Optimized drilling

Patent metadata

Field	Value
Publication number	US-9574432-B2
Application number	US-201113993640-A
Country	US
Kind code	B2
Filing date	Dec 13, 2011
Priority date	Dec 13, 2010
Publication date	Feb 21, 2017
Grant date	Feb 21, 2017

Abstract

The invention provides a method of optimizing the rate of penetration of a hydraulically or pneumatically powered rotor and stator driven drill as it drills a wellbore into the earth, the method comprising: (a) measuring a first set of rotor and stator operating parameters including the weight applied to the drill bit, the speed of rotation of the rotor and rotor torque for a first period of time, (b) generating a first set of relationships from the first set of operating parameters to enable the rotor speed and rotor torque to be predicted over a range of operating parameter values, (c) determining the rate of penetration for the first period of time from measurements of weight applied to the bit and rotation speed of the bit, (d) determining whether any other combination of weight applied to bit and rotation speed of bit, provided by the relationships determined in step (b) are capable of providing a greater rate of penetration, and (e) adjusting at least one operating parameter to move the weight applied to bit and/or speed of rotation of bit towards the combination which provides a first greater rate of penetration.

First claim

The invention claimed is:

1. A method of optimising the rate of penetration of drilling equipment comprising a drillstring extending within a wellbore from the surface to a downhole motor connected to a drill bit to extend the wellbore into the earth, wherein the motor comprises a hydraulically or pneumatically powered rotor and stator and is driven by through flow of drilling fluid pumped from the surface to the downhole motor through the drillstring, the method comprising:
(a) measuring a first set of rotor and stator operating parameters including the weight applied to the drill bit, fluid flow rate and pressure drop through the downhole motor, the speed of rotation of the rotor and rotor torque, while drilling for a first period of time,
(b) generating a first set of relationships from the first set of operating parameters to enable the rotor rotation speed and rotor torque to be predicted over a range of operating parameter values, these relationships comprising at least:
rotor torque as a function of pressure drop due to energy transfer to the rotor,
rotor rotation speed as a function of pressure drop due to energy transfer to the rotor and flow rate through the downhole motor, and
rotor torque as a function of weight applied to the drill bit,

(c) determining the rate of penetration for the first period of time from measurements of weight applied to the bit and rotation speed of the bit,
(d) determining whether any other combination of weight applied to bit and rotation speed of bit, provided by the relationships determined in step (b) are capable of providing a greater rate of penetration, and
(e) adjusting at least one operating parameter to move the weight applied to bit and/or speed of rotation of bit towards the combination which provides a first greater rate of penetration.

2. The method according to claim 1 , wherein the downhole motor is a positive or cavity displacement motor or a turbine.

3. The method according to claim 1 , wherein the measurement of the rotation speed of the motor is made downhole in the vicinity of the rotor.

4. The method according to claim 1 , wherein the torque produced by the rotor is measured downhole.

5. The method according to claim 1 , wherein the drilling equipment includes a drive at the surface and the drill string extends from the drive at the surface to the downhole motor, and wherein in step (e), the at least one operating parameter which is adjusted comprises at least one of rotation speed of the drill string and flow rate of drilling fluid through the downhole motor.

6. The method according to claim 1 , wherein, once at the first greater rate of penetration, the method of the invention is carried out again to measure a second set of rotor and stator operating parameters while drilling, generate a second set of relationships to determine a second greater rate of penetration, and to alter the operating parameters to move towards the second greater rate of penetration.

7. The method according to claim 6 , wherein the method is repeated again or as often as desired, until no further optimisation of the penetration of the rotor are found.

8. The method according to claim 1 , wherein following a period of drilling, the method is carried out again at a later period of time, resulting in a further set of measured operating parameters which are employed to generate a further set of relationships, which may indicate a new further greater rate of penetration, and the operating parameters can then be altered to move towards this new further greater rate of penetration.

9. The method according to claim 1 , wherein following a period of drilling, the method is carried out again at a later period of time, resulting in a further set of measured operating parameters which are employed to generate a further set of relationships, which are employed to monitor and diagnose problems arising during drilling.

10. The method according to claim 1 , wherein the method is carried out repeatedly whilst drilling, to provide a real-time determination of the hydraulic performance of the rotor and stator and to enable continuous adjustment and optimisation of rate of penetration to occur as drilling progresses.

11. The method according to claim 1 , wherein the set of operating parameters at step (a) include the density of drilling fluid, the bottom hole fluid pressure and pressure applied to the drilling fluid at the surface.

12. A system for optimising the rate of penetration of drilling equipment comprising a drillstring extending within a wellbore from the surface to a downhole motor connected to a drill bit to extend the wellbore into the earth, wherein the motor comprises a hydraulically or pneumatically powered rotor and stator and is driven by through flow of drilling fluid pumped from the surface to the downhole motor through the drillstring, the system comprising:
one or more sensors configured to measure a first set of rotor and stator operating parameters including the weight applied to the drill bit, fluid flow rate and pressure drop through the downhole motor, the speed of rotation of the rotor and rotor torque while drilling for a first period of time; and
a processor configured to:
generate a first set of relationships from the first set of operating parameters to enable the rotor rotation speed and rotor torque to be predicted over a range of operating parameter values, these relationships comprising at least:
rotor torque as a function of pressure drop due to energy transfer to the rotor,
rotor rotation speed as a function of pressure drop due to energy transfer to the rotor and flow rate through the downhole motor, and
rotor torque as a function of weight applied to the drill bit,

determine the rate of penetration for the first period of time from measurements of weight applied to the bit and rotation speed of the bit,
determine whether any other combination of weight applied to bit and rotation speed of bit, provided by the first set of relationships are capable of providing a greater rate of penetration, and
send a signal to adjust at least one operating parameter to move the weight applied to bit and/or speed of rotation of bit towards the combination which provides a first greater rate of penetration.

13. The system of claim 12 , wherein at least one of the one or more sensors comprise measurement while drilling sensors.

14. The system of claim 12 , wherein the processor is positioned at a downhole location.

15. The system of claim 12 , wherein the signal is communicated to the surface by wired drill pipe.

16. A method of optimising the rate of penetration of drilling equipment comprising a drillstring extending within a wellbore from the surface to a downhole motor connected to a drill bit to extend the wellbore into the earth, wherein the motor comprises a hydraulically or pneumatically powered rotor and stator and is driven by through flow of drilling fluid pumped from the surface to the downhole motor through the drill string and wherein density of drilling fluid and pressure applied at the surface are such that drilling is carried out with a bottom-hole pressure below that of the formation fluid pressure, the method comprising:
(a) measuring a first set of rotor and stator operating parameters including the weight applied to the drill bit, fluid flow rate and pressure drop through the downhole motor, density of drilling fluid, bottom hole fluid pressure, pressure applied to the drilling fluid at the surface, rotation speed of the rotor and rotor torque, while drilling for a first period of time,
(b) generating a first set of relationships f

Assignees

• Ringer Maurice
• Barrett Michael P
• Jeffryes Benjamin P
• Aldred Walter David
• Johnson Ashley
• Schlumberger Technology Corp

Inventors

• Ringer Maurice
• Barrett Michael P
• Jeffryes Benjamin P
• Aldred Walter David
• Johnson Ashley

Classifications

• H02K11/215

  Magnetic effect devices, e.g. Hall-effect or magneto-resistive elements · CPC title

• G01P3/487

  delivered by rotating magnets · CPC title

• E21B45/00

  Measuring the drilling time or rate of penetration · CPC title

• E21B4/02 Primary

  Fluid rotary type drives · CPC title

• E21B44/00

  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 title