Wellbore tripping advisor
A method for determining a maximum tripping velocity for tripping a downhole tool string in a wellbore includes obtaining contextual data including wellbore data, tool string data, and drilling fluid data; computing downhole drilling fluid pressures at multiple tool string velocities and accelerations using the obtained contextual data and a wellbore hydraulics model; generating an equivalent circulation density (ECD) contour along a two-dimensional acceleration and velocity parameter space from the computed downhole drilling fluid pressures; and evaluating the ECD contour with at least one of a formation pore pressure or a formation fracture pressure to generate the maximum tripping velocity.
1 . A method for determining a maximum tripping velocity for tripping a downhole tool string in a wellbore, the method comprising:
obtaining contextual data including wellbore data, tool string data, and drilling fluid data;
computing downhole drilling fluid pressures at multiple tool string velocities and accelerations using the obtained contextual data and a wellbore hydraulics model;
generating an equivalent circulation density (ECD) contour along a two-dimensional acceleration and velocity parameter space from the computed downhole drilling fluid pressures; and
evaluating the ECD contour with a formation fracture pressure to generate the maximum tripping velocity, wherein the evaluating the ECD contour further comprises:
obtaining the formation fracture pressure;
applying a safety buffer to the obtained formation fracture pressure to obtain upper and lower fracture pressures;
determining upper and lower fracture pressure contours;
determining a maximum tripping in velocity and a minimum tripping in velocity from the upper and lower fracture pressure contours; and
tripping the tool string in the wellbore at a velocity based on the determined maximum tripping in velocity.
2 . The method of claim 1 , wherein
the wellbore data comprises a wellbore diameter;
the tool string data comprises a tool string diameter and a tool string depth;
the drilling fluid data includes a drilling fluid viscosity, a drilling fluid density, and a drilling fluid gel strength.
3 . The method of claim 1 , wherein the ECD contour comprises a surge contour and a swab contour.
4 . The method of claim 1 , wherein the two-dimensional acceleration and velocity parameter space comprises a two dimensional parameterized acceleration length and steady state tripping velocity that are based on a trip acceleration profile including an initial acceleration interval, a steady state velocity interval, and a deceleration interval.
5 . The method of claim 1 , wherein the evaluating the ECD contour further comprises generating a maximum tripping acceleration.
6 . The method of claim 1 , wherein the evaluating the ECD contour further comprises:
obtaining a formation pore pressure;
applying an additional safety buffer to the obtained formation pore pressure to obtain upper and lower pore pressures;
determining upper and lower pore pressure contours; and
determining a minimum tripping out velocity and a maximum tripping out velocity from the upper and lower pore pressure contours.
7 . The method of claim 1 , further comprising displaying the maximum tripping velocity on a trip advisor board.
8 . A system for tripping a tool string in a wellbore; the system comprising:
a tool string deployed in a wellbore;
a processor configured to:
receive contextual data including wellbore data, tool string data, and drilling fluid data;
compute downhole drilling fluid pressures at multiple tool string velocities and accelerations using the received contextual data and a wellbore hydraulics model;
generate an equivalent circulation density (ECD) contour along a two-dimensional acceleration and velocity parameter space from the computed downhole drilling fluid pressures; and
evaluate the ECD contour with a formation fracture pressure to generate a maximum velocity for tripping the tool string, wherein the evaluate the ECD contour further comprises:
obtain the formation fracture pressure;
apply a safety buffer to the obtained formation fracture pressure to obtain upper and lower fracture pressures;
determine upper and lower fracture pressure contours; and
determine a maximum tripping in velocity and a minimum tripping in velocity from the upper and lower fracture pressure contours; and
a trip advisor board display configured to display the maximum tripping velocity; wherein
the system trips the tool string in the wellbore at a velocity based on the determined maximum tripping in velocity.
9 . The system of claim 8 , wherein the two-dimensional acceleration and velocity parameter space comprises a two dimensional parameterized acceleration length and steady state tripping velocity that are based on a trip acceleration profile including an initial acceleration interval, a steady state velocity interval, and deceleration interval.
10 . The system of claim 8 , wherein the evaluate the ECD contour further comprises generate a maximum tripping acceleration.
11 . The system of claim 8 , wherein the evaluate the ECD contour further comprises:
obtain a formation pore pressure;
apply an additional safety buffer to the obtained formation pore pressure to obtain upper and lower pore pressures;
determine upper and lower pore pressure contours; and
determine a minimum tripping out velocity and a maximum tripping out velocity from the upper and lower pore pressure contours.
12 . A method for tripping a tool string in a wellbore, the method comprising:
obtaining contextual data including wellbore data, tool string data, and drilling fluid data;
computing downhole drilling fluid pressures at multiple tool string velocities and accelerations using the obtained contextual data and a wellbore hydraulics model;
generating an equivalent circulation density (ECD) contour along a two-dimensional acceleration and velocity parameter space from the computed downhole drilling fluid pressures;
evaluating the ECD contour with a formation fracture pressure to generate a maximum tripping velocity and a minimum tripping velocity, wherein the evaluating the ECD contour further comprises:
obtaining the formation fracture pressure;
applying a safety buffer to the obtained formation fracture pressure to obtain upper and lower fracture pressures;
determining upper and lower fracture pressure contours; and
determining a maximum tripping in velocity and a minimum tripping in velocity from the upper and lower fracture pressure contours; and
tripping the tool string in the wellbore at a velocity between the determined minimum tripping in velocity and the determined maximum tripping in velocity.
13 . The method of claim 12 , wherein the two-dimensional acceleration and velocity parameter space comprises a two dimensional parameterized acceleration length and steady state tripping velocity that are based on a trip acceleration profile including an initial acceleration interval, a steady state velocity interval, and deceleration interval.
14 . The method of claim 12 , wherein:
the evaluating the ECD contour further comprises generating a maximum tripping acceleration; and
the tripping further comprises tripping the tool string in the wellbore at an acceleration that is less than the maximum tripping acceleration.
15 . The method of claim 12 , wherein the evaluating the ECD contour further comprises:
obtaining a formation pore pressure;
applying an additional safety buffer to the obtained formation pore pressure to obtain upper and lower pore pressures;
determining upper and lower pore pressure contours; and
determining a minimum tripping out velocity and a maximum tripping out velocity from the upper and lower pore pressure contours.