US20130277275A1

US20130277275A1 - Method for treating heavy oil

Info

Publication number: US20130277275A1
Application number: US13/822,818
Authority: US
Inventors: James Hill; Claudio Arato
Original assignee: Petrosonic Energy Inc
Current assignee: Petrosonic Energy Inc
Priority date: 2008-03-11
Filing date: 2009-03-11
Publication date: 2013-10-24
Also published as: EA201401282A1; EA021729B1; EA201071060A1; EP2260089A1; EP2260089A4; WO2009111871A1

Abstract

According to the invention, there is provided a method for treating heavy crude oil (HCO) which includes the steps of combining the HCO with an alkane containing solvent to form an HCO/solvent mixture, sonicating this mixture at audio frequency to precipitate asphaltenes from the HCO/solvent mixture, and separating the precipitated asphaltenes from the HCO/solvent mixture.

Description

FIELD OF INVENTION

The present invention relates to a method for deasphalting oils containing asphaltenes (such as heavy crude oil (HCO), bitumen, and oil refinery residues) using solvents and acoustic sound energy resulting in an upgraded higher value synthetic crude oil which may be further upgraded by chemical or biological/chemical processes.

BACKGROUND OF INVENTION

It is well known that solvent deasphalting can be used to upgrade heavy crude oil (HCO), including bitumen, to a synthetic crude oil (SCO) via enhancement of its chemical and physical properties such as:

- increased API gravity
- decreased viscosity
- decreased nickel content
- decreased vanadium content
- decreased sulphur content

API gravities above 19 and viscosities below 350 centistokes are particularly desirable for purposes of product pipelining.
Nickel contamination in oil refineries can come from two (2) sources: corrosion of stainless steel (e.g. via the presence of hydrogen chloride or naphthenic acids) or nickel organometallic compounds (e.g. porphyrins) in the asphaltene portion of bitumen. Nickel, a hydrogen scavenger, causes catalyst fouling via coke formation due to dehydrogenation of alkanes to olefins in refinery catalytic crackers. Therefore SCO containing less nickel is more valuable.
Vanadium contamination in oil refineries can come from vanadium organometallic compounds (e.g. porphyrins) in the asphaltene portion of bitumen. Vanadium destroys catalytic cracker catalysts by altering their crystal structure to non-catalytic forms. Therefore SCO containing less vanadium is more valuable.
U.S. Pat. Nos. 4,941,134 and 5,005,773 issued to Nyberg et al. describe a sonic reactor for the transmission of energy into fluid mediums using a “resonating bar” or probe.
U.S. Pat. No. 6,357,526 (Abdel-Halim and Subramanian) describes “flashing” of light ends from HCO followed by solvent deasphalting of the flasher residue.
Canadian patent 2,549,358 (Boakye) describes a chemical and biological upgrading process for heavy oils which includes solvent deasphalting as a primary step. Although the process achieves high quality SCO output, the deasphalting step is prohibitively expensive and therefore not commercially viable due to excessive solvent requirements e.g. 10:1 preferred solvent to oil volume ratio (see page 5 section [0016]) and deasphalter processing times e.g. 2 to 3 hours (see page 2 section [0005]).
The process of deasphalting has two purposes: to initiate upgrading of the HCO, by an average quantity of 4-5 API, as per prior technical evaluation as well as to remove a substantial quantity of sulphur from the HCO to the precipitated, insoluble asphaltene fraction. Deasphalting involves the solubilization of non-asphaltenes and the precipitation of asphaltenes, i.e. molecules insoluble in the deasphalting solvent.
U.S. Pat. No. 3,779,902 (Mitchell and Speight) shows, in Example 1, the relative deasphalting capability of a series of non-polar alkane solvents on Athabasca bitumen at 1:1 solvent to bitumen weight ratio. The solvent-bitumen mixtures were shaken vigorously for 5-10 minutes at 0.5 hour intervals for approximately 8 hours. At the end of the 8 hour reaction period, the fractions were separated by decantation followed by filtration, with light suction of the solvent-bitumen solution. The following Table 1 shows degree of asphaltene precipitation in weight % for each of the solvents:

	TABLE 1

	Solvent	Asphaltenes precipitated (weight %)

	propane	100
	butane	100
	n-pentane	100
	Hexane isomers	75
	Heptane isomers	67
	Pentane/hexane	83
	Pentane/heptane	75
	cyclopentane	1
	cyclohexane	0

Deasphalting was high for non-cyclic alkanes and improved as the molecular weight of the alkane was reduced. Deasphalting was efficient based on the low solvent:bitumen ratio, however, deasphalting was extremely slow (i.e. 8 hours).
Prior art deasphalting of heavy crude oil and refinery residues suffers from the following problems alone or in combination:

- excessive solvent to heavy crude oil/residue ratios
- excessive processing times

SUMMARY OF THE INVENTION

The present invention is a method for converting heavy crude oil (HCO), such as bitumen, or oil refinery residues to a higher grade synthetic crude oil (SCO) or refinery output via separation of the SCO from asphaltenes. Asphaltenes are defined as the part of the HCO or refinery residue precipitated by addition of a low-boiling paraffin solvent such as n-pentane. The SCO can be used as is or further upgraded via chemical and/or biological processing e.g. Canadian patent 2,549,358.
According to the invention, there is provided a method for treating heavy crude oil (HCO) which includes the steps of combining the HCO with an alkane containing non-polar solvent to form an HCO/solvent mixture, sonicating this mixture at audio frequency to precipitate asphaltenes from the HCO/solvent mixture, and separating the precipitated asphaltenes from the HCO/solvent mixture.
Preferably, vacuum filtration is used to remove. precipitated asphaltenes from the HCO/solvent mixture.
Distillation may be used to remove solvent from the HCO/solvent mixture after removal of precipitated asphaltenes so as to create a deasphalted and solvent free synthetic crude oil (SCO).
The alkane containing solvent may include pentane, hexane or iso-octane.
The deasphalted HCO/solvent mixture may advantageously be used as the feedstock for a chemical and/or biological oil upgrading process.
The chemical and/or biological, process uses enzyme sources and one or more oxidants in the presence of an acid.
The enzyme source may be soyabean husk and the enzyme, peroxidase.
The acid may be acetic acid.
The oxidant may be hydrogen peroxide combined with iron oxide.
The deasphalting time is preferably 2 minutes (120 seconds) or less.
The deasphalting time may be 60 seconds.
The deasphalting solvent:HCO weight ratio may be less than or equal to 3.5.
The deasphalting solvent:HCO weight ratio may be 1.16 or less.
The deasphalting solvent:HCO weight ratio may be 0.91.
The method exhibits improved solvent deasphalting, without excessive blending and dilution, by virtue of much faster deasphalting at low solvent to oil ratios, including separation of asphaltenes from deasphalted oil (in contrast to prior art methods). More particularly, this improved deasphalting is achieved by applying low-frequency, high amplitude acoustic energy to the HCO-solvent process stream (referred to as “sonication” of the HCO-solvent mixture) followed by separation of precipitated solvent insolubles (asphaltenes) via filtration, centrifugation, settling, or other appropriate technique. The method results in a SCO product that meets pipeline specifications in terms of API gravity and viscosity.
The current invention is a method for simplified, accelerated deasphalting of HCO's with non-polar solvents, under low frequency acoustic sonication at an audio frequency that is well below the ultrasonic range (ultrasound frequency range commences at approximately 20,000 Hertz (Hz)).
“Audio frequency” refers to a range of 16 Hz to 20,000 Hz, however, in the preferred embodiment of the invention the sonic mixing takes place at a frequency range of 30 Hz-5,000 Hz, or more preferably, in a range of 100 Hz-1,000 Hz.
Such sonication devices come in two preferred types: sonicating probes in direct contact with fluids; and fluid containing vessels where the sonication is applied indirectly to the fluids via the vessel(e.g. component #44 on U.S. Pat. No. 5,005,773). Sonication devices can be of any type which can generate the desired acoustic frequency, high amplitude and sufficient energy density to the process fluids at an industrial scale. The preferred sonication device would achieve a high energy efficiency by using a balanced dynamic system operating at its natural resonance frequency to sonicate the fluid containing vessel (e.g. see Nyberg U.S. Pat. Nos. 4,941,134 and 5,005,773 component #44 where such vessel is mounted axially to the resonating member but in the absence of grinding media).
In particular, non-polar, non-cyclic, low molecular weight alkane solvents and their associated analogs such as propane, pentane, hexane, heptane and iso-octane are used.
“Sonication” and “low frequency acoustic sonication” refer to methods whereby a material is subjected to low frequency acoustic vibration. Devices for producing such vibration, “sonicators”, are disclosed in, for example, U.S. Pat. Nos. 4,941,134 and 5,005,773 (Nyberg et al.). Unlike ultrasonic devices, these low frequency sonic reactors are reducible to large scale commercial practice (e.g. 20 kilowatt sonicator modules) and can achieve HCO deasphalting at low solvent:HCO doses (with ultra-low residence times in the sonicator (e.g. less than 120 seconds).

BRIEF DESCRIPTION OF THE DRAWINGS

Further features and advantages will be apparent from the following detailed description, given by way of example, of a preferred embodiment taken in conjunction with the accompanying drawings, wherein:

FIG. 1 is a Heavy Oil Deasphalting Process Flow Diagram;

FIG. 2 is a Heavy Oil Upgrading Process Flow Diagram;

FIG. 3 is a SIMDIST graph for Upgraded and Raw oil showing boiling point temperature versus percentage of oil distilled at that temperature for heavy oil from South Western Texas;

FIG. 4 is a SIMDIST graph for heavy oil from Lloydminster;

FIG. 5 is a SIMDIST graph for heavy oil from Albania; and

FIG. 6 is a SIMDIST graph for American Oil Refinery Residue.

DETAILED DESCRIPTION OF THE INVENTION

The process is comprised of the following key unit operations:

- Intense agitation of the HCO/solvent mixture using audio frequency sonic energy “sonication”, resulting in efficient separation of asphaltenes from the HCO/solvent mixture. Such sonication devices come in two preferred types: sonicating probes in direct contact with fluids; and sonication of fluid containing vessels;
- Separation of the HCO from the asphaltene solids via physical separation e.g. decantation, filtration, centrifugation, etc.
- Optional biological and/or chemical oxidation of asphaltene stripped HCO/solvent mixture to create and SCO/solvent mixture.
- Removal of solvent from the asphaltene stripped HCO/solvent mixture to create a solvent free SCO.
- Recycling of the solvent for further processing of raw HCO.

The sonication device reactor typically involves the conversion of electric power, via sequentially activated magnets, to produce vibrational energy. As an example one sonication device used an electro-magnetic drive system to resonate a three tonne solid steel bar. Vibrational energy from the bar is transmitted to the attached to the fluid containing sonic reaction chambers (vessels containing the HCO-solvent mixture) and through which fluid materials can be pumped and be subjected to very intense audio frequency agitation (“sonication”). The vigorous sonication is used in the current process to enhance solvent extraction of the non-asphaltene fraction from the HCO through enhanced mass transfer as a result of the sonication and secondary effects such as cavitation.
The sonic reactors are large (beyond bench and lab scale) low frequency sonication reactors that have sufficient processing capacity for commercial applications. The sonic reactors are readily transportable and require no anchoring once on site.
Heat generation testwork indicates specific energy inputs for the 20 kW to 50 kW sonic reactor ranging up to 90 kW/m³of reactor volume (450 Horsepower/1,000 US gallons). This range of power input is at least one to two orders of magnitude (10 to 100 times) greater than is achieved by energy intensive industrial mixing systems such as flotation cells or standard agitation systems.
The energy and fluid dynamic conditions and energy intensity produced by sonication devices, and in particular by the sonic reactors, is advantageous for chemical process operations. Sonication enhances process reactions by causing intense mixing and other fluid dynamic effects such that sonication improves the selectivity or efficiency of the desired chemical or physical reaction.
The following non-limiting examples illustrate the effectiveness of the invention:

EXAMPLE 1

Upgrading Oil from a Texas Oil Source
The oil came from a heavy oil field located in Southwestern Texas. Fifty grams of the Southwestern Texas HCO was blended with 175 grams of iso-octane solvent (225 grams total) for sonic deasphalting in a baffled 1.7 litre stainless steel reaction chamber. The deasphalting occurred at 25 kW power applied continuously for 120 seconds in batch mode in a 1.7 lire sonic reaction chamber. Subsequently the deasphalted material was separated through direct vacuum filtration. Optionally, the subsequent deasphalted oil was oxidized via the prior art described by Boakye (Canadian patent #2,549,358) utilizing acetic acid, hydrogen peroxide, peroxidase enzyme source (i.e. soyabean husk) and iron oxide. The oxidation reaction was quenched through absorption of generated polar compounds and sulfur compounds by passing the deasphalted HCO/solvent/reagent reaction product through a natural clay and activated carbon mixture that removes excess and/or unconsumed oxidation reagents.
The solvent is recovered by atmospheric distillation at temperatures sufficient to evaporate the solvent. Any solvent recovery system may be used and persons skilled in the art may specify equipment based on recovery and cost considerations.

TABLE 2

Sample Candidate Oil Balance (Run 081018E-
1), normalized to 1 barrel of oil:

Inputs	Mass (kg)	Outputs	Mass (kg)

Crude Oil	154	Upgraded Oil	146
Solvent	539	Asphaltenes	6
Biological Catalyst	9	Solvent	512
Oxidizing Reagents	18	Solvent Loss	27
Chemical Catalyst	9	Reagent + Catalyst	19
Adsorbent Agents	40	Reagent + Catalyst	19
		Loss
		Adsorbent Agents
	40
TOTAL	769	TOTAL	769
Crude Oil Volume	1 bbl	Upgraded Oil Volume	1.05 bbl

TABLE 3

Analytical			Change
Parameters	Raw	Upgraded	(%)	Method

Total Acid	0.59	0.99	67.8	ASTM D664
Number (TAN)
(mg KOH/g)
API gravity	17.4	27.9	71.8	ASTM D4052
(° API, @15° C.)
Density	949.9	887.2	−6.6	ASTM D4052
(kg/m³, @15° C.)
Nickel (μg/g)	5.4	1.9	−64.8	ASTM D5185
Vanadium (μg/g)	12	4.2	−65.0	ASTM D5185
Sulfur (mass %)	3.73	2.78	−25.5	ASTM D4294
SIMDIST	IBP = 129.6	IBP = 90.0	—	ASTM D7169
(by GC)	See plot	See plot
(IBP¹-720° C.)

¹IBP = Initial Boiling Point (° C.)

Referring to FIG. 3, the SIMDIST shows the simulated distillation via gas chromatography of upgraded and raw oil from Southwestern, Texas. The upper curve corresponds to raw-crude and the lower one to upgraded crude. This is the same for FIGS. 4 to 6. If one arbitrarily chooses a value of 20 on the x-axis then 20% of the upgraded oil is distilled at 260° C. while 20% of the raw oil is distilled at 310° C. Oil value tends to increase as the boiling points of its components decrease.

EXAMPLE 2

Upgrading Oil from a Canadian Oil Source
Oil from a heavy oil field located near Lloydminster, Alberta, Canada was tested.
Fifty grams of Lloydminster HCO was blended with 175 grams of iso-octane solvent (225 grams total) for sonic deasphalting in a baffled 1.7 litre stainless steel reaction chamber. The deasphalting occurred at 25 kW power applied continuously for 120 seconds in batch mode. After the deasphalted material was separated through direct vacuum filtration, the subsequent deasphalted oil was oxidized via the prior art described by Boakye (Canadian patent #2,549,358) utilizing acetic acid, hydrogen peroxide, peroxidase enzyme source (i.e. soyabean husk) and iron oxide. The oxidation reaction was quenched through absorption of generated polar compounds and sulfur compounds by passing the deasphalted HCO/solvent/reagent reaction product through a natural clay and activated carbon mixture.

TABLE 4

Sample Candidate Oil Balance (Run 081017E-1):

Inputs	Mass (kg)	Outputs	Mass (kg)

Crude Oil	154	Upgraded Oil	127
Solvent	539	Asphaltenes	27
Biological Catalyst	9	Solvent	512
Oxidizing Reagents	18	Solvent Loss	27
Chemical Catalyst	9	Reagent + Catalyst	18
Adsorbent Agents	40	Reagent + Catalyst Loss	18
		Adsorbent Agents	40
TOTAL	769	TOTAL	769
Crude Oil Volume	1 bbl	Upgraded Oil Volume	0.95 bbl

TABLE 5

Analytical			Change
Parameters	Raw	Upgraded	(%)	Method

Total Acid	1.24	0.78	−37.1	ASTM D664
Number (TAN)
(mg KOH/g)
API gravity	14.4	30.8	+113.9	ASTM D4052
(° API, @15° C.)
Density	969.0	871.5	−10.1	ASTM D4052
(kg/m³, @15° C.)
Nickel (μg/g)	46	7.4	−83.9	ASTM D5185
Vanadium (μg/g)	95	20	−79.0	ASTM D5185
Sulfur (mass %)	3.62	2.15	−40.6	ASTM D4294
SIMDIST	IBP = 112.8	IBP = 88.4	—	ASTM D7169
(by GC)	See plot	See plot
(IBP¹-720° C.)

¹IBP = Initial Boiling Point (° C.)

Referring to FIG. 4, this SIMDIST graph corresponds to Example 2.

EXAMPLE 3

Upgrading Oil from an Albanian Oil Source
The oil from a heavy oil field located in Albania was tested next.
Fifty grams of Albanian HCO was blended with 175 grams of iso-octane solvent (225 grams total) for sonic deasphalting in a baffled 1.7 litre stainless steel reaction chamber. The deasphalting occurred at 25 kW power applied continuously for 120 seconds in batch mode. After the deasphalted material was separated through direct vacuum filtration, the subsequent deasphalted oil was oxidized through the prior art described by Boakye (Canadian patent #2,549,358) utilizing acetic acid, hydrogen peroxide, peroxidase enzyme source (i.e. soyabean husk) and iron oxide. The oxidation reaction was quenched through absorption of generated polar compounds and sulfur compounds by passing the deasphalted HCO/solvent/reagent reaction product through a natural clay and activated carbon mixture that remove all excess and/or unconsumed oxidation reagents.

TABLE 6

Sample Candidate Oil Balance (Run 081119E-1):

Inputs	Mass (kg)	Outputs	Mass (kg)

Crude Oil	158	Upgraded Oil	118
Solvent	474	Asphaltenes	41
Biological Catalyst	9	Solvent (Recovered)	450
Oxidizing Reagents	18	Solvent Loss	23
Chemical Catalyst	9	Reagent + Catalyst	18
Adsorbent Agents	40	Reagent + Catalyst Loss	18
		Adsorbent Agents	40
TOTAL	708	TOTAL	708
Crude Oil Volume	1 bbl	Upgraded Oil Volume	0.83 bbl

TABLE 7

Analytical			Change
Parameters	Raw	Upgraded	(%)	Method

Total Acid	0.56	0.30	−46.4	ASTM D664
Number (TAN)
(mg KOH/g)
API gravity	10.8	25.1	+132.4	ASTM D4052
° API, @15° C.)
Density	994	903	−9.2	ASTM D4052
(kg/m³, @15° C.)
Nickel (μg/g)	68.5	8.6	−87.5	ASTM D5185
Vanadium (μg/g)	348.4	56	−83.9	ASTM D5185
Sulfur (mass %)	5.96	2.78	−53.4	ASTM D4294
SIMDIST	IBP = 110.6	IBP = 93.9	—	ASTM D7169
(by GC)	See plot	See plot
(IBP¹-720° C.)

¹IBP = Initial Boiling Point (° C.)
Referring to FIG. 5 this SIMDIST refers to the heavy oil from Albania

EXAMPLE 4

The next test sample was Processed American oil refinery residue. The oil refinery residue (“asphalt extender tank bottoms”) came from an oil refinery manufacturing refinery gas fuels, fuel additives, lubricants and anticorrosive materials.
Fifty grams of refinery residue was blended with 175 grams of n-pentane solvent for sonic deasphalting in a baffled 1.7 litre stainless steel reaction chamber. The methodology involved the addition of 50 grams of the selected heavy oil indicated for each example to 175 grams of solvent (225 grams total) for sonic deasphalting. The deasphalting occurred at kW power applied continuously for 120 seconds in batch mode. After the deasphalted material was separated through direct vacuum filtration, the subsequent deasphalted oil was oxidized via the prior art described by Boakye (Canadian patent #2,549,358) utilizing acetic acid, hydrogen peroxide, peroxidase enzyme source (i.e. soyabean husk) and iron oxide. The oxidation reaction was quenched through absorption of generated polar compounds and sulfur compounds by passing the deasphalted HCO/solvent/reagent reaction product through a natural clay and activated carbon mixture that remove all excess and/or unconsumed oxidation reagents.

TABLE 8

Sample Candidate Oil Balance (Run 080829V-1):

Inputs	Mass (kg)	Outputs	Mass (kg)

Crude Oil	154	Upgraded Oil	120
Solvent	620	Asphaltenes	34
Biological Catalyst	9	Solvent	589
Oxidizing Reagents	18	Solvent Loss	31
Chemical Catalyst	9	Reagent + Catalyst	18
Adsorbent Agents	40	Reagent + Catalyst Loss	18
		Adsorbent Agents	40
TOTAL	850	TOTAL	769
Crude Oil Volume	1 bbl	Upgraded Oil Volume	0.87 bbl

TABLE 9

Analytical			Change
Parameters	Raw	Upgraded	(%)	Method

Total Acid	3.19	0.26	−91.8	ASTM D664
Number (TAN)
(mg KOH/g)
API gravity	14.5	32.5	+124.1	ASTM D4052
(° API, @15° C.)
Density	969.0	862.5	−11.0	ASTM D4052
(kg/m³, @15° C.)
Nickel (μg/g)	12.2	<1.0	−91.8	ASTM D5185
Vanadium (μg/g)	23.8	1.7	−92.9	ASTM D5185
Sulfur (mass %)	1.18	0.62	−47.5	ASTM D4294
SIMDIST	IBP = 130.8	IBP = 85.5	—	ASTM D7169
(by GC)	See plot	See plot
(IBP¹to 720° C.)

¹IBP = Initial Boiling Point (° C.)
Referring to FIG. 6, this SIMDIST corresponds to Example 4.

EXAMPLE 5

Pentane Solvent Deasphalting Only Using Acoustic Sonication Only

The methodology involved mixing 619.4 g heavy crude oil (HCO) from Alberta with 716.7 g of solvent (n-pentane)(1,336 grams total), and therefore a solvent:oil weight ratio of 1.16, in a baffled 1.7 litre stainless steel reaction chamber. Acoustic energy was applied for 60 seconds at 40 kW continuously in batch mode followed by direct insoluble asphaltenes fraction filtration and atmospheric pressure distillation for solvent removal. The mass yield on the deasphalted oil was 85.3% of the HCO feedstock.

TABLE 10

			Change
Analytical Parameters	Raw	Upgraded	(%)	Method

API gravity	10.7	20.8	+94.4	ASTM D4052
(° API, @15° C.)
Density	994.5	928.2	−6.7	ASTM D4052
(kg/m³, @15° C.)
Viscosity (cSt)	25460	253.9	−99.0
Nickel (μg/g)	69	50	−27.5	ASTM D5185
Vanadium (μg/g)	159	118	−24.5	ASTM D5185
Sulfur (mass %)	4.34	3.74	−13.8	ASTM D4294
SIMDIST (by GC)	IBP = 175	IBP = 31	—	ASTM D7169
(IBP¹-720° C.)

EXAMPLE 6

Hexane Solvent Deasphalting Only Using Acoustic Sonication Only

The methodology involved mixing to a solvent: oil ratio of 1.09 by adding 690.9 g heavy crude oil (HCO) from Alberta with 631.6 g of solvent(n-hexane)(1,323 grams total) and therefore a solvent:oil weight ratio of 0.91, in a baffled 1.7 litre stainless steel reaction chamber. Acoustic energy was applied for 60 seconds at 40 kW continuously in batch mode followed by direct insoluble asphaltenes fraction filtration and atmospheric pressure distillation for solvent removal. The mass yield on deasphalted oil was 95.5% of the HCO feedstock.

TABLE 11

			Change
Analytical Parameters	Raw	Upgraded	(%)	Method

API gravity	10.7	15.0	+40.1	ASTM D4052
(° API, @15° C.)
Density	994.5	965.9	−2.9	ASTM D4052
(kg/m³, @15° C)

Accordingly, while this invention has been described with reference to illustrative embodiments, this description is not intended to be construed in a limiting sense, for instance longer residence times and higher solvent ratios could be used. Various modifications of the illustrative embodiments, as well as other embodiments of the invention, will be apparent to persons skilled in the art upon reference to this description. It is therefore contemplated that the appended claims will cover any such modifications or embodiments as fall within the scope of the invention.

Claims

We claim:

1. A method for treating heavy crude oil (HCO) comprising the steps of:

a) combining said HCO with an alkane containing solvent to form an HCO/solvent mixture;

b) sonicating said mixture at audio frequency to precipitate asphaltenes from the HCO/solvent mixture; and

c) separating the precipitated asphaltenes from the HCO/solvent mixture.

2. A method as in claim 1, vacuum filtering the HCO/solvent mixture to remove precipitated asphaltenes.

3. A method as in claim 1, distilling the HCO-solvent mixture to remove solvent from the HCO/solvent mixture after removal of precipitated asphaltenes so as to create a deasphalted and solvent free synthetic crude oil (SCO).

4. A method as in claim 1, wherein the alkane contains solvent selected from the group consisting of pentane, hexane and iso-octane.

5. A method as in claim 1, wherein the deasphalted HCO/solvent mixture is used as the feedstock for a chemical and/or biological oil upgrading process.

6. A method as in claim 5, wherein the chemical and/or biological process uses enzyme sources.

7. A method as in claim 5, wherein the chemical and/or biological process uses one or more oxidants in the presence of an acid.

8. A claim as in claim 6, wherein the enzyme source is soyabean husk.

9. A claim as in claim 8, wherein the enzyme is peroxidase.

10. A claim as in claim 7, wherein the acid is acetic acid.

11. A claim as in claim 7, wherein the oxidant is hydrogen peroxide combined with iron oxide.

12. A method as in claim 1, wherein the deasphalting time is 2 minutes (120 seconds) or less.

13. A method as in claim 13, wherein the deasphalting time is 60 seconds.

14. A method as in claim 1, wherein the deasphalting solvent:HCO weight ratio is less than or equal to 3.5.

15. A method as in claim 15, wherein the deasphalting solvent:HCO weight ratio is 1.16 or less.

16. A method as in claim 16, wherein the deasphalting solvent:HCO weight ratio is 0.91.