Method of automatically controlling the trajectory of a drilled well

• US 8,676,558 B2
• Filed: 05/05/2011
• Issued: 03/18/2014
• Est. Priority Date: 06/29/2007
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Pirovolou, Dimitros K.
• Primary Examiner(s): Craig, Dwin M
• Application Number:
  US13/101,823
• Publication Number:
  US 20110213601A1
• Time in Patent Office: 1,048 Days
• Field of Search: 703/10, 702/9
• US Class Current: 703/10
• CPC Class Codes: E21B 2200/20 Computer models or simulations, e.g. for reservoirs under production, drill bits
• CPC Class Codes: E21B 7/04 Directional drilling

Abstract

Steering behavior model can include build rate and/or turn rate equations to model bottom-hole assembly behavior. Build and/or turn rate equations can be calibrated by adjusting model parameters thereof to minimize any variance between actual response 118 and estimated response produced for an interval of the well. Estimated position and orientation 104 of a bottom-hole assembly along a subsequent interval can be generated by inputting subsequent tool settings into the calibrated steering behavior model. Estimated position and orientation 104 can be compared to a well plan 106 with a controller 108 which determines a corrective action 110. Corrective action 110 can be converted from a build and/or turn rate to a set of recommended tool settings 114 by using an inverse application 112 of the steering behavior model. As additional data 118 becomes available, steering behavior model can be further calibrated 102 through iteration.

Claims

1. A method of controlling the trajectory of a drill string comprising:

providing a steering behavior model of a bottom hole assembly in a borehole, the model having at least a build rate equation relating the build rate to tool settings or a turn rate equation relating the turn rate to tool settings;

determining a first estimated position of the bottom hole assembly by inputting a first tool setting into the steering behavior model;

comparing the first estimated position with a pre-existing well plan to obtain a variance; and

utilizing a mathematical inverse of the steering behavior model to generate a second tool setting, the second tool setting being selected so as to correct the variance between the first estimated position and the pre-existing well plan.

2. The method of claim 1 further comprising calibrating the steering behavior model by minimizing any variance between an actual build rate and an actual turn rate of the bottom hole assembly generated by the first tool setting and a first estimated build rate and turn rate.

3. The method of claim 2 further comprising comparing the first estimated position to a well plan to determine any deviation of the bottom-hole assembly from the well plan.

4. The method of claim 3 wherein the second estimated position is closer to the well plan the first estimated position.

5. The method of claim 1 further comprising calibrating the steering behavior model by minimizing any variance between the actual build rate or the actual turn rate of the bottom hole assembly generated by the first tool setting and the first estimated build rate or the first estimated turn rate generated by inputting the first tool setting into the steering behavior model.

6. The method of claim 1 further comprising automatically generating a signal to a control means of the drill string to accomplish the second tool setting.

7. A method of controlling the trajectory of a drill string in a wellbore, the method comprising:

providing a steering behavior model having a build rate equation relating the build rate to tool settings or a turn rate equation relating the turn rate to tool settings;

calibrating the steering behavior model by minimizing any variance between an actual build rate or an actual turn rate of the drill string generated by a first tool setting and a first estimated build rate or a first estimated turn rate generated by inputting the first tool setting into the steering behavior model; and

determining a second estimated build rate or a second estimated turn rate by inputting a second tool setting into the steering behavior model;

comparing the second estimated position with a pre-existing well plan to obtain a deviation of the drill string therefrom; and

utilizing a mathematical inverse of the steering behavior model to calculate tool settings necessary to correct the deviation at the second estimated position, said calculations beginning at a previous point in the wellbore.

8. The method of claim 7 further comprising automatically transmitting the recommended tool setting to a component in the drill string.

9. The method of claim 7 wherein the calibrating step further comprises adjusting a model parameter of at least one of the build rate equation and the turn rate equation to minimize the any variance.

10. The method of claim 7 wherein the tool setting is selected from the group consisting of weight on bit, mud flow rate, rotational speed of the drill string, rotational speed of a drill bit, toolface angle, steering ratio, and drilling cycle.

11. A method of controlling the trajectory of a drill string in a wellbore, the method comprising:

providing a steering behavior model having a build rate equation relating the build rate to tool settings and a turn rate equation relating the turn rate to tool settings of a bottom-hole assembly;

providing an actual azimuth and inclination at a first interval of drilling;

determining an actual build rate and an actual turn rate at the first interval;

calibrating the steering behavior model by minimizing any variance between the actual build rate and the actual turn rate and a first estimated build rate generated by inputting a first set of tool settings into the steering behavior model; and

determining a second estimated build rate and a second estimated turn rate with the calibrated steering behavior model for a subsequent second interval drilled with a subsequent second set of tool settings;

computing mathematical integrals of the build rate equation and the turn rate equation over the subsequent second interval to obtain corresponding inclination and azimuth equations from which a second estimated inclination and azimuth for the second interval are obtained;

computing mathematical integrals of the inclination and azimuth equations over the second interval to produce an estimated position of the bottom-hole assembly;

comparing the second estimated position with a pre-existing well plan to obtain a deviation of the drill string therefrom; and

utilizing an inverse of the steering behavior model to calculate tool settings necessary to correct the deviation at the second estimated position, said calculations beginning at a previous point in the wellbore.

12. The method of claim 11 further comprising:

providing an actual azimuth and inclination data set for the second interval drilled with the second set of tool settings; and

further calibrating the steering behavior model by minimizing any variance between the actual build rates and turn rates of the first and subsequent second intervals and the first and second estimated build rates and the estimated turn rates generated by inputting the first and second sets of tool settings into the calibrated steering behavior model.

13. The method of claim 11 wherein the build rate equation and the turn rate equations comprise at least one of drilling parameters, drilling tool settings, position and orientation of the drill string, properties of the formation, geometry of the bottom-hole assembly, and model parameters.

14. The method of claim 11 wherein the at least one of the build rate equation and the turn rate equation has a model parameter and further wherein the calibrating step further comprises adjusting the model parameter of at least one of the build rate equation and the turn rate equation to minimize the any variance.