Frictional Pressure Losses for Annular Flow of Drilling Mud and Mud-Gas Mixtures

Langlinais, J.P.; Bourgoyne, A.T.; Holden, W.R.

doi:10.1115/1.3231154

Cited by 7 publications

(6 citation statements)

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“…The frictional pressure drop data used in this study are taken from Langlinais et al (1985), who measured annular pressure drops using several different mud systems. The data (91 points) were obtained from two 1828 m deep cased wells in Louisiana.…”

Section: Measured Datamentioning

confidence: 99%

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Frictional Pressure Losses for Annular Flow of Drilling Muds

Abdul-Majeed

1996

Polymer-Plastics Technology and Engineering

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Based on measured pressure drop data (91 points), an attempt is made to use the Robertson-Stiff rheological model for estimating the pressure drop for annular single-phase flow. The model parameters A, B, and C , are calculated using the Golden Section Search Method. The pressure drop equation derived by Aswad and Saleh, in terms of the model parameters, has been used for laminar flow. For turbulent flow, a new friction factor correlation is proposed, which represents a generalization of the Caetano et al. equation for Newtonian fluids. In addition to the present data bank, used in the development of the proposed friction factor, another set of data from the Middle East are used for comparison purposes. It is observed based on statistical results that the laminar and turbulent flow equations described by the Robertson-Stiff model show excellent results and clearly outperform the two popular models, the Bingham plastic and the power law.

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Section: Measured Datamentioning

confidence: 99%

“…The laminar flow equations for Bingham plastic and power-law models are presented and evaluated in the literature (Langlinais et al, 1985;Jensen & Sharma, 1987). Also the laminar flow equation for the Robertson-Stiff model is presented (Aswad & Saleh, 1990), but has not been evaluated until now.…”

Section: Introductionmentioning

confidence: 99%

Frictional Pressure Losses for Annular Flow of Drilling Muds

Abdul-Majeed

1996

Polymer-Plastics Technology and Engineering

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“…The procedure outlined by Langlinais et al 3 for calculating flowing pressure gradients for two-phase, gas/drilling-fluid annular flow used the Hagedorn and Brown correlation 11 with an equivalent diameter defined by the hydraulic-diameter concept. The hydraulic diameter is defined as Note that the pressure losses resulting from acceleration are neglected.…”

Section: Appendix A-calculation Of Drilled Gas Concentrationmentioning

confidence: 99%

“…and are summarized in Appendix C. These equations are valid only for gas/drilling-fluid ratios in the range of those encountered for drilled gas and should not be applied to describe the behavior of gas kicks. Fluid densities can be calculated with the Peng-Robinson equation of state (PREOS), 2 which is outlined in Appendix D. The frictional pressure gradient of the gas/drilling-fluid mixture can be determined as recommended by Langlinais et al 3 and described in Appendix E.…”

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confidence: 99%

Methods for Handling Drilled Gas in Oil-Based Drilling Fluids

O'Bryan

Bourgoyne

1989

SPE Drilling Engineering

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This paper presents calculation methods for predicting the behavior of drilled-gas contamination of oil-based drilling fluids. The methods are verified by experiments conducted in a 6, OOO-ft [1828.8-m] test well. This paper also presents field-handling procedures developed with the calculation methods. IntroductionDuring drilling operations, the bit routinely drills through gasbearing formations. Although proper drilling-fluid density selection will prevent gas from flowing from these formations into the borehole, the gas contained in the pore space of the rock destroyed by the bit will always become mixed with the drilling fluid. This gas is often called "drilled gas." If an oil-based drilling fluid is used, drilled gas will normally dissolve completely in the drilling fluid at bottomhole conditions because the volume of gas is small compared with the volume of drilling fluid in which it is mixed (Fig. I). When this gas/drilling-fluid mixture is pumped near the surface, however, gas will come out of solution and expand rapidly because of the greatly reduced pressure. This gas evolution will often begin when the gas/drilling-fluid mixture is within a few hundred feet of the surface, providing little time for the rig crew to react before gas reaches the surface. Hazardous situations have been reported where significant amounts of gas have been released on the rig floor and drilling fluid has been spewed over the crown block while the annular blowout preventers (BOP's) are being closed.These problems occur because the equipment and procedures sometimes used are not adequate for some of the well conditions experienced. To design a system properly for safe handling of drilled gas in oil-based drilling fluids, a calculation procedure is needed for predicting well behavior under various field conditions. This type of calculation procedure would also permit evaluation of existing rig equipment for the purpose of imposing operationallimitations, such as a maximum safe penetration rate (ROP). This paper presents techniques for estimating the amount of drilled gas entering an oil-based drilling fluid and for predicting the behavior of the gas/drilling-fluid mixture in the annulus as it is circulated to the surface. With the methods presented, the gas/ drilling-fluid bubblepoint depth, the maximum loss in bottomhole pressure (BHP), and an approximate annular pressure profile can be calculated. The volume of drilling fluid that would be expelled from the well and the associated gas rate can also be estimated. The calculation procedures presented were verified by experiments conducted in a 6,000-ft [1828.8-m] test well.Several alternative methods for handling drilled gas in oil-based drilling fluids were explored with the calculation procedure. Special considerations for deepwater floating drilling operations are also discussed. Calculation ProcedureThe calculation procedure developed requires completion of three steps: (I) determination of the concentration and total volume of drilled gas entering the drilling fluid at the...

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“…Langlinais et al 5 presented experimental data of annular frictional pressure drops for mud-gas mixtures flowing in vertical wells. The mixtures were composed of water-base drilling mud and nitrogen gas.…”

Section: Introductionmentioning

confidence: 99%

Modeling of Transient Cuttings Transport in Underbalanced Drilling (UBD)

Doan¹,

Oguztöreli

Masuda

et al. 2003

SPE Journal

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Underbalanced drilling (UBD) holds several important advantages over conventional drilling technology. These include minimization of formation damage, faster penetration rate, and ability for evaluation of reservoir productivity during the drilling process. As UBD technology matures, it has also been used more and more in different applications. However, many aspects of UBD technology remain poorly understood. The model presented in this paper seeks to understand the mechanisms involved in the transport of cuttings in UBD.The model simulates the transport of drill cuttings in an annulus of arbitrary eccentricity and includes a wide range of transport phenomena, including cuttings deposition and resuspension, formation, and movement of cuttings bed. The model consists of conservation equations for the fluid and cuttings components in the suspension and the cuttings deposit bed. Interaction between the suspension and the cuttings deposit bed, and between the fluid and cuttings components in the suspension, are incorporated. Solution of the model determines the distribution of fluid and cuttings concentration, velocity, fluid pressure, and velocity profile of cuttings deposit bed at different times.The model is used to determine the critical transport velocity for different hydrodynamic conditions. Results from the model agree quite closely, qualitatively, with experimental data obtained from a cuttings transport flow loop at the Technology Research Center of the Japan Natl. Oil Corp. (TRC/JNOC)'s Kashiwazaki Test Field in Japan. These results show the importance of slippage in the formation of the cuttings deposit bed. The model is useful in evaluating the minimum flow rate for effective cuttings removal in UBD.

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Frictional Pressure Losses for Annular Flow of Drilling Mud and Mud-Gas Mixtures

Cited by 7 publications

References 0 publications

Frictional Pressure Losses for Annular Flow of Drilling Muds

Frictional Pressure Losses for Annular Flow of Drilling Muds

Methods for Handling Drilled Gas in Oil-Based Drilling Fluids

Modeling of Transient Cuttings Transport in Underbalanced Drilling (UBD)

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