An Experimental Analysis of Vertical Two-Phase Flow Using a Drilling Mud/Natural Gas Medium

1983 ◽  
Author(s):  
J.P. White
Keyword(s):  
Natural Gas ◽  
Experimental Analysis ◽  
Two Phase Flow ◽  
Phase Flow ◽  
Drilling Mud ◽  
Two Phase ◽  
Gas Medium

Experimental analysis of two-phase flow in a radial centrifugal pump

2017 ◽  
Author(s):  
Henrique Stel ◽  
Edgar Ofuchi ◽  
Dalton Bertoldi ◽  
Moisés Marcelino Neto ◽  
Rigoberto Morales ◽  
...  
Keyword(s):  
Centrifugal Pump ◽  
Experimental Analysis ◽  
Two Phase Flow ◽  
Phase Flow ◽  
Two Phase

An Evaluation of Existing Two-Phase Flow Correlations for Use With ASME Sharp Edge Metering Orifices

1977 ◽  
Vol 99 (3) ◽  
pp. 343-347 ◽  
Author(s):  
L. T. Smith ◽  
J. W. Murdock ◽  
R. S. Applebaum
Keyword(s):  
Natural Gas ◽  
Data Base ◽  
Root Mean Square ◽  
Two Phase Flow ◽  
Salt Water ◽  
Sharp Edge ◽  
Phase Flow ◽  
Mean Square ◽  
Two Phase ◽  
Liquid Flows

The two-phase flow correlations developed by Murdock, James, Marriott, and Smith and Leang are evaluated for the case of flow through sharp edge measuring orifices which physically meet ASME standards for flow measurement. The evaluation is based on two sets of consistent orifice flow data. The first data base consists of 34 test points for the flow of steam-water mixtures. The second data base consists of 81 data points for the flow of air-water, natural gas-water, natural gas-salt water, and natural gas-distillate mixtures. The root mean square fractional deviation of each correlation is used to determine its predictive reliability. Computed root mean square fraction deviations for steam-water flows are: James, ±0.081; Marriott, ±0.114; Murdock, ±0.141; Smith and Leang, ±0.218. For the case of gas-liquid flows, the values are: Murdock, ±0.074; James, ±0.178; Smith and Leang, ±0.183; Marriott, ±0.458.

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.

scholarly journals Experimental Analysis of Two-phase Flow nozzle for Desalination and Power Generation System

2012 ◽  
Vol 49 ◽  
pp. 324-329 ◽  
Author(s):  
Sara Vahaji ◽  
Abhijit Date ◽  
Sherman C. Cheung ◽  
Jiyuan Tu ◽  
Aliakbar Akbarzadeh ◽  
...  
Keyword(s):  
Power Generation ◽  
Experimental Analysis ◽  
Two Phase Flow ◽  
Phase Flow ◽  
Generation System ◽  
Two Phase ◽  
Power Generation System

Two-Phase Flow Measurement With Orifices

1962 ◽  
Vol 84 (4) ◽  
pp. 419-432 ◽  
Author(s):  
J. W. Murdock
Keyword(s):  
Natural Gas ◽  
Two Phase Flow ◽  
Salt Water ◽  
Practical Method ◽  
Reynolds Numbers ◽  
Phase Flow ◽  
Research Committee ◽  
Two Phase ◽  
Use Of Data ◽  
Flow Metering

This paper presents a practical method for computing two-phase flow rates through AGA-ASME stamdard orifice meters to a tolerance of 1.5 per cent. A rational equation is developed modifying the present single-phase metering equation by the introduction of one experimentally determined constant and permitting the use of data already contained in the ASME Fluid Meters Research Committee publications. Equations are also given for computing the two-phase flow of natural gas using the American Gas Association Report No. 3. No additional data are needed for the solution of two-phase flow metering problems. The experimental constant is derived from the analysis of 90 test points for two phase flow of steam-water, air-water, natural gas-water, natural gas-salt water, and natural gas-distillate combinations. Three separate test series are described for orifices equipped with radius, flange, and pipe tap locations in 2 1/2, 3, and 4-inch pipe with beta ratios ranging from 0.25 to 0.50. Pressures ranged from atmospheric to 920 psia, differentials from 10 to 500 inches of water, and liquid weight fractions from 2 to 89 per cent. Temperatures were from 50 to 500 F and Reynolds numbers for the liquid from 50 to 50,000 and for the gas from 15,000 to 1,000,000. These data were correlated to a standard deviation of 0.75 per cent. The areas where further research is needed to increase the universality of the two-phase metering equation are delineated.

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