A comparison of the UCB sulfur recovery process with conventional sulfur recovery technology for treating recycle gas from a crude oil residuum hydrotreater | Zendy

Lynn Scot | Zendy; Neumann Dan W. | Zendy; Sciamanna Steven F. | Zendy; Vorhis Frederick H. | Zendy

Open Access

A comparison of the UCB sulfur recovery process with conventional sulfur recovery technology for treating recycle gas from a crude oil residuum hydrotreater

Author(s) -

Lynn Scot,

Neumann Dan W.,

Sciamanna Steven F.,

Vorhis Frederick H.

Publication year - 1987

Publication title -

environmental progress

Language(s) - English

Resource type - Journals

eISSN - 1547-5921

pISSN - 0278-4491

DOI - 10.1002/ep.670060413

Subject(s) - residuum , sulfur , sour gas , claus process , natural gas processing , capital cost , waste management , amine gas treating , process engineering , petroleum , flue gas desulfurization , natural gas , petroleum engineering , chemistry , environmental science , engineering , environmental engineering , hydrogen sulfide , electrical engineering , organic chemistry , soil science

In this paper the University of California, Berkeley, Sulfur Recovery Process (UCBSRP) is compared to conventional technology for the case of the removal of H 2 S from the recycle gas of a high‐pressure petroleum residuum hydrotreater. The conventional technology selected for this comparison consists of an absorber/stripper operation using diethanol amine as the absorbent, a Claus sulfur plant, and a SCOTT tail‐gas treating unit. Flowsheets, stream flows and conditions, and the total purchased cost of the major items of equipment are presented for both processes. From this comparison it is estimated that the direct fixed capital (DFC) for the UCBSRP would be about 61% of that for the conventional technology. The utility costs for this application of the UCBSRP are estimated to be less than the credit for the high‐pressure steam produced whereas the utility costs for the conventional process are substantially more.

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