- Low-pressure physical absorption (Laminol®) for high H₂S content.
- Typical capacity 500-10 000 Nm³/h
- Suitable to remove high levels of H₂S in streams (300+ ppm)
De-sulphurization (H₂S Removal)
Remove H₂S from process gas to protect equipment, stabilise quality and reduce OPEX
Benefits
Benefits of Laminol® in De-sulphurisation
The advantages of Laminol apply across sites regardless of sulphur concentrations, from CHPs and boilers to biogas and CO₂ capture or liquefaction lines. This solution is positioned specifically for H₂S removal with a focus on low operational cost and adaptability.
Benefit tabs
Protect downstream equipment
Stable low-ppm outlets prevent corrosion and poisoning in membranes, adsorbents, catalysts. Biogas upgraders hold recovery longer, CO₂ capture packages avoid solvent degradation and chemical synthesis steps see fewer trips.
H₂S attacks metal surfaces and deactivates membranes, adsorbents and catalysts. Holding outlet sulphur below spec prevents fouling, corrosion and solvent degradation in CO₂ capture, liquefaction and upgrading. In sustainable-fuel routes like methanol or Fischer–Tropsch, ppm-level stability preserves selectivity and keeps reactors on stream for longer campaigns.
Proven performance at scale
The system is sized to your flow and sulphur load. Typical modules handle 500 to 10 000 Nm³/h and can reduce 300+ ppm in the inlet to < 4 ppm at the outlet. These ranges are indicative; we customize outside them when the duty demands it.
For biogas plants, stable pre-treat lifts methane recovery. Active carbon polishing steps are removed, membrane upgrading systems are safe and continued performance is ensured.
Protect downstream equipment
Removing H₂S at the source cuts nuisance alarms and complaints. Defined sampling points and time-aligned logs make audits faster and link outlet quality to operating state
Built to your flow and sulphur load
Modules are sized to duty, with parallel paths for campaigns and growth. Typical projects treat 500 – 10 000 Nm³/h and drop 300+ ppm in the inlet to < 4 ppm at the outlet. Higher duties and different specs are available on request. Space, access and lifting are planned up front so any expansions gets certification quickly.
Capacity increases are modular. Add a second tank for more days of cover, add a second absorber vessel or run parallel systems to raise treatment rate, while keeping the same HMI layout, alarm classes and SOPs. Tie-in points, drains and lifting access are planned up front so new equipment is installed with short outages and minimal recertification. Documentation, spares and training stay common across modules, which keeps engineering effort low as volumes grow. The operating gains you banked at the first duty remain in place after expansion.
Stable low-ppm outlets prevent corrosion and poisoning in membranes, adsorbents, catalysts. Biogas upgraders hold recovery longer, CO₂ capture packages avoid solvent degradation and chemical synthesis steps see fewer trips.
H₂S attacks metal surfaces and deactivates membranes, adsorbents and catalysts. Holding outlet sulphur below spec prevents fouling, corrosion and solvent degradation in CO₂ capture, liquefaction and upgrading. In sustainable-fuel routes like methanol or Fischer–Tropsch, ppm-level stability preserves selectivity and keeps reactors on stream for longer campaigns.
The system is sized to your flow and sulphur load. Typical modules handle 500 to 10 000 Nm³/h and can reduce 300+ ppm in the inlet to < 4 ppm at the outlet. These ranges are indicative; we customize outside them when the duty demands it.
For biogas plants, stable pre-treat lifts methane recovery. Active carbon polishing steps are removed, membrane upgrading systems are safe and continued performance is ensured.
Removing H₂S at the source cuts nuisance alarms and complaints. Defined sampling points and time-aligned logs make audits faster and link outlet quality to operating state
Modules are sized to duty, with parallel paths for campaigns and growth. Typical projects treat 500 – 10 000 Nm³/h and drop 300+ ppm in the inlet to < 4 ppm at the outlet. Higher duties and different specs are available on request. Space, access and lifting are planned up front so any expansions gets certification quickly.
Capacity increases are modular. Add a second tank for more days of cover, add a second absorber vessel or run parallel systems to raise treatment rate, while keeping the same HMI layout, alarm classes and SOPs. Tie-in points, drains and lifting access are planned up front so new equipment is installed with short outages and minimal recertification. Documentation, spares and training stay common across modules, which keeps engineering effort low as volumes grow. The operating gains you banked at the first duty remain in place after expansion.
Unique Selling Points
Key Advantages
Quick reasons companies add de-sulphurization before capture, liquefaction, upgrading or synthesis. If these match your goals, run the fit check and we will size the system to your sulphur load and flow.
Protects assets
Stable low H2S ppm
500–10 000 Nm³/h typical scope
Retrofit ready
No activated carbon required
Client success
Real results in real workplaces
Customers use our systems to secure CO₂ supply, stabilise operating costs and recover more energy from existing assets. Explore our cases to see how similar plants solved supply risk and improved performance.
How It Works
Step-by-step
The Laminol process removes the hydrogen sulfide and follows several steps to regenerate the solvent.
Step 1
Characterization
The stream at the inlet is first characterized in its flow rate and H2S range, so to ensure the downstream Laminol equipment is fit for purpose.
Step 2
Contact and removal
A Laminol® based absorber stage is where the gas is put in contact with the solvent. As the solvent is highly selective and efficient the gas is instantly cleaned from H2S. Inline sensors check the quality of the stripped gas.
Step 3
Solid sulphur removal
Solid sulphur is removed from the rich solvent using a filter or a high capacity decanter.
Step 4
Solvent reactivation
Solvent is reactivated for re-use. With very low make-up rates and utility consumption, this results in predictable low overall OPEX.
Frequently asked questions
Need more clarity?
Below you’ll find quick answers to the questions we hear most, from feed-gas limits to maintenance routines. Expand any item for details; if you don’t see your question, our engineers are one click away.
All frequently asked questionsWe configure outlet ppm to your spec using dry polishing beds, absorbers, or a hybrid (lead-lag + polish) to keep levels steady, even during load swings. The result is a stable front-end for downstream carbon capture, CO₂ liquefaction, e-fuels production, chemical processing or biogas upgrading.
Holding a clean, dry gas protects solvents, membranes, and catalysts, extending service intervals and keeping your decarbonization solutions on-plan. Trend-based control and sampling make QA and changeouts predictable.
Sulphur corrodes equipment and poisons solvents, PSA beds, and biogas membrane elements. Upstream H₂S removal de-risks the entire train so each unit operates close to nameplate efficiency: fewer shutdowns, fewer surprises.
It’s also a cost issue: clean feed reduces solvent make-up, avoids premature media replacement, and protects cold ends in CO₂ recovery and liquefaction. Starting with sulphur control is a cornerstone of reliable industrial decarbonization.
We design for change on measured breakthrough, not on the calendar, so you only swap when you need to. Clear access, drains and sampling keep routines quick and safe.
Logs and alarms are aligned with your CMMS so planning is simple. That way, sulphur control supports, rather than distracts from, your core production goals.
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