Abstract
Abstract Over the past several years, considerable attention has been devoted to the dangers of hydrogen sulfide during different phases of the oil industry, including drilling, completion, work-over operations, processing and transportation. These dangers are well understood and have been the subject of numerous field case histories and scientific studies. On the other side, a little or almost no attention is devoted to investigate the possible positive applications of hydrogen sulfide in the oil industry as an injectant to improve oil recovery. A variety of techniques have been used to improve oil recovery from reservoirs in which there is no longer oil flow by natural forces. Water and/or gas injection(s) have been used successfully to improve the oil recovery of depleted reservoirs. The major goals of this simulation study are to investigate the feasibility of water, sour gas, and simultaneous hydrogen sulfide-water injection into oil reservoirs to improve oil recovery. Furthermore, the influences of water injection rate, hydrogen sulfide concentration and applied gas injection rate on oil recovery are studied. To achieve these purposes, a three-dimensional simulation model was developed using actual field data of an oil field in the United Arab Emirates. This simulation model was used to test the feasibility of simultaneous hydrogen sulfide-water injection to increase the oil recovery. The results indicated that injection of water, or sour gas (hydrogen sulfide), or simultaneous hydrogen sulfide-water into oil reservoir increased oil recovery. This increment in the oil recovery due to hydrogen sulfide and/or simultaneous hydrogen sulfide-water injections were attributed to higher molecular weight of hydrogen sulfide in comparison to methane and increment of reservoir potential. The increase of gas concentration and/or injection rate increased the oil recovery. The application of the suggested technique is expected to increase oil recovery and also maintain reservoir pressure.
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