Patent Application
20090111900
This invention related to a process for converting carbon monoxide and hydrogen to liquid motor fuels and/or waxes, and in particular a low pressure process using a particular catalyst on a defined substrate.
The Fischer-Tropsch (FT) process for converting carbon monoxide and hydrogen to liquid motor fuels and/or wax has been known since the 1920's.
During the Second World War synthetic diesel was manufactured in Germany using coal gasification to supply a 1:1 ratio of hydrogen and carbon monoxide for conversion to fuel hydrocarbons. Because of trade sanctions and the paucity of natural gas, South Africa further developed the coal via gasification route to synthesis gas and employed a fixed-bed iron Fischer-Tropsch catalyst. Iron catalysts are very active for the water-gas shift reaction which moves the gas composition from a deficiency of hydrogen and closer to the optimum H2/CO ratio of around 2.0. When large natural gas supplies were developed, steam and autothermal reformers were employed to produce the synthesis gas feedstock to slurry-bed FT reactors using cobalt or iron catalysts.
In Gas-To-Liquids (GTL) plants, compromises must be made between liquid product yield and plant operating and capital costs. For example, if there is a market for electricity, a steam reformer design may be chosen because this technology produces a large amount of waste heat: flue gas heat can be converted to electricity using an ‘economiser’ and steam turbine. If conservation of natural gas feedstock and low capital cost are paramount, autothermal or partial oxidation reformers using air are favored.
Another factor in selecting the best reformer type is the nature of the reformer hydrocarbon feed gas. If the gas is rich in CO2, this can be advantageous because the desired H2/CO ratio can then be achieved directly in the reformer gas without the need to remove excess hydrogen, and some of the CO2 is converted to CO, increasing the potential volume of liquid hydrocarbon product that can be produced. Additionally, the volume of steam that is required is reduced, which reduces the process energy requirements,
The market for Fischer-Tropsch (FT) processes is concentrated on large “World-Scale” plants with natural gas feed rates of greater than 200 million scfd because of the considerable economies if scale. These plants operate at high-pressure, about 450 psia, and use extensive recycling of tail gas in the FT reactor. For, example, the Norsk Hydro plant design has a recycle ratio of about 3.0. The emphasis is on achieving the maximum wax yield. In terms of product slate, these large plants strive for the maximum yield of FT waxes in order to minimize the formation of C1-C5 products. The waxes are then hydrocracked to primarily diesel and naphtha fractions. Unfortunately, light hydrocarbons are also formed in this process. The reformers use some form of autothermal reforming with oxygen produced cryogenically from air, an expensive process in terms of operating cost and capital cost. The ecomonies of scale justify the use of high operating pressure, the use of oxygen natural gas reforming, extensive tail gas recycling to the FT reactor for increasing synthesis gas conversion and controlling heat removal and product wax hydrocracking. To date, an economical FT plant design has not been developed for small plants with capacities of less than 100 million scfd.
The present invention strives for optimized economics in a completely different market: small FT plants using less than 100 million scfd. The emphasis is on simplicity and minimized capital cost, somewhat at the expense of efficiency.
The catalytic hydrogenation of carbon monoxide to produce a variety of products ranging from methane to heavy hydrocarbons (up to C80 and higher) as well as oxygenated hydrocarbons is usually referred to as Fischer-Tropsch synthesis. The high molecular weight hydrocarbon product primarily comprises normal paraffins which can not be used directly as motor fuels because their cold properties are not compatible. After further hydroprocessing, Fischer-Tropsch hydrocarbon products can be transformed into products with a higher added value such as diesel, jet fuel or kerosene. Consequently, it is desirable to maximize the production of high value liquid hydrocarbons directly.
Catalytically active group VIII, in particular, iron, cobalt and nickel are used as Fischer-Tropsch catalysts; cobalt/ruthenium is one of the most common catalyzing systems. Further, the catalyst usually contains a support or carrier metal as well as a promoter, e.g., rhenium.
Metal oxides, e.g., silica, alumina, titania, zirconia or mixture thereof, have been utilized as catalyst supports in Fischer-Tropsch hydrocarbons synthesis. U.S. Pat. No. 4,542,122 disclosed a cobalt or cobalt thoria on titania as a hydrocarbon synthesis catalyst. U.S. Pat. No. 4,088,671 disclosed a cobalt-ruthenium catalyst where alumina was used as a support. European Pat. No. 142,887 described a silica supported cobalt catalyst together with zirconium, titanium, ruthenium and/or chromium.
U.S. Pat. No. 4,801,573 described a promoted cobalt and rhenium catalyst supported on alumina. The amount of cobalt is most preferably about 10-40 wt % of the catalyst. However, rhenium is preferably about 2-20 wt of cobalt content. U.S. Pat. No. 5,248,701 disclosed a copper promoted cobalt-manganese spinel that was said to be useful as a Fischer-Tropsch catalyst with selectivity for olefins and higher paraffins.
U.S. Pat. No. 4,738,948, issued in Apr. 19, 1988, describes a catalyst comprising cobalt ruthenium at an atomic ratio of 10-400, on a refractory carrier, such as titania or silica. The catalyst is used for conversion of synthesis gas with an H2:CO ratio of 0.5-10, preferably 0.5-4, to C5-C40 hydrocarbons at a pressure of 80-600 psig and at a temperature of 160-300° C., at a gas hourly space velocity of 100-5000 v/hr/v.
After a period of time in operation, a catalyst becomes deactivated, losing its effectiveness for synthesis gas conversion. Among the main deactivation mechanisms for cobalt based catalysts are sulfur poisoning [e.g. R. L. Espinoza, et al, Applied Catalysis A:General 186 (1999)13], metal oxidation [e.g. D. Schanke et al, Catal. Lett. 34 (1995) 269] and surface condensation of heavy hydrocarbons [e.g. E. Iglesia et al, J. Catal. 143 (1993)345].
U.S. Pat. No. 5,728,918, issued on Mar. 17, 1998, described a catalyst comprising cobalt on a support, used for conversion of synthesis gas with an H2:CO ratio of 1-3, preferably 1.8-2.2, to C5+ hydrocarbons at a pressure of 1-100 bar and at a temperature of 150-300° C., at a typical gas hourly space velocity of 1000-6000 v/hr/v. Generation Activation of this catalyst was achieved by using a gas containing carbon monoxide and less than 30% hydrogen at a temperature more than 10° C. above Fischer-Tropsch conditions in the range 100-500° C. at a pressure of 0.5-10 bar, for air, at least 10 min preferably 1-12 hours.
Fischer-Tropsch synthesis performed at low pressure, 17-21 atmospheres, and relatively high temperature, usually produces short chain hydrocarbons of 0.6-0.7 chain growth probability factor. U.S. Pat App. No 20050209348 issued on Sep. 22, 2005, described a Fischer-Tropsch process performed at an elevated temperature between 230-280° C., for example 240° C. and at elevated pressure typically between 1.7 MPa and 2.1 MPa, for example 1.8 MPa, using a compact reactor. The preferred catalyst comprised a coating of gamma alumina support with 10-40% cobalt (by weight compared to the alumina) and with a promoter such as ruthenium, platinum or gadolinium which is less than 10% of the cobalt weight. The gas hourly space velocity was very high, for example 20000 hr−1 and the produced hydrocarbon liquid consisted of saturated linear alkanes of chain lengths range between about 6-17. Consequently, it is rich in aircraft fuel. However, the selectivity to the production of C5+ hydrocarbon was less than 65% and the conversion of carbon monoxide was no greater than 75%.
Hence, there is still a great need to identify other Fischer-Tropsch processes which can be used to directly produce different types of fuel such as, diesel fuel.
The invention consists of a low-pressure Fischer-Tropsch process and a catalyst that produces a high diesel-fraction yield. Process pressure is below 200 psig. The catalyst is cobalt deposited at greater than 5 weight percent on gamma alumina, optionally along with rhenium or ruthenium at 0.01-2 wt. %. It has been discovered that this catalyst is very effective at low pressures in converting synthesis gas into diesel in high yield. The present invention is particularly well suited to conversion of low pressure gases containing low molecular weight hydrocarbons into FT liquids. Examples of applications are landfill gas, oil field solution gas and low pressure gas from de-pressured gas fields. In all these cases, multiple-stage gas and air compression would be required in traditional FT plants. The high efficiency of the present FT catalyst enables high CO conversion and produces a product stream containing up to 90+ wt. % diesel in a single pass. The use of air in the natural gas reformer provides a synthesis gas containing approximately 50% nitrogen, which facilitates heat removal in the FT reactor as sensible heat and increases gas velocity and heat transfer efficiency, so that tail gas recycling is not needed. Naphtha can be partially separated from the hydrocarbon product by flash distillation at low cost to generate a more pure diesel product. This also serves to provide some product cooling. The liquid hydrocarbon product is excellent for blending with petroleum diesel to increase cetane number and reduce sulfur content.
In order to operate the FT process at high conversions with oxygen-blown reformer synthesis gas, the approach has been to recycle tail gas in a high proportion—at a ratio of 3.0 or greater bases on fresh gas feed. A secondary benefit is that the fresh gas is diluted in carbon monoxide, which reduces the required rate of heat removal from the FT reactor, reduces hot-spotting and improving the product slate. However, tailgas recycling is a very energy and capital expensive activity. The separation of oxygen from air is also an energy and capital expensive activity.
The approach taken in the present process is to use air in the reformer, which gives a synthesis gas containing approximately 50% nitrogen as inert diluent, eliminating the need for tail gas recycling to moderate FT reactor heat removal requirements. Others employing air-blown synthesis gas in FT processes have achieved the desired high CO conversions by using multiple FT reactors in series, which entails high capital costs and complex operation. The present process achieves high CO conversion in a simple single pass and a high diesel cut by using a special catalyst.
The catalyst of the present invention employs an alumina support with high cobalt concentration, along with a low level of rhenium to facilitate catalyst reduction. The high cobalt concentrations increase catalyst activity, enabling high single-pass synthesis gas conversion.
The Anderson-Shultz-Florey theory predicts the FT hydrocarbons to cover a very wide range of carbon numbers, from 1-60, whereas the most desirable product is diesel fuel (C9-C23, Chevron definition). In order to reduce the ‘losses’ of CO to making C1-C5 hydrocarbons, a common approach is to strive to make mostly wax in the FT reactor and then, in a separate operation, to hydrocrack the wax to mostly diesel and naphtha. Surprisingly, the process and catalyst of the present invention makes diesel in high yield (to 90 wt %) directly in the FT reactor, obviating the need for expensive and complex hydrocracking facilities.
Because of the elimination of oxygen purification, high-pressure compression, tail gas recycling and hydrocracking, the present process can be applied economically in much smaller plants than hitherto considered possible for FT technology.
Letter A represents the raw hydrocarbon-containing process feed gas. This could be from a wide variety of sources: for example, from a natural gas field, a land-fill facility (biogenic gas), a petroleum oil processing facility (solution gas), among others. The pressure of the gas for the present process can vary widely, from atmospheric pressure to 200 psia or higher. Single-stage or two-stage compression may be required, depending on the source pressure and the desired process operating pressure. For example, for landfill gas, the pressure is typically close to atmospheric pressure and blowers are used to transmit the gas into combustion equipment. Solution gas, which is normally flared, must also be compressed to the process operating pressure. There are also many old exploited and late-life natural gas fields with pressure too low for acceptance into pipelines that could make possible feedstock for the present process. Other natural gas sources, which may or may not be stranded (no access to a pipeline) may already be at or above the desired process operation pressure and these are also candidates. Another candidate is natural gas that is too high in inerts such as nitrogen to meet pipeline specifications.
Letter B represents hydrocarbon gas conditioning equipment. The gas may require clean-up to remove components that would damage reformer or FT catalyst. Examples of these are mercury, hydrogen sulfide, silicones and organic chlorides. Organic chlorides, such as found in land-fill gas, produce hydrochloric acid in the reformer, which can cause severe corrosion. Silicones form a continuous silicon dioxide coating on the catalyst, blocking pores. Hydrogen sulphide is a powerful FT catalyst poison and is usually removed to 1.0 ppm or lower. Some gas, from sweet-gas fields, may not require any conditioning (clean-up).
The hydrocarbon concentration in the raw gas affects the economics of the process because less hydrocarbon product is formed from the same volume of feed gas. Nevertheless, the process can operate with 50% or lower methane concentration, for example, using land-fill gas. There may even be reasons to operate the process even at a financial loss: for example to meet greenhouse gas government or corporate emission standards. The process can operate with feed gases containing only methane hydrocarbon or containing natural gas liquids by the application of known reformer technologies. The presence of carbon dioxide in the feed gas is beneficial.
Letter C represents the reformer, which may be of several types depending on the composition of the feed gas. A significant benefit of low pressure reformer operation is the lower rate of the Brouard reaction and diminution of metal dusting.
Partial oxidation reformers normally operate at very high pressure ie. 450 psia or greater, and so are not optimum for a low-pressure FT process. It is energetically inefficient, and can easily make soot, however, it does not require water, and makes a syngas with a H2/CO ratio near 2.0, optimum for FT catalysts. Partial oxidation reformers may be employed in the present process.
Steam reformers are capital expensive and require flue gas heat recovery to maximize efficiency in large plants. Because the synthesis gas contains relatively low levels of inerts such as nitrogen, temperature control in the FT reactor can be difficult without tail gas recycling to the FT reactor. However, the low level of inerts enables recycling of some tail gas to the reformer tube-side, supplementing natural gas feed, or to the shell side to provide heat. Keeping in mind that FT tail gas must be combusted before venting in any event, this energy can be used for electrical generation or, better yet, to provide the reformer heat which would be otherwise be provided from burning natural gas. For small FT plants, steam reformers are a viable choice. Steam reformers may be employed in the present process.
Autothermal reforming is an efficient process of relatively low capital cost that uses moderate temperatures and modest steam concentrations to produce a soot-free synthesis gas with H2/CO around 2.5 using low-CO2 natural gas feed, which is closer to the desired ratio than for steam reforming. However some hydrogen removal is still required for most natural gas feeds. If the feed gas contains greater than about 33% CO2, as is the case with land-fill gas feed, then an H2/CO ratio of 2.0 can be achieved without any recycle streams, and the water use can also be diminished. This is the most desired type of reformer for the present low-pressure FT processes.
Letter D represents the optional water that is injected as steam into the reformer. All reformer technologies except partial oxidation require the injection of steam.
Letter E represents an oxidizing gas, which could be air, oxygen or oxygen-enriched air.
Letter F represents a cooler for reducing the reformer outlet temperature from greater than 800° C. to close to ambient. The cooling may be done in several stages, but preferably in a single stage. The cooling may be achieved with shell-and-tube or plate-and-frame heat exchangers and the recovered energy may be utilized to pre-heat the reformer feed gases, as is well known in the industry. Another way of cooling the reformer tail gas is by direct injection of water into the stream or by passing the stream through water in a vessel.
Letter G represents a separator for separating the reformer synthesis gas from condensed water, so as to minimize the amount of water entering downstream equipment.
Letter H represents optional hydrogen removal equipment such as Prism™ hydrogen-selective membranes which are sold by Air Products, or Cynara membranes from Natco.
Certain reformer processes produce a synthesis gas too rich in hydrogen, some of which must be removed to achieve optimum FT reactor performance. An ideal H2/CO ratio is 2.0-2.1, whereas the raw synthesis gas may have a ratio of 3.0 or higher. High hydrogen concentrations give rise to larger CO loss to producing methane instead of the desired motor fuels or motor fuel precursor such as naphtha.
Letter I represents typical FT reactors, which are of the fixed-bed or slurry bubble type and either may be used. However, the fixed-bed is preferred because if its simplicity of operation and ease of scale-up.
Letter J represents a back-pressure controller which sets the process pressure. It may be placed in other locations depending on the product recovery and possible partial separation process employed.
Letter K represents product cooling and recovery. Product cooling is typically accomplished by heat exchange with cold water and serves to pre-heat the water for use elsewhere in the FT plant. Separation is accomplished in a separator vessel designed for oil/water separation. However a second alternative is to flash—cool the FT reactor product before the aforementioned cooler-separator as shown in
The FT products 2 flow through a pressure let-down valve 3 and into a flash drum 5. The inert gases and lower-boiling hydrocarbons, water and naphtha go overhead as vapour out of the flash drum and through cooler 7. The diesel and light waxes collect in vessel 5. The water and naphtha condense in cooler 7 and are collected in vessel 9. The remaining gases exit overhead in stream 10 and are typically combusted, sometimes with energy recovery, or are used to generate electricity.
Catalyst synthesis was conducted by ordinary means as practiced by those knowledgable in the art. The catalyst support was alumina trilobe extrudate obtained from Sasol Germany GmbH (hereafter referred to as ‘trilobe’). The extrudate dimensions were 1.67 mm diameter and 4.1 mm length. The support was calcined in air at 500° C. for 24 hours. A solution mixture of cobalt nitrate and perrhenic acid was added to the support by the method of incipient wetness to achieve 5 wt % cobalt metal and 0.5 wt. % rhenium metal in the finished catalyst. The catalyst was dried slowly and then heated in a convection oven at the rate of 1.0° C. per minute to 350° C. and held at that temperature for 12 hours. A volume of 29 cc of oxidized catalyst was placed in a ½ inch OD tube that had an outer annular space through which temperature-control water was flowed under pressure in order to remove the heat of reaction. In effect, the FT reactor was a shell-and-tube heat exchanger with catalyst placed in the tube side. The inlet gas and water were both at the targeted reaction temperature. Catalyst reduction was accomplished by the following procedure:
Reduction-gas flow rate (cc/min)/H2 in nitrogen (%)/temperature (° C.)/time (hours):
1. 386/70/200/4, pre-heat stage
2. 386/80/to 325/4, slow heating stage
3. 386/80/325/30, fixed-temperature stage
During Fischer-Tropsch catalysis, total gas flow to the FT reactor was at a GHSV of 1000 hr−1. Gas composition was representative of an air-autothermal reformer gas: 50% nitrogen, 33.3% H2 and 16.7% CO. A seasoning of the catalyst was used to reduce methane production. This was accomplished by holding the reactor temperature at 170° C. for the first 24 hours. Presumably, this process causes carbonylation of the cobalt surface and increased FT activity. CO conversion and liquid production were measured at a variety of temperatures between 190° C. and 220° C.
This is the same as Example 1, except that the cobalt metal loading was 10 wt %.
This is the same as Example 1, except that the cobalt metal loading was 15 wt %.
This is the same as Example 1, except that the cobalt metal loading was 20 wt %.
This is the same as Example 1, except that the cobalt metal loading was 26 wt %.
This is the same as Example 1, except that the cobalt metal loading was 35 wt %.
The effect of Co loading on catalyst performance was tested with Examples 1-6 with the results shown in Table 2. Tests were conducted at various temperatures and the temperature that gave the largest amount of hydrocarbon product is listed. It is clear that 5% cobalt was not enough to provide a useful amount of liquid hydrocarbons: the best concentration was 20 wt % Co, which gave 1.03 ml/h. The concentration of diesel range hydrocarbons in the hydrocarbon product was 75.3-92.5% at cobalt loadings of 10 wt % cobalt or higher. The highest diesel production rate (0.78 ml/h) was achieved with the trilobe support with 20% cobalt at 70 psia.
The catalyst in Example 4 was run in the standard testing rig as described above at a temperature of 202.5° C. and at a variety of pressures. Results in Table 3 and
This is identical to Example 1, except that the alumina support was CSS-350, obtained from Alcoa, and the cobalt loading was 20 weight percent. This support is spherical with a diameter of 1/16 inch.
As seen in Table 4, the maximum diesel production rate was achieved at 215° C. and 70 psia. Compared with Catalyst 4, Catalyst 7 gave a lower diesel production rate at its optimum temperature (215° C.), but a higher diesel fraction.
This is identical to Example 1, except that the alumina support was LD-5, obtained from Alcoa, and the cobalt loading was 20 weight percent. This support is spherical with a mesh size distribution of 7/14.
Example 8 was tested at 70 psia and two temperatures. Table 5 shows that the optimum temperature was 220° C. and the hydrocarbon liquid was 6.1% naphtha, 90.8% diesel and 3.1% light waxes.
This is identical to Example 1, except that the alumina support was F-220, obtained from Alcoa, and the cobalt loading was 20 weight percent. F-220 is a spherical support with a mesh size distribution of 7/14.
Example 9 catalyst was tested at 70 psia. As shown in Table 6 and
This is identical with Example 4, except that the promoter was ruthenium rather than rhenium.
Data in Table 7 and
This was identical with Example 3, except that Aerolyst 3038 silica catalyst support from Degussa was used instead of alumina.
The hydrocarbon liquid production rate was 0.55 ml/h at 210° C. The carbon distribution curve shown in
The Examples 1-11 in this disclosure show that a narrow distribution of hydrocarbons, mainly in the diesel range, is obtained.
This application is a continuation of U.S. patent application Ser. No. 11/594,209 filed Nov. 8, 2006, of which is incorporated herein by reference in its entirety and for all its teachings, disclosures and purposes.
| Number | Date | Country | |
|---|---|---|---|
| Parent | 11594209 | Nov 2006 | US |
| Child | 12318107 | US |
