Closed loop drilling system

• US 5,842,149 A
• Filed: 10/22/1996
• Issued: 11/24/1998
• Est. Priority Date: 10/22/1996
• Status: Expired due to Term

• Current Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Dubinsky, Vladimir, Leggett, James V. III, Harrell, John W.
• Primary Examiner(s): McElheny, Jr., Donald E.
• Application Number:
  US08/734,935
• Time in Patent Office: 763 Days
• Field of Search: 702/6, 702/7, 702/9, 324/369, 175/45, 175/50
• US Class Current: 702/9
• CPC Class Codes: E21B 44/00 Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
• CPC Class Codes: E21B 44/005 Below-ground automatic control systems
• CPC Class Codes: E21B 44/02 Automatic control of the tool feed E21B44/005, E21B44/10 take precedence

Abstract

The present invention provides a closed-loop drilling system for drilling oilfield boreholes. The system includes a drilling assembly with a drill bit, a plurality of sensors for providing signals relating to parameters relating to the drilling assembly, borehole, and formations around the drilling assembly. Processors in the drilling system process sensors signal and compute drilling parameters based on models and programmed instructions provided to the drilling system that will yield further drilling at enhanced drilling rates and with extended drilling assembly life. The drilling system then automatically adjusts the drilling parameters for continued drilling. The system continually or periodically repeats this process during the drilling operations. The drilling system also provides severity of certain dysfunctions to the operator and a means for simulating the drilling assembly behavior prior to effecting changes in the drilling parameters.

Claims

1. An automated drilling system for drilling oilfield wellbores at enhanced rates of penetration and with extended life of drilling assembly, comprising:

(a) a tubing adapted to extend from the surface into the wellbore;

(b) a drilling assembly comprising a drill bit at an end thereof and a plurality of sensors for detecting selected drilling parameters and generating data representative of said drilling parameters;

(c) a computer comprising at least one processor for receiving signals representative of said data;

(d) a force application device for applying a predetermined force on the drill bit within a range of forces;

(e) a force controller for controlling the operation of the force application device to apply the predetermined force;

(f) a source of drilling fluid under pressure at the surface for supplying a drilling fluid

(g) a fluid controller for controlling the operation of the fluid source to supply a desired predetermined pressure and flow rate of the drilling fluid;

(h) a rotator for rotating the bit at a predetermined speed of rotation within a range of rotation speeds;

(i) receivers associated with the computer for receiving agnate signals representative of the data;

(j) transmitters associated with the computer for sending control signals directing the force controller, fluid controller and rotator controller to operate the force application device, source of drilling fluid under pressure and rotator to achieve enhanced rates of penetration and extended drilling assembly life.

2. The automated drilling system of claim 1, wherein the force application device comprises a rotary rig at the surface, with the rotary rig further supplying tubing as necessary for continued drilling operations.

3. The automated drilling system of claim 1, wherein the force application device comprises a coiled tubing rig at the surface, with the coiled-tubing rig further supplying tubing as necessary for continued drilling operations.

4. The automated drilling system of claim 1, wherein the force application device comprises thruster downhole associated with the drilling assembly and a wellbore engagement device for selectively engaging the sidewall of the wellbore on application of thrust force by the thruster, with the processor signaling a rig at the surface to supply tubing as necessary for continued drilling operations.

5. The automated drilling system of claim 1, wherein the rotator is a rotary rig at the surface.

6. The automated drilling system of claim 1, wherein the rotator is a motor downhole on the tubing driven by the fluid under pressure supplied from a source at the surface.

7. The automated drilling system of claim 1, wherein the rotator comprises an electric motor.

8. The automated drilling system of claim 1, wherein the computer is located at least in part downhole.

9. The automated drilling system of claim 1, wherein the drilling assembly further comprises formation evaluation sensors on the drilling assembly for detecting downhole formation parameters and generating data representative of the formation parameters, and a direction control device on the tubing for steering the drilling assembly toward a desired formation, with the computer receiving the data and generating control signals for controlling the operation of the direction control device.

10. The automated drilling system of claim 1, wherein the transmitters communicate via media selected from the group comprising electro-magnetic, tubing acoustic, fluid acoustic, mud pulse, fiber optics, and electric conductor.

11. The automated drilling system of claim 1, wherein the sensor measure downhole parameters selected from the group comprising bit bounce, torque, shock, vibration, rotation, stick-slip, whirl, bending moment, and drill bit condition.

12. The automated drilling system of claim 1, wherein the downhole sensors are selected from the group comprising pressure sensor, accelerometer, magnetometer, gyroscopes, temperature sensor, force on bit sensors, and drill bit wear sensor.

13. An automated method for drilling an oilfield wellbore with a drilling system having a drilling assembly having a drill bit at an end thereof at enhanced drilling rates and with extended drilling assembly life, said drilling assembly conveyable with a tubing into the wellbore, said drilling assembly containing a plurality of downhole sensors for determining parameters relating to the formations surrounding the wellbore and the condition of the drilling assembly elements, comprising:

(a) conveying the drilling assembly with the tubing into the wellbore for further drilling the wellbore;

(b) initiating drilling of the wellbore with the drilling assembly utilizing a plurality known initial drilling parameters;

(c) determining from the downhole sensors during drilling of the wellbore parameters relating to the condition of the drilling assembly;

(d) providing a model for use by the drilling system to compute new value for the drilling parameters that when utilized for further drilling of the wellbore will provide drilling of the wellbore at an enhanced drilling rate and with extended drilling assembly life; and

(e) further drilling the wellbore utilizing the new values of the drilling parameters.

14. The automated method of drilling an oilfield wellbore according to claim 13, wherein the drilling parameters are selected from the group comprising rate of penetration, drilling fluid rate, weight on bit, rotational speed of the drill bit, thrust force on the drill bit, and the drilling fluid viscosity.

15. The automated method of drilling an oilfield wellbore according to claim 13, wherein the parameters relating to the physical condition of the drilling assembly are selected from the group comprising bit bounce, torque, shock, lateral vibration, axial vibration, radial force on the drilling assembly, stick-slip, whirl, bending moment, drill bit condition, bit bounce, whirl, and axial force on the drilling assembly.

16. The automated method of drilling an oilfield wellbore according to claim 13, wherein the downhole sensors are selected from the group comprising a temperature sensor, pressure sensor, vibration sensor, sensor for determining wear of the drill bit, pressure sensor for determining pressure drop across a mud motor, sensor for determining the rotational speed of the drill bit, fluid flow rate sensor, shock sensor, sensor for determining whirl, sensor for determining axial vibration, sensor for determining radial vibration, resistivity sensor, gamma ray sensor, and acoustic sensor.

17. The automated method of drilling an oilfield wellbore according to claim 13, wherein the models include a model for relating to determining dysfunction of a selected member of the drill string during drilling operations.

18. The automated method of drilling an oilfield wellbore according to claim 13, wherein the models include a look-up table which provides drilling parameter values corresponding to parameters relating to the physical condition of the drilling assembly.

19. The automated method of drilling an oilfield wellbore according to claim 13, wherein the drilling system automatically changes the drilling parameters to the new parameter values for performing continued drilling.

20. The automated method of drilling an oilfield wellbore according to claim 13 further comprising periodically repeating steps (c) through (e).

21. The automated method of drilling an oilfield wellbore according to claim 13 further comprising:

(i) determining the position of the drilling assembly in the wellbore during drilling;

(ii) comparing the determined position with a preexisting desired position to determine the difference between said positions; and

(iii) changing the drilling direction when the difference is greater than a predetermined value.

22. The automated method of drilling an oilfield wellbore according to claim 13 wherein a control unit in the drilling assembly causes a directional device in the drilling assembly to change the drilling direction.

23. An automated method for drilling an oilfield wellbore with a drilling system having a drilling assembly having a drill bit at an end thereof at enhanced drilling rates and with extended drilling assembly life, said drilling assembly conveyable with a tubing into the wellbore and having a plurality of downhole sensors for determining parameters relating to the formations surrounding the wellbore and the physical condition of the drilling assembly elements, comprising:

(a) conveying the drilling assembly with the tubing into the wellbore for further drilling the wellbore;

(b) initiating drilling of the wellbore with the drilling assembly utilizing a plurality known initial drilling parameters;

(c) determining from the downhole sensors during drilling of the wellbore parameters relating to the physical condition of the drilling assembly and the formation surrounding the drilling assembly;

(d) providing models associated with the drilling system and combining the determined parameters with said models to compute new value for the drilling parameters in the plurality of parameters that when utilized for further drilling the wellbore will provide drilling of the wellbore at an enhanced drilling rate and with extended drilling assembly life; and

(e) further drilling the wellbore utilizing the new values of the drilling parameters.

24. An automated drilling system for drilling oilfield wellbores at enhanced rates of penetration and with extended life of drilling assembly, comprising:

(a) a drilling assembly having a drill bit, said drilling assembly adapted to be conveyed by a tubing into the wellbore from the surface;

(b) a force application device for applying a predetermined force on the drill bit within a range of forces;

(c) a force controller for controlling the operation of the force application devise to apply the predetermined force;

(d) a source of drilling fluid under pressure at the surface for supplying a drilling fluid;

(e) a fluid controller for controlling the operation of the fluid source to supply a desired predetermined pressure and flow rate of the drilling fluid;

(f) a rotator for rotating the bit at a predetermined speed of rotation within a range of rotation speeds;

(g) a plurality of sensors for detecting selected drilling assembly parameters during the drilling operations and generating data representative of said drilling assembly parameters;

(h) a computer comprising at least one processor, said computer determining from the generated data and at least one model provided to the computer drilling parameters that will yield enhanced drilling rate and extended drilling assembly life, said computer further causing the force controller, fluid controller and rotator controller to operate the force application device, source of drilling fluid under pressure and rotator to operate in accordance with the computed drilling parameters to achieve enhanced rates of penetration and extended drilling assembly life.

25. A system for drilling boreholes, comprising:

(a) a drill string having a drill bit at a bottom end;

(b) a bottom hole assembly (BHA) for providing data representative of the values of selected downhole drill string parameters; and

(c) a surface control unit for receiving the data, displaying dysfunctions relating to said drill string parameters and determining a corrective action for alleviating said dysfunctions.

26. The apparatus as specified in claim 25, wherein the downhole drill string parameters are selected from a group comprising torque, shock, vibration, bending moment, whirl, stick-slip, and bit bounce.

27. The apparatus as specified in claim 25, wherein the surface control unit includes a computer having a model associated therewith.

28. The apparatus as specified in claim 27, wherein the computer determines the corrective action based on a predefined matrix of values contained in the model and displays the dysfunctions and the corrective action on a display associated with the surface control unit.

29. A drilling system for drilling oilfield wellbores, comprising:

(a) a drill string having a drilling assembly comprising a drill bit at an end for drilling the wellbores

(b) a plurality of sensors in the drill string for detecting motion of the drill string along predefined directions and generating signals corresponding to the detected motions;

(c) a processor in the drill string, said processor calculating parameters relating to selected operating conditions of the drill string and determining the severity of such computed parameters;

(d) a transmitter associated with the drill string for transmitting data to the surface corresponding to the severity of the computed parameters; and

(f) a computer at the surface, said computer receiving said data, displaying the severity of the computed parameters and determining a set of drilling parameters which when used for further drilling of the wellbore will enhance the drilling rate and extend the operating life of the drill string.

30. A system for simulating borehole drilling conditions for a given bottom hole assembly (BHA) and a borehole profile, said simulator comprising:

(a) a computer;

(b) a memory associated with said computer for storing therein programmed instructions; and

(c) a model associated with said computer, said model having defined therein parameters relating to the BHA and the borehole profile, said computer utilizing the model for determining dysfunctions relating to the BHA for a given set of surface-controlled parameters, said computer further determining a corrective action for alleviating said dysfunction.

31. The apparatus as specified in claim 30, wherein the computer displays the dysfunctions and the corrective action on a display.

32. The apparatus as specified in claim 31, wherein the computer displays the severity level of each said dysfunction.

33. A method of drilling a wellbore utilizing a drill string having a drill bit at an end thereof, comprising:

(a) making a plurality of measurements relating to the motion of the drill string during drilling;

(b) determining downhole a plurality of drill string parameters from the plurality of measurements;

(c) transmitting data to the surface corresponding to the severity of the drill string parameters;

(d) determining at the drilling parameters that will alleviate the dysfunctions for further drilling of the wellbore; and

(e) continuing drilling by adjusting the drilling parameters.