Comparison of Computational Fluid Dynamics of Erosion in Coiled Tubing to Field and Test Data

Rosine, Randy; Blanco, Iván; Bailey, Michael

doi:10.2118/113619-ms

Cited by 12 publications

(3 citation statements)

References 6 publications

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“…(2004) 19 also indicates that the solids contained in the fluid become highly concentrated on the conduit wall nearest the high velocity fluid stream due to centrifugal force. Other researchers 18,20 have estimated internal erosion patterns as a result of the near-wall concentration of solids and have determined that erosion rates are elevated in that area. These findings are obtained using fluids (1) of a different rheology than a drilling fluid, (2) that contain solids of a different size, concentration and hardness to that found in a drilling fluid and (3) that are traveling 8 times slower than fluid passing through BOP flex-loops during a 100 bpm dynamic kill (i.e., 50 bpm each through the choke and kill lines).…”

Section: Defining the Injectivity Limits Of A Subsea Relief Wellmentioning

confidence: 99%

Blowout Prevention and Relief Well Planning for the Wheatstone Big-Bore Gas Well Project

Upchurch

Falkner

House

2015

SPE Annual Technical Conference and Exhibition

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The offshore Wheatstone LNG Project in Western Australia utilizes subsea big-bore gas wells as the preferred method of producing the field. Wheatstone wells use a 9 -5/8" production conduit from the top of the gas pay zone to the ocean floor. Well bores of this size are necessary to match the large productive capacity of the gas reservoirs they penetrate. This producing scenario provides the obvious benefit of yielding large volumes of gas through the use of relatively few wells. Each of those highly productive wells, however, also represents a source of gas that, if accidently allowed to flow unhindered, could present an uncommonly difficult well control challenge. It is for this reason that the Wheatstone Drilling and Completions Team evaluated a wide range of possible reservoir and well architecture scenarios to fully understand the possible scale of relief well responses that might be necessary in the event of a blowout. The conclusions from this evaluation were surprising. Our originally-planned well design concept called for penetrating the Wheatstone gas reservoirs with a casing shoe set 950m vertically above. Our analysis indicated that 3-4 relief wells would be simultaneously required to bring a blowout under control. Based on these results, both the well and the drilling execution plan were redesigned to minimize the number of required relief wells. In summary, the redesign amounted to setting casing immediately (i.e., Յ 3m) above the gas reservoir before actually penetrating it, with the resulting benefit of reducing the required number of relief wells to 2. Although this reduction is beneficial, it should be noted that there is only one documented subsea case where 2 or more relief wells have been drilled with the intent of simultaneously pumping into both to effect a dynamic kill. Given this fact, our well control-related preparations for executing this project were more extensive than that of preceding projects. This paper chronicles the full extent of the engineering and operational planning performed to ensure that no uncontrolled hydrocarbon releases occurred during the execution of the Wheatstone Project's subsea big-bore gas wells and, if a blowout were to occur, that the response to such an unprecedented event would be sufficient and robust. Covered in the paper are (1) reservoir deliverability modeling, (2) dynamic kill modeling, (3) gas plume modeling, (4) relief well trajectory and mooring planning, (5) pilot hole execution planning, (6) a newly applied LWD technology for sensing resistivity vertically below the drill bit and (7) a discussion of future research that has been identified as necessary to better define the fluid injectivity capabilities of subsea relief wells.

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Section: Defining the Injectivity Limits Of A Subsea Relief Wellmentioning

confidence: 99%

Blowout Prevention and Relief Well Planning for the Wheatstone Big-Bore Gas Well Project

Upchurch

Falkner

House

2015

SPE Annual Technical Conference and Exhibition

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“…However, because of the feature of its structure, the ball seat is eroded and worn to different degrees due to impingement between the tool surface and entrained sand particles in the fracturing fluid [9] [10]. Since the erosion of ball seat cannot seal the seat, it will degrade fracturing performance or even cause the failure of fracturing process [11][12] [13]. Thus, the investigation of the ball seat will extend its service life and increase oil production for industry [14].…”

Section: Introductionmentioning

confidence: 99%

Numerical Study on Erosion Characteristic and Structural Optimization of Ball Seat for Hydraulic Fracturing

Wang,

2023

Advances in Transdisciplinary Engineering

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As one of the most important fracturing tools, the ball seat is widely used in the hydraulic fracturing process in the horizontal well. Due to the erosion of sand-carrying fluid on the inner wall of the ball seat, severe wear will occur on the surface of the material. This will lead to leak pressure and cause the fracturing failure. This study aims to investigate the erosion behavior of different ball seat structures and optimize the structure to increase erosion-resistant performance during the fracturing process. In this study, a two-section model of the ball seat combined with curved surface thought is proposed, and four models are designed. Based on the computational fluid dynamics (CFD) with Fluent software, four models are simulated and analyzed in actual working conditions using the dynamic mesh method with erosive wear deformation analysis for the first time. The simulation results show that the convex and concave curve surface structure has the lowest maximum erosion rate and most minor erosive wear deformation. Besides, from the point of view of pressure, research reveals the mechanism of different erosion behavior of ball seat structures and finds the optimal structure. Based on this structure, the curvature parameters are optimized by analyzing a set of models with different curvature. The results show that the optimal structure, convex and concave curve surface structure, with the 49 mm curvature radius of the convex curve and 57 mm curvature radius of the concave curve has the best performance to resist erosion wear. This research can offer a significant reference for structural optimization of the ball seat, simulation methods and prediction of the lifespan study of the ball seat.

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“…Rosine et al used computational fluid dynamics software to provide greater insight into actual coiled tubing flow patterns, including fluid flow velocity profiles, secondary flow regimes and erosion phenomenon. Their researches indicated that CFD had been proved to be an effective alternative to the full-scale testing (Rosine et al, 2008). Based on these studies, the CFD simulation methods are widely used in oil and gas industry.…”

Section: Introductionmentioning

confidence: 99%

Structural optimization of downhole fracturing tool using turbulent flow CFD simulation

Zheng

Wang

et al. 2015

Journal of Petroleum Science and Engineering

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Comparison of Computational Fluid Dynamics of Erosion in Coiled Tubing to Field and Test Data

Cited by 12 publications

References 6 publications

Blowout Prevention and Relief Well Planning for the Wheatstone Big-Bore Gas Well Project

Blowout Prevention and Relief Well Planning for the Wheatstone Big-Bore Gas Well Project

Numerical Study on Erosion Characteristic and Structural Optimization of Ball Seat for Hydraulic Fracturing

Structural optimization of downhole fracturing tool using turbulent flow CFD simulation

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