TX 75083-3836, U.S.A., fax 01-972-952-9435.
AbstractMany water injectors and oil producers are damaged due to the accumulation of iron sulfide deposits near the wellbore area. For example, iron sulfide is present in water supply and injection wells as a product of sulfate reducing bacteria (SRB). Hydrochloric acid can be used to remove iron sulfide, however this process can result in the release of hydrogen sulfide, a toxic and corrosive gas. Moreover, hydrogen sulfide reacts with ferric ions and precipitates elemental sulfur. Elemental sulfur is insoluble in acids, practically impossible to dissolve, and can damage the formation. The objectives of this study are to screen hydrogen sulfide scavengers, which can be used during well stimulation, and assess the performance of the selected chemical in the field.A simple, fast procedure was developed to evaluate hydrogen sulfide scavengers. Several types of scavengers, all aldehyde-based chemicals, were examined. The concentration of hydrogen sulfide scavenger was varied from 0 to 10 wt%. Reaction temperature was kept constant at 25 °C. A simple, fast procedure was developed to screen hydrogen sulfide scavengers used during well stimulation. The efficiency of capturing hydrogen sulfide was found to be a function of scavenger type and concentration. At scavenger concentrations greater than 0.5 wt%, a polymer-like material was observed with most scavengers examined; this material adversely affected acid reaction with iron sulfide and could cause formation damage. Low sulfide concentrations were obtained in the acid returns when S-1 was added in the acid formulation.