Petroleum Refining Gas Analysis Solutions

The Claus reaction 2 H₂S + SO₂ → 3 S + 2 H₂O runs at stoichiometric optimum when H₂S and SO₂ enter the catalytic converters at a 2:1 mole ratio. Drift in either direction drops sulfur recovery efficiency — too much H₂S leaves unconverted H₂S in tail-gas (odor, health, compliance); too much SO₂ leaves unreacted SO₂ and wastes oxidation capacity. Continuous in-situ cross-stack TDLAS H₂S measurement paired with a UV-fluorescence SO₂ analyzer on the tail-gas closes this loop in real time.

Thermal-conductivity (TCD) analyzers (ZS6300-H2 class) measure bulk H₂ %vol at product-gas outlet with ppm-level detection limit and multi-decade dynamic range. TCD handles the ≈99 % purity target directly; trace-grade sub-ppm impurity measurement — relevant for fuel-cell-grade hydrogen — needs laser-based (TDLAS) or chromatography paths and sits outside the bulk TCD scope.

Under 40 CFR Part 60 Subpart Ja, yes — the flare vent-gas total-hydrocarbon measurement is a heated-line, heated-FID reference method. Cold sample paths strip heavier hydrocarbons and bias the reading low. A heated-FID total-hydrocarbon analyzer with heated extractive sampling above 180 °C, configured for the flare-header dynamic range, is the technology of record for this duty.

Yes. HF alkylation uses anhydrous HF as the catalyst and requires both process HF measurement (for catalyst loading and conversion control) and perimeter HF safety monitoring (for personnel exposure). TDLAS HF (ZS8100-HF class) with heated Monel / PFA sampling is the process technology of record; fixed HF safety sensors plus UV-DOAS are additional perimeter layers. Sulfuric alkylation does not need HF analyzers but imposes its own mist / aerosol / sulfate-tracking chemistry outside this scope.

A tail gas analyzer is the continuous analyzer on the gas leaving a Claus sulfur recovery unit (SRU) — and, where fitted, the tail-gas treating unit (TGTU) — used to trim sulfur recovery and confirm emissions compliance. It measures the residual sulfur species (H₂S, SO₂) and supporting components so SRU air demand can be controlled; the classic Claus control target is a roughly 2:1 H₂S-to-SO₂ ratio. Technology is selected by where the analyzer sits and the stream condition: in-situ cross-stack TDLAS for H₂S and pulsed UV fluorescence or UV absorption for SO₂, with in-situ optics or heated-extractive sampling chosen for stream temperature and sulfur dew point. GESHINE covers SRU feed and tail-gas H₂S / SO₂ duty within the wider refining gas analysis scope, alongside fired-heater O₂ and flare-header monitoring.

Refinery gas — the mixed fuel-gas and process off-gas from FCC units, reformers, hydrotreaters, and the gas plant — is analyzed for both combustion control and safety. Full component speciation (H₂, C1–C4 hydrocarbons, H₂S, CO) for fuel-gas heating value and balance is a process-GC duty; GESHINE’s role is the dedicated component measurements that run continuously alongside it: H₂S for treating and corrosion, O₂ for fired-heater combustion, and CO / CO₂ for efficiency. Where one delivered system must combine continuous component analysis with GC composition, that is scoped as a partner-GC integration. The refining industry solutions map these measurements unit by unit.