Coriolis flow meters for power & utilities

The meter measures the heat carrier mass directly, from the phase shift of the oscillating tubes. The second parameter is temperature, read by the built-in Pt100 resistance thermometer. Both values go to the heat calculator, which determines the amount of heat.

At central and individual heating points (TsTP and ITP), at balance-of-ownership boundaries, in boiler houses, at TPP fuel facilities and in water treatment systems. Duties include commercial heat metering, reagent dosing and fuel measurement.

By the formula Q = m · c · (Tsupply − Treturn): mass flow multiplied by heat capacity and by the temperature difference between supply and return. The meter provides mass and temperature; the heat calculator or DCS performs the calculation, in Gcal or kWh.

Electromagnetic, ultrasonic and turbine meters measure volume, and at varying temperature the density of the heat carrier changes, adding a conversion error. Direct mass measurement removes that step — noticeable in transition seasons when the network temperature varies widely.

At large trunk-line sizes the meter costs more than volumetric options, so the economics do not always work. Steam and high temperatures require a suitable execution, and the heat carrier composition affects the choice of tube material. Selection follows the site parameters.

It does. Network water and superheated water up to 200 °C are handled by standard executions; the built-in temperature sensor provides the second parameter for heat energy calculation. High-temperature loops get a heat-resistant execution.

Yes, steam is among the typical media on this page. For gases and steam the allowable error is ±0.5–1.0%. The execution and materials follow steam pressure and temperature, which are specified in the datasheet.

Yes. Corrosion inhibitors, anti-scaling agents, flocculants and regeneration acid solutions for ion-exchange filters are liquids handled by mass measurement; for small flows the page recommends DN15–DN25 sensors with high sensitivity.

It does. Boiler fuel oil and furnace fuel are viscous media requiring heating, so an isothermal jacket holds 50–80 °C — keeping the fuel fluid and preventing waxing.

Diesel for start-up and light-up operations runs through standard executions. The data needed for selection — flow rate, temperature, pressure and required accuracy — are listed in the datasheet, which is also used to confirm materials and connections.

Make-up is a regular liquid stream; sensitivity at low flows matters, and the page's configurations note this for U sensors, including night-time regimes. The line size is selected from the flow rate and allowable pressure loss.

U sensors DN15–DN100: DN32–DN50 cover TsTP and ITP metering stations on supply and return, DN65–DN100 cover trunk-line inlets and fuel oil supply, DN15–DN25 cover reagent dosing. The geometry follows the flow rate and installation space.

For fuel oil, yes. The jacket keeps the measuring chamber at 50–80 °C so the fuel stays fluid, and protects against solidification and waxing; heating can be steam or electric.

The ME200 in the Ex version: two current outputs (mass flow and temperature), a totaliser, RS-485 Modbus RTU and HART. This configuration is intended for boiler houses and fuel facilities where hazardous-area protection is required.

It sends mass flow and temperature over digital interfaces to a third-party heat calculator, and accumulated values to the DCS or the energy accounting system. The station can be built around a standard calculator, with the meter acting as the primary element.

Flanges to GOST, ANSI and DIN, and threaded connections. The connection type, face-to-face length and mounting dimensions are fixed at the selection stage — especially important when replacing meters on an operating station.

Ready to quote once the station data arrive: medium, flow rate, pressure, temperature, line size, connection and hazardous-area class, via datasheet or configurator. The proposal covers the execution and the price; size, materials, pressure and Ex build the cost.

Heat accounting targets accuracy from ±0.1% for settlements. Liquids as a group run from ±0.1% to ±1.0% depending on size, and steam or gas service is rated at ±0.5–1.0%. Calibration on a flow calibration rig is individual for every unit.

The meter is entered under No. 98506-26, which is the basis for use in state-regulated metering: commercial heat accounting and settlements between supplier and consumer. Without measuring-instrument status such a station cannot be built.

Yes, the meter is a measuring instrument. Verification follows the approved procedure — on a flow calibration rig, or on site with provers connected to the line, without removing the sensor. The company also supplies pipe provers and compact provers.

The Pt100 sensor reads the temperature at the installation point — supply or return, depending on the mounting. The meter transmits temperature together with mass flow, so the station needs no separate temperature sensor on that pipeline.

No — straight pipe lengths upstream and downstream are not specified. In a tight heating chamber or an ITP this saves space: the meter occupies only its own seat, and the remaining installation guidance is given in the operating manual.

A typical station uses sensors on both supply and return lines; the built-in temperature sensor reads the line where the meter is installed. Orientation is flexible, and the layout and installation points are fixed per project.

Selection starts from the mounting dimensions: the seat and the station interfaces must be preserved. In many cases the replacement is done without welding; compatibility with Micro Motion and Endress+Hauser meters is checked against the piping drawing or a nameplate photo.

Via RS-485 Modbus RTU, HART and two current outputs; accumulated mass and volume are transmitted over the digital interfaces. Integration with the DCS and energy resource accounting systems (ASKUE) is a standard task.

Dust-rated zones rely on ME200, the only option carrying Ex ia tb IIIC T80 °C Db. Gas ratings run Ex ib IIC T6…T1 Gb to Ex ia IIC T6…T1 Ga on the sensor side; the matching transmitters are Ex db ib IIC T6 Gb (ME100) and Ex db ia IIC T6 Gb (ME200).

The document pack covers operation and metrology: type description, verification procedure, operating manual and EAEU (TR CU) certificates. For warranty, two terms run in parallel — 18 months from delivery, 12 months from installation — and the one finishing earlier applies.

The manufacturer: commissioning supervision, start-up, service and verification are provided on the territory of Russia. For utilities and TPPs this means service does not depend on foreign contractors.

Nothing inside the sensor wears out — no moving parts, no seals to replace on schedule. Design figures are a 20-year average service life and 100,000 hours between failures; for a metering station that means minimal operating cost.

Yes. The company builds metering skids and measuring systems, including verification equipment — pipe provers and compact provers. The scope, layout and installation requirements are defined by the project. ---