AGA Fully Turbulent Flow

The AGA Fully Turbulent Flow equation is one of the more widely used flow rate equations for large diameter pipes, estimating pressure drops and flow rates with a strong degree of accuracy provided that an accurate estimate of the pipe roughness is known with correctness.

Formulas

AGA Equation

The transmission value for the AGA equation is calculated using the Von Karman equation:

F=4log_{10}biggr(frac{3.7D}{k}biggr)

F=4log_{10}\biggr(\frac{3.7D}{k}\biggr)

Where:
𝐹 βˆ’ Transmission Factor
π‘˜ βˆ’ Pipe Roughness
𝐷 βˆ’ Internal Diameter (in)

Using this transmission factor, we can calculate the flow rate, upstream pressure, downstream pressure, and predicted inner diameter of the pipe: Q=

EC_Q\cdot \left( \frac{T_b}{P_b} \right)\cdot \sqrt {\frac{P_1^2-e^sP_2^2}{GT_fL_eZ}}\cdot D^{2.5}

Q=E\cdot F\cdot C_Q\cdot \left( \frac{T_b}{P_b} \right)\cdot \sqrt   {\frac{P_1^2-e^sP_2^2}{GT_fL_eZ}}\cdot D^{2.5}

𝑄 βˆ’ Flow Rate at Base Conditions (ft3/day)
E – Pipeline efficiency
𝐢𝑄 βˆ’ 38.77
𝑇𝑏 βˆ’ Base Temperature (Β°R)
𝑃𝑏 βˆ’ Base Pressure (psia)
𝑇𝑓 βˆ’ Gas Flowing Temperature (Β°R)
𝐷 βˆ’ Internal Diameter (in)
π‘˜ βˆ’ Pipe Roughness (in)
𝑃1 βˆ’ Upstream Pressure (psia)
𝑃2 βˆ’ Downstream Pressure (psia)
𝐺 βˆ’ Gas Specific Gravity
𝑍 βˆ’ Compressibility Factor
Le βˆ’ Elevation-Adjusted Pipe Segment Length, including Expansion (mi, see below for definition)

s=frac{C_Striangle HG}{T_fZ}

s=\frac{C_S G\Delta H }{T_fZ}

𝑠 βˆ’ Elevation adjustment parameter
𝐢𝑆 βˆ’ 0.0375
G – Gas specific gravity
βˆ†π» βˆ’ Change in Elevation (ft) [Downstream Elevation (ft) – Upstream Elevation(ft)]
𝑍 βˆ’ Compressibility Factor
𝑇𝑓 βˆ’ Gas Flowing Temperature (Β°R)

L_e=frac{(e^s-1)}{s}

L_e=\frac{(e^s-1)}{s}\times L

𝐿𝑒 βˆ’ Elevation-Adjusted Pipe Segment Length including Expansion (mi)
𝑠 βˆ’ Elevation adjustment parameter
L – Pipe Segment Length including Expansion (mi)

Average Gas Velocity

The predicted average gas velocity from this system is:

V= 0.002122 \frac{Q}{D^2} \left(\frac{T_b}{P_b}\times \frac{P_\text{avg}}{T_f} \right)

V= 0.002122 \frac{Q}{D^2} \left(\frac{T_b}{P_b}\times  \frac{P_\text{avg}}{T_f}  \right) 

𝑉 βˆ’ Average gas velocity (ft/sec)
𝑄 βˆ’ Flow rate at base conditions (ft^3/hr)
𝐷 βˆ’ Internal Diameter (in)
𝑇𝑏 βˆ’ Base Temperature (Β°R)
𝑃𝑏 βˆ’ Base Pressure (psia)
𝑇𝑓 βˆ’ Gas Flowing Temperature (Β°R)
π‘ƒπ‘Žπ‘£π‘” βˆ’ Average Internal Gas Pressure (psia)

For Small Pressure Drop (P2 > 0.8 P1):
P_{avg}=frac{(P_1-P_2)}{2}

P_{avg}=\frac{P_1-P_2}{2}

For large pressure drop :P_{avg}=
frac{2}{3}biggr[ P_1+P_2-frac{P_1P_1}{P_1+P_2} biggr]

P_{avg}=\frac{2}{3}\biggr[  P_1+P_2-\frac{P_1P_1}{P_1+P_2}    \biggr]

Sonic and Erosional Velocity

The predicted average gas velocity is checked against the sonic velocity of the gas, and the velocity at which erosion is predicted to occur on the pipe. If the gas exceeds the erosional velocity, operating at these conditions will cause long-term damage to the pipe; if the velocity exceeds the sonic velocity, the flow becomes choked, and the results of the AGA fully turbulent flow calculator are no longer applicable.

The erosional velocity of the gas is given by:
V_\text{errosion} = C_\text{errosion} \sqrt{10.73\cdot \frac{Z T_f}{29GP_\text{avg}}}

V_\text{errosion} = C_\text{errosion} \sqrt{10.73\cdot \frac{Z T_f}{29GP_\text{avg}}}

where:
𝑉errosion βˆ’ Erosional gas velocity(ft/sec)
Cerrosion βˆ’ Erosional gas constant (usually 100)
Z βˆ’ Gas compressibility factor
𝑇𝑓 βˆ’ Gas Flowing Temperature (Β°R)
G βˆ’ Gas specific gravity
π‘ƒπ‘Žπ‘£π‘” βˆ’ Average Internal Gas Pressure (psia)

The sonic velocity of the gas is given by:
V_\text{errosion} = C_\text{errosion} \sqrt{10.73\cdot \frac{Z T_f}{29GP_\text{avg}}}

V_\text{sonic} = 41.42\sqrt{\gamma_h \frac{T_f}{G}}

where:
𝑉sonic βˆ’ Sonic gas velocity(ft/sec)
𝑇𝑓 βˆ’ Gas Flowing Temperature (Β°R)
G βˆ’ Gas specific gravity
π‘ƒπ‘Žπ‘£π‘” βˆ’ Average Internal Gas Pressure (psia)
Ξ³h – Sonic velocity constant
\gamma_h = 1.0836 -0.000115T_f +\frac{ 5.62 – 0.002T_f }{28.974G}

\gamma_h = 1.0836 -0.000115T_f +\frac{ 5.62 - 0.002T_f }{28.974G} 

Case Guide

Part 1: Create Case

  1. Select the AGA Fully Turbulent Flow application in the Hydraulics module.
  2. To create a new case, click the β€œAdd Case” button.
  3. Enter Case Name, Location, Date and any necessary notes.
  4. Fill out all required parameters.
  5. Make sure the values you are inputting are in the correct units.
  6. Click the CALCULATE button to overview results

Input Parameters

  • Internal Pipe Diameter(in)
  • Length of Pipeline(mi)
  • Upstream Elevation(ft)
  • Downstream Elevation(ft)
  • Pipe Roughness Value (in)
  • Pipeline Efficiency Factor
  • Gas Operating Temperature(Β°F)
  • Base Temperature(Β°F)
  • Base Pressure(psia)
  • Upstream Pressure(psig)
  • Downstream Pressure(psig)
  • Flow rate (MCFD)
  • Gas Specific Gravity
  • Compressibility Factor
  • Erosional Velocity Constant
Downstream Pressure
Flow Rate
Internal Pipe Diameter
Upstream Pressure

Part 2: Outputs/Reports

  1. If you need to modify an input parameter, click the CALCULATE button after the change.
  2. To SAVE, fill out all required case details then click the SAVE button.
  3. To rename an existing file, click the SAVE As button. Provide all case info then click SAVE.
  4. To generate a REPORT, click the REPORT button.
  5. The user may export the Case/Report by clicking the Export to Excel icon.
  6. To delete a case, click the DELETE icon near the top of the widget.

Results

  • Downstream Pressure(psig)
  • Flow Rate(MCFD)
  • Internal Pipe Diameter(in)
  • Upstream Pressure(psig)
  • Transmission Factor
  • Velocity(ft/sec.)
  • Erosional Velocity(ft/sec.)
  • Sonic Velocity(ft/sec.)
Downstream Pressure
Flow Rate
Internal Pipe Diameter
Upstream Pressure

References

  • McAllister, E. W., β€œPipeline Rules of Thumb” Gulf Professional Publishing, Seventh Edition
  • Menon, Shahi E., β€œGas Pipeline Hydraulics”, Systek Technologies, Inc.
  • Carroll, Landon and Hudkins, Weston R., β€œAdvanced Pipeline Design”
  • American Gas Association (AGA), β€œReference: Eq-17-18, Section 17, GPSA”, Engineering Data Book, Eleventh Edition

FAQ

  • Gas Purging Calculations?

    Purging is a process of removing gas from the pipeline. Controlled purging of gases from pipelines by direct displacement with other gases that have been safely practiced for many years with the recognition that some flammable mixture is present. Purging of gases from pipelines by direct displacement with another gas also has been similarly practiced. It works both ways; however, there will always be an atmosphere of type of a mixture. This is due to the densities of the gases. Check Out

  • What is Erosional Velocity?

    Pipe erosion begins when velocity exceeds the value of C/SQRT(ρ) in ft/s, where ρ = gas density (in lb./ft3) and C = empirical constant (in lb./s/ft2) (starting erosional velocity). We used C=100 as API RP 14E (1984). However, this value can be changed based on the internal conditions of the pipeline. Check Out

  • What is Sonic Velocity?

    The maximum possible velocity of a compressible fluid in a pipe is called sonic velocity. Oilfield liquids are semi-compressible, due to dissolved gases. Check Out

Updated on July 10, 2025

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