Two-Phase Flow Correlations as Applied to Pumping Well Testing

1994 ◽  
Vol 116 (2) ◽  
pp. 121-128 ◽  
Author(s):  
C. S. Kabir ◽  
A. R. Hasan
Keyword(s):  
Two Phase Flow ◽  
Laboratory Data ◽  
Objective Evaluation ◽  
Well Testing ◽  
Phase Flow ◽  
Two Phase ◽  
Pipe Length ◽  
Annular Geometry ◽  
Test Computation ◽  
Gas Void Fraction

In a pumping-well buildup test, computation of bottom-hole pressure (BHP) and flow rate (BHF) requires the use of a two-phase flow correlation for estimating the gas void-fraction or holdup along the pipe length and shut-in time. Various correlations are available to perform this task. The purpose of this work is to review these two-phase correlations and to provide an objective evaluation. This analysis is necessitated by the fact that considerable differences in BHP and BHF may occur—depending upon the correlation used—in wells with long pumping liquid columns or those that have high gas/liquid ratio production. Consequently, a potential exists for obtaining different reservoir parameters from transient interpretation. Using laboratory data for two-phase flow in annular geometry, relative strengths of these correlations are explored. Our own data and those of others (a total of 114 points) are used in this comparative study. For static liquid columns, the correlations of Hasan-Kabir, Gilbert, and Podio et al. provide acceptable agreement with experimental data, exceptions being the Godbey-Dimon and Schmidt et al. correlations. In contrast, for the moving liquid column scenario, as in a buildup test, the Hasan-Kabir model provides the best agreement with the dataset used in this work. A basis for smoothing the bubbly/slug transition boundary is given for the Hasan-Kabir method, together with a field example.

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

1985 ◽  
Vol 107 (1) ◽  
pp. 142-151 ◽  
Author(s):  
J. P. Langlinais ◽  
A. T. Bourgoyne ◽  
W. R. Holden
Keyword(s):  
Experimental Data ◽  
Single Phase ◽  
Two Phase Flow ◽  
Hydraulic Diameter ◽  
Phase Flow ◽  
Drilling Mud ◽  
Two Phase ◽  
Bingham Plastic ◽  
Pressure Losses ◽  
Annular Geometry

The calculation of single-phase and two-phase flowing pressure gradients in a well annulus is generally based on an extension of empirical correlations developed for Newtonian fluids in circular pipes. Various techniques for extending pipe flow correlations to an annular geometry have been presented in the literature which involve the representation of the annular well geometry with an equivalent circular diameter and the representation of non-Newtonian fluid behavior with an apparent Newtonian viscosity. Unfortunately, little experimental data have been available which would allow a comparison of the relative accuracy of the various proposed techniques. In this study, experimental pressure gradient data have been taken in two 6000-ft wells. Frictional pressure losses for single-phase flow (mud only) in two annuli were compared to values predicted by the Bingham plastic and power law models. These calculations utilized the equivalent diameters defined by the Crittendon criteria, the hydraulic diameter, and the slot approximation. Also, total pressure difference for two-phase flow was measured for one annular geometry. This data was compared to that predicted by the Poettmann and Carpenter, Hagedorn and Brown, Orkiszewski, and Beggs and Brill correlations. Comparison of experimental data with the various prediction techniques was favorable, each having advantage in certain situations. For the data investigated, the Crittendon criteria using a Bingham plastic model gave the best results. The two-phase flow data was best predicted by the Hagedorn and Brown correlation utilizing an equivalent hydraulic diameter.

Evaluation of Void Fraction Correlations for the Statistical and Numerical Analysis of Two-Phase Flows Inside Producing Geothermal Wells

2008 ◽  
Author(s):  
A. A´lvarez del Castillo ◽  
E. Santoyo ◽  
O. Garci´a-Valladares ◽  
P. Sa´nchez-Upton
Keyword(s):  
Void Fraction ◽  
Two Phase Flow ◽  
Flow Patterns ◽  
Temperature Gradients ◽  
Production Performance ◽  
Phase Flow ◽  
Two Phase ◽  
Precise Knowledge ◽  
Geothermal Wells ◽  
Gas Void Fraction

The modeling of heat and fluid flow inside two-phase geothermal wells is a vital task required for the study of the production performance. Gas void fraction is one of the crucial parameters required for a better prediction of pressure and temperature gradients in two-phase geothermal wells. This parameter affects the correct matching between simulated and measured data. Modeling of two-phase flow inside wells is complex because two phases exist concurrently (exhibiting various flow patterns that depend on their relative concentrations, the pipe geometry, and the mass flowrate). A reliable modeling requires the precise knowledge of the two-phase flow patterns (including their transitions and some flow parameters). In this work, ten empirical correlations were used to estimate the gas void fraction in vertical-inclined pipes, and to evaluate their effect on the prediction of two-phase flow characteristics of some Mexican geothermal wells. High quality downhole pressure/ temperature logs collected from four producing geothermal wells were studied [Los Azufres, Mich. (Az-18); Los Humeros, Pue. (H-1), and Cerro Prieto, B.C. (M-90 and M-201)]. The pressure/ temperature gradients were simulated using an improved version of the wellbore simulator GEOPOZO, and the gas void fraction correlations. The simulated results were statistically compared with measured field data.

Liquid and Gas-Phase Distributions in a Jet With Phase Change

1988 ◽  
Vol 110 (4a) ◽  
pp. 955-960 ◽  
Author(s):  
Flavio Dobran
Keyword(s):  
Phase Change ◽  
Pressure Distribution ◽  
Total Pressure ◽  
Two Phase Flow ◽  
Phase Flow ◽  
Gas Velocity ◽  
Flow Properties ◽  
Two Phase ◽  
Pipe Length ◽  
Pressure Peak

A two-phase flow high-velocity jet with phase change was studied numerically. The jet is assumed to be created by the two-phase critical flow discharge through a pipe of variable length and attached to a vessel containing the saturated liquid at different stagnation pressures. The jet flow is assumed to be axisymmetric and the modeling of the two-phase flow was accomplished by a nonequilibrium model that accounts for the relative velocity and temperature difference between the phases. The numerical solution of the governing set of balance and conservation equations revealed steep gradients of flow properties in both radial and axial directions. The liquid phase in the jet is shown to remain close to the jet axis, and its velocity increases until it reaches a maximum corresponding to the gas velocity, and thereafter decreases at the same rate as the gas velocity. The effect of decreasing the pipe length is shown to produce a larger disequilibrium in the jet and a double pressure peak in the total pressure distribution. A comparison of the predicted total pressure distribution in the jet with the experimental data of steam–water at different axial locations is demonstrated to be very reasonable.

Numerical Simulation of the Gas-Liquid Flow in a Rotary Gas Separator

1998 ◽  
Vol 120 (1) ◽  
pp. 41-48 ◽  
Author(s):  
G. Lackner ◽  
F. J. S. Alhanati ◽  
S. A. Shirazi ◽  
D. R. Doty ◽  
Z. Schmidt
Keyword(s):  
Void Fraction ◽  
Liquid Flow ◽  
Two Phase Flow ◽  
Numerical Procedure ◽  
Phase Flow ◽  
Two Phase ◽  
Free Gas ◽  
Gas Separator ◽  
Gas Liquid Flow ◽  
Gas Void Fraction

The presence of free gas at the pump intake adversely affects the performance of an electrical submersible pump (ESP) system, often resulting in low efficiency and causing operational problems. One method of reducing the amount of free gas that the pump has to process is to install a rotary gas separator. The gas-liquid flow associated with the down hole installation of a rotary separator has been investigated to address its overall phase segregation performance. A mathematical model was developed to investigate factors contributing to gas-liquid separation and to determine the efficiency of the separator. The drift-flux approach was used to formulate this complex two-phase flow problem. The turbulent diffusivity was modeled by a two-layer mixing-length model and the relative velocity between phases was formulated based on published correlations for flows with similar characteristics. The well-known numerical procedure of Patankar-Spalding for single-phase flow computations was extended to this two-phase flow situation. Special discretization techniques were developed to obtain consistent results. Special under relaxation procedures were also developed to keep the gas void fraction in the interval [0, 1]. Predicted mixture velocity vectors and gas void fraction distribution for the two-phase flow inside the centrifuge are presented. The model’s predictions are compared to data gathered on a field scale experimental facility to support its invaluable capabilities as a design tool for ESP installations.

scholarly journals A Numerical Study on Oscillatory Flow-Induced Sediment Motion over Vortex Ripples

2015 ◽  
Vol 45 (1) ◽  
pp. 228-246 ◽  
Author(s):  
Xin Chen ◽  
Xiping Yu
Keyword(s):  
Turbulence Model ◽  
Oscillatory Flow ◽  
Flow Model ◽  
Two Phase Flow ◽  
Numerical Study ◽  
Laboratory Data ◽  
Phase Flow ◽  
Mass Force ◽  
Two Phase ◽  
Reference Concentration

AbstractA two-dimensional, two-phase flow model is applied to the study of sediment motion over vortex ripples under oscillatory flow conditions. The Reynolds-averaged continuity equations and momentum equations for both the fluid and sediment phases, which include the drag force, the added mass force, the lift force for interphase coupling, and the standard k–ε turbulence model as well as the Henze–Tchen particle turbulence model for closure, are numerically solved with a finite-volume method. The model is effective over the whole depth from the undisturbed sandy bed to the low concentration region above the ripples. Neither a reference concentration nor a pickup function is required over the ripple bed as in a conventional advection–diffusion model. There is also no need to identify the bed load and the suspended load. The study focuses on the effects of erodible ripples on the intrawave flow and sediment motion over the ripples. The computational results show reasonable agreement with the available laboratory data. It is demonstrated that the formation–ejection process of vortices and the trapping–lifting process of sediment over vortex ripples can be well described by the two-phase flow model. The numerical model can also accurately predict the vertical distribution of the mean sediment concentration.

scholarly journals A Potential Parameter for A Non-Darcy Form of Two-Phase Flow Behaviour, Compressibility Related

2018 ◽  
Vol 7 (3.3) ◽  
pp. 126 ◽  
Author(s):  
Bashir Busahmin ◽  
Brij Maini
Keyword(s):  
Two Phase Flow ◽  
Flow Behavior ◽  
Laboratory Data ◽  
Phase Flow ◽  
Two Phase ◽  
Daily Production ◽  
Recovery Method ◽  
Fundamental Factor ◽  
Foamy Oil ◽  
Conventional Solution

Numerous scientists did their studies and conducted various laboratory experiments related to a non-Darcy behavior of a two-phase flow for the past thirty years, and made an effort to clarify the behavior. Non-Darcy flow behavior, phenomena occurred in primary recovery method of reservoirs that have an API degree gravity of less than 20. It was confirmed that it results in greater production. The compressibility of foam fits to be the one of the general fundamental factor that directs the lifetime of a non-Darcy form of two phase flow behavior or also is known as the foamy oil.  In the process of usual drive depletion, foamy oil featured of low production GOR and high daily production rate. Foamy oil is more compressible than conventional solution gas due to the oil that gas dispersed in it; as a result, oil formation volume factor is much higher than that in conventional oil. This paper represents a laboratory data followed by some of the analysis related to the properties of non-Darcy form of two phase flow and that is the compressibility parameter. The experimental results showed that at different saturation pressures and at a room temperature, the trends fit the expected behavior above the saturation pressures. Moreover, the measurements of live oil compressibility were also attempted below the saturation pressures. It was concluded that other properties such as the viscosity is added a significant effect rather than compressibility in the behavior of what so called  foamy oil compared to the presence or absence of asphaltenes and other polar oil components.  

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