WO2018111342A1 - Composition d'amine pour l'extraction à la vapeur de bitume - Google Patents

Composition d'amine pour l'extraction à la vapeur de bitume Download PDF

Info

Publication number
WO2018111342A1
WO2018111342A1 PCT/US2017/037908 US2017037908W WO2018111342A1 WO 2018111342 A1 WO2018111342 A1 WO 2018111342A1 US 2017037908 W US2017037908 W US 2017037908W WO 2018111342 A1 WO2018111342 A1 WO 2018111342A1
Authority
WO
WIPO (PCT)
Prior art keywords
oxide capped
ether
group
ethylene oxide
glycol ether
Prior art date
Application number
PCT/US2017/037908
Other languages
English (en)
Inventor
Cole A. WITHAM
Yuko Kida
Biplab MUKHERJEE
Christopher W. NELSON
Timothy J. Young
Original Assignee
Dow Global Technologies Llc
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Dow Global Technologies Llc filed Critical Dow Global Technologies Llc
Publication of WO2018111342A1 publication Critical patent/WO2018111342A1/fr

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
    • 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
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
    • C09K8/592—Compositions used in combination with generated heat, e.g. by steam injection

Definitions

  • the present invention relates to the recovery of bitumen from oil sands. More particularly, the present invention is an improved method for bitumen recovery from oil sands through either surface mining or in situ recovery.
  • the improvement is the use of a composition comprising an amine and an ethylene oxide capped glycol ether and/or a propylene oxide capped glycol ether as an extraction aid in the water and/or steam used in the bitumen recovery process.
  • bitumen deposits of heavy oil, typically referred to as bitumen.
  • the bitumen from these oil sands may be extracted and refined into synthetic oil or directly into petroleum products.
  • the difficulty with bitumen lies in that it typically is very viscous, sometimes to the point of being more solid than liquid. Thus, bitumen typically does not flow as less viscous, or lighter, crude oils do.
  • bitumen Because of the viscous nature of bitumen, it cannot be produced from a well drilled into the oil sands as is the case with lighter crude oil. This is so because the bitumen simply does not flow without being first heated, diluted, and/or upgraded. Since normal oil drilling practices are inadequate to produce bitumen, several methods have been developed over several decades to extract and process oil sands to remove the bitumen. For shallow deposits of oil sands, a typical method includes surface extraction, or mining, followed by subsequent treatment of the oil sands to remove the bitumen.
  • An extraction agent such as sodium hydroxide (NaOH), surfactants, and/or air may be mixed with the oil sands.
  • Water is added to the oil sands to create an oil sands slurry, to which additives such as NaOH may be added, which is then transported to an extraction plant, typically via a pipeline.
  • additives such as NaOH may be added
  • the slurry is agitated and the water and NaOH releases the bitumen from the oil sands.
  • Air entrained with the water and NaOH attaches to the bitumen, allowing it to float to the top of the slurry mixture and create a froth.
  • the bitumen froth is further treated to remove residual water and fines, which are typically small sand and clay particles.
  • the bitumen is then either stored for further treatment or immediately treated, either chemically or mixed with lighter petroleum products, and transported by pipeline for upgrading into synthetic crude oil.
  • Cyclic Steam Stimulation is the conventional "huff and puff" in situ method whereby steam is injected into the well at a temperature of 250°C to 400°C. The steam rises and heats the bitumen, decreasing its viscosity. The well is allowed to sit for days or weeks, and then hot oil mixed with condensed steam is pumped out for a period of weeks or months. The process is then repeated.
  • the "huff and puff” method requires the site to be shut down for weeks to allow pumpable oil to accumulate.
  • the CSS method typically results in 20 to 25 percent recovery of the available oil.
  • SAGD Steam Assisted Gravity Drainage
  • the present invention is an improved bitumen recovery process comprising the step of treating oil sands with a composition comprising (i) an amine and (ii) a glycol ether wherein the treatment is to oil sands recovered by surface mining or in situ production to oil sands in a subterranean reservoir.
  • the amine (i) of the present invention is represented by the following formula:
  • R 1 , R 2 , and R 3 are independently H, or a linear or branched or cyclic alkyl, phenyl, or alkylphenyl group of 1 to 8 carbons, preferably independently H or a linear alkyl groups having 1 to 4 carbons, preferably dimethylamine, diethylamine, butylamine, dibutylamine, isobutylamine, diisobutylamine, diethylamine, propylamine, dipropylamine, ⁇ propylamine, isopropylamine, diisopropylamine, hexylamine, pentylamine,
  • R 1 and R 2 are independently -H, -AL where -AL is an unsubstituted Ci to C20, preferably Ci to C 6 alkyl group, a C 6 to C12 aromatically substituted Ci to C20, preferably Ci to C 6 alkyl group, or combination thereof, wherein -AL may contain one or more of a -COOR 4 where R 4 is -H, alkyl, aryl or alkylaryl, CN, -CHO, -NR 5 R 6 group where R 5 and R 6 are independently -H, alkyl or aryl, -OH group, -O- group, -S- group, -N- group, - CI, -Br, -F, or R 1 and R 2 may form an unsubstituted or substituted imine, or R 1 and R 2 may form
  • ethylenediamine N-phenyl-o-phenylenediamine, 2,4,6-tri-tert-butylaniline, N- phenylglycine, 3,5-di-tert-butylaniline, -l,l'-binaphthyl-2,2'-diamine, 4'-aminobenzo-15- crown 5-ether, a-methylbenzylamine, 4-(dimethylamino)phenylacetic acid, N-benzyl- ethylenediamine, N-methylphenethylamine, 1 ,2-diphenylethylenediamine, tritylamine, N- phenylethylenediamine, pyridine, toluidine, anisidine, methylaniline, diphenylamine, halogen substitution of aromatic amines, indole, indoline, quinoline, l-amino-4- alkylaminobenzene, 1,4-diaminobenzene, imidazole
  • glycol ether (ii) is selected from: (a) an ethylene oxide capped glycol ether described by the following structure:
  • R is a linear, branched, cyclic alkyl, phenyl, or alkyl phenyl group of equal to or greater than 4 carbons, preferably n-butyl, n-pentyl , 2-methyl-l-pentyl, n-hexyl, n-heptyl, n-octyl, 2-ethylhexyl, 2-propylheptyl, phenyl, or cyclohexyl, m is equal to 0 to 3, preferably 1 to 2, and n is 1 to 3, preferably 1 or 2, more preferably m + n is 2, preferably the ethylene capped glycol ether is one of, or a combination thereof, ethylene oxide capped n-butyl ether of propylene glycol, ethylene oxide capped n-hexyl ether of propylene glycol, or ethylene
  • RO-( C2H 4 0)o(CH 2 CH(CH3)0)p H HI wherein is a linear, branched, cyclic alkyl, phenyl, or alkyl phenyl group of equal to or greater than 4 carbons, preferably n-butyl, n-pentyl , 2-methyl-l-pentyl, n-hexyl, n-heptyl, n-octyl, 2-ethylhexyl, 2-propylheptyl, phenyl, or cyclohexyl, o is 0 to 3, , preferably 1 or 2, and p is 1 to 3, preferably 1 or 2, preferably o + p is 2, preferably the propylene capped glycol ether is one of, or a combination thereof, propylene oxide capped n-butyl ether, propylene oxide capped n-butyl ether of ethylene glycol, propylene oxide capped n-he
  • the weight ratio of the amine to glycol ether is 50:50.
  • the bitumen recovery process by surface mining described herein above comprises the steps of: i) surface mining oil sands, ii) preparing an aqueous slurry of the oil sands, iii) treating the aqueous slurry with the amine and ethylene oxide capped glycol ether and/or a propylene oxide capped glycol ether composition, iv) agitating the treated aqueous slurry, v) transferring the agitated treated aqueous slurry to a separation tank, and vi) separating the bitumen from the aqueous portion, preferably the ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether is present in the aqueous slurry in an amount of from 0.01 to 10 weight percent based on the weight of the oil sands.
  • the bitumen recovery process by in situ production described herein above comprises the steps of: i) treating a subterranean reservoir of oil sands by injecting steam containing the amine and ethylene oxide capped glycol ether and/or a propylene oxide capped glycol ether composition into a well, and ii) recovering the bitumen from the well, preferably the concentration of the ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether in the steam is in an amount of from 0.01 to 10 weight percent.
  • bitumen and/or heavy oil from oil sands is accomplished by, but not limited to, two methods; surface mining or in situ recovery sometimes referred to as well production.
  • the oil sands may be recovered by surface or strip mining and transported to a treatment area.
  • a good summary can be found in the article "Understanding Water- Based Bitumen Extraction from Athabasca Oil Sands", J. Masliyah, et al., Canadian Journal of Chemical Engineering, Volume 82, August 2004.
  • the basic steps in bitumen recovery via surface mining include: extraction, froth treatment, tailings treatment, and upgrading. The steps are interrelated; the mining operation affects the extraction and in turn the extraction affects the upgrading operation.
  • the oil sand is mined in an open-pit mine using trucks and shovels.
  • the mined oil sands are transported to a treatment area.
  • the extraction step includes crushing the oil sand lumps and mixing them with
  • conditioned oil sands slurry is introduced to hydrotransport pipelines or to tumblers, where the oil sand lumps are sheared and size reduction takes place.
  • bitumen is recovered or "released' , or "liberated”, from the sand grains.
  • Chemical additives can be added during the slurry preparation stage; for examples of chemicals known in the art see US2008/0139418, incorporated by reference herein in its entirety. In typical operations, the operating slurry temperature ranges from 35°C to 75°C, preferably 40°C to 55°C.
  • bitumen in the tumblers and hydrotransport pipelines creating froth.
  • the aerated bitumen floats and is subsequently skimmed off from the slurry. This is accomplished in large gravity separation vessels, normally referred to as primary separation vessels (PSV), separation cells (Sep Cell) or primary separation cells (PSC).
  • PSV primary separation vessels
  • Sep Cell separation cells
  • PSC primary separation cells
  • Small amounts of bitumen droplets (usually un- aerated bitumen) remaining in the slurry are further recovered using either induced air flotation in mechanical flotation cells and tailings oil recovery vessels, or cyclo-separators and hydrocyclones.
  • overall bitumen recovery in commercial operations is about 88 to 95 percent of the original oil in place.
  • the recovered bitumen in the form of froth normally contains 60 percent bitumen, 30 percent water and 10 percent solids.
  • bitumen froth recovered as such is then de-aerated, and diluted (mixed) with solvents to provide sufficient density difference between water and bitumen and to reduce the bitumen viscosity.
  • a solvent e.g., naphtha or hexane
  • the dilution by a solvent facilitates the removal of the solids and water from the bitumen froth using inclined plate settlers, cyclones and/or centrifuges.
  • a paraffinic diluent solvent
  • partial precipitation of asphaltenes occurs. This leads to the formation of composite aggregates that trap the water and solids in the diluted bitumen froth. In this way gravity separation is greatly enhanced, potentially eliminating the need for cyclones or centrifuges.
  • the tailings stream from the extraction plant goes to the tailings pond for solid-liquid separation.
  • the clarified water is recycled from the pond back to the extraction plant.
  • gypsum may be added to mature fine tailings to consolidate the fines together with the coarse sand into a non- segregating mixture. This method is referred to as the consolidated (composite) tailing (CT) process.
  • CT is disposed of in a geotechnical manner that enhances its further dewatering and eventual reclamation.
  • tailings from the extraction plant are cycloned, with the overflow (fine tailings) being pumped to thickeners and the cyclone underflow (coarse tailings) to the tailings pond. Fine tailings are treated with flocculants, then thickened and pumped to a tailings pond. Further, the use of paste technology (addition of
  • flocculants/polyelectrolytes or a combination of CT and paste technology may be used for fast water release and recycle of the water in CT to the extraction plant for bitumen recovery from oil sands.
  • the recovered bitumen is upgraded. Upgrading either adds hydrogen or removes carbon in order to achieve a balanced, lighter hydrocarbon that is more valuable and easier to refine.
  • the upgrading process also removes contaminants such as heavy metals, salts, oxygen, nitrogen and sulfur.
  • the upgrading process includes one or more steps such as: distillation wherein various compounds are separated by physical properties, coking, hydro-conversion, solvent deasphalting to improve the hydrogen to carbon ratio, and hydrotreating which removes contaminants such as sulfur.
  • the improvement to the process of recovering bitumen from oil sands is contacting the oil sands containing the bitumen with a composition comprising, consisting essentially of, or consisting of (i) an amine, preferably a non-aromatic and/or an aromatic amine and (ii) a glycol ether, preferably an ethylene oxide capped glycol ether (ii)(a) and/or propylene oxide capped glycol ether (ii)(b).
  • Preferred amines (i) of the present invention may be non- aromatic, aromatic, or mixtures thereof and are represented by the following formula:
  • R 1 , R 2 , and R 3 are independently H, or a linear or branched or cyclic alkyl, phenyl, or alkylphenyl group of 1 to 8 carbons, preferably independently H or a linear alkyl groups having 1 to 4 carbons
  • R 1 and R 2 are independently -H, -AL where -AL is an unsubstituted Ci to C20, preferably Ci to C 6 alkyl group, a C 6 to C12 aromatically substituted Ci to C20, preferably Ci to C 6 alkyl group, or combination thereof, wherein -AL may contain one or more of a -COOR 4 where R 4 is -H, alkyl, aryl or alkylaryl, CN, -CHO, - NR 5 R 6 group where R 5 and R 6 are independently -H, alkyl or aryl, -OH group, -CD- group, -S- group, -N- group, -CI, -Br, -F, or R 1 and R 2 may form an unsubstituted or substituted imine, or R 1 and R 2 may form a 5 to 7 atom saturated or unsaturated cyclic moiety wherein there may be one or more carbon atom, oxygen atom, nitrogen atom, or sulfur
  • the amine is dimethylamine, diethylamine, butylamine, dibutylamine, isobutylamine, diisobutylamine, diethylamine, propylamine, dipropylamine, ⁇ propylamine, isopropylamine, diisopropylamine, hexylamine, pentylamine,
  • the aromatic amine is 2,4,6-trimethylaniline, N-benzyl-2- phenethylamine, N-butylbenzylamine, dibenzylamine, 2-aminobiphenyl,
  • aminodiphenylmethane aniline, 2-phenoxyaniline, 9,10-diaminophenanthrene, l-amino-2- methylnaphthalene, N,N-bis(salicylidene)ethylenediamine, N-phenyl-o-phenylenediamine, 2,4,6-tri-tert-butylaniline, N-phenylglycine, 3,5-di-tert-butylaniline, -l,l'-binaphthyl-2,2'- diamine, 4'-aminobenzo-15-crown 5-ether, a-methylbenzylamine, 4-(dimethylamino) phenylacetic acid, N-benzyl-ethylenediamine, N-methylphenethylamine, 1,2- diphenylethylenediamine, tritylamine, N-phenylethylenediamine, pyridine, toluidine, anisidine, methylaniline, diphenylamine,
  • the amine (i) is present in the composition of the present invention in an
  • weight percent preferably equal to or greater than 10 weight percent, preferably equal to or greater than 20 weight percent, preferably equal to or greater than 30 weight percent,
  • the amine (i) is present in the composition of the present invention in an
  • weight percent preferably equal to or less than 80 weight percent, preferably equal to or less than 70 weight percent, preferably equal to or less than 60 weight percent, preferably equal to or less than 50 weight percent based on the combined weights of the amine (i) and the glycol ether (ii).
  • the glycol ether is an ethylene oxide capped glycol ethers (ii)(a) of the present invention are represented by the following formula: RO-(CH 2 CH(CH 3 )0) m (C2H 4 0)n H ⁇ wherein R is a linear, branched, cyclic alkyl, phenyl, or alkyl phenyl group of equal to or greater than 4 carbons, preferably n-butyl, n-pentyl , 2-methyl-l-pentyl, n- hexyl, n-heptyl, n-octyl, 2-ethylhexyl, 2-propylheptyl, phenyl, or cyclohexyl, m is 0 to 3, preferably 1 or 2,
  • n are independently 1 to 3, preferably 1 or 2, preferably m + n is 2.
  • the glycol ether is a propylene oxide capped glycol ethers (ii)(b) of the present invention are represented by the following formulas:
  • RO-( C2H 4 0)o(CH 2 CH(CH3)0)p H HI wherein is a linear, branched, cyclic alkyl, phenyl, or alkyl phenyl group of equal to or greater than 4 carbons, preferably n-butyl, n-pentyl , 2-methyl-l-pentyl, n-hexyl, n-heptyl, n-octyl, 2-ethylhexyl, 2-propylheptyl, phenyl, or cyclohexyl,
  • o is 0 to 3, preferably 1 or 2
  • p is 1 to 3, preferably 1 or 2, preferably m + n is 2.
  • the ethylene oxide cap comprises 1 to 3 ethylene oxide units.
  • Preferred ethylene oxide capped glycol ethers are the ethylene oxide capped n-butyl ether, the ethylene oxide capped n-butyl ethers of propylene glycol, the ethylene oxide capped n-butyl ethers of dipropylene glycol, the ethylene oxide capped n- butyl ethers of tripropylene glycol, the ethylene oxide capped n-pentyl ether, the ethylene oxide capped n-pentyl ethers of propylene glycol, the ethylene oxide
  • capped n-pentyl ethers of dipropylene glycol the ethylene oxide capped n-pentyl ethers of tripropylene glycol, the ethylene oxide capped 2-methyl-l-pentyl ether, the ethylene oxide capped 2-methyl-l-pentyl ethers of propylene glycol, the ethylene oxide capped 2-methyl-l-pentyl ethers of dipropylene glycol, the ethylene oxide capped 2-methyl-l-pentyl ethers of tripropylene glycol, the ethylene oxide capped n-hexyl ether, the ethylene oxide capped n-hexyl ethers of propylene glycol, the ethylene oxide capped n-hexyl ethers of dipropylene glycol, the ethylene oxide capped n-hexyl ethers of tripropylene glycol, the ethylene oxide capped n-heptyl ether, the ethylene oxide capped n-heptyl
  • propylene oxide capped glycol ethers of the present invention means that the propylene oxide cap comprises 1 to 3 propylene oxide units.
  • Preferred propylene oxide capped glycol ethers are the propylene oxide capped n-butyl ether, the propylene oxide capped n-butyl ethers of ethylene glycol, the propylene oxide capped n-butyl ethers of diethylene glycol, the propylene oxide capped n-butyl ethers of triethylene glycol, the propylene oxide capped n-pentyl ether, the propylene oxide capped n-pentyl ethers of ethylene glycol, the propylene oxide capped n-pentyl ethers of diethylene glycol, the propylene oxide capped n- pentyl ethers of triethylene glycol, the propylene oxide capped 2-methyl-l-pentyl ether, the propylene oxide capped 2-methyl-l-pentyl ether
  • glycol ether (ii) is present in the composition of the present invention in an amount equal to or less than 90 weight percent, preferably equal to or less than 80 weight percent, preferably equal to or less than 70 weight percent, preferably equal to or less than 60 weight percent, preferably equal to or less than 50 weight percent based on the combined weights of the amine (i) and glycol ether (ii).
  • glycol ether (ii) is present in the composition of the present invention in an amount equal to or greater than 10 weight percent, preferably equal to or greater than 20 weight percent, preferably equal to or greater than 30 weight percent, preferably equal to or greater than 40 weight percent, preferably equal to or greater than 50 weight percent based on the combined weights of the amine (i) and glycol ether (ii).
  • the amine to glycol ether weight ratio is 50:50.
  • capped glycol ether solution/oil sand slurry is typically agitated from 5 minutes to 4 hours, preferably for an hour or less.
  • the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether solution oil sands slurry is heated to equal to or greater than 35 °C, more preferably equal to or greater than
  • the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether solution oil sands slurry is heated to equal to or less than 100°C, more preferably equal to or less than 80°C, and more preferably equal to or less than 75°C.
  • the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether treated slurry may be transferred to a separation tank, typically comprising a diluted detergent solution, wherein the bitumen and heavy oils are separated from the aqueous portion.
  • the solids and the aqueous portion may be further treated to remove any additional free organic matter.
  • bitumen is recovered from oil sands through well production wherein the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether composition as described herein above can be added to oil sands by means of in situ treatment of the oil sand deposits that are located too deep for strip mining.
  • the two most common methods of in situ production recovery are cyclic steam stimulation (CSS) and steam-assisted gravity drainage (SAGD). CSS can utilize both vertical and horizontal wells that alternately inject steam and pump heated bitumen to the surface, forming a cycle of injection, heating, flow and extraction.
  • SAGD utilizes pairs of horizontal wells placed one over the other within the bitumen pay zone.
  • the upper well is used to inject steam, creating a permanent heated chamber within which the heated bitumen flows by gravity to the lower well, which extracts the bitumen.
  • VAPEX vapor recovery extraction
  • CHOPS cold heavy oil production with sand
  • the improvement to the process of recovering bitumen from oil sands is the addition of the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether composition during the slurry preparation stage.
  • the sized material is added to a slurry tank with agitation and combined with the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether composition.
  • the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether composition may be added to the oil sands slurry neat or as an aqueous solution having a concentration of from 0.01 to 10 weight percent ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether based on the total weight of the amine/ethylene oxide capped glycol ether composition solution.
  • the ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether is present in the aqueous oil sands slurry in an amount of from 0.01 to 10 weight percent based on the weight of the oil sands.
  • the basic steps in the in situ treatment to recover bitumen from oil sands includes: steam injection into a well, recovery of bitumen from the well, and dilution of the recovered bitumen, for example with condensate, for shipping by pipelines.
  • the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether composition is used as a steam additive in a bitumen recovery process from a subterranean oil sand reservoir.
  • the mode of steam injection may include one or more of steam drive, steam soak, or cyclic steam injection in a single or multi-well program.
  • Water flooding may be used in addition to one or more of the steam injection methods listed herein above.
  • the steam is injected into an oil sands reservoir through an injection well, and wherein formation fluids, comprising reservoir and injection fluids, are produced either through an adjacent production well or by back flowing into the injection well.
  • the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether composition-steam injection stream is introduced to the reservoir at a temperature in the range of from 150°C to 300°C, preferably 180°C to 260°C.
  • the particular steam temperature and pressure used in the process of the present invention will depend on such specific reservoir characteristics as depth, overburden pressure, pay zone thickness, and bitumen viscosity, and thus will be worked out for each reservoir.
  • the steam temperature can be raised above 260°C during the steam-only injection.
  • steam used herein is meant to include superheated steam, saturated steam, and less than 100 percent quality steam.
  • the term "less than 100 percent quality steam” refers to steam having a liquid water phase present. Steam quality is defined as the weight percent of dry steam contained in a unit weight of a steam-liquid mixture. “Saturated steam” is used synonymously with “100 percent quality steam”. "Superheated steam” is steam which has been heated above the vapor- liquid equilibrium point. If super-heated steam is used, the steam is preferably super-heated to between 5 to 50°C above the vapor-liquid equilibrium temperature, prior to adding the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether composition.
  • the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether composition may be added to the steam neat or as a concentrate. If added as a concentrate, it may be added as a 1 to 99 weight percent solution in water.
  • the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether composition is substantially volatilized and carried into the reservoir as an aerosol or mist.
  • the rationale is to maximize the amount of amine and/or ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether traveling with the steam into the reservoir.
  • the amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether composition is preferably injected intermittently or continuously with the steam, so that the steam- amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether composition injection stream reaches the downhole formation through common tubing.
  • the rate of amine/ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether composition addition is adjusted so as to maintain the preferred ethylene oxide capped glycol ether and/or propylene oxide capped glycol ether
  • the rate of steam injection for a typical oil sands reservoir might be on the order of enough steam to provide an advance through the formation of from 1 to 3 feet/day.
  • An effective SAGD additive must satisfy many requirements to be considered as successful.
  • the major criteria of a successful additive is the ability of the additive to travel with steam and reach unrecovered in-situ bitumen in reservoir formation, favorably interact with water/bitumen/rock to enhance bitumen recovery, and not adversely interfere with existing operations.
  • the requirement of an additive to vaporize at SAGD operating temperatures and travel with steam limits the choice and consideration of different chemistries in SAGD technology. For example, many high molecular weight surfactants even though are known to help enhance oil recovery are not considered as SAGD additives due to their inability to travel with steam owing to high boiling point.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Organic Chemistry (AREA)
  • Wood Science & Technology (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Materials Engineering (AREA)
  • Polyethers (AREA)

Abstract

L'invention concerne un procédé de récupération de bitume à partir de sables bitumineux. Les sables bitumineux peuvent être exploités à ciel ouvert et transportés vers une zone de traitement ou peuvent être traités directement par traitement in situ de dépôts de sables bitumineux situés trop profondément pour une exploitation à ciel ouvert.. De manière spécifique, la présente invention comprend une étape qui consiste à traiter des sables bitumineux avec une composition comprenant une amine et un éther de glycol coiffé d'oxyde d'éthylène et/ou un éther de glycol coiffé d'oxyde de propylène.
PCT/US2017/037908 2016-12-14 2017-06-16 Composition d'amine pour l'extraction à la vapeur de bitume WO2018111342A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201662433915P 2016-12-14 2016-12-14
US62/433,915 2016-12-14

Publications (1)

Publication Number Publication Date
WO2018111342A1 true WO2018111342A1 (fr) 2018-06-21

Family

ID=59285334

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2017/037908 WO2018111342A1 (fr) 2016-12-14 2017-06-16 Composition d'amine pour l'extraction à la vapeur de bitume

Country Status (1)

Country Link
WO (1) WO2018111342A1 (fr)

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2019070926A1 (fr) * 2017-10-06 2019-04-11 Dow Global Technologies Llc Composition d'alcanolamine et de glycoléther pour une extraction améliorée de bitume
WO2020006422A1 (fr) * 2018-06-29 2020-01-02 Dow Global Technologies Llc Additifs pour une extraction améliorée du bitume
US11236595B2 (en) 2018-10-26 2022-02-01 Championx Usa Inc. Additives for steam-injection oil recovery

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20080139418A1 (en) 2000-09-28 2008-06-12 United Energy Corporation Method for extracting heavy oil and bitumen from tar sands
WO2015143034A1 (fr) * 2014-03-21 2015-09-24 Dow Global Technologies Llc Extraction a la vapeur de bitume in situ par etapes
WO2016014394A2 (fr) * 2014-07-23 2016-01-28 Baker Hughes Incorporated Ferrofluides absorbés sur du graphène/oxyde de graphène pour rap

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20080139418A1 (en) 2000-09-28 2008-06-12 United Energy Corporation Method for extracting heavy oil and bitumen from tar sands
WO2015143034A1 (fr) * 2014-03-21 2015-09-24 Dow Global Technologies Llc Extraction a la vapeur de bitume in situ par etapes
WO2016014394A2 (fr) * 2014-07-23 2016-01-28 Baker Hughes Incorporated Ferrofluides absorbés sur du graphène/oxyde de graphène pour rap

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
J. MASLIYAH ET AL.: "Understanding Water-Based Bitumen Extraction from Athabasca Oil Sands", CANADIAN JOURNAL OF CHEMICAL ENGINEERING, vol. 82, August 2004 (2004-08-01), XP055107660, DOI: doi:10.1002/cjce.5450820403

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2019070926A1 (fr) * 2017-10-06 2019-04-11 Dow Global Technologies Llc Composition d'alcanolamine et de glycoléther pour une extraction améliorée de bitume
US11001747B2 (en) 2017-10-06 2021-05-11 Dow Global Technologies Llc Alkanolamine and glycol ether composition for enhanced extraction of bitumen
EA039889B1 (ru) * 2017-10-06 2022-03-23 Дау Глоубл Текнолоджиз Ллк Композиция, содержащая алканоламин и простой эфир гликоля, предназначенная для улучшенного извлечения битума
WO2020006422A1 (fr) * 2018-06-29 2020-01-02 Dow Global Technologies Llc Additifs pour une extraction améliorée du bitume
CN112368356A (zh) * 2018-06-29 2021-02-12 陶氏环球技术有限责任公司 增强沥青提取的添加剂
US11834607B2 (en) 2018-06-29 2023-12-05 Dow Global Technologies Llc Additives for enhanced extraction of bitumen
US11236595B2 (en) 2018-10-26 2022-02-01 Championx Usa Inc. Additives for steam-injection oil recovery

Similar Documents

Publication Publication Date Title
US10138719B2 (en) Method of extracting bitumen from oil sands with a propylene oxide capped glycol
US10941347B2 (en) Composition for steam extraction of bitumen
US10633593B2 (en) Enhanced steam extraction of bitumen from oil sands
AU2013363442B2 (en) Improved method to extract bitumen from oil sands
WO2018111342A1 (fr) Composition d'amine pour l'extraction à la vapeur de bitume
US11001747B2 (en) Alkanolamine and glycol ether composition for enhanced extraction of bitumen
WO2018017221A1 (fr) Procédé pour extraire du bitume à partir de sables bitumineux au moyen d'amines aromatiques
US20210261852A1 (en) Enhanced steam extraction of bitumen from oil sands
US11834607B2 (en) Additives for enhanced extraction of bitumen

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 17735692

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 17735692

Country of ref document: EP

Kind code of ref document: A1