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Publication numberUS2694035 A
Publication typeGrant
Publication dateNov 9, 1954
Filing dateDec 23, 1949
Priority dateDec 23, 1949
Publication numberUS 2694035 A, US 2694035A, US-A-2694035, US2694035 A, US2694035A
InventorsBlanding Forrest H, Burgess Mason Ralph, Hemminger Charles E, Smith Lloyd B
Original AssigneeStandard Oil Dev Co
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Distillation of oil-bearing minerals in two stages in the presence of hydrogen
US 2694035 A
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Description  (OCR text may contain errors)

Nov. 9, 1954 Filed Dec. 23, 1949- TWO STAGES IN THE PRESENCE OF HYDROGEN 2 Sheets-Sheet l FLUE. GAS TD WASTE flEATBOIl-Ek &

12.4w sun LE DISCHA/ZC/NG t Pnooucr l GAS COOLING cAs I PREHEAT CARBON RETORT/NG .SHALE BUEN/Nq CHARGING SPENT T l .SHALE FUEL GAS 8 ABSORBER Nov. 9, 1954 L..-B. SMITH ETAL 2,694,035

DISTILLATION OF OIL-BEARING MINERALS IN TWO STAGES IN THE PRESENCE OF HYDROGEN.

Fi] ed Dec. 23, 1949 2 Sheets-Sheet 2 43 CYCLONE SHALE HOPPER ASSEMBLY /6 1F CYCLONE ASSEMBLY BURNER & COOLER N/O Ex/T T GAS /QEAC7'OR. 9;,

O 37 2 HOT 34 '/8 SOLIDS 69 I DISCARDED SHALE K SOLIDS om HOT STEA M oz. ,2 HOT INERT GAS I 3H2 45 A COOLER T L .7 47

HEATER 27 5/ aL wig 49 /24 STEAM 5o STEAM 8 1 STQIPPER 32 3/ 23 CONDEN.'SATE m T 30 a4 Ir 7 22 .B.M fag -2 2 m W M a r United States Patent DISTILLATION 0F OIL-BEARING MINERALS 1N avg STAGES IN THE PRESENCE or ypno- Lloyd B. Smith and Ralph Burgess Mason, Baton Rouge, La., and Forrest H. Blanding, Cranford, and Charles E. Hemminger, Westfield, N. J., assignors to Standard Oil Development Company, a corporation of Delaware Application December 23, 1949, Serial No. 134,771 6 Claims. (Cl. 196-.49.)

The present invention relates to the art of distilling oil-bearing minerals. More particularly, the present invention pertains to a novel process for the recovery of valuable volatile fuels, such as combustible gases, motor fuels, heating and fuel oils from oil-bearing minerals such as oil shale, oil sand, tar sands and the like, by retorting such minerals in the presence of extraneous hydrogen.

It is known that certain types of naturally occurring oil-bearing minerals, such as oil shales, contain materials which may be converted by a pyrolytic treatment into hydrocarbon oils in commercially feasible yields. Various techniques have been employed in commercial and experimental shale retorting processes including batchtype fixed bed operations and continuous procedures wherein the shale is passed in the form of a dense moving bed, a highly turbulent relatively dense fluidized bed or a dilute solids in-gas suspension through a retorting zone at suitable retorting conditions. Among these techniques, fluid operation has outstanding advantages because it combines continuity of operation with perfect uniformity of temperature and excellent heat transfer characteristics and thus afiords the greatest output per unit volume of reactor space and highest oil yields per weight unit of shale charged.

However, in spite of this considerable procedural ad vance the shale retorting art is still confronted with the serious problem of product quality. The kerogen of the shale, that is its hydrocarbonaceous constituent which is converted into hydrocarbon oils and gas in,

the course of the retortinq process, is very rich in organic sulfur and nitrogen which enter the product oil and complicate considerably its utilization for various fuel purposes. In addition, the crude oil produced is extremely heavy and yields only. small amounts of straight run motor fuel range hydrocarbon oils. Extensive and expensive refining operations are, therefore, required: to remove nitrogen and sulfur and to improve the motor fuel yield by destructive hydrogenation. and/or cracking 'of the heavy crude. A substantial improvement of the Quality of the crude oil product Without loss of normally liquid product is, therefore, urgently needed.

For these reasons, it has been. suggested. prior to the present invention to carry out the shale distillation- 111; the presence of steam and hydrogen at extremely short contact times and at conditionsconducive to a. reaction of the. steam with the shale coke. to form. hydrogen and carbon oxides and to a hydrogenation of the shaleoil by the hydrogen produced. While this procedure may increase the proportion of low boiling hydrocarbons and reduce the amount of sulfur and nitrogen in theoil removed, the extreme temperatures required are conducive to excessive cracking and gas formation whereby. the

total oil yield is seriously affected.

The present invention overcomes these difliculties and affords various additional advantagesas will appear from the description below wherein reference. will be:

made to the accompanying drawing.

In accordance with the present invention, the distilla: tion of oil shale is carried out. in the presence of; extraneous hydrogen at relatively mild temperatures not exceeding about 1.100" F. and preferably within a range of about 700900 F. at elevated pressures and for contacttimes suflicient. tocause at least a substantialreduction of the sulfur and nitrogen content of the product; 80

within the widera'nge of.

oil. While pressures varying from about 500 to 10,000 p. s. i. g. may be used, it has been found that pressures even substantially below 1000 p. s. i. g. and particularly Within the range of about 600800 p. s. i. g. give excellent and normally superior results with respect to total oil yield, product gravity, as Well as sulfur and nitrogen content so that substantial savings in equipment cost may be realized as compared with prior art procedures requiring pressures substantially in excess of 1000. p. s. i. g. Hydrogen feed rates of, say, about 5,,000-15,00.0 normal cu. ft. per ton of shale per hour may be used, feed rates of about 6,000-

10,000 normal cu. ft. preferred.

The contact time, i. e.,. the time for which the shale should be exposed to hydrogen at the above condition depends largely on the contacting technique employed. Fixed and moving bed operations, due to their poor heat transfer characteristics and ineflicient gas-solids contact, require relatively the longest contact times averaging about 5-15 hour's. Relatively short contact times may be employed in fiuidetype operation which is the preferred technique for carrying out the process of the present invention. However, even when employing the preferrd embodiment of the invention, contact times of at least 1 minute and preferably about 1 to 4 minutes should be used.

It has also been found that the hydrogen treatment of the invention may be employed. with excellent results in stages involving a hydrogen-soaking stage carried out at relatively low temperatures of, say, about 650-750 F. preceding the distillation stage proper carried out in the presence of hydrogen at temperatures of about 800-950 F. The soaking stage may amount to about 5-15 hours followed by retorting for about an.- other 1-5 hours, in fixedbed'batch operation.

flhe hydrogen may besupplied in substantially pure form or in the form of suitable gas mixtures rich in hydrogen. In this respect, it is interesting to note that experimental data indicate'a beneficial influence of the resence of carbon monoxide in addition to hydrogen. Ratios of carbon monoxide tohydrogen up to l and even higher than 1 may be successfully used with frequently improved results with. respect to. total oil yield. Relatively inexpensive hydrogen-containing gases, such as water gas, synthesis gas, or the like, are, therefore, particularly suitable for the purposes of the present in.- vention.

A further embodiment of the invention involves the addition of small amounts of inorganic polar compounds, such as water, sodium hydroxide, calcium chloride and the like, to the shale undergoing the hydrogenatingretorting treatment in accordance with the invention. Additions of this type amounting to as little as about 2-10 lbs. per ton of shale have been found to be conducive to apreciable improvements. withrespect to oil yield and/or product quality.

All embodiments of the invention may be carried out inthe presence of suitable hydrogenation and/or'eraclc ing catalysts to improve product quality and permit the use of milder reaction conditions. Particular advantages are secured when catalysts volatile at the reaction conditions are used which may be readily added to the feed gases of the process in. desirable proportions of about 50-300 lbs.'per ton of shale. Preferred hydrogenation catalysts of this type are thecarbonyls of iron, cobalt and nickel. Volatile cracking catalysts suitable for the purposes of the invention include the halides of hydrogen, aluminum, zinc, boron and phosphorus.

Many of, the advantages of the invention may be realized independently of the specific retorting technique employed and practically all conventional procedures may be readily adapted for. the purposes of the invention. Two examples of such adaptions are illustrated in the attached drawing wherein per ton of shale per hour being Figure l is a schematical flow plan.of afixed bed batch,-

type procedure suitable to carry out an embodiment of the invention; and

process of the invention.

These systems will be brieny described hereinafter for a fuller understanding of the invention.

Referring now to rigure l of the drawing, the system shown essentially comprises a series of pressure-resistant fixed bed treating zones 1, 2, 3, 4, and 6 which are operated in cyclic rotation for the purposes of discharging, gas preheating, carbon burning, retorting, product cooling and shale charging, as indicated in the drawing, to provide a substantially continuous flow of product oil. A typical complete cycle is about as follows:

A series of at least four vessels are in active use. In vessel 2 product tail gas may be preheated and cracked by hot burnt shale to produce hydrogen at temperatures of about l200lS00 F. Steam may be added at this point to produce CO and additional hydrogen by a reaction of the steam with residual shale carbon. Unreacted steam and the CO formed have a beneficial effect in the subsequent distillation, as previously pointed out. In vessel 3 retorted shale may be heated to about 1500- 2000 F. by burning residual carbon with air with or without recirculation of fine gas to control the temperature in the bed, that is, to avoid flame fronts. Steam may also be added to the air for this purpose and to produce combustible gas from the carbon left on the shale. In vessel 4 fresh shale is subjected to distillation temperatures in the order of 800-l000 F. in the presence of hydrogen. In vessel 5 the hot product gases and vapors are contacted with fresh shale and a large portion of the distilled oil is condensed onto the shale and drips out of the bottom of the vessel. Of course, two or more vessels may be used in each of these functional steps. As the shale is exhausted during retorting in the original vessel, the valves are changed, say, after a period of about 12 hours, so that the vessels change places, that is, the spent shale is subjected to burning and the burnt shale from the previous operation is used to preheat the gas and product Hz. The raw shale which was being preheated by condensation and cooling of the retorting gas now is subjected to higher temperatures so that distillation takes place. A new vessel with raw shale is then introduced to cool the gases. The cooled shale from the first of the above series of vessels is discharged. Separate vessels 1 and 6 may be provided for the stages of charging fresh shale and discharging cool spent shale. Subsequent cycles are exemplified by the tabulation below:

The recirculating gas for this operation is the fixed hydrocarbon gases from the operation which has been passed through gas recovery equipment, such as a condenser 8 and an absorber 10, to remove most of the light hydrocarbons. An important element of the design is that this gas is subjected to temperatures in the order of 12001500 F. in the vessel containing the burnt shale. Thus, the gases entering the retort are sufiiciently hot to heat the shale therein and part of the lighter hydrocarbons, as ethane and propane, left in the gas after the gas recovery plant are cracked to produce hydrogen. This hydrogen is then available to react with the compounds in the shale so that a higher grade crude oil results than otherwise would result from the retorting of the shale. The pressures in the vessels may be of the order of 300- 700 p. s. i. g. This pressure decreases the size of the vessels and increases the hydrogenation effect. No large compression plant is necessary to attain this pressure be-. cause the recirculating gas is maintained at this pressure throughout the system.

While the above procedure has certain advantages in that it avoids problems connected with shale disintegration and mechanical handling of the shale, a fully continuous system of the fluidized solids type is preferred for the purposes of the invention from the point of view of capacity and yields. An example for this type of operation is illustrated in Figure 2 and will now be briefly described with reference thereto.

Referring now to Figure 2, the system shown therein is essentially of the conventional so-called two-vessel type comprising a fluid-type retortll) and a separate fluid-type burner 3:, both of conventional design. in operation, raw coarse shale is fed from a pressurized lock hopper 1 through line 3 to an upper portion of retort 10. Hot burned shale from burner 35 is supplied via line 37 to a lower portion of retort 10 to maintain suitable distillation temperatures of about 800950 F. in retort 10, all in a manner known per so. A gas rich in hydrogen, such as substantially pure H2 or suitable mixtures of Hz and CO is fed from line 12 to the bottom of retort 10 at a rate sufiicient to hydrogenate and fiuidize the shale which disintegrates upon retorting to a readily fiuidizable particle size so that a highly turbulent solids phase is formed having an apparent density of about 10-40 lbs. per cu. ft.

Volatile retorting products and excess feed gas are Withdrawn through line 16, preferably via a gas-solids separator 13 from which separated solids may be returned to retort 10 through dip-pipe 14. The hot retort effluent is passed through a condenser 17 to a separator 18 wherein liquid product is separated from tail gas. Product oil is recovered through line 19 for further treatment. A portion of the tail gas may be vented through line 20. The remainder of the tail gas may be passed through a conventional absorber for light hydrocarbons (not shown) and then returned by means of pump 22 via line 24 and a preheater 25 to line 12 and retort 10. Make-up feed lgas, 2%1011 as H2 or H2+CO may be supplied through Shale retorted in retort 10 is withdrawn through line 27 from the bottom of retort 10 and passed to a fluidized stripper 29 similar in construction to retort 10. Super heated steam and/or hydrogen gas from line 24 may be introduced to the bottom of stripper 29 via lines 30 and 31 to strip adhering distillation products from the shale. Stripper 29 may also be operated as a second retorting stage operated at a temperature higher than retort 10 when the latter is used as a hydrogen-soaking zone operated at a relatively low temperature, as previously described. I

Completely retorted and stripped shale is passed through line 32 into line 34 wherein it is picked up by combustion air and passed to burner 35 to form a dense fluidized mass of burning shale therein. The air feed rate is so controlled that the burner temperature is maintained by about 50-200 F. higher than the temperature of retort 10. Hot recycle shale is returned to retort 10 through line 37 as described above at a rate of about 5-20 lbs. per lb. of fresh shale charged. Excess solids may be discarded via line 39. The gases are withdrawn overhead. from burner 35 through line 41, if desired, via a gas-solids separator 43.

Off-gases from stripper 29 may be passed through line 45 either to a separate condenser 47 and settler 49 or via line 16 to cooler 17 and separator 18. Liquid separated in separator 49 may be recovered through line 50 and off-gas may be returned via line 51 to recycle line 24.

In both systems illustrated, additional materials such as polar inorganic compounds and volatile catalysts may be supplied either with the fresh shale or to the gas feed lines of the distillation retorts in a manner obvious to those skilled in the art. Various modifications of these systems are within the skill of the expert.

The advantages afforded by the present invention will be further demonstrated by the experimental data reported below.

Example 1 sure and temperatures of 900l000 F. The Fischer assay or Fischer yield test is mentioned in The Science of Petroleum by Dunstan et a1. 3108, and is described in detail in Zeitschrift Angewandte Chemie, vol. 33 (1920), pp. 172-175. Various addition agents were added by impregnation of the raw shale.v For comparison, another batch of the same raw shale.-

(Oxford, 1938), page;

was subjected to a conventional Fischer assay test. The conditions and results of these tests are tabulated below:

duction of oil, and thereafter retorting said hydrogen treated shale also in presence of hydrogen, at a tem- Fischer 1 Assay Added Component Tlgst of None None H NaOH C8012 aw Shale Method 01' Addition (2) Soaking Gas Hz H: H1 H2 H1 Pressure, p. s. i. g 750 2, 900 2, 800 750 750 Soaking Temp., F 700 700 700 700 700 Hours of Soaking Run 12 12 12 12 12 Total Recovery, Wt. Percent 98 98 97 98 Fischer Retorting of Oil Shale Oil Yield, Gal./Ton 30.2 32.4 31.4 31. 2 26. 6 33. 5 Oil Gravity, API--- 21. 5 27. 4 24.4 32. 1 28. 9 25. 9 Sulfur in Oil, Wt. Percent 0. 7 0. 301 0.301 0. 270 Nitrogen in Oil, Wt. Percent 2 1.85 1. 93 1.99

1 5% of Shale Direct to Autoclave.

2 Impregnation of Shale with 5% Solution and Dried. The above data demonstrate the beneficial influence of hydrogen retorting in accordance with the invention with respect to total oil yield and product quality showing a substantial drop in sulfur and nitrogen and an appreciable increase in the API gravity. The addition of water further favored API gravity while the addition of CaClz resulted in a further increase of the total yield. The somewhat lower yield in presence of sodium hydroxide is offset by the increase in API gravity and decreased sulfur content of the product.

Example [I assay retortings were used for comparison. The detailed conditions and results of these experiments are tabulated below:

conducted under elevated pressure below about 1000 p. s. 1. g.

2. The process of claim 1 in which a minor proportion, based on shale, of an inorganic polar compound is added to said retorting zone.

3. The process of claim 2 in which said compound is water.

4. The method of claim 2 in which said compound is NaOH.

c 50.1 The method of claim 2 in which said compound is 6. The process of claim 1 in which said oil shale is present in said retorting zone in the form of a turbulent, dense fluidized mass of subdivided solids and at least a substantial portion of said heat is supplied in the form of sensible heat of hot shale distillation residue burned and heated to a temperature higher than said first-named lxscher T t d lAischer T t d IXscher ssay rea e ssay rea e ssay Raw Product A Treated Product B Treated C D E Shale Shale Product Run Hours 1-12 1-4 7-12 1 Extraneous Feed.-. H20 H20 -.f 3. GRate, gals/Tom H 0.99 1.1 as ea 2 Hz H 1:1 H 00 Rate, cu.it./Ton/Hr 8, 200 7, 360 8, 030 8,400 2+ 9, 100 Pressure, p. s. 1. g 750 750 75 750 750 Temperature, F 900-1000 720 724 883 706 883 Material Bal., Percent 99 Treated Treated Treated Treated Treated Treated Product Product Product Product Product Product Oil Product:

Yield, Gals/Ton.-. 23.9 22.1 9.5 19.3 7.1 28.7 7. 8 29.3 8.0 28.3 Gravity, A. P. I 19. 4 20. 1 23.1 24 26. 1 26. 7 26 24. 3 26. 8 26.8 Sulfur, Wt. Percent. 0. 79 0.47 0. 23 0.3 0. 74 0.31 0.30 0. 72 0. 31 Nitrotgcn, Wt. Per- 2 2 54 1 95 9 con 1- 6 2. 79 1. 86 2. 44 1. Total Oil Yield 23.9 31.6 19.3 35.8 37.1 36.3 2 57 The above data demonstrate the beneficial influence of two-stage operation (see runs C and E) and the improvement afiorded by the use of water in combination with Hz (see run D) with respect to total yield and sulfur content. Also some decrease in nitrogen content was obtained and it has tentatively been established that the nitrogen content of the hydro stripped oil is more amenable to removal by acid washing than that remaining in the retorted oil.

The above description and exemplary operations have served to illustrate specific embodiments of the invention but are not intended to be limiting in scope.

What is claimed is:

1. The process of producing oil from subdivided oil shale which comprises first soaking said shale at 650 to 750 F. in a gas containing substantial proportions of hydrogen, amounting to 6000 to 10,000 cubic feet of hydrogen under standard conditions per ton of shale, for a period of about 5 to 15 hours to obtain incipient protemperature in -a separate combustion zone and supplied to said retorting zone at said higher temperature.

References Cited in the file of this patent UNITED STATES PATENTS

Patent Citations
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US1343100 *Aug 28, 1917Jun 8, 1920William Thurlow EdwardMethod of obtaining motor-fuels and light paraffin-oils from shale; and benzene, toluene, and solvent naphtha from coal
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Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US2721169 *May 21, 1954Oct 18, 1955Exxon Research Engineering CoDesulfurization of fluid coke with oxygen and hydrogen
US2768939 *Sep 13, 1954Oct 30, 1956Exxon Research Engineering CoIntegrated fluid coke desulfurization process
US2793172 *Jul 23, 1954May 21, 1957Exxon Research Engineering CoIntegrated fluid coke desulfurization process
US2872383 *Jul 7, 1954Feb 3, 1959Exxon Research Engineering CoDesulfurization of high sulfur fluid coke particles
US2872384 *Nov 30, 1954Feb 3, 1959Exxon Research Engineering CoDesulfurization of fluid coke with hydrogen above 2400deg. f.
US2884371 *Dec 30, 1954Apr 28, 1959Exxon Research Engineering CoHydrocracking shale oil
US2888395 *Mar 29, 1954May 26, 1959Universal Oil Prod CoHydrocarbon conversion process in the presence of hydrogen produced in the process
US2905595 *Sep 16, 1955Sep 22, 1959Union Oil CoTar sand distillation process and apparatus
US3074877 *Jul 1, 1959Jan 22, 1963Texaco IncMethod for recovering oil from oil-bearing minerals
US3224954 *Feb 3, 1964Dec 21, 1965Texaco IncRecovery of oil from oil shale and the like
US3377267 *Aug 6, 1965Apr 9, 1968Chevron ResVapor-liquid phase separation of hydroconversion process effluent with the use of hydrogen and steam
US3617469 *Dec 26, 1968Nov 2, 1971Texaco IncHydrotorting of shale to produce shale oil
US3617470 *Dec 26, 1968Nov 2, 1971Texaco IncHydrotorting of shale to produce shale oil
US3617471 *Dec 26, 1968Nov 2, 1971Texaco IncHydrotorting of shale to produce shale oil
US4468314 *Sep 1, 1982Aug 28, 1984Exxon Research And Engineering Co.Hydropyrolysis of carbonaceous material
US4469584 *Sep 1, 1982Sep 4, 1984Exxon Research And Engineering Co.Process for pyrolyzing oil-shale
US4545891 *Mar 30, 1982Oct 8, 1985Trw Inc.Dispersion in alkali metal solutions
US4594141 *Dec 18, 1984Jun 10, 1986The Standard Oil CompanyUsing an olefin and halogen compound in aqueous acidic media; pressurization
US5059307 *Oct 11, 1989Oct 22, 1991Trw Inc.Process for upgrading coal
US5085764 *Dec 19, 1989Feb 4, 1992Trw Inc.Process for upgrading coal
Classifications
U.S. Classification208/408, 208/115, 208/145, 208/412, 201/20, 201/45, 201/36, 208/89, 208/427, 208/126
International ClassificationC10G1/00, C10G1/06
Cooperative ClassificationC10G1/006, C10G1/06
European ClassificationC10G1/00D, C10G1/06