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Petroleum Wells-Drilling/Production/Construction

Modeling and Analysis of Drillstring Vibration in Riserless Environment

[+] Author and Article Information
Robello Samuel

Halliburton Technology Fellow
Drilling Engineering,
Halliburton,
Houston, TX 77042
e-mail: Robello.samuel@halliburton.com

Contributed by the Petroleum Division of ASME for publication in the Journal of Energy Resources Technology. Manuscript received July 20, 2012; final manuscript received August 22, 2012; published online November 15, 2012. Editor: Hameed Metghalchi.

J. Energy Resour. Technol 135(1), 013101 (Nov 15, 2012) (11 pages) Paper No: JERT-12-1166; doi: 10.1115/1.4007691 History: Received July 20, 2012; Revised August 22, 2012

Riserless drilling poses numerous operational challenges that adversely affect the efficiency of the drilling process. These challenges include increased torque and drag, buckling, increased vibration, poor hole cleaning, tubular failures, poor cement jobs, and associated problems during tripping operations. These challenges are closely associated with complex bottomhole assemblies (BHAs) and the vibration of the drillstring when the topholes are drilled directionally. Current methods lack proper modeling to predict drillstring vibration. This paper presents and validates a modified model to predict severe damaging vibrations, analysis techniques, and guidelines to avoid the vibration damage to BHAs and their associated downhole tools in the riserless highly deviated wells. The dynamic analysis model is based on forced frequency response (FFR) to solve for resonant frequencies. In addition, a mathematical formulation includes viscous, axial, torsional, and structural damping mechanisms. With careful consideration of input parameters and judicious analysis of the results, the author demonstrates that drillstring vibration can be avoided by determining the 3D vibrational response at selected excitations that are likely to cause them. The analysis also provides an estimate of relative bending stresses, shear forces, and lateral displacements for the assembly used. Based on the study, severe vibrations causing potentially damaging operating conditions were avoided, which posed a major problem in the nearby wells. The study indicates that the results are influenced by various parameters, including depth of the mud line, offset of the wellhead from the rig center, wellbore inclination, curvature, wellbore torsion, and angle of entry into the wellhead. This study compares simulated predictions with actual well data and describes the applicability of the model. Simple guidelines are provided to estimate the operating range of the drilling parameter to mitigate and avoid downhole tool failures.

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References

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Figures

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Fig. 1

Node force balance

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Fig. 2

Various excitation boundary conditions at bit

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Fig. 3

Well schematic (Well 1)

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Fig. 4

Well dogleg and wellbore torsion

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Fig. 5

Dogleg and well profile energy

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Fig. 6

Rotational speed versus stresses

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Fig. 7

Rotational speed versus vibration intensity values

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Fig. 8

Strain energy versus depth

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Fig. 9

Strain energy for various positions of stabilizers

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Fig. 10

Dogleg and wellbore torsion

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Fig. 11

Dogleg and well profile energy

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Fig. 12

Strain energy at various depths

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Fig. 13

Strain energy and well profile energy for various depths

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