CA1300000C - Recovery of heavy oil - Google Patents
Recovery of heavy oilInfo
- Publication number
- CA1300000C CA1300000C CA000550500A CA550500A CA1300000C CA 1300000 C CA1300000 C CA 1300000C CA 000550500 A CA000550500 A CA 000550500A CA 550500 A CA550500 A CA 550500A CA 1300000 C CA1300000 C CA 1300000C
- Authority
- CA
- Canada
- Prior art keywords
- bitumen
- deposit
- conditioning
- recovery
- conditioned
- 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 - Fee Related
Links
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
- C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10C—WORKING-UP PITCH, ASPHALT, BITUMEN, TAR; PYROLIGNEOUS ACID
- C10C3/00—Working-up pitch, asphalt, bitumen
- C10C3/007—Working-up pitch, asphalt, bitumen winning and separation of asphalt from mixtures with aggregates, fillers and other products, e.g. winning from natural asphalt and regeneration of waste asphalt
-
- 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
- C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
- C10G1/04—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
Landscapes
- Chemical & Material Sciences (AREA)
- Engineering & Computer Science (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Organic Chemistry (AREA)
- General Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Life Sciences & Earth Sciences (AREA)
- Wood Science & Technology (AREA)
- Civil Engineering (AREA)
- Structural Engineering (AREA)
- Materials Engineering (AREA)
- Analytical Chemistry (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
ABSTRACT OF THE DISCLOSURE
RECOVERY OF HEAVY OIL
A two stage method for the recover of heavy crude oil or bitumen associated with a solid inorganic substance and water from an underground deposit comprises chemically conditioning the deposit in situ with an aqueous solution of an alkaline compound and subsequently treating the conditioned deposit to recover the heavy crude oil or bitumen from it.
The method is particularly suitable for recovering bitumam from tar sand.
In situ conditioning increases the yield of product.
RECOVERY OF HEAVY OIL
A two stage method for the recover of heavy crude oil or bitumen associated with a solid inorganic substance and water from an underground deposit comprises chemically conditioning the deposit in situ with an aqueous solution of an alkaline compound and subsequently treating the conditioned deposit to recover the heavy crude oil or bitumen from it.
The method is particularly suitable for recovering bitumam from tar sand.
In situ conditioning increases the yield of product.
Description
~3 [l~
6340(2) RECO_ RY OF HEAVY OIL
This invention relates to a method for the recovery of heavy oil, especially bitumen from tar sands.
As reserves of conventional crude oils (approximately 15 to 30 API) decline, increasing importance will be attached to efficient methods for recovering heavy crude oils (8-12 API) and the even heavier bitumens (less than 8 API). Most bitumens are associated with minerals such as clays and quartz, and are known as tar sands.
The ~lberta tar sands are among the largest deposits of their kind in the world and are estimated to contain about one trillion barrels of bitumen in place. The Athabasca region alone has reserves of 250 billion barrels. About 0.7 million acres of the Athabasca deposit is overlain by 150 ft, or less, of overburden and is potentially capable of being mined from the surface. The remaining 16.6 million acres are at such depths that the bitumen can only be recovered by in-situ methods.
The crude bitumen occurs in beds of sand and clay, usually partly connected together, and in porous carbonate rocks.
In high grade tar sand the pore space is filled with bitumen (typically 15-20X weight) and water.
In low grade tar sands, i.e. containing less than lOX by weight bitumen, clusters of small particles exist within the framework formed by the coarse inorganic grains. These particles, known as fines, are saturated with water. Thus the amount of connate water in the tar sand increases with increasing fines.
~3~0~
content.
The bitumen typically has an API gravity of 7 and is denser than water at room temperature but becomes less dense than water at elevated temperatures.
Ln the case of deposits near the surface the overburden may be removed and the tar sand recovered by open cast mining.
Mined tar sands are refined by the aforementioned hot water process. A dsscription of this process is given in US~ ~ 474 616.
In broad summary, this process comprises first conditioning the tar sand, to make it amenable to flotation separation of the bitumen from the solids. Conditioning involves feeding mined tar sands, hot water (80C), an alkaline process aid (usually NaOH), and steam into a rotating horizontal drum wherein the ingredients are agitated together under relatively hlgh shear conditions.
During conditioning, the mined tar sand (in which the bitumen, connate water and solids are tightly bound together) becomes an aqueous slurry of porridge-like consistency, wherein the components are in loose association.
The slurry leaving the drum is screened to remove oversize material and then flooded or diluted with additional hot water.
The bitumen is then recovered by primary and secondary froth flotation.
This process suffers from the disadvantages that bitumen/water emulsions are formed and the separated water contains colloidal dispersions of clay, fines and oil which are extremely stable and present serious problems in their disposal.
For deposits at a greater depth, the technigue of jet leaching can be employed. Jet leaching is a known technique for the extraction of tar sands which comprises drilling and fixing casing until the pay æone is reached. The ore is then fragmented by directing high velocity jets of water onto it and the bitumen is pumped to the surface, leaving most of the solid particles downhole.
In a conventional single stage jet leaching process alkaline water (pH> 11) at high temperatures (i 80C) is used to mobilise the bitumen. The water is generally deaerated and stripped of ~3~
divalent metal ions.
Alternative approaches for deep deposits are the use of cyclic steam stimulation or steam drive to recover the bitumen.
Cyclic steam stimulation is otherwise known as "huff and puff".
In this process, steam is injected and the bitumen produced through the same well. The steam is injected down the well for several weeks. On the termination of steam injection, bitumen flows freely up the well for about one week, after which it has to be pumped to the surface. Pumping can usually be continued for several months before more steam must be injected.
In steam drive, the steam acts to heat the deposit and drive the bitumen from an injection well to a production well.
In all these methods, oil recovery is assisted when the sand is water wet and hindered when it is oil wet.
In the case of tar sands, most of the sand is water wet.
It is an ob~ect of the present invention to condition chemically the material in situ by in~ecting an aqueous solution of an alkaline compound into the reservoir.
Thus according to the present invention there is provided a a two stage method for the recovery of heavy crude oil or bitumen associated with a solid inorganic substance and water from an underground deposit, which method comprises chemically conditioning the deposit ~n situ with an aqueous solution of an alkaline compound and subsequently treating the conditioned deposit to recover heavy crude oil or bitumen from it.
In the first stage the preferred alkaline compound is sodium hydro~ide.
This is preferably added to render the pH of the conditioning solution in the range 11 to 12.5.
The alkaline solution is left in a quiescent state so that physico-chemical action (rather than mechanical) detaches the bitumen from the inorganic solid making it more amenable to recovery.
In the second stage, a number of options are open to recover the bitumen. These include steam drive, cyclic steam simulation, a '~i;, ,~"
r6~
130~ 0 modified cyclic steam simulation in which steam and alkali are injected together, cold or hot water drive and jet leaching, preferably the latter, where tar sand is concerned.
It is believed, although applicants do not wish to be bound by this theory, that the presence of the alkali causes the water films surrounding the inorganic grains to swell and thereby promote the separation of bitumen from the tar sand matrix.
In all cases, in situ conditioning will increase yields and, in the case of cyclic steam stimulation, will extend the periods between injection of steam.
The invention is illustrated with reference to the following Examples and the accompanying drawings.
In the accompanying drawings:
Fig. 1 is a graph of bitumen recovery against initial pH of sodium hydroxide conditioning agent;
Fig. 2 is a graph plotting bitumen recovery against contact time of the conditioning agent illustrating the e~fects of contact time and temperature; and Fig. 3 is a graph of bitumen recovery against temperature of leachant illustrating the effect of varying the temperature of the leachant in the extraction step following the conditioning process.
A medium grade (11.6 wt ~ bitumen) Athabascan tar sand sample was used. The tar sand had poor processing characteristics and as such was considered to be suitable for investigating experimental procedures aimed at improving processability.
Example l Static Tests A series of experiments were conducted in which samples of tar sand (10 g) were conditioned in a sample jar by contacting with sodium hydroxide solution (10 ml;
over pH range 9 - 13), initially at a known temperature (20 - 80C), and allowed to cool naturally for a known time period (0.25 - 24 h).
After this conditioning stage, a quantity o~
~a o - 4a -deionised water (35 ml) was added to the jar and bitumen removal effected by heat treatment in a water bath (0.5 h at 80C) followed by inversion of the jar to promote bitumen separation and flotation.
Example 2 Dynamic Jet Leaching Tests A series of experiments were carried out in parallel with the static jar tests using a laboratory scale jet leaching test system as described in GB 2176224A.
Samples of tar sand (125 g) were conditioned by contacting with sodium hydroxide solution (50 ml over pH
range 9 - 13), initially at a known temperature (20 - 80C), and allowed to cool naturally ~ 3~
over a known time period (0.25 - 24 h).
After conditioning, deionised water (1350 ml) was added to the closed jet leaching loop and bitumen recovered by jetting with leachant at known temperature (30 - 80C), for a constant time period (0.67 h) and jet velocity (ca 3 m s~l).
For both static and jet leaching tests, the extent of bitumen recovery was determined gravimetrically by solvent (toluene) extraction of the cleaned sand following bitumen extraction.
Pigure 1 illustrates the bitumen recovery from the tar sand for both the static and jet leaching tests, as a function of the initial pH of the sodium hydroxide conditioning agent. For the two different experimental procedures, there i9 a critical pH (ca 11) below which the conditioning process i5 less effective. Increasing this pH resulted in tar sand conditioning, characterised by rapid disintegration of the tar sand matrix, the formation of a stable clay dispersion in the supernatant conditioning fluid, and the adoption of a sandy rather than oily tar sand appearance. At higher pH (> ca 12.5) the characteristic physical transformation of the tar sand matrix was not observed. Here the bitumen recovery can be ascribed primarily to an emulsification type extraction mechanism, as was evident by the appearance of the leachant following a typical jet leaching experiment. For all conditioned samples subsequent bitumen recoveries in a second stage extraction step were much higher than those observed in a single stage extraction without prior tar sand conditioning where typically < 5% bitumen was recovered. The apparent limit in bitumen recovery (ca 85%) is thought to arise from the relatively moderate shear conditlons (low jet velocity, short jetting times) imposed on the tar sand during a typical experiment.
The concept of a two stage chemical conditioning/extraction type process also resulted in further benefits such as improved quality of both recovered bitumen and leachant, compared to bitumen recovered by a single stage alkali extraction process, as summarised in Table 1.
~;. ' ~3~:300~0 Effect of Contact Time/Temperature Th~se aspects ar~ illustrated in Figure 2 in which bitumen recovery ls seen to increase with increasing contact time and conditioning temperature, approaching a plateau in recovery at around 24 h contact time. At low contact times, the effect of varying the temperatura of the conditioning agent i~ more importan~, whereas for longer times (> 24 h), the bitumen recovery ~
independent of the initial conditioning temperature. For example, tar sand conditioned at 20~C for 24 hours results in an equivalent bitumen recovery to that conditioned initially at 80C for 24 hours. This suggests that the predominant mechanism in the conditioning process and, in particular, the migration of bitumen within the tar sand matrix is chemically rather than temperature controlled.
Effect of Leachant Temp_rature FollowinR Conditionin~
Figure 3 shows the effect of varying the temperature of the leachant in the extraction step following the conditionLng process. After tar sand conditioning at 20C (24 h), a leachant temperature of only 45C results in high (ca 80%) bitumen recovery.
Higher leachant temperature only marginally improves the extent of rscovery, although the kinetics or rate of bitumen recovery is observed to increase significantly.
Such a profile is in sharp contrast to the strong temperature dependence exhibited for an unconditioned single stage bitumen extract~on process in which a hiBher total concentration of sodium hydroxide than for the two stage proces~ of conditioning and recovery (5.6 x 10-3 moles NaOH cf to 7.9 x 10-4 moles) was present in the leachant.
The data in Table 1 reveal that the total alkali consumption in both the two stage process (conditioning + recovery) and the single stage alkali extraction procedure are similar, although the mode of operation o the sodium hydroxide differs greatly.
In the two stage process the alkali serves to reiect un-wanted clay particles from the tar sand matrix and cause~ migration of bitumen droplets away from sand grains ~n readiness for detachment.
~lL3 (~ 1)0 Reduction of pH in the second stage extraction step (to ca pH 9) promotes clay settling and discourages bitumen emulsification. By comparison, in the single stage alkali process, a similar chemical driving force is not present to the same extent, such that bitumen removal is more dependent on a viscosity reduction mechanism with the requirement of high leachant temperatures. Furthermore, the relatively high final alkalinity of the leachant (ca pH 11.2) promotes stabilisation of the clay dispersion and emulsification of the bitumen.
Thus a two stage process (chemical conditioning followed by jet leaching) not only improves the degree of bitumen recovery but also produces a hi&her quality bitumen with lower solids and water content. A further advantage is gained in that stable fines suspensions are not produced thereby reducing the need for effluent treatment and water processing prior to recycling.
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6340(2) RECO_ RY OF HEAVY OIL
This invention relates to a method for the recovery of heavy oil, especially bitumen from tar sands.
As reserves of conventional crude oils (approximately 15 to 30 API) decline, increasing importance will be attached to efficient methods for recovering heavy crude oils (8-12 API) and the even heavier bitumens (less than 8 API). Most bitumens are associated with minerals such as clays and quartz, and are known as tar sands.
The ~lberta tar sands are among the largest deposits of their kind in the world and are estimated to contain about one trillion barrels of bitumen in place. The Athabasca region alone has reserves of 250 billion barrels. About 0.7 million acres of the Athabasca deposit is overlain by 150 ft, or less, of overburden and is potentially capable of being mined from the surface. The remaining 16.6 million acres are at such depths that the bitumen can only be recovered by in-situ methods.
The crude bitumen occurs in beds of sand and clay, usually partly connected together, and in porous carbonate rocks.
In high grade tar sand the pore space is filled with bitumen (typically 15-20X weight) and water.
In low grade tar sands, i.e. containing less than lOX by weight bitumen, clusters of small particles exist within the framework formed by the coarse inorganic grains. These particles, known as fines, are saturated with water. Thus the amount of connate water in the tar sand increases with increasing fines.
~3~0~
content.
The bitumen typically has an API gravity of 7 and is denser than water at room temperature but becomes less dense than water at elevated temperatures.
Ln the case of deposits near the surface the overburden may be removed and the tar sand recovered by open cast mining.
Mined tar sands are refined by the aforementioned hot water process. A dsscription of this process is given in US~ ~ 474 616.
In broad summary, this process comprises first conditioning the tar sand, to make it amenable to flotation separation of the bitumen from the solids. Conditioning involves feeding mined tar sands, hot water (80C), an alkaline process aid (usually NaOH), and steam into a rotating horizontal drum wherein the ingredients are agitated together under relatively hlgh shear conditions.
During conditioning, the mined tar sand (in which the bitumen, connate water and solids are tightly bound together) becomes an aqueous slurry of porridge-like consistency, wherein the components are in loose association.
The slurry leaving the drum is screened to remove oversize material and then flooded or diluted with additional hot water.
The bitumen is then recovered by primary and secondary froth flotation.
This process suffers from the disadvantages that bitumen/water emulsions are formed and the separated water contains colloidal dispersions of clay, fines and oil which are extremely stable and present serious problems in their disposal.
For deposits at a greater depth, the technigue of jet leaching can be employed. Jet leaching is a known technique for the extraction of tar sands which comprises drilling and fixing casing until the pay æone is reached. The ore is then fragmented by directing high velocity jets of water onto it and the bitumen is pumped to the surface, leaving most of the solid particles downhole.
In a conventional single stage jet leaching process alkaline water (pH> 11) at high temperatures (i 80C) is used to mobilise the bitumen. The water is generally deaerated and stripped of ~3~
divalent metal ions.
Alternative approaches for deep deposits are the use of cyclic steam stimulation or steam drive to recover the bitumen.
Cyclic steam stimulation is otherwise known as "huff and puff".
In this process, steam is injected and the bitumen produced through the same well. The steam is injected down the well for several weeks. On the termination of steam injection, bitumen flows freely up the well for about one week, after which it has to be pumped to the surface. Pumping can usually be continued for several months before more steam must be injected.
In steam drive, the steam acts to heat the deposit and drive the bitumen from an injection well to a production well.
In all these methods, oil recovery is assisted when the sand is water wet and hindered when it is oil wet.
In the case of tar sands, most of the sand is water wet.
It is an ob~ect of the present invention to condition chemically the material in situ by in~ecting an aqueous solution of an alkaline compound into the reservoir.
Thus according to the present invention there is provided a a two stage method for the recovery of heavy crude oil or bitumen associated with a solid inorganic substance and water from an underground deposit, which method comprises chemically conditioning the deposit ~n situ with an aqueous solution of an alkaline compound and subsequently treating the conditioned deposit to recover heavy crude oil or bitumen from it.
In the first stage the preferred alkaline compound is sodium hydro~ide.
This is preferably added to render the pH of the conditioning solution in the range 11 to 12.5.
The alkaline solution is left in a quiescent state so that physico-chemical action (rather than mechanical) detaches the bitumen from the inorganic solid making it more amenable to recovery.
In the second stage, a number of options are open to recover the bitumen. These include steam drive, cyclic steam simulation, a '~i;, ,~"
r6~
130~ 0 modified cyclic steam simulation in which steam and alkali are injected together, cold or hot water drive and jet leaching, preferably the latter, where tar sand is concerned.
It is believed, although applicants do not wish to be bound by this theory, that the presence of the alkali causes the water films surrounding the inorganic grains to swell and thereby promote the separation of bitumen from the tar sand matrix.
In all cases, in situ conditioning will increase yields and, in the case of cyclic steam stimulation, will extend the periods between injection of steam.
The invention is illustrated with reference to the following Examples and the accompanying drawings.
In the accompanying drawings:
Fig. 1 is a graph of bitumen recovery against initial pH of sodium hydroxide conditioning agent;
Fig. 2 is a graph plotting bitumen recovery against contact time of the conditioning agent illustrating the e~fects of contact time and temperature; and Fig. 3 is a graph of bitumen recovery against temperature of leachant illustrating the effect of varying the temperature of the leachant in the extraction step following the conditioning process.
A medium grade (11.6 wt ~ bitumen) Athabascan tar sand sample was used. The tar sand had poor processing characteristics and as such was considered to be suitable for investigating experimental procedures aimed at improving processability.
Example l Static Tests A series of experiments were conducted in which samples of tar sand (10 g) were conditioned in a sample jar by contacting with sodium hydroxide solution (10 ml;
over pH range 9 - 13), initially at a known temperature (20 - 80C), and allowed to cool naturally for a known time period (0.25 - 24 h).
After this conditioning stage, a quantity o~
~a o - 4a -deionised water (35 ml) was added to the jar and bitumen removal effected by heat treatment in a water bath (0.5 h at 80C) followed by inversion of the jar to promote bitumen separation and flotation.
Example 2 Dynamic Jet Leaching Tests A series of experiments were carried out in parallel with the static jar tests using a laboratory scale jet leaching test system as described in GB 2176224A.
Samples of tar sand (125 g) were conditioned by contacting with sodium hydroxide solution (50 ml over pH
range 9 - 13), initially at a known temperature (20 - 80C), and allowed to cool naturally ~ 3~
over a known time period (0.25 - 24 h).
After conditioning, deionised water (1350 ml) was added to the closed jet leaching loop and bitumen recovered by jetting with leachant at known temperature (30 - 80C), for a constant time period (0.67 h) and jet velocity (ca 3 m s~l).
For both static and jet leaching tests, the extent of bitumen recovery was determined gravimetrically by solvent (toluene) extraction of the cleaned sand following bitumen extraction.
Pigure 1 illustrates the bitumen recovery from the tar sand for both the static and jet leaching tests, as a function of the initial pH of the sodium hydroxide conditioning agent. For the two different experimental procedures, there i9 a critical pH (ca 11) below which the conditioning process i5 less effective. Increasing this pH resulted in tar sand conditioning, characterised by rapid disintegration of the tar sand matrix, the formation of a stable clay dispersion in the supernatant conditioning fluid, and the adoption of a sandy rather than oily tar sand appearance. At higher pH (> ca 12.5) the characteristic physical transformation of the tar sand matrix was not observed. Here the bitumen recovery can be ascribed primarily to an emulsification type extraction mechanism, as was evident by the appearance of the leachant following a typical jet leaching experiment. For all conditioned samples subsequent bitumen recoveries in a second stage extraction step were much higher than those observed in a single stage extraction without prior tar sand conditioning where typically < 5% bitumen was recovered. The apparent limit in bitumen recovery (ca 85%) is thought to arise from the relatively moderate shear conditlons (low jet velocity, short jetting times) imposed on the tar sand during a typical experiment.
The concept of a two stage chemical conditioning/extraction type process also resulted in further benefits such as improved quality of both recovered bitumen and leachant, compared to bitumen recovered by a single stage alkali extraction process, as summarised in Table 1.
~;. ' ~3~:300~0 Effect of Contact Time/Temperature Th~se aspects ar~ illustrated in Figure 2 in which bitumen recovery ls seen to increase with increasing contact time and conditioning temperature, approaching a plateau in recovery at around 24 h contact time. At low contact times, the effect of varying the temperatura of the conditioning agent i~ more importan~, whereas for longer times (> 24 h), the bitumen recovery ~
independent of the initial conditioning temperature. For example, tar sand conditioned at 20~C for 24 hours results in an equivalent bitumen recovery to that conditioned initially at 80C for 24 hours. This suggests that the predominant mechanism in the conditioning process and, in particular, the migration of bitumen within the tar sand matrix is chemically rather than temperature controlled.
Effect of Leachant Temp_rature FollowinR Conditionin~
Figure 3 shows the effect of varying the temperature of the leachant in the extraction step following the conditionLng process. After tar sand conditioning at 20C (24 h), a leachant temperature of only 45C results in high (ca 80%) bitumen recovery.
Higher leachant temperature only marginally improves the extent of rscovery, although the kinetics or rate of bitumen recovery is observed to increase significantly.
Such a profile is in sharp contrast to the strong temperature dependence exhibited for an unconditioned single stage bitumen extract~on process in which a hiBher total concentration of sodium hydroxide than for the two stage proces~ of conditioning and recovery (5.6 x 10-3 moles NaOH cf to 7.9 x 10-4 moles) was present in the leachant.
The data in Table 1 reveal that the total alkali consumption in both the two stage process (conditioning + recovery) and the single stage alkali extraction procedure are similar, although the mode of operation o the sodium hydroxide differs greatly.
In the two stage process the alkali serves to reiect un-wanted clay particles from the tar sand matrix and cause~ migration of bitumen droplets away from sand grains ~n readiness for detachment.
~lL3 (~ 1)0 Reduction of pH in the second stage extraction step (to ca pH 9) promotes clay settling and discourages bitumen emulsification. By comparison, in the single stage alkali process, a similar chemical driving force is not present to the same extent, such that bitumen removal is more dependent on a viscosity reduction mechanism with the requirement of high leachant temperatures. Furthermore, the relatively high final alkalinity of the leachant (ca pH 11.2) promotes stabilisation of the clay dispersion and emulsification of the bitumen.
Thus a two stage process (chemical conditioning followed by jet leaching) not only improves the degree of bitumen recovery but also produces a hi&her quality bitumen with lower solids and water content. A further advantage is gained in that stable fines suspensions are not produced thereby reducing the need for effluent treatment and water processing prior to recycling.
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Claims (6)
1. A two stage method for the recovery of heavy crude oil or bitumen associated with a solid inorganic substance and water from an underground deposit which method comprises chemically conditioning the deposit in situ with an aqueous solution of an alkaline compound, said conditioning comprising contacting the solid inorganic substance with the solution in a quiescent state to detach the bitumen from the solid inorganic substance, and subsequently treating the conditioned deposit to recover heavy crude oil or bitumen from it.
2. A method according to claim 1 wherein the deposit is a tar sand deposit.
3. A method according to claim 1 or 2 wherein the alkaline compound is sodium hydroxide.
4. A method according to claim 1 wherein the alkaline compound is added in amount sufficient to render the pH of the conditioning solution in the range 11 to 12.5.
5. A method according to claim 2 wherein the conditioned deposit is treated by steam drive, cyclic steam simulation, modified cyclic steam stimulation, or cold or hot water drive.
6. A method according to claim 2 wherein the conditioned deposit is treated by jet leaching.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| GB868625933A GB8625933D0 (en) | 1986-10-30 | 1986-10-30 | Recovery of heavy oil |
| GB8625933 | 1986-10-30 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1300000C true CA1300000C (en) | 1992-05-05 |
Family
ID=10606524
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000550500A Expired - Fee Related CA1300000C (en) | 1986-10-30 | 1987-10-28 | Recovery of heavy oil |
Country Status (3)
| Country | Link |
|---|---|
| EP (1) | EP0269231A1 (en) |
| CA (1) | CA1300000C (en) |
| GB (1) | GB8625933D0 (en) |
Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US10487636B2 (en) | 2017-07-27 | 2019-11-26 | Exxonmobil Upstream Research Company | Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes |
| US11002123B2 (en) | 2017-08-31 | 2021-05-11 | Exxonmobil Upstream Research Company | Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation |
| US11142681B2 (en) | 2017-06-29 | 2021-10-12 | Exxonmobil Upstream Research Company | Chasing solvent for enhanced recovery processes |
| US11261725B2 (en) | 2017-10-24 | 2022-03-01 | Exxonmobil Upstream Research Company | Systems and methods for estimating and controlling liquid level using periodic shut-ins |
Families Citing this family (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5264118A (en) * | 1989-11-24 | 1993-11-23 | Alberta Energy Company, Ltd. | Pipeline conditioning process for mined oil-sand |
| US7809538B2 (en) | 2006-01-13 | 2010-10-05 | Halliburton Energy Services, Inc. | Real time monitoring and control of thermal recovery operations for heavy oil reservoirs |
| US7832482B2 (en) | 2006-10-10 | 2010-11-16 | Halliburton Energy Services, Inc. | Producing resources using steam injection |
| US7770643B2 (en) | 2006-10-10 | 2010-08-10 | Halliburton Energy Services, Inc. | Hydrocarbon recovery using fluids |
Family Cites Families (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CA1129801A (en) * | 1979-06-08 | 1982-08-17 | Michael A. Kessick | Alkali recycle process for recovery of heavy oils and bitumens |
| CA1134309A (en) * | 1980-04-08 | 1982-10-26 | Shimon S. Tchernyak | Conditioning drum for a tar sands hot water extraction process |
-
1986
- 1986-10-30 GB GB868625933A patent/GB8625933D0/en active Pending
-
1987
- 1987-10-08 EP EP19870308937 patent/EP0269231A1/en not_active Withdrawn
- 1987-10-28 CA CA000550500A patent/CA1300000C/en not_active Expired - Fee Related
Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US11142681B2 (en) | 2017-06-29 | 2021-10-12 | Exxonmobil Upstream Research Company | Chasing solvent for enhanced recovery processes |
| US10487636B2 (en) | 2017-07-27 | 2019-11-26 | Exxonmobil Upstream Research Company | Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes |
| US11002123B2 (en) | 2017-08-31 | 2021-05-11 | Exxonmobil Upstream Research Company | Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation |
| US11261725B2 (en) | 2017-10-24 | 2022-03-01 | Exxonmobil Upstream Research Company | Systems and methods for estimating and controlling liquid level using periodic shut-ins |
Also Published As
| Publication number | Publication date |
|---|---|
| GB8625933D0 (en) | 1986-12-03 |
| EP0269231A1 (en) | 1988-06-01 |
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