On novel processes for removing sulphur from refinery streams
Introduction
Recent developments in environmental legislation are inexorably moving us to a world of zero-sulphur, i.e., in this respect spectroscopically pure, transportation fuels. For the time being, “zero-sulphur” means <10 ppmw S, but it is not excluded that the upper limit will in time come down even further. It is also to be noted that 10 ppmw is not de rigueur everywhere yet, but this is certainly only a question of time.
In the wake of this legislation, especially in the case of gasoline desulphurization, quite a number of novel process options have been created, or revived, both catalytic and non-catalytic ones, some of which have indeed been successfully commercialized. The subject has been ably reviewed by Babich and Moulijn [1], Song and Ma [2], [3] and – for gasoline only – Brunet et al. [4]. Since after the first flurry of novelty creation things have quieted down to a certain extent, we will not go over the field in extenso again, but try and limit ourselves to a brief overview of ongoing developments.
Even a cursory glance at the list of ideas that have been canvassed to address the zero-sulphur issues will show that most of them have not (yet?) been implemented, i.e., not progressed beyond the pilot-plant stage, if indeed they did reach that stage. This is of course to be expected in this Darwinian world. Indeed, for a given design to be commercialized, it needs to meet quite a stringent set of criteria, some of the more important of which include:
- -
Capital cost: e.g., the less unit operations (less pieces of equipment) the better, no expensive materials; preferably a single product stream for diesel.
- -
Operation cost: e.g., minimize the consumption of hydrogen or expensive chemicals, minimize the generation of waste streams (esp. dilute ones).
- -
Product volume should be high, e.g., >99%.
- -
Process cycle life should be reasonably long, e.g., four plus years in general, and five plus years for FCC gasoline post treatment units in order to match the FCC cycle length.
- -
Technical complexity should be avoided as much as possible: e.g., no difficult to operate units (minimizing down time), no difficult catalyst(s) (tolerant of upsets).
- -
Feed flexibility.
- -
Overall value to refiner.
To be a possible winner, a particular process design needs to look good on all counts, and this one can easily imagine not being a trivial matter.
The next two sections will summarize the developments in the areas of gasoline, and diesel desulphurization, respectively, where the emphasis will be on the non-catalytic routes, after which some concluding remarks will be made.
Section snippets
Gasoline desulphlurization
Of all the streams that go into the mogas (motor gasoline) pool, it is the fluid catalytic cracking (FCC) derived naphtha, which is by far the highest contributor to its sulphur content. This stream is characterized by a high olefin content, which makes it very suitable for a gasoline product with a high octane number. In the absence of severe sulphur specifications, the stream can therefore usually be directly blended into the mogas pool, after sweetening, in contrast to hydrocracker or
Diesel desulphurization
While the challenge in gasoline hydrodesulphurization is achieving a high hydrogenation selectivity of sulphur over olefin, the main issue in diesel HDS is the low reactivity of highly aromatic sulphur species. The issue has already been pointed out in the 1980's [35], [36], and nicely reviewed by Girgis and Gates [37], and the reactivity of thiophene (T), benzo-thiophene (BT) and dibenzothiophene (DBT) is shown in Table 1. The hydrodesulphurization reactivity constant k shows a decrease of
Concluding remarks
It would appear that for the time being the classical hydrotreating options and their offshoots still hold the field of transportation-fuel desulphurization. These processes are relatively simple, robust and flexible, and the corresponding catalysts are still susceptible to improvement. A lot of effort is still being spent on this latter aspect, both in industry and in academia. Nevertheless, in the gasoline area a few of the possible alternatives did achieve commercial status, e.g., S-Zorb,
Acknowledgement
Authors acknowledge Dr. Jacques Dirkx for very useful discussions.
References (126)
- et al.
Fuel
(2003) - et al.
Appl. Catal. B
(2003) Catal. Today
(2003)- et al.
Appl. Catal. A
(2005) - B.D. Alexander, G.A. Huff, V.R. Pradhan, W.J. Reagan, R.H. Cayton, BP Amoco, US...
- F. Diehl, L. Magna, B.H. Olivier, D. Uzio, French patent, FR...
- et al.
Adv. Catal.
(1998) - et al.
J. Catal.
(2005)et al.Energy Fuels
(2005) Appl. Catal. A
(2005)
Chem. Eng. Sci.
Trans. Faraday Soc.
Tetrahedron
Energy Fuels
J. Catal.
China Petro. Proc. Petr. Tech.
Energy Fuels
Energy Fuels
Commercial Octogainsm unit provides zero sulphur gasoline with higher octane from a heavy cracked naphtha feed
NPRA
Long term reliability
Hydrocarbon Eng.
Producing low sulphur gasoline reliably
NPRA
PrimeG+™ commercial performance of FCC naphtha desulphurization technology
NPRA
PTQ Autumn
Ind. Eng. Chem. Res.
Sekiyu Gakkaishi
Production of ultra-low sulphur fuels: today and tomorrow
NPRA
Continued innovation
Hydrocarbon Eng.
Ind. Eng. Chem. Res.
Adsorption process for removal of nitrogen and sulphur
PTQ Summer
Am. Chem. Soc. Fuel Chem. Div. Prepr.
Catal. Rev.
Sep. Sci. Technol.
J. Am. Chem. Soc. Commun.
Ind. Eng. Chem. Res.
A.C.S. Fuel Chem. Div. Prepr.
Appl. Catal. A
Appl. Catal. B
Ind. Eng. Chem. Res.
Profitable desulphurisation
Hydrocarbon Eng.
Cited by (320)
Selective ring-opening of polycyclic to monocyclic aromatics: A data- and technology-oriented critical review
2023, Progress in Energy and Combustion ScienceFrom gray to blue hydrogen: Trends and forecasts of catalysts and sorbents for unit process
2023, Renewable and Sustainable Energy ReviewsInvestigation of methods for fuel desulfurization wastewater treatment
2023, Chemical Engineering Research and Design