[1] Two parallel experiments involving the evolution and runup of plunging solitary waves on a sloping bed were conducted: (1) a rigid-bed experiment, allowing direct (hot film) measurements of bed shear stresses and (2) a sediment-bed experiment, allowing for the measurement of pore water pressures and for observation of the morphological changes. The two experimental conditions were kept as similar as possible. The experiments showed that the complete sequence of the plunging solitary wave involves the following processes: shoaling and wave breaking; runup; rundown and hydraulic jump; and trailing wave. The bed shear stress measurements showed that the mean bed shear stress increases tremendously (with respect to that in the approaching wave boundary layer), by as much as a factor of 8, in the runup and rundown stages, and that the RMS value of the fluctuating component of the bed shear stress is also affected, by as much as a factor of 2, in the runup and hydraulic jump stages. The pore water pressure measurements showed that the sediment at (or near) the surface of the bed experiences upward directed pressure gradient forces during the down-rush phase. The magnitude of this force can reach values as much as approximately 30% of the submerged weight of the sediment. The experiments further showed that the sediment transport occurs in the sheet flow regime for a substantial portion of the beach covering the area where the entire sequence of the wave breaking takes place. The bed morphology is explained qualitatively in terms of the measured bed shear stress and the pressure gradient forces.
Crack-like defects may occur coincident with corrosion defects and represent a new hybrid form of defect in gas and oil pipelines that is not directly addressed in the current codes or methods of assessment. There is a need to provide assessment and evaluate the integrity of the line as well as identify requirements for defect repair or line hydrotest. A numerical investigation was undertaken to evaluate the predicted collapse pressure of crack in corrosion (CIC) defects in typical line pipe. Longitudinally oriented CIC defects were evaluated as long cracks occurring within long, corrosion grooves of uniform depth. This was a conservative representation of a finite length CIC defect. It was found that the collapse pressure for CIC defects varied between that of a long uniform depth crack and a long uniform depth corrosion defect. The transition to corrosion defect behaviour only occurred when the corrosion defect depth was significant (greater than 75% of the total defect depth). Finite-length CIC defects were then investigated using a numerical investigation to identify the effect of crack and corrosion length. The collapse pressure of a finite length crack within an infinitely long corrosion defect was found to be lower than a crack of equivalent total depth and length. This reduction in collapse pressure was attributed to increased local stresses in the vicinity of the crack due to the coincident corrosion. The predicted collapse pressure increased towards the crack-only value when the length of the corrosion defect was decreased to that of the crack. CIC defects were evaluated as cracks using the NG-18 approach and BS 7910 code (Level 2A FAD). The NG-18 approach conservatively predicted lower collapse pressures than the FE analysis, whereas the FAD approach was conservative for shallow defects and could be non-conservative for deeper defects. These results are attributed to the presence of the corrosion and the fact that no factor of safety was included in the analysis. Future studies will investigate experimental validation of the FE and FAD methods for this type of defect.
Wide plate testing has been traditionally applied to evaluate the tensile strain capacity (TSC) of pipelines with girth weld flaws. These wide plate tests cannot incorporate the effect of internal pressure, however, numerical analysis in recent studies showed that the TSC is affected by the level of internal pressure inside the pipeline (Wang et al. 2007, "Strain Based Design of High Strength Pipelines," 17th International Offshore and Polar Engineering Conference (ISOPE), Lisbon, Portugal, Vol. 4, pp. 3186–3193). Moreover, most of the past studies focused on the effect of circumferential flaws on the TSC for pipelines of steel grade X65 or higher. The current Oil and Gas Pipeline System Code CSA Z662-11 provides equations to predict the TSC as a function of geometry and material properties of the pipelines. These equations were based on extensive studies on pipes having grades X65 or higher without considering the effect of internal pressure. This paper investigates the TSC for pipelines obtained using an experimental technique considering the effect of internal pressure and flaw size. Eight full-scale tests of X52 NPS 12 in. pipes with 6.91 mm wall thickness were conducted in order to investigate the effect of circumferential flaws close to a girth weld on the TSC for vintage pipelines subjected to eccentric tensile forces and internal pressure. The tensile strains along the pipe length and on the outer circumference of the pipe were measured using biaxial strain gauges and a digital image correlation (DIC) system. Postfailure macrofractography analysis was used to confirm the original size of the machined flaw and to identify areas of plastic deformation and brittle/ductile fracture surfaces. From the experimental and numerical results, the effect of internal pressure and flaw size on the TSC and the crack mouth opening displacement (CMOD) at failure were investigated and presented.
A numerical modeling procedure was developed, using the finite-element simulator ABAQUS/Standard, to predict the local buckling and post-buckling response of high strength pipelines subject to combined state of loading. The numerical procedures were calibrated using test data from large-scale experiments examining the local buckling of high strength linepipe. The numerical model’s response was consistent with the measured experimental response for predicting the local buckling behavior well into the post-yield range. A parametric study was conducted that examined element selection, mesh topology, second-order effects, geometric imperfections and material properties. The results from this study are presented.
Using the finite element methods, a parametric study was conducted to examine the influence of pipeline diameter, internal pressure, girth weld offset misalignment amplitude and modeled length on the local buckling of high strength pipelines. The numerical procedures were calibrated from full-scale tests on high strength pipelines subject to internal pressure and end rotation. The peak moment decreased with increasing pressure and girth weld offset misalignment amplitude. The limit curvature increased with increasing pressure and decreased with increasing girth weld offset misalignment amplitude. The effect of reducing the modeled pipeline segment length, from 5.5 D to 3.5 D, was to increase the limit curvature at the peak moment and to delay the onset of nonlinear ovalization response to higher curvature amplitudes. The influence of girth weld offset misalignment on the local buckling response was examined in terms of a strain capacity reduction parameter known as the girth weld factor. This study has determined current practice, based on DNV OS-F101 standard, was appropriate; moreover, the potential for reduction in this conservative approach is identified.
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