Catalytic reforming is a chemical process used to convert petroleum refinery naphthas distilled from crude oil (typically having low octane ratings) into high-octane liquid products called reformates, which are premium blending stocks for high-octane gasoline. The process converts low-octane linear hydrocarbons (paraffins) into branched alkanes (isoparaffins) and cyclic naphthenes, which are then partially dehydrogenated to produce high-octane aromatic hydrocarbons. The dehydrogenation also produces significant amounts of byproduct hydrogen gas, which is fed into other refinery processes such as hydrocracking. A side reaction is hydrogenolysis, which produces light hydrocarbons of lower value, such as methane, ethane, propane and butanes.

Continuous Catalytic reforming (CCR) unit

In addition to a gasoline blending stock, reformate is the main source of aromatic bulk chemicals such as benzene, toluene, xylene and ethylbenzene which have diverse uses, most importantly as raw materials for conversion into plastics. However, the benzene content of reformate makes it carcinogenic, which has led to governmental regulations effectively requiring further processing to reduce its benzene content.

This process is quite different from and not to be confused with the catalytic steam reforming process used industrially to produce products such as hydrogen, ammonia, and methanol from natural gas, naphtha or other petroleum-derived feedstocks. Nor is this process to be confused with various other catalytic reforming processes that use methanol or biomass-derived feedstocks to produce hydrogen for fuel cells or other uses.

These are the two main classes into which the catalysts utilised for the reforming processes fall.

  1. Supported noble metals
  2. non-noble transition metal
CCR
Continuous Catalytic Reforming / platforming

The best catalyst for the synthesis of syngas utilising various procedures has been the subject of several research. Rhodium,[1][2] ruthenium,[3][4] and platinum,[5][6] as well as palladium[7] and iridium[8] catalysts, have all been the subject of in-depth study on hydrogen production, catalytic thermal decomposition, and dry reforming catalysts.[9] Noble metals-based catalysts are much more effective and often less susceptible to deactivation by carbon production or oxidation, but because they are more expensive (costing 100–150 times more than nickel catalysts), they are less frequently used.[10] In industrial uses, catalysts depending on nickel are increasingly often utilised. However, due to carbon accumulation, their resilience is low. The most crucial issue for methane reforming, particularly in dry reforming, is the suppression of carbon deposition for non-noble metal catalysts. Increasing the surface basicity of catalysts and regulating the particle sizes of active ingredients are two techniques used to prevent carbon from depositing. The improvement of metal-support interaction, the creation of solid solutions, and plasma processes are only a few of the strategies that have been developed to manage the metal particle sizes. The surface basicity of catalysts was increased by using basic metal oxides as a support or promoter. Increased catalysts and processes as a consequence of the work of several authors have improved overall efficiency and environmental performance.[11][12]

History

In the 1940s, Vladimir Haensel,[13] a research chemist working for Universal Oil Products (UOP), developed a catalytic reforming process using a catalyst containing platinum. Haensel's process was subsequently commercialized by UOP in 1949 for producing a high octane gasoline from low octane naphthas and the UOP process become known as the Platforming process.[14] The first Platforming unit was built in 1949 at the refinery of the Old Dutch Refining Company in Muskegon, Michigan.

In the years since then, many other versions of the process have been developed by some of the major oil companies and other organizations. Today, the large majority of gasoline produced worldwide is derived from the catalytic reforming process.

To name a few of the other catalytic reforming versions that were developed, all of which utilized a platinum and/or a rhenium catalyst:

Chemistry

Before describing the reaction chemistry of the catalytic reforming process as used in petroleum refineries, the typical naphthas used as catalytic reforming feedstocks will be discussed.

Typical naphtha feedstocks

A petroleum refinery includes many unit operations and unit processes. The first unit operation in a refinery is the continuous distillation of the petroleum crude oil being refined. The overhead liquid distillate is called naphtha and will become a major component of the refinery's gasoline (petrol) product after it is further processed through a catalytic hydrodesulfurizer to remove sulfur-containing hydrocarbons and a catalytic reformer to reform its hydrocarbon molecules into more complex molecules with a higher octane rating value. The naphtha is a mixture of very many different hydrocarbon compounds. It has an initial boiling point of about 35 °C and a final boiling point of about 200 °C, and it contains paraffin, naphthene (cyclic paraffins) and aromatic hydrocarbons ranging from those containing 6 carbon atoms to those containing about 10 or 11 carbon atoms.

The naphtha from the crude oil distillation is often further distilled to produce a "light" naphtha containing most (but not all) of the hydrocarbons with 6 or fewer carbon atoms and a "heavy" naphtha containing most (but not all) of the hydrocarbons with more than 6 carbon atoms. The heavy naphtha has an initial boiling point of about 140 to 150 °C and a final boiling point of about 190 to 205 °C. The naphthas derived from the distillation of crude oils are referred to as "straight-run" naphthas.

It is the straight-run heavy naphtha that is usually processed in a catalytic reformer because the light naphtha has molecules with 6 or fewer carbon atoms which, when reformed, tend to crack into butane and lower molecular weight hydrocarbons which are not useful as high-octane gasoline blending components. Also, the molecules with 6 carbon atoms tend to form aromatics which is undesirable because governmental environmental regulations in a number of countries limit the amount of aromatics (most particularly benzene) that gasoline may contain.[15][16][17]

There are a great many petroleum crude oil sources worldwide and each crude oil has its own unique composition or "assay". Also, not all refineries process the same crude oils and each refinery produces its own straight-run naphthas with their own unique initial and final boiling points. In other words, naphtha is a generic term rather than a specific term.

The table just below lists some fairly typical straight-run heavy naphtha feedstocks, available for catalytic reforming, derived from various crude oils. It can be seen that they differ significantly in their content of paraffins, naphthenes and aromatics:

Typical Heavy Naphtha Feedstocks
Crude oil name
Location 		Barrow Island
Australia[18]		 Mutineer-Exeter
Australia[19]		 CPC Blend
Kazakhstan[20]		 Draugen
North Sea[21]
Initial boiling point, °C149140149150
Final boiling point, °C204190204180
Paraffins, liquid volume %46625738
Naphthenes, liquid volume %42322745
Aromatics, liquid volume %1261617

Some refinery naphthas include olefinic hydrocarbons, such as naphthas derived from the fluid catalytic cracking and coking processes used in many refineries. Some refineries may also desulfurize and catalytically reform those naphthas. However, for the most part, catalytic reforming is mainly used on the straight-run heavy naphthas, such as those in the above table, derived from the distillation of crude oils.

The reaction chemistry

There are many chemical reactions that occur in the catalytic reforming process, all of which occur in the presence of a catalyst and a high partial pressure of hydrogen. Depending upon the type or version of catalytic reforming used as well as the desired reaction severity, the reaction conditions range from temperatures of about 495 to 525 °C and from pressures of about 5 to 45 atm.[22][23]

The commonly used catalytic reforming catalysts contain noble metals such as platinum and/or rhenium, which are very susceptible to poisoning by sulfur and nitrogen compounds. Therefore, the naphtha feedstock to a catalytic reformer is always pre-processed in a hydrodesulfurization unit which removes both the sulfur and the nitrogen compounds. Most catalysts require both sulphur and nitrogen content to be lower than 1 ppm.

The four major catalytic reforming reactions are:[24]

1: The dehydrogenation of naphthenes to convert them into aromatics as exemplified in the conversion methylcyclohexane (a naphthene) to toluene (an aromatic), as shown below:
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2: The isomerization of normal paraffins to isoparaffins as exemplified in the conversion of normal octane to 2,5-Dimethylhexane (an isoparaffin), as shown below:
3: The dehydrogenation and aromatization of paraffins to aromatics (commonly called dehydrocyclization) as exemplified in the conversion of normal heptane to toluene, as shown below:
4: The hydrocracking of paraffins into smaller molecules as exemplified by the cracking of normal heptane into isopentane and ethane, as shown below:

During the reforming reactions, the carbon number of the reactants remains unchanged, except for hydrocracking reactions which break down the hydrocarbon molecule into molecules with fewer carbon atoms.[23] The hydrocracking of paraffins is the only one of the above four major reforming reactions that consumes hydrogen. The isomerization of normal paraffins does not consume or produce hydrogen. However, both the dehydrogenation of naphthenes and the dehydrocyclization of paraffins produce hydrogen. The overall net production of hydrogen in the catalytic reforming of petroleum naphthas ranges from about 50 to 200 cubic meters of hydrogen gas (at 0 °C and 1 atm) per cubic meter of liquid naphtha feedstock. In the United States customary units, that is equivalent to 300 to 1200 cubic feet of hydrogen gas (at 60 °F and 1 atm) per barrel of liquid naphtha feedstock.[25] In many petroleum refineries, the net hydrogen produced in catalytic reforming supplies a significant part of the hydrogen used elsewhere in the refinery (for example, in hydrodesulfurization processes). The hydrogen is also necessary in order to hydrogenolyze any polymers that form on the catalyst.

In practice, the higher the content of naphthenes in the naphtha feedstock, the better will be the quality of the reformate and the higher the production of hydrogen. Crude oils containing the best naphtha for reforming are typically from Western Africa or the North Sea, such as Bonny light oil or Norwegian Troll.

Model reactions using lumping technique

Owing to too many components in catalytic reforming process feedstock, untraceable reactions and the high temperature range, the design and simulation of catalytic reformer reactors is accompanied by complexities. The lumping technique is used extensively for reducing complexities so that the lumps and reaction pathways that properly describe the reforming system and kinetic rate parameters do not depend on feedstock composition.[23] In one of the recent works, naphtha is considered in terms of 17 hydrocarbon fractions with 15 reactions in which C1 to C5 hydrocarbons are specified as light paraffins and the C6 to C8+ naphtha cuts are characterized as isoparaffins, normal paraffins, naphthenes and aromatics.[23] Reactions in catalytic naphtha reforming are elementary and Hougen-Watson Langmuir-Hinshelwood type reaction rate expressions are used to describe the rate of each reaction. Rate equations of this type explicitly account for the interaction of chemical species with catalyst and contain denominators in which terms characteristic of the adsorption of reacting species are presented.[23]

Process description

The most commonly used type of catalytic reforming unit has three reactors, each with a fixed bed of catalyst, and all of the catalyst is regenerated in situ during routine catalyst regeneration shutdowns which occur approximately once each 6 to 24 months. Such a unit is referred to as a semi-regenerative catalytic reformer (SRR).

Some catalytic reforming units have an extra spare or swing reactor and each reactor can be individually isolated so that any one reactor can be undergoing in situ regeneration while the other reactors are in operation. When that reactor is regenerated, it replaces another reactor which, in turn, is isolated so that it can then be regenerated. Such units, referred to as cyclic catalytic reformers, are not very common. Cyclic catalytic reformers serve to extend the period between required shutdowns.

The latest and most modern type of catalytic reformers are called continuous catalyst regeneration (CCR) reformers. Such units are defined by continuous in-situ regeneration of part of the catalyst in a special regenerator, and by continuous addition of the regenerated catalyst to the operating reactors. As of 2006, two CCR versions available: UOP's CCR Platformer process[26] and Axens' Octanizing process.[27] The installation and use of CCR units is rapidly increasing.

Many of the earliest catalytic reforming units (in the 1950s and 1960s) were non-regenerative in that they did not perform in situ catalyst regeneration. Instead, when needed, the aged catalyst was replaced by fresh catalyst and the aged catalyst was shipped to catalyst manufacturers to be either regenerated or to recover the platinum content of the aged catalyst. Very few, if any, catalytic reformers currently in operation are non-regenerative.

The process flow diagram below depicts a typical semi-regenerative catalytic reforming unit.

Schematic diagram of a typical semi-regenerative catalytic reformer unit in a petroleum refinery

The liquid feed (at the bottom left in the diagram) is pumped up to the reaction pressure (5–45 atm) and is joined by a stream of hydrogen-rich recycle gas. The resulting liquid–gas mixture is preheated by flowing through a heat exchanger. The preheated feed mixture is then totally vaporized and heated to the reaction temperature (495–520 °C) before the vaporized reactants enter the first reactor. As the vaporized reactants flow through the fixed bed of catalyst in the reactor, the major reaction is the dehydrogenation of naphthenes to aromatics (as described earlier herein) which is highly endothermic and results in a large temperature decrease between the inlet and outlet of the reactor. To maintain the required reaction temperature and the rate of reaction, the vaporized stream is reheated in the second fired heater before it flows through the second reactor. The temperature again decreases across the second reactor and the vaporized stream must again be reheated in the third fired heater before it flows through the third reactor. As the vaporized stream proceeds through the three reactors, the reaction rates decrease and the reactors therefore become larger. At the same time, the amount of reheat required between the reactors becomes smaller. Usually, three reactors are all that is required to provide the desired performance of the catalytic reforming unit.

Some installations use three separate fired heaters as shown in the schematic diagram and some installations use a single fired heater with three separate heating coils.

The hot reaction products from the third reactor are partially cooled by flowing through the heat exchanger where the feed to the first reactor is preheated and then flow through a water-cooled heat exchanger before flowing through the pressure controller (PC) into the gas separator.

Most of the hydrogen-rich gas from the gas separator vessel returns to the suction of the recycle hydrogen gas compressor and the net production of hydrogen-rich gas from the reforming reactions is exported for use in the other refinery processes that consume hydrogen (such as hydrodesulfurization units and/or a hydrocracker unit).

The liquid from the gas separator vessel is routed into a fractionating column commonly called a stabilizer. The overhead offgas product from the stabilizer contains the byproduct methane, ethane, propane and butane gases produced by the hydrocracking reactions as explained in the above discussion of the reaction chemistry of a catalytic reformer, and it may also contain some small amount of hydrogen. That offgas is routed to the refinery's central gas processing plant for removal and recovery of propane and butane. The residual gas after such processing becomes part of the refinery's fuel gas system.

The bottoms product from the stabilizer is the high-octane liquid reformate that will become a component of the refinery's product gasoline. Reformate can be blended directly in the gasoline pool but often it is separated in two or more streams. A common refining scheme consists in fractionating the reformate in two streams, light and heavy reformate. The light reformate has lower octane and can be used as isomerization feedstock if this unit is available. The heavy reformate is high in octane and low in benzene, hence it is an excellent blending component for the gasoline pool.

Benzene is often removed with a specific operation to reduce the content of benzene in the reformate as the finished gasoline has often an upper limit of benzene content (in the UE this is 1% volume). The benzene extracted can be marketed as feedstock for the chemical industry.

Catalysts and mechanisms

Most catalytic reforming catalysts contain platinum or rhenium on a silica or silica-alumina support base, and some contain both platinum and rhenium. Fresh catalyst is chlorided (chlorinated) prior to use.

The noble metals (platinum and rhenium) are considered to be catalytic sites for the dehydrogenation reactions and the chlorinated alumina provides the acid sites needed for isomerization, cyclization and hydrocracking reactions.[24] The biggest care has to be exercised during the chlorination. Indeed, if not chlorinated (or insufficiently chlorinated) the platinum and rhenium in the catalyst would be reduced almost immediately to metallic state by the hydrogen in the vapour phase. On the other hand, an excessive chlorination could depress excessively the activity of the catalyst.

The activity (i.e., effectiveness) of the catalyst in a semi-regenerative catalytic reformer is reduced over time during operation by carbonaceous coke deposition and chloride loss. The activity of the catalyst can be periodically regenerated or restored by in situ high temperature oxidation of the coke followed by chlorination. As stated earlier herein, semi-regenerative catalytic reformers are regenerated about once per 6 to 24 months. The higher the severity of the reacting conditions (temperature), the higher the octane of the produced reformate but also the shorter the duration of the cycle between two regenerations. Catalyst's cycle duration is also very dependent on the quality of the feedstock. However, independently of the crude oil used in the refinery, all catalysts require a maximum final boiling point of the naphtha feedstock of 180 °C.

Normally, the catalyst can be regenerated perhaps 3 or 4 times before it must be returned to the manufacturer for reclamation of the valuable platinum and/or rhenium content.[24]

Weaknesses and Competition

The sensitivity of catalytic reforming to contamination by sulfur and nitrogen requires hydrotreating the naphtha before it enters the reformer, adding to the cost and complexity of the process. Dehydrogenation, an important component of reforming, is a strongly endothermic reaction, and as such, requires the reactor vessel to be externally heated. This contributes both to costs and the emissions of the process. Catalytic reforming has a limited ability to process naphthas with a high content of normal paraffins, e.g. naphthas from the gas-to-liquids (GTL) units. The reformate has a much higher content of benzene than is permissible by the current regulations in many countries. This means that the reformate should either be further processed in an aromatics extraction unit, or blended with appropriate hydrocarbon streams with low content of aromatics. Catalytic reforming requires a whole range of other processing units at the refinery (apart from the distillation tower, a naphtha hydrotreater, usually an isomerization unit to process light naphtha, an aromatics extraction unit, etc.) which puts it out of reach for smaller (micro-)refineries.

Main licensors of catalytic reforming processes, UOP and Axens, constantly work on improving the catalysts, but the rate of improvement seems to be reaching its physical limits. This is driving the emergence of new technologies to process naphtha into gasoline by companies like Chevron Phillips Chemical (Aromax [28]) and NGT Synthesis (Methaforming,[28][29]).

Economics

Catalytic reformation is profitable in that it converts long-chain hydrocarbons, for which there is limited demand despite high supply, into short-chained hydrocarbons, which, due to their uses in petrol fuel, are in much greater demand. It can also be used to improve the octane rating of short-chained hydrocarbons by aromatizing them.[30]

References

  1. ↑ Horn, R; Williams, K; Degenstein, N; Schmidt, L (2006-08-15). "Syngas by catalytic partial oxidation of methane on rhodium: Mechanistic conclusions from spatially resolved measurements and numerical simulations". Journal of Catalysis. 242 (1): 92–102. doi:10.1016/j.jcat.2006.05.008.
  2. ↑ Salazar-Villalpando, Maria D.; Miller, Adam C. (March 2011). "Catalytic partial oxidation of methane and isotopic oxygen exchange reactions over 18O labeled Rh/Gadolinium doped ceria". International Journal of Hydrogen Energy. 36 (6): 3880–3885. doi:10.1016/j.ijhydene.2010.11.040.
  3. ↑ Ishihara, A; Qian, E; Finahari, I; Sutrisna, I; Kabe, T (2005-04-27). "Addition effect of ruthenium on nickel steam reforming catalysts". Fuel. 84 (12): 1462–1468. doi:10.1016/j.fuel.2005.03.006.
  4. ↑ Shamsi, Abolghasem (January 2009). "Partial oxidation of methane and the effect of sulfur on catalytic activity and selectivity". Catalysis Today. 139 (4): 268–273. doi:10.1016/j.cattod.2008.03.033.
  5. ↑ Souza, Mariana M.V.M.; Macedo Neto, Octávio R.; Schmal, Martin (March 2006). "Synthesis Gas Production from Natural Gas on Supported Pt Catalysts". Journal of Natural Gas Chemistry. 15 (1): 21–27. doi:10.1016/S1003-9953(06)60003-0.
  6. ↑ Salazar-Villalpando, Maria D.; Miller, Adam C. (January 2011). "Hydrogen production by methane decomposition and catalytic partial oxidation of methane over Pt/CexGd1−xO2 and Pt/CexZr1−xO2". Chemical Engineering Journal. 166 (2): 738–743. doi:10.1016/j.cej.2010.11.076.
  7. ↑ Ryu, J; Lee, K; Kim, H; Yang, J; Jung, H (2008-05-08). "Promotion of palladium-based catalysts on metal monolith for partial oxidation of methane to syngas". Applied Catalysis B: Environmental. 80 (3–4): 306–312. doi:10.1016/j.apcatb.2007.10.010.
  8. ↑ Richardson, J.T.; Paripatyadar, S.A. (May 1990). "Carbon dioxide reforming of methane with supported rhodium". Applied Catalysis. 61 (1): 293–309. doi:10.1016/S0166-9834(00)82152-1.
  9. ↑ Barbero, J. (2003). "Support Effect in Supported Ni Catalysts on Their Performance for Methane Partial Oxidation". Catalysis Letters. 87 (3/4): 211–218. doi:10.1023/A:1023407609626. S2CID 91889442.
  10. ↑ Zeppieri, M.; Villa, P.L.; Verdone, N.; Scarsella, M.; De Filippis, P. (2010-10-20). "Kinetic of methane steam reforming reaction over nickel- and rhodium-based catalysts". Applied Catalysis A: General. 387 (1–2): 147–154. doi:10.1016/j.apcata.2010.08.017. ISSN 0926-860X.
  11. ↑ Ertl, Gerhard; Knözinger, Helmut; Schüth, Ferdi; Weitkamp, Jens, eds. (2008-03-15). Handbook of Heterogeneous Catalysis: Online. Weinheim, Germany: Wiley-VCH Verlag GmbH & Co. KGaA. doi:10.1002/9783527610044. ISBN 978-3-527-31241-2.
  12. ↑ Molenbroek, Alfons M.; Helveg, Stig; Topsøe, Henrik; Clausen, Bjerne S. (September 2009). "Nano-Particles in Heterogeneous Catalysis". Topics in Catalysis. 52 (10): 1303–1311. doi:10.1007/s11244-009-9314-1. ISSN 1022-5528. S2CID 95513283.
  13. ↑ A Biographical Memoir of Vladimir Haensel written by Stanley Gembiki, published by the National Academy of Sciences in . 2006.
  14. ↑ Platforming described on UOP's website Archived December 30, 2006, at the Wayback Machine
  15. ↑ Canadian regulations on benzene in gasoline Archived 2004-10-12 at the Wayback Machine
  16. ↑ United Kingdom regulations on benzene in gasoline Archived November 23, 2006, at the Wayback Machine
  17. ↑ "EPA Seeks Less Benzene In Gasoline". The Washington Post. Archived from the original on 2018-12-20.
  18. ↑ "Barrow Island crude oil assay" (PDF). Archived from the original (PDF) on 2008-03-09. Retrieved 2006-12-16.
  19. ↑ "Mutineer-Exeter crude oil assay" (PDF). Archived from the original (PDF) on 2008-03-09. Retrieved 2006-12-16.
  20. ↑ CPC Blend crude oil assay
  21. ↑ Draugen crude oil assay Archived November 28, 2007, at the Wayback Machine
  22. ↑ OSHA Technical Manual, Section IV, Chapter 2, Petroleum refining Processes (A publication of the Occupational Safety and Health Administration)
  23. 1 2 3 4 5 Arani, H. M.; Shirvani, M.; Safdarian, K.; Dorostkar, E. (December 2009). "Lumping procedure for a kinetic model of catalytic naphtha reforming". Brazilian Journal of Chemical Engineering. 26 (4): 723–732. doi:10.1590/S0104-66322009000400011. ISSN 0104-6632.
  24. 1 2 3 Gary, J.H.; Handwerk, G.E. (1984). Petroleum Refining Technology and Economics (2nd ed.). Marcel Dekker, Inc. ISBN 0-8247-7150-8.
  25. ↑ US Patent 5011805, Dehydrogenation, dehydrocyclization and reforming catalyst (Inventor: Ralph Dessau, Assignee: Mobil Oil Corporation)
  26. ↑ "CCR Platforming" (PDF). uop.com. 2004. Archived from the original (PDF) on November 9, 2006.
  27. ↑ Octanizing Options Archived 2008-03-09 at the Wayback Machine (Axens website)
  28. 1 2 "Archived copy" (PDF). Archived from the original (PDF) on 2018-04-08. Retrieved 2018-04-08.{{cite web}}: CS1 maint: archived copy as title (link)
  29. ↑ "Leading Industry magazine "Hydrocarbon Processing" acknowledges NGTS' innovation process".
  30. ↑ Lichtarowicz, Marek. "Cracking and related refinery". Retrieved 2017-12-03.
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