System Configuration

Complete units include contactor column where sour gas contacts lean amine solution absorbing acid gases, amine circulation pump, lean/rich heat exchanger recovering thermal energy, flash separator removing dissolved hydrocarbons, regenerator column stripping absorbed gases from rich amine, reboiler providing regeneration heat, reflux condenser minimizing amine losses, filtration equipment, and PLC control system. All equipment factory-assembled on structural skid with interconnecting piping, instrumentation, and electrical systems.

Process Overview

Sour gas flows upward through the contactor packed tower contacting descending lean amine. Chemical absorption removes H₂S and CO₂ producing sweet gas meeting specifications typically H₂S below 4 ppm. Rich amine circulates to regeneration where heating releases absorbed acid gases, reconcentrating the solution. Lean amine returns to the contactor completing the continuous cycle. Acid gas from regenerator overhead flows to disposal through sulfur recovery, flaring, or reinjection.

Amine Selection

MEA offers high reactivity for deep H₂S removal but requires higher regeneration energy. DEA provides balanced performance for moderate acid gas loading. MDEA selectively removes H₂S over CO₂ useful when CO₂ retention is desired. Formulated amines optimize performance for specific applications. ERGIL selects amine chemistry based on gas composition, treating objectives, and operating economics.

Capacity Range

Packaged units handle 0.5 to 50 MMSCFD gas flow with acid gas concentrations from trace levels to 30% H₂S plus CO₂. Operating pressures 50 to 1500 psig across wellhead, gathering, processing, and transmission applications. Modular designs enable capacity expansion through parallel unit installation or staged construction approaches.

Control Systems

Automated PLC control manages amine circulation rates, regeneration temperature, level controls, and safety interlocks. Instrumentation monitors acid gas concentrations, amine strength, filter differential pressure, and system performance. Remote monitoring provides operational data and diagnostic capabilities. Simplified HMI enables operator oversight with minimal training requirements.

Applications

Natural gas sweetening in production and processing facilities, refinery hydrogen purification, syngas treating in ammonia and methanol plants, biogas upgrading, sour water stripping, and any application requiring H₂S or CO₂ removal. Serves onshore and offshore installations across oil and gas, refining, petrochemical, and industrial gas sectors.

Design Standards

Equipment per ASME Section VIII pressure vessel code, API 12J for packaged units, and NACE for sour service. Materials selected for corrosive amine environments. Explosion-proof electrical systems for hazardous area classification. Complete testing and documentation including process guarantees and performance validation.

ERGIL amine sweetening units deliver reliable acid gas removal with proven technology, single-source accountability, and comprehensive support from engineering through commissioning.