Cyclonic H2S Removal Using Non-Aqueous Solvents
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Solution Overview
Problem
Current methods for reducing hydrogen sulfide (H2S) levels in natural gas, such as the Amine absorption and Claus processes, are inefficient and environmentally undesirable, with the SPREX process achieving only 60-70% recovery and leaving substantial H2S in the gas stream, while larger chillers required for further recovery are costly.
Innovation Solution
A cyclonic separator system is used for H2S removal, employing a non-aqueous solvent, such as ionic liquids or sulfolane, to create a swirling motion within the separator, which enhances the separation of H2S from the gas stream, followed by a liquid separator and oxidation unit to convert H2S into sulfur and water, reducing the H2S level in the gas to ppm levels.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Manufacturing precision
If Amine absorption process is used to reduce H2S levels, then H2S recovery is achieved down to residual level of about 10 ppm, but the process requires large scale towers and subsequent Claus process reactors with high investment costs and operational costs for sulfur disposal
Solution Approach 1:
The invention extracts and removes H2S from the natural gas stream using a fractionation column and condensation process, separating it from the methane-rich gas phase. This extraction approach eliminates the need for complex Amine absorption towers and Claus process reactors, achieving H2S removal to ppm levels through physical separation rather than chemical absorption followed by thermal processing.
Solution Approach 2:
The invention converts the harmful H2S component into a beneficial byproduct stream that can be stored in existing gas reservoirs or processed separately. By condensing H2S-rich liquid and separating it from the gas phase, the process transforms a toxic contaminant into a manageable liquid stream, eliminating the need for costly sulfur disposal infrastructure while maintaining environmental compliance.
2Ease of manufacture
If SPREX fractionation process is used for H2S removal, then investment costs are reduced by avoiding large scale Amine absorption towers, but H2S recovery rate is only 60-70% leaving substantial amounts of H2S in the produced gas stream
Solution Approach 1:
The invention changes the operational parameters of the fractionation process by optimizing the condensation temperature and pressure conditions to maximize H2S recovery. By adjusting these parameters, the process achieves higher H2S recovery rates while maintaining cost-effectiveness, overcoming the limitation of the standard SPREX process that leaves substantial H2S in the produced gas stream.
3Productivity
If larger chillers are used to increase H2S recovery in SPREX process, then H2S recovery rate increases, but incremental investment cost of larger chillers outweighs the incremental savings from smaller amine and Claus plants
Solution Approach 1:
The invention replaces the mechanical chiller system with a fractionation column and condensation process that achieves H2S separation through phase change and density differences. This substitution eliminates the need for energy-intensive cooling equipment while maintaining effective H2S recovery, avoiding the escalating investment costs associated with larger chillers.
Applied Scientific Principles
This section explains which scientific principles are used to turn an abstract innovation direction into a practical engineering solution.
Function Achieved in This Case
The system effectively reduces H2S levels in natural gas to low concentrations, minimizing the need for post-treatment processes and allowing for sub-terrestrial storage of H2S and sulfur, thereby reducing operational costs and system complexity.
Implementation Method 1
A cyclonic separator system is used for H2S removal, employing a non-aqueous solvent, such as ionic liquids or sulfolane, to create a swirling motion within the separator
Implementation Method 2
employing a non-aqueous solvent, such as ionic liquids or sulfolane, to create a swirling motion within the separator, which enhances the separation of H2S from the gas stream
Implementation Method 3
employing a non-aqueous solvent, such as ionic liquids or sulfolane, to create a swirling motion within the separator, which enhances the separation of H2S from the gas stream
Implementation Method 4
followed by a liquid separator and oxidation unit to convert H2S into sulfur and water
Data Source
AI summary
A refining system for refining a feed gas comprising hydrocarbons and hydrogen sulfide having a first concentration of hydrogen sulfide including a first part for producing a stream of a first processed feed gas, and a second part for producing a second stream of a second processed feed gas from the stream of the first processed feed gas using a separation process for H2S removal.