Automated group Metering unit (AGMU) BARS

Features and Benefits

• The installations can be made in separation and non-separation (using a multiphase flow meter) versions;
• It is possible to manufacture installations for difficult operating conditions (high _H2S content, high gas factor, abnormally high formation pressure, etc.)
• Implementation of various well switching options (PSM; specially designed ball valve system);
• The installations can be made both stationary and mobile;
• The MODUL-BARS control system is a unique scalable solution.

Compound

The exact equipment composition is determined based on the customer's requirements. The standard control unit consists of a process unit and a local automation unit.

Composition of the technological block:

• technological equipment for separating well fluids
  (in case of a separation plant);
• oil, gas and water measuring lines with installed instrumentation and automation devices (flow, pressure and temperature control and measurement devices), valves and control valves;
• Engineering systems for the safe and efficient operation of the facility: shelter, heating and ventilation systems, gas control system, automatic fire detection system, etc.
  

Composition of the automation unit:

• The control system is implemented on a programmable logic controller installed in a control cabinet;
• electric power distribution system (EPDS);
• Engineering systems for the safe and efficient operation of the installation: shelter, heating and ventilation systems, automatic fire detection system, etc.
• Metrological characteristics

• Parameter	Units of measurement	Meaning
  Measurement range of mass flow rate of NGV mixture	t/h (t/day)	from 0.1 to 83.3 (from 2.4 to 2,000)
  Measurement range of volumetric flow rate of free petroleum gas reduced to standard conditions	m3 /h ( m3 /day)	from 2 to 62,500 (from 50 to 1,500,000)
  Limits of permissible relative error in measuring the mass and mass flow rate of the NGV mixture (1)
  - when the viscosity of oil in reservoir conditions is no more than 200 mPa s	%	±2.5
  - when the oil viscosity in reservoir conditions is 200 mPa s or more	%	±10.0
  Limits of permissible relative error in measuring the mass of the NGV mixture without taking into account water in the NGV mixture (in volume fractions) (1)
  - up to 70%	%	±6
  - from 70% to 95%	%	±15
  - over 95%	%	not standardized

• Technical specifications

• Parameter	Units of measurement	Meaning
  Measured environment		Well fluid, associated petroleum gas
  Working pressure, no more than	MPa	16.0
  Maximum number of connected wells (depending on the installation version)	pcs	24
  Characteristics of the working environment
  - temperature (1), (2)	°C	from -5 to +100
  - kinematic viscosity at a temperature of 20°C, no more than (3)	sSt	1500
  - range of well fluid density	kg/m 3	from 650 to 1300
  - maximum gas content under standard conditions (gas factor), no more than	m 3 /t	1000
  - water content in liquid (water cut, WLR)	%	from 0 to 100
  - hydrogen sulfide content, volumetric, no more than	%	25.0
  - amount of mechanical impurities, no more than	mg/l	3000
  - paraffin content in oil, volumetric, no more than	%	7.0

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