IND-01Process industry
Oil & Gas Instrumentation & Automation
Measurement, analysis and control for production, processing, storage and transfer facilities — selected for hazardous areas, integrated with the control system and supported through the asset's life.
Capability area · no project records published yet
01Wellhead & gathering
- PT-101, pressure transmitter
- TT-102, temperature transmitter
- FT-103, flow transmitter
02Separation
- LT-201, level transmitter
- PT-202, pressure transmitter
- FT-203, flow transmitter
03Compression
- PT-301, pressure transmitter
- TT-302, temperature transmitter
- FT-303, flow transmitter
04Gas treatment & dew-pointing
- AT-401, analyzer transmitter (H₂O)
- AT-402, analyzer transmitter (H₂S)
- PDT-403, differential pressure transmitter
05Storage & transfer
- LT-501, level transmitter
- TT-502, temperature transmitter
- FT-503, flow transmitter
01Process context
The process environment
Oil and gas facilities handle flammable hydrocarbons at pressures and temperatures that leave little margin for measurement error. Separation, compression, treatment, storage and transfer each depend on pressure, level, flow and temperature measurements that feed control loops, alarms and shutdown logic — and, where product changes ownership, commercial accounting.
Most instruments sit in hazardous areas, so the protection concept, cable entries and installation practice matter as much as accuracy. Sand, wax, hydrates, H₂S and changing fluid compositions complicate flow and level measurement, and gas quality often needs continuous online analysis rather than periodic sampling.
02Measurement & control points
Typical measurement and control points
General practice across oil & gas facilities, in process order: what is measured, the technology commonly used and how it reaches control. Illustrative — every plant differs.
| Process area | Parameters | Typical technology | Integration |
|---|---|---|---|
01Wellhead & gathering
|
|
| RTU or PLC at remote sites, with telemetry to central SCADA. |
02Separation
|
|
| Level and pressure control loops in PLC or DCS, with high- and low-level alarms. |
03Compression
|
|
| Packaged unit control panel linked to plant control over serial or Ethernet protocols. |
04Gas treatment & dew-pointing
|
|
| Analyzer values and health status to PLC or DCS; sample-system alarms. |
05Storage & transfer
|
|
| Tank inventory and transfer data to SCADA; metering data to accounting systems. |
01
Wellhead & gathering
- PT-101
- TT-102
- FT-103
- Parameters
- Wellhead pressure
- Flowline temperature
- Gas and liquid flow
- Typical technology
- Pressure transmitters
- Temperature transmitters in thermowells
- DP or ultrasonic flow
- Integration
- RTU or PLC at remote sites, with telemetry to central SCADA.
02
Separation
- LT-201
- PT-202
- FT-203
- Parameters
- Liquid and interface level
- Vessel pressure
- Outlet flows
- Typical technology
- Guided-wave radar or DP level
- Level switches
- Pressure transmitters
- Control valves
- Integration
- Level and pressure control loops in PLC or DCS, with high- and low-level alarms.
03
Compression
- PT-301
- TT-302
- FT-303
- Parameters
- Suction and discharge pressure
- Discharge temperature
- Compressor flow
- Typical technology
- Pressure transmitters
- RTDs or thermocouples
- DP flow elements
- Integration
- Packaged unit control panel linked to plant control over serial or Ethernet protocols.
04
Gas treatment & dew-pointing
- AT-401H₂O
- AT-402H₂S
- PDT-403
- Parameters
- Water dew point
- H₂S and CO₂ content
- Pressure drop across beds and filters
- Typical technology
- Moisture analyzers
- Gas analyzers with sample conditioning
- DP transmitters
- Integration
- Analyzer values and health status to PLC or DCS; sample-system alarms.
05
Storage & transfer
- LT-501
- TT-502
- FT-503
- Parameters
- Tank level and temperature
- Transfer flow
- Pump discharge pressure
- Typical technology
- Radar level gauges
- Multi-point temperature
- Coriolis or ultrasonic flowmeters
- Integration
- Tank inventory and transfer data to SCADA; metering data to accounting systems.
Tag key · ISA 5.1
- PT
- Pressure transmitter
- TT
- Temperature transmitter
- FT
- Flow transmitter
- LT
- Level transmitter
- AT
- Analyzer transmitter
- PDT
- Differential pressure transmitter
Loop numbers follow the process area — 1xx for area 01, 2xx for area 02 — as on a plant P&ID. The points are typical of the industry, not taken from a specific plant.
03Engineering considerations
What makes oil & gas facilities demanding
The conditions that shape instrument selection, installation and control design in this environment.
Hazardous-area classification
Instruments in classified zones need a protection concept — intrinsic safety, flameproof enclosure or another recognised method — matched to the zone, gas group and temperature class, and installed so the protection is preserved.
Remote and unattended sites
Wellpads and pipeline stations are often unmanned. Power budgets, communication links and device diagnostics decide whether a remote measurement can be trusted without a site visit.
Difficult process media
Sand, wax, hydrates and sour service affect wetted-material selection, impulse-line design and the choice of flow and level principle — often more than the measuring range does.
Commercial measurement
Where hydrocarbons change ownership, flow measurement is governed by metering standards and contract terms. Accuracy, verification and records have to be engineered in from the start.
04Capabilities
How Spaaronn's capabilities apply
Spaaronn's capability scope, read for oil & gas facilities — from individual measurements to integrated, supported systems.
- 01InstrumentationTransmitters, gauges, switches and control valves selected for area classification, pressure rating and process media; installed, calibrated and loop-checked.
- 02Industrial AutomationPLC, HMI and SCADA for process units, remote sites and packaged equipment, with sequencing and alarm handling configured to the process.
- 03Analytical SystemsMoisture and gas analyzers with sample extraction, conditioning and analyzer housings, integrated with the control system.
- 04System IntegrationPackaged-unit controllers, analyzers, RTUs and existing DCS or SCADA brought onto common networks and protocols.
- 05Turnkey ProjectsInstrumentation and control packages executed from site survey and engineering through installation, testing and commissioning.
- 06AMC & Lifecycle SupportPreventive maintenance and calibration support planned around continuous operation and turnarounds.
Typical applications
Arrangements where these capabilities commonly come together in oil & gas plants.
All applications- Process Gas AnalysisOnline analyzers with sample extraction, conditioning and control-system integration.
- Tank Level & InventoryContinuous level, point level, temperature and pressure for storage and process tanks.
- PLC & SCADA MigrationBrownfield modernization of control systems with planned cut-over and minimal disruption.
Next steps
Where to go next
Technical guides that apply to oil & gas requirements — then the conversation.
- 01AnalyticalAnalyzer Sampling & Sample Conditioning BasicsWhy most analyzer problems start in the sample system, and how to design it well.
- 02Application guidesFlow Measurement Technology SelectionElectromagnetic, vortex, Coriolis, ultrasonic, DP and thermal mass — matched to the fluid.
- 03Application guidesLevel Measurement Methods for TanksHydrostatic, DP, radar, ultrasonic, guided-wave and point-level methods compared.
- 04ActionDiscuss an Oil & Gas RequirementShare the process, the conditions and the existing control system.
Oil & Gas enquiry
Planning measurement or control for a hydrocarbon facility?
Share the process medium, operating conditions, area classification and existing control system. An engineer can help translate it into an instrumentation and integration approach.