Elastic pipe control with managed pressure drilling

• US 10,184,305 B2
• Filed: 05/07/2014
• Issued: 01/22/2019
• Est. Priority Date: 05/07/2014
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Lovorn, James Randolph, Samuel, Robello, Bakri Yassin Ibrahim, Emad
• Primary Examiner(s): Thompson, Kenneth L
• Application Number:
  US15/116,328
• Publication Number:
  US 20170009543A1
• Time in Patent Office: 1,721 Days
• CPC Class Codes: E21B 21/08 Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure valve arrangements therefor E21B21/10
• 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 49/003 by analysing drilling variables or conditions E21B49/005 takes precedence; systems specially adapted for monitoring a plurality of drilling variables or conditions E21B44/00
• CPC Class Codes: E21B 49/08 Obtaining fluid samples or testing fluids, in boreholes or wells
• CPC Class Codes: E21B 49/0875 determining specific fluid parameters
• CPC Class Codes: G01N 11/00 Investigating flow properties of materials, e.g. viscosity, plasticity; Analysing materials by determining flow properties
• CPC Class Codes: G01N 9/00 Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity
• CPC Class Codes: G06F 17/11 for solving equations , e.g. nonlinear equations, general mathematical optimization problems optimization specially adapted for a specific administrative, business or logistic context G06Q10/04
• CPC Class Codes: G06F 30/20 Design optimisation, verification or simulation optimisation, verification or simulation of circuit designs G06F30/30

Abstract

Disclosed embodiments include systems and methods for improving the accuracy of bottom hole pressure control. One example embodiment includes a torque and drag model that calculates the elasticity of the drill string, which is included in a managed pressure drilling control system. The addition of the torque and drag calculations provide more accurate surge/swab effect calculations based on pipe movement corrected for elasticity effects. The results of these calculations will be used in a real-time hydraulics model to determine a setpoint pressure which will be utilized by a MPD choke system. Further, the real-time torque and drag models are calibrated to actual hole conditions in real-time using survey, temperature, pressure and downhole tool data to calculate friction factors in a wellbore.

Claims

1. A method comprising:

obtaining at least one fluid property of an input fluid to a well and of a return fluid from the well;

calculating an elasticity parameter of a drill string within the well based at least in part on the at least one fluid property;

calculating a wellhead setpoint pressure that results in a predetermined downhole pressure at a predetermined location in the well, the calculation based at least in part on the elasticity parameter and the at least one fluid property; and

controllably regulating the flow of the return fluid to maintain the calculated wellhead setpoint pressure.

2. The method of claim 1, wherein the at least one fluid property comprises at least one of:

fluid density, oil/water ratio, chlorides content, electric stability, shear stress of the fluid, gel strength, plastic viscosity, yield point, and combinations thereof.

3. The method of claim 1, wherein calculating the elasticity parameter further comprises using a torque and drag model to calculate the elasticity of the drill string.

4. The method of claim 3, further comprising calibrating the torque and drag model to conditions within the well.

5. The method of claim 1, further comprising calculating at least one friction factor present within the well.

6. The method of claim 1, wherein obtaining at least one fluid property comprises withdrawing a sample of the input fluid and the return fluid and regulating a temperature and a pressure of each sample to a predetermined temperature and a predetermined pressure before obtaining the at least one fluid property.

7. The method of claim 1, wherein the predetermined downhole pressure is in a range that is less than a fracture pressure and greater than, or equal to, a pore pressure of a formation surrounding the well.

8. The method of claim 1, wherein the predetermined downhole pressure is less than a pore pressure of a formation surrounding the well.

9. A method for controlling a downhole pressure during drilling comprising:

periodically sensing in real-time at least one fluid property of an input fluid into a well and of a return fluid from the well;

inputting the at least one fluid property into of a drilling control system;

calculating in real-time, using the drilling control system, a wellhead setpoint pressure that results in a predetermined downhole pressure at a predetermined location in the well, the calculation based at least in part on the at least one fluid property and an elasticity model of the well incorporating the at least one fluid property; and

controllably regulating the flow of the return fluid to maintain the calculated wellhead setpoint pressure.

10. The method of claim 9, wherein the drilling control system includes a hydraulics model incorporating the at least one fluid property.

11. The method of claim 9, wherein the at least one fluid property comprises at least one of:

fluid density, oil/water ratio, chlorides content, electric stability, shear stress of the fluid, gel strength, plastic viscosity, yield point, and combinations thereof.

12. The method of claim 9, wherein continuously sensing the at least one fluid property comprises withdrawing a sample of the input fluid and the return fluid and regulating a temperature and a pressure of each sample to a predetermined temperature and a predetermined pressure before obtaining the at least one fluid property.

13. The method of claim 9, wherein the predetermined downhole pressure is in a range that is less than a fracture pressure and greater than, or equal to, a pore pressure of a formation surrounding the well.

14. The method of claim 9, wherein the predetermined downhole pressure is less than a pore pressure of a formation surrounding the well.

15. A drilling system for managed pressure drilling, comprising:

at least one sensor configured to continually sense at least one fluid property of an input fluid to a well and a return fluid from the well;

a controllably adjustable flow control apparatus disposed in a return flow line to regulate a flow of the return fluid; and

a controller operably connected to the controllably adjustable flow control apparatus to instruct the controllably adjustable flow apparatus to regulate the flow of the return fluid to maintain a wellhead setpoint pressured based at least in part on an elasticity model of the well incorporating the at least one fluid property.

16. The drilling system of claim 15, wherein the controller comprises a processor in data communication with a memory, the memory containing programmed instruction that when executed calculates a surface wellhead setpoint pressure that results in a desired downhole pressure at a predetermined location, where the calculated wellhead setpoint pressure is based at least in part on the sensed fluid property.

17. The drilling system of claim 15 wherein the programmed instructions further comprise a hydraulics model of the well.

18. The drilling system of claim 15, wherein the controller acts autonomously to adjust the controllably adjustable flow control apparatus to regulate the flow of the return fluid to maintain the calculated wellhead setpoint pressure.

19. The drilling system of claim 15, wherein the at least one sensor comprises at least one first sensor in hydraulic communication with the input fluid and at least one second sensor in hydraulic communication with the return fluid.

20. The drilling system of claim 15, wherein the at least one sensor further comprises at least one first sensor positioned in the well configured to measure a downhole condition.