© 2019 Department of Petroleum Resources. All rights reserved Department of Petroleum Resources (DPR) PROCEDURE GUIDE

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86 | P a g e 
 
 
3 
Fluid measured (gas/liquid) 
 
 
4 
Meter type 
 
 
C 
METER TUBE 
 
 
1 
Flow conditioner (Yes/No) 
 
 
2 
Type of flow conditioner 
 
 
3 
How 
fastened? 
(welded/flanged/pinned) 
 
 
4 
Dimensions  
Length: 
 
Upstream diameter: 
Downstream diameter: 
First pipe connection: 
Second pipe connection: 
Upstream pressure tap: 
Downstream pressure tap: 
5 
Thermowell (Location, length, 
condition) 
 
 
6 
Pipe alignment (Yes/No) 
 
 
D 
PRESSURE TAPS 
 
 
1 
Orientation 
 
 
2 
Location 
of 
static 
pressure 
transducer 
(upstream/downstream) 
 
 
3 
No. of pressure taps 
 
 
4 
Pressure tap size  
 
 
5 
Condition of tap hole edge 
 
 
6 
Temperature probe type 
 
 
E 
METER PARAMETERS 
 
 
1 
Minimum flow rate 
 
 
2 
Maximum flow rate 
 
 
3 
Meter factor 
 
 
 
 
1.15 MEASUREMENT OF GAS BY MULTIPATH ULTRASONIC METERS 
1.15.1 Introduction 
Ultrasonic meters are inferential meters that derive the gas flow rate by measuring the 
transit times of high-frequency sound pulses. Transit times are measured for sound pulses 
transmitted and received between pairs of transducers positioned on or in the pipe. Pulses 
transmitted downstream with the gas flow are accelerated by the flow and pulses 
transmitted upstream against the gas flow along the identical acoustic path are 
decelerated. The difference in these transit times along the acoustic paths is related to the 
average gas flow velocity. 
1.15.2 Design requirements: 
The design shall be done in accordance with AGA 9 and other relevant standards and should 
be done in such a way not to allow for settlement of liquids and sediments.