Raw natural gas contains hydrogen suflide, the level of which varies by field. Due to its toxicity, flammability, and corrosivity, H2S is an extremely important component to control at all stages of natural gas handling, from wellhead to the customer. The destructive effects of H2S on equipment and pipelines along with the constant threat to personnel safety justify major investment in H2S measurement technology.
The OMA H2S Analyzer is a highly field-proven solution for fast-response H2S measurement in several natural gas applications. Due to excellent accuracy and dynamic range, the OMA is the analyzer of choice both for high-level (e.g. wellhead gas) and low-level (e.g. sales gas pipeline) H2S ranges.
Older technologies like GC and paper tape are being phased out due to the superior performance and ease of photometric H2S analyzers. The OMA provides fast response measurement with less downtime than these alternatives for more effective control in a natural gas process. When compared against competing photometers, the OMA provides more accurate measurement at a wider concentration range due to the dispersive "full-spectrum" acquisition at high resolution.
The best way to ensure H2S scrubbing efficiency of the amine treating is to measure H2S in the outlet gas of the scrubber, particularly in conjunction with lean amine / rich amine analysis for optimization of the amine regenerator. H2S measurement in the raw gas (wellhead gas) determines how much processing a particular feedstock requires for adequate H2S removal, and the measurement point in the scrubber outlet gas indicates if the scrubber has performed within specification.
OMA H2S Analyzers provide a full-featured suite of solutions for total amine scrubber control, including monitoring the scrubber inlet gas, outlet gas, lean (fresh) amine, and rich (saturated) amine. With low cost of ownership and automated performance for unattended operation, these analyzers lead to significant savings on amine scrubber operation and power costs. Excellent accuracy at low ppm concentrations make OMA the natural choice for measuring H2S breakthrough in a scrubber outlet or downstream from any removal system.
At the point where natural gas is transferred from one operator to another, e.g. from a producer to a regional distributor, a custody transfer station carefully manages the metered transmission of the gas stream. Since H2S loading is an important parameter in sales gas quality, both operators implement an H2S measurement method in order to verify and cross-reference the H2S loading for smooth assurance of purchase specifications.
Deploying the OMA H2S in Natural Gas Analyzers simplifies the custody transfer operation by automating the H2S validation procedure. Compared to alternative high-maintenance methods, the OMA provides reliable set-and-forget H2S measurement after a one-time calibration. Utilizing mirror OMA units on each side of a custody transfer station allows real-time cross-referencing and redundant H2S readings for additional confirmation of proper analyzer operation.
The pipelines used to transport processed natural gas (sales gas) to customers are susceptible to severe corrosion damage when H2S in the gas stream frees the iron content from the steel pipe interior surface. The most proactive method of preventing this dangerous and expensive pipeline damage is to continuously measure H2S concentration in the sales gas pipeline and ensure that the level does not exceed a set threshold of concern.
The OMA H2S in Natural Gas Analyzer provides proven reliable H2S monitoring in distribution pipelines with configurable alarms for the problematic concentration range. Real-time analysis along with rich trend data allows for optimal expenditure of H2S removal resources (e.g. scavengers) and rapid response to upset conditions. With excellent accuracy at low ppm ranges, the OMA provides an ideal sales gas quality & H2S safety assurance solution.
The wellhead is responsible for handling the raw natural gas extraction out of the underground formation while preventing gas leaks or blowouts due to gas pressure. The wellhead gas is subsequently sent to some form of H2S removal system (usually amine srubbers or scavenger beds). It is critical to continuously measure the H2S concentration in the wellhead extracted gas stream because H2S loading can range widely (typically 0-5%) and must be measured in order to properly operate the removal system according to the feed gas composition. Since the wellhead must operate reliably (often in remote locations) while handling up to 20,000 psi pressure, a reliable gas analyzer should be installed on the raw gas line to detect corrosion risks.
The OMA H2S in Natural Gas Analyzer is perfectly suited for wellhead gas monitoring because (1) the system sustains accuracy even when H2S concentration fluctuates rapidly with wide swings, (2) the system is automated for reliable unattended operation in remote environments, and (3) the system can analyze the high-pressure sample directly with flow cell rated up to 3000 psi and no sensitivity to moisture in the UV-Vis wavelength domain.