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Publication numberUS3224954 A
Publication typeGrant
Publication dateDec 21, 1965
Filing dateFeb 3, 1964
Priority dateFeb 3, 1964
Publication numberUS 3224954 A, US 3224954A, US-A-3224954, US3224954 A, US3224954A
InventorsAn Security First National Ban, Schlinger Warren G
Original AssigneeTexaco Inc
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Recovery of oil from oil shale and the like
US 3224954 A
Abstract  available in
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Claims  available in
Description  (OCR text may contain errors)

Dec. 21, 1965 w, G, SCHLINGER ET AL 3,224,954

RECOVERY OF OIL FROM OIL SHALE AND THE LIKE TMll-1- U IM Pff/ME Dec. 2l, 1965 w, SCHUNGER ET AL 3,224,954

RECOVERY OF OIL `FROM OIL SHALE AND THE LIKE Original Filed May 29, 1959 l 2 Sheets-Sheet 2 i c Q x Q i E El Il n L\ k f .fv d 'f-4% f b4 i m Q QN N tix Q4 u ma .3 ai al E Q United States Patent C) 3,224,954 RECOVERY OF OIL FROM OIL SHALE AND THE LIKE Warren G. Schlinger, Pasadena, Calif., Aand Du Bois Eastman, deceased, late of Whittier, Calif., by Security First National Bank of Los Angeles, Calif., executor, assignors to Texaco Inc., New York, N.Y., a corporation of Delaware Continuation of application Ser. No. 816,755, May 29, 1959. This application Feh. 3, 1964, Ser. No. 342,852 7 Claims. (Cl. 208-11) This application is a continuation of our copending patent application, Serial Number 816,755 now abandoned, tiled May 29, 1959.

The present invention relates to the production of oil from oil-bearing minerals. The process of this invention involves recovery of oil from oil-bearing minerals, for example, oil shale, oil sand, and tar sand, and simultaneous treatment of said recovered oil with hydrogen. The process results in the production of recovered oil in high yield having relatively low viscosity, low sulfur content, and good renability, particularly in comparison with oil recovered from these same oil-bearing materials by conventional retorting or by extraction with solvents.

In carrying out the process of this invention, an oilbearing mineral is subjected to treatment with hydrogen containing gas at a pressure in the range of 1000 to 2500 pounds per square inch gauge and at a temperature in the range of about 800 to 950 F. for a period of about 20 l minutes to hours, preferably not more than 2 hours.

High oil yields are obtained. Oil yields of more than 100 percent, and typically 125 to 135 percent, by volume, in comparison with the standard Fischer Assay, are obtained from commercial grade oil shales. The quantity of oil remaining in the residue is too small to support combustion. In addition, the recovered oil has lower viscosity, lower specific gravity and lower carbon residue than oils recovered by conventional retorting procedures.

It is known that certain oil-bearing minerals, called oil shales, contain certain substances known as kerogens which may be converted to hydrocarbon oil by the application of heat. Other oil-bearing minerals, such as oil sands or tar sands, contain hydrocarbons which may be distilled or extracted from the mineral residue, or displaced by means of liquids, particularly at elevated temperatures. As is well known, however, oil recovered from oil shale and tar sands, is generally of poor quality as compared with most crude petroleum oils. In particular, the oil from such oil-bearing minerals generally is of low API gravity and contains relatively little material boiling in the distillate boiling range. In addition, the oil has a relatively high content of organic sulfur and organic nitrogen compounds. Yields of motor fuels from these oils by conventional petroleum refining process are comparatively poor. Extensive treating and refining operations are necessary to remove nitrogen and sulfur and to obtain maximum yields of commercially desirable products from the crude oil.

The process of this invention provides a method for direct recovery of oil of improved product quality from oil shales and tar sands by hydroretorting, a combination hydrogenation and heat treatment, under carefully controlled conditions of time, temperature and pressure. In addition, some ammonia is produced which may be recovered as a valuable by-product.

"ice

We are aware of the fact that it has been proposed heretofore to upgrade crude oil recovered from oil shale or tar sand by treatment with hydrogen, either catalytically or non-catalytically, for the express purpose of improving product quality. We are also aware that it has been proposed heretofore to retort oil shale in the presence of hydrogen. Usually such processes are carried out at pressures below about 1000 p.s.i.g. at relatively mild temperatures, e.g. below about 1000 F., or at higher temperature and pressure. We have found that much improved results may be obtained by retorting the oil shale under relatively mild temperatures of 800 to 950 F. in the presence of hydrogen at a pressure above about 1000 p.s.i.g. and in the range of 1000 to 2500 p.s.i.g.

One major disadvantage of prior processes for treating oil-bearing minerals with hydrogen is the large volumetime relationship required in such processes. For example, the time required for treatment of a batch of oil shale by conventional processes ranges from about 6 to 24 hours, thus requiring extensive installations of retorts capable of holding a large volume of material for a period of several hours. When it is appreciated that the oil contents of commercial oil shales range from about 15 to about 40 gallons per ton, the immense investment in equipment required for a plant designed to produce, for example, 10,000 barrels of crude shale oil per day becomes immediately apparent.

As pointed out above, the time required for processing oil-bearing minerals by the process of this invention is short in comparison with other processes. In general, it is only necessary to raise the temperature of the material to 800 F. or above by heat exchange with the hot gas and hold the particles at a temperature in the range of 800 to 950 F. in the presence of the high pressure hydrogen for a period of about 20 minutes to two hours. The external heat required for the hydroretorting operation is comparatively low and is easily supplied by the hot hydrogen stream itself without the necessity for supplemental heating by heat exchange through the walls of the vessel or by means of a heated circulating solid. The relatively mild temperature prevents decomposition of the carbonate, primarily calcium carbonate, in oil shale. A large part of the heat required in conventional shale retorting processes is required for decomposition of the carbonates, liberating carbon dioxide which generally serves no useful purpose in the process, and is actually detrimental.

The extent of recovery of hydrocarbon from oil shale by the process of this invention is such that there is not suicient fuel value in the residual shale to support combustion. This is in sharp contrast with conventional processes which burn the residual shale. Shaleresidue obtained in a number of test runs was largely in the form of an impalpable powder or soft lumps easily disintegrated to powder. These residues appear to be suitable as raw material for the production of Portland cement.

In accordance with a preferred embodiment of the present invention, tar sand, or oil shale lumps or pieces having a maximum size of `about 11/2 tol 2 inches, is charged into a pressure vessel, preferably a series of such vessels. and contacted with a hydrogen-rich gas stream which is passed upwardly through said vessel under a pressure Within the range of 1000 to 2500 p.s.i.g. and a temperature within the range of 800 to 950I F. It is not necessary to preheat the mineral prior to contact with hydrogen. As the hydrogen passes up through the re tort, a fairly sharp temperature profile is observed, above which the temperature is less than retorting temperature, probably as a result `of condensation of oil vapors on the cooler material. Oil is entrained in `the hydrogen-rich gas passing through the mineral and carried from the vessel where it is recovered by conventional methods, eg. condensation and/or adsorption. Following recovery of the oil from the effluent gas, the hydrogen-rich gas is recirculated Vto the retorting vessel. The recirculatted gas may be processed for recovery of ammonia and for removal of sulfur-containing gas, eg. hydrogen sulfide, contained therein but this is not essential to the operation. It is not essential that the gas pass upward through the retort; horizontal flow (cross flow) or down flow may be used with suitable retorts.

Hydrogen feed rates of the order of 25,000 to 150,000 standard cubic feet (60 F. and atmospheric pressure) per ton of mineral per hour maybe employed. Generally the hydrogen consumption is within the range of about 500 to about 3,000 standard cubic feet per barrel of oil produced. Hydrogen preferably is supplied in relatively pure form, eg. 90 volume percent or higher, but may be supplied as a gas mixture having a hydrogen concentration in the range of from about 25 to about 99 percent hydrogen by volume. The hydrogen pressure in the system preferably is at least 1000 p.s.i.g. and preferably Within the range of 1500 to 2000 p.\s.i.g. Treating time may range from about 20 minutes to 5 hours, although generally satisfactory recovery may be obtained within 30 minutes at reaction temperatures above 800 F. The holding time in the reaction vessel may be somewhat longer, depending upon the size of the vessel and the gas feed rate.

A preferred embodiment of the present invention involves the combination of hydroretorting the mineral under specified pressure-time-temperature conditions followed by passing the total efuent from the hydroretorting reactor in vapor phase directed over a hydrogenation catalyst, for example, a cobalt-molybdenum hydrogenation catalyst. Catalysts which are effective for use in the present process are those which promote hydrogenation of hydrocarbons. In general, the oxides of the Group VI metals and of the first transition series of Group VIH of the Periodic Table of the Elements are effective catlysts. Solid catalyst, such as oxides or sulii-des of molybdenum, tungsten, zirconium, chromium, vandium, iron, cobalt or nickel on a suitable carrier material, for example, silica, magnesia, alumina, bauxite, alumiunm silicate or clay, are suitable known hydrogenation catalysts. A preferred catalyst comprises 1.5 to 5 weight percent cobalt oxide and 7 to 14 weight percent molybdenum yoxide on an alumina support. Preferably7 the vaporous products `of the hydroretorting operation are passed directly into contact with one or more beds of solid catalytic material, for example, cobalt molybdate on a suitable support.

The hydrocarbon products are suitably recovered from the fixed gases by condensation, absorption or a combination thereof. The remaining gases may be recycled to the process as desired, together with fresh feed hydrogen from a suitable source.

The fresh feed hydrogen may be produced economically by partial oxidation of a portion of the gas or loil product of the process. Partial oxidation of carbonaceous fuels to carbon monoxide has recently been developed commercially. Gaseous, liquid `or solid carbonaceous fuels may be converted to carbon monoxide and hydrogen by reaction at elevated temperature and pressure with free oxygen in a compact reaction zone free from catalyst and packing. The resulting carbon monoxide may be converted to hydrogen by reaction with steam in the water gas shift reaction to produce carbon dioxide and hydrogen. Removal of carbon dioxide from the resulting gas stream yields relatively pure hydrogen. From about 3 to about 13 percent of the recovered oil is suicient to supply all the hydrogen required for the process, the lower figure corresponding to hydrogen consumption of about 600 s.c.f. per barrel, and the higher, to about 2600 s.c.f. per barrel.

The process of this invention will be more readily understood from the following detailed description taken in conjunction with the attached drawing.

FIG. 1 illustrates diagrammatically an arrangement of apparatus suitable for carrying out the present process.

FIG. 2 illustrates schematically an arrangement of apparatus wherein a plurality of retorts are employed.

FIG. 3 illustrates diagrammatically, a retorting vessel suitable for carrying out the process of this invention on a commercial scale.

With reference to FIG. 1 of the drawing, oil shale crushed to a particle size not greater than 2 inches in diameter is charged into a retort 1 in the form of a pressure vessel, wherein it is contacted with hydrogen-rich gas at elevated pressure and temperature, hereinafter specified, for a period of time sulicient to effect substantially complete recovery of hydrocarbons from the oil shale. The shale in the retort is maintained in a settled bed condition, as distinguished from a fluid bed or a suspension or entrainment operation. The shale may be processed batchwise in a stationary bed or continuously in a downwardly moving bed or in an upwardly moving bed.

ln a continuous processing operation, shale is introduced continuously or intermittently into the upper portion of retort 1 while residue is removed continuously or intermittently from its lower portion. The rate of introduction of oil shale and withdrawal of residue is regulated so that the time of contact between the hydrogenrich gas and the oil shale is within the range of about 20 minutes to 5 hours and sufficient to effect substantially complete recovery of hydrocarbons from the shale. The incoming oil shale may be preheated to about 700 F. or higher, suitably by contact with a hot gas substantially inert with respect to the oil shale and its hydrocarbon content, for example nitrogen, steam, or ilue gas although preheating of the shale is not essential.

Hydrogen-rich gas is preheated in heater 2 to a temperature in the range of about S50 to 1,000o F. and introduced into the retort. The hydrogen-rich gas passes upwardly through the particles of oil shale in the retort at a velocity below that required to expand the bed of shale, or luidize the particles, and insu'icient to entrain more than a minor amount of Laolid particles in the gas stream. Hydrogen-rich gas containing recovered hydrocarbons from the oil shale is passed to catalyst chamber 3 containing a hydrogeuation catalyst effective for hydrogenation of hydrocarbons in vapor phase.

Heater unit 4 may be provided to maintain the temperature of the gases and vapors reaching the catalyst chamber within the desired operating range for optimum improvement of the retorted oil by the vapor phase hydrogenation reaction taking place in catalyst chamber 3. Generally, in batch operations, it is desirable to pass the gases and oil vapors through heater 4, at least during that period of the cycle in which oil vapors carried over from the retort in the gas stream in appreciable amounts are at a temperature below about 700 F. When the retort is operated in a continuous manner, heater 4 may be used or not depending upon the temperature of the gas stream containing oil vapors leaving the upper portion of the retort. Since the temperature of the eflluent stream from the retort is dependent to a large extent upon the temperature of the shale at the gas outlet from chamber 1, it will be evident that by preheating the incoming oil shale the temperature of the oil at the gas outlet point may be maintained suiciently high that heater 4 is unnecessary. In latter case, the hydrogen-rich gas and accompanying oil vapors may be passed directly to catalyst chamber 3 via line 6.

The unit 4 may take the form of a turbulent-flow hydrogenation unit in which the oil and hydrogen are subjected to highly turbulent flow in a conduit at a ternperature in the range of 800 to 1500 F. and a pressure in the range of 1000 to 2500 pounds per square inch gauge for a reaction time of at last ve seconds. Turbulent flow hydrogenation is described in my copending application, Serial No. 740,138, filed June 5, 1958. In turbulent flow hydrogenation, the ow rate of hydrogen and oil are correlated with conduit diameter and reaction temperature and pressure to give the desired turbulence level. It has been found that the ratio of average apparent viscosity of the flowing stream, Em, to the molecular or kinematic viscosity p. should be at least 25 and preferably in the range of 50 to 1000. Em may be defined in terms which may be determined by physical measurements by the following equation:

fifa@ 15 2a dit Wherein clp/dx is the pressure drop in pounds per square foot per foot of conduit length; g is the acceleration of gravity in feet per second; ro is the radius of the conduit in feet; and a is the specific weight of the flowing uid in pounds per cubic foot.

The gases and vapors from the catalyst chamber 3 are passed to cooler 7 for condensation of the readily liqueable hydrocarbon from the gas stream. Gas and liquid are separated from one another in separator 8. The gas is recycled via line 9 to compressor 10 Where it is returned to heater' 2 and to retort 1. Hydrogen required for the process is supplied from a suitable source through line 11. Liquid is withdrawn through line 12.

If desired, catalyst chamber 3 and cooler 7 may be bypassed. Thus in batch processing oil shale, effluent gases from the retort may be passed through line 6 directly to separator 8 and recycled without cooling during a portion of the cycle. If desired, gases from retort 1 may be drawn through a suitable guard separator 13, to effect removal of solid particles and entrained liquid, directly to recycle line 9. This latter procedure may be desirable in batchwise processing of the oil shale during the preheating period, i.e. during the period in which the charge of oil shale in the retort is being heated up to a temperature of about 600 F.

In the continuous processing of oil shale, as outlined hereinabove, it may also sometimes be desirable to withdraw a portion of the gaseous eluent from retort 1 from a point above the point of product Withdrawal, e.g. via separator 13 for direct recycle. By this means the temperature of the effluent stream withdrawn through line 6 may be maintained at the temperature level desirable in catalyst chamber 3 without the necessity for preheating the incoming oil shale or alternatively the use of heater 4. When gases are withdrawn to separator 13, readily condensable hydrocarbons contained in the gas stream are condensed on the relatively cool oil shale, serving to preheat the shale. Hydrocarbons so condensed are revaporized at a lower point in the retort and recovered through product line 6.

In batch processing operations a series of retorts may be used with suitable switching arrangements to permit the retorting vessels to be connected with various inlet and outlet lines in sequence to preheat the shale, retort the shale, and cool the residue.

FIG. 2 of the drawing illustrates diagrammatically an arrangement of apparatus for carrying out a batchwise hydroretorting of oil shale in a series of retorts in accordance with the present invention. As illustrated, pressure vessels 16, 17, 18, 19, 2t) and 21 are arranged for treatment in sequence in the order illustrated. The piping is arranged so that the various pressure vessels may be IRI! connected in a cyclic manner to provide the ow pattern illustrated in the figure. It is to be understood that neither of the specific arrangements illustrated nor the specific number of vessels is to be taken as limiting our invention.

In operation, retort 16 is charged or recharged, while the remaining retorts are connected for gas circulation. Residue from a previous retorting opeation is discharged from retort 16 and fresh oil shale in the form of particle no larger than 2 inches in average diameter is charged to the retort. Numeral 17 designates a pressure vessel which has been charged with fresh shale and is undergoing preheating. Preheating of the fresh shale may be accomplished in a number of ways. In the specific embodiment illustrated in FIG. 2, the preheating is accomplished by means of circulating hydrogen-rich gas preheated by contact with hot residual shale resulting from the hydroretorting operation. In this particular example, hydrogenrich gas is passed through spent or residual shale in retort 21 Where it is heated to a temperature, of the order of 500 F. for example, and then passed over the fresh shale in retort 17 to preheat the fresh shale. Gas discharged from retort 17 is passed to cooler 22, then through separator 23 to compressor 24 for recirculation.

Following preheat of the oil shale (as illustrated, in retort 17), the shale is preheated further :and retorting started by passing hot hydrogen-rich gas, for example, at a temperature of the order of 900 F., over the shale particles. Efuent gas from retort 18 may be processed directly for recovery of oil or passed through a second retort 20from which a considerable portion of the hydrocarbons have been retorted, depending upon. the temperature and hydrocarbon content of the effluent. The retorting is completed in retort 20 to which heated gas or cold recycle gas may be supplied as required. In retort 20, retorting is completed and the residual shale is cooled moderately, e.g. to a temperature of the order of 500 to 600 F. Effluent gas containing hydrocarbon vapors from retort 20 passed to catalyst reactor 26 in which the hydrocarbons recovered from the oil shale are subjected to catalytic treatment with hydrogen at reactor pressure and a temperature above 800 F. Some vapor phase hydrogenation of the hydrocarbons takes place in reactor 26 in which the catalyst preferably is disposed in a series of beds 27.

Hydrogen-rich gas and hydrocarbon leaving the catalyst chamber 26 pass through heat exchanger 28, wherein they are cooled by heat exchange with cold hydrogenrich gas, and through cooler 22 for further cooling sufiicient to effect condensation of readily condensible hydrocarbons, and are then passed to separator 23 maintained at substantially retort pressure. In separator 23, condensed liquid is separated from residual gases comprising hydrogen and gaseous hydrocarbons recovered from the oil shale. The gases pass to compressor 24 and are recirculated to the retorts.

Hydrogen from a suitable source, preferably in relatively pure form, is introduced to the system as required through line 29. From compressor 24, a part of the hydrogen-rich gas is passed to retort 21 as previously mentioned. A further portion of the hydrogen-rich gas passes through heat exchanger 2S where it is heated by indirect heat exchange with the product from catalytic reactor 26, for example, to a temperature of the order of 600 to 700 F. and then passed through heater 31 Wherein it is heated to a temperature in the range of 800 to 950 F. A part of the gas from heater 31 is passed to retort 18 in which recovery of hydrocarbons from the shale is initiated and further portion of the heated gas is passed to retort 19 in which recovery of hydrocarbons from previously heated and partially retorted shale is continued. Gaseous effluent from retort 19 containing hydrocarbon vapors is passed to catalytic reactor 26. The mixture of shale oil vapors and hydrogen from the retorts may be subjected to turbulent flow hydrogenation (not 7 illustrated) as described hereinabove in connection with FIG. 1.

In the sequence illustrated, a period of time for each operation in the range of to 45 minutes is usually adequate. It will be appreciated that the time requirements will depend to some extent on the particle sizes of the oil shale and the depth of the shale bed in each of the retorts. It will be evident that the larger particle sizes require longer heating times than do the smaller particles. The minimum time requirement, therefore, is largely dependent upon the time required to process the largest shale particles in the charge to the retorts. As previously indicated, a period of two hours above 800 F. is generally adequate for pieces up to 2 inches in diameter. During the retorting periods proper, i.e. the period following the preheat, during which hydrocarbons are vaporized from the shale particles, the bed depth has considerable effect upon the time required for retorting a given amount of shale. The results of a number of trial runs, data for which are reported in the following examples, indicate that it is possible to recover the hydrocarbon from oil shale substantially completely in about minutes at a temperature in the range of 800 to 950 F. with hydrogen at a pressure in the range of 1,000 to 2,500 p.s.i.g. It will be appreciated however that in a bed several feet in depth, the zone of actual retorting extends over only a portion of the entire shale bed. For example, in retort 19 of FIG. 2, shale in the lowermost portion of the vessel is completely retorted. As the hot gas from the heater ascends through the portion of the shale bed in which retorting is complete, the temperature of the hot gases remains essentially constant and the residual shale particles are substantially inert with respect to the processing gas stream. At a somewhat higher level in the bed, hydrocarbons liberated from the oil shale are undergoing vaporization from the shale and simultaneous reaction with hydrogen contained in the processing gas stream. The net effect of these reactions is an endothermic one. Consequently, the temperature of the gas stream beings to fall as it ascends through that portion of the bed in which hydrocarbon vapors are liberated from the shale. In this connection it should be noted that the liquid product from the oil shale has an atmospheric boiling range of from about 140 to about 725 F. (Example 1). As the processing gas containing these hydrocarbon vapors ascends to a still higher level in the shale bed, a part of the oil vapor is condensed by contact with the cooler shale in the upper portion of the retort. The high temperature retorting zone moves slowly up through the bed of oil shale. It will be apparent that the depth of the bed has an appreciable effect on the length of time required for retorting. The superficial linear gas velocity in the retorts generally is in the range of 0.005 to 0.5 feet per second, preferably 0.01 to 0.25 feet per second. Low gas velocities prevent entrainment of ne particles of residue in the processing gas stream. At the same time, the temperature of the processing gas stream is limited to a maximum of about 950 F. Consequently, relatively shallow large beds of shale are preferred for retorting. A preferred retort is illustrated in FIG. 3.

With reference to FIG. 3, the numeral 40 designates a pressure vessel shell adapted to withstand operating pressure and provided with a liner of refractory insulating material. The preferred form of retort is a horizontal cylinder as illustrated with a plurality of loading nozzles 41 along its topmost surface and a plurality of ash discharge nozzles 42 along its lowermost surface. Nozzles 41 and 42 are provided with suitable Valves 43 and 44 to permit the flow of crushed shale into the retort and the withdrawal of residue from the retort and to effectively seal the nozzles against pressure during the retorting operation. Crushed oil shale of a suitable size for retorting is applied to nozzle 41 from feed hopper 45. Hydrogen-rich gas is introduced to the retort through line 46 and nozzles 47 and distributed throughout the shale bed by perforated plates 48. Processing gas and hydrocarbon vapors are collected by a perforated header 49 in the upper portion of the retort above the normal level, indicated by dashed line 51, of the oil shale during the retorting operations. Effluent gas and hydrocarbon vapors from the retorts are discharged through line 52 for further processing, for example as illustrated in FIG. 2. The process of this invention is further illustrated in the following examples reporting data from a number of runs made in accordance with the above described process.

EXAMPLE 1 Colorado oil shale having a Fischer Assay of about 43.5 gallons per ton Was crushed to 11/2 inch maximum size and treated with hydrogen in a vertical reactor 6 inches in diameter by l2 feet long. Runs A and B, reported in Table l below, represent composite data from several batches of shale. The reactor was charged with to 150 pounds shale per batch, pressured with hydrogen, and circulation established. The gas at a rate of about 7,000 s.c.f.h., was passed through a preheater, up through the reactor, through a cooler and a condensate separator and back to the heater. Makeup hydrogen was added as required to maintain pressure. rThe temperature of the hydrogen was then raised to 800 to 900 F. and circulation continued 3 to 4 hours. When the temperature of the gas stream at the top of the reactor reached 800 F., circulation of the gas stream was continued for two hours. Inspection of the residual shale from the reactor showed no apparent difference from top of the reactor to the hydrogen inlet, evidencing that shale treated for the minimum period of time (at the top of the reactor) was as effectively extracted as that treated for the entire period.

Operating conditions and results are shown in Table 1, in comparison with the standard Fischer Assay described in U.S. Bureau of Mines, RJ. 3977 (October 1946). Each run represents several batches of shale processed in the reactor. The characterization factor, K.V., an index of the type hydrocarbon recovered, is described by Watson, Nelson, and Murphy, Ind. Eng. Chem. 25,880 (1933); 27, 1460 (1935).

These data show the substantial increase in oil yields over the Fischer Assay and improvement in API Gravity, pour point and yield of distillate, as compared with oil from the Fischer Assay.

EXAMPLE 2 A series of runs were made with the same oil shale and retorting apparatus as was used for Runs A and B of Example 1. Substantially pure hydrogen was used as the retorting gas in each case. The total effluent from the shale was passed without condensation or separation of vapors, into direct contact with a hydrogenation catalyst in the form of 1A; inch pellets comprising 3.1 weight percent cobalt oxide and 8.5 weight percent molybdenum oxide on alumina. In Run C, 15 pounds of catalyst was placed in the reactor, directly above the shale bed. The catalyst bed was approximately 15 inches in depth. In Runs D and E the actalyst was contained in a separate vessel, four feet long and three inches inside diameter filled with the catalyst (a total of about l2 pounds). The total efiiuent from the hydroretorting reactor was passed directly to the catalyst chamber without heating or cooling. In Run F, the total effluent from the retort was heated before contacting the catalyst in the catalyst vessel. Runs E and F illustrate the effect of the temperature of the catalytic treatment of the hydrocarbon vapors on product quality. In each case, the bulk of the oil vapors from each batch of shale passed over the catalyst in a relatively short period of time (estimated at about 15 minutes) so that the space velocity of oil vapors over the catalyst was relatively high. Operating conditions and results are shown in Table 2.

Table I Fischer Assay Run A Run B Retorting Gus None H2 H2 Retorti'ng Period, Hrs./Batch 4 3 Operating Conditions:

Pressure, p.s.i.g 1,802 1,803 Temperature. F Preheater Outlet 875 915 Overhead 642 662 Gas Flow, s,e.f.h 7,000 7,000 Yields. Product Lb Ash 570 329 133.1 86. 16. 0 4. 7 3. 7 3.3 1G. 7 16. 0 s 739. 439. 0 telcovcry. Wt. Percent 97. 7 96.4

Gals/Ton 43. 2Q 48. 17 52. 85 Percent Fischer Assay 100. 0 3 111 3 122 Water:

Gals/Ton 3. 5. 19 2. 55 Percent Fischer Assay 100.0 3 148 3 73 Hydrogen Consumption,

sx1/bbl. (Est.) 60G-800 600-800 Product Oil:

Gravity, API 25. 9 27. 1 Viscosity, SSU at 122 F 80. 0 59. 4 Carbon Residue, Wt.

Percent 1.10 1.05 0.63 0. 88 1. 42 1. 26 Pour Point, F 90 85 Distillation, F.-

IBF.-." 153 140 397 358 676 664 724 715 11.78 11.77 92. 5 93. 0 di e 7. 5 7. 0 Ash, Carbon Content, Wt.

Percent 4-5 2 00 0.83

1 Composite from Fischer Assays. 2 Typical Fischer Assay-10 Samples. 3 Based 0n Typical Fischer Assay (2).

Table 2 Run D Run E Run F Retorting Gas H2 H2 H2 Retorting Period, Hr. -5 4 3 Catalyst Cobalt Cobalt Cobalt Cobalt Molybdate Molybdate Molybdate Molybdate Operating Conditions:

Pressure, p.s.i.g -2, 000 1. 900 2,000 Temperature, cF.-

Preheater Outlet, Avg 920 910 930 Overhead, Avg 660 720 730 Catalyst Chamber Inlet 685 825 Gas Flow, s.c.f.h.,

Avg 6, 450 e, ooo Yields: Product, Lbs.-

Ash 1, 628. 5 305. 5 288. 0 407. 1 81. 3 71.6 82.8 9.2 16. 9 35. 3 4. 2 7. 2 Loss 11. 8 10. 8 22. 8 Total Shale Charged, Lbs 2, 165. 5 41.1. 0 406. 5 telcovery, Wt. Percent 99. 5 97. 5 94. 4

Gals/Ton 52. 04 Percent Fischer Assay 2 134 3 128 3 120 Water:

Gals/Ton 9.18 7. 53 Percent Fischer Assa 2 223 3 128 3 239 Hydrogen Consumption, s

. 1, 000-1, 2, 500 2, 700 4, 000 Product Oil:`

Gravity, API 32. 3 34. 5 32. 2 39. 4 Viscosity, SSU at 122 F 40. 9 41. 2 47. 3 33. 7 Carbon Residue, Wt. Perit 0, 37 0. 03 Trace 0. 06 0.43 0. 12 0. 13 0.06 0. 0. 77 1. 20 0. 49 80 90 45 K .V Recovery, Percent.- Residue Ash, Carbon Content, Wt.

Percent 0. 86 1. 07 0. 57

lBased on Typical Fischer Assay (2), Example 1.

2 Based on Fischer Assay avg. of 7 runs.

3 Based on Fischer Assay of 42.86 and 4.191bs. oil and H2O, respectively.

In all of the runs in this example, preheated hydrogen is passed up through the retorting vessel. Circulation was continued for a period of two hours after the temperature at the top of the shale bed reached 800 F. From one half to one hour was required to bring this 5 temperature up to 800 F. At the conclusion of the twohour period, the re in the preheater was cut out and the cool hydrogen circulated through the reactor until the temperature of the eiuent gases from the reactor had dropped to less 4than 150 F. 10

EXAMPLE 3 Runs were made with the same oil shale as in the foregoing examples using mixtures of hydrogen and carbon monoxide, and hydrogen and carbon dioxide as stripping gases. In each of the following runs, the procedure was the same as in Run F of Example 2. In Run G, the composition of gas initially supplied to the reactor and added as make up gas in the processing of each batch contained 69 mole percent hydrogen and 30 mole percent carbon dioxide. In Run H, the gas supplied to the reactor contained 57 mole percent hydrogen and 42 mole percent carbon monoxide. Operating conditions and results are Overhead Catalyst Chamber Inle Gas Flow, s,e.f.h

Yields, Product, Lbs.:

A 197. 5 411 Oil 53. 96. 6 Water 44. 5 39. 4 4() Gas 5. 6 15.8 Toltal Shale Charged, Lbs

Gals. /Ton 55. 39 48. 69 Percent Fischer Assay 1 129 1 114 Water:

Gals/Ton 40. 58 17. 60 Percent Fischer Assay- 1 968 1 420 45 Hydrogen Consumption, s,e.f./bblA (est.) 6,550 6,500 Product Oil:

Gravity, API. 28. 8 29.6 Viscosity, SSU at 122 F 49. 7 45.2 Carbon Residue, Wt. Percent 0. 38 0.65 Sulfur, Wt. Percent 0. 32 0. 46 Nitrogen, Wt. Percen 1. 46 1. 44 Pour Point, 85 85 50 Distillation, F.:

IBP

1Based on Fischer Assay of 42.86 and 4.19 Lbs. Oil and H2O,

respectively.

It will be noted from the a'bove data that there is a considerable increase in the relative quantity of gas and water produced. This indicates reaction between the carbon oxides and hydrogen. Hydrogen consumption in these runs was exceptionally high as compared with Runs C, D and E, of Example 2. The increase in water yield is particularly noticeable in the case of the carbon dioxide-hydrogen mixture. Water production is generally undesirable since it represents a direct loss of hydrogen to no useful product. The quality of the oil from Runs 70 G and H was not as high as that from Runs C, D and E. Run H however, shows a considerable increase in gas yield as compared with Runs C, D and E. Where gas is a desired product, e.g. for heating gas, operation as illustrated by Run H maybe desirable.

While the process of this invention has lbeen described and illustrated with specific reference to the treatment of oil shale, it is to be understood that it is equally effective for the processing of tar sands or oil sands.

Obviously, many modications and variations of the invention, as hereinbefore set forth, may be made without departing from the spirit and scope thereof, and therefore only such limitations should be imposed as are indicated in the appended claims.

We claim:

1. A continuous process for the production of hydrocarbon oils from oil shale by retorting with hydrogen which comprises maintaining a downwardly moving settled bed of oil shale particles in a vertically extended retorting zone, introducing hydrogen into the lower portion of said zone and passing hydrogen at a temperature within the range of from about 800 to about 950 F. at a rate of from about 25,000-to about 150,000 standard cubic feet per ton of shale per hour at a pressure within the range of about 1,000 to about 2,500 pounds per square inch gauge upwardly through said bed eiecting retorting of hydrocarbons from said shale, Withdrawing said hydrocarbons solely in vapor phase in admixture with unreacted hydrogen from said zone at an intermediate point below the top of said lbed and passing resulting mixture at a temperature above about 700 F. directly from said retorting zone into contact with a bed of solid catalyst effective for promoting vapor phase hydrogenation of said hydrocarbons, recovering resulting hydrocarbons from the vaporous efliuent of said bed of catalyst, recyling unconverted hydrogen to said process, withdrawing residual oil shale substantially free from carbon from the lower end of said retorting zone, introducing cold raw shale in particle form into the upper end of said zone as said residual shale is withdrawn from said zone to maintain said bed of shale particles therein, withdrawing hydrogen-rich gas substantially free from readily condensible hydrocarbon vapors from the upper portion of said zone above the point of withdrawal of said hydrocarbons in vapor phase, and recycling said hydrogen-rich gas to the lower portion of said zone.

2. A process for the production of hydrocarbon oils from the oil shale by retorting with hydrogen in a settled bed of oil shale particles in a vertically extended retorting zone, which comprises introducing hydrogen into the lower portion of said Zone and passing said hydrogen at a temperature in the range of 800 F. to 950 F. and at a pressure within the range of about 1,000 to about 2,500 pounds per square inch gauge upwardly through said bed at a rate of from about 25,000 to about 150,000 standard cubic feet per ton of oil shale per hour for a period of time within the range of 20 minutes to 5 hours effecting retorting of hydrocarbons from said shale as hydrocarbon vapors mixed with said hydrogen, and passing said mixture solely in vapor phase at a temperature above 700 F. over a bed of solid catalyst effective for promoting vapor phase hydrogenation of said hydrocarbons, recovering resulting hydrocarbons from the vaporous eftluent of said catalyst, recycling unconverted hydrogen to said process, and discharging residual oil shale substantially free from carbon from said retorting zone.

3. A process according to claim 2 wherein said catalyst is selected from the group consisting of the oxides and sullides of molybdenum, tungsten, zirconium, chromium, vanadium, iron, cobalt and nickel.

4. A process according to claim 2 wherein said cata* lyst is cobalt molybdate.

5. A process according to claim 2 wherein said catalyst comprises 1.5 to 5 weight percent cobalt oxide and 7 -to 14 weight percent molybdenum oxide on alumina.

6. A process according to claim 2 wherein said catalyst comprises molybdenum sulde.

7. A process according to claim 1 wherein said cata- 13 lyst consists essentially of oxides of cobalt and 2,694,035 molybdenum. 2,697,683 2,991,164 References Cited by the Examiner 3,117,072

UNITED STATES PATENTS 1,833,155 11/1931 Danner etal. 208-11 2,639,982 5/ 1953 Kalbach 208-11 Smith et al. 208-145 Engel et al 208-216 Elliott et al 208-11 Eastman et a1. 208-11 PAUL M. COUGHLAN, Primary Examiner.

ALPHONSO D. SULLIVAN, Examiner.

Patent Citations
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Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US3475317 *Dec 10, 1965Oct 28, 1969Huntington Morgan GMethod and apparatus for destructive distillation of solid hydrocarbonaceous materials including reactions between gases and unsized solids and the physical separation thereof
US3494855 *Jun 10, 1968Feb 10, 1970Universal Oil Prod CoDesulfurization of high metal black oils
US3539027 *Sep 20, 1968Nov 10, 1970Eaton Yale & TowneIntegrating conveyorized weighing system
US3922215 *Jun 1, 1973Nov 25, 1975American Gas AssProcess for production of hydrocarbon liquids and gases from oil shale
US4010092 *May 10, 1974Mar 1, 1977Union Oil Company Of CaliforniaOil shale retorting-gasification process
US4166786 *Dec 12, 1977Sep 4, 1979Occidental Petroleum CorporationPyrolysis and hydrogenation process
US4449994 *Jan 15, 1982May 22, 1984Air Products And Chemicals, Inc.Low energy process for separating carbon dioxide and acid gases from a carbonaceous off-gas
US4493763 *Jul 15, 1983Jan 15, 1985Exxon Research And Engineering Co.Pretreatment of oil-shale for enhanced arsenic removal
US4772379 *Oct 29, 1985Sep 20, 1988Ann Arbor Nuclear, Inc.Extraction and liquefaction of fossil fuels using gamma irradiation and solvents
US4950383 *Dec 8, 1989Aug 21, 1990The United States Of America As Represented By The Secretary Of The Air ForceCatalyst of nickel oxide, molybdenum oxide, phosphorus oxide, aluminumoxide and second catalyst of chromium oxide, cobalt oxide, molybdenum oxide and aluminum oxide
Classifications
U.S. Classification208/422, 208/419, 208/143, 208/408, 208/58
International ClassificationC10G1/00
Cooperative ClassificationC10G1/002
European ClassificationC10G1/00B