APPLICATION DECISIONS
Engineering logic for the measurement point
Define the stream before choosing a sensing principle. State whether it is liquid, gas, vapour or multiphase and identify water, solids, wax, condensate, hydrogen sulphide or other constituents relevant to materials and impulse paths. Include normal, start-up, shutdown and upset pressure and temperature. A separator level duty, compressor suction pressure and custody-related pipeline flow point are different measurement problems even when the connection size appears similar.
Installation strongly affects the result. Pressure taps can collect liquid in gas service or gas in liquid service; differential-pressure impulse lines require phase control and suitable slopes. Radar level review needs vessel and nozzle drawings, foam or vapour information and an unobstructed echo path. Flow selection needs minimum, normal and maximum rates, actual fluid properties, pipe dimensions, upstream disturbances and allowable pressure loss. Heating, insulation, vibration and outdoor exposure should be included in the layout.
Safety and evidence are configuration-specific. State the hazardous-area classification, gas or dust group, temperature class, ingress environment and any project material or traceability requirement. The requested certificate must identify a scope that covers the ordered model and options; a family photograph or another variant is not evidence. Final review should connect the proposed SKU to current drawings, pressure-temperature limits, wetted materials, output, cable entry and applicable controlled documents.
Measurement and engineering factors
- Fluid phase and composition
- Identify liquid, gas, vapour or multiphase behaviour plus density, viscosity, water, solids, wax, corrosive constituents and phase changes.
- Operating envelope
- Provide minimum, normal and maximum pressure, temperature and rate, including start-up, shutdown, vacuum, surge and depressurisation conditions.
- Mechanical installation
- Define tapping location, pipe or vessel geometry, nozzle, impulse lines, manifolds, vibration, mounting, insulation and maintenance access.
- Measurement objective
- Distinguish control, protection, allocation, inventory, condition monitoring or another duty and identify the receiving system and response needs.
- Hazard and evidence
- List area classification, environmental protection, material, calibration, drawing, inspection and traceability documents required for the selected configuration.
Application scenarios for review
- Separator or scrubber pressure and level measurement where fluid interfaces, foam, density, vessel pressure and nozzle geometry are documented.
- Pipeline or terminal monitoring where flow range, fluid properties, pressure loss, straight runs and pressure-temperature conditions are available for sizing.
- Compressor, pump and packaged utility points where pulsation, vibration, outdoor exposure, isolation and maintenance access are considered.
Limitations and confirmation points
- This page does not establish suitability for sour service, custody transfer, safety-instrumented functions or a hazardous area without configuration-specific evidence.
- Multiphase flow, changing composition, flashing, wax, solids and severe pulsation may require specialist calculations or technologies beyond a standard catalogue selection.
APPLICATION RFQ
Information to send for application review
- Measurement variable and purpose
- Fluid phase and composition
- Minimum, normal and maximum operating values
- Start-up, shutdown and upset conditions
- Pipe or vessel dimensions and connection
- Density, viscosity, solids and phase-change risks
- Wetted-material restrictions
- Power, output and control-system interface
- Hazardous-area and environmental classification
- Quantity and required evidence package
PRODUCT FAMILIES
Related measurement categories
APPLICATION FAQ
Frequently asked questions
What process data should an oil and gas instrument RFQ include?
Provide the fluid name, phase and composition; minimum, normal and maximum pressure, temperature, level or flow; density and viscosity at stated conditions; start-up, shutdown and upset cases; pipe or vessel dimensions; connection standard; wetted-material restrictions; power and output; environmental exposure; area classification; and required documents. Identify the measurement purpose and receiving system. This lets the proposal separate process suitability, mechanical limits and evidence requirements instead of relying on a generic industry label.
How should hazardous-area requirements be specified?
Use the project classification document to state zone or division, gas or dust group, temperature class, protection concept and applicable national or project standard. Add ambient limits, cable-entry method and enclosure requirements. Ask for the current certificate and schedule covering the exact model and relevant options. The website does not imply that every configuration carries the same approval, and a certificate for another enclosure, sensor or connection should not be transferred to the proposed SKU.
Can one flow-meter principle cover liquid, gas and multiphase streams?
No single principle should be assumed to cover all three. Conductivity, viscosity, density, compressibility, solids, entrained gas, pressure, temperature, velocity range and allowable pressure loss change the shortlist. Gas and steam may also need compensation inputs, while multiphase measurement can require specialised methods and interpretation. Submit actual minimum, normal and maximum conditions for sizing, then verify the proposed meter, bore, installation and calculation method in configuration-specific documents.