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Research Papers: Petroleum Engineering

An Analysis of Common Drill Stem Vibration Models

[+] Author and Article Information
Mohammed F. Al Dushaishi

School of Engineering,
Texas A&M International University,
Laredo, TX 78045
e-mail: aldushaishi@gmail.com

Runar Nygaard

School of Chemical Engineering,
Oklahoma State University,
Stillwater, OK 74078
e-mail: runar.nygaard@okstate.edu

Daniel S. Stutts

Department of Mechanical
and Aerospace Engineering,
Missouri University of Science and Technology,
Rolla, MO 65409
e-mail: stutts@mst.edu

1Corresponding author.

Contributed by the Petroleum Division of ASME for publication in the JOURNAL OF ENERGY RESOURCES TECHNOLOGY. Manuscript received December 6, 2016; final manuscript received August 14, 2017; published online September 12, 2017. Assoc. Editor: Arash Dahi Taleghani.

J. Energy Resour. Technol 140(1), 012905 (Sep 12, 2017) (12 pages) Paper No: JERT-16-1493; doi: 10.1115/1.4037682 History: Received December 06, 2016; Revised August 14, 2017

Excessive drill stem (DS) vibration while rotary drilling of oil and gas wells causes damages to drill bits and bottom hole assemblies (BHAs). In an attempt to mitigate DS vibrations, theoretical modeling of DS dynamics is used to predict severe vibration conditions. To construct the model, decisions have to be made on which beam theory to be used, how to implement forces acting on the DS, and the geometry of the DS. The objective of this paper is to emphasize the effect of these assumptions on DS vibration behavior under different, yet realistic, drilling conditions. The nonlinear equations of motion were obtained using Hamilton's principle and discretized using the finite element method. The finite element formulations were verified with uncoupled analytical models. A parametric study showed that increasing the weight on bit (WOB) and the drill pipe (DP) length clearly decreases the DS frequencies. However, extending the drill collar length does not reveal a clear trend in the resulting lateral vibration frequency behavior. At normal operating conditions with a low operating rotational speed, less than 80 RPM, the nonlinear Euler–Bernoulli and Timoshenko models give comparable results. At higher rotational speeds, the models deliver different outcomes. Considering only the BHA overestimates the DS critical operating speed; thus, the entire DS has to be considered to determine the critical RPM values to be avoided.

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Figures

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Fig. 1

Drilling assembly showing the DS (Lds) that consists of DPs (Ldp) and BHA, including drill collars (Ldc) and stabilizers, on the left and the modeling configuration on the right

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Fig. 2

Configuration of axis orientation (a) rotation around the x-axis, (b) rotation around the yx-axis, and (c) rotation around the zxy-axis

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Fig. 3

Free vibration frequencies obtained from finite element and analytical models (a) axial, (b) torsional, and (c) lateral

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Fig. 4

First and tenth lateral natural frequencies under varying axial load for Euler–Bernoulli (EBT) and Timoshenko (TBT) models

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Fig. 5

Effect of changing WOB, length of DS (Lds), length of drill collar (Ldc), and fluid density (MW) on the DS (a) lateral, (b) torsional, and (c) axial frequencies

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Fig. 6

Percentage difference of lateral frequency between the Euler–Bernoulli (EBT) and the Timoshenko (TBT) models under varying drilling conditions for (a) first mode results and (b) tenth mode results

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Fig. 7

Drill stem first axial, torsional, and lateral natural frequencies when considering only the BHA, the DS consisting of DP only, and the entire DS

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