CA1231911A - Process and facility for upgrading heavy hydrocarbons employing a diluent - Google Patents
Process and facility for upgrading heavy hydrocarbons employing a diluentInfo
- Publication number
- CA1231911A CA1231911A CA000442425A CA442425A CA1231911A CA 1231911 A CA1231911 A CA 1231911A CA 000442425 A CA000442425 A CA 000442425A CA 442425 A CA442425 A CA 442425A CA 1231911 A CA1231911 A CA 1231911A
- Authority
- CA
- Canada
- Prior art keywords
- diluent
- crude oil
- mixture
- process according
- boiling point
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired
Links
- 239000003085 diluting agent Substances 0.000 title claims abstract description 81
- 238000000034 method Methods 0.000 title claims abstract description 45
- 229930195733 hydrocarbon Natural products 0.000 title claims description 23
- 150000002430 hydrocarbons Chemical class 0.000 title claims description 23
- 239000010779 crude oil Substances 0.000 claims abstract description 81
- 239000000571 coke Substances 0.000 claims abstract description 39
- 238000009835 boiling Methods 0.000 claims abstract description 25
- 238000002156 mixing Methods 0.000 claims abstract description 14
- 238000011033 desalting Methods 0.000 claims abstract description 12
- 230000018044 dehydration Effects 0.000 claims abstract description 6
- 238000006297 dehydration reaction Methods 0.000 claims abstract description 6
- 239000000203 mixture Substances 0.000 claims description 39
- 239000000047 product Substances 0.000 claims description 37
- 238000004821 distillation Methods 0.000 claims description 30
- 239000004215 Carbon black (E152) Substances 0.000 claims description 22
- 239000007789 gas Substances 0.000 claims description 22
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 17
- 229910001868 water Inorganic materials 0.000 claims description 17
- 239000007788 liquid Substances 0.000 claims description 16
- 150000003839 salts Chemical class 0.000 claims description 12
- 230000005484 gravity Effects 0.000 claims description 11
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 claims description 9
- 229910052717 sulfur Inorganic materials 0.000 claims description 9
- 239000011593 sulfur Substances 0.000 claims description 9
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 claims description 8
- PXHVJJICTQNCMI-UHFFFAOYSA-N Nickel Chemical compound [Ni] PXHVJJICTQNCMI-UHFFFAOYSA-N 0.000 claims description 8
- 229910052751 metal Inorganic materials 0.000 claims description 7
- 239000002184 metal Substances 0.000 claims description 7
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 6
- 239000008186 active pharmaceutical agent Substances 0.000 claims description 6
- 229910052799 carbon Inorganic materials 0.000 claims description 6
- 238000005292 vacuum distillation Methods 0.000 claims description 6
- 150000002739 metals Chemical class 0.000 claims description 5
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims description 4
- 229910052742 iron Inorganic materials 0.000 claims description 4
- 229910052759 nickel Inorganic materials 0.000 claims description 4
- 230000003134 recirculating effect Effects 0.000 claims description 4
- 229910052720 vanadium Inorganic materials 0.000 claims description 4
- LEONUFNNVUYDNQ-UHFFFAOYSA-N vanadium atom Chemical compound [V] LEONUFNNVUYDNQ-UHFFFAOYSA-N 0.000 claims description 4
- 238000004064 recycling Methods 0.000 claims description 3
- 239000013049 sediment Substances 0.000 claims description 3
- 239000011780 sodium chloride Substances 0.000 claims description 2
- 238000011144 upstream manufacturing Methods 0.000 claims 2
- 238000010438 heat treatment Methods 0.000 claims 1
- 238000000354 decomposition reaction Methods 0.000 abstract description 6
- 230000002028 premature Effects 0.000 abstract description 4
- 239000000463 material Substances 0.000 abstract description 3
- 239000003921 oil Substances 0.000 description 19
- 235000002639 sodium chloride Nutrition 0.000 description 7
- 238000004939 coking Methods 0.000 description 5
- 238000004519 manufacturing process Methods 0.000 description 5
- 230000003111 delayed effect Effects 0.000 description 4
- 239000012263 liquid product Substances 0.000 description 3
- 239000007787 solid Substances 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical class S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 2
- 230000015556 catabolic process Effects 0.000 description 2
- 238000005520 cutting process Methods 0.000 description 2
- 238000006731 degradation reaction Methods 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 238000005194 fractionation Methods 0.000 description 2
- 239000000446 fuel Substances 0.000 description 2
- 239000003502 gasoline Substances 0.000 description 2
- 239000002010 green coke Substances 0.000 description 2
- 239000003350 kerosene Substances 0.000 description 2
- 239000003915 liquefied petroleum gas Substances 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 239000002245 particle Substances 0.000 description 2
- 239000003209 petroleum derivative Substances 0.000 description 2
- 238000012545 processing Methods 0.000 description 2
- 229910052782 aluminium Inorganic materials 0.000 description 1
- XAGFODPZIPBFFR-UHFFFAOYSA-N aluminium Chemical compound [Al] XAGFODPZIPBFFR-UHFFFAOYSA-N 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000011329 calcined coke Substances 0.000 description 1
- 239000007795 chemical reaction product Substances 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 239000002283 diesel fuel Substances 0.000 description 1
- 238000005984 hydrogenation reaction Methods 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000010791 quenching Methods 0.000 description 1
- 230000000171 quenching effect Effects 0.000 description 1
- 238000007670 refining Methods 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G33/00—Dewatering or demulsification of hydrocarbon oils
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G7/00—Distillation of hydrocarbon oils
Landscapes
- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Engineering & Computer Science (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Organic Chemistry (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Coke Industry (AREA)
Abstract
ABSTRACT OF THE DISCLOSURE
A process and facility for upgrading heavy hydrocarbonaceous materials for making coke suitable for metallurgical purposes comprises mixing the heavy hydrocarbonaceous materials with a diluent having a closely controlled boiling range so as to facilitate transport, dehydration and desalting of the crude oil. In addition, the diluent aids in controlling temperature and residence time of the crude thereby avoiding premature decomposition.
A process and facility for upgrading heavy hydrocarbonaceous materials for making coke suitable for metallurgical purposes comprises mixing the heavy hydrocarbonaceous materials with a diluent having a closely controlled boiling range so as to facilitate transport, dehydration and desalting of the crude oil. In addition, the diluent aids in controlling temperature and residence time of the crude thereby avoiding premature decomposition.
Description
3~.~3~l~
BACKGRO'JI~'D OF ~HE INVEI~TION
The present ~nvention relates to a process and racility for upgradin~ heavy hydrocar~on2ceous materials, and more particularly, a proce~s and facility lor upgrading heavy crude oils generally characterized ~y high speci1ic gravities, high pour points, high viscosities and high contents of sulfur, metals, water, salt and conradson carbon ~or making coke suita~le for metallurgical purposes.
In the typical delayed coking process, residual oil is heated ~y exchanging heat with liquid products from the process and is fed into a fractionating tower wherein light end products producedin the process or present in the residual oil are separated by distillation. The residual oil is then pumped from the base o~ the fractionating tower through a tubular furnace under pressure where it is heated to the required temperature and discharged into the bottom of the coke drum.
The first stages of thermal`decomposition reduce this residual oil to volatile products and a very heavy tar or pitch which further decomposes to yield solid coke particles. The vapors formed during the decomposition produce pores and channels in the coke and pitch mass through which the incoming residual oil from the furnace must pass. The incoming oil and decomposition vapors serve to a~ltate and maintain the coke mass and residual oil mixture at relatively uniform temperature. This decomposition process is continued until the` coke drum is filled ~ith a mass of coke with a small amount of pItch. The vapors ~ormed i~ \
;~3~
leave the top of the coke drum and are returned to the fractionatinc tower where they a.e l`ractionated into the desired petroleum cuts. After the coke drum is filled with a mixture of coke particles and some tar, residual vapors are removed, and the coke is removed from .he drum hy hydraulic or mechanical means. This green delayed ~etroleum coke has particular crystalline and chemical properties which make it especially suitable for making carbon anodes for the aluminum industry, but the green coke must be calcined or carbonized by further treatment to produce a finished calcined coke product.
~ ue to the characteristics of the heavy crude oils of the type set forth above they cannot be processed economically by conventional processing. In addition to their low auality these crude oils are extremely temperature sensitive and decompose at relatively low temperatures. The processin~ and treatment of these crude oils at conventional conditions and in typical refining processes results in higher operating costs and the production of products which are predominantly of little value.
Naturally, it is highly desirable to provide a process and facility for upgrading heavy crude oils so as to allow for the economic production of valuable petroleum products. The process and facility of the present inve~tion should allow for the economic production of coke suitable for metallurgical purposes.
Accordingly, it is a principal object of the present invention to provide a process and facility for upgrading heavy crude oils.
In particular the present invention seeks to provide a process and facillty for upgrading heavy crude oils for use in the production of metallurgical coke.
The invention further seeks to provide a process and facility for upgrading heavy crude oils wherein a hydro-carbon diluent is employed to facilitate control of temperature and residence time thereby prohibiting premature decomposition.
Still further the invention seeks to provide a process and facility for upgrading heavy crude oils wherein the crude oil is carefully fractionated to maximize liquid yields during the coking step.
In accordance with one aspect of the invention there is provided a process for upgrading heavy crude oils for making coke suitable for metallurgical purposes which includes the steps of (a) mixing a diluent with incoming heavy crude oil SO dS to form a mixture of crude oil and diluent; (b) sub-jecting the mixture of crude oil and diluent to distillation whereby gas hydrocarbon products, an overhead liquid hydro-carbon product and a residuum are produced; (c) subjecting the overhead liquid hydrocarbon product to further treatment whereby naphtha and off gases are separated out as overhead products and a narrow boiling point diluent is produced;
(d) recycling the narrow boiling point diluent; and (e) mixing the narrow boiling point diluent with said incorning heavy crude oil.
In accordance with another aspect of the invention there is provided a facility or apparatus for upgrading heavy crude oils for making coke suitable for metallurgical purposes including (a) means for mixing a diluent with incoming heavy crude oil so as to form a mixture of crude oil and diluent;
(b) a distillation unit downstream of the means for mixing the diluent with incoming heavy crude for distilling the mixture into gas hydrocarbon products, an overhead liquid hydrocarbon product and a residuum product; (c) splitter means downstream of the distillation unit to further treat said overhead liquid hydrocarbon product so as to obtain a narrow boiling point diluent; and (d) recirculating mears for recirculating the narrow boiling point diluent to the means for mixing the narrow boiling point diluent with the incoming heavy crude oil.
The present invention relateS to a process and facility for upgrading heavy hydrocarbonaceous materials9 and more particularly a process and facility for upgrading heavy crude oils for making coke suitable for metallurgical purposes. The crude oils found in Orinoco Oil Belt of Venezuela are generally characterized by high gravities (close to that of water); high pour points (solid at ambient temperatures); high viscosities;
high metals, sulfur, water, salt and conradson carbon contents.
In addition, the crude oils are extremely temperature sensitive, that is they easily decompose at low temperatures. The process .~23~
INT~104 and facility of` the present invention allows for the economic production of petroleum products of upgraded -value such as LPG, gasoline, kerosene~ jet fuel, diesel oil and gas oils.
The process and facility employs the use of a hydrocarbon diluent with a closely controlled boiling range to facilitate transport, dehydration and desalting of the crude oil. Further, the diluent facilitates close control of temperatures and residence times thus avoiding premature decomposition and therewith degradation of coker yields. The process and facility also uses a coker fractionator and coker heater design intended to better control the quantity and quality of the coker recycle s-tream to minimize gas- and coke formation and improve the density of the produced coke. The process and facility utilizes a careful fractionation of the crude oil for front end control to ma~imize liquid yields in the coking step.
BRIEF DESCRIPTION OF THE DRAWING
The Figure is a schematic flow diagram illustrating the p:rocess and facility of the present invention.
DETAILED DESCRIPTION
The f`acility 10 and process of the present invention as shown in the drawing depicts the various stages of a delayed coke pilot plant including the facility for upgrading heavy crude 1~3 ~ IhlT~lO4 oil feedstocks. A typical heavy crude oil feedstock ~rom the Orinoco Oil Belt has the ~ollowing composition and properties:
TABLE I
.
Gravity API 8.o (1,0l4 Kg/ms) Sulfur, % wt 3.71 Mercaptans, wt ppm hlil Pour Point, F 80 Nitrogen, % wt 0.60 Water and Sediments, % Vol 6.4 Salt Content as NaCl, Lbs/1000 BBls. 500 Conradson Carbong % wt 13.8 H2S, wt ppm 37 Neutrali~a-~ion Number, mgr KOH/gr 3.95 MNI, % wt 13.54 Asphaltenes, % wt 7.95 UOP K Factor 11.3 Viscosities:
XV at 180F, cst 118LI
KV at 140F, cst 7558 KV at 122F, cst 19229 Metals Content:
Iron, wt ppm 19 Vanadium, wt ppm 396 Nickel, wt ppm 78 ,~
3~L
INT~104 Most of the oils fall within the following composition and properties:
TABLE II
Gravity, APl 6 ~ 12 Viscosities:
KV at 180F, cst 400 - 2500 KV at 140F, cst Z000 - 20000 KV at 122F, cst 5 - 4 Metals Content:
Iron, wt ppm 15 - 25 Vanadium~ wt ppm 3O - 5~
Nickel, wt ppm 60 - 120 Asphaltenes, % wt 6 - 12 Salt Content as NaCls Lbs/1000 BBls. 35 - 1000 Pour Point, F 50 - 9Q
Sulfur, % wt 3.5 - 4.5 Water and Sediments~ % Vol 0.2 - 10 The crude feedstock is supplied to the facility shown in the Figure via line 12. Tne heavy crude oil is mixed with a diluent at the productlon well and later at the facility the crude is mixed with additional diluent delivered to line 12 by way of primary llne 14~ recycled diluent line 15 and line 18.
The use of the diluent is critIcal for a number of reasons.
Firstly, the diluent lowers the viscosity and pour point of the crude so that it is not solid at room temperature thereby facilitating transport of the crude. Secondly, the diluent aids in controlling the temperatures and residence times in the facility thereby avoiding premature decompos~tion and ~ INT-104 there~ith degradation of coker yields~ The diluent should be mixed ~ith t.he crude oil in an amount of fro~ about 10 to about 50 percent volume. In accordance with the present invention, the diluent should be a narro~ ~oiling hydrocarbon diluent having suitable solubility characteristics so as to avoid separationO The composition and properties of the diluent should fall ~ithin the following ranges:
TABLE III
Gravity, API 20 65 Viscosities:
KV at 100F, cst 0.5 - 10.5 KV at 210F, cst 0.1 ~ 3 Distillation ASTM ~-86 (F) 50% Vol 200 - 610 EP 250 _ 800 3o A diluent having the following composition and properties is preferred:
TA~LE IV
Gravity, API 35, Ll Sulfur 9 ~ wt o.48 Pour Point~ F -25 Water and Sedimentsg ~ Vol 0.02 Conradson Carbon, ~ wt 0.05 KV at 100F, cst 3.35 KV at 122F, cst 2.78 Distillation ASTM D-86 (F) 50~ Vol 496 The incom:lng feedstock from line 12, which is mixed with dlluent from line 18, :Ls fed to a desalting statlon 20 comprising in series a dehydrator 22 and a first and second stage desalter 24 and 26, respectively. The water content of the crude oil is reduced ln dehydrator 22 down to about 1.0 volume percent and the salt content is reduced in the dehydrator to about 150 PTB, and in the desalters 24 and 26 down to about 5 PTB. The temperature in the desalting station 20 should not exceed 275F.
The desalted crude oil flows from desalter 26 to ~ired heater 28 where the crude is preheated to its desired _ 9 _ ~ 3 ~{~ Nq - 1 0 4 crude tower feed :Lnlet temperature and from there to an atmospheric pressure oil distillation unit 30 where it is separated into gases, liquid products and atmospheric residuum.
The atmospheric distillation unit 30 is designed for several modes of operation.
In one operation~ 500F plus residuum is produced and is drawn off and fed via line 32 to combination tower 34 for use as coker feed. The 500F minus overhead is drawn off through line 36 to splitter tower 38. The off gases from the atmospheric distillation unit 30 are removed through line 40 and passed to a gas scrubber of' conventional design. The gas oil products from atmospheric distillation unit 30 are drawn off through line 42. The 500F minus overhead is fed to splitter tower 3 where naph-tha and off gases are separated out as overhead products and drawn off through lines 44 and 46, respectively.
The splitter tower bottom product is a narrow boiling 400F-500F liquid having properties and composition suitable for use as the diluent. The splitter bottom product is drawn off through line 16 and is recycled and mixed with the crude oil feedstock entering dehydrator 22.
In another mode of operation of atmospheric distillation unit 30, the unit will again produce a 500F minus overhead product which is drawn off and fed to splitter tower 38 via line 36. A 500F to 70~F gas oil is produced and removed through line 42. The atmospheric residuum is a 700F plus 3o ~3~
Il`~T-104 product which is drawn off through line 32 to line 48 where it is fed to gas fired heater 50 where the atmospheric residuum ls heated to its desired temperature and from there to vacuum distillation unit 52 for further processing. The atmospheric residuum is vacuum distilled in distillation unit 52 to produce a vaporized gas oil product which is drawn off through line 54 which may be recovered separately or combined with gas oil from the atmospheric unit 30. The vent ~ases from the vacuum distillation unit 52 are removed through line 56 and combined with the o~f gases from the atmospheric unit 30. The vacuum distillation unit is designed to produce from the atmospheric residue 900F plus vacuum residuum which is drawn off through line 58 and .fed to combination to~er 34 for use as coker feed via line 32.
The reduced crude coker feed from either o.f the above modes o~ operAtion is fed via line 32 to combination tower 34.
Combination tower 34 comprises a heat transfer portion and a ~ractionator portion. The coker fresh feed ~rom the atmospheric residuum or vacuum residuum flows via line 32 to the bottom section of combination tower 34 where it is heated by direct contact with coker effluent and fractionated to produce a reduced coker feed mixed with recycle. Coker ~eedstock is wlthdrawn from the bottom portion of combination tower 34 via line 60 and flows to coker heater 62 where the feedstock is heated to the desired temperature of about 920F. The coker ~3o ~3.~3~ INT-104 feedstock is heated as it passes through coker heater 62 and is fed via line 64 to one of several delayed coking drums, either coke drum 66 or coke drum 68, where the hydrocarbon feedstock decomposes leaving a mass of green coke. The coke drum vapor containing coker products and recycle is drawn off through line 70 and flows to the fractionation portion of combination tower 34. The recycle is condensed and mixed with the fresh feed in the bottom section of tower 34 while the coker products are fractionated lnto off gas, coker naphtha, coker distillate and coker gas. The above fractionated coker products are drawn off via lines 72, 74, 76 and 78, respectively.
The unit is designed to operate normally with a recycle ratio of 0.1. However, if necessary the recycle ratio may be increased to 1.0 with a small reduction in fresh feed.
After sufficient coke is deposited in one coke drum, for example coke drum 66, the flow of the coker heater feedstock is switched to another coke drum 68 which has been preheated.
The coke in coke drum 68 is then removed. The coke bed in the full drum is steam stripped and then cooled by water quenching.
After draining of the water, the top and bottom heads of the drum are removed. The coke is then removed by hydraulic cutting and collected in a coke pit. Coke cutting water drained from the coke pit is collected through sluiceway and is pumped to storage tank for reuse. The empty drum is then reheated, steam purged and pressure tested. It is then reheated 3o ~3 ~ T- 1 0 ~I
wlth superheated steam to about 70F and ready to receive the coking heater ef~luent again.
The coker liquid products may be further processed by hydrogenation to produce final products such as LPG, gasoline, kerosene, ~et fuel, diesel oils and gas oils.
It is to be understood that the invention is not limited to the illustrations described and shown herein, which are deemed to be merely illustrative of the best mode~ of carrying out the invention, and which are susceptible of modification of form, size, arrangement of parts and details of operation.
The inventlon rather is intended to encompass all such modifications which are within its spirit and scope as defined by the claims.
3o
BACKGRO'JI~'D OF ~HE INVEI~TION
The present ~nvention relates to a process and racility for upgradin~ heavy hydrocar~on2ceous materials, and more particularly, a proce~s and facility lor upgrading heavy crude oils generally characterized ~y high speci1ic gravities, high pour points, high viscosities and high contents of sulfur, metals, water, salt and conradson carbon ~or making coke suita~le for metallurgical purposes.
In the typical delayed coking process, residual oil is heated ~y exchanging heat with liquid products from the process and is fed into a fractionating tower wherein light end products producedin the process or present in the residual oil are separated by distillation. The residual oil is then pumped from the base o~ the fractionating tower through a tubular furnace under pressure where it is heated to the required temperature and discharged into the bottom of the coke drum.
The first stages of thermal`decomposition reduce this residual oil to volatile products and a very heavy tar or pitch which further decomposes to yield solid coke particles. The vapors formed during the decomposition produce pores and channels in the coke and pitch mass through which the incoming residual oil from the furnace must pass. The incoming oil and decomposition vapors serve to a~ltate and maintain the coke mass and residual oil mixture at relatively uniform temperature. This decomposition process is continued until the` coke drum is filled ~ith a mass of coke with a small amount of pItch. The vapors ~ormed i~ \
;~3~
leave the top of the coke drum and are returned to the fractionatinc tower where they a.e l`ractionated into the desired petroleum cuts. After the coke drum is filled with a mixture of coke particles and some tar, residual vapors are removed, and the coke is removed from .he drum hy hydraulic or mechanical means. This green delayed ~etroleum coke has particular crystalline and chemical properties which make it especially suitable for making carbon anodes for the aluminum industry, but the green coke must be calcined or carbonized by further treatment to produce a finished calcined coke product.
~ ue to the characteristics of the heavy crude oils of the type set forth above they cannot be processed economically by conventional processing. In addition to their low auality these crude oils are extremely temperature sensitive and decompose at relatively low temperatures. The processin~ and treatment of these crude oils at conventional conditions and in typical refining processes results in higher operating costs and the production of products which are predominantly of little value.
Naturally, it is highly desirable to provide a process and facility for upgrading heavy crude oils so as to allow for the economic production of valuable petroleum products. The process and facility of the present inve~tion should allow for the economic production of coke suitable for metallurgical purposes.
Accordingly, it is a principal object of the present invention to provide a process and facility for upgrading heavy crude oils.
In particular the present invention seeks to provide a process and facillty for upgrading heavy crude oils for use in the production of metallurgical coke.
The invention further seeks to provide a process and facility for upgrading heavy crude oils wherein a hydro-carbon diluent is employed to facilitate control of temperature and residence time thereby prohibiting premature decomposition.
Still further the invention seeks to provide a process and facility for upgrading heavy crude oils wherein the crude oil is carefully fractionated to maximize liquid yields during the coking step.
In accordance with one aspect of the invention there is provided a process for upgrading heavy crude oils for making coke suitable for metallurgical purposes which includes the steps of (a) mixing a diluent with incoming heavy crude oil SO dS to form a mixture of crude oil and diluent; (b) sub-jecting the mixture of crude oil and diluent to distillation whereby gas hydrocarbon products, an overhead liquid hydro-carbon product and a residuum are produced; (c) subjecting the overhead liquid hydrocarbon product to further treatment whereby naphtha and off gases are separated out as overhead products and a narrow boiling point diluent is produced;
(d) recycling the narrow boiling point diluent; and (e) mixing the narrow boiling point diluent with said incorning heavy crude oil.
In accordance with another aspect of the invention there is provided a facility or apparatus for upgrading heavy crude oils for making coke suitable for metallurgical purposes including (a) means for mixing a diluent with incoming heavy crude oil so as to form a mixture of crude oil and diluent;
(b) a distillation unit downstream of the means for mixing the diluent with incoming heavy crude for distilling the mixture into gas hydrocarbon products, an overhead liquid hydrocarbon product and a residuum product; (c) splitter means downstream of the distillation unit to further treat said overhead liquid hydrocarbon product so as to obtain a narrow boiling point diluent; and (d) recirculating mears for recirculating the narrow boiling point diluent to the means for mixing the narrow boiling point diluent with the incoming heavy crude oil.
The present invention relateS to a process and facility for upgrading heavy hydrocarbonaceous materials9 and more particularly a process and facility for upgrading heavy crude oils for making coke suitable for metallurgical purposes. The crude oils found in Orinoco Oil Belt of Venezuela are generally characterized by high gravities (close to that of water); high pour points (solid at ambient temperatures); high viscosities;
high metals, sulfur, water, salt and conradson carbon contents.
In addition, the crude oils are extremely temperature sensitive, that is they easily decompose at low temperatures. The process .~23~
INT~104 and facility of` the present invention allows for the economic production of petroleum products of upgraded -value such as LPG, gasoline, kerosene~ jet fuel, diesel oil and gas oils.
The process and facility employs the use of a hydrocarbon diluent with a closely controlled boiling range to facilitate transport, dehydration and desalting of the crude oil. Further, the diluent facilitates close control of temperatures and residence times thus avoiding premature decomposition and therewith degradation of coker yields. The process and facility also uses a coker fractionator and coker heater design intended to better control the quantity and quality of the coker recycle s-tream to minimize gas- and coke formation and improve the density of the produced coke. The process and facility utilizes a careful fractionation of the crude oil for front end control to ma~imize liquid yields in the coking step.
BRIEF DESCRIPTION OF THE DRAWING
The Figure is a schematic flow diagram illustrating the p:rocess and facility of the present invention.
DETAILED DESCRIPTION
The f`acility 10 and process of the present invention as shown in the drawing depicts the various stages of a delayed coke pilot plant including the facility for upgrading heavy crude 1~3 ~ IhlT~lO4 oil feedstocks. A typical heavy crude oil feedstock ~rom the Orinoco Oil Belt has the ~ollowing composition and properties:
TABLE I
.
Gravity API 8.o (1,0l4 Kg/ms) Sulfur, % wt 3.71 Mercaptans, wt ppm hlil Pour Point, F 80 Nitrogen, % wt 0.60 Water and Sediments, % Vol 6.4 Salt Content as NaCl, Lbs/1000 BBls. 500 Conradson Carbong % wt 13.8 H2S, wt ppm 37 Neutrali~a-~ion Number, mgr KOH/gr 3.95 MNI, % wt 13.54 Asphaltenes, % wt 7.95 UOP K Factor 11.3 Viscosities:
XV at 180F, cst 118LI
KV at 140F, cst 7558 KV at 122F, cst 19229 Metals Content:
Iron, wt ppm 19 Vanadium, wt ppm 396 Nickel, wt ppm 78 ,~
3~L
INT~104 Most of the oils fall within the following composition and properties:
TABLE II
Gravity, APl 6 ~ 12 Viscosities:
KV at 180F, cst 400 - 2500 KV at 140F, cst Z000 - 20000 KV at 122F, cst 5 - 4 Metals Content:
Iron, wt ppm 15 - 25 Vanadium~ wt ppm 3O - 5~
Nickel, wt ppm 60 - 120 Asphaltenes, % wt 6 - 12 Salt Content as NaCls Lbs/1000 BBls. 35 - 1000 Pour Point, F 50 - 9Q
Sulfur, % wt 3.5 - 4.5 Water and Sediments~ % Vol 0.2 - 10 The crude feedstock is supplied to the facility shown in the Figure via line 12. Tne heavy crude oil is mixed with a diluent at the productlon well and later at the facility the crude is mixed with additional diluent delivered to line 12 by way of primary llne 14~ recycled diluent line 15 and line 18.
The use of the diluent is critIcal for a number of reasons.
Firstly, the diluent lowers the viscosity and pour point of the crude so that it is not solid at room temperature thereby facilitating transport of the crude. Secondly, the diluent aids in controlling the temperatures and residence times in the facility thereby avoiding premature decompos~tion and ~ INT-104 there~ith degradation of coker yields~ The diluent should be mixed ~ith t.he crude oil in an amount of fro~ about 10 to about 50 percent volume. In accordance with the present invention, the diluent should be a narro~ ~oiling hydrocarbon diluent having suitable solubility characteristics so as to avoid separationO The composition and properties of the diluent should fall ~ithin the following ranges:
TABLE III
Gravity, API 20 65 Viscosities:
KV at 100F, cst 0.5 - 10.5 KV at 210F, cst 0.1 ~ 3 Distillation ASTM ~-86 (F) 50% Vol 200 - 610 EP 250 _ 800 3o A diluent having the following composition and properties is preferred:
TA~LE IV
Gravity, API 35, Ll Sulfur 9 ~ wt o.48 Pour Point~ F -25 Water and Sedimentsg ~ Vol 0.02 Conradson Carbon, ~ wt 0.05 KV at 100F, cst 3.35 KV at 122F, cst 2.78 Distillation ASTM D-86 (F) 50~ Vol 496 The incom:lng feedstock from line 12, which is mixed with dlluent from line 18, :Ls fed to a desalting statlon 20 comprising in series a dehydrator 22 and a first and second stage desalter 24 and 26, respectively. The water content of the crude oil is reduced ln dehydrator 22 down to about 1.0 volume percent and the salt content is reduced in the dehydrator to about 150 PTB, and in the desalters 24 and 26 down to about 5 PTB. The temperature in the desalting station 20 should not exceed 275F.
The desalted crude oil flows from desalter 26 to ~ired heater 28 where the crude is preheated to its desired _ 9 _ ~ 3 ~{~ Nq - 1 0 4 crude tower feed :Lnlet temperature and from there to an atmospheric pressure oil distillation unit 30 where it is separated into gases, liquid products and atmospheric residuum.
The atmospheric distillation unit 30 is designed for several modes of operation.
In one operation~ 500F plus residuum is produced and is drawn off and fed via line 32 to combination tower 34 for use as coker feed. The 500F minus overhead is drawn off through line 36 to splitter tower 38. The off gases from the atmospheric distillation unit 30 are removed through line 40 and passed to a gas scrubber of' conventional design. The gas oil products from atmospheric distillation unit 30 are drawn off through line 42. The 500F minus overhead is fed to splitter tower 3 where naph-tha and off gases are separated out as overhead products and drawn off through lines 44 and 46, respectively.
The splitter tower bottom product is a narrow boiling 400F-500F liquid having properties and composition suitable for use as the diluent. The splitter bottom product is drawn off through line 16 and is recycled and mixed with the crude oil feedstock entering dehydrator 22.
In another mode of operation of atmospheric distillation unit 30, the unit will again produce a 500F minus overhead product which is drawn off and fed to splitter tower 38 via line 36. A 500F to 70~F gas oil is produced and removed through line 42. The atmospheric residuum is a 700F plus 3o ~3~
Il`~T-104 product which is drawn off through line 32 to line 48 where it is fed to gas fired heater 50 where the atmospheric residuum ls heated to its desired temperature and from there to vacuum distillation unit 52 for further processing. The atmospheric residuum is vacuum distilled in distillation unit 52 to produce a vaporized gas oil product which is drawn off through line 54 which may be recovered separately or combined with gas oil from the atmospheric unit 30. The vent ~ases from the vacuum distillation unit 52 are removed through line 56 and combined with the o~f gases from the atmospheric unit 30. The vacuum distillation unit is designed to produce from the atmospheric residue 900F plus vacuum residuum which is drawn off through line 58 and .fed to combination to~er 34 for use as coker feed via line 32.
The reduced crude coker feed from either o.f the above modes o~ operAtion is fed via line 32 to combination tower 34.
Combination tower 34 comprises a heat transfer portion and a ~ractionator portion. The coker fresh feed ~rom the atmospheric residuum or vacuum residuum flows via line 32 to the bottom section of combination tower 34 where it is heated by direct contact with coker effluent and fractionated to produce a reduced coker feed mixed with recycle. Coker ~eedstock is wlthdrawn from the bottom portion of combination tower 34 via line 60 and flows to coker heater 62 where the feedstock is heated to the desired temperature of about 920F. The coker ~3o ~3.~3~ INT-104 feedstock is heated as it passes through coker heater 62 and is fed via line 64 to one of several delayed coking drums, either coke drum 66 or coke drum 68, where the hydrocarbon feedstock decomposes leaving a mass of green coke. The coke drum vapor containing coker products and recycle is drawn off through line 70 and flows to the fractionation portion of combination tower 34. The recycle is condensed and mixed with the fresh feed in the bottom section of tower 34 while the coker products are fractionated lnto off gas, coker naphtha, coker distillate and coker gas. The above fractionated coker products are drawn off via lines 72, 74, 76 and 78, respectively.
The unit is designed to operate normally with a recycle ratio of 0.1. However, if necessary the recycle ratio may be increased to 1.0 with a small reduction in fresh feed.
After sufficient coke is deposited in one coke drum, for example coke drum 66, the flow of the coker heater feedstock is switched to another coke drum 68 which has been preheated.
The coke in coke drum 68 is then removed. The coke bed in the full drum is steam stripped and then cooled by water quenching.
After draining of the water, the top and bottom heads of the drum are removed. The coke is then removed by hydraulic cutting and collected in a coke pit. Coke cutting water drained from the coke pit is collected through sluiceway and is pumped to storage tank for reuse. The empty drum is then reheated, steam purged and pressure tested. It is then reheated 3o ~3 ~ T- 1 0 ~I
wlth superheated steam to about 70F and ready to receive the coking heater ef~luent again.
The coker liquid products may be further processed by hydrogenation to produce final products such as LPG, gasoline, kerosene, ~et fuel, diesel oils and gas oils.
It is to be understood that the invention is not limited to the illustrations described and shown herein, which are deemed to be merely illustrative of the best mode~ of carrying out the invention, and which are susceptible of modification of form, size, arrangement of parts and details of operation.
The inventlon rather is intended to encompass all such modifications which are within its spirit and scope as defined by the claims.
3o
Claims (36)
1. A process for upgrading heavy crude oils for making coke suitable for metallurgical purposes comprising:
(a) mixing a diluent with incoming heavy crude oil so as to form a mixture of crude oil and diluent;
(b) subjecting the mixture of crude oil and diluent to distillation whereby gas hydrocarbon products, an over-head liquid hydrocarbon product and a residuum are produced;
(c) subjecting said overhead liquid hydrocarbon pro-duct to further treatment whereby naphtha and off gases are separated out as overhead products and a narrow boiling point diluent is produced;
(d) recycling said narrow boiling point diluent; and (e) mixing said narrow boiling point diluent with said incoming heavy crude oil.
(a) mixing a diluent with incoming heavy crude oil so as to form a mixture of crude oil and diluent;
(b) subjecting the mixture of crude oil and diluent to distillation whereby gas hydrocarbon products, an over-head liquid hydrocarbon product and a residuum are produced;
(c) subjecting said overhead liquid hydrocarbon pro-duct to further treatment whereby naphtha and off gases are separated out as overhead products and a narrow boiling point diluent is produced;
(d) recycling said narrow boiling point diluent; and (e) mixing said narrow boiling point diluent with said incoming heavy crude oil.
2. A process according to claim 1, wherein said narrow boiling point diluent boils at a range of about between 150°F and 800°F.
3. A process according to claim 2, including subject-ing said mixture of crude oil and diluent to dehydration and desalting prior to subjecting said mixture to distillation.
4. A process according to claim 2, including preheat-ing said mixture of crude oil and diluent prior to dis-tillation.
5. A process according to claim 3, wherein the salt content of said mixture of crude oil and diluent is reduced down to about not more than 5 PTB.
6. A process according to claim 3, wherein the water content of said mixture of crude oil and diluent is reduced down to about not more than 1.0 volume percent.
7. A process according to claim 3, wherein desalting temperature is less than or equal to about 275°F.
8. A process according to claim 1, wherein said diluent is mixed with said crude oil in an amount of from about 10 to 50 volume percent.
9. A process according to claim 1, wherein said over-head liquid hydrocarbon product boils at a temperature of less than or equal to about 500°F.
10. A facility for upgrading heavy crude oils for making coke suitable for metallurgical purposes comprising:
(a) means for mixing a diluent with incoming heavy crude oil so as to form a mixture of crude oil and diluent;
(b) a distillation unit downstream of the means for mixing the diluent with incoming heavy crude for distilling said mixture into gas hydrocarbon products, an overhead liquid hydrocarbon product and a residuum product;
(c) splitter means downstream of said distillation unit to further treat said overhead liquid hydrocarbon product so as to obtain a narrow boiling point diluent; and (d) recirculating means for recirculating said narrow boiling point diluent to said means for mixing said narrow boiling point diluent with said incoming heavy crude oil.
(a) means for mixing a diluent with incoming heavy crude oil so as to form a mixture of crude oil and diluent;
(b) a distillation unit downstream of the means for mixing the diluent with incoming heavy crude for distilling said mixture into gas hydrocarbon products, an overhead liquid hydrocarbon product and a residuum product;
(c) splitter means downstream of said distillation unit to further treat said overhead liquid hydrocarbon product so as to obtain a narrow boiling point diluent; and (d) recirculating means for recirculating said narrow boiling point diluent to said means for mixing said narrow boiling point diluent with said incoming heavy crude oil.
11. A facility according to claim 10, wherein said narrow boiling point diluent boils at a range of about between 150°F and 300°F.
12. A facility according to claim 11, including means for dehydrating and desalting said mixture of crude oil prior to subjecting said mixture to distillation.
13. A facility according to claim 11, including means for preheating said mixture of crude oil and diluent prior to distillation.
14. A facility according to claim 12, wherein the salt content of said mixture of crude oil and diluent is reduced by said means to dehydrate and desalt to about not more than 5 PTB.
15. A facility according to claim 12, wherein the water content of said mixture of crude oil and diluent is reduced by said means to dehydrate and desalt to about not more than 1.0 volume percent.
16. A facility according to claim 10, wherein said diluent is mixed with said crude oil in an amount of from about 10 to 50 volume percent.
17. A facility according to claim 10, wherein said overhead liquid hydrocarbon product boils at a temperature of less than or equal to about 500°F.
18. A process for upgrading a heavy crude oil feedstock characterized by a high specific gravity, high pour point, high viscosity and high metal, sulfur, water, salt and conradson carbon contents for making coke suitable for metallurgical purposes comprising:
(a) mixing a diluent with incoming heavy crude oil so as to form a mixture of crude oil and diluent so as to lower the viscosity and facilitate dehydration and desalting of the crude oil;
(b) feeding the mixture of crude oil and diluent to a dehydrator wherein the water content of the mixture of crude oil and diluent is reduced down to about not more than 1.0 volume percent;
(c) feeding the dehydrated mixture of crude oil and diluent to a desalter wherein the salt content of the mixture of crude oil and diluent is reduced down to about not more than 5 PTB;
(d) feeding the dehydrated and desalted mixture of crude oil and diluent to an atmospheric distillation unit wherein gas hydrocarbon products, an overhead 500°F minus liquid hydrocarbon product and a residuum are produced;
(e) feeding said overhead 500°F minus liquid hydro-carbon product to a splitter unit for further treatment whereby naphtha and off gases are separated out as overhead products and a narrow boiling point diluent having a boiling range of from about 400° to 500°F is produced;
(f) recycling said narrow boiling point diluent; and (g) mixing said narrow boiling point diluent with said incoming heavy crude oil feedstock prior to dehydration and desalting so as to lower the viscosity of the crude and control its temperature and residence time in said dehydrator and said desalter so as to facilitate dehydration and desalting.
(a) mixing a diluent with incoming heavy crude oil so as to form a mixture of crude oil and diluent so as to lower the viscosity and facilitate dehydration and desalting of the crude oil;
(b) feeding the mixture of crude oil and diluent to a dehydrator wherein the water content of the mixture of crude oil and diluent is reduced down to about not more than 1.0 volume percent;
(c) feeding the dehydrated mixture of crude oil and diluent to a desalter wherein the salt content of the mixture of crude oil and diluent is reduced down to about not more than 5 PTB;
(d) feeding the dehydrated and desalted mixture of crude oil and diluent to an atmospheric distillation unit wherein gas hydrocarbon products, an overhead 500°F minus liquid hydrocarbon product and a residuum are produced;
(e) feeding said overhead 500°F minus liquid hydro-carbon product to a splitter unit for further treatment whereby naphtha and off gases are separated out as overhead products and a narrow boiling point diluent having a boiling range of from about 400° to 500°F is produced;
(f) recycling said narrow boiling point diluent; and (g) mixing said narrow boiling point diluent with said incoming heavy crude oil feedstock prior to dehydration and desalting so as to lower the viscosity of the crude and control its temperature and residence time in said dehydrator and said desalter so as to facilitate dehydration and desalting.
19. A process according to claim 18, including pre-heating said mixture of crude oil and diluent prior to dis-tillation.
20. A process according to claim 18, wherein desalting temperature is less than or equal to about 275°F.
21. A process according to claim 18, 19 or 20, wherein said diluent is mixed with said crude oil in an amount of from about 10 to 50 volume percent.
22. A process according to claim 18, 19 or 20, wherein the crude oil feedstock has a higher viscosity at 180°F than the narrow boiling point diluent has at 100°F.
23. A process according to claim 18, 19 or 20, wherein the ratio of the viscosity of the crude oil feed-stock to the narrow boiling point diluent at 122°F is in a range of about 1800:1 to 14000:1.
24. A process according to claim 18, 19 or 20, wherein the crude oil feedstock has a pour point of about 50° to 90°F.
25. A process according to claim 18, 19 or 20, wherein the crude oil feedstock has a specific gravity of about 6° to 12° API.
26. A process according to claim 18, 19 or 20, wherein the crude oil feedstock contains from about 3.5 to 4.5 wt. % sulfur.
27. A process according to claim 18, 19 or 20, wherein the crude oil feedstock contains from about 300 to 500 ppm by weight vanadium, about 60 to 120 ppm by weight nickel and about 15 to 25 ppm by weight iron.
28. A process according to claim 18, 19 or 20, wherein the crude oil feedstock has a viscosity of about 400 to 2500 KV at 180°F, cst, about 2000 to 20000 KV at 140°F, cst and about 5000 to 40000 KV at 122°F, cst.
29. A process according to claim 18, 19 or 20, wherein the crude oil feedstock is characterized by the following composition and properties:
Gravity °API 6-12 Viscosities:
KV at 180°F, cst 400-2500 KV at 140°F, cst 2000-20000 KV at 122°F, cst 5000-40000 Metals Content:
Iron, wt ppm 15-25 Vanadium, wt ppm 300-500 Nickel, wt ppm 60-120 Asphaltenes, % wt 6-12 Salt Content as NaCl, Lbs/1000 BBls. 35-1000 Pour point, °F 50-90 Sulfur, % wt 3.5-4.5 Water and Sediments, % Vol. 0.2-10
Gravity °API 6-12 Viscosities:
KV at 180°F, cst 400-2500 KV at 140°F, cst 2000-20000 KV at 122°F, cst 5000-40000 Metals Content:
Iron, wt ppm 15-25 Vanadium, wt ppm 300-500 Nickel, wt ppm 60-120 Asphaltenes, % wt 6-12 Salt Content as NaCl, Lbs/1000 BBls. 35-1000 Pour point, °F 50-90 Sulfur, % wt 3.5-4.5 Water and Sediments, % Vol. 0.2-10
30. A process according to claim 18, wherein the diluent has a specific gravity of about 20° to 65° API.
31. A process according to claim 30, wherein the diluent has a viscosity of about 0.5 to 10.5 KV at 100°F, cst and of about 0.1 to 3.0 KV at 210°F, cst.
32. An apparatus for upgrading a heavy crude oil feed-stock characterized by a high specific gravity, high pour point, high viscosity and high metal, sulfur, water, salt and conradson carbon contents for making coke suitable for metallurgical purposes comprising:
(a) a heavy crude oil feedstock inlet line;
(b) a dehydrator downstream of said heavy crude oil feedstock inlet line for receiving crude oil therefrom;
(c) a diluent feed line for feeding a diluent to said heavy crude feedstock in said heavy crude oil feedstock inlet line upstream of said dehydrator, (d) a desalter downstream of said dehydrator for receiving a mixture of crude oil and diluent from said dehydrator wherein the water content of the mixture of crude oil and diluent from said dehydrator is not more than 1.0 volume percent;
(e) a distillation unit downstream of said dehydrator for receiving a dehydrated and desalted mixture of crude oil and diluent from said desalter wherein said mixture of crude oil and diluent from said desalter has a salt content of not more than 5 PTB;
(f) a splitter means downstream of said distillation unit for receiving the overhead liquid hydrocarbon product from said distillation unit so as to obtain a narrow boiling point diluent; and (g) feed lines for feeding said narrow boiling point diluent from said splitter means to said diluent feed line for mixing said diluent with said heavy crude feedstock prior to the dehydrating and desalting of said heavy crude oil and diluent mixture.
(a) a heavy crude oil feedstock inlet line;
(b) a dehydrator downstream of said heavy crude oil feedstock inlet line for receiving crude oil therefrom;
(c) a diluent feed line for feeding a diluent to said heavy crude feedstock in said heavy crude oil feedstock inlet line upstream of said dehydrator, (d) a desalter downstream of said dehydrator for receiving a mixture of crude oil and diluent from said dehydrator wherein the water content of the mixture of crude oil and diluent from said dehydrator is not more than 1.0 volume percent;
(e) a distillation unit downstream of said dehydrator for receiving a dehydrated and desalted mixture of crude oil and diluent from said desalter wherein said mixture of crude oil and diluent from said desalter has a salt content of not more than 5 PTB;
(f) a splitter means downstream of said distillation unit for receiving the overhead liquid hydrocarbon product from said distillation unit so as to obtain a narrow boiling point diluent; and (g) feed lines for feeding said narrow boiling point diluent from said splitter means to said diluent feed line for mixing said diluent with said heavy crude feedstock prior to the dehydrating and desalting of said heavy crude oil and diluent mixture.
33. An apparatus according to claim 32 including a furnace means downstream of said desalter and upstream of said distillation unit for preheating said dehydrated and desalted mixture of crude oil and diluent prior to distillation.
34. An apparatus according to claim 32, including a coker downstream of said distillation unit for receiving said distillation residue.
35. An apparatus according to claim 32, including a vacuum distillation downstream of said distillation unit for receiving said distillation residue.
36. An apparatus according to claim 35, including a coker downstream of said vacuum distillation unit for receiving said vacuum distillation residue.
Applications Claiming Priority (4)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US06/465,179 US4455221A (en) | 1983-02-09 | 1983-02-09 | Process for upgrading heavy hydrocarbons employing a diluent |
| US465,179 | 1983-02-09 | ||
| US465,180 | 1983-02-09 | ||
| US06/465,180 US4521277A (en) | 1983-02-09 | 1983-02-09 | Apparatus for upgrading heavy hydrocarbons employing a diluent |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1231911A true CA1231911A (en) | 1988-01-26 |
Family
ID=27041246
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000442425A Expired CA1231911A (en) | 1983-02-09 | 1983-12-02 | Process and facility for upgrading heavy hydrocarbons employing a diluent |
Country Status (8)
| Country | Link |
|---|---|
| BR (1) | BR8400408A (en) |
| CA (1) | CA1231911A (en) |
| CH (1) | CH660021A5 (en) |
| DE (1) | DE3401888A1 (en) |
| ES (2) | ES527913A0 (en) |
| GB (1) | GB2134920B (en) |
| IT (1) | IT1179353B (en) |
| MX (1) | MX166752B (en) |
Families Citing this family (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CA1219236A (en) * | 1985-03-01 | 1987-03-17 | David W. Mcdougall | Diluent distallation process and apparatus |
| ATE432333T1 (en) * | 2001-12-07 | 2009-06-15 | Namik Niyaz Ogly Mamedov | METHOD FOR RECYCLING MIXED OIL WASTE AND DEVICE FOR IMPLEMENTING THE METHOD |
| US20230101524A1 (en) * | 2021-09-28 | 2023-03-30 | Indian Oil Corporation Limited | Method for producing anode grade coke from crude oils |
Family Cites Families (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB720612A (en) * | 1951-06-27 | 1954-12-22 | Standard Oil Dev Co | A process of converting hydrocarbon materials containing distillable and non-distillable hydrocarbon constituents into distillate oils and coke |
| DE1253230B (en) * | 1958-09-03 | 1967-11-02 | Shell Int Research | Process for the production of petroleum coke with moderating properties |
| DE2116504B2 (en) * | 1971-04-05 | 1974-05-30 | Fa. C. Conradty, 8500 Nuernberg | Process for the production of specialty cokes |
| JPS5144103A (en) * | 1974-09-25 | 1976-04-15 | Maruzen Oil Co Ltd | Sekyukookusuno seizoho |
| US4176046A (en) * | 1978-10-26 | 1979-11-27 | Conoco, Inc. | Process for utilizing petroleum residuum |
| ZA818168B (en) * | 1980-12-05 | 1982-10-27 | Lummus Co | Coke production |
| ATE18252T1 (en) * | 1981-12-09 | 1986-03-15 | Peter Spencer | METHOD AND DEVICE FOR THERMAL TREATMENT OF HEAVY FUEL OIL. |
-
1983
- 1983-12-02 CA CA000442425A patent/CA1231911A/en not_active Expired
- 1983-12-09 ES ES527913A patent/ES527913A0/en active Granted
-
1984
- 1984-01-03 IT IT47506/84A patent/IT1179353B/en active
- 1984-01-14 GB GB08401069A patent/GB2134920B/en not_active Expired
- 1984-01-20 DE DE19843401888 patent/DE3401888A1/en active Granted
- 1984-01-23 CH CH282/84A patent/CH660021A5/en not_active IP Right Cessation
- 1984-01-31 BR BR8400408A patent/BR8400408A/en not_active IP Right Cessation
- 1984-02-01 MX MX200206A patent/MX166752B/en unknown
-
1985
- 1985-05-28 ES ES543552A patent/ES8704196A1/en not_active Expired
Also Published As
| Publication number | Publication date |
|---|---|
| ES8600369A1 (en) | 1985-10-01 |
| CH660021A5 (en) | 1987-03-13 |
| DE3401888A1 (en) | 1984-08-23 |
| ES527913A0 (en) | 1985-10-01 |
| ES8704196A1 (en) | 1987-03-16 |
| GB2134920A (en) | 1984-08-22 |
| DE3401888C2 (en) | 1992-07-09 |
| GB8401069D0 (en) | 1984-02-15 |
| BR8400408A (en) | 1984-09-11 |
| MX166752B (en) | 1993-02-01 |
| IT1179353B (en) | 1987-09-16 |
| IT8447506A0 (en) | 1984-01-03 |
| GB2134920B (en) | 1987-01-21 |
| ES543552A0 (en) | 1987-03-16 |
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