Abstract
A process, a process plant and equipment for conversion of a feedstock rich in oxygenates to a hydrocarbon including directing the feedstock in combination with a recycle gas stream to a hydroprocessing step, to provide a two-phase hydroprocessed process stream including at least hydrogen, methane and hydrocarbons, combining a methane lean stream of hydrocarbons being liquid at ambient temperature, with a methane donor stream being either (i) the two-phase hydroprocessed process stream including methane or (ii) a gaseous stream derived from the two-phase hydroprocessed process stream by phase separation, to provide a multiple-phase combined stream, separating the multiple-phase combined stream into at least a hydrogen rich gas stream and a rich liquid hydrocarbon stream, in a desorption step desorbing an amount of methane from the rich liquid hydrocarbon stream, to provide a methane rich gas phase and a liquid product stream of hydrocarbons.
Claims
1. A process for conversion of a feedstock rich in oxygenates to a liquid product stream of hydrocarbons comprising the steps of a. directing said feedstock in combination with a recycle gas stream to a hydroprocessing step, to provide a two-phase hydroprocessed process stream comprising at least hydrogen, methane and hydrocarbons, b. combining a methane lean stream of hydrocarbons being liquid at ambient temperature and pressure, with a methane donor stream being either (i) said two-phase hydroprocessed process stream or (ii) a gaseous hydroprocessed stream derived from the two-phase hydroprocessed process stream by a means of phase separation, and optionally cooling, to provide a multiple-phase combined stream, c. separating said multiple-phase combined stream in at least a hydrogen rich gas stream comprising a majority of the hydrogen comprised in said hydroprocessed process stream and a rich liquid hydrocarbon stream comprising absorbed methane, d. in a desorption step, desorbing an amount of methane from said rich liquid hydrocarbon stream, in order to transfer an amount of methane to the gas phase, in order to provide a methane rich gaseous stream, and in order to provide a liquid product stream of hydrocarbons.
2. The process according to claim 1, wherein said methane lean stream of hydrocarbons is combined with the two-phase hydroprocessed process stream to provide said multiple-phase combined stream, prior to cooling and phase separation of the combined stream to provide said hydrogen rich gas stream and said rich liquid hydrocarbon stream.
3. The process according to claim 1, wherein the two-phase hydroprocessed process stream is cooled, and phase separated by a flashing step, to provide a gas stream and a liquid stream and wherein the methane lean stream of hydrocarbons is combined in a combining step with the gas stream to provide said multiple-phase combined stream.
4. The process according to claim 3, wherein the flashing step as well as the combining step are made in an integrated absorption zone and flashing zone, such that the methane lean stream of hydrocarbons is combined with the two-phase hydroprocessed hydrocarbon stream to provide said stream rich liquid stream of hydrocarbons comprising the methane.
5. A The process according to claim 3, wherein the flashing step as well as the combining step are carried out in separate devices for flash separation and absorption.
6. The process according to claim 1 wherein separating said two-phase hydroprocessed process stream, is carried out, after optional cooling, by directing the two-phase hydroprocessed process stream to a high pressure stripper receiving a stripping medium, and providing a stripped liquid stream and a stripper overhead stream.
7. The process according to claim 6 wherein said stripper overhead stream constitutes the gaseous hydroprocessed stream, which is combined with a methane lean stream of hydrocarbons prior to being directed to a first separator, providing at least said methane enriched liquid stream of hydrocarbons and said hydrogen rich gaseous stream, and in which said methane rich liquid stream is directed to a further separator providing said desorption step, to provide a methane reduced liquid stream and the methane rich gaseous stream.
8. The process according to claim 1, wherein the pressure of the multiple phase combined stream is at least 3000 kPa.
9. The process according to claim 1, wherein the temperature of the multiple phase combined stream is from 20? C. to 275?C, such as from 20? C. to 90? C. or 150? C. or from 150? C. or 200? C. to 275? C.
10. The process according to claim 1, wherein the desorption step comprises decreasing the pressure to less than 2000 kPa.
11. The process according to claim 1, wherein the desorption step comprises stripping the methane enriched liquid stream of hydrocarbons with a stripping medium, such as hydrogen or steam.
12. The process according to claim 1, wherein the desorption step involves a decrease of pressure by 80% of the pressure before desorption.
13. The process according to claim 1, wherein the liquid product stream of hydrocarbons comprises at least an amount of the methane reduced liquid stream or a product of further hydroprocessing of the methane reduced liquid stream.
14. The process according to claim 1, wherein the liquid stream of hydrocarbons comprises at least an amount of the liquid hydroprocessed stream or a product of further hydroprocessing of the liquid hydroprocessed stream.
15. A process plant comprising a hydroprocessing section having a liquid phase inlet, a gas phase inlet and an outlet, a first means of separation having an inlet, a liquid phase outlet and a gas phase outlet, a means of absorption, having a liquid inlet and a gas phase inlet, a liquid phase outlet and a gas phase outlet, optionally in an integrated device in the same pressure vessel as said first means of separation such that by the gas phase outlet of the first means of separation, the gas phase inlet of the means of absorption and the liquid phase outlet of the means of absorption are internal to the integrated device, a second means of separation having an inlet, a liquid phase outlet and a gas phase outlet, wherein the liquid phase inlet of the hydroprocessing section is configured to receive an oxygenate feedstock, the gas phase inlet of the hydroprocessing section is configured to receive a gas rich in hydrogen, and the outlet of the hydroprocessing section is in fluid communication with the inlet of the first means of separation, the gas phase outlet of the first means of separation is in fluid communication with the gas phase inlet of the means of absorption, a liquid hydrocarbon stream is directed to said liquid phase inlet of the means of absorption and the gas phase outlet of the means of absorption is in fluid communication with said gas phase inlet of the hydroprocessing section, optionally via a means of purification, the liquid phase outlet of the means of absorption is in fluid communication with the inlet of said second means of separation.
16. The process plant according to claim 15, further comprising a means of pressurization having an inlet and an outlet, wherein the liquid phase outlet of said second means of separation is in fluid communication with the inlet of said means of pressurization, and the outlet of said means of pressurization is in fluid communication with the inlet of said means of absorption.)
17. An integrated means of separation and absorption comprising a multiple phase stream inlet, a liquid phase inlet, a liquid phase outlet and a gas phase outlet, said integrated means of separation and absorption comprising a separation zone and an absorption zone in a single pressure vessel, wherein said separation zone is positioned below said absorption zone and configured to allow fluid communication between the separation zone and the absorption zone, and wherein said absorption zone, has a liquid inlet and a gas phase outlet, and optionally comprises means for enhancing the contact between gas and liquid.
Description
BRIEF DESCRIPTION OF FIGURES
[0062] FIG. 1 shows a process layout according to the present disclosure suited for revamping an existing plant.
[0063] FIG. 2 shows a process layout according to the present disclosure suited for building a new plant.
[0064] FIG. 3 shows a process layout according to the prior art.
[0065] FIG. 4 shows a process layout according to the present disclosure employing a high pressure stripper.
[0066] FIG. 5 shows a process layout according to the present disclosure employing a high pressure stripper with an integrated absorber/separator.
[0067] FIG. 6 shows a process layout according to the prior art employing a high pressure stripper.
[0068] FIG. 7 shows a process layout according to the prior art employing a high pressure strip-per.
[0069] FIG. 1 shows a process layout according to the present disclosure suited for revamping an existing plant, with an existing layout comprising a high pressure cold separator and a low pressure cold separator, in which a hydrocarbonaceous feedstock stream 102, such as a mixture rich in oxygenates, together with a recycle gas stream 104, and an amount of make-up hydrogen 105, is directed as a total feed stream to a hydroprocessing reactor HDP, comprising a material catalytically active in hydroprocessing, to provide a multiple-phase hydroprocessed stream 108. In the case of a feedstock rich in oxygenates, the catalytically active material is active in hydrodeoxygenation, and for other feedstocks, the catalytically active material may be active in other hydrotreatment processes, hydroisomerization or hydrocracking. The multiple-phase hydroprocessed stream 108 is (after cooling) directed to a high pressure cold separator HPCS, where the multiple-phase hydroprocessed stream 108 is separated in a polar liquid stream 110 (which may not be present if the hydrocarbonaceous feedstock is not rich in oxygenates), a non-polar liquid stream 112 and a gaseous hydroprocessed stream 114, which will comprise light gases such as unreacted hydrogen, methane, propane, and hydrogen sulfide. Both liquid streams 110, 112, are directed to a downstream low pressure cold separator LPCS. In the low pressure cold separator LPCS the input is separated in three phases; a hydrogen rich gas stream 116, mainly comprising hydrogen and methane dissolved in the non-polar liquid stream 112, a non-polar product stream 118 and a polar sour water stream 120 which is directed to a sour water system.
[0070] The non-polar product stream 118 is directed to a product stripper PS, in which a product stream 122 is separated from a stripper vapor 124 by use of a stripping medium such as steam 126. The stripper will typically operate with reflux and a polar stream may also be condensed and directed to a sour water system
[0071] The gaseous hydroprocessed stream 114 is directed to an absorber ABS, also receiving a lean liquid stream of hydrocarbons 128, which is effectively contacted with the gaseous hydroprocessed stream, to maximize capturing of methane in the liquid stream of hydrocarbons, to provide a methane enriched liquid stream of hydrocarbons 130 and a methane reduced gaseous stream 132, which may be pressurized in compressor C, and directed as recycle gas 104. In a cold low pressure separation for desorption DES, the mixture is flashed, to separate a methane reduced liquid stream 134 and a methane rich gaseous stream 136. The methane reduced liquid stream 134 is pressurized in pump P and recycled as the lean liquid stream of hydrocarbons 128. As an amount of liquid hydrocarbons may be present in the methane rich gaseous stream 136, a make-up stream of liquid hydrocarbons 138 may be provided, e.g. from the product outlet of the product stripper PS.
[0072] FIG. 2 shows a process layout according to the present disclosure suited for a plant in which there is no tie of existing equipment. Again, a hydrocarbonaceous feedstock stream 202, such as a mixture rich in oxygenates, together with a recycle gas stream 204, and an amount of make-up hydrogen 205, is directed as a total feed stream to a hydroprocessing reactor HDP, comprising a material catalytically active in hydroprocessing, to provide a multiple-phase hydroprocessed stream 208. In the case of a feedstock rich in oxygenates, the catalytically active material is active in hydrodeoxygenation, and for other feedstocks, the catalytically active material may be active in other hydrotreatment processes, hydroisomerization or hydrocracking. The multiple-phase hydroprocessed stream 208 is (after cooling) directed to an integrated high pressure cold separator-absorber HPCSA. In the integrated high pressure cold separator-absorber HPCSA, the multiple-phase hydroprocessed stream 208 is separated in a polar liquid stream 210 (which may not be present if the hydrocarbonaceous feedstock is not rich in oxygenates), a non-polar liquid stream 212 and a gaseous phase, which will comprise light gases such as unreacted hydrogen, methane, propane, and hydrogen sulfide. In the top part of the integrated high pressure cold separator-absorber HPCSA, a lean liquid stream of hydrocarbons 238 is received and contacts the gaseous phase of the hydroprocessed stream, and absorbs methane and other soluble gases, and releases a methane reduced gaseous stream 232, which may be pressurized in compressor C, and directed as recycle gas 204. Both liquid streams 210, 212 are directed to a downstream low pressure cold separator LPCS. In the low pressure cold separator LPCS the input is separated in three phases; a hydrogen rich gas stream 216, mainly comprising hydrogen and methane dissolved in the non-polar liquid stream 212, a non-polar product stream 218 and a polar sour water stream 220 which is directed to a sour water system.
[0073] The non-polar product stream 218 is directed to a product stripper PS, in which a product stream 222 is separated from a stripper vapor 224 by use of a stripping medium such as hydrogen 226. The stripper will typically operate with reflux and a polar stream may also be condensed and directed to a sour water system. An amount of the product stream is pressurized in pump P and directed as the lean liquid stream of hydrocarbons 238 for the integrated high pressure cold separator-absorber HPCSA, but other streams could also be used for this purpose.
[0074] FIG. 3 shows a process layout according to the prior art, in which a hydrocarbonaceous feedstock stream 302, such as a mixture rich in oxygenates, together with a recycle gas stream 304, and an amount of make-up hydrogen 305, is directed as a total feed stream to a hydroprocessing reactor HDP, comprising a material catalytically active in hydroprocessing, to provide a hydroprocessed stream 308. In the case of a feedstock rich in oxygenates, the catalytically active material is active in hydrodeoxygenation, and for other feedstocks, the catalytically active material may be active in other hydrotreatment processes, hydroisomerization or hydrocracking. The hydroprocessed stream 308 is (after cooling) directed to a high pressure cold separator HPCS, where the hydroprocessed stream 308 is separated in a polar liquid stream 310 (which may not be present if the hydrocarbonaceous feedstock is not rich in oxygenates), a non-polar liquid stream 312 and a gaseous hydroprocessed stream 314, which will comprise unreacted hydrogen, methane, propane, and hydrogen sulfide. To avoid a build-up of undesired components, a purge stream 336 may be taken out, and the remaining stream of recycle gas 332, may be pressurized in compressor C, and directed as recycle gas 304. Both liquid streams 310, 312 are directed to a downstream low pressure cold separator LPCS. In the low pressure cold separator LPCS the input is separated in three phases; a hydrogen rich gas stream 316, mainly comprising hydrogen and methane dissolved in the non-polar liquid stream 312, a non-polar product stream 318 and a polar sour water stream 320 which is directed to a sour water system.
[0075] The non-polar product stream 318 is directed to a product stripper PS, in which a product stream 322 is separated from a stripper vapor 324 by use of a stripping medium such as hydrogen 326. The stripper will typically operate with reflux and a polar stream may also be condensed and directed to a sour water system
[0076] FIG. 4 shows a process layout according to the present disclosure in which separation is carried out in a high pressure stripper HPS. A hydrocarbonaceous feedstock stream 402, such as a mixture rich in oxygenates, is together with a recycle gas stream 404, and an amount of make-up hydrogen 405, is directed as a total feed stream to a hydroprocessing reactor HDP, comprising a material catalytically active in hydroprocessing, to provide a hydroprocessed stream 408. In the case of a feedstock rich in oxygenates, the catalytically active material is active in hydrodeoxygenation, and for other feedstocks, the catalytically active material may be active in other hydrotreatment processes, hydroisomerization or hydrocracking. The hydroprocessed stream 408 is (after cooling) directed to a high pressure stripper HPS, also receiving a stripping medium, typically hydrogen 426. The hydroprocessed stream 408 is separated in a stripped liquid stream 422 and a stripper vapor 418. The stripper overhead stream 418 is combined with a lean liquid stream of hydrocarbons 438 and cooled e.g. in an air cooler COOL. The cooled combined stripper overhead stream/lean oil mixture 424, is directed to a high pressure overhead separator HPO, in which the inlet is separated into sour water 420, a methane enriched liquid stream of hydrocarbons 430 and a methane reduced gaseous stream 432, which may be pressurized in compressor C, and directed as recycle gas 404. In a cold low pressure overhead separator LPO , the methane enriched liquid stream of hydrocarbons 430 is flashed, to separate a methane reduced liquid stream 434 and a methane rich gaseous stream 436, and typically also a sour water stream 420. The methane reduced liquid stream 434 is pressurized in pump P and recycled split in overhead condensate for the high pressure stripper HPS and as the lean liquid stream of hydrocarbons 438.
[0077] FIG. 5 shows an alternative process layout according to the present disclosure in which separation is carried out in a high pressure stripper HPS. A hydrocarbonaceous feedstock stream 502, such as a mixture rich in oxygenates, is together with a recycle gas stream 504, and an amount of make-up hydrogen 505, is directed as a total feed stream to a hydroprocessing reactor HDP, comprising a material catalytically active in hydroprocessing, to provide a hydroprocessed stream 508. In the case of a feedstock rich in oxygenates, the catalytically active material is active in hydrodeoxygenation, and for other feedstocks, the catalytically active material may be active in other hydrotreatment processes, hydroisomerization or hydrocracking. The hydroprocessed stream 508 is (after cooling) directed to a high pressure stripper HPS, also receiving a stripping medium, typically hydrogen 526. The hydroprocessed stream 508 is separated in a stripped liquid stream 522 and a stripper vapor 518. The stripper overhead stream 518 is cooled e.g. in an air cooler COOL. The cooled stripper overhead stream 524, is directed to a high pressure overhead absorber/separator HPOA, which comprises an inlet for a lean liquid stream of hydrocarbons 538 in addition to the inlet for the stripper overhead stream 524. The high pressure overhead absorber/separator HPOA is configured for providing contact between the lean liquid stream of hydrocarbons and the gas phase, and this contact may be enhanced by provision of trays or filling elements at the top of the high pressure overhead absorber/separator HPOA. The inlet is, similar to the embodiment illustrated in FIG. 4, separated into sour water 520, a methane enriched liquid stream of hydrocarbons 530 and a methane reduced gaseous stream 532, which may be pressurized in compressor C, and directed as recycle gas 504. An amount of this stream may be withdrawn as purge stream 533. In a cold low pressure overhead separator LPO , the methane enriched liquid stream of hydrocarbons 530 is flashed, to separate a methane reduced liquid stream 534 and a methane rich gaseous stream 536, and typically also a sour water stream 520. The methane reduced liquid stream 534 is pressurized in pump P and recycled split in overhead condensate for the high pressure stripper HPS and as the lean liquid stream of hydrocarbons 538, directed for the high pressure overhead absorber/separator HPOA.
[0078] FIG. 6 shows an comparative alternative process layout according to the prior art in which separation is carried out in a high pressure stripper HPS. A hydrocarbonaceous feedstock stream 602, such as a mixture rich in oxygenates, is together with a recycle gas stream 604, and an amount of make-up hydrogen 605, is directed as a total feed stream to a hydroprocessing reactor HDP, comprising a material catalytically active in hydroprocessing, to provide a hydroprocessed stream 608. In the case of a feedstock rich in oxygenates, the catalytically active material is active in hydrodeoxygenation, and for other feedstocks, the catalytically active material may be active in other hydrotreatment processes, hydroisomerization or hydrocracking. The hydroprocessed stream 608 is (after cooling) directed to a high pressure stripper HPS, also receiving a stripping medium, typically hydrogen 626. The hydroprocessed stream 608 is separated in a stripped liquid stream 622 and a stripper overhead stream 618. The stripper overhead stream 618 is cooled e.g. in an air cooler COOL. The cooled stripper overhead stream 624, is directed to a high pressure overhead separator HPO, where the inlet stream is separated into sour water 620, a liquid stream of hydrocarbons 630 and a gaseous stream 632, which may be pressurized in compressor C, and directed as recycle gas 604. As the gaseous stream 632 contains methane, a purge stream may have to be taken out to avoid a build up of methane.
[0079] FIG. 7 shows a process layout according to the prior art in which separation is carried out in a high pressure stripper HPS. A hydrocarbonaceous feedstock stream 702, such as a mixture rich in oxygenates, is together with a recycle gas stream 704, and an amount of make-up hydrogen 705, is directed as a total feed stream to a hydroprocessing reactor HDP, comprising a material catalytically active in hydroprocessing, to provide a hydroprocessed stream 708. In the case of a feedstock rich in oxygenates, the catalytically active material is active in hydrodeoxygenation, and for other feedstocks, the catalytically active material may be active in other hydrotreatment processes, hydroisomerization or hydrocracking. The hydroprocessed stream 708 is (after cooling) directed to a high pressure stripper HPS, also receiving a stripping medium, typically hydrogen 726. The hydroprocessed stream 708 is separated in a stripped liquid stream 722 and a stripper vapor 718. The stripper overhead stream 718 is cooled e.g. in an air cooler COOL. The cooled stripper overhead stream 724, is directed to a high pressure overhead separator HPO, in which the inlet is separated into sour water 720, a liquid stream of hydrocarbons 730 and a gaseous stream 732, which may be pressurized in compressor C, and directed as recycle gas 704. An amount of this stream may be withdrawn as purge stream 733. In a cold low pressure overhead separator LPO , the liquid stream of hydrocarbons 730 is flashed, to separate a liquid stream 734 and a gaseous stream 736, and typically also a sour water stream 720. The methane reduced liquid stream 734 is pressurized in pump P and recycled as overhead condensate for the high pressure stripper HPS.
EXAMPLES
[0080] The processes of the configuration shown in FIG. 2 and FIG. 3 were compared. In both processes a biological feedstock comprising rapeseed oil was hydrotreated, to complete hydrodeoxygenation, with the production of a liquid phase of the hydroprocessed stream.
[0081] In the process of the examples an amount of methane is produced after production of CO.sub.2 by decarboxylation and subsequent conversion to CO and methanation to CH.sub.4 in the hydrodeoxygenation reactor. In the process of the prior art, according to FIG. 3, a significant part of the methane produced is recycled with the hydrogen in the gas loop of the process. Contrary to this, in the process of the present disclosure, according to FIG. 2, an increased amount of methane may be absorbed in the lean hydrocarbon and withdrawn from the gas loop.
[0082] Table 1 shows the amount of light gases (in vol %) in the hydroprocessed stream 208, in the oil outlet 212 from the high pressure cold separator and absorber HPCSA, and in the methane reduced gaseous stream 232, which is directed as recycle gas, for the two processes. In this configuration, the ratio between the methane reduced gaseous stream 232 used as recycle gas and lean liquid stream of hydrocarbons 238 was 725 Nm.sup.3/m.sup.3. This corresponds to a total amount of combined liquid hydrocarbon withdrawn from the high pressure cold separator and absorber HPCSA of 156 m.sup.3/h.
[0083] Table 2 similarly shows the amount of light gases (in vol %) in the hydroprocessed stream 308, in the non-polar liquid stream 312 from the high pressure cold separator HPCS, and in the recycle gas 332, for the two processes. As no lean hydrocarbon is recycled, the total amount of liquid hydrocarbon withdrawn from the high pressure cold separator HPCS is only 90 m.sup.3/h, which constitutes a lower capacity for withdrawing methane from the recycle gas.
[0084] Of the methane leaving the hydroprocessing process in the hydroprocessed stream 308, in the process of FIG. 3 without absorber, 5.1% remains dissolved in the liquid phase. Contrary to this with an absorber in the process of FIG. 1, the amount of methane absorbed in the oil is increased to about 7.5%. Accordingly, the majority of methane is recycled to the recycle gas loop, but nevertheless, the small difference causes a significant difference in the stable concentration of methane, such that the inventive process decreases the concentration of methane in the recycle gas from 25.9% vol to 16.6% vol. In addition especially the amount of propane withdrawn from the recycle gas is increased and thus the amount of C1-C3 hydrocarbons in the recycle gas is reduced from 33.5% vol to 20.3% vol. This reduction corresponds to an increase in hydrogen concentration from 63.7% vol to 77.8% vol, which is an increase in partial pressure from 36 Bar to 44 Bar (assuming a pressure of 57.5 Bar), which would have required significant increased investment in process equipment, if it was sought to be implemented by increasing the overall pressure, which may not be possible when converting existing plants in a revamp.
[0085] The operation of the absorber may be varied by varying the amount of the liquid stream of hydrocarbons.
[0086] In Table 3 the effect of adjusting selected parameters in the process are shown. The two scenarios of Table 2 (no lean hydrocarbon used for absorption, as in FIG. 3) and Table 1 (lean hydrocarbon being diesel) are compared with a similar scenario with naphtha as lean hydrocarbonall three at the same pressure. From this it is clear that an increased removal of methane, and related increase in hydrogen partial pressure may be obtained by using a light hydrocarbon, such as naphtha, if conveniently available. In the following two lines it is further seen that if the pressure of operation is 100 bar, the effect of absorption of methane in lean hydrocarbon is higher.
[0087] Table 4 shows an alternative approach to evaluating the benefit of the process. In this evaluation a process simulation was executed for FIG. 5 and FIG. 7 respectively on the basis of a total feed rate of 199 m.sup.3/h (streams 508 and 708), with the objective of a purity of at least 80 vol % in the hydrogen treat gas stream (the combination of streams 504 and 505 or 704 and 705). Comparing FIG. 5 and FIG. 4 shows that the presence of a lean hydrocarbon absorber results in a more pure recycle gas (72.6 vol % of 504 vs. 72.3 vol % of 704), a reduced amount of purge (533 and 536 combined vs. 733 and 736 combined) and thus 25,000 Nm.sup.3/h less make-up gas (505 vs 705).
TABLE-US-00001 TABLE 1 Stream 208 212 232 H.sub.2O % vol 7.6 0.32 0.12 H.sub.2S % vol 0 0.04 0.02 CO % vol 0.5 0.07 0.6 CO.sub.2 % vol 0.7 0.47 0.78 H.sub.2 % vol 60.7 4.03 77.76 C1 % vol 13.8 4.24 16.62 C2 % vol 0.8 0.81 0.75 C3 % vol 4.5 9.16 2.92 C4+ % vol 11.52 80.86 0.43
TABLE-US-00002 TABLE 2 Stream 308 312 314 H.sub.2O % vol 7.6 0.37 0.12 H.sub.2S % vol 0.0 0.07 0.04 CO % vol 0.5 0.08 0.65 CO.sub.2 % vol 0.9 0.67 1.08 H.sub.2 % vol 49.2 3.43 63.68 C1 % vol 20.8 6.54 25.87 C2 % vol 1.3 1.38 1.34 C3 % vol 7.7 17.98 6.26 C4+ % vol 12.0 69.49 0.98
TABLE-US-00003 TABLE 3 Lean hydrocarbon Pressure [bar] H.sub.2 [% vol] C1 [% vol] None 57.5 63.68 25.87 Diesel 57.5 77.76 16.62 Naphtha 57.5 83.98 10.93 None 100 78.31 15.07 Diesel 100 86.81 9.45
TABLE-US-00004 TABLE 4 Unit Stream# Value Stream# Value 1000 Nm3/h 505 931.0 705 956.0 m3/h 502 198.9 702 198.9 m3/h 508 220.2 708 218.5 m3/h 538 116.3 1000 Nm3/h 533 87.5 733 127.3 1000 Nm3/h 504 2475.9 704 2450.9 vol % H.sub.2 72.6 72.3 1000 Nm3/h 536 24.0 736 16.7 vol % H.sub.2O 1.4 0.9 vol % H.sub.2S 0.2 0.1 vol % CO 0.1 0.1 vol % CO.sub.2 0.6 0.6 vol % H.sub.2 23.2 32.8 vol % C1 22.1 24.7 vol % C2 7.7 7.3 vol % C3 38.4 29.4 vol % C4+ 6.3 4.1
