BR-112023007266-B1 - METHOD FOR OPTIMIZING A MANEUVERING VELOCITY PROFILE FOR A PIPE AND SYSTEM FOR OPTIMIZING A MANEUVERING VELOCITY PROFILE FOR A PIPE STRING IN A WELLBORE

BR112023007266B1BR 112023007266 B1BR112023007266 B1BR 112023007266B1BR-112023007266-B1

Abstract

METHOD FOR OPTIMIZING A MANEUVERING VELOCITY PROFILE FOR A PIPE AND SYSTEM FOR OPTIMIZING A MANEUVERING VELOCITY PROFILE FOR A PIPE STRING IN A WELLBORE. The systems and methods of this disclosure relate to the optimization of a maneuvering velocity profile for pipes in a wellbore. A method for optimizing a maneuvering velocity profile for a pipe, comprising: determining a static gel strength of a wellbore fluid; determining an acceleration curve for the pipe in the wellbore based on the wellbore pressure constraints, wherein the wellbore pressure constraints are based in part on the static gel strength of the fluid; determining a deceleration curve for the pipe; and combining the acceleration curve with the deceleration curve to provide the maneuvering velocity profile for the pipe.

Inventors

DALE E. JAMISON
ROBERT L. WILLIAMS

Assignees

HALLIBURTON ENERGY SERVICES, INC

Dates

Publication Date: 20260310
Application Date: 20201230
Priority Date: 20201223

Claims (20)

1. A method for optimizing a maneuvering velocity profile for a pipe, characterized by comprising: - determining the static gel strength of a fluid in a wellbore; - determining an acceleration curve for the pipe in the wellbore based on the wellbore pressure constraints, wherein the wellbore pressure constraints are based in part on the static gel strength of the fluid; - determining a deceleration curve for the pipe; and - combining the acceleration curve with the deceleration curve to provide the maneuvering velocity profile for the pipe.
2. Method, according to claim 1, characterized in that the determination of the deceleration curve comprises inverting a cubic parabola, wherein the cubic parabola is a position function for the tube.
3. Method according to claim 1, characterized in that it further comprises moving the pipe in the wellbore based on the maneuvering velocity profile and the wellbore pressure constraints.
4. Method according to claim 1, characterized in that it further comprises determining mechanical jolts based on the acceleration curve or the deceleration curve.
5. Method, according to claim 1, characterized in that it further comprises determining the acceleration curve for the pipe that causes the equivalent circulating densities (ECD) in the wellbore to be less than a formation fracture pressure and greater than a pore pressure.
6. Method according to claim 1, characterized in that the tube is enclosed in a support.
7. Method according to claim 1, characterized in that it further comprises determining the resistance of the static gel during a connection of the tube to another tube.
8. Method according to claim 1, characterized in that it further comprises determining the resistance of the static gel during a disconnection of another tube from the tube.
9. Method for optimizing a maneuvering velocity profile for a pipe, characterized by comprising: - determining a static gel strength of a wellbore fluid; - determining an acceleration curve for the pipe in the wellbore that maintains equivalent circulation densities (ECDs) in the wellbore that are less than a formation fracture pressure and greater than a pore pressure, wherein the ECDs are based in part on the static gel strength of the fluid; - determining a deceleration curve for the pipe by inverting a cubic parabola; and - combining the acceleration curve with the deceleration curve to provide the maneuvering velocity profile for the pipe.
10. Method according to claim 9, characterized in that it further comprises moving the pipe in the wellbore based on the maneuvering velocity profile.
11. Method according to claim 9, characterized in that it further comprises determining mechanical jolt based on the acceleration curve or the deceleration curve.
12. Method according to claim 9, characterized in that the tube is enclosed in a support.
13. Method according to claim 9, characterized in that it further comprises determining the static resistance of the gel during a connection of the tube to another tube.
14. Method according to claim 9, characterized in that it further comprises determining the static resistance of the gel during a disconnection of another tube from the tube.
15. Method according to claim 9, characterized in that inverting the cubic parabola comprises inverting a position function for the tube.
16. System for optimizing a maneuvering velocity profile for a tubing string in a wellbore, characterized in that it comprises: - the tubing string disposed in the wellbore, the wellbore comprising a fluid; - a gel resistance analyzer in fluid communication with the fluid; - a system controller in communication with the gel resistance analyzer, the system controller configured to: - receive static gel resistance information of the fluid from the gel resistance analyzer; - determine an acceleration curve for the tubing string in the wellbore based on the wellbore pressure constraints, wherein the wellbore pressure constraints are based in part on the static gel resistance of the fluid; - determine a deceleration curve for the tubing string; and - combine the acceleration curve with the deceleration curve to provide the maneuvering velocity profile for the tubing string.
17. System according to claim 16, characterized in that the system controller is further configured to move the pipe string in the wellbore based on the maneuvering speed profile.
18. System according to claim 16, characterized in that the system controller is further configured to determine the mechanical jolt based on the acceleration curve or the deceleration curve.
19. System according to claim 16, characterized in that the system controller is further configured to receive static gel resistance information during a connection of a tube to the tube string or during a disconnection of the tube from the tube string.
20. System according to claim 16, characterized in that the gel resistance analyzer is in fluid communication with a mud well that is positioned on a wellbore surface.

Description

Fundamentals [0001] During well drilling operations, pipe may be inserted into a wellbore (“entry maneuver”) or pulled out of the wellbore (“exit maneuver”) for various purposes, such as changing a drill bit or other downhole tool or setting up a conduit such as casing or a liner in the wellbore. [0002] The maneuver may be limited by speed due to changes in hydrostatic fluid pressure in the wellbore. Fluid displacement due to pipe displacement combined with viscous effects of the drilling fluid (“mud”) in the wellbore can cause fluctuations in the hydrostatic pressure of the drilling fluid. [0003] For example, if hydrostatic pressure is increased due to excessive velocity, a fracture pressure of one or more exposed formations in an uncased portion of the wellbore may be exceeded (“surge”). Conversely, a decrease in hydrostatic pressure caused by excessive velocity may result in a reduction of hydrostatic pressure below a formation fluid or pore pressure of exposed formations (“piston sway”). Furthermore, pipe maneuvering may also be restricted due to mechanical jolt of the pipe as it is accelerated or decelerated through the wellbore; if jolt limits are exceeded for certain components of the pipe string, damage may occur. Consequently, various problems may arise during pipe maneuvering. Brief Description of the Drawings [0004] These drawings illustrate certain aspects of some examples in this disclosure and should not be used to limit or define the disclosure. [0005] Figure 1 is a graph illustrating the kinematic curves for the movement of the pipe during maneuvering operations, according to the examples in this disclosure; [0006] Figure 2 illustrates a cubic parabola representing a position for a tube, according to examples in this disclosure; [0007] Figure 3 illustrates a graph representing acceleration and deceleration times for the tube, according to examples in this disclosure; [0008] Figure 4 illustrates a graph representing acceleration and mechanical jolt curves for the tube, according to examples from this disclosure; [0009] Figure 5 illustrates discrete sources of pressure during maneuvering operations, according to examples in this disclosure; [0010] Figure 6 illustrates pressure responses and limits at a single point in a wellbore, according to examples in this disclosure; [0011] Figure 7 illustrates an exemplary workflow for optimizing maneuvering speed profiles, according to examples in this disclosure; [0012] Figure 8 illustrates a graph representing ECDs versus acceleration times, according to examples from this disclosure; and [0013] Figure 9 illustrates a system for using the maximum speed curve to optimize a maneuvering operation, according to examples in this disclosure. Detailed Description [0014] This disclosure generally relates to techniques for determining an ideal travel or running speed for tubulars or downhole pipes, such as drill strings and/or casing strings. In particular examples, the techniques described herein may consider or account for a gelation and breakdown rate of drilling fluid; maximum and minimum equivalent static density (ESD), such as surge and piston pressures; fluid momentum; and/or mechanical jolt. The disclosed techniques may use gel breakdown information that can distinguish how much of a gel is stiff and how much is brittle, as well as how the gel structure decays with shear and time for each. [0015] In order to optimize and automate the pipe maneuvering process, the techniques described here can be used with real-time rheology monitoring, hydraulics and/or graphical software and/or drilling fluid hardware. The physical phenomena of gel impact, fluid inertia and hydraulics for peak and minimum maneuvering pressures can be simulated using mathematical functions. In some examples, a cubic parabola with derivatives that are continuous through the 3rd derivative can be used as shown by Equations 1 to 4: x(t) = kt3 (1)V(t) = 3kt2 (2)α(t) = 6kt (3)J(t) = 6k (4)where x(t) is a pipe position during the maneuver; t is time; k is a constant; V(t) is the velocity and the first derivative of Equation 1; a(t) is the acceleration and the second derivative of Equation 1; and J(t) is the mechanical jolt and the third derivative of Equation 1. [0016] Figure 1 is a graph illustrating 100 curves corresponding to Equations 1 to 4 during maneuvering operations, according to examples in this disclosure. In some examples, a pipe acceleration in a wellbore can be provided by real-time rheology monitoring, hydraulics, drilling simulation, and/or drilling fluid graphics software and/or hardware. In particular examples in this disclosure, the cubic parabola, X(t), can be inverted to provide a maximum maneuvering velocity profile. As noted earlier, Equations 1 to 4 illustrate a cubic parabola including its derivatives. The derivatives can be continuous through the 3rd derivative. [0017] Figure 2 illustrates the cubic parabola, X(t), flipped or inverted to form a cubic parabola 200, ac