Fire and Gas Detection Across the Entire Hydrocarbon Chain

No single detection philosophy covers the whole hydrocarbon chain. A wellhead platform, a pipeline compressor station and a refinery process unit share an industry and almost nothing else — the gases differ, the ventilation differs, the manning levels differ, and so does what a missed detection actually costs. A layout copied from one segment into another will pass a drawing review and fail in service.

ZE-Tronics engineers, supplies, installs, commissions and calibrates fire and gas safety systems across all three segments, and treats each one on its own terms. We have worked in Azerbaijan’s oil and gas sector since 2012, as an authorised partner of the manufacturers whose equipment the specifications name, with our own engineering, installation and calibration capability in country.

Upstream — production and wellhead facilities

Open, naturally ventilated installations where gas disperses quickly and detector placement is governed by wind behaviour rather than by plot geometry. Point detectors alone under-perform here: a release that never crosses a sensor is a release that is never seen. The combination that works is open-path infrared across the likely dispersion corridors, backed by ultrasonic leak detection for high-pressure releases that vent to atmosphere before they can form a measurable cloud.

• Open-path infrared across process decks, wellhead areas and ventilation paths
• Ultrasonic gas leak detection — it detects the leak, not the accumulation
• Hydrogen sulphide monitoring in sour service, with fixed and personal layers
• Multi-spectrum infrared flame detection rated for offshore exposure and false-alarm immunity
• Cause-and-effect logic tied into emergency shutdown and wellhead isolation

Offshore and near-shore installations add salt, vibration and constant weather to the specification. Enclosure ratings, cable gland selection and mounting design matter as much as the sensor technology; a correctly chosen detector on a poorly engineered bracket is a maintenance problem waiting to happen.

Midstream — pipelines, compression and terminals

Long, thinly manned assets where the first responder is often a control room hundreds of kilometres away. Detection has to remain reliable without frequent attention, and the system has to communicate meaningfully rather than simply raise an alarm. Digital detector diagnostics, drift trending and historical logging turn a maintenance visit from a fixed calendar event into a decision based on evidence.

• Compressor station fire and gas detection in hazardous-area rated enclosures
• Tank farm and loading gantry vapour monitoring at grade and at the rim
• Linear heat detection along pipe racks, cable routes and conveyor structures
• Remote monitoring architecture for unmanned or lightly manned stations
• Foam and water spray systems for atmospheric and floating-roof storage tanks
• Explosion-proof beacons, sounders and voice notification sized for the area

Downstream — refining and processing

Dense process units, many simultaneous hazards, and consequences that escalate quickly from one unit to the next. Coverage assessment matters more here than anywhere else. A detector layout that looks complete on a plot plan can leave real gaps at grade level, under structures and behind large equipment — the places where a heavy hydrocarbon vapour actually collects.

• Fire and gas mapping per ISA TR84.00.07, with stated geographic and scenario coverage
• Furnace, heater and reformer flame monitoring with combustion safeguard logic
• Toxic gas detection matched to the actual process inventory, not to a generic list
• Integration with the emergency shutdown hierarchy and the plant-wide control system
• Deluge, foam and clean agent release logic with confirmed voting arrangements

Keeping detection independent — and still connected

NFPA 72, NORSOK and UK HSE guidance all point the same way: the fire and gas system should not depend on the process control system for its safety function. It must act on what it detects and then inform the control system of what it has done. What none of them prescribe is how that interface should be built. That is an engineering decision, and it is where a lot of otherwise well-specified systems become fragile.

We design the interface deliberately — hardwired for the actions that must never depend on a communication link, serial or fieldbus for the status, diagnostics and trending that make the system maintainable. The result is a safety layer that survives a control system fault and still gives operations a single, coherent picture.

Working inside a running plant

Most oil and gas work is brownfield, and the constraint is rarely technical. It is permits, isolations and the discipline of impairment planning. Every hour a detection loop is out of service is an hour of reduced protection that has to be recorded, time-bounded and compensated for by other means. We plan modifications around turnaround windows wherever the schedule allows, and we say clearly when it does not.

Calibration is not an afterthought

A gas detector that has not been calibrated is an assumption, not a measurement. Catalytic sensors drift and can be poisoned; infrared sensors need their optics verified; electrochemical cells age. Our in-house laboratory is accredited to AZS ISO/IEC 17025:2020 for both fixed and portable gas detection, so calibration is traceable rather than nominal. Our electronics repair bench handles flame, gas and smoke detectors and their controllers in country, which removes weeks of shipping from every fault.

Why operators use one integrator

Fire and gas systems fail at the handover points between vendors. A detector specified correctly at FEED, procured against the wrong certification, mounted where a dispersion study says it will never see a release, and calibrated on a schedule that ignores its own drift history is a detector that protects nobody. Owning the whole chain — design, certified supply, installation, commissioning, accredited calibration and lifecycle support — removes those seams, and with them most of the ways the system can quietly stop working.

See our full service range, or send us a plot plan and talk to our engineers.