H2S and CO2 are the most common unwanted species in natural gas. Many wells contain large concentrations of these two components. Removing H2S and CO2 is critically important for a plant for safety reasons and design requirements. As wells around the world become more sour, where possible this process has shifted from large plants to smaller units closer to the point of extraction to minimize both risk and expense. This has led to the use of many different sour gas treatment units to meet the specific demands of the location. These units take sour gas and remove the H2S and CO2 through a wide variety of techniques and produce sweet gas on the outlet. Plants rely on these units to bring the levels down to below 5 ppm H2S and under 4% CO2 for plant safety, export restrictions, and corrosion concerns.
H2S is an extremely toxic and dangerous gas. The hazards associated with the high levels of H2S found in sour gas increase the risk of each job performed in areas where it is present, leading to more expensive safety measures and more difficult working conditions. It is important to ensure that H2S is removed to within safe limits once it passes through the acid gas treatment unit and into areas that are not specifically engineered for high levels of acid gas. High levels of H2S in the gas can also lead to sulfur stress cracking in pipes and H2S and CO2 generally increase corrosion throughout the plant. This decreases the life expectancy of equipment and increases the chances for an emission incident. Depending on the levels involved and specific local requirements, exotic materials are required to handle the corrosion potential on all equipment before H2S can be confirmed to have been removed.
Sweet gas is also monitored as a specification for the final output of the process. Natural gas must meet specifications to be transported through pipelines for environmental safety, and protection of equipment. Sending off-spec gas downstream can have dramatic consequences, both in the plant and downstream of the plant. Elevated levels of H2S will affect the lifetime of piping running from the plant to the export utility, which is a substantial capital investment. Additionally, releasing off-spec gas down the process pipe results in heavy fines. The Sweet gas analysis point is the first place where this can be picked up. If off-spec gas is discovered here, the plant can divert the gas to flare, or recycle it through the scrubbers to achieve a lower sulfur level. If it makes it to the export analyzers before this happens, it is harder to divert, and will result a larger amount of gas needing to be recycled or flared off to maintain the export specifications.
The OMA system continuously measures 0-10 ppm H2S and 0-5% CO2 concentrationin the sweet gas stream. The analyzer provides real-time data on how this unit operation is functioning, allowing for seamless control of acid gas treatment units. This system pairs nicely with the export natural gas analyzer to ensure the quality of your product.
In the diagram below, the sweet gas analysis point is identified by AT2.
H2S and CO2 are measured at AT2 in the stream leaving the absorber.
Any single photodiode measurement is vulnerable to noise, signal saturation, or unexpected interference. This susceptibility to error makes a lone photodiode data point an unreliable indicator of one chemical’s absorbance.
As accepted in the lab community for decades, the best way to neutralize this type of error is to use collateral data in the form of ‘confirmation wavelengths,’ i.e. many data points at many wavelengths instead of a single wavelength:
In the figures above, each diamond represents a single photodiode and data point. The nova II registers absorbance at each integer wavelength within the 210-250 nm measurement range and produces an H2S absorbance curve. After being calibrated on a full spectrum of pure H2S, the OMA knows the absorbance-concentration correlation for each measurement wavelength; the system can average the modeled concentration value from each wavelength to completely eradicate the effect of noise at any single photodiode.
The OMA visualizes the H2S absorbance curve in this manner and knows the expected relation of each data point to the others in terms of the curve’s structure. This curve analysis enables the OMA to automatically detect erroneous results at specific wavelengths, such as when a single photodiode is saturated with light. The normal photometer, with a single data point, is completely incapable of internally verifying its measurement.
The system is built to monitor 0-10 ppm H2S and 0-5% CO2 in sweet gas. Key features for this low level H2S and CO2 application include:
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