PATENT ABSTRACT
A distributed drilling simulation system includes a choke manifold, a high pressure manifold, a blowout preventer console, a choke console, a remote console, a driller console, a teacher console and a graphic projecting unit, wherein the driller console, the remote console, the blowout preventer console, the choke console, the choke manifold, and the high pressure manifold are interconnected through a PPI (processor/peripheral interface) protocol. The teacher console is connected with the PPI protocol through a PPI interface. A communication program and a main control program run on a main control computer and a graphic processing program runs on a graphic computer. The invention has the advantages of realizing high-degree top driving drilling simulation, enhancing the field sense for teaching and training, shortening the training period and reducing the training cost.

PATENT DESCRIPTION
BACKGROUND OF THE PRESENT INVENTION 
     1. Field of Invention 
     The invention relates to a drilling simulation system, more particularly to a distributed drilling simulation system. 
     2. Description of Related Arts 
     At present, a centralized system structure with low reliability and robustness is employed for the current oversea and domestic drilling simulators typically. Moreover, the adoption of common animation technique could lead to fuzzy and non-smooth graphic display and lack of sense of reality. Besides, a screen with common size is used as the display screen for displaying the drilling process, and thus there is a shortage of indispensable impact and immersion in graphic display. In addition, the majority of oversea and domestic novel drilling machines are equipped with top drive drilling device. However, the majority of current drilling simulators implement simulation based upon rotary table drive. In this case, even if the top drive mode is utilized, the simulation is still relatively rough and the simulation for drilling accidents and complex underground situations is not complete and detailed enough. Therefore, practical significance is not accomplished. 
     SUMMARY OF THE PRESENT INVENTION 
     The objective of the invention is to overcome the defects in existing drilling simulators and provide a distributed drilling simulation system. The drilling simulator is based upon advanced computer network and distributed system structure. Embedded system design is used for front-end trainee console operating system, system design, manufacture and test are performed per industrial standards, and the system operates stably and reliably. Graphic animation is realized by full three-dimensional real-time animation technology. An operator can perform drilling operation in accordance with the position and state reflected by graphics, so that excellent sense of reality is brought to the operation. Large circular-screen graphic display technology is adopted in graphic display, and all the pictures in the process of drilling have larger display size, wider vision, more display contents, and the visual effect with better impact and immersion. Highly simulative top drive simulation is adopted as the drilling drive mode, which offers better suitability for technical change and meets the market demands. The event drive-based drilling accident and underground complex situation handling technology is capable of simulative training for training employees in advance so as to improve safety. 
     The objective of the invention is implemented through the technical proposal as follows. The distributed drilling simulation system comprises a choke manifold, a high pressure manifold, a blowout preventer console, a choke console, a remote console, a driller console, a teacher console, and a graphic projecting unit, wherein the driller console is used for controlling the lifting of winch, the rotating speed of rotary table and the speed regulation of mud pump in a simulative manner, acquiring winch clutch position, winch gear, rotary table clutch position, rotary table gear, pump regulator position, diesel engine power regulator position and the like, and monitoring parameters such as suspending weight, weight on bit, driller gas source pressure, mud density, mud viscosity and mud fluid loss. The blowout preventer controller has the basic functions including the on/off control of components in blowout preventer and monitoring vertical tube pressure, sleeve pressure, driller gas source and the like. The choke console has the basic functions including monitoring vertical tube pressure and sleeve pressure after shutting in and during killing, controlling vertical tube pressure and sleeve pressure during killing, and calculating discharge quantity (replacement quantity) during killing. The remote console drives handles by means of PLC control stepping motor to complete on/off control of the components in the blowout preventer. The high pressure manifold is used for simulatively controlling drilling fluid flow path. The choke manifold is used for simulatively controlling drilling fluid flow path and controlling vertical tube pressure and sleeve pressure at wellhead via hydraulic valve. The teacher console comprises two high-performance computers, which are the main control computer and the graphic processing computer respectively. The main control computer has the basic functions of storing and setting simulative parameters, running main control program, graphic control, calculating and drawing parameter curves, scoring and trainee management, acquiring parameters of front end equipment and controlling all controlled instruments, and executing mechanisms at the front end. The graphic processing computer is connected with the main control computer via an Ethernet, adopts TCP/IP communication protocol, and has the basic functions of displaying static background picture, controlled dynamic pictures, such as drill pipe motion and formation layering, automatic animation, and recording curves. The graphic projecting unit, which comprises a high-performance projector with higher resolution and brightness and a large-size screen, is connected with the graphic processing computer to project all the pictures onto a large screen curtain. The driller console, the remote console, the blowout preventer console and the choke console are interconnected via a PPI protocol. The teacher console is connected with the PPI protocol via a PPI interface. The choke manifold is connected with the choke console. The high pressure manifold is connected with the blowout preventer console. 
     A driller console comprises a chassis and an internal control plate. The front face of the chassis is provided with a driller console front face control panel. The side face of the chassis is provided with a driller console side face control panel, wherein the driller console front face control panel is provided with a pressure gauge set, a weight indicator, a rotary table torque indicator, a backup gauge, a switch set, a button set A, a display set, a winch speed adjusting handle, and a brake handle. The pressure gauge set comprises a gas source pressure gauge, a cooling water pressure gauge, a winch oil pressure gauge, a rotary table oil pressure gauge, a cathead pressure gauge, a pump pressure gauge, a tongs pressure gauge, a left tongs pressure gauge, a right tongs pressure gauge, and a safety tongs pressure gauge. The switch set comprises a left cathead switch, a right cathead switch, a hydraulic station unloading switch, a protective reset switch, an air horn switch, a rotary table inertial brake switch, a pneumatic inching switch, a backup switch, an emergency brake switch, and a parking brake switch. The button set A comprises a No. 1 button, a No. 2 button, a No. 3 button, a No. 4 button, a No. 5 button, a No. 6 button, a No. 7 button, a No. 8 button, a No. 9 button, a No. 10 button, a No. 11 button, a No. 12 button, a No. 13 button, and a No. 14 button. The display set comprises a parameter display, a mud density display, a mud viscosity display, and a mud fluid loss display. The internal control plate comprises a driller console programmable logic controller PLC 1  and a driller console programmable logic controller PLC 2 . A CPU module of the driller console programmable logic controller PLC 1  is connected with the winch speed adjusting handle and the brake handle respectively via an AD module. The CPU module of the driller console programmable logic controller PLC 1  is also connected with the gas source pressure gauge, the cooling water pressure gauge, the winch oil pressure gauge, the rotary table oil pressure gauge, the cathead pressure gauge, the rotary table torque indicator, the pump pressure gauge, the tongs pressure gauge, the backup gauge, the left tongs pressure gauge, the right tongs pressure gauge, and the safety tongs pressure gauge via a DA module The CPU module of the driller console programmable logic controller PLC 1  is also connected with the weight indicator, the emergency brake switch and the parking brake switch via a digital input/output (DIO) extension module The CPU module of the driller console programmable logic controller PLC 1  is also connected, via a switch quantity output port thereof, with the input end of a weight indicator controller the output end of which is connected with the weight indicator The CPU module of the driller console programmable logic controller PLC 1  is also connected with the left cathead switch, the right cathead switch, the hydraulic station unloading switch, the protective reset switch, the air horn switch, the rotary table inertial brake switch, the pneumatic inching switch, the backup switch, the No. 1 button, the No. 2 button, the No. 3 button, the No. 4 button, the No. 5 button, the No. 6 button, the No. 7 button, the No. 8 button, the No. 9 button, the No. 10 button, the No. 11 button, the No. 12 button, the No. 13 button, and the No. 14 button via a switch quantity input port thereof, and simultaneously connected with the No. 1 button, the No. 2 button, the No. 3 button, the No. 4 button, the No. 5 button, the No. 6 button, the No. 7 button, and the No. 8 button via the switch quantity output port. The CPU module of the driller console programmable logic controller PLC 1  is further connected with a driller console data transmitting/receiving plate via a serial port. The driller console data transmitting/receiving plate is connected with the mud density display, the mud viscosity display and the mud fluid loss display via parallel ports. The driller console side face control panel comprises an indicator set, a selector valve set, a button set B, a regulating valve set, a torque indicator, and a tachometer. The indicator set comprises a programmable logic controller PLC 1  indicator, a programmable logic controller PLC 2  indicator, a power generator  1  indicator, a power generator  2  indicator, a power generator  3  indicator, a power generator  4  indicator, a mud pump A indicator, a mud pump B indicator, a mud pump C indicator, a winch A indicator, a winch B indicator, a drill table indicator, a constant-speed drilling or constant-pressure drilling indicator, an internal blowout preventer indicator, a hydraulic pump operation indicator, a rotary head locking indicator, a brake indicator, a fault alarm indicator, and an in-position indicator. The selector valve set comprises a PLC working selector valve, a motor working selector valve, a winch working selector valve, a mud pump A working selector valve, a mud pump B working selector valve, a mud pump C working selector valve, a rotary table working selector valve, a winch constant-speed drilling or constant-pressure drilling working selector valve, an elevator link rotation selector valve, an internal blowout preventer working selector valve, a hydraulic pump selector valve, a rotary head locking selector valve, a backup tongs working selector valve, an elevator link inclination selector valve, a brake working mode selector valve, an auxiliary operation selector valve, a fan working selector valve, a motor selector valve, an operating mode selector valve, and a rotating direction selector valve. The button set B comprises a machine emergency stop button, a variable-frequency emergency stop button, a drill table torque adjusting knob, a mud pump A adjusting knob, a mud pump B regulating knob, a mud pump C regulating knob, a rotary table rotating speed adjusting knob, a constant-pressure drilling weight-on-bit adjusting knob, an elevator link middle position button, a mute button, and an emergency stop button. The regulating valve set comprises a makeup torque limiting regulating valve, a drilling well torque limiting regulating valve and a rotating speed setting regulating valve. A CPU module of the driller console programmable logic controller PLC 2  is connected with the drill table torque adjusting knob, the mud pump A adjusting knob, the mud pump B regulating knob, the mud pump C regulating knob, the rotary table rotating speed adjusting knob, the constant-pressure drilling weight-on-bit adjusting knob, the makeup torque limiting regulating valve, the drilling well torque limiting regulating valve, and the rotating speed setting regulating valve via the AD module respectively. The CPU module of the driller console programmable logic controller PLC 2  is also connected with the torque indicator and the tachometer via the DA module, connected with the brake indicator, the fault alarm indicator, the in-position indicator, the mute button, the emergency stop button, the brake working mode selector valve, the auxiliary operation selector valve, the fan working selector valve, the motor selector valve, the operating mode selector valve, and the rotating direction selector valve via the DIO extension module. The CPU module of the driller console programmable logic controller PLC 2  is also connected with the PLC 1  indicator, the PLC 2  indicator, the power generator  1  indicator, the power generator  2  indicator, the power generator  3  indicator, the power generator  4  indicator, the mud pump A indicator, the mud pump B indicator, the mud pump C indicator, the winch A indicator, the winch B indicator, the drill table indicator, the constant-speed drilling or constant-pressure drilling indicator, the internal blowout preventer indicator, the hydraulic pump operation indicator, and the rotary head locking indicator via the switch quantity output port thereof. The CPU module of the driller console programmable logic controller PLC 2  is further connected with the PLC working selector valve, the motor working selector valve, the winch working selector valve, the machine emergency stop button, the variable-frequency emergency stop button, the mud pump A working selector valve, the mud pump B working selector valve, the mud pump C working selector valve, the rotary table working selector valve, the winch constant-speed drilling or constant-pressure drilling working selector valve, the elevator link rotation selector valve, the elevator link middle position button, the internal blowout preventer working selector valve, the hydraulic pump selector valve, the rotary head locking selector valve, the backup tongs working selector valve, and the elevator link inclination selector valve via the switch input port thereof. 
     The objective of the invention is implemented through the technical proposal as follows. The distributed drilling simulation system comprises a choke manifold, a high pressure manifold, a blowout preventer console, a choke console, a remote console, a driller console, a teacher console, and a graphic projecting unit, wherein the driller console is used for controlling the lifting of winch, the rotating speed of rotary table and the speed regulation of mud pump in a simulative manner, acquiring winch clutch position, winch gear, rotary table clutch position, rotary table gear, pump regulator position, diesel engine power regulator position and the like, and monitoring parameters such as suspending weight, weight on bit, driller gas source pressure, mud density, mud viscosity and mud fluid loss. The blowout preventer controller has the basic functions including the on/off control of components in blowout preventer and monitoring vertical tube pressure, sleeve pressure, driller gas source and the like. The choke console has the basic functions including monitoring vertical tube pressure and sleeve pressure after shutting in and during killing, controlling vertical tube pressure and sleeve pressure during killing, and calculating discharge quantity (replacement quantity) during killing. The remote console drives handles by means of PLC control stepping motor to complete on/off control of the components in the blowout preventer. The high pressure manifold is used for simulatively controlling drilling fluid flow path. The choke manifold is used for simulatively controlling drilling fluid flow path and controlling vertical tube pressure and sleeve pressure at wellhead via hydraulic valve. The teacher console comprises two high-performance computers, which are the main control computer and the graphic processing computer respectively. The main control computer has the basic functions of storing and setting simulative parameters, running main control program, graphic control, calculating and drawing parameter curves, scoring and trainee management, acquiring parameters of front end equipment and controlling all controlled instruments, and executing mechanisms at the front end. The graphic processing computer is connected with the main control computer via an Ethernet, adopts TCP/IP communication protocol (Transmission Control Protocol/Internet Protocol), and has the basic functions of displaying static background picture, controlled dynamic pictures, such as drill pipe motion and formation layering, automatic animation, and recording curves. The graphic projecting unit, which comprises a high-performance projector with higher resolution and brightness and a large-size screen, is connected with the graphic processing computer to project all the pictures onto a large screen curtain. The driller console, the remote console, the blowout preventer console and the choke console are interconnected via a PPI protocol (point to point interface protocol). The teacher console is connected with the PPI protocol via a PPI interface (point to point interface). The choke manifold is connected with the choke console. The high pressure manifold is connected with the blowout preventer console. 
     A driller console comprises a chassis and an internal control plate. The front face of the chassis is provided with a driller console front face control panel. The side face of the chassis is provided with a driller console side face control panel, wherein the driller console front face control panel is provided with a pressure gauge set, a weight indicator, a rotary table torque indicator, a backup gauge, a switch set, a button set A, a display set, a winch speed adjusting handle, and a brake handle. The pressure gauge set comprises a gas source pressure gauge, a cooling water pressure gauge, a winch oil pressure gauge, a rotary table oil pressure gauge, a cathead pressure gauge, a pump pressure gauge, a tongs pressure gauge, a left tongs pressure gauge, a right tongs pressure gauge, and a safety tongs pressure gauge. The switch set comprises a left cathead switch, a right cathead switch, a hydraulic station unloading switch, a protective reset switch, an air horn switch, a rotary table inertial brake switch, a pneumatic inching switch, a backup switch, an emergency brake switch, and a parking brake switch. The button set A comprises a No. 1 button, a No. 2 button, a No. 3 button, a No. 4 button, a No. 5 button, a No. 6 button, a No. 7 button, a No. 8 button, a No. 9 button, a No. 10 button, a No. 11 button, a No. 12 button, a No. 13 button, and a No. 14 button. The display set comprises a parameter display, a mud density display, a mud viscosity display, and a mud fluid loss display. The internal control plate comprises a driller console programmable logic controller PLC 1  and a driller console programmable logic controller PLC 2 . A CPU (central processing unit) module of the driller console programmable logic controller PLC 1  is connected with the winch speed adjusting handle and the brake handle respectively via an AD module (analog to digital module). The CPU module of the driller console programmable logic controller PLC 1  is also connected with the gas source pressure gauge, the cooling water pressure gauge, the winch oil pressure gauge, the rotary table oil pressure gauge, the cathead pressure gauge, the rotary table torque indicator, the pump pressure gauge, the tongs pressure gauge, the backup gauge, the left tongs pressure gauge, the right tongs pressure gauge, and the safety tongs pressure gauge via a DA module (digital to analog module) The CPU module of the driller console programmable logic controller PLC 1  is also connected with the weight indicator, the emergency brake switch and the parking brake switch via a digital input/output (DIO) extension module The CPU module of the driller console programmable logic controller PLC 1  is also connected, via a switch quantity output port thereof, with the input end of a weight indicator controller the output end of which is connected with the weight indicator The CPU module of the driller console programmable logic controller PLC 1  is also connected with the left cathead switch, the right cathead switch, the hydraulic station unloading switch, the protective reset switch, the air horn switch, the rotary table inertial brake switch, the pneumatic inching switch, the backup switch, the No. 1 button, the No. 2 button, the No. 3 button, the No. 4 button, the No. 5 button, the No. 6 button, the No. 7 button, the No. 8 button, the No. 9 button, the No. 10 button, the No. 11 button, the No. 12 button, the No. 13 button, and the No. 14 button via a switch quantity input port thereof, and simultaneously connected with the No. 1 button, the No. 2 button, the No. 3 button, the No. 4 button, the No. 5 button, the No. 6 button, the No. 7 button, and the No. 8 button via the switch quantity output port. The CPU module of the driller console programmable logic controller PLC 1  is further connected with a driller console data transmitting/receiving plate via a serial port. The driller console data transmitting/receiving plate is connected with the mud density display, the mud viscosity display and the mud fluid loss display via parallel ports. The driller console side face control panel comprises an indicator set, a selector valve set, a button set B, a regulating valve set, a torque indicator, and a tachometer. The indicator set comprises a programmable logic controller PLC 1  indicator, a programmable logic controller PLC 2  indicator, a power generator  1  indicator, a power generator  2  indicator, a power generator  3  indicator, a power generator  4  indicator, a mud pump A indicator, a mud pump B indicator, a mud pump C indicator, a winch A indicator, a winch B indicator, a drill table indicator, a constant-speed drilling or constant-pressure drilling indicator, an internal blowout preventer indicator, a hydraulic pump operation indicator, a rotary head locking indicator, a brake indicator, a fault alarm indicator, and an in-position indicator. The selector valve set comprises a PLC working selector valve, a motor working selector valve, a winch working selector valve, a mud pump A working selector valve, a mud pump B working selector valve, a mud pump C working selector valve, a rotary table working selector valve, a winch constant-speed drilling or constant-pressure drilling working selector valve, an elevator link rotation selector valve, an internal blowout preventer working selector valve, a hydraulic pump selector valve, a rotary head locking selector valve, a backup tongs working selector valve, an elevator link inclination selector valve, a brake working mode selector valve, an auxiliary operation selector valve, a fan working selector valve, a motor selector valve, an operating mode selector valve, and a rotating direction selector valve. The button set B comprises a machine emergency stop button, a variable-frequency emergency stop button, a drill table torque adjusting knob, a mud pump A adjusting knob, a mud pump B regulating knob, a mud pump C regulating knob, a rotary table rotating speed adjusting knob, a constant-pressure drilling weight-on-bit adjusting knob, an elevator link middle position button, a mute button, and an emergency stop button. The regulating valve set comprises a makeup torque limiting regulating valve, a drilling well torque limiting regulating valve and a rotating speed setting regulating valve. A CPU module of the driller console programmable logic controller PLC 2  is connected with the drill table torque adjusting knob, the mud pump A adjusting knob, the mud pump B regulating knob, the mud pump C regulating knob, the rotary table rotating speed adjusting knob, the constant-pressure drilling weight-on-bit adjusting knob, the makeup torque limiting regulating valve, the drilling well torque limiting regulating valve, and the rotating speed setting regulating valve via the AD module respectively. The CPU module of the driller console programmable logic controller PLC 2  is also connected with the torque indicator and the tachometer via the DA module, connected with the brake indicator, the fault alarm indicator, the in-position indicator, the mute button, the emergency stop button, the brake working mode selector valve, the auxiliary operation selector valve, the fan working selector valve, the motor selector valve, the operating mode selector valve, and the rotating direction selector valve via the DIO extension module. The CPU module of the driller console programmable logic controller PLC 2  is also connected with the PLC 1  indicator, the PLC 2  indicator, the power generator  1  indicator, the power generator  2  indicator, the power generator  3  indicator, the power generator  4  indicator, the mud pump A indicator, the mud, pump B indicator, the mud pump C indicator, the winch A indicator, the winch B indicator, the drill table indicator, the constant-speed drilling or constant-pressure drilling indicator, the internal blowout preventer indicator, the hydraulic pump operation indicator, and the rotary head locking indicator via the switch quantity output port thereof. The CPU module of the driller console programmable logic controller PLC 2  is further connected with the PLC working selector valve, the motor working selector valve, the winch working selector valve, the machine emergency stop button, the variable-frequency emergency stop button, the mud pump A working selector valve, the mud pump B working selector valve, the mud pump C working selector valve, the rotary table working selector valve, the winch constant-speed drilling or constant-pressure drilling working selector valve, the elevator link rotation selector valve, the elevator link middle position button, the internal blowout preventer working selector valve, the hydraulic pump selector valve, the rotary head locking selector valve, the backup tongs working selector valve, and the elevator link inclination selector valve via the switch input port thereof. 
     The working flow of the driller console mud density regulation subprogram is approximately as follows. The subprogram begins running to read switch quantity in. Density value is increased by 0.01 if an increase button is pressed. Otherwise, whether a decrease button is pressed is judged. If so, the density value is decreased by 0.01 and then the beginning state of the subprogram is returned. If not, the beginning state of the subprogram is returned as well, and the above steps are cycled. 
     The driller console weight indicator control subprogram outputs the stepping pulse according to the weight value of the weight indicator to control the rotation of the stepping motor, so that the suspending weight pointer points at the corresponding value. Its working flow is approximately as follows. The subprogram begins running to read the suspending weight value of the weight indicator from a reception buffer zone. If the suspending weight value is 0 and the suspending weight pointer is located at the zero point, return is directly performed. If the suspending weight value is 0 and the suspending weight pointer is not located at the zero point, the stepping motor is controlled to rotate anticlockwise until the suspending weight pointer points at the zero point. When the suspending weight value is not 0, whether a change occurs is judged at first. If not, return is directly performed. If so, whether the suspending weight value becomes larger or smaller is judged. If the suspending weight value becomes larger, the direction control symbol of the stepping motor is set as 1 (clockwise rotation). If the suspending weight value becomes smaller, the direction control symbol of the stepping motor is set as 0 (anticlockwise rotation). Afterwards, the suspending weight variation difference is calculated, wherein 1 stepping pulse suspending weight difference is output, followed by subtracting 1 until 0 is obtained, and finally, return is performed. 
     The working flow of the driller consoler side face panel main control program is approximately as follows. The program begins, the in-position indicator is initialized. Switch quantity is read and stored in the transmission buffer zone. The A/D result is read and stored in the transmission buffer zone. Whether the internal blowout preventer is closed is judged. If so, the internal blowout preventer indicator is on. Then, whether the hydraulic pump operates is judged. If so, the hydraulic pump operation indicator is on. If not, the hydraulic pump operation indicator is off. Then, whether the rotary head is locked is judged. If so, the rotary head locking indicator is on. If not, the rotary head locking indicator is off. Then, a rotating speed setting subprogram and a torque setting subprogram are called. If the rotating speed setting symbol is 0 (this symbol value is set in the rotating speed setting subprogram), rotating speed data is read from the reception buffer zone and output to D/A. If not, the tachometer displays a rotating speed value transmitted from a host PC. Then, whether a torque setting symbol is 0 is judged. If so, torque data is read from the reception buffer zone and output to D/A. Then, return is performed, and otherwise, return is performed directly. 
     The working flow of the driller console drilling torque setting program is approximately as follows. The subprogram is initiated. The A/D result is read. Whether the setting knob is regulated is judged. If so, it means that an operator is setting a drilling torque upper limit. At this moment, a current regulation value is displayed in real-time by the instrument. In the case that no change occurs within 3 seconds, it is considered as being set. Afterwards, the instrument displays a drilling torque value transmitted from the host PC. Finally, the subprogram is returned. 
     The remote console comprises a chassis and an internal control plate. The front face of the chassis is provided with a remote console control panel. The remote console control panel is provided with a ring oil pressure regulating valve, a manifold pressure regulating valve, a manifold pressure gauge, an accumulator pressure gauge, a ring oil pressure gauge, a bypass valve, a blowout preventer valve, a pipe ram control valve, a blind ram control valve, a shear ram control valve, a ring ram control valve, an accumulator main switch, a left-path accumulator switch, and a right-path accumulator switch. The internal control plate comprises a remote console programmable logic controller PLC and a valve controller. A CPU module of the remote console programmable logic controller PLC is connected with the manifold pressure regulating valve and the ring oil pressure regulating valve via the AD module respectively. The CPU module of the remote console programmable logic controller PLC is also connected with the manifold pressure gauge and the accumulator pressure gauge via the DA module  1 , connected with the ring oil pressure gauge via the DA module  2 , and connected with the accumulator main switch, the left-path accumulator switch, and the right-path accumulator switch via the switch quantity input port thereof. The CPU module of the remote console programmable logic controller PLC is further connected with a control input end of the valve controller via twelve switch quantity outputs (the twelve switch quantity outputs are respectively used as a bypass valve startup control signal, a bypass on or off control signal, a blowout preventer valve startup control signal, a blowout preventer valve on or off control signal, a pipe ram control valve startup control signal, a pipe ram control valve on or off control signal, a blind ram control valve startup control signal, a blind ram control valve on or off control signal, a shear ram control valve startup control signal, a shear ram control valve on or off control signal, a ring ram control valve startup control signal, and a ring ram control valve on or off control signal). The output of the valve controller is connected with the bypass valve, the blowout preventer valve, the pipe ram control valve, the blind ram control valve, the shear ram control valve, and the ring ram control valve respectively. The bypass valve, the blowout preventer valve, the pipe ram control valve, the blind ram control valve, the shear ram control valve and the ring ram control valve are accessed to twelve switch quantity input ports (the twelve switch quantity inputs are respectively used as a bypass valve on/off feedback signal, a blowout preventer valve on/off feedback signal, a pipe ram control valve on/off feedback signal, a blind ram control valve on/off feedback signal, a shear valve control valve on/off feedback signal, and a ring ram control valve on/off feedback signal) of the remote console programmable logic controller PLC respectively via feedback signal wires. 
     In which, the manifold pressure regulating valve is used for regulating manifold pressure. The ring oil pressure regulating valve is used for regulating ring oil pressure. The manifold pressure gauge is used for displaying manifold pressure value, the accumulator pressure gauge is used for displaying accumulator pressure value. The ring oil pressure gauge is used for displaying ring oil pressure value. The bypass valve is used for opening or closing a bypass pipeline and feeding back the on/off state of a bypass ram. The blowout preventer valve is used for opening or closing blowout preventer pipelines and feeding back the on/off state of the blowout preventer valve. The accumulator main switch is used for opening or closing an accumulator main pipeline. 
     The working flow of the remote console control program is approximately as follows. When the control program is initiated, Port  1  of the PLC is initialized by the initialization port to realize point-to-point communication with the blowout preventer, and simultaneously, instrument initialization is displayed. Switch quantity is read and stored in an internal buffer zone for subsequent processing. The A/D result is then read and stored in the transmission buffer zone. NET_RW and the blowout preventer console are called for data transmission and reception. Ring, pipe ram, blowout prevention and shear control subprograms are called. The rotation of the stepping motor is controlled according to the operation of a blowout preventer handle in order to switch on the control oil path of the blowout preventer, so that the blowout preventer is controlled to be on or off. If the left and right oil path switches and the oil path main switch are switched on, a ring pressure regulating value is transmitted to a ring instrument display buffer zone. If a bypass is selected to be on, a manifold pressure regulating value is transmitted to a manifold pressure instrument display buffer zone. Otherwise, a 21 MPa display value is transmitted to the instrument display buffer zone. If the left and right oil path switches and the oil path main switch are not switched on, 0 value is transmitted to the instrument display buffer zone. Then, data are read from the instrument display buffer zone to the D/A. Finally, return is performed to read and store the switch quantity in the internal buffer zone, and the above steps are cycled. 
     The working flow of the remote console subprogram is approximately as follows. The subprogram begins running to read the state of the blowout preventer operation handle from the reception buffer zone in order to judge whether the blowout preventer operation handle operates. The stepping motor rotates only if the blowout preventer operation handle operates. If the stepping motor does not rotate, the beginning state is returned. Otherwise, the stepping motor rotation symbol is controlled to be set, the rotation direction of the stepping motor is selected based upon ON or OFF. In the case of ON, the direction control symbol is set as 0 (indicating left rotation). In the case of complete OFF, the stepping motor rotation symbol is controlled to be zeroed. Then, the beginning state is returned. In the case of incomplete OFF, return is also performed. In the case of OFF, the direction control symbol is set as 1 (indicating right rotation). In the case of complete ON, the stepping motor rotation symbol is controlled to be zeroed. Then, the beginning state is returned, and in the case of incomplete ON, return is also performed, and the above steps are cycled. 
     The choke manifold comprises a choke tube and a valve installed on the choke tube. The choke tube is installed on a choke manifold frame and is featured by vertical and crossed distribution of transverse tubes and vertical tubes. A plurality of flat valves is arranged on the transverse tubes and the vertical tubes. The transverse tubes comprise a choke manifold upper transverse tube and a choke manifold lower transverse tube. The two ends of the choke manifold upper transverse tube are fixedly connected to the choke manifold frame. One end of the choke manifold upper transverse tube is provided with a separator outlet while the other end thereof is provided with a backup outlet. The vertical tubs comprise an overflow inlet tube, a hydraulic choke tube and a manual choke tube. The lower ends of the overflow inlet tube, the hydraulic choke tube and the manual choke tube are provided with an overflow inlet, a hydraulic choke valve and a manual choke valve respectively. The upper end of the overflow inlet tube is fixedly connected to the choke manifold frame. 
     The overflow inlet tube is connected with the choke manifold upper transverse tube and with the choke manifold lower transverse tube respectively in a crosswise manner to form a crossing point a and a crossing point b. The flat valve A is installed on the overflow inlet tube at the upper part of the crossing point a. The flat valve b and the flat valve c are sequentially installed on the overflow inlet tube between the crossing point a and the crossing point b. The pressure gauge is arranged at the crossing point b. A blowout preventer valve ON/OFF indicator is installed on the overflow inlet tube at the lower part of the crossing point b. The two ends of the choke manifold lower transverse tube are fixedly connected to the hydraulic choke tube and the manual choke tube respectively to form a nodal point c and a nodal point d. The flat valve D and the flat valve E are installed on the choke manifold lower transverse tube between the crossing point b and the crossing point c. The flat valve F and the flat valve G are installed on the choke manifold lower transverse tube between the crossing point b and the crossing point d. The upper ends of the hydraulic choke tube and the manual choke tube are connected with the choke manifold upper transverse tube respectively to form a nodal point e and a nodal point f. The flat valve H is installed on the hydraulic choke tube between the nodal point c and the nodal point e. A hydraulic indicator is installed on the manual choke tube at the lower part of the nodal point c. The end part of the manual choke tube is provided with the hydraulic choke valve. The flat valve I is installed on the manual choke tube between the nodal point d and the nodal point f. The manual choke valve is arranged at the end part of the manual choke tube at the lower part of the nodal point d. The flat valve J is arranged on the choke manifold upper transverse tube between the nodal point e and the backup outlet. The flat valve K is arranged on the choke manifold upper transverse tube between the nodal point f and the separator outlet. 
     The high pressure manifold comprises a high pressure tube and a valve installed on the high pressure valve. The high pressure tube is installed on a high pressure manifold frame and is featured by vertical connection and distribution of transverse tubes and vertical tubes. A high pressure manifold upper transverse tube, a high pressure manifold lower transverse tube, a left vertical tube and a right vertical tube are jointed at the middle of the high pressure tube to form a rectangle. A plurality of flat valves is arranged on the transverse tubes and the vertical tubes. The transverse tubes further comprise a left mud inlet tube, a right mud inlet tube and a grouting outlet tube. The left end of the left mud inlet tube is fixedly connected to the high pressure manifold frame. The left end part of the left mud inlet tube is provided with a mud inlet I. The right end of the right mud inlet tube is fixedly connected to the high pressure manifold frame. The right end part of the right mud inlet tube is provided with a mud inlet II. The left end of the grouting outlet tube is fixedly connected to the high pressure manifold frame. The left end part of the grouting outlet tube is provided with a grouting outlet. The vertical tubes further comprise an upper vertical tube and a lower vertical tube. The upper end of the upper vertical tube is fixedly connected to the high pressure manifold frame. The upper end part of the upper vertical tube is provided with a backup inlet. The lower end of the lower vertical tube is fixedly connected to the high pressure manifold frame. The lower end part of the lower vertical tube is provided with a vertical tube outlet. 
     The left mud inlet tube and the right mud inlet tube are in T-shaped connection with the rectangular left vertical tube and the rectangular right vertical tube respectively to form a nodal point h and a nodal point i. The flat valve L is installed on the left vertical tube at the upper part of the nodal point h. The flat valve M is installed on the left vertical tube at the lower part of the nodal point h. The flat valve N is installed on the right vertical tube at the upper part of the nodal point i. The flat valve O is installed on the right vertical tube at the lower part of the nodal point i. The upper vertical tube and the lower vertical tube are in T-shaped connection with the rectangular high pressure manifold upper transverse tube and the rectangular high pressure manifold lower transverse tube respectively to form a nodal point g and a nodal point j. The grouting outlet tube is in T-shaped connection with the lower vertical tube to form a nodal point k. The flat valve P is installed on the grouting outlet tube. The flat valve Q is installed on the lower vertical tube at the lower part of the nodal point k. 
     The blowout preventer console comprises a chassis and an internal control plate. The front face of the chassis is provided with a blowout preventer control panel. The blowout preventer control panel is provided with an accumulator pressure gauge, a ring blowout preventer oil pressure gauge, a gas source pressure gauge, a manifold pressure gauge, a ring ram switch, a ring ram on indicator, a ring ram off indicator, a gas source switch, a bypass ram switch, an upper pipe ram switch, an upper pipe ram on indicator, an upper pipe ram off indicator, a blind ram switch, a blind ram on indicator, a blind ram off indicator, a kill manifold ram switch, a kill manifold on indicator, a kill manifold off indicator, a blowout preventer valve switch, a blowout preventer valve off indicator, a blowout preventer valve on indicator, a lower pipe ram switch, a lower pipe ram on indicator, and a lower pipe ram off indicator. The internal control plate comprises a blowout preventer programmable logic controller PLC. A CPU module of the blowout preventer programmable logic controller PLC is connected with the accumulator pressure gauge and the ring blowout preventer oil pressure gauge via the DA module  1  respectively. The CPU module of the blowout preventer programmable logic controller PLC is also connected with the gas source pressure gauge and the manifold pressure gauge via the DA module  2  respectively. The CPU module of the blowout preventer programmable logic controller PLC is further connected with the ring ram switch, the gas source switch, the bypass ram switch, the upper pipe ram switch, the blind ram switch, the kill manifold ram switch, the blowout preventer valve switch, and the lower pipe ram switch respectively via the switch quantity input port thereof. The CPU module of the blowout preventer programmable logic controller PLC is further connected with the ring ram on indicator, the ring ram off indicator, the upper pipe ram on indicator, the upper pipe ram off indicator, the blind ram on indicator, the blind ram off indicator, the kill manifold on indicator, the kill manifold off indicator, the blowout preventer valve off indicator, the blowout preventer valve on indicator, the lower pipe ram on indicator, and the lower pipe ram off indicator respectively via the switch quantity output port thereof. The CPU module of the blowout preventer programmable logic controller PLC is further connected, via the switch quantity input port thereof, with the flat valves L, M, N, O, P and Q installed on the high pressure tube in the high pressure manifold respectively. In which, the accumulator pressure gauge is used for displaying accumulator pressure value. The ring blowout preventer oil pressure gauge is used for displaying ring blowout preventer oil pressure value. The gas source pressure gauge is used for displaying gas source pressure value. The manifold pressure gauge is used for displaying manifold pressure value. The ring ram switch is used for opening or closing ring ram. The ring ram ON/OFF indicator is used for indicating the ON/OFF of ring ram. 
     The working flow of the blowout preventer control program is approximately as follows. When the control program is initiated. The Port  1  of the PLC is initialized by the initialization port to realize point-to-point communication with the remote console, and simultaneously, initialization is displayed by both indicators and the display instruments. Switch quantity is read and stored in the internal buffer zone for being directly read by PC. The NET_RW and the remote console are called for data transmission and reception. Ring, pipe ram, blowout prevention and shear control subprograms are called to control the indicators according to the blowout preventer operation handle and the on/off time in order to display whether the blowout preventers are completely opened/closed. Afterwards, the state of the indicator (for indicating on/off state of the blowout preventer) is stored in the transmission buffer zone. Then, an alarm control standard is read from the reception buffer zone. Alarm is switched on in the case of choosing to alarm and alarm is switched off in the case of choosing to not alarm. Finally, the step of reading and storing the switch quantity in the transmission buffer zone is returned, and the above steps are cycled. 
     The working flow of the ring blowout preventer control sub-program is approximately as follows. The subprogram begins running the ON/OFF states including the operation handle state of the blowout preventer and the operation handle state of the remote console are read. In the case that the remote console is connected, if the gas source on the blowout preventer is chosen to be on and the ring is on or the ring on the remote console is on, the time is set to be 8 seconds. The indicator is ON if the ring blowout preventer is on. The indicator is OFF if the ring blowout preventer is OFF. Then, the subprogram is returned. Otherwise, the subprogram is returned. If the gas source on the blowout preventer is chosen to be ON and the ring is OFF or the ring on the remote console is OFF, the time is set to be 8 seconds. The indicator is ON if the ring blowout preventer is OFF. The indicator is OFF if the ring blowout preventer is ON. Then, the subprogram is returned. Otherwise, the subprogram is returned. In the case that no remote console is connected, if the gas source on the blowout preventer is ON and the ring is ON, the time is set to be 8 seconds. The indicator is ON if the ring blowout preventer is ON. The indicator is OFF if the ring blowout preventer is OFF. Then, the subprogram is returned. If the time is not set to be 8 seconds, the subprogram is still returned. If the gas source on the blowout preventer is ON and the ring is OFF, the time is set to be 8 seconds. The indicator is ON if the ring blowout preventer is OFF. The indicator is OFF if the ring blowout preventer is ON. Then, subprogram is returned, and otherwise, the subprogram is returned. 
     The choke console comprises a chassis and an internal control plate. The front face of the chassis is provided with a choke control panel. The choke control panel is provided with a vertical tube pressure gauge, a pump speed gauge, a sleeve pressure gauge, a hydraulic choke valve selection indicator, a dual-pump selection switch, a choke valve selection switch, a pump stroke display, a choke valve opening gauge, a manual choke valve selection indicator, a reset button, a driller gas source switch, a choke control valve switch, and a choke valve speed adjusting knob. The internal control plate comprises a choke programmable logic controller PLC. A CPU module of the choke programmable logic controller PLC is connected with the choke valve speed adjusting knob ( 190 ) via the AD module. The CPU module of the choke programmable logic controller PLC is also connected with the vertical tube pressure gauge and the sleeve pressure gauge via the DA module  1 . The CPU module of the choke programmable logic controller PLC is also connected with the pump speed gauge and the choke valve opening gauge via the DA module  2 . The CPU module of the choke programmable logic controller PLC is further connected with a choke data transmitting/receiving plate via a serial port. The choke data transmitting/receiving plate is connected with a pump stroke display via a parallel port. The CPU module of the choke programmable logic controller PLC is further connected with the hydraulic choke valve selection indicator and the manual choke valve selection indicator via the switch quantity output port thereof respectively. The CPU module of the choke programmable logic controller PLC is further connected with the dual-pump selection switch, the choke valve selection switch, the reset button, the driller gas source switch and the choke control valve switch via the switch quantity input port thereof respectively. The CPU module of the choke programmable logic controller PLC is further connected, via the switch quantity input port thereof, with the flat valves A, B, C, D, E, F, G, H, I, J and K installed on the choke tube in the choke manifold respectively. The CPU module of the choke programmable logic controller PLC is connected with the manual choke valve in the choke manifold via the AD module and with a pressure gauge via the DA module  1 . In which, the vertical tube pressure gauge is used for indicating vertical tube pressure. The sleeve pressure gauge is used for indicating sleeve pressure, the pump speed gauge is used for indicating pump speed. The choke valve opening gauge is used for indicating choke valve opening. The dual-pump selection switch is used for selecting No. 1 pump, No. 2 pump or the dual pumps. The pump stroke display is used for displaying accumulated pump strokes. The choke valve selection switch is used for selecting the manual choke valve or the hydraulic choke valve. The manual choke valve selection indicator is used for indicating the selection of the manual choke valve. The hydraulic choke valve selection indicator is used for indicating the selection of the hydraulic choke valve. The reset button is used for resetting pump stroke, the driller gas source switch is used for opening or closing driller gas source. The choke control valve switch is used for increasing or decreasing the opening of the choke regulating valve. The choke valve speed adjusting knob is used for increasing or decreasing the speed of the choke regulating valve. 
     The choke data transmitting/receiving plate comprises a serial port chip, a single chip microcomputer, a latch, and a bus buffer. The input end of the serial port chip is connected with the serial port of the choke programmable logic controller PLC via the serial port. The output end of the serial port chip is connected with the transmitting data line and the receiving data line of the single chip microcomputer respectively. The single chip microcomputer is further connected with the latch and the bus buffer via buses respectively. The output ports of the latch and the bus buffer are connected with the pump stroke display via the parallel ports. 
     The pump stroke display comprises an address buffer, a data buffer, a comparator, a decoder, a dip switch, a nixie tube drive chip, and a nixie tube. The input ports of the address buffer and the data buffer are both connected with the parallel port. The output port of the data buffer is connected with the nixie tube drive chip. The output port of the address buffer is connected with one input end of the comparator and the decoder respectively. The other input end of the comparator is connected with the dip switch. The output port is connected with the enabling end of the decoder. The output end of the decoder is connected with the nixie tube drive chip. The output end of the nixie tube drive chip is connected with the nixie tube. 
     The working flow of the choke control program is approximately as follows. When the control program is initiated, the port Port 1  of the PLC is initialized by the initialization port to realize data communication with the LED display control plate. Then, switch quantities (including switch quantity inputs of the dual-pump selection switch, the choke valve selection switch, the reset switch, the driller gas source switch and the choke valve control switch) are read and stored in the transmission buffer zone for being directly read by PC communication. The A/D result I then read and stored in the transmission buffer zone for being directly read by PC communication. Whether a hydraulic mode or a manual mode is selected is judged. If the hydraulic mode is selected, the hydraulic indicator is turned ON. If the manual mode is selected, the manual indicator is turned ON. Afterwards, data is read from the reception buffer zone and output to the D/A in order to control the display of instruments for displaying vertical tube pressure, sleeve pressure, pumps speed and chokes speed. The data is then transmitted to the LED display control plate via the serial port. The switch quantities are read again and stored in the transmission buffer zone, and the above steps are cycled. In addition, the entire system is a bus-type network including one PC serving as a master station and a plurality of PLCs serving as a slave station. Every communication is initiated by the master station. The slave station monitors and judges whether transmission and reception requests about the slave station is present. Its working flow is approximately as follows: The master station transmits a signal. If the slave station monitors the transmission and reception requests about the slave station, the slave station agrees with the reception of the requests so that the data is received and stored in the reception buffer zone. Afterwards, the slave station returns to continue monitoring. If the slave station does not monitor the transmission and reception requests about the slave station and does not receive and transmit the requests, the slave station returns to monitor. If the slave station does not receive the request, but agrees with the reception of the requests, in this case, the data are read from the transmission buffer zone and transmitted. Then, the slave station returns to monitor, and the above steps are cycled. 
     The main control computer comprises one or more than one general computers as well as a communication program and a main control program running thereon. The graphic computer comprises one or more than one general computers as well as a graphic processing program running thereon. The communication program is connected with front end hardware via the PPI protocol. The main control program is connected with the communication program and the graphic processing program via the TCP/IP protocol respectively, wherein the front end hardware comprises the blowout preventer console, the choke console, the remote console, and the driller console. 
     The main control program comprises an operation training module, a system management module and a scoring module. The main control program is connected with front end hardware equipment via the communication program to obtain the state of the hardware equipment in real-time, for example parameters such as rotation number of drill table, brake state, mud discharging quantity and mud density, needed to be obtained in the simulation for drilling process. Then, a typical drilling process is simulated by means of relevant mathematical models to finish the following tasks. 1. A control command is sent to the graphic processing program via TCP/IP protocol, and thus the graphic processing program can be driven to generate an animation process that is synchronous with the operation of the hardware equipment. 2. An intelligent scoring system is realized. 3. A signal is fed back to the front end hardware, enabling the parameter display of front end instruments to accord with onsite situation. 
     System management module, which comprises hardware self-inspection, user management and killing scheme management, is mainly used for completing management and configuration for the distributed drilling simulation system. The functions like system self-inspection and user management can be completed using this module. Meanwhile, some parameters in the system are changed so as to change the operation mode of the main control program. In this way, different demands are met. 
     The scoring module is mainly used for automatically scoring the training process. Scoring is related mainly to two factors. (1) Operating Flow: all the operating flows of trainees are recorded in the system, wherein the operating flow of trainee is compared with a preset operating flow in the system upon the completion of trainee examination to evaluate the accordance of the two flows and score the operating flow of trainees on this basis. (2) Operating Level: In addition to the grasp of corrective operating flow by trainees, their operating flow shall be taken into consideration in comprehensively evaluating the technical level of trainees, e.g. whether the selection for weight on bit during drilling in is appropriate and whether drilling is even, wherein for the problem whether the control for pressure during killing meets the demand of killing constructor, the system determines the operating level score by adopting a method for recording relevant data curves in the operating flow and comparing the data curves with standard curves afterwards. The scoring process is as follows: a trainee logs in the system, begins examination and completes corresponding operations, wherein the system scores automatically based upon relevant standards to obtain a final score. 
     The graphic processing program comprises a scene initialization module, a process animation control module, a collision processing module and a render effect module. A vivid, virtual drilling environment is created by means of full three-dimensional animation so that trainees feel as if they were in a real drilling environment, and thus the mental resilience of trainees in accident handling is improved and better training effect is obtained. The four modules have the following functions: 
     Scene initialization: The current scene of every operation differs owing to the complexity of drilling process and the operability of virtual training. Before a new operation begins, the graphic program initializes the current scene after receiving an operation command sent from the control computer, for example the current number, state and position of operating components on a drilling platform. 
     Process animation control: In the process of completing the specified process operation, every action from drilling console is converted into a digital signal. The digital signal is transmitted to the main control computer. Protocol data are then sent to the graphic program by the main control computer and the graphic program gives a specific response after the acquisition of parameters. Motion parameters, specific motions and view selection (including aboveground visual angle, underground visual angle, blowout preventer visual angle, multi-view display, and etc.) of various control systems on drilling platform are reflected on a graphic machine. 
     Collision processing: The situation of ‘wall through’ is not allowed in the motion simulation process of three-dimensional graphics. Therefore, collision detection shall be performed on motion objects. To cause model motion to be realistic, a drilling simulator visual simulating system certainly includes collision detecting and processing parts. 
     Render effect: Simulation for flame, bubble, liquid jetting effects is realized. Movie-level illumination effect is accomplished using GLSL, and illumination modes like daylight, night and searchlight can be simulated respectively, thus greatly improving graphic effect and sense of reality. 
     The operation training module comprises an RIH sub-module, a POOH sub-module, a drill-in sub-module, an accident and complex situation handling sub-module, a shut in sub-module, and a killing sub-module. The operation training module provides the training about 23 common technological processes and event drive processes in the drilling process, and accordingly, is the most important module in the main control program. Event drive training has no limitation to trainees, who therefore can operate the simulator randomly, and the graphic system will reflect reasonable mechanical motions and simultaneously give a voice prompt with regard to erroneous operations. The module is mainly used for cognitive training of new trainees about drilling site and drilling machinery. In technical process training, trainees are required to operate the simulator per its technical process, in order to intensify the comprehension of trainees on the technical process and make trainees master the operation process of the simulator. 
     Among all the sub-modules, the top driving event drive sub-module is used for operation simulation based on real top driver, and the simulation includes control logic contents like internal blowout preventer, locking of rotary head, rotation of elevator links, inclination of elevator links, backup tongs, drilling well or rotary makeup or torque, reversal rotation or stoppage or positive rotation, and etc. 
     The RIH sub-module is used for simulating the RIH process and trainees are required to master the RIH process correctively to reach the purpose of steady RIH. Its actual flow is as follows: 
     (a) Normal RIH flow: Begin this operation, start up an elevator, then place and make up a stand, move the elevator away, drop a drill bit, take off elevator links, judge whether RIH is performed, wherein if so, return to start up the elevator, or otherwise, end this operation. 
     (b) Set weight flow: Begin this operation, perform RIH normally, perform punching and reaming in the event of set weight, end this operation, and return if set weight does not occur. 
     (c) Fluctuation pressure controlling RIH flow: Begin this operation, start up an elevator, then place and make up a stand, move the elevator away, drop a drill bit at low speed, press corresponding button to take off elevator links, judge whether RIH is continued, wherein if so, return to begin this operation, or otherwise, end this operation. 
     The POOH sub-module is used for simulating the POOH process and trainees are required to master the POOH process correctively to reach the purpose of steady POOH. Its actual operating flow is as follows: 
     (a) Normal POOH flow: Begin this operation, lift up a drill bit, unload a stand, pour mud, judge whether POOH is performed, wherein if so, return to begin this operation, or otherwise, end this operation. 
     (b) Getting overpull flow: Begin this operation, perform POOH normally, perform circulative freeing in the event of getting overpull, perform back reaming, end this operation, and return to normal POOH in the case of being unstuck. 
     (c) Suction pressure controlling POOH flow: Begin this operation, lift the drill bit at low speed, unload the stand, pour the mud, judge whether POOH is continued, wherein if so, return to lift the drill bit at low speed, or otherwise, end this operation. 
     The drill sub-module is used for simulating typical drilling well condition and trainees are required to master the drilling process correctively to reach the purpose of even drilling and simultaneously to master the drilling technology for complicated formation. Its actual operating flow is as follows: 
     (a) Normal drilling and stand makeup flow: Begin this operation, circulate mud, perform light press and running in, perform drilling normally, make up the stand, and drop by a certain depth to end this operation. 
     (b) Drilling flow under different formation drillabilities: Begin this operation, circulate mud, perform light press and running in, drill by 1 meter at a first formation, drill by 1 meter at a second formation, drill by 1 meter at a third formation, take out drilling pipe, and end this operation. 
     (c) Drilling flow under bouncing: Begin this operation, perform drilling normally if not bouncing occurs, lift up drilling pipe if bouncing occurs, change rotating speed and weight on bit, drop drilling pipe, judge whether bouncing is reduced, wherein return to lift up drilling pipe if bouncing is not reduced and circulate the operation until bouncing is reduced, then ream bouncing sections, and end this operation. 
     (d) High-pressure formation drilling flow: Begin this operation, circulate mud, perform drilling normally, judge whether overflowing occurs, perform drilling normally if not overflowing occurs, otherwise, increase mud density, continue drilling, make up the stand, and finally, end this operation. 
     (e) Low-pressure formation drilling flow: Begin this operation, circulate mud, perform drilling normally, judge whether leakage occurs, perform drilling normally if not leakage occurs, otherwise, increase mud density, continue drilling, make up the stand, and finally, end this operation. 
     The accident and complex situation handling sub-module is used for simulating common failures and complex situations in the drilling process. The simulating system creates an accident randomly and requires trainee to judge the type of this accident by means of the phenomenon (mainly changes of a variety of instruments) reflected by simulator and handle the accident properly. Its actual operating flow is as follows: 
     (a) Adhesion sticking judging and handling flow: Begin this operation, lift up the drilling pipe, judge whether there is a ground failure, continue lifting up the drilling pipe if there is no failure, drop the drill bit interruptedly if there is a failure, move the drill bit, circulate mud, free the moved drill bit, then judge whether the moved drill bit has been freed, wherein if not, return to continue freeing until freeing is completed, and end this operation. 
     (b) Solids settling sticking judging and handling flow: Begin this operation, perform POOH normally, judge whether there is solids settling sticking, if not, return to normal POOH, move the drill bit if there is solids settling sticking, circulate mud in small quantity, judge whether pump pressure is normal, wherein if not, return to circulate mud, and if so, circulate mud in large quantity, and finally, end this operation. 
     (c) Balling-up sticking judging and handling flow: Begin this operation, perform light press and running in, perform drilling, judge whether there is balling-up sticking, wherein if not, return to normal POOH, and if so, circulate mud in larger quantity, perform reaming at high speed, regulate mud performances, continue drilling, and finally, end this operation. 
     (d) Taper tap fishing flow: Begin this operation, wash top of fish, detect fallen fish downwards, judge whether the fallen fish is detected, wherein if not, return to continue downward detection, and if so, release thread, make thread, try to lift up the drill pipe, lift up the fallen fish, and finally, end this operation. 
     (e) Junk milling flow: Begin this operation, wash well bottom, mill twice, continue milling until the mill is broken, and end this operation. 
     The shut in sub-module is used for simulating four shut in conditions. Trainees are required to locate overflowing timely and to be able to shut in well safely and rapidly as required by the ‘four, seven’ motions. 
     (a) Operating flow of normal drilling and shutting in: Begin this operation, perform drilling normally, judge whether overflowing occurs, wherein if not, perform drilling normally, and if so, open the choke manifold and close ring blowout preventer, upper pipe ram blowout preventer, throttle valve and J2A flat valves, then log well and end this operation. 
     (b) Operating flow of POOH and shutting in: Begin this operation, unload a square drilling pipe, lift up a vertical pipe, judge whether overflowing occurs, wherein if not, return to lift up the vertical pipe, and if so, make up a drill bit blowout preventer in advance, shut in well, log well, and end this operation. 
     (c) Operating flow of drill collar lifting and shutting in: Begin this operation, lift up a drill collar, judge whether overflowing occurs, wherein if not, return to lift up the drill collar, and if so, make up a blowout preventing single pipe in advance, shut in well, log well, and end this operation. 
     (d) Operating flow of emptying and shutting in: Begin this operation, judge whether the overflowing quantity is large after the drill collar is lifted up, wherein if so, shut in well, log well and finally end this operation, and if not, make up the blowout preventing single pipe in advance, shut in well, log well, and finally end this operation. 
     The killing sub-module is used for simulating three conventional killing operations. Trainees are required to control wellhead pressure correctively to reach the purpose of succeeding in killing at a time. Its actual operating flow is as follows: 
     (a) Operating flow of killing by driller&#39;s method: Begin this operation, set mud pump stroke, discharge contaminated mud, judge whether the contaminated mud is completely discharged, wherein if not, return to discharge the contaminated mud completely, and if so, increase mud density, perform killing by weighted mud, judge whether killing is finished, wherein if not, return to continue killing, and if so, end this operation. 
     (b) Operating flow of killing by engineer&#39;s method: Begin this operation, set mud pump stroke, increase mud density, then perform killing by weighted mud, judge whether killing is finished, wherein if not, return to continue killing, and if so, end this operation. 
     (c) Operating flow of killing by overweight mud driller&#39;s method: Begin this operation, prepare overweight mud, pump the overweight mud in, judge whether circulation is finished, wherein if so, regulate mud density, perform killing by killing mud, and judge whether killing is finished, wherein if not, return to continue killing, and if so, end this operation. 
     The invention has the advantages of realizing high-degree top driving drilling simulation, enhancing the field sense for teaching and training, shortening the training period and reducing the training cost. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         FIG. 1  is a structural schematic diagram of the distributed drilling simulator. 
         FIG. 2  is a structural schematic diagram of the front face of the driller console. 
         FIG. 3  is a structural schematic diagram of the side face of the driller console. 
         FIG. 4  is a diagram of the connection relationship between the internal control plate of the driller console and major components on the front face of the control panel. 
         FIG. 5  is a diagram of the connection relationship between the internal control plate of the driller console and major components on the side face of the control panel. 
         FIG. 6  is a structural schematic diagram of the control panel of the remote console. 
         FIG. 7  is a diagram of the connection relationship between the internal control plate of the remote console and major components on the control panel. 
         FIG. 8  is a structural schematic diagram of the choke manifold. 
         FIG. 9  is a structural schematic diagram of the high pressure manifold. 
         FIG. 10  is a structural schematic diagram of the blowout preventer control panel. 
         FIG. 11  is a diagram of the connection relationship between the internal control plate of the blowout preventer console and major components on the control panel. 
         FIG. 12  is a structural schematic diagram of the choke control panel. 
         FIG. 13  is a diagram of the connection relationship between the internal control plate of the choke and major components on the control panel. 
         FIG. 14  is a schematic constitution diagram of the driller console data transmitting/receiving plate. 
         FIG. 15  is a schematic constitution diagram of the mud density display, the mud viscosity display and the mud fluid loss display in the driller console. 
         FIG. 16  is a working flow chart of the driller console control program. 
         FIG. 17  is a working flow chart of the mud density regulating subprogram of the driller console. 
         FIG. 18  is a working flow chart of the weight indicator control subprogram of the driller console. 
         FIG. 19  is a working flow chart of the driller console side face control panel main control program. 
         FIG. 20  is a working flow chart of the drilling torque setting program of the driller console. 
         FIG. 21  is a control flow chart of the remote console. 
         FIG. 22  is a flow chart of the remote console control subprogram. 
         FIG. 23  is a schematic diagram of on/off state of the flat valves under the hydraulic mode of the choke manifold. 
         FIG. 24  is a schematic diagram of on/off state of the flat valves under the manual mode of the choke manifold. 
         FIG. 25  is a schematic diagram of on/off state of the flat valves under the grouting mode in the case that No. 1 pump is selected by the high pressure manifold. 
         FIG. 26  is a schematic diagram of on/off state of the flat valves under the circulating mode in the case that No. 1 pump is selected by the high pressure manifold. 
         FIG. 27  is a schematic diagram of on/off state of the flat valves under the grouting mode in the case that No. 2 pump is selected by the high pressure manifold. 
         FIG. 28  is a schematic diagram of on/off state of the flat valves under the circulating mode in the case that No. 2 pump is selected by the high pressure manifold. 
         FIG. 29  is a schematic diagram of on/off state of the flat valves under the grouting mode in the case that dual pumps are selected by the high pressure manifold. 
         FIG. 30  is a schematic diagram of on/off state of the flat valves under the circulating mode in the case that dual pumps are selected by the high pressure manifold. 
         FIG. 31  is a control flow chart of the blowout preventer. 
         FIG. 32  is a flow chart of the blowout preventer control subprogram. 
         FIG. 33  is a schematic constitution diagram of the pump stroke display in the choke. 
         FIG. 34  is a flow chart of the choke control program. 
         FIG. 35  is a flow chart of the communication between the choke and the PC. 
         FIG. 36  is a schematic constitution diagram of the choke data transmitting/receiving plate. 
         FIG. 37  is a flow chart of normal RIH. 
         FIG. 38  is a flow chart of set weight. 
         FIG. 39  is a flow chart of fluctuation pressure controlling RIH. 
         FIG. 40  is a flow chart of normal POOH. 
         FIG. 41  is a flow chart of getting overpull. 
         FIG. 42  is a flow chart of suction pressure controlling POOH. 
         FIG. 43  is a flow chart of normal drilling and stand makeup. 
         FIG. 44  is a flow chart of drilling under different formation drillabilities. 
         FIG. 45  is a flow chart of drilling under bouncing. 
         FIG. 46  is a flow chart of high-pressure formation drilling. 
         FIG. 47  is a flow chart of low-pressure formation drilling. 
         FIG. 48  is a flow chart of adhesion sticking judging and handling. 
         FIG. 49  is a flow chart of solids settling sticking judging and handling. 
         FIG. 50  is a flow chart of balling-up sticking judging and handling. 
         FIG. 51  is a flow chart of taper tap fishing. 
         FIG. 52  is a flow chart of junk milling. 
         FIG. 53  is a flow chart of normal drilling and shutting in. 
         FIG. 54  is a flow chart of POOH and shutting in. 
         FIG. 55  is a flow chart of drill collar lifting and shutting in. 
         FIG. 56  is a flow chart of emptying and shutting in. 
         FIG. 57  is a flow chart of killing by driller&#39;s method. 
         FIG. 58  is a flow chart of killing by engineer&#39;s method. 
         FIG. 59  is a flow chart of killing by overweight mud driller&#39;s method. 
         FIG. 60  is a constitution diagram of the applications of the distributed drilling simulator. 
         FIG. 61  is a flow chart of scoring. 
     
    
    
     Wherein,  1 —driller console front face control panel,  2 —gas source pressure gauge,  3 —cooling water pressure gauge,  4 —winch oil pressure gauge,  5 —rotary table oil pressure gauge,  6 —weight indicator,  7 —cathead pressure gauge,  8 —parameter display,  9 —rotary table torque indicator,  10 —pump pressure gauge,  11 —tongs pressure gauge,  12 —backup gauge,  13 —left tongs pressure gauge,  14 —right tongs pressure gauge,  15 —safety tongs pressure gauge,  16 —left cathead switch,  17 —right cathead switch,  18 —hydraulic station unloading switch,  19 —protective reset switch,  10 —air horn switch,  21 —rotary table inertial brake switch,  22 —pneumatic inching switch,  23 —backup switch,  24 —winch speed regulating handle,  25 —No. 1 button,  26 —No. 2 button,  27 —No. 3 button,  28 —No. 4 button,  29 —No. 5 button,  30 —No. 6 button,  31 —No. 7 button,  32 —No. 8 button,  33 —No. 9 button,  34 —No. 10 button,  35 —No. 11 button,  36 —No. 12 button,  37 —No. 13 button,  38 —No. 14 button,  39 —mud density display,  40 —mud viscosity display,  41 —mud fluid loss display,  42 —brake handle,  43 —emergency brake switch,  44 —parking brake switch,  45 —driller console side face control panel,  46 —programmable controller PLC 1  indicator,  47 —programmable controller PLC 2  indicator,  48 —engine  1  indicator,  49 —engine  2  indicator,  50 —engine  3  indicator,  51 —engine  4  indicator,  52 —mud pump A indicator,  53 —mud pump B indicator,  54 —mud pump C indicator,  55 —winch A indicator,  56 —winch B indicator,  57 —drill table indicator,  58 —constant—speed drilling or constant—pressure drilling indicator,  59 —PLC working selector valve,  60 —motor working selector valve,  61 —winch working selector valve,  62 —machine emergency stop button,  63 —variable—frequency emergency stop button,  64 —drill table torque adjusting knob,  65 —mud pump A working selector valve,  66 —mud pump B working selector valve,  67 —mud pump C working selector valve,  68 —rotary table working selector valve,  69 —winch constant—speed drilling or constant—pressure drilling working selector valve,  70 —mud pump A adjusting knob,  71 —mud pump B regulating knob,  72 —mud pump C regulating knob,  73 —rotary table rotating speed adjusting knob,  74 —constant—pressure drilling weight—on—bit adjusting knob,  75 —internal blowout preventer indicator,  76 —hydraulic pump operation indicator,  77 —rotary head locking indicator,  78 —elevator link rotation selector valve,  79 —elevator link middle position button,  80 —brake indicator,  81 —in—position indicator,  82 —internal blowout preventer working selector valve,  83 —hydraulic pump selector valve,  84 —rotary head locking selector valve,  85 —backup tongs working selector valve,  86 —elevator link inclination selector valve,  87 —brake working mode selector valve,  88 —mute button,  89 —emergency stop button,  90 —auxiliary operation selector valve,  91 —fan working selector valve,  92 —motor selector valve,  93 —operating mode selector valve,  94 —rotating direction selector valve,  95 —makeup torque limiting regulating valve,  96 —torque indicator,  97 —tachometer,  98 —falut alarm indicator,  99 —drilling well torque limiting regulating valve,  100 —rotating speed setting regulating valve,  101 —choke manifold,  102 —high pressure manifold,  103 —blowout preventer console,  104 —choke console,  105 —remote console,  106 —driller console,  107 —teacher console,  108 —graphic projecting unit,  109 —remote console control panel,  110 —ring oil pressure regulating valve,  111 —manifold pressure regulating valve,  112 —manifold pressure gauge,  113 —accumulator pressure gauge,  114 —ring oil pressure gauge,  115 —bypass valve,  116 —blowout preventer valve,  117 —pipe ram control valve,  118 —blind ram control valve,  119 —shear ram control valve,  120 —ring ram control valve,  121 —accumulator main switch,  122 —left—path accumulator switch,  123 —right—path accumulator switch,  124 —choke manifold frame,  125 —choke manifold upper transverse tube,  126 —choke manifold lower transverse tube,  127 —separator outlet,  128 —backup outlet,  129 —overflow inlet tube,  130 —hydraulic choke tube,  131 —manual choke tube,  132 —overflow inlet,  133 —blowout preventer valve on/off indicator,  134 —hydraulic choke valve,  135 —manual choke valve,  136 —hydraulic indicator, A, B, C, D, E, F, G, H, I, J, K—flat valve, a, b—crossing point, c, d, e, f—nodal points,  137 —high pressure manifold frame,  138 —high pressure manifold upper transverse tube,  139 —high pressure manifold lower transverse tube,  140 —left vertical tube,  141 —right vertical tube,  142 —left mud inlet tube,  143 —grouting outlet tube,  144 —mud inlet I,  145 —mud inlet H,  146 —grouting outlet,  147 —upper vertical tube,  148 —lower vertical tube,  149 —backup inlet,  150 —vertical tube outlet,  151 —right mud inlet tube, L, M, N,  0 , P, Q—flat valves, g, h, i, j, k—nodal points,  152 —blowout preventer control panel,  153 —accumulator pressure gauge,  154 —ring blowout preventer oil pressure gauge,  155 —gas source pressure gauge  156 —manifold pressure gauge  157 —ring ram switch,  158 —ring ram on indicator,  159 —a ring ram off indicator,  160 —gas source switch,  161 —upper pipe ram switch,  162 —upper pipe ram on indicator,  163 —upper pipe ram off indicator,  164 —bypass ram switch,  165 —blind ram switch,  166 —blind ram on indicator,  167 —blind ram off indicator,  168 —kill manifold ram switch,  169 —kill manifold on indicator,  170 —kill manifold off indicator,  171 —blowout preventer valve switch,  172 —blowout preventer valve off indicator,  173 —blowout preventer valve on indicator,  174 —lower pipe ram switch,  175 —lower pipe ram on indicator,  176 —lower pipe ram off indicator,  177 —choke control panel,  178 —vertical tube pressure gauge,  179 —pump speed gauge,  180 —sleeve pressure gauge,  181 —hydraulic choke valve selection indicator,  182 —dual—pump selection switch,  183 —choke valve selection switch,  184 —pump stroke display,  185 —choke valve opening gauge,  186 —manual choke valve selection indicator,  187 —reset button,  188 —driller gas source switch,  189 —choke control valve switch, and  190 —choke valve speed adjusting knob. 
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT 
     Further description is made below to the technical disclosure of the invention with reference to the drawings. As shown in  FIG. 1 , the distributed drilling simulator comprises a choke manifold  101 , a high pressure manifold  102 , a blowout preventer console  103 , a choke console  104 , a remote console  105 , a driller console  106 , a teacher console  107 , and a graphic projecting unit  108 . The graphic projecting unit  108  comprises two projectors and one large-size screen. The teacher console  107  is composed of a main control computer and a graphic computer. The driller console  106 , the main control computer and the graphic processing computer are interconnected via a TCP/IP protocol. The driller console  106 , the remote console  105 , the blowout preventer console  103 , and the choke console  104  are interconnected with a SIEMENS PPI protocol. The teacher console  107  is interconnected with the PPI protocol via a PPI interface. The PPI interface is a SIEMENS CP5611 card. The choke manifold  101  is connected with the choke console  104  and the high pressure manifold  102  is connected with the blowout preventer console  103 . 
     As shown in  FIG. 2 , the driller console comprises a chassis and an internal control plate. The front face of the chassis is provided with a driller console front face control panel  1 . The side face of the chassis is provided with a driller console side face control panel  45 , wherein the driller console front face control panel  1  is provided with a pressure gauge set, a weight indicator  6 , a rotary table torque indicator  9 , a backup gauge  12 , a switch set, a button set A, a display set, a winch speed adjusting handle  24 , and a brake handle  42 . The pressure gauge set comprises a gas source pressure gauge  2 , a cooling water pressure gauge  3 , a winch oil pressure gauge  4 , a rotary table oil pressure gauge  5 , a cathead pressure gauge  7 , a pump pressure gauge  10 , a tongs pressure gauge  11 , a left tongs pressure gauge  13 , a right tongs pressure gauge  14 , and a safety tongs pressure gauge  15 . The switch set comprises a left cathead switch  16 , a right cathead switch  17 , a hydraulic station unloading switch  18 , a protective reset switch  19 , an air horn switch  20 , a rotary table inertial brake switch  21 , a pneumatic inching switch  22 , a backup switch  23 , an emergency brake switch  43 , and a parking brake switch  44 . The button set A comprises a No. 1 button  25 , a No. 2 button  26 , a No. 3 button  27 , a No. 4 button  28 , a No. 5 button  29 , a No. 6 button  30 , a No. 7 button  31 , a No. 8 button  32 , a No. 9 button  33 , a No. 10 button  34 , a No. 11 button  35 , a No. 12 button  36 , a No. 13 button  37 , and a No. 14 button  38 . The display set comprises a parameter display  8 , a mud density display  39 , a mud viscosity display  40 , and a mud fluid loss display  41 . The internal control plate comprises a driller console programmable logic controller PLC 1  and a driller console programmable logic controller PLC 2 . The driller console programmable logic controller PLC 1  and the driller console programmable logic controller PLC 2  are both SIEMENS S7-200. As shown in  FIG. 4 , a CPU module of the driller console programmable logic controller PLC 1  is connected with the winch speed adjusting handle  24  and the brake handle  42  via an AD module respectively. The CPU module of the driller console programmable logic controller PLC 1  is also connected with the gas source pressure gauge  2 , the cooling water pressure gauge  3 , the winch oil pressure gauge  4 , the rotary table oil pressure gauge  5 , the cathead pressure gauge  7 , the rotary table torque indicator  9 , the pump pressure gauge  10 , the tongs pressure gauge  11 , the backup gauge  12 , the left tongs pressure gauge  13 , the right tongs pressure gauge  14 , and the safety tongs pressure gauge  15  via a DA module. The CPU module of the driller console programmable logic controller PLC 1  is also connected with the weight indicator  6 , the emergency brake switch  43  and the parking brake switch  44  via a digital input/output DIO extension module. The CPU module of the driller console programmable logic controller PLC 1  is also connected, via a switch quantity output port thereof, with the input end of a weight indicator controller the output end of which is connected with the weight indicator. The CPU module of the driller console programmable logic controller PLC 1  is further connected with the left cathead switch  16 , the right cathead switch  17 , the hydraulic station unloading switch  18 , the protective reset switch  19 , the air horn switch  20 , the rotary table inertial brake switch  21 , the pneumatic inching switch  22 , the backup switch  23 , the No. 1 button  25 , the No. 2 button  26 , the No. 3 button  27 , the No. 4 button  28 , the No. 5 button  29 , the No. 6 button  30 , the No. 7 button  31 , the No. 8 button  32 , the No. 9 button  33 , the No. 10 button  34 , the No. 11 button  35 , the No. 12 button  36 , the No. 13 button  37 , and the No. 14 button  38  via a switch quantity input port thereof, and simultaneously connected with the No. 1 button  25 , the No. 2 button  26 , the No. 3 button  27 , the No. 4 button  28 , the No. 5 button  29 , the No. 6 button  30 , the No. 7 button  31  and the No. 8 button  32  via the switch quantity output port. The CPU module of the driller console programmable logic controller PLC 1  is further connected with a driller console data transmitting/receiving plate via a serial port. The driller console data transmitting/receiving plate is connected with the mud density display  39 , the mud viscosity display  40  and the mud fluid loss display  41  via parallel ports. As shown in  FIG. 3 , the driller console side face control panel  45  comprises an indicator set, a selector valve set, a button set B, a regulating valve set, a torque indicator  96  and a tachometer  97 . The indicator set comprises a programmable logic controller PLC 1  indicator  46 , a programmable logic controller PLC 2  indicator  47 , a power generator  1  indicator  48 , a power generator  2  indicator  49 , a power generator  3  indicator  50 , a power generator  4  indicator  51 , a mud pump A indicator  52 , a mud pump B indicator  53 , a mud pump C indicator  54 , a winch A indicator  55 , a winch B indicator  56 , a drill table indicator  57 , a constant-speed drilling or constant-pressure drilling indicator  58 , an internal blowout preventer indicator  75 , a hydraulic pump operation indicator  76 , a rotary head locking indicator  77 , a brake indicator  80 , a fault alarm indicator  98  and an in-position indicator  81 . The selector valve set comprises a PLC working selector valve  59 , a motor working selector valve  60 , a winch working selector valve  61 , a mud pump A working selector valve  65 , a mud pump B working selector valve  66 , a mud pump C working selector valve  67 , a rotary table working selector valve  68 , a winch constant-speed drilling or constant-pressure drilling working selector valve  69 , an elevator link rotation selector valve  78 , an internal blowout preventer working selector valve  82 , a hydraulic pump selector valve  83 , a rotary head locking selector valve  84 , a backup tongs working selector valve  85 , an elevator link inclination selector valve  86 , a brake working mode selector valve  87 , an auxiliary operation selector valve  90 , a fan working selector valve  91 , a motor selector valve  92 , an operating mode selector valve  93 , and a rotating direction selector valve  94 . The button set B comprises a machine emergency stop button  62 , a variable-frequency emergency stop button  63 , a drill table torque adjusting knob  64 , a mud pump A adjusting knob  70 , a mud pump B regulating knob  71 , a mud pump C regulating knob  72 , a rotary table rotating speed adjusting knob  73 , a constant-pressure drilling weight-on-bit adjusting knob  74 , an elevator link middle position button  79 , a mute button  88 , and an emergency stop button  89 . The regulating valve set comprises a makeup torque limiting regulating valve  95 , a drilling well torque limiting regulating valve  99 , and a rotating speed setting regulating valve  100 . As shown in  FIG. 5 , a CPU module of the driller console programmable logic controller PLC 2  is connected with the drill table torque adjusting knob  64 , the mud pump A adjusting knob  70 , the mud pump B regulating knob  71 , the mud pump C regulating knob  72 , the rotary table rotating speed adjusting knob  73 , the constant-pressure drilling weight-on-bit adjusting knob  74 , the makeup torque limiting regulating valve  95 , the drilling well torque limiting regulating valve  99 , and the rotating speed setting regulating valve  100  via the AD module respectively. The CPU module of the driller console programmable logic controller PLC 2  is also connected with the torque indicator  96  and the tachometer  97  via the DA module. The CPU module of the driller console programmable logic controller PLC 2  is also connected with the brake indicator  80 , the fault alarm indicator  98 , the in-position indicator  81 , the mute button  88 , the emergency stop button  89 , the brake working mode selector valve  87 , the auxiliary operation selector valve  90 , the fan working selector valve  91 , the motor selector valve  92 , the operating mode selector valve  93 , and the rotating direction selector valve  94  via the digital input/output extension module The CPU module of the driller console programmable logic controller PLC 2  is further connected with the PLC 1  indicator  46 , the PLC 2  indicator  47 , the power generator  1  indicator  48 , the power generator  2  indicator  49 , the power generator  3  indicator  50 , the power generator  4  indicator  51 , the mud pump A indicator  52 , the mud pump B indicator  53 , the mud pump C indicator  54 , the winch A indicator  55 , the winch B indicator  56 , the drill table indicator  57 , the constant-speed drilling or constant-pressure drilling indicator  58 , the internal blowout preventer indicator  75 , the hydraulic pump operation indicator  76 , and the rotary head locking indicator  77  via the switch quantity output port thereof. The CPU module of the driller console programmable logic controller PLC 2  is further connected with the PLC working selector valve  59 , the motor working selector valve  60 , the winch working selector valve  61 , the machine emergency stop button  62 , the variable-frequency emergency stop button  63 , the mud pump A working selector valve  65 , the mud pump B working selector valve  66 , the mud pump C working selector valve  67 , the rotary table working selector valve  68 , the winch constant-speed drilling or constant-pressure drilling working selector valve  69 , the elevator link rotation selector valve  78 , the elevator link middle position button  79 , the internal blowout preventer working selector valve  82 , the hydraulic pump selector valve  83 , the rotary head locking selector valve  84 , the backup tongs working selector valve  85 , and the elevator link inclination selector valve  86  via the switch input port thereof. 
     As shown in  FIG. 14 , the driller console data transmitting/receiving plate comprises a serial port chip, a single chip microcomputer, a latch and a bus buffer. The input end of the serial port chip is connected with the serial port of the driller console programmable logic controller PLC 1  via the serial port. The output end of the serial port chip is connected with the transmitting data line and the receiving data line of the single chip microcomputer respectively. The single chip microcomputer is further connected with the latch and the bus buffer via buses respectively. The output ports of the latch and the bus buffer are connected with the mud density display  39 , the mud viscosity display  40  and the mud fluid loss display  41  via the parallel ports. 
     As shown in  FIG. 15 , each of the mud density display  39 , the mud viscosity display  40  and the mud fluid loss display  41  comprises an address buffer, a data buffer, a comparator, a decoder, a dip switch, a nixie tube drive chip, and a nixie tube. The input ports of the address buffer and the data buffer are both connected with the parallel port. The output port of the data buffer is connected with the nixie tube drive chip. The output port of the address buffer is connected with one input end of the comparator and the decoder respectively. The other input end of the comparator is connected with the dip switch. The output port is connected with the enabling end of the decoder. The output end of the decoder is connected with the nixie tube drive chip. The output end of the nixie tube drive chip is connected with the nixie tube. 
       FIG. 16  is a flow chart of the driller console control program. Its working flow is approximately as follows. When a control program is initiated, a port Port 1  of the PLC is initialized by an initialization port to realize data communication with an LED display control plate. Then, switch quantity is read and stored in a transmission buffer zone. An A/D result is read and stored in the transmission buffer zone. Mud density, mud viscosity and mud fluid loss regulating subprograms are called and an XMT subprogram is then called. Data are transmitted to the LED display control plate. If a left cathead is switched on, 800 is output to D/A to make the left cathead display normal working pressure value. Otherwise, 0 is output to D/A. Then, whether a right cathead is switched on is judged, wherein if so, 800 is output to D/A to make the right cathead display normal working pressure value, or otherwise, 0 is output to D/A. A button indicator control subprogram is then called and a weight indicator control subprogram is called. Stepping pulse is output according to a suspending weight value of the weight indicator to control the rotation of the stepping motor, so that a suspending weight pointer points at a corresponding value. Finally, initialization is performed by returning to port, and the above steps are cycled. 
       FIG. 17  is a working flow chart of the mud density regulating subprogram of the driller console. Its working flow is approximately as follows. The sub-program begins running to read switch quantity in. Density value is increased by 0.01 if an increase button is pressed. Otherwise, whether a decrease button is pressed is judged, wherein if so, the density value is decreased by 0.01 and then the beginning state of the subprogram is returned, and if not, the beginning state of the subprogram is returned as well, and the above steps are cycled. 
       FIG. 18  is a flow chart of the weight indicator control subprogram. The driller console weight indicator control subprogram outputs the stepping pulse according to the weight value of the weight indicator to control the rotation of the stepping motor, so that the suspending weight pointer points at the corresponding value. Its working flow is approximately as follows. The subprogram begins running to read the suspending weight value of the weight indicator from a reception buffer zone. If the suspending weight value is 0 and the suspending weight pointer is located at the zero point, return is directly performed. If the suspending weight value is 0 and the suspending weight pointer is not located at the zero point, the stepping motor is controlled to rotate anticlockwise until the suspending weight pointer points at the zero point. When the suspending weight value is not 0, whether a change occurs is judged at first, wherein if not, return is directly performed, and if so, whether the suspending weight value becomes larger or smaller is judged. If the suspending weight value becomes larger, the direction control symbol of the stepping motor is set as 1 (clockwise rotation). If the suspending weight value becomes smaller, the direction control symbol of the stepping motor is set as 0 (anticlockwise rotation). Afterwards, the suspending weight variation difference is calculated, wherein 1 stepping pulse suspending weight difference is output, and followed by subtracting 1 until 0 is obtained, and finally, return is performed. 
       FIG. 19  is a flow chart of the driller console side face control panel main control program. Its working flow is approximately as follows. The program begins, the in-position indicator is initialized. Switch quantity is read and stored in the transmission buffer zone. The A/D result is read and stored in the transmission buffer zone. Whether the internal blowout preventer is closed is judged, wherein if so, the internal blowout preventer indicator is on, and then whether the hydraulic pump operates is judged, wherein if so, the hydraulic pump operation indicator is on, and if not, the hydraulic pump operation indicator is off. Then, whether the rotary head is locked is judged, wherein if so, the rotary head locking indicator is on, and if not, the rotary head locking indicator is off. Then, a rotating speed setting subprogram and a torque setting subprogram are called, wherein if the rotating speed setting symbol is 0 (this symbol value is set in the rotating speed setting subprogram), rotating speed data is read from the reception buffer zone and output to D/A, and if not, the tachometer displays a rotating speed value transmitted from a host PC. Then, whether a torque setting symbol is 0 is judged, wherein if so, torque data is read from the reception buffer zone and output to D/A, and then return is performed. Otherwise, return is performed directly. 
       FIG. 20  is a flow chart of the drilling torque setting program. Its working flow is approximately as follows. The sub-program is initiated, the A/D result is read. Whether the setting knob is regulated is judged, wherein if so, it means that an operator is setting a drilling torque upper limit. At this moment, a current regulation value is displayed in real-time by the instrument, and in the case that no change occurs within 3 seconds, it is considered as being set. Afterwards, the instrument displays a drilling torque value transmitted from the host PC, and finally, the subprogram is returned. 
     As shown in  FIG. 6 , the remote console  105  comprises a chassis and an internal control plate. The front face of the chassis is provided with a remote console control panel  109 . The remote console control panel  109  is provided with a ring oil pressure regulating valve  110 , a manifold pressure regulating valve  111 , a manifold pressure gauge  112 , an accumulator pressure gauge  113 , a ring oil pressure gauge  114 , a bypass valve  115 , a blowout preventer valve  116 , a pipe ram control valve  117 , a blind ram control valve  118 , a shear ram control valve  119 , a ring ram control valve  120 , an accumulator main switch  121 , a left-path accumulator switch  122 , and a right-path accumulator switch  123 . The internal control plate comprises a remote console programmable logic controller PLC and a valve controller. The remote console programmable logic controller PLC 2  is SIEMENS S7-200. As shown in  FIG. 7 , a CPU module of the remote console programmable logic controller PLC is connected with the manifold pressure regulating valve  111  and the ring oil pressure regulating valve  110  via the AD module respectively. The CPU module of the remote console programmable logic controller PLC is also connected with the manifold pressure gauge  112  and the accumulator pressure gauge  113  via the DA module  1 . The CPU module of the remote console programmable logic controller PLC is further connected with the ring oil pressure gauge  114  via the DA module  2 . The CPU module of the remote console programmable logic controller PLC is further connected with the accumulator main switch  121 , the left-path accumulator switch  122  and the right-path accumulator switch  123  via the switch quantity input port thereof. The CPU module of the remote console programmable logic controller PLC is further connected with a control input end of the valve controller via twelve switch quantity outputs (the twelve switch quantity outputs are respectively used as a bypass valve startup control signal, a bypass on or off control signal, a blowout preventer valve startup control signal, a blowout preventer valve on or off control signal, a pipe ram control valve startup control signal, a pipe ram control valve on or off control signal, a blind ram control valve startup control signal, a blind ram control valve on or off control signal, a shear ram control valve startup control signal, a shear ram control valve on or off control signal, a ring ram control valve startup control signal, and a ring ram control valve on or off control signal). The output of the valve controller is connected with the bypass valve  115 , the blowout preventer valve  116 , the pipe ram control valve  117 , the blind ram control valve  118 , the shear ram control valve  119 , and the ring ram control valve  120  respectively. The bypass valve  115 , the blowout preventer valve  116 , the pipe ram control valve  117 , the blind ram control valve  118 , the shear ram control valve  119 , and the ring ram control valve  120  are accessed to twelve switch quantity input ports (the twelve switch quantity inputs are respectively used as a bypass valve on/off feedback signal, a blowout preventer valve on/off feedback signal, a pipe ram control valve on/off feedback signal, a blind ram control valve on/off feedback signal, a shear valve control valve on/off feedback signal and a ring ram control valve on/off feedback signal) of the remote console programmable logic controller PLC respectively via feedback signal wires. 
     In which, the manifold pressure regulating valve is used for regulating manifold pressure. The ring oil pressure regulating valve is used for regulating ring oil pressure. The manifold pressure gauge is used for displaying manifold pressure value. The accumulator pressure gauge is used for displaying accumulator pressure value. The ring oil pressure gauge is used for displaying ring oil pressure value. The bypass valve is used for opening or closing a bypass pipeline and feeding back the on/off state of a bypass ram. The blowout preventer valve is used for opening or closing blowout preventer pipelines and feeding back the on/off state of the blowout preventer valve. The accumulator main switch is used for opening or closing an accumulator main pipeline. 
       FIG. 21  is a control flow chart of the remote console. Its working flow is approximately as follows. When the control program is initiated, the port Port 1  of the PLC is initialized by the initialization port to realize point-to-point communication with the blowout preventer, and simultaneously, instrument initialization is displayed. Switch quantity is read and stored in an internal buffer zone for subsequent processing. The A/D result is then read and stored in the transmission buffer zone. NET_RW and the blowout preventer console are called for data transmission and reception. Ring, pipe ram, blowout prevention and shear control subprograms are called. The rotation of the stepping motor is controlled according to the operation of a blowout preventer handle in order to switch on the control oil path of the blowout preventer, so that the blowout preventer is controlled to be on or off. If the left and right oil path switches and the oil path main switch are switched on. A ring pressure regulating value is transmitted to a ring instrument display buffer zone. If a bypass is selected to be on, a manifold pressure regulating value is transmitted to a manifold pressure instrument display buffer zone. Otherwise, a 21 MPa display value is transmitted to the instrument display buffer zone. If the left and right oil path switches and the oil path main switch are not switched on, 0 value is transmitted to the instrument display buffer zone. Then, data are read from the instrument display buffer zone to the D/A. Finally, return is performed to read and store the switch quantity in the internal buffer zone, and the above steps are cycled. 
       FIG. 22  is a flow chart of the remote console control sub-program. Its working flow is approximately as follows. The sub-program begins running to read the state of the blowout preventer operation handle from the reception buffer zone in order to judge whether the blowout preventer operation handle operates. The stepping motor rotates only if the blowout preventer operation handle operates. If the stepping motor does not rotate, the beginning state is returned. Otherwise, the stepping motor rotation symbol is controlled to be set. The rotation direction of the stepping motor is selected based upon ON or OFF. In the case of ON, the direction control symbol is set as 0 (indicating left rotation). In the case of complete OFF, the stepping motor rotation symbol is controlled to be zeroed. Then, the beginning state is returned, and in the case of incomplete OFF, return is also performed. In the case of OFF, the direction control symbol is set as 1 (indicating right rotation). In the case of complete on, the stepping motor rotation symbol is controlled to be zeroed. Then, the beginning state is returned. In the case of incomplete ON, return is also performed, and the above steps are cycled. 
     As shown in  FIG. 8 , the choke manifold  101  comprises a choke tube and a valve installed on the choke tube. The choke tube is installed on a choke manifold frame  124  and is featured by vertical and crossed distribution of transverse tubes and vertical tubes. A plurality of flat valves is arranged on the transverse tubes and the vertical tubes. The transverse tubes comprise a choke manifold upper transverse tube  125  and a choke manifold lower transverse tube  126 . The two ends of the choke manifold upper transverse tube  125  are fixedly connected to the choke manifold frame  124 . One end of the choke manifold upper transverse tube  125  is provided with a separator outlet  127  while the other end thereof is provided with a backup outlet  128 . The vertical tubs comprise an overflow inlet tube  129 , a hydraulic choke tube  130  and a manual choke tube  131 . The lower ends of the overflow inlet tube  129 , the hydraulic choke tube  130  and the manual choke tube  131  are provided with an overflow inlet  132 , a hydraulic choke valve  134  and a manual choke valve  135  respectively. The upper end of the overflow inlet tube  129  is fixedly connected to the choke manifold frame  124 . 
     In which, the overflow inlet tube  129  is connected with the choke manifold upper transverse tube  125  and with the choke manifold lower transverse tube  126  respectively in a crosswise manner to form a crossing point a and a crossing point b. The flat valve A is installed on the overflow inlet tube  129  at the upper part of the crossing point a. The flat valve b and the flat valve c are sequentially installed on the overflow inlet tube  129  between the crossing point a and the crossing point b. The pressure gauge  191  is arranged at the crossing point b. A blowout preventer valve on/off indicator  133  is installed on the overflow inlet tube  129  at the lower part of the crossing point b. The two ends of the choke manifold lower transverse tube  126  are fixedly connected to the hydraulic choke tube  130  and the manual choke tube  131  respectively to form a nodal point c and a nodal point d. The flat valve D and the flat valve E are installed on the choke manifold lower transverse tube  126  between the crossing point b and the crossing point c. The flat valve F and the flat valve G are installed on the choke manifold lower transverse tube  126  between the crossing point b and the crossing point d. The upper ends of the hydraulic choke tube  130  and the manual choke tube  131  are connected with the choke manifold upper transverse tube  125  respectively to form a nodal point e and a nodal point f. The flat valve H is installed on the hydraulic choke tube  130  between the nodal point c and the nodal point e. A hydraulic indicator  136  is installed on the manual choke tube  131  at the lower part of the nodal point c. The end part of the manual choke tube is provided with the hydraulic choke valve  134 . The flat valve I is installed on the manual choke tube  131  between the nodal point d and the nodal point f. The manual choke valve  135  is arranged at the end part of the manual choke tube  131  at the lower part of the nodal point d. The flat valve J is arranged on the choke manifold upper transverse tube  125  between the nodal point e and the backup outlet  128 . The flat valve K is arranged on the choke manifold upper transverse tube  125  between the nodal point f and the separator outlet  127 . 
     The working principle of the choke manifold is as follows. When all the operations begin, the choke manifold is set to be in a half-on state. On the choke console, if the hydraulic choke mode is selected: as shown in  FIG. 23 , the flat valves D, E, H, G, B and J are opened. The needle valve, the flat valves F, C, I, A and K, and the manual choke valve  12  are closed. 
     On the choke console, if the manual choke mode is selected: as shown in  FIG. 24 , the flat valves F, G, I, K, B and D, and the manual choke valve  12  are opened, and that the flat valves E, H, C, A and J are closed. 
     As shown in  FIG. 9 , the high pressure manifold  102  comprises a high pressure tube and a valve installed on the high pressure valve. The high pressure tube is installed on a high pressure manifold frame  137  and is featured by vertical connection and distribution of transverse tubes and vertical tubes. A high pressure manifold upper transverse tube  138 , a high pressure manifold lower transverse tube  139 , a left vertical tube  140 , and a right vertical tube  141  are jointed at the middle of the high pressure tube to form a rectangle. A plurality of flat valves is arranged on the transverse tubes and the vertical tubes. The transverse tubes further comprise a left mud inlet tube  142 , a right mud inlet tube  143  and a grouting outlet tube  143 . The left end of the left mud inlet tube  142  is fixedly connected to the high pressure manifold frame  137 . The left end part of the left mud inlet tube  142  is provided with a mud inlet I  144 . The right end of the right mud inlet tube  151  is fixedly connected to the high pressure manifold frame  137 . The right end part of the right mud inlet tube  151  is provided with a mud inlet II  145 . The left end of the grouting outlet tube  143  is fixedly connected to the high pressure manifold frame  137 . The left end part of the grouting outlet tube  143  is provided with a grouting outlet  146 . The vertical tubes further comprise an upper vertical tube  147 , and a lower vertical tube  148 . The upper end of the upper vertical tube  147  is fixedly connected to the high pressure manifold frame  137 . The upper end part of the upper vertical tube  147  is provided with a backup inlet  149 . The lower end of the lower vertical tube  148  is fixedly connected to the high pressure manifold frame  137 . The lower end part of the lower vertical tube  148  is provided with a vertical tube outlet  150 . 
     In which, the left mud inlet tube  142  and the right mud inlet tube  151  of the high pressure manifold  102  are in T-shaped connection with the rectangular left vertical tube  140  and the rectangular right vertical tube  141  respectively to form a nodal point h and a nodal point i. The flat valve L is installed on the left vertical tube  140  at the upper part of the nodal point h. The flat valve M is installed on the left vertical tube  140  at the lower part of the nodal point h. The flat valve N is installed on the right vertical tube  141  at the upper part of the nodal point i. The flat valve O is installed on the right vertical tube  141  at the lower part of the nodal point i. The upper vertical tube  147  and the lower vertical tube  148  are in T-shaped connection with the rectangular high pressure manifold upper transverse tube  138  and the rectangular high pressure manifold lower transverse tube  139  respectively to form a nodal point g and a nodal point j. The grouting outlet tube  143  is in T-shaped connection with the lower vertical tube  148  to form a nodal point k. The flat valve P is installed on the grouting outlet tube  143 . The flat valve Q is installed on the lower vertical tube  148  at the lower part of the nodal point k. 
     The working principle of the high pressure manifold is as follows. When all the operations begin, the high pressure manifold is set to be in a corrective grouting or circulating state. On the choke console, if the No. 1 pump is selected, the state is set as the grouting state, wherein as shown in  FIG. 25 , the flat valves M, P and N are opened and the flat valves L, O and Q are closed. The state is set as the circulating state, wherein as shown in  FIG. 26 , the flat valves M, Q and N are opened and the flat valves L, O and P are closed. 
     On the choke console, if the No. 2 pump is selected, the state is set as the grouting state, wherein as shown in  FIG. 27 , the flat valves O, P and L are opened and the flat valves M, N and Q are closed. The state is set as the circulating state, wherein as shown in  FIG. 28 , the flat valves O, Q and L are opened and the flat valves M, N and P are closed. 
     On the choke console, if the dual pumps are selected, the state is set as the grouting state, wherein as shown in  FIG. 29 , the flat valves M, O and P are opened and the flat valves L, N and Q are closed. The state is set as the circulating state, wherein as shown in  FIG. 30 , the flat valves M, O and Q are opened and the flat valves L, N and P are closed. 
     As shown in  FIG. 10 , the blowout preventer console  103  is characterized by comprising a chassis and an internal control plate. The front face of the chassis is provided with a blowout preventer control panel  152 . The blowout preventer control panel  152  is provided with an accumulator pressure gauge  153 , a ring blowout preventer oil pressure gauge  154 , a gas source pressure gauge  155 , a manifold pressure gauge  156 , a ring ram switch  157 , a ring ram on indicator  158 , a ring ram off indicator  159 , a gas source switch  160 , a bypass ram switch  164 , an upper pipe ram switch  161 , an upper pipe ram on indicator  162 , an upper pipe ram off indicator  163 , a blind ram switch  165 , a blind ram on indicator  166 , a blind ram off indicator  167 , a kill manifold ram switch  168 , a kill manifold on indicator  169 , a kill manifold off indicator  170 , a blowout preventer valve switch  171 , a blowout preventer valve off indicator  172 , a blowout preventer valve on indicator  173 , a lower pipe ram switch  174 , a lower pipe ram on indicator  175 , and a lower pipe ram off indicator  176 . The internal control plate comprises a blowout preventer programmable logic controller PLC. A CPU module of the blowout preventer programmable logic controller PLC is connected with the accumulator pressure gauge  153  and the ring blowout preventer oil pressure gauge  154  via the DA module  1  respectively and connected with the gas source pressure gauge  155 , and the manifold pressure gauge  156  via the DA module  2  respectively. The CPU module of the blowout preventer programmable logic controller PLC is further connected with the ring ram switch  157 , the gas source switch  160 , the bypass ram switch  164 , the upper pipe ram switch  161 , the blind ram switch  165 , the kill manifold ram switch  168 , the blowout preventer valve switch  171 , and the lower pipe ram switch  174  respectively via the switch quantity input port thereof. The CPU module of the blowout preventer programmable logic controller PLC is further connected with the ring ram on indicator  158 , the ring ram off indicator  159 , the upper pipe ram on indicator  162 , the upper pipe ram off indicator  163 , the blind ram on indicator  166 , the blind ram off indicator  167 , the kill manifold on indicator  169 , the kill manifold off indicator  170 , the blowout preventer valve off indicator  172 , the blowout preventer valve on indicator  173 , the lower pipe ram on indicator  175 , and the lower pipe ram off indicator  176  respectively via the switch quantity output port thereof. The CPU module of the blowout preventer programmable logic controller PLC is further connected, via the switch quantity input port thereof, with the flat valves L, M, N, O, P and Q installed on the high pressure tube in the high pressure manifold respectively. 
       FIG. 31  is a control flow chart of the blowout preventer. Its working flow is approximately as follows. When the control program is initiated, the port Port 1  of the PLC is initialized by the initialization port to realize point-to-point communication with the remote console, and simultaneously, initialization is displayed by both indicators and the display instruments. Switch quantity is read and stored in the internal buffer zone for being directly read by PC. The NET_RW and the remote console are called for data transmission and reception. Ring, pipe ram, blowout prevention and shear control subprograms are called to control the indicators according to the blowout preventer operation handle and the on/off time in order to display whether the blowout preventers are completely opened/closed. Afterwards, the state of the indicator (for indicating ON/OFF state of the blowout preventer) is stored in the transmission buffer zone. Then, an alarm control standard is read from the reception buffer zone. Alarm is switched on in the case of choosing to alarm and alarm is switched off in the case of choosing to not alarm. Finally, the step of reading and storing the switch quantity in the transmission buffer zone is returned, and the above steps are cycled. 
       FIG. 32  is a flow chart of the ring blowout preventer control sub-program. Its working flow is approximately as follows. The sub-program begins running. The ON/OFF states including the operation handle state of the blowout preventer and the operation handle state of the remote console are read. In the case that the remote console is connected, if the gas source on the blowout preventer is chosen to be ON and the ring is ON or the ring on the remote console is ON, the time is set to be 8 seconds. The indicator is ON if the ring blowout preventer is on. The indicator is OFF if the ring blowout preventer is OFF. Then, the sub-program is returned. Otherwise, the sub-program is returned. If the gas source on the blowout preventer is chosen to be ON and the ring is OFF or the ring ON the remote console is OFF, the time is set to be 8 seconds. The indicator is ON if the ring blowout preventer is OFF. The indicator is OFF if the ring blowout preventer is ON. Then, the sub-program is returned. Otherwise, the sub-program is returned. In the case that no remote console is connected, if the gas source on the blowout preventer is ON and the ring is ON, the time is set to be 8 seconds. The indicator is ON if the ring blowout preventer is ON. The indicator is OFF if the ring blowout preventer is OFF, and then the sub-program is returned. If the time is not set to be 8 seconds, the sub-program is still returned. If the gas source on the blowout preventer is ON and the ring is OFF, the time is set to be 8 seconds. The indicator is ON if the ring blowout preventer is OFF. The indicator is OFF if the ring blowout preventer is ON. Then, sub-program is returned, or otherwise, the subprogram is returned. 
     As shown in  FIG. 12 , the choke console  104  comprises a chassis and an internal control plate. The front face of the chassis is provided with a choke control panel  177 . The choke control panel  177  is provided with a vertical tube pressure gauge  178 , a pump speed gauge  179 , a sleeve pressure gauge  180 , a hydraulic choke valve selection indicator  181 , a dual-pump selection switch  182 , a choke valve selection switch  183 , a pump stroke display  184 , a choke valve opening gauge  185 , a manual choke valve selection indicator  186 , a reset button  187 , a driller gas source switch  188 , a choke control valve switch  189 , and a choke valve speed adjusting knob  190 . The internal control plate comprises a choke programmable logic controller PLC. A CPU module of the choke programmable logic controller PLC is connected with the choke valve speed adjusting knob  190  via the AD module. The CPU module of the choke programmable logic controller PLC is also connected with the vertical tube pressure gauge  178  and the sleeve pressure gauge  180  via the DA module  1 . The CPU module of the choke programmable logic controller PLC is further connected with the pump speed gauge  179  and the choke valve opening gauge  185  via the DA module  2 , and connected with a choke data transmitting/receiving plate via a serial port. The choke data transmitting/receiving plate is connected with a pump stroke display  184  via a parallel port. The CPU module of the choke programmable logic controller PLC is further connected with the hydraulic choke valve selection indicator  181  and the manual choke valve selection indicator  186  via the switch quantity output port thereof respectively, and connected with the dual-pump selection switch  182 , the choke valve selection switch  183 , the reset button  187 , the driller gas source switch  188  and the choke control valve switch  189  via the switch quantity input port thereof respectively. The CPU module of the choke programmable logic controller PLC is further connected, via the switch quantity input port thereof, with the flat valves A, B, C, D, E, F, G, H, I, J and K installed on the choke tube in the choke manifold respectively. The CPU module of the choke programmable logic controller PLC is further connected with the manual choke valve  135  in the choke manifold via the AD module and with a pressure gauge  191  via the DA module  1 . 
     As shown in  FIG. 36 , the choke data transmitting/receiving plate comprises a serial port chip, a single chip microcomputer, a latch and a bus buffer. The input end of the serial port chip is connected with the serial port of the choke programmable logic controller PLC via the serial port. The output end of the serial port chip is connected with the transmitting data line and the receiving data line of the single chip microcomputer respectively. The single chip microcomputer is further connected with the latch and the bus buffer via buses respectively. The output ports of the latch and the bus buffer are connected with the pump stroke display  184  via the parallel ports. The pump stroke display  184  comprises an address buffer, a data buffer, a comparator, a decoder, a dip switch, a nixie tube drive chip, and a nixie tube. The input ports of the address buffer and the data buffer are both connected with the parallel port. The output port of the data buffer is connected with the nixie tube drive chip. The output port of the address buffer is connected with one input end of the comparator and the decoder respectively. The other input end of the comparator is connected with the dip switch. The output port is connected with the enabling end of the decoder. The output end of the decoder is connected with the nixie tube drive chip. The output end of the nixie tube drive chip is connected with the nixie tube. 
       FIG. 34  is a flow chart of the choke control program. Its working flow is approximately as follows. When the control program is initiated, the port Port 1  of the PLC is initialized by the initialization port to realize data communication with the LED display control plate. Then, switch quantities (including switch quantity inputs of the dual-pump selection switch, the choke valve selection switch, the reset switch, the driller gas source switch and the choke valve control switch) are read and stored in the transmission buffer zone for being directly read by PC communication. The A/D result I is then read and stored in the transmission buffer zone for being directly read by PC communication. Whether a hydraulic mode or a manual mode is selected is judged, wherein if the hydraulic mode is selected, the hydraulic indicator is turned on, and if the manual mode is selected, the manual indicator is turned on. Afterwards, data are read from the reception buffer zone and output to the D/A in order to control the display of instruments for displaying vertical tube pressure, sleeve pressure, pumps speed and chokes speed. The data are then transmitted to the LED display control plate via the serial port. The switch quantities are read again and stored in the transmission buffer zone, and the above steps are cycled. In addition, the entire system is a bus-type network including one PC serving as a master station and a plurality of PLCs serving as a slave station. Every communication is initiated by the master station, the slave station monitors and judges whether transmission and reception requests about the slave station is present. 
       FIG. 35  is a flow chart of the communication between the choke and the PC. Its working flow is approximately as follows. The master station transmits a signal, wherein if the slave station monitors the transmission and reception requests about the slave station, the slave station agrees with the reception of the requests so that the data is received and stored in the reception buffer zone. Afterwards, the slave station returns to continue monitoring, wherein if the slave station does not monitor the transmission and reception requests about the slave station and does not receive and transmit the requests, the slave station returns to monitor, and if the slave station does not receive the request, but agrees with the reception of the requests, in this case, the data are read from the transmission buffer zone and transmitted. Then, the slave station returns to monitor, and the above steps are cycled. 
     As shown in  FIG. 60 , the main control computer comprises one or more than one general computers as well as a communication program and a main control program running thereon. The graphic computer comprises one general computers as well as a graphic processing program running thereon. The communication program is connected with front end hardware via the PPI protocol, wherein the front end hardware comprises the blowout preventer console, the choke console, the remote console and the driller console. The main control program is connected with the communication program and the graphic processing program via the TCP/IP protocol respectively. 
     The main control program comprises an operation training module, a system management module and a scoring and management module. The program is communicated with front end hardware equipment via the communication program to obtain the state of the hardware equipment in real-time. The a plurality of typical drilling processes is simulated by means of relevant mathematical models to finish the following tasks. 1. A control command is sent to the graphic processing program via the TCP/IP protocol, in order to control graphic actions. 2. An intelligent scoring system is realized. 3. A signal is fed back to the front end hardware, enabling the parameter display of front end instruments to accord with onsite situation. 
     System management module comprises hardware self-inspection, user management and killing scheme management. It is mainly used for completing management and configuration for software system. The functions like system self-inspection and user management can be completed using this module. Meanwhile, some parameters in the system are changed so as to change the operation mode of the main control program. In this way, different demands are met. 
     The scoring module is mainly used for automatically scoring the training process and simultaneously providing perfect score management function. Scoring is related mainly to two factors: 1. Operating Flow: All the operating flow of trainees is recorded in the system, wherein the operating flow of trainee is compared with a preset operating flow in the system upon the completion of trainee examination to evaluate the accordance of the two flows and score the operating flow of trainees on this basis. 2. Operating Level: In addition to the grasp of corrective operating flow by trainees, their operating flow shall be taken into consideration in comprehensively evaluating the technical level of trainees, e.g. whether the selection for weight on bit during drilling in is appropriate and whether drilling is even. For the problem whether the control for pressure during killing meets the demand of killing constructor, the system determines the operating level score by adopting a method for recording relevant data curves in the operating flow and comparing the data curves with standard curves afterwards. As shown in  FIG. 61 , the scoring process is as follows: a trainee logs in the system, begins examination and completes corresponding operations. Then, the system scores automatically based upon relevant standards to obtain a final score. 
     The graphic processing program comprises a scene initialization module, a process animation control module, a collision processing module, and a render effect module. A vivid, virtual drilling environment is created by means of full three-dimensional animation so that trainees feel as if they were in a real drilling environment, and thus the mental resilience of trainees in accident handling is improved and better training effect is obtained. The four modules have the following functions: 
     Scene initialization: The current scene of every operation differs owing to the complexity of drilling process and the operability of virtual training. Before a new operation begins, the graphic program initializes the current scene after receiving an operation command sent from the control computer, for example the current number, state and position of operating components on a drilling platform. 
     Process animation control: In the process of completing the specified process operation, every action from drilling console is converted into a digital signal, wherein the digital signal is transmitted to the main control computer, the protocol data are then sent to the graphic program by the main control computer, and the graphic program gives a specific response after the acquisition of parameters. Motion parameters, specific motions and view selection (including aboveground visual angle, underground visual angle, blowout preventer visual angle, multi-view display, etc.) of various control systems on drilling platform are reflected on a graphic machine. 
     Collision processing: The situation of ‘wall through’ is not allowed in the motion simulation process of three-dimensional graphics. Therefore, collision detection shall be performed on motion objects. To cause model motion to be realistic, a drilling simulator visual simulating system certainly includes collision detecting and processing parts. 
     Render effect: Simulation for flame, bubble, liquid jetting effects is realized, wherein movie-level illumination effect is accomplished using GLSL, and illumination modes like daylight, night and searchlight can be simulated respectively. Thus, greatly improving graphic effect and sense of reality. 
     The operation training module comprises an RIH sub-module, a POOH sub-module, a drill-in sub-module, an accident and complex situation handling sub-module, a shut in sub-module, and a killing sub-module. The operation training module provides the training about 23 common technological processes and event drive processes in the drilling process. Accordingly, it is the most important module in the main control program. Event drive training has no limitation to trainees, who therefore can operate the simulator randomly. The graphic system will reflect reasonable mechanical motions and simultaneously give a voice prompt with regard to erroneous operations. The module is mainly used for cognitive training of new trainees about drilling site and drilling machinery. In technical process training, trainees are required to operate the simulator per its technical process, in order to intensify the comprehension of trainees on the technical process and make trainees master the operation process of the simulator. 
     Among all the sub-modules, the top driving event drive sub-module is used for operation simulation based on real top driver. The simulation includes control logic contents like internal blowout preventer, locking of rotary head, rotation of elevator links, inclination of elevator links, backup tongs, drilling well or rotary makeup or torque, reversal rotation or stoppage or positive rotation, and etc. 
       FIG. 37  is a flow chart of normal RIH. Its working flow is approximately as follows: begin this operation, start up an elevator, then place and make up a stand, move the elevator away, drop a drill bit, take off elevator links, and judge whether RIH is performed, wherein if so, return to start up the elevator, or otherwise, end this operation. 
       FIG. 38  is a flow chart of set weight. Its working flow is approximately as follows: begin this operation, perform RIH normally, perform punching and reaming in the event of set weight, end this operation, and return if set weight does not occur. 
       FIG. 39  is a flow chart of fluctuation pressure controlling RIH. Its working flow is approximately as follows: begin this operation, start up an elevator, then place and make up a stand, move the elevator away, drop a drill bit at low speed, press corresponding button to take off elevator links, and judge whether RIH is continued, wherein if so, return to begin this operation, or otherwise, end this operation. 
       FIG. 40  is a flow chart of normal POOH. Its working flow is approximately as follows: begin this operation, lift up a drill bit, unload a stand, pour mud, and judge whether POOH is performed, wherein if so, return to begin this operation, or otherwise, end this operation. 
       FIG. 41  is a flow chart of getting overpull. Its working flow is approximately as follows: begin this operation, perform POOH normally, perform circulative freeing in the event of getting overpull, perform back reaming, end this operation, and return to normal POOH in the case of being unstuck. 
       FIG. 42  is a flow chart of suction pressure controlling POOH. Its working flow is approximately as follows: begin this operation, lift the drill bit at low speed, unload the stand, pour the mud, and judge whether POOH is continued, wherein if so, return to lift the drill bit at low speed, or otherwise, end this operation. 
       FIG. 43  is a flow chart of normal drilling and stand makeup. Its working flow is approximately as follows: begin this operation, circulate mud, perform light press and running in, perform drilling normally, make up the stand, and drop by a certain depth to end this operation. 
       FIG. 44  is a flow chart of drilling under different formation drillabilities. Its working flow is approximately as follows: begin this operation, circulate mud, perform light press and running in, drill by 1 meter at a first formation, drill by 1 meter at a second formation, drill by 1 meter at a third formation, take out drilling pipe, and end this operation. 
       FIG. 45  is a flow chart of drilling under bouncing. Its working flow is approximately as follows: begin this operation, perform drilling normally if not bouncing occurs, lift up drilling pipe if bouncing occurs, change rotating speed and weight on bit, drop drilling pipe, judge whether bouncing is reduced, wherein return to lift up drilling pipe if bouncing is not reduced, circulate the operation until bouncing is reduced, then ream bouncing sections, and end this operation. 
       FIG. 46  is a flow chart of high-pressure formation drilling. Its working flow is approximately as follows: begin this operation, circulate mud, perform drilling normally, judge whether overflowing occurs, wherein perform drilling normally if not overflowing occurs, or otherwise, increase mud density, continue drilling, make up the stand, and, finally, end this operation. 
       FIG. 47  is a flow chart of low-pressure formation drilling. Its working flow is approximately as follows: begin this operation, circulate mud, perform drilling normally, judge whether leakage occurs, perform drilling normally if not leakage occurs, otherwise, increase mud density, continue drilling, make up the stand, and, finally, end this operation. 
       FIG. 48  is a flow chart of adhesion sticking judging and handling. Its working flow is approximately as follows: begin this operation, lift up the drilling pipe, judge whether there is a ground failure, continue lifting up the drilling pipe if there is no failure, drop the drill bit interruptedly if there is a failure, move the drill bit, circulate mud, free the moved drill bit, then judge whether the moved drill bit has been freed, wherein if not, return to continue freeing until freeing is completed, and end this operation. 
       FIG. 49  is a flow chart of solids settling sticking judging and handling. Its working flow is approximately as follows: begin this operation, perform POOH normally, judge whether there is solids settling sticking, wherein if not, return to normal POOH, move the drill bit if there is solids settling sticking, circulate mud in small quantity, judge whether pump pressure is normal, wherein if not, return to circulate mud, and if so, circulate mud in large quantity, and, finally, end this operation. 
       FIG. 50  is a flow chart of balling-up sticking judging and handling. Its working flow is approximately as follows: begin this operation, perform light press and running in, perform drilling, judge whether there is balling-up sticking, wherein if not, return to normal POOH, and if so, circulate mud in larger quantity, perform reaming at high speed, regulate mud performances, continue drilling, and, finally, end this operation. 
       FIG. 51  is a flow chart of taper tap fishing. Its working flow is approximately as follows: begin this operation, wash top of fish, detect fallen fish downwards, judge whether the fallen fish is detected, wherein if not, return to continue downward detection, and if so, release thread, make thread, try to lift up the drill pipe, lift up the fallen fish, and, finally, end this operation. 
       FIG. 52  is a flow chart of junk milling. Its working flow is approximately as follows: begin this operation, wash well bottom, mill twice, continue milling until the mill is broken, and end this operation. 
       FIG. 53  is a flow chart of normal drilling and shutting in. Its working flow is approximately as follows: begin this operation, perform drilling normally, judge whether overflowing occurs, wherein if not, perform drilling normally, and if so, open the choke manifold and close ring blowout preventer, upper pipe ram blowout preventer, throttle valve and J2A flat valves, then log well and end this operation. 
       FIG. 54  is a flow chart of POOH and shutting in. Its working flow is approximately as follows: begin this operation, unload a square drilling pipe, lift up a vertical pipe, judge whether overflowing occurs, wherein if not, return to lift up the vertical pipe, and if so, make up a drill bit blowout preventer in advance, shut in well, log well, and end this operation. 
       FIG. 55  is a flow chart of drill collar lifting and shutting in. Its working flow is approximately as follows: begin this operation, lift up a drill collar, judge whether overflowing occurs, wherein if not, return to lift up the drill collar, and if so, make up a blowout preventing single pipe in advance, shut in well, log well, and end this operation. 
       FIG. 56  is a flow chart of emptying and shutting in. Its working flow is approximately as follows: begin this operation, judge whether the overflowing quantity is large after the drill collar is lifted up, wherein if so, shut in well and log well and finally end this operation, and if not, make up the blowout preventing single pipe in advance, shut in well, log well, and finally end this operation. 
       FIG. 57  is a flow chart of killing by driller&#39;s method. Its working flow is approximately as follows: begin this operation, set mud pump stroke, discharge contaminated mud, judge whether the contaminated mud is completely discharged, wherein if not, return to discharge the contaminated mud completely, and if so, increase mud density, perform killing by weighted mud, judge whether killing is finished, wherein if not, return to continue killing, and if so, end this operation. 
       FIG. 58  is a flow chart of killing by engineer&#39;s method. Its working flow is approximately as follows: begin this operation, set mud pump stroke, increase mud density, then perform killing by weighted mud, and judge whether killing is finished, wherein if not, return to continue killing, and if so, end this operation. 
       FIG. 59  is a flow chart of killing by overweight mud driller&#39;s method. Its working flow is approximately as follows: begin this operation, prepare overweight mud, pump the overweight mud in, judge whether circulation is finished, wherein if so, regulate mud density, perform killing by killing mud, and judge whether killing is finished, wherein if not, return to continue killing, and if so, end this operation. 
     One skilled in the art will understand that the embodiment of the present invention as shown in the drawings and described above is exemplary only and not intended to be limiting. 
     It will thus be seen that the objects of the present invention have been fully and effectively accomplished. The embodiments have been shown and described for the purposes of illustrating the functional and structural principles of the present invention and is subject to change without departure from such principles. Therefore, this invention includes all modifications encompassed within the spirit and scope of the following claims.