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This paper summarizes results of a joint industry program (JIP) to address ammonium bisulfide (NH 4 HS) corrosion in H 2 S-dominated alkaline sour waters typically found in refinery services such as the reactor effluent air cooler (REAC) systems of hydroprocessing units.
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This Phase II work in NH3-dominated sour waters studied the impact of several process variables including NH4HS concentration, NH3 partial pressure, H2S partial pressure, temperature, cyanide concentration, and velocity (wall shear stress).
In this paper the charging procedure will be demonstrated. Two case histories will be shown including autoclave telemetry data (pressure and temperature) and pressure measurements taken at temperature.
Traditionally, sour severity of high-pressure, high temperature (HPHT) oil and gas production wells were assessed by H2S partial pressure (PH2S): The mole fraction of H2S in the gas (yH2S) multiplied by the total pressure (PT). While PH2S is appropriate for characterizing the sour severity of wellbores operating at low total pressures (e.g., PT < 35 MPa) and/or for highly sour systems (e.g., yH2S > 1 mol%), PH2S usually over-predicts the actual sour severity of HPHT systems, leading to sub-optimal material selection options.