 118, a hydraulic system model 120, a prognostic device 122, a data validator 124 and a controller 126. These elements may be similar to described in International Order Serial No. PCT / US10 / 56433 filed on November 12, 2010.
    The hydraulic system model 120 is used to determine a desired pressure in the annular space 20 to thereby achieve a desired pressure in the orifice of the well 12. The hydraulic system model 120, using data such as the depth of the well, rpm of the drilling column, speed of execution, type of mud, etc., the models of the well orifice 12, the drilling column 16, the fluid flow through the drilling column and the annular space 20 (including the circulation density equivalent due to such a flow), etc.
    The data acquisition and control interface 118 receives this data from the various sensors 36, 38, 40, 44, 46, 54, 56, 58, 60, 62, 66, 67, 72, together with the platform data and downhole and relays that data to the hydraulic system model 120 and data validator 124. In addition, interface 118 relays the desired annular pressure from hydraulic system model 120 to data validator 124.
    The prognostic device 122 can be included in this example to determine, based on the previous data, which sensor data must currently be received and which annular pressure should be desired. The prognostic device 122 may comprise a neural network, a genetic algorithm, a fuzzy logic, etc., or any combination of prognostic elements to produce predictions of the sensor data and desired annular pressure.
    Data validator 124 uses these predictions to determine whether any of the data from the particular sensor is valid, whether the annular pressure output desired by the hydraulic system model 120 is adequate, etc. If appropriate, data validator 124 transmits the desired annular pressure to controller 126 (such as a programmable logic controller, which may include a proportional integral derivative controller (PID)), which controls the operation of the throttle 34, the pump 70 and the various flow control devices 128 (such as valves, etc.).
    In this way, the choke 60, pump 70 and flow control devices 128 can be automatically controlled to achieve and maintain the desired pressure in the annular space 20. The actual pressure in the annular space 20 is typically measured at or near the top of the well 24 (for example, by means of sensors 36, 38, 40), which can be in a terrestrial or submarine location.
    Referring to FIG. 3, in addition, now, represented in a schematic form, is a vertical pipe pressure control system 80, which can be used with well system 10 and / or process control system 74. Naturally, the system Vertical pipe pressure control 80 can be used with other well systems and other process control systems, in accordance with the principles of this disclosure.
    In the example shown in FIG. 3, controller 126 can be used to control the operation of the choke 34 based on one selected from one of the three possible annular pressure setpoint sources. The selection of the annular pressure reference value source is performed by an operator using a human-machine interface (HMI) 82, such as a properly configured computer, monitor, etc., and / or event detection software. The reference pressure source of the annular pressure can be selected via HMI 82, or it can be selected automatically by the control logic.
    Annular pressure is sometimes referred to as the wellhead pressure, as it is usually measured at or near the top of the well 24. However, in some situations (such as subsea drilling operations, etc.), the pressure in the annular space 20 may not be measured at the top of the well 24, or at least the pressure in the annular space 20 measured at the top of the well cannot be used to control the pressure in the well well 12. For example, the pressure in the annular space 20 measured at a location on the surface, or semi-submerged floating platform, etc., it can possibly be used to control the pressure in the well well 12. In this description, the top well pressure is assumed to be synonymous with annular pressure, but it must be clearly understood that, in other examples, the annular pressure cannot be measured at the top of the well, or as a pressure measurement of the top of the well cannot be used to control the pressure of the well orifice.
    Using the human-machine interface 82, the operator can select to control the well-hole pressure using or a well-top pressure reference value (WHP) 84 manually entered for the human-machine interface, a reference value of wellhead pressure 86 resulting from process control system 74 as described above, or a wellhead pressure reference value 88 taken from a controller 90.
    Controller 126 may include a proportional integral differential controller (PID) and may be implemented in a programmable logic controller (PLC) of the types well known to those skilled in the art. The proportional integral differential controller operates on the basis of the difference between the selected wellhead pressure reference value 84, 86, or 88, and the measured wellhead pressure (for example, by means of sensors 36, 38 or 40 ).
    The proportional integral differential controller determines whether or how the throttle 34, pump 70, other flow control devices 128, etc., should be adjusted to minimize the difference e. The programmable logic controller adjusts throttle 34, etc., based on the output of the proportional integral differential controller. Of course, process control devices, except a proportional integral differential controller and / or a programmable logic controller can be used, if desired.
    The pressure reference value of the top of the well 88 is selected by the operator, if the operator wants to control the pressure of the well orifice based on the pressure measured in the vertical pipe line 26 (for example, measured using sensor 44). A situation that may be desired is in a well control process, for example, following a flow of fluid into the well orifice 12 from formation 64.
    Controller 90 (which can comprise a proportional integral differential controller) receives a difference between a desired vertical pipe pressure (SPP) 92, which can be entered manually via the human-machine interface 82, and the vertical pipe pressure measure 94 (for example, measured using pressure sensor 44). Controller 90 determines whether or what the wellhead pressure should be adjusted to minimize the difference e, and generates the appropriate desired wellhead pressure reference value 88 for selection using the human machine interface 82.
    Preferably, controllers 90, 126 operate via cascade control, with an external circuit (including controller 90 and sensor 44) to control the pressure in the vertical piping, and an internal circuit (including controller 126, the sensor 40, the throttle 34, the pump 70 and other flow control devices 128) to control the pressure from the top of the well. More preferably, the dynamics of the internal circuit (for example, the frequency of comparisons between the measured wellhead pressure 96 and the selected wellhead pressure reference value 88) is at least four times the dynamics of the external circuit ( for example, the frequency of comparisons between the measured vertical pipe pressure 94 and the desired vertical pipe pressure 92).
    The proportional integral differential controller of controller 90 can base its calculations on the following equation 1:
    where u is the reference value of the outlet pressure from the top of well 88, k is an indicator of the sequence (with k being a present sample, k-1, being the next previous sample, k-2 being two previous samples) , Kp is a gain for controller 90, Ts is a sampling interval, Td is a derived time, Ti is an integral time, and e is the difference between the desired vertical pipe pressure 92 and the measured vertical pipe pressure 94.
    Referring to FIG. 4, in addition, now, a schematic view of a portion of the vertical pipe pressure control system 80 is illustrated representatively. From this point of view, it can be seen that the controller 90 receives the desired vertical piping pressure 92 from an initialization module 98.
    Module 98 supplies controller 90 with initial values for some variables at startup. The desired vertical pipeline pressure 92 is preferably entered via the human-machine interface 82. Alternatively, an initial setpoint pressure value for wellhead 100 can be provided to controller 90 via module 98. The setpoint The initial pressure of the wellhead pressure 100 can be based on the last reference value of the pressure of the wellhead 88 supplied to controller 126 by controller 90.
    Certain configuration data 102 can be entered by an operator through the human-machine interface 82 and supplied with module 98 and controller 90. Data 102 can include maximum and minimum values allowed for the production of controller 90, the gain of the controller, the integral times and derivatives, and the sampling interval. Preferably, all of these variables (with the exception of the sampling interval) can be changed by the operator during the pressure control operation.
    The prognostic device 122 and data validator 124 can be used to validate the wellhead pressure setpoint 88 generated by controller 90. Thus, a wellhead pressure setpoint 88 out of range or wrong can be prevented from entering controller 126.
    The pressure of the vertical pipeline is effectively being controlled when the reference value of the wellhead pressure 88 generated by the controller 90 is selected to be used by the controller 126 to control the pressure of the wellhead. This is because the pressure reference value of the top of the well 88 is adjusted by the controller 90 to minimize the difference between the desired vertical pipe pressure 92 and the measured vertical pipe pressure 94. Thus, the throttle 34, the pump 70 and / or other flow control devices 128 are controlled by controller 126, so that the pressure in the vertical pipeline is maintained at the desired level.
    It can now be duly appreciated that this disclosure provides several advances in the pressure control technique of the well orifice. The vertical pipe pressure control system 80 described above can be used to regulate the operation of a process control system 74, whereby a desired vertical pipe pressure 92 is maintained.
    The above disclosure provides the technique with a method for controlling the pressure in the vertical pipeline of a drilling operation. The method may include comparing a measured vertical pipe pressure 94 with a desired vertical pipe pressure 92, and automatically adjusting a choke 34 in response to the comparison, thereby reducing a difference between the measured vertical pipe pressure 94 and the desired vertical pipe pressure 92.
    The choke 34 receives fluid 18, while a pump from platform 68 pumps the fluid through a drill column 16. Automatically adjusting the choke 34 can include a controller 90 producing an annular pressure setpoint 88. Controller 90 can comprise a proportional integral differential controller.
    Automatically adjusting the choke 34 can also include comparing a measured annular pressure 96 with the annular pressure setpoint 88, and automatically adjusting the choke 34 so that a difference between the measured annular pressure 96 and the setpoint annular pressure 88 is reduced. The comparison of the annular pressure measured 96 with the reference value of the annular pressure 88 can be performed at least four times as frequently as comparing the pressure of the vertical pipe measured 94 with the pressure of the desired vertical pipe 92.
    Also described above, it is a vertical pipe pressure control system 80 for use in a drilling operation. System 80 may include a controller 90, which generates an annular pressure setpoint 88 based on a comparison of a measured vertical pipe pressure 94 with a desired vertical pipe pressure 92, and a choke 34, which is automatically adjusted in response to the annular pressure setpoint 88.
    The automatic adjustment of the choke 34 preferably reduces the difference between the vertical pipe pressure measured 94 and the desired vertical pipe pressure 92.
    Another controller 126 can compare a measured annular pressure 96 with the annular pressure reference value 88. The automatic adjustment of the throttle 34 preferably reduces a difference between the measured annular pressure 96 and the annular pressure reference value 88.
    The measured annular pressure 96 is preferably measured against the reference value of the wellhead pressure 88, at least four times as frequent as the pressure of the vertical pipe 94, is compared to the pressure of the desired vertical pipe 92.
    The above disclosure also describes a well system 10, which can include a vertical pipe line 26 connected to a drill column 16 in a well 12 hole, a sensor 44 that measures pressure in the vertical pipe line 26, and a controller 90, which generates an annular pressure reference value 88 based, at least in part, on a difference between the measured pressure 94, and the desired vertical pipe pressure of 92.
    It is to be understood that the various modalities of the present disclosure described here can be used in various orientations, such as inclined, inverted, horizontal, vertical, etc., and in various configurations, without departing from the principles of this disclosure. The modalities are described merely as examples of useful applications of the disclosure principles, which are not limited to the specific details of these modalities.
    Naturally, a person skilled in the art, upon careful consideration of the description above the representative modalities of the description, would readily realize that many modifications, additions, substitutions, deletions and other modifications can be made to specific modalities, and such modifications are contemplated by the principles of this disclosure. Thus, the description detailed above is to be clearly understood as being provided by way of illustration and only as an example, the scope and scope of the present invention being limited only by the appended claims and their equivalents.
    权利要求:
    Claims (17)
    [0001]
    1. Method of controlling the pressure of the vertical pipe in a drilling operation, the method CHARACTERIZED by the fact that it comprises: comparing a measured vertical pipe pressure (94) with a desired vertical pipe pressure (92) while extending from a hole the well; generate an annular pressure reference value (88) based on the comparison; and automatically adjusting a choke (34) in response to the generation, thereby reducing a difference between the measured vertical pipe pressure (94) and the desired vertical pipe pressure (92).
    [0002]
    2. Method, according to claim 1, CHARACTERIZED by the fact that the choke (34) receives the fluid (18) while a platform pump (68) pumps the fluid through a drilling column (16).
    [0003]
    3. Method, according to claim 1, CHARACTERIZED by the fact that it automatically adjusts the choke (34) further comprising a controller (90) generating the reference value of the annular pressure (88).
    [0004]
    4. Method, according to claim 3, CHARACTERIZED by the fact that automatically adjusting the choke (34) also comprises comparing a measured annular pressure (96) with the reference value of the annular pressure (88), and automatically adjusting the choke (34) so that a difference between the measured annular pressure (96) and the annular pressure reference value (88) is reduced.
    [0005]
    5. Method, according to claim 4, CHARACTERIZED by the fact that the comparison between the measured annular pressure (96) and the reference value of the annular pressure (88) is performed at least four times as frequently as the comparison between the measured vertical pipe pressure (94) and the desired vertical pipe pressure (92).
    [0006]
    6. Method, according to claim 3, CHARACTERIZED by the fact that the controller (90) comprises a proportional integral differential controller.
    [0007]
    7. Vertical pipe pressure control system (80) for use in a drilling operation, the system FEATURED by the fact that it comprises: a first controller (90), which generates a reference value for the annular pressure (88) based on the comparison between a measured vertical pipe pressure (94) and a desired vertical pipe pressure (92); and a choke (34), which is automatically adjusted in response to the annular pressure set point (88), in which the automatic adjustment of the choke (34) reduces the difference between the measured vertical pipe pressure (94) and the desired vertical pipe pressure (92).
    [0008]
    8. System, according to claim 7, CHARACTERIZED by the fact that the choke (34) receives fluid (18) while the platform pump (68) pumps the fluid through a drilling column (16).
    [0009]
    9. System according to claim 7, CHARACTERIZED by the fact that a second controller (126) compares a measured annular pressure (96) with the reference value of the annular pressure (88).
    [0010]
    10. System according to claim 9, CHARACTERIZED by the fact that the automatic adjustment of the choke (34) reduces the difference between the measured annular pressure (96) and the reference value of the annular pressure (88).
    [0011]
    11. System according to claim 9, CHARACTERIZED by the fact that the measured annular pressure (96) is compared to the reference value of the annular pressure (88), at least four times as frequent as the pressure of the measured vertical pipe (94) is compared with the desired vertical pipe pressure (92).
    [0012]
    12. System according to claim 7, CHARACTERIZED by the fact that the first controller (90) comprises a proportional integral differential controller.
    [0013]
    13. Well system (10), CHARACTERIZED by the fact that it comprises: a vertical pipe line (26) connected to a drilling column (16) in a well hole (12); a sensor (44), which measures the pressure (94) in the vertical pipeline (26); a first controller (90), which generates an annular pressure reference value (88) based, at least in part, on a difference between the measured pressure and the desired vertical pipe pressure (92); and a choke (34), which is automatically adjusted in response to the annular pressure set point (88), in which the automatic adjustment of the choke (34) reduces the difference between the measured pressure and the desired vertical pipe pressure.
    [0014]
    14. System, according to claim 13, CHARACTERIZED by the fact that a second controller (126) compares the measured annular pressure (96) with the reference value of the annular pressure (88).
    [0015]
    15. System according to claim 14, CHARACTERIZED by the fact that the automatic adjustment of the choke (34) reduces the difference between the measured annular pressure (96) and the reference value of the annular pressure (88).
    [0016]
    16. System, according to claim 14, CHARACTERIZED by the fact that the measured annular pressure (96) is compared with the annular pressure reference value (88), at least four times as frequent as the vertical pipe pressure measure (94) is compared with the desired vertical pipe pressure (92).
    [0017]
    17. System according to claim 13, CHARACTERIZED by the fact that the first controller (90) comprises a proportional integral differential controller.
    类似技术:
    公开号 | 公开日 | 专利标题
    BR112013024718B1|2020-10-27|vertical pipe pressure control method and system for use in a drilling operation and well system
    US10233708B2|2019-03-19|Pressure and flow control in drilling operations
    US9249638B2|2016-02-02|Wellbore pressure control with optimized pressure drilling
    BRPI0413251B1|2015-09-29|DRILLING SYSTEM AND METHOD FOR DRILLING A DRILLING HOLE IN A GEOLOGICAL FORMATION
    BR112014013215B1|2021-05-04|well drilling method
    US10047578B2|2018-08-14|Pressure control in drilling operations with choke position determined by Cv curve
    BRPI0706315A2|2011-03-22|methods for determining the existence of a well control event and for controlling the formation pressure while drilling a borehole through an underground formation
    US8240398B2|2012-08-14|Annulus pressure setpoint correction using real time pressure while drilling measurements
    BR112014032853B1|2021-01-26|method of controlling pressure in a well bore in a well drilling operation, and, well system
    CA2801695C|2015-08-11|Annulus pressure setpoint correction using real time pressure while drilling measurements
    CA2831039C|2016-08-23|Wellbore pressure control with optimized pressure drilling
    BR112014010960B1|2021-08-31|METHOD FOR CONTROLLING PRESSURE IN A WELL
    MX2014010132A|2014-09-08|Well drilling systems and methods with pump drawing fluid from annulus.
    EP2707570A1|2014-03-19|Pressure and flow control in drilling operations
    BR112014032979B1|2021-09-28|PRESSURE CONTROL METHOD IN A WELL HOLE AND SYSTEM FOR DRILLING A WELL HOLE
    同族专利:
    公开号 | 公开日
    WO2012138349A1|2012-10-11|
    CA2827935A1|2012-10-11|
    CA2827935C|2015-11-17|
    AU2011364954B2|2016-03-24|
    EP2694772A1|2014-02-12|
    CN103459755A|2013-12-18|
    EP2694772A4|2016-02-24|
    MX2013011657A|2013-11-01|
    RU2553751C2|2015-06-20|
    CN103459755B|2016-04-27|
    BR112013024718A2|2016-12-20|
    RU2013148471A|2015-05-20|
    US8833488B2|2014-09-16|
    US20120255776A1|2012-10-11|
    MY168333A|2018-10-30|
    AU2011364954A1|2013-09-12|
    引用文献:
    公开号 | 申请日 | 公开日 | 申请人 | 专利标题
    US3387851A|1966-01-12|1968-06-11|Shaffer Tool Works|Tandem stripper sealing apparatus|
    US3362487A|1966-05-03|1968-01-09|Swaco Inc|Control for a hydraulically actuated choke in a drilling mud flow line|
    US3443643A|1966-12-30|1969-05-13|Cameron Iron Works Inc|Apparatus for controlling the pressure in a well|
    US3429385A|1966-12-30|1969-02-25|Cameron Iron Works Inc|Apparatus for controlling the pressure in a well|
    US3552502A|1967-12-21|1971-01-05|Dresser Ind|Apparatus for automatically controlling the killing of oil and gas wells|
    US3603409A|1969-03-27|1971-09-07|Regan Forge & Eng Co|Method and apparatus for balancing subsea internal and external well pressures|
    US3677353A|1970-07-15|1972-07-18|Cameron Iron Works Inc|Apparatus for controlling well pressure|
    US3815673A|1972-02-16|1974-06-11|Exxon Production Research Co|Method and apparatus for controlling hydrostatic pressure gradient in offshore drilling operations|
    US3827511A|1972-12-18|1974-08-06|Cameron Iron Works Inc|Apparatus for controlling well pressure|
    US3971926A|1975-05-28|1976-07-27|Halliburton Company|Simulator for an oil well circulation system|
    US4046191A|1975-07-07|1977-09-06|Exxon Production Research Company|Subsea hydraulic choke|
    US4063602A|1975-08-13|1977-12-20|Exxon Production Research Company|Drilling fluid diverter system|
    US4091881A|1977-04-11|1978-05-30|Exxon Production Research Company|Artificial lift system for marine drilling riser|
    US4099583A|1977-04-11|1978-07-11|Exxon Production Research Company|Gas lift system for marine drilling riser|
    US4234043A|1977-10-17|1980-11-18|Baker International Corporation|Removable subsea test valve system for deep water|
    FR2407337B1|1977-10-27|1983-01-21|Petroles Cie Francaise|
    US4436157A|1979-08-06|1984-03-13|Baker International Corporation|Latch mechanism for subsea test tree|
    US4291772A|1980-03-25|1981-09-29|Standard Oil Company |Drilling fluid bypass for marine riser|
    US4355784A|1980-08-04|1982-10-26|Warren Automatic Tool Company|Method and apparatus for controlling back pressure|
    US4468056A|1981-10-05|1984-08-28|The B. F. Goodrich Company|Swivel|
    US4502534A|1982-12-13|1985-03-05|Hydril Company|Flow diverter|
    US4832126A|1984-01-10|1989-05-23|Hydril Company|Diverter system and blowout preventer|
    US4626135A|1984-10-22|1986-12-02|Hydril Company|Marine riser well control method and apparatus|
    US4685521A|1985-04-17|1987-08-11|Raulins George M|Well apparatus|
    US4682913A|1986-08-28|1987-07-28|Shell Offshore Inc.|Hydraulic stab connector|
    US4813495A|1987-05-05|1989-03-21|Conoco Inc.|Method and apparatus for deepwater drilling|
    US4880060A|1988-08-31|1989-11-14|Halliburton Company|Valve control system|
    GB2229787A|1989-03-28|1990-10-03|Derek William Frank Clarke|A mobile emergency shut off valve system|
    US5006845A|1989-06-13|1991-04-09|Honeywell Inc.|Gas kick detector|
    US5154078A|1990-06-29|1992-10-13|Anadrill, Inc.|Kick detection during drilling|
    US5303582A|1992-10-30|1994-04-19|New Mexico Tech Research Foundation|Pressure-transient testing while drilling|
    US5444619A|1993-09-27|1995-08-22|Schlumberger Technology Corporation|System and method of predicting reservoir properties|
    FR2726858B1|1994-11-14|1997-02-07|
    US5887657A|1995-02-09|1999-03-30|Baker Hughes Incorporated|Pressure test method for permanent downhole wells and apparatus therefore|
    US6012015A|1995-02-09|2000-01-04|Baker Hughes Incorporated|Control model for production wells|
    GB9514510D0|1995-07-15|1995-09-13|Expro North Sea Ltd|Lightweight intervention system|
    US6021377A|1995-10-23|2000-02-01|Baker Hughes Incorporated|Drilling system utilizing downhole dysfunctions for determining corrective actions and simulating drilling conditions|
    US5720356A|1996-02-01|1998-02-24|Gardes; Robert|Method and system for drilling underbalanced radial wells utilizing a dual string technique in a live well|
    US7185718B2|1996-02-01|2007-03-06|Robert Gardes|Method and system for hydraulic friction controlled drilling and completing geopressured wells utilizing concentric drill strings|
    US6457540B2|1996-02-01|2002-10-01|Robert Gardes|Method and system for hydraulic friction controlled drilling and completing geopressured wells utilizing concentric drill strings|
    US6065550A|1996-02-01|2000-05-23|Gardes; Robert|Method and system for drilling and completing underbalanced multilateral wells utilizing a dual string technique in a live well|
    US6035952A|1996-05-03|2000-03-14|Baker Hughes Incorporated|Closed loop fluid-handling system for use during drilling of wellbores|
    US5862863A|1996-08-26|1999-01-26|Swisher; Mark D.|Dual completion method for oil/gas wells to minimize water coning|
    US6315051B1|1996-10-15|2001-11-13|Coupler Developments Limited|Continuous circulation drilling method|
    US6002985A|1997-05-06|1999-12-14|Halliburton Energy Services, Inc.|Method of controlling development of an oil or gas reservoir|
    NO974348L|1997-09-19|1999-03-22|Petroleum Geo Services As|Device and method for controlling rise margin|
    US6273193B1|1997-12-16|2001-08-14|Transocean Sedco Forex, Inc.|Dynamically positioned, concentric riser, drilling method and apparatus|
    US6101447A|1998-02-12|2000-08-08|Schlumberger Technology Corporation|Oil and gas reservoir production analysis apparatus and method|
    US6913092B2|1998-03-02|2005-07-05|Weatherford/Lamb, Inc.|Method and system for return of drilling fluid from a sealed marine riser to a floating drilling rig while drilling|
    US6263982B1|1998-03-02|2001-07-24|Weatherford Holding U.S., Inc.|Method and system for return of drilling fluid from a sealed marine riser to a floating drilling rig while drilling|
    US6138774A|1998-03-02|2000-10-31|Weatherford Holding U.S., Inc.|Method and apparatus for drilling a borehole into a subsea abnormal pore pressure environment|
    US6102673A|1998-03-27|2000-08-15|Hydril Company|Subsea mud pump with reduced pulsation|
    US6325159B1|1998-03-27|2001-12-04|Hydril Company|Offshore drilling system|
    US6230824B1|1998-03-27|2001-05-15|Hydril Company|Rotating subsea diverter|
    RU2148698C1|1998-07-14|2000-05-10|Открытое акционерное общество "Северо-Кавказский научно-исследовательский проектный институт природных газов" Открытого акционерного общества "Газпром"|Method for opening of productive gas-bearing bed by drilling|
    US7721822B2|1998-07-15|2010-05-25|Baker Hughes Incorporated|Control systems and methods for real-time downhole pressure management |
    US7096975B2|1998-07-15|2006-08-29|Baker Hughes Incorporated|Modular design for downhole ECD-management devices and related methods|
    US7174975B2|1998-07-15|2007-02-13|Baker Hughes Incorporated|Control systems and methods for active controlled bottomhole pressure systems|
    US7270185B2|1998-07-15|2007-09-18|Baker Hughes Incorporated|Drilling system and method for controlling equivalent circulating density during drilling of wellbores|
    US7806203B2|1998-07-15|2010-10-05|Baker Hughes Incorporated|Active controlled bottomhole pressure system and method with continuous circulation system|
    US8011450B2|1998-07-15|2011-09-06|Baker Hughes Incorporated|Active bottomhole pressure control with liner drilling and completion systems|
    US6415877B1|1998-07-15|2002-07-09|Deep Vision Llc|Subsea wellbore drilling system for reducing bottom hole pressure|
    US7159669B2|1999-03-02|2007-01-09|Weatherford/Lamb, Inc.|Internal riser rotating control head|
    EP1157189B1|1999-03-02|2006-11-22|Weatherford/Lamb, Inc.|Internal riser rotating control head|
    EG22117A|1999-06-03|2002-08-30|Exxonmobil Upstream Res Co|Method and apparatus for controlling pressure and detecting well control problems during drilling of an offshore well using a gas-lifted riser|
    US6853921B2|1999-07-20|2005-02-08|Halliburton Energy Services, Inc.|System and method for real time reservoir management|
    US6732798B2|2000-03-02|2004-05-11|Schlumberger Technology Corporation|Controlling transient underbalance in a wellbore|
    US6173768B1|1999-08-10|2001-01-16|Halliburton Energy Services, Inc.|Method and apparatus for downhole oil/water separation during oil well pumping operations|
    US6328107B1|1999-09-17|2001-12-11|Exxonmobil Upstream Research Company|Method for installing a well casing into a subsea well being drilled with a dual density drilling system|
    US7096976B2|1999-11-05|2006-08-29|Halliburton Energy Services, Inc.|Drilling formation tester, apparatus and methods of testing and monitoring status of tester|
    US6450262B1|1999-12-09|2002-09-17|Stewart & Stevenson Services, Inc.|Riser isolation tool|
    GB9930450D0|1999-12-23|2000-02-16|Eboroil Sa|Subsea well intervention vessel|
    US6598682B2|2000-03-02|2003-07-29|Schlumberger Technology Corp.|Reservoir communication with a wellbore|
    WO2001073261A2|2000-03-27|2001-10-04|Rockwater Limited|Riser with retrievable internal services|
    US6547002B1|2000-04-17|2003-04-15|Weatherford/Lamb, Inc.|High pressure rotating drilling head assembly with hydraulically removable packer|
    NO312312B1|2000-05-03|2002-04-22|Psl Pipeline Process Excavatio|Device by well pump|
    GB2362398B|2000-05-16|2002-11-13|Fmc Corp|Device for installation and flow test of subsea completions|
    MXPA02009772A|2000-05-22|2003-03-27|Robert A Gardes|Method for controlled drilling and completing of wells.|
    US6530437B2|2000-06-08|2003-03-11|Maurer Technology Incorporated|Multi-gradient drilling method and system|
    AU7264201A|2000-07-19|2002-01-30|Schlumberger Technology Bv|A method of determining properties relating to an underbalanced well|
    CA2448404A1|2001-04-25|2002-11-07|Halliburton Energy Services, Inc.|Method, system and tool for reservoir evaluation and well testing during drilling operations|
    US6585044B2|2000-09-20|2003-07-01|Halliburton Energy Services, Inc.|Method, system and tool for reservoir evaluation and well testing during drilling operations|
    US6374925B1|2000-09-22|2002-04-23|Varco Shaffer, Inc.|Well drilling method and system|
    NO313924B1|2000-11-02|2002-12-23|Agr Services As|Flushing tool for internal cleaning of vertical riser, as well as method for the same|
    US6474422B2|2000-12-06|2002-11-05|Texas A&M University System|Method for controlling a well in a subsea mudlift drilling system|
    US20020112888A1|2000-12-18|2002-08-22|Christian Leuchtenberg|Drilling system and method|
    GB0101259D0|2001-01-18|2001-02-28|Wellserv Plc|Apparatus and method|
    US6484816B1|2001-01-26|2002-11-26|Martin-Decker Totco, Inc.|Method and system for controlling well bore pressure|
    US6920085B2|2001-02-14|2005-07-19|Halliburton Energy Services, Inc.|Downlink telemetry system|
    US7093662B2|2001-02-15|2006-08-22|Deboer Luc|System for drilling oil and gas wells using a concentric drill string to deliver a dual density mud|
    US7992655B2|2001-02-15|2011-08-09|Dual Gradient Systems, Llc|Dual gradient drilling method and apparatus with multiple concentric drill tubes and blowout preventers|
    US7090036B2|2001-02-15|2006-08-15|Deboer Luc|System for drilling oil and gas wells by varying the density of drilling fluids to achieve near-balanced, underbalanced, or overbalanced drilling conditions|
    US6926101B2|2001-02-15|2005-08-09|Deboer Luc|System and method for treating drilling mud in oil and gas well drilling applications|
    WO2002068787A2|2001-02-23|2002-09-06|Exxonmobil Upstream Research Company|Method and apparatus for controlling bottom-hole pressure during dual-gradient drilling|
    US6802379B2|2001-02-23|2004-10-12|Exxonmobil Upstream Research Company|Liquid lift method for drilling risers|
    US6901391B2|2001-03-21|2005-05-31|Halliburton Energy Services, Inc.|Field/reservoir optimization utilizing neural networks|
    CA2803812C|2001-09-10|2015-11-17|Ocean Riser Systems As|Arrangement and method for regulating bottom hole pressures when drilling deepwater offshore wells|
    EP1432887B1|2001-09-14|2006-03-29|Shell Internationale Researchmaatschappij B.V.|System for controlling the discharge of drilling fluid|
    US6957698B2|2002-09-20|2005-10-25|Baker Hughes Incorporated|Downhole activatable annular seal assembly|
    GB2416559B|2001-09-20|2006-03-29|Baker Hughes Inc|Active controlled bottomhole pressure system & method|
    US6981561B2|2001-09-20|2006-01-03|Baker Hughes Incorporated|Downhole cutting mill|
    US6745857B2|2001-09-21|2004-06-08|National Oilwell Norway As|Method of drilling sub-sea oil and gas production wells|
    US7023691B1|2001-10-26|2006-04-04|E.O. Schweitzer Mfg. Llc|Fault Indicator with permanent and temporary fault indication|
    CA2468732A1|2001-12-03|2003-06-12|Shell Canada Limited|Method for formation pressure control while drilling|
    US7797139B2|2001-12-07|2010-09-14|Chevron U.S.A. Inc.|Optimized cycle length system and method for improving performance of oil wells|
    US20030111799A1|2001-12-19|2003-06-19|Cooper Cameron Corporation|Seal for riser assembly telescoping joint|
    US20030121667A1|2001-12-28|2003-07-03|Alfred Massie|Casing hanger annulus monitoring system|
    US7027968B2|2002-01-18|2006-04-11|Conocophillips Company|Method for simulating subsea mudlift drilling and well control operations|
    US6904981B2|2002-02-20|2005-06-14|Shell Oil Company|Dynamic annular pressure control apparatus and method|
    EP1488073B2|2002-02-20|2012-08-01|@Balance B.V.|Dynamic annular pressure control apparatus and method|
    US7185719B2|2002-02-20|2007-03-06|Shell Oil Company|Dynamic annular pressure control apparatus and method|
    NO316183B1|2002-03-08|2003-12-22|Sigbjoern Sangesland|Method and apparatus for feeding tubes|
    US6892812B2|2002-05-21|2005-05-17|Noble Drilling Services Inc.|Automated method and system for determining the state of well operations and performing process evaluation|
    US6732804B2|2002-05-23|2004-05-11|Weatherford/Lamb, Inc.|Dynamic mudcap drilling and well control system|
    US7836973B2|2005-10-20|2010-11-23|Weatherford/Lamb, Inc.|Annulus pressure control drilling systems and methods|
    GB2405891B|2002-07-08|2005-11-16|Shell Int Research|Choke for controlling the flow of drilling mud|
    GB2391880B|2002-08-13|2006-02-22|Reeves Wireline Tech Ltd|Apparatuses and methods for deploying logging tools and signalling in boreholes|
    US6820702B2|2002-08-27|2004-11-23|Noble Drilling Services Inc.|Automated method and system for recognizing well control events|
    US20040065440A1|2002-10-04|2004-04-08|Halliburton Energy Services, Inc.|Dual-gradient drilling using nitrogen injection|
    US7040394B2|2002-10-31|2006-05-09|Weatherford/Lamb, Inc.|Active/passive seal rotating control head|
    US8826988B2|2004-11-23|2014-09-09|Weatherford/Lamb, Inc.|Latch position indicator system and method|
    US7926593B2|2004-11-23|2011-04-19|Weatherford/Lamb, Inc.|Rotating control device docking station|
    US8132630B2|2002-11-22|2012-03-13|Baker Hughes Incorporated|Reverse circulation pressure control method and system|
    US7055627B2|2002-11-22|2006-06-06|Baker Hughes Incorporated|Wellbore fluid circulation system and method|
    US6662110B1|2003-01-14|2003-12-09|Schlumberger Technology Corporation|Drilling rig closed loop controls|
    US6920942B2|2003-01-29|2005-07-26|Varco I/P, Inc.|Method and apparatus for directly controlling pressure and position associated with an adjustable choke apparatus|
    NO318220B1|2003-03-13|2005-02-21|Ocean Riser Systems As|Method and apparatus for performing drilling operations|
    US20060186617A1|2003-07-11|2006-08-24|Ryan Farrelly|Personal transportation device for supporting a user's foot having multiple transportation attachments|
    EP1664478B1|2003-08-19|2006-12-27|Shell Internationale Researchmaatschappij B.V.|Drilling system and method|
    US7320370B2|2003-09-17|2008-01-22|Schlumberger Technology Corporation|Automatic downlink system|
    US7237623B2|2003-09-19|2007-07-03|Weatherford/Lamb, Inc.|Method for pressurized mud cap and reverse circulation drilling from a floating drilling rig using a sealed marine riser|
    EP1519003B1|2003-09-24|2007-08-15|Cooper Cameron Corporation|Removable seal|
    US7032691B2|2003-10-30|2006-04-25|Stena Drilling Ltd.|Underbalanced well drilling and production|
    US20050092523A1|2003-10-30|2005-05-05|Power Chokes, L.P.|Well pressure control system|
    CN100353027C|2003-10-31|2007-12-05|中国石油化工股份有限公司|Under balance drilling bottom pressure automatic control system and method|
    NO319213B1|2003-11-27|2005-06-27|Agr Subsea As|Method and apparatus for controlling drilling fluid pressure|
    US7337660B2|2004-05-12|2008-03-04|Halliburton Energy Services, Inc.|Method and system for reservoir characterization in connection with drilling operations|
    US7278497B2|2004-07-09|2007-10-09|Weatherford/Lamb|Method for extracting coal bed methane with source fluid injection|
    US7237613B2|2004-07-28|2007-07-03|Vetco Gray Inc.|Underbalanced marine drilling riser|
    NO321854B1|2004-08-19|2006-07-17|Agr Subsea As|System and method for using and returning drilling mud from a well drilled on the seabed|
    WO2006041820A2|2004-10-04|2006-04-20|M-I L.L.C.|Modular pressure control and drilling waste management apparatus for subterranean borehole operations|
    US20060100836A1|2004-11-09|2006-05-11|Amardeep Singh|Performance forecasting and bit selection tool for drill bits|
    US7487837B2|2004-11-23|2009-02-10|Weatherford/Lamb, Inc.|Riser rotating control device|
    CA2489968C|2004-12-10|2010-08-17|Precision Drilling Technology Services Group Inc.|Method for the circulation of gas when drilling or working a well|
    GB2464416B|2005-02-22|2010-06-30|Weatherford Lamb|Expandable tubulars for use in a wellbore|
    US7658228B2|2005-03-15|2010-02-09|Ocean Riser System|High pressure system|
    US7407019B2|2005-03-16|2008-08-05|Weatherford Canada Partnership|Method of dynamically controlling open hole pressure in a wellbore using wellhead pressure control|
    US20070235223A1|2005-04-29|2007-10-11|Tarr Brian A|Systems and methods for managing downhole pressure|
    US7913774B2|2005-06-15|2011-03-29|Schlumberger Technology Corporation|Modular connector and method|
    CA2612111A1|2005-06-17|2006-12-28|Baker Hughes Incorporated|Active controlled bottomhole pressure system and method with continuous circulation system|
    NO324167B1|2005-07-13|2007-09-03|Well Intervention Solutions As|System and method for dynamic sealing around a drill string.|
    NO326166B1|2005-07-18|2008-10-13|Siem Wis As|Pressure accumulator to establish the necessary power to operate and operate external equipment, as well as the application thereof|
    WO2007016000A1|2005-07-27|2007-02-08|Baker Hughes Incorporated|Active bottomhole pressure control with liner drilling and compeltion system|
    EP1969204A4|2006-01-05|2012-12-26|Prad Res & Dev Ltd|Method for determining formation fluid entry into or drilling fluid loss from a borehole using a dynamic annular pressure control system|
    US7610251B2|2006-01-17|2009-10-27|Halliburton Energy Services, Inc.|Well control systems and associated methods|
    US20070246263A1|2006-04-20|2007-10-25|Reitsma Donald G|Pressure Safety System for Use With a Dynamic Annular Pressure Control System|
    US8636060B2|2007-01-25|2014-01-28|Intelliserv, Llc|Monitoring downhole conditions with drill string distributed measurement system|
    NO325931B1|2006-07-14|2008-08-18|Agr Subsea As|Device and method of flow aid in a pipeline|
    CA2667199C|2006-10-23|2014-12-09|M-I L.L.C.|Method and apparatus for controlling bottom hole pressure in a subterranean formation during rig pump operation|
    US7699109B2|2006-11-06|2010-04-20|Smith International|Rotating control device apparatus and method|
    CA2867390C|2006-11-07|2015-12-29|Charles R. Orbell|Method of installing and retrieving multiple modules from a riser string|
    US7921919B2|2007-04-24|2011-04-12|Horton Technologies, Llc|Subsea well control system and method|
    NO326492B1|2007-04-27|2008-12-15|Siem Wis As|Sealing arrangement for dynamic sealing around a drill string|
    BRPI0812880A2|2007-06-01|2014-12-09|Agr Deepwater Dev Systems Inc|SYSTEM AND METHOD FOR LIFTING A WELL HOLE DRILLING FLUID IN A TRAINING, PITCHING LIFTING RETURN FLUID SYSTEM IN A TRAINING, METHOD FOR CONTROLING A WELL HOLE IN A FORMATION|
    NO327556B1|2007-06-21|2009-08-10|Siem Wis As|Apparatus and method for maintaining substantially constant pressure and flow of drilling fluid in a drill string|
    NO327281B1|2007-07-27|2009-06-02|Siem Wis As|Sealing arrangement, and associated method|
    CA2694482C|2007-07-27|2013-05-28|Weatherford/Lamb, Inc.|Continuous flow drilling systems and methods|
    US7913764B2|2007-08-02|2011-03-29|Agr Subsea, Inc.|Return line mounted pump for riserless mud return system|
    US7997345B2|2007-10-19|2011-08-16|Weatherford/Lamb, Inc.|Universal marine diverter converter|
    EP2053196A1|2007-10-24|2009-04-29|Shell Internationale Researchmaatschappij B.V.|System and method for controlling the pressure in a wellbore|
    US7938190B2|2007-11-02|2011-05-10|Agr Subsea, Inc.|Anchored riserless mud return systems|
    US20090159334A1|2007-12-19|2009-06-25|Bp Corporation North America, Inc.|Method for detecting formation pore pressure by detecting pumps-off gas downhole|
    US7708064B2|2007-12-27|2010-05-04|At Balance Americas, Llc|Wellbore pipe centralizer having increased restoring force and self-sealing capability|
    US8640778B2|2008-04-04|2014-02-04|Ocean Riser Systems As|Systems and methods for subsea drilling|
    CN201330573Y|2008-11-26|2009-10-21|西部钻探克拉玛依钻井工艺研究院|Bottom-hole pressure precision control system of under balance drilling|
    US7984770B2|2008-12-03|2011-07-26|At-Balance Americas, Llc|Method for determining formation integrity and optimum drilling parameters during drilling|
    US8281875B2|2008-12-19|2012-10-09|Halliburton Energy Services, Inc.|Pressure and flow control in drilling operations|
    GB2477880B|2008-12-19|2012-12-19|Halliburton Energy Serv Inc|Pressure and flow control in drilling operations|
    US8322432B2|2009-01-15|2012-12-04|Weatherford/Lamb, Inc.|Subsea internal riser rotating control device system and method|
    NO329687B1|2009-02-18|2010-11-29|Agr Subsea As|Method and apparatus for pressure regulating a well|
    GB0905633D0|2009-04-01|2009-05-13|Managed Pressure Operations Ll|Apparatus for and method of drilling a subterranean borehole|
    HUE049420T2|2009-07-09|2020-09-28|Tucc Tech Llc|Ultra high viscosity pill and methods for use with an oil-based drilling system|
    US9528334B2|2009-07-30|2016-12-27|Halliburton Energy Services, Inc.|Well drilling methods with automated response to event detection|
    US9567843B2|2009-07-30|2017-02-14|Halliburton Energy Services, Inc.|Well drilling methods with event detection|
    WO2011043764A1|2009-10-05|2011-04-14|Halliburton Energy Services, Inc.|Integrated geomechanics determinations and wellbore pressure control|
    US20120186873A1|2009-10-05|2012-07-26|Halliburton Energy Services, Inc.|Well drilling method utilizing real time response to ahead of bit measurements|
    US8899348B2|2009-10-16|2014-12-02|Weatherford/Lamb, Inc.|Surface gas evaluation during controlled pressure drilling|
    AU2010340366B2|2010-01-05|2014-10-23|Halliburton Energy Services, Inc.|Well control systems and methods|
    CN201593387U|2010-02-03|2010-09-29|中国石油天然气集团公司|Drilling annulus pressure precise control system|
    DK2542753T3|2010-03-05|2016-12-05|Safekick Americas Llc|System and method for safe well control operation|
    US8201628B2|2010-04-27|2012-06-19|Halliburton Energy Services, Inc.|Wellbore pressure control with segregated fluid columns|
    US8820405B2|2010-04-27|2014-09-02|Halliburton Energy Services, Inc.|Segregating flowable materials in a well|
    US9249638B2|2011-04-08|2016-02-02|Halliburton Energy Services, Inc.|Wellbore pressure control with optimized pressure drilling|
    US9080407B2|2011-05-09|2015-07-14|Halliburton Energy Services, Inc.|Pressure and flow control in drilling operations|CA2867390C|2006-11-07|2015-12-29|Charles R. Orbell|Method of installing and retrieving multiple modules from a riser string|
    US9567843B2|2009-07-30|2017-02-14|Halliburton Energy Services, Inc.|Well drilling methods with event detection|
    US9249638B2|2011-04-08|2016-02-02|Halliburton Energy Services, Inc.|Wellbore pressure control with optimized pressure drilling|
    CN102402184B|2011-10-28|2013-09-11|中国石油集团川庆钻探工程有限公司|Shaft pressure model prediction system controlling method|
    US9447647B2|2011-11-08|2016-09-20|Halliburton Energy Services, Inc.|Preemptive setpoint pressure offset for flow diversion in drilling operations|
    CN105143599B|2013-03-20|2018-05-01|普拉德研究及开发股份有限公司|Well system controls|
    WO2015065883A1|2013-10-28|2015-05-07|Schlumberger Canada Limited|Frequency analysis of drilling signals|
    EP3033481A4|2013-11-21|2017-04-05|Halliburton Energy Services, Inc.|Pressure and flow control in continuous flow drilling operations|
    GB2526255B|2014-04-15|2021-04-14|Managed Pressure Operations|Drilling system and method of operating a drilling system|
    CN104405362B|2014-10-28|2017-04-26|中国石油集团西部钻探工程有限公司|Automatic bottom hole pressure control device for under-balanced drilling and using method of device|
    US9988866B2|2014-12-12|2018-06-05|Halliburton Energy Services, Inc.|Automatic choke optimization and selection for managed pressure drilling|
    US10060208B2|2015-02-23|2018-08-28|Weatherford Technology Holdings, Llc|Automatic event detection and control while drilling in closed loop systems|
    US9909374B2|2015-03-03|2018-03-06|Halliburton Energy Services, Inc.|Managed pressure drilling with hydraulic modeling that incorporates an inverse model|
    US10544656B2|2015-04-01|2020-01-28|Schlumberger Technology Corporation|Active fluid containment for mud tanks|
    US10353358B2|2015-04-06|2019-07-16|Schlumberg Technology Corporation|Rig control system|
    US10323474B2|2015-07-07|2019-06-18|Halliburton Energy Services, Inc.|Heave compensated managed pressure drilling|
    US20170122092A1|2015-11-04|2017-05-04|Schlumberger Technology Corporation|Characterizing responses in a drilling system|
    CN105672997A|2016-03-18|2016-06-15|西南石油大学|Monitoring method for formation leakage of drilling fluid|
    WO2018165643A1|2017-03-10|2018-09-13|Schlumberger Technology Corporation|Automated choke control apparatus and methods|
    US10753169B2|2017-03-21|2020-08-25|Schlumberger Technology Corporation|Intelligent pressure control devices and methods of use thereof|
    US20180313187A1|2017-05-01|2018-11-01|Schlumberger Technology Corporation|Single body choke line and kill line valves|
    CN108952605B|2017-05-26|2021-01-29|中国石油化工股份有限公司|Underground runner type pressure control device, underground pressure control drilling system and drilling method thereof|
    CN107327298A|2017-07-05|2017-11-07|中国石油大学|A kind of gas cut degree evaluation method based on well head spillway discharge|
    RU2020112485A3|2017-09-05|2021-12-01|
    US10782197B2|2017-12-19|2020-09-22|Schlumberger Technology Corporation|Method for measuring surface torque oscillation performance index|
    NO344235B1|2018-01-05|2019-10-14|Roxar Software Solutions As|Well flow simulation system|
    US10760417B2|2018-01-30|2020-09-01|Schlumberger Technology Corporation|System and method for surface management of drill-string rotation for whirl reduction|
    CN108798638A|2018-08-15|2018-11-13|中国石油大学|A kind of experimental provision for simulating Shallow fluid intrusion pit shaft|
    US10822944B1|2019-04-12|2020-11-03|Schlumberger Technology Corporation|Active drilling mud pressure pulsation dampening|
    法律状态:
    2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2019-09-10| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2020-05-05| B06A| Patent application procedure suspended [chapter 6.1 patent gazette]|
    2020-08-25| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2020-10-27| B16A| Patent or certificate of addition of invention granted [chapter 16.1 patent gazette]|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 08/04/2011, OBSERVADAS AS CONDICOES LEGAIS. |
    2022-02-01| B21F| Lapse acc. art. 78, item iv - on non-payment of the annual fees in time|Free format text: REFERENTE A 11A ANUIDADE. |
    优先权:
    申请号 | 申请日 | 专利标题
    PCT/US2011/031767|WO2012138349A1|2011-04-08|2011-04-08|Automatic standpipe pressure control in drilling|
    [返回顶部]