We make easy-to-use engineering software for the oil & gas industry. Our software is designed for practical field applications, and the programs have been tested and proven for both onshore and offshore oil and gas installations. The programs are designed for use right away, easy, clutter-free and fast.
The programs are provided “as is” without warranty of any kind, either expressed or implied, including any warranty of merchantability or fitness for a particular purpose. In no event shall the author or Norcraft be held liable for any loss of profit, special, incidental, consequential, or other similar claims.
The software programs are Excel Macros and must be run under Excel 2007 and up with ‘Macros’ enabled. If downloading the ‘Demo’- version of the programs, you are required to register the program(s) for a licensing fee of $9.95 for each program and the full version will be e-mailed to you. The free programs do not require any registration.
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Pograms AGA-3 and ISO-5167 will size orifice plates for given design conditions, find pressure drop for a given flow, or flow for a given pressure drop. The standards (AGA-3 ( API-2530: 1991) and ISO-5167: 2003) are originally designed for gas orifices. In these programs they are also used for liquid orifices.
The programs let you calculate the following orifice-types:
-Restriction Orifice - Gas
-Restriction Orifice - Liquid
For gas-calculations you have to enter specific gas gravity, temperature and pressure. You can also give mole-fractions of N2, CO2 and H2S for sour gas calculations.
The AGA-8 equation is used for calculating Z-factor (compressibility factor) for natural gases, and the Redlich-Kwong equation of state for air and nitrogen.
For oil-calculations you have to enter specific oil gravity, temperature and pressure. It is also recommended to give molecular weight of oil. For water-calculations the input requirements are salinity, temperature, and pressure.
NOTE: It is assumed that all dissolved solids for water are expressed as equivalent sodium chloride concentration.
The results are an orifice specification sheet giving the necessary data for design of an orifice or evaluating an existing orifice.
The results will contain a few factors that you should know:
The velocity of approach factor is defined as:
Ev = 1/(Sqrt(1-Beta^4))
The flow coefficient, Alpha, is defined as:
Alpha = Ev * Cd
and orifice to pipe diameter ratio is given as:
Beta = OD/PID
API/ ANSI-2530 - 1991 (AGA Report No. 3) (AGA3):
The basic flow equation is:
Qv = Fn*(Fc+Fsl)*Y1*Fpb*Ftb*Ftf*Fgr*Fpv*Sqrt(Pf1*hw)
Fn = Numeric conversion factor
Cd = Discharge coefficient = (Fc + Fsl)
Fc = Orifice calculation factor
Fsl= Slope factor
Y1 = Expansion factor based on upstream tap
Fpb= Pressure base factor, set to 1.0 (14.73 psia)
Ftb= Temperature base factor, set to 1.0 (60 deg F)
Ftf= Flowing temperature factor
Fgr= Specific gravity factor
Fpv= Super-compressibility factor
Pf1= Absolute flowing pressure based on upstream tap
hw = Orifice differential pressure, in H2O at 60 deg F
The above equation is often simplified to:
Qv = C' * Sqrt(Pf1*hw)
where C' is called the Composite orifice flow factor.
For other factors and the factors for pipe taps you are advised to consult the standard API-2530-1991, Part 3.
ISO-5167-2: 2003 ( ISO-5167):
The basic flow equation is:
Qm = C*E*Eps*Pi/4*OD^2*Sqrt(2*dP*Roh)
Qm = Mass flow rate (kg/s)
C = Discharge coefficient = Alpha/E
E = Velocity of approach factor = 1/(Sqrt(1-Beta^4))
Eps = Expansion factor due to pressure drop
Pi = 3.14159
OD = Orifice diameter at actual flowing conditions
dP = Differential pressure across orifice
Roh = Density of flowing fluid measured at upstream tap
For other factors consult the standard ISO-5167-2: 2003.
Program WatGas - Water-Natural Gas Phase Behavior Calculations
Watgas calculatesWater-Natural Gas interaction phase behavior, and includes the following types of calculations:
-Hydrate formation calculations
-Water content predictions of natural gases
-Inhibitor quantities (methanol/glycols) to avoid hydrate problems in pipelines
-Solid CO2 formation predictions
The program handles gases with known compositions and non-compositional gases (only gas gravity is needed). Note that the compositional model is more reliable than the non-compositional model, although they give similar results.
Almost all gases contain some water vapor. When leaving the producing formation, gas is saturated with water vapor, which is in equilibrium with reservoir liquid water at temperatures and pressures prevailing there.
Knowing the water content of natural gases is essential to the design and operation of production, dehydration and transmission systems. Water may condense in production and gathering systems. This may result in hydrate formation and plugging of flow systems and damage to internals of production equipment.
Condensed water may form water slugs, which will tend to decrease flow efficiency and increase the pressure drop in a line. Presence of free water in pipeline systems may also cause corrosion. If carbon dioxide and/or hydrogen sulfide are present, the gases may form carbonic acid and sulphurous acid respectively if dissolved in water.
Program GOWProp (Gas-Oil-Water Physical Properties
Program GOWProp is a Physical Properties program that calculates PVT properties of gas, oil, and water — with your choice of calculation methods. Pick from a selection of standard equations for calculating certain properties. More than 12 properties are calculated and the results include a pressure depletion table of the various properties and will plot the output on screen. U.S. and SI Units.
Oil properties are calculated based on a black-oil model. In fluid-property terms the black-oil model employs 2 pseudo-components:
1) "OIL" defined as produced oil at stock tank conditions
2) "GAS" defined as produced separator gas
The basic assumption is that gas may dissolve in the oil phase, but oil will not dissolve in the gas phase. For mixtures of heavy oil and light components this is a reasonable assumption, but is a misleading assumption for mixtures of light and intermediate components.
The following fluids are included:
-Monoethylene glycol/Water mixtures
-Diethylene glycol/Water mixtures
-Triethylene glycol/Water mixtures
GOWProp will let you choose between SI-units (metric) or Customary units.
The gas property routine calculates:
-Gas formation volume factor
-Z-factor (gas deviation factor)
-Ideal isentropic coefficient, Cp/Cv
-Real isentropic coefficient, k
-Pseudo Critical properties
-Pseudo Reduced properties
The liquid property routine calculates:
-API gravity (for oil only)
-Formation volume factor (oil and water only)
-Solution gas-liquid ratio (oil and water only)
-Bubble point pressure (oil only)
-Pseudo Critical properties
-Pseudo Reduced properties
A pressure liberation table of properties (at constant temperature) will also presented from given pressure down to atmospheric conditions (14.696 psia [1.01325 Bara]).
Program GOSep (Gas-Oil Separator Flash Calculations)
Program GOSep performs flash calculations for gas/oil separators to optimize liquid recovery. In this program two (2) separator stages are used to transition the oil from reservoir to stock tank conditions.
Composition of reservoir fluid and pressures/temperatures at each stage are required input parameters.
Equilibrium ratios (K-values) are used for calculating compositions of gas and liquid phases at given temperatures and pressures. Normally an equation of state (EOS) is used for predicting equilibrium ratios, and is a function of composition, pressure and temperature.
Based on the fact that compositional effects on equilibrium ratios are small below about 1000 psia, Standing 45 developed a correlation for calculating equilibrium ratios based on data reported by Katz and Hachmuth46 . The correlation gives the following equation for each component:
F = b x (1/Tb - 1/T)
K = equilibrium ratio
a, b, c = correlating parameter
P = pressure, psia
T = temperature, deg R
Tb = boiling point, deg R
X = mole fraction in liquid phase
y = mole fraction in vapor phase
Last Revised: Mar, 2014