US20080269045A1 - Production of lower molecular weight hydrocarbons - Google Patents
Production of lower molecular weight hydrocarbons Download PDFInfo
- Publication number
- US20080269045A1 US20080269045A1 US12/109,812 US10981208A US2008269045A1 US 20080269045 A1 US20080269045 A1 US 20080269045A1 US 10981208 A US10981208 A US 10981208A US 2008269045 A1 US2008269045 A1 US 2008269045A1
- Authority
- US
- United States
- Prior art keywords
- molecular weight
- composition
- halides
- catalytic composition
- cycloalkane
- 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.)
- Abandoned
Links
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 84
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 80
- 238000004519 manufacturing process Methods 0.000 title claims description 6
- 239000000203 mixture Substances 0.000 claims abstract description 102
- 230000003197 catalytic effect Effects 0.000 claims abstract description 57
- -1 transition metal salt Chemical class 0.000 claims abstract description 35
- GWEVSGVZZGPLCZ-UHFFFAOYSA-N Titan oxide Chemical compound O=[Ti]=O GWEVSGVZZGPLCZ-UHFFFAOYSA-N 0.000 claims abstract description 29
- 239000004408 titanium dioxide Substances 0.000 claims abstract description 14
- 239000011398 Portland cement Substances 0.000 claims abstract description 13
- 229910052723 transition metal Inorganic materials 0.000 claims abstract description 10
- 239000004215 Carbon black (E152) Substances 0.000 claims description 54
- 239000003921 oil Substances 0.000 claims description 49
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 34
- 238000000034 method Methods 0.000 claims description 31
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 25
- 239000011435 rock Substances 0.000 claims description 17
- 150000001924 cycloalkanes Chemical class 0.000 claims description 14
- 239000002245 particle Substances 0.000 claims description 13
- ODINCKMPIJJUCX-UHFFFAOYSA-N calcium oxide Inorganic materials [Ca]=O ODINCKMPIJJUCX-UHFFFAOYSA-N 0.000 claims description 12
- 150000001875 compounds Chemical class 0.000 claims description 12
- 239000000377 silicon dioxide Substances 0.000 claims description 12
- 241000876852 Scorias Species 0.000 claims description 11
- 239000000047 product Substances 0.000 claims description 11
- 239000000292 calcium oxide Substances 0.000 claims description 10
- 239000004568 cement Substances 0.000 claims description 10
- 239000002283 diesel fuel Substances 0.000 claims description 9
- 238000002156 mixing Methods 0.000 claims description 8
- 239000011269 tar Substances 0.000 claims description 8
- 239000010457 zeolite Substances 0.000 claims description 7
- JKWMSGQKBLHBQQ-UHFFFAOYSA-N diboron trioxide Chemical compound O=BOB=O JKWMSGQKBLHBQQ-UHFFFAOYSA-N 0.000 claims description 6
- 229910052810 boron oxide Inorganic materials 0.000 claims description 5
- 239000011026 pyroclastic rock Substances 0.000 claims description 5
- 239000008262 pumice Substances 0.000 claims description 4
- 239000005335 volcanic glass Substances 0.000 claims description 4
- UQSXHKLRYXJYBZ-UHFFFAOYSA-N iron oxide Inorganic materials [Fe]=O UQSXHKLRYXJYBZ-UHFFFAOYSA-N 0.000 claims description 3
- NDLPOXTZKUMGOV-UHFFFAOYSA-N oxo(oxoferriooxy)iron hydrate Chemical compound O.O=[Fe]O[Fe]=O NDLPOXTZKUMGOV-UHFFFAOYSA-N 0.000 claims description 3
- 150000004820 halides Chemical class 0.000 claims 8
- 229910017052 cobalt Inorganic materials 0.000 claims 4
- 239000010941 cobalt Substances 0.000 claims 4
- BPQQTUXANYXVAA-UHFFFAOYSA-N Orthosilicate Chemical compound [O-][Si]([O-])([O-])[O-] BPQQTUXANYXVAA-UHFFFAOYSA-N 0.000 claims 2
- BRPQOXSCLDDYGP-UHFFFAOYSA-N calcium oxide Chemical compound [O-2].[Ca+2] BRPQOXSCLDDYGP-UHFFFAOYSA-N 0.000 claims 2
- 239000007795 chemical reaction product Substances 0.000 claims 2
- TWNQGVIAIRXVLR-UHFFFAOYSA-N oxo(oxoalumanyloxy)alumane Chemical compound O=[Al]O[Al]=O TWNQGVIAIRXVLR-UHFFFAOYSA-N 0.000 claims 2
- 235000012239 silicon dioxide Nutrition 0.000 claims 2
- 238000005336 cracking Methods 0.000 abstract description 11
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 abstract description 7
- 239000001257 hydrogen Substances 0.000 abstract description 7
- 229910052739 hydrogen Inorganic materials 0.000 abstract description 7
- 239000007789 gas Substances 0.000 description 31
- 239000008186 active pharmaceutical agent Substances 0.000 description 25
- 239000000523 sample Substances 0.000 description 21
- 230000005484 gravity Effects 0.000 description 20
- 239000000295 fuel oil Substances 0.000 description 17
- 238000006243 chemical reaction Methods 0.000 description 16
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 16
- 239000003208 petroleum Substances 0.000 description 13
- 230000015572 biosynthetic process Effects 0.000 description 12
- 238000005755 formation reaction Methods 0.000 description 12
- 239000010779 crude oil Substances 0.000 description 11
- 239000000463 material Substances 0.000 description 11
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 10
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 9
- 239000010426 asphalt Substances 0.000 description 9
- 230000008569 process Effects 0.000 description 9
- 239000000758 substrate Substances 0.000 description 9
- 229910021578 Iron(III) chloride Inorganic materials 0.000 description 8
- 229910052681 coesite Inorganic materials 0.000 description 8
- 229910052906 cristobalite Inorganic materials 0.000 description 8
- RBTARNINKXHZNM-UHFFFAOYSA-K iron trichloride Chemical compound Cl[Fe](Cl)Cl RBTARNINKXHZNM-UHFFFAOYSA-K 0.000 description 8
- 239000011347 resin Substances 0.000 description 8
- 229920005989 resin Polymers 0.000 description 8
- 239000002689 soil Substances 0.000 description 8
- 229910052682 stishovite Inorganic materials 0.000 description 8
- 229910052717 sulfur Inorganic materials 0.000 description 8
- 239000011593 sulfur Substances 0.000 description 8
- 229910052905 tridymite Inorganic materials 0.000 description 8
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 7
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 7
- 238000005984 hydrogenation reaction Methods 0.000 description 7
- JEIPFZHSYJVQDO-UHFFFAOYSA-N iron(III) oxide Inorganic materials O=[Fe]O[Fe]=O JEIPFZHSYJVQDO-UHFFFAOYSA-N 0.000 description 7
- 239000007788 liquid Substances 0.000 description 7
- 238000011084 recovery Methods 0.000 description 7
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 6
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 description 6
- 238000004458 analytical method Methods 0.000 description 6
- 230000008859 change Effects 0.000 description 6
- 239000007787 solid Substances 0.000 description 6
- 239000002904 solvent Substances 0.000 description 6
- 125000003118 aryl group Chemical group 0.000 description 5
- 229910002092 carbon dioxide Inorganic materials 0.000 description 5
- 229910052593 corundum Inorganic materials 0.000 description 5
- 239000012535 impurity Substances 0.000 description 5
- 239000002244 precipitate Substances 0.000 description 5
- 239000000126 substance Substances 0.000 description 5
- 229910001845 yogo sapphire Inorganic materials 0.000 description 5
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 4
- 238000002347 injection Methods 0.000 description 4
- 239000007924 injection Substances 0.000 description 4
- 230000009467 reduction Effects 0.000 description 4
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 description 3
- 239000000084 colloidal system Substances 0.000 description 3
- 238000002485 combustion reaction Methods 0.000 description 3
- 238000004821 distillation Methods 0.000 description 3
- 230000008030 elimination Effects 0.000 description 3
- 238000003379 elimination reaction Methods 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 3
- 238000011065 in-situ storage Methods 0.000 description 3
- 229910052500 inorganic mineral Inorganic materials 0.000 description 3
- NMCUIPGRVMDVDB-UHFFFAOYSA-L iron dichloride Chemical compound Cl[Fe]Cl NMCUIPGRVMDVDB-UHFFFAOYSA-L 0.000 description 3
- 238000005259 measurement Methods 0.000 description 3
- 229910044991 metal oxide Inorganic materials 0.000 description 3
- 150000004706 metal oxides Chemical class 0.000 description 3
- 239000011707 mineral Substances 0.000 description 3
- 238000007254 oxidation reaction Methods 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 2
- 229910021577 Iron(II) chloride Inorganic materials 0.000 description 2
- VQTUBCCKSQIDNK-UHFFFAOYSA-N Isobutene Chemical compound CC(C)=C VQTUBCCKSQIDNK-UHFFFAOYSA-N 0.000 description 2
- CPLXHLVBOLITMK-UHFFFAOYSA-N Magnesium oxide Chemical compound [Mg]=O CPLXHLVBOLITMK-UHFFFAOYSA-N 0.000 description 2
- 229910021536 Zeolite Inorganic materials 0.000 description 2
- 150000001335 aliphatic alkanes Chemical class 0.000 description 2
- 239000001273 butane Substances 0.000 description 2
- 229910052799 carbon Inorganic materials 0.000 description 2
- 239000003054 catalyst Substances 0.000 description 2
- 238000006555 catalytic reaction Methods 0.000 description 2
- 239000003795 chemical substances by application Substances 0.000 description 2
- 239000002131 composite material Substances 0.000 description 2
- 239000013068 control sample Substances 0.000 description 2
- ORTQZVOHEJQUHG-UHFFFAOYSA-L copper(II) chloride Chemical compound Cl[Cu]Cl ORTQZVOHEJQUHG-UHFFFAOYSA-L 0.000 description 2
- 230000007423 decrease Effects 0.000 description 2
- 238000006477 desulfuration reaction Methods 0.000 description 2
- 230000023556 desulfurization Effects 0.000 description 2
- HNPSIPDUKPIQMN-UHFFFAOYSA-N dioxosilane;oxo(oxoalumanyloxy)alumane Chemical compound O=[Si]=O.O=[Al]O[Al]=O HNPSIPDUKPIQMN-UHFFFAOYSA-N 0.000 description 2
- 238000004817 gas chromatography Methods 0.000 description 2
- 229910003480 inorganic solid Inorganic materials 0.000 description 2
- 238000011068 loading method Methods 0.000 description 2
- 229910052751 metal Inorganic materials 0.000 description 2
- 239000002184 metal Substances 0.000 description 2
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- 239000010450 olivine Substances 0.000 description 2
- 229910052609 olivine Inorganic materials 0.000 description 2
- 230000003647 oxidation Effects 0.000 description 2
- 239000001294 propane Substances 0.000 description 2
- 238000007670 refining Methods 0.000 description 2
- 239000013049 sediment Substances 0.000 description 2
- 150000004760 silicates Chemical class 0.000 description 2
- 239000010802 sludge Substances 0.000 description 2
- 230000000638 stimulation Effects 0.000 description 2
- 239000008399 tap water Substances 0.000 description 2
- 235000020679 tap water Nutrition 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- 239000002699 waste material Substances 0.000 description 2
- FGRBYDKOBBBPOI-UHFFFAOYSA-N 10,10-dioxo-2-[4-(N-phenylanilino)phenyl]thioxanthen-9-one Chemical compound O=C1c2ccccc2S(=O)(=O)c2ccc(cc12)-c1ccc(cc1)N(c1ccccc1)c1ccccc1 FGRBYDKOBBBPOI-UHFFFAOYSA-N 0.000 description 1
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 1
- 241000237858 Gastropoda Species 0.000 description 1
- 235000019738 Limestone Nutrition 0.000 description 1
- 238000010795 Steam Flooding Methods 0.000 description 1
- 238000010793 Steam injection (oil industry) Methods 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 1
- YKTSYUJCYHOUJP-UHFFFAOYSA-N [O--].[Al+3].[Al+3].[O-][Si]([O-])([O-])[O-] Chemical compound [O--].[Al+3].[Al+3].[O-][Si]([O-])([O-])[O-] YKTSYUJCYHOUJP-UHFFFAOYSA-N 0.000 description 1
- 239000004480 active ingredient Substances 0.000 description 1
- JYIBXUUINYLWLR-UHFFFAOYSA-N aluminum;calcium;potassium;silicon;sodium;trihydrate Chemical compound O.O.O.[Na].[Al].[Si].[K].[Ca] JYIBXUUINYLWLR-UHFFFAOYSA-N 0.000 description 1
- 229910052612 amphibole Inorganic materials 0.000 description 1
- 229910052925 anhydrite Inorganic materials 0.000 description 1
- 150000004945 aromatic hydrocarbons Chemical class 0.000 description 1
- 239000012298 atmosphere Substances 0.000 description 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 230000005587 bubbling Effects 0.000 description 1
- 239000006227 byproduct Substances 0.000 description 1
- 239000000378 calcium silicate Substances 0.000 description 1
- 229910052918 calcium silicate Inorganic materials 0.000 description 1
- OSGAYBCDTDRGGQ-UHFFFAOYSA-L calcium sulfate Chemical compound [Ca+2].[O-]S([O-])(=O)=O OSGAYBCDTDRGGQ-UHFFFAOYSA-L 0.000 description 1
- OYACROKNLOSFPA-UHFFFAOYSA-N calcium;dioxido(oxo)silane Chemical group [Ca+2].[O-][Si]([O-])=O OYACROKNLOSFPA-UHFFFAOYSA-N 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- QGJOPFRUJISHPQ-NJFSPNSNSA-N carbon disulfide-14c Chemical compound S=[14C]=S QGJOPFRUJISHPQ-NJFSPNSNSA-N 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 238000003421 catalytic decomposition reaction Methods 0.000 description 1
- 238000004517 catalytic hydrocracking Methods 0.000 description 1
- 239000003518 caustics Substances 0.000 description 1
- 239000004927 clay Substances 0.000 description 1
- 229910001603 clinoptilolite Inorganic materials 0.000 description 1
- GVPFVAHMJGGAJG-UHFFFAOYSA-L cobalt dichloride Chemical compound [Cl-].[Cl-].[Co+2] GVPFVAHMJGGAJG-UHFFFAOYSA-L 0.000 description 1
- 238000004939 coking Methods 0.000 description 1
- 239000000356 contaminant Substances 0.000 description 1
- 229960003280 cupric chloride Drugs 0.000 description 1
- 238000005202 decontamination Methods 0.000 description 1
- 230000003588 decontaminative effect Effects 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000004880 explosion Methods 0.000 description 1
- 229940032296 ferric chloride Drugs 0.000 description 1
- 229960002089 ferrous chloride Drugs 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000006260 foam Substances 0.000 description 1
- 239000000446 fuel Substances 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 229910001385 heavy metal Inorganic materials 0.000 description 1
- BHEPBYXIRTUNPN-UHFFFAOYSA-N hydridophosphorus(.) (triplet) Chemical compound [PH] BHEPBYXIRTUNPN-UHFFFAOYSA-N 0.000 description 1
- 239000000852 hydrogen donor Substances 0.000 description 1
- 239000011261 inert gas Substances 0.000 description 1
- 229910010272 inorganic material Inorganic materials 0.000 description 1
- 239000011147 inorganic material Substances 0.000 description 1
- 150000002500 ions Chemical class 0.000 description 1
- 150000002576 ketones Chemical class 0.000 description 1
- 239000006028 limestone Substances 0.000 description 1
- 239000003915 liquefied petroleum gas Substances 0.000 description 1
- 239000000395 magnesium oxide Substances 0.000 description 1
- 238000001819 mass spectrum Methods 0.000 description 1
- 239000010445 mica Substances 0.000 description 1
- 229910052618 mica group Inorganic materials 0.000 description 1
- 239000002808 molecular sieve Substances 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 239000005332 obsidian Substances 0.000 description 1
- 150000002894 organic compounds Chemical class 0.000 description 1
- 239000010815 organic waste Substances 0.000 description 1
- 239000007800 oxidant agent Substances 0.000 description 1
- 239000001301 oxygen Substances 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
- 239000012466 permeate Substances 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
- 150000002989 phenols Chemical class 0.000 description 1
- 229910052655 plagioclase feldspar Inorganic materials 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 239000005373 porous glass Substances 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 239000000843 powder Substances 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 229910052611 pyroxene Inorganic materials 0.000 description 1
- 238000005067 remediation Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 238000007086 side reaction Methods 0.000 description 1
- 229910052604 silicate mineral Inorganic materials 0.000 description 1
- URGAHOPLAPQHLN-UHFFFAOYSA-N sodium aluminosilicate Chemical compound [Na+].[Al+3].[O-][Si]([O-])=O.[O-][Si]([O-])=O URGAHOPLAPQHLN-UHFFFAOYSA-N 0.000 description 1
- 239000011343 solid material Substances 0.000 description 1
- 241000894007 species Species 0.000 description 1
- 238000003756 stirring Methods 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- CCEKAJIANROZEO-UHFFFAOYSA-N sulfluramid Chemical group CCNS(=O)(=O)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)F CCEKAJIANROZEO-UHFFFAOYSA-N 0.000 description 1
- 230000000153 supplemental effect Effects 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 239000000725 suspension Substances 0.000 description 1
- TXEYQDLBPFQVAA-UHFFFAOYSA-N tetrafluoromethane Chemical compound FC(F)(F)F TXEYQDLBPFQVAA-UHFFFAOYSA-N 0.000 description 1
- 238000004227 thermal cracking Methods 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G11/00—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
- C10G11/02—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils characterised by the catalyst used
- C10G11/04—Oxides
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
- B01J23/00—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00
- B01J23/002—Mixed oxides other than spinels, e.g. perovskite
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
- B01J27/00—Catalysts comprising the elements or compounds of halogens, sulfur, selenium, tellurium, phosphorus or nitrogen; Catalysts comprising carbon compounds
- B01J27/06—Halogens; Compounds thereof
- B01J27/08—Halides
-
- B01J35/40—
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B09—DISPOSAL OF SOLID WASTE; RECLAMATION OF CONTAMINATED SOIL
- B09C—RECLAMATION OF CONTAMINATED SOIL
- B09C1/00—Reclamation of contaminated soil
- B09C1/08—Reclamation of contaminated soil chemically
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
- C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
- C04B28/04—Portland cements
-
- 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
-
- 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
- C09K8/594—Compositions used in combination with injected gas, e.g. CO2 orcarbonated gas
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
- B01J2523/00—Constitutive chemical elements of heterogeneous catalysts
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B2111/00—Mortars, concrete or artificial stone or mixtures to prepare them, characterised by specific function, property or use
- C04B2111/00474—Uses not provided for elsewhere in C04B2111/00
- C04B2111/0081—Uses not provided for elsewhere in C04B2111/00 as catalysts or catalyst carriers
Abstract
A catalytic composition useful for cracking and reducing the viscosity of heavy hydrocarbons. The catalytic composition comprises Portland cement, a volcanic ash component, titanium dioxide, and a transition metal salt. Optionally, a hydrogen source is added to the catalytic composition.
Description
- This application claims priority from U.S. Provisional Application Ser. No. 60/398,089 filed Jul. 24, 2002, which is incorporated hereby by reference.
- 1. Field of the Invention
- This invention relates to a process for catalytic decomposition (cracking) followed by hydrogenation of high molecular weight hydrocarbons to produce lower molecular weight hydrocarbon products in both surface and subsurface applications at ambient temperatures and pressure with no CO or CO2 emissions.
- This invention further pertains to the separation of inorganic solids, sands, clays, etc., from hydrocarbon compound substrates and mixtures or sludge derived from an originating petroleum source, subsurface or surface, or in the form of petroleum contaminated waste.
- This invention also pertains to the complete or partial desulfurization by reduction of the sulfur-containing species.
- This invention also pertains to the remediation of soils by the removal of hydrocarbon contaminants.
- 2. Description of Related Art/Prior Art
- The generally accepted concept of the origination of oil and gas is that it was generated from the thermal degradation of kerogen, a fossilized material in shale and other sedimentary rock that yields oil upon heating. It is the most common source of carbon in the earth's crust. The major factors affecting the concentration of petroleum are the chemical nature of the kerogen, temperature, time, mineral composition, resident geological structure, etc.
- Traditional technology for cracking and hydrogenation, such as catalytically cracking hydrocarbon, serve to form more valuable lower molecular weight products. Hydrocracking reactions between the initial hydrocarbon substrate and the catalytic agent may be carried out in a series of bed reactors or in a distillation column. Such reactions are endothermic and, as such, the reactors must be heated. Additionally, hydrogen is recycled through the system to ensure maximum hydrocarbon saturation to form the lower molecular weight hydrocarbon products and to remove excess hydrogen generated by the catalytic reaction. In these systems, polyaromatic rings are also opened and the by-products hydrogenated.
- Substantial quantities of petroleum in the earth have proven difficult or impossible to recover because they are in the form of high molecular weight hydrocarbon mixtures which are distributed and intermixed in tar sands, shale, and various rock formations. Furthermore, hydrocarbon compounds cannot be economically extracted from “depleted” oil wells because they are not sufficiently concentrated to be extractable by drilling, have lost their original gas pressure, and/or have relatively high density and viscosity at the given location. The latter compounds will not flow unless heat energy is applied to the petroleum deposit, as, for example, by steam. Additionally, once extracted, these materials still require heat energy to remain as liquids and may be contaminated. Waste or contaminated materials (e.g., soil, rock, sludge, oil tars) containing hydrocarbons, crude or refined, cannot be economically extracted from naturally or man-made contaminated materials.
- There are well known enhanced production techniques to obtain oil from depleted or under-producing wells. In situ combustion is a technique used to heat crude petroleum materials below the surface of the earth to reduce their viscosity. An oxidizing agent, such as air, is injected into the subsurface deposit at sufficiently high temperatures to initiate a combustion process or a phosphorous bomb or gas burner is lowered into the well. The lower molecular weight hydrocarbons generated then rise to the surface of the deposit. There are drawbacks to this procedure in that the high temperatures necessary for combustion, combined with the presence of oxygen, lead to undesirable side reactions of coking and the formation of phenols and ketones, which are difficult to process through other refining techniques.
- Thermal recovery techniques from under-producing, depleted, and heavy oil wells and bitumen deposits may also comprise steam injection. The purpose of the injected steam is to heat the heavy hydrocarbon deposit, thereby significantly reducing the viscosity and making an economically acceptable level of recovery of the hydrocarbon deposit. In situ hydrovisbreaking and steam flooding are alternatives to the combustive techniques. Sometimes, in this process, a catalyst is suspended in the steam and circulated throughout a subsurface deposit. This heat permits the endothermic reaction to occur, causing lower molecular weight hydrocarbons rise to the surface of the petroleum deposit. This process may only be used in formations that have sufficient overburden thicknesses to withstand the injection of high temperature, high pressure materials.
- Waterflooding techniques are also a frequently employed method to improve oil recovery from depleted or nearly depleted oil wells and can be expected to yield between 5% and 50% of the remaining petroleum products. The water to be injected must first be filtered to eliminate all potentially reactive particles. Then it is pumped into the well under pressure either from a group of strategically placed injection wells or from injection wells at the edge of the oilfield. Water rarely circulates evenly through the underground deposits. In most cases, the water permeates the deposits until it causes a breakthrough, creating a path of least resistance to the producing well along which the water will flow. The oil has a lower specific gravity than water and floats on top of the water. Such waterfloods are most effective in areas where there is little primary production. Variants of this technique include alkaline or caustic flooding, which involve the addition of basic agents to the water, such as sodium hydroxide.
- Miscible gas drive for enhanced oil recovery involves injecting an inert gas, such as carbon dioxide, nitrogen, or liquefied petroleum gas into the reservoir. The gas mixes with the petroleum deposits, making the oil less viscous, and pressures the fluid oil towards the producing well. Sometimes alternating between pumping gas and water through the well is employed. Solvent or chemical flooding comprises injecting a liquid with different chemicals in batches (slugs) into a deposit. A micellar-polymer flood will contain a polymeric surfactant to wash reservoir pore spaces clean of the heavy oils present within the earth formation. Other solvents can be used to mix with and reduce the viscosity of the petroleum deposits. Frequently used solvents include aromatic hydrocarbons, carbon disulfide, and carbon tetrafluoride, which are all capable of dissolving bituminous petroleum deposits. Water-based solvents have been used, with both heated and unheated water, to carry active ingredients throughout subsurface formations. Solvents or chemicals are frequently pumped through pipelines along with the treated oil. These must be separated out, e.g., by distillation to preserve both expensive solvents and the treated oil. Elimination of this refining step would reduce complications and cost.
- It can be relatively difficult and economically unfeasible to separate hydrocarbon compound mixtures from some of the inorganic solid materials that are naturally intermixed.
- This invention relates to compositions and methods for cracking and hydrogenating high molecular weight hydrocarbons to produce lower molecular weight hydrocarbons from substrates containing relatively higher molecular weight hydrocarbons. Hydrogenation is facilitated by the presence of water and, optionally, by the addition of refined and unrefined alkane and cycloalkane hydrocarbons (C5-C25). The treatment with the inventive composition results in the lower molecular weight characteristics, as can be shown by both increased API value (generally the API value is more than doubled) and lower viscosity. These substrates may be treated on the earth's surface or in subsurface deposits at ambient temperatures and pressures.
- The catalytic composition of the present invention is a reactive inorganic composition capable of homogeneous cracking and hydrogenation of high molecular weight hydrocarbon compounds in the presence of water at ambient temperature and pressure. The catalytic composition is an admixture of organic compounds in water.
- The exact proportions of said catalytic composition are varied depending on the high molecular weight hydrocarbon to be treated and the desired lower molecular weight hydrocarbon products. The essential particulate components of the catalytic composition are SiO2, Al2O3, Fe2O3, and CaO. Typical ranges are shown in Table 1 below. All weight percents are based on the total weight of these components combined in a particulate blend.
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TABLE 1 Particulate Broad Range Preferred Component (wt. %) Range (wt. %) SiO2 20-60 5-35 Al2O3 1-10 1.5-5 Fe2O3 0.5-15 1-10 CaO 20-40 25-35 TiO2/B2O3 2-4 2 FeCl3/FeCl2 8-12 8 - To form the catalytic composition, all of the particulate components must initially be ground to about 3000 Blaine or finer. Blaine is a measurement of grain fineness consisting of the ratio of a particle's surface area (in square centimeters) to weight (in grams). Then, these particles are blended with about one to five, preferably two to three times their weight water. An essential first reaction occurs when the solid particles are added to the water. This reaction forms reactive colloidal particles based on the connected surfaces of clays, metal oxides, zeolitic entities, and molecular sieves. The mixture is blended until the particles are completely suspended in the water.
- Alternatively, the catalytic composition may use composite materials to provide the essential components. For example a cement component and a volcanic ash component may provide the SiO2, Al2O3, Fe2O3, and CaO components. Table 2 below illustrates the broad and preferred ranges of these compounds.
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TABLE 2 Particulate Broad Range Preferred Component (wt. %) Range (wt. %) Portland 30-50 45 Cement Volcanic Ash 30-50 45 TiO2 2-4 2 FeCl3/FeCl2 8-12 8 - The cement component is most preferably a Portland cement. Portland cements are mixtures of limestone and clay that have been ground and treated in a kiln from 1400 to 1600° C. About 24% of Portland cement by weight is calcium silicate and about 66% by weight is CaO. Impurities may include up to about 3% by weight of alumina, ferric oxide, and magnesia.
- The volcanic ash component may consist of scoria, pumice, tuff, tuffstone, mafic volcanic rock, ultramafic volcanic rock, pyroclastic rock, volcanic glasses, basalt or silica-based zeolites. Scoria is the most preferred volcanic ash component. The most preferred embodiment contains British Columbia scoria. Scoria is the most common material in volcanic cones and is formed of small particles (about 1 cm across) of hardened volcanic lava. British Columbia scoria consists of about 46% SiO2, about 18% Fe2O3, about 8% CaO, and about 2.4% TiO2. Scoria from southern Mexico consists of about 79% SiO2 and about 6.6% F2O3. Pumice is a light pyroclastic rock that is hardened from a lava foam into a porous glass. Tuffstone is created from pieces of volcanic ash welded together by lithification upon eruption. Tuff consists of non-welded pieces of volcanic ash. Mafic rock is defined as igneous rock which contains substantial quantities of silicates, such as pyroxene, amphibole, olivine, and mica. Ultramafic rock a volcanic rock with an ultrabasic composition and over 90% composed of Fe—Mg minerals, predominantly olivine, orthopyroxene, and clinopyroxene. Pyroclastic rock is rock which is formed by either a volcanic explosion or an aerial expulsion from a volcanic vent. Volcanic glasses are called obsidian and consist of silica particles fused by the intense heat of a volcano. Basalt is a mafic, igneous rock composed of plagioclase. Different varieties of basalt differ in their degree of silica saturation. Zeolites are a family of aluminum silicate minerals that may occur naturally or be produced synthetically. Zeolites from British Columbia typically consist of about 89% SiO2, 0.8% Fe2O3, and about 1% CaO.
- Any transition metal salt with a +2 or +3 oxidation state will function in the catalytic composition. Preferred compounds include ferric chloride, ferrous chloride, cupric chloride, and cobalt chloride. Ferric chloride is the most preferred.
- Not including the specific metal oxides listed above, the most preferred metal oxide is titanium dioxide (TiO2). In the most preferred embodiment, titanium dioxide accounts for about 2% by weight of the total weight of the catalytic composition. Boron oxide (B2O3) can also be substituted and used in place of and in concert with TiO2.
- The components other than Portland cement are varied depending on the specific high molecular weight substrate being treated. Such customization can be readily carried out by testing small samples of the substrate with different catalytic compositions to determine the most effective components and relative component ratios. Particular examples are set forth below. Solid components may account for 2-10% by weight of the catalytic composition, and preferably comprise 5-10% by weight.
- Though specific materials are recited herein by their common names, it will be understood that other composites formed of various minerals and compounds may also be used.
- Optionally, refined and unrefined alkanes and cycloalkanes, such as naphtha or diesel fuel, of the C5 to C25 range are frequently employed to facilitate and intensify the hydrogenation process. This refined or unrefined hydrocarbon component is incorporated to serve as a hydrogen donor. The included water will also function as a hydrogen source. Typically, diesel fuel or naphtha is mixed with the high molecular weight hydrocarbon substrate prior to the addition of the aqueous colloid suspension. The refined or unrefined hydrocarbon component may consist of any C5 to C25 alkane or cycloalkane or mixture thereof and may range from 0 to 50% by weight of the total catalytic composition added. Naphtha or condensate is the most preferred refined hydrocarbon.
- Catalytic composition to crude oil loading may vary from a ratio of 2:1 to 4:1. The preferable loading ratio is 3:1.
- After vigorously admixing the catalytic composition in water with the high molecular weight hydrocarbon compounds and, optionally, with a refined hydrocarbon at ambient temperatures and pressures, a rapid, almost instantaneous, reaction of cracking and hydrogenation occurs to produce a product composed of lower molecular weight hydrocarbons. The lower molecular weight hydrocarbons float on top of the water-based colloid in a separate layer. Sulfur-based and metallic impurities form solid, inert precipitates upon reaction with the catalytic composition after mixing. The process proceeds to completion very rapidly, often within minutes from the time of complete addition of the catalytic composition with no CO2 or CO emissions.
- The terms high molecular weight hydrocarbon and low molecular weight hydrocarbon as used herein are relative terms to one another. The term high molecular weight hydrocarbon signifies a mixture of hydrocarbons and their entrained impurities with an average molecular weight of the hydrocarbons higher than the average molecular weight of the hydrocarbons in a low molecular weight hydrocarbon. Thus, the use of the terms “high molecular weight hydrocarbon” and “low molecular weight hydrocarbon” does not signify any particular molecular weight ranges.
- High molecular weight hydrocarbons are typically materials such as crude oils, asphaltenes, tars, heavy oils, and the like which have limited or no practical use, but which can be converted to more valuable and useful lower molecular weight hydrocarbons via chemical means. Medium oils have resins or polar fractions less than about 25% of the weight of the total oil and have API gravity of 20 to 30 with viscosities in the range of about 100 to 1000 centipoise; heavy oils have resins or polar fractions between about 25 and 40% of the total weight of the oil and have API gravity of 10 to 20 with a viscosities in the range of about 100 to 10000 centipoise; tars have resins or polar fractions greater than about 40% of the total weight of the oil and have API gravity less than about 8 to 10 and a viscosity greater than about 8000 centipoise.
- The lowest molecular weight hydrocarbons may include C1 to C4 gases, e.g., methane, propane, natural gas. The inventive process also results in a reduction of density and viscosity and an increased API gravity value in the treated hydrocarbon mixture.
- In the inventive process, any solid fraction in the starting high molecular weight hydrocarbon (soils, sediments, rock mixtures, sands, etc.) will precipitate to the bottom of the aqueous mixture. A significant percentage of heavy metal ion impurities in the starting high molecular weight hydrocarbon will attach or bind to the solid fraction in the precipitate. The low molecular weight hydrocarbon product will float to the surface of the water allowing for easy retrieval of the products.
- For treatment of a high molecular weight hydrocarbon below the earth's surface, the solids in the inventive catalytic composition are initially slurried with water or with a water/refined hydrocarbon mixture. This mixture is then injected into a reservoir or source rock formation of an oil or gas well. This petroleum-containing geologic formation associated with a given oil and/or gas well may be considered “dead” or under-producing and still be a candidate for the inventive treatment. The catalytic composition will reduce oil density, increase API gravity, and reduce the viscosity of any contacted oil deposits. This will increase the value of the oil per barrel. Typical barrel price of heavy oil, with an API below 16, is about $8 to about $10. With the addition of about $1.50 to $2.00 of chemistry per barrel, the value of the same oil will increase to about $15 to about $18 per barrel.
- In the context of a fracture and/or stimulation project on the given well, the composition may be injected under pressure. The chosen catalytic composition is directed to the reservoir formation associated with the oil or gas producing formation which has been deemed to have the greatest amount of oil and gas. The catalytic composition reacts with the silicates in the geologic formation as well as high molecular weight hydrocarbons present in the region of fracture/stimulation. The chemical reactions between the catalytic composition and the hydrocarbons generate C1 to C4 gases, most notably methane and butane, and these relatively lower viscosity hydrocarbon gases then diffuse into the surrounding hydrocarbon mass. This pervasive in-situ chemical reaction stimulates the formation of desirable lower molecular weight hydrocarbon liquid and gases with the lower density and viscosity.
- Another subsurface application of the present invention can occur at shallow depths in heavy oil producing environments where the method of hydrocarbon recovery uses water flooding and a pressure circulation system through the oil-bearing formation. The catalytic composition can be added to the circulating water to cause cracking and hydrogenation reactions in the heavy oils, thereby reducing the viscosity by the generation of C1 to C4 gases and lower molecular weight hydrocarbons with lower density and viscosity. This causes and increased rate of recovery of desirable hydrocarbons from the treated well. Also, the quality of the recovered oil is improved. The addition of the catalytic composition to steam being injected into the treated hydrocarbons is also possible.
- The present invention will allow the oil to be recovered more rapidly than conventional technology, thereby using less steam, energy, and time for the upgrading and recovery process. The overall petroleum quality in terms of a reduction in viscosity and API value would be improved by the application of these enhanced production technologies. Treated oils with lower viscosities and densities may increase the value and efficiency of heavy oils that need to be transported by pipelines.
- The inventive procedure may be used to upgrade high molecular weight hydrocarbon material or substrates on the earth's surface. For example, it may be used in the treatment or “upgrading” of tar sands or heavy oil. The hydrocarbon is treated in a storage and mixing facility. The catalytic composition is admixed with the substrate of high molecular weight hydrocarbon material. Diesel fuel or condensate or a like refined or unrefined hydrocarbon is added to the admixture as a supplemental hydrogen source for the cracking reactions. Upgrading consists of chemically treating or fractionating bitumen or heavy oils to increase its value by reducing the density and viscosity, thereby generating a higher quality crude oil substitute. The specific objectives of upgrading are to increase the percentage of the saturate and aromatic fractions, reduce the polar and pentane insolvable fractions, reduce viscosity, increase API gravity, and reduce overall hydrocarbon molecular weight. API gravity is a term to relate the relative specific densities of oil products developed by the American Petroleum Institute. To convert between API gravity and specific gravity, the following formula should be followed: API to specific gravity: SG=141.5/(131.5+°API).
- By reducing the density, increasing the API gravity, and reducing the viscosity heavy oil or tar sands bitumen would need no or reduced addition of condensate to allow the oil to be pumped through pipes. For example, there exists a pipeline that moves 778,000 barrels of heavy oil per day from Alberta to U.S. In addition to the oil, 300,000 barrels of condensate are added so it can be pumped. The value of the oil is currently $12 per barrel. If the API gravity were 20 to 23, then there would be no need of condensate. The value of the treated oil would now be $16-$18 per barrel and the operator could then pump 1,000,000 barrels of oil per day. Condensate is in such short supply that the condensate is currently distilled out of the oil in the U.S. and pumped back to Alberta daily.
- For surface applications of the present invention, the inventive reaction may be carried out at ambient temperatures and pressure, i.e., at about room temperature, which is defined as about 20 to 25° C. (about 68 to 77° F.). Ambient pressure is about 1 atmosphere (about 760 Torr).
- Hydrogen sulfide may be generated in large amounts by thermal cracking from kerogen and from liquid sulfur-containing compounds present in crude oils. Sulfur content of crude oil generally decreases with depth, possibly due to cracking and elimination of sulfur as H2S. The total sulfur content in crude oil, heavy oil, bitumens, and tars varies from 0.04% to 8%. Generally, oils with high densities and low API gravities will have higher sulfur contents.
- Some of the hydrogen generated from surface catalytic reactions between the catalytic composition and water and with the refined or unrefined hydrogen source will convert sulfur heteroatoms in the polar (resin) and asphaltene fractions to H2S. Through a series of oxidation reactions, the catalytic composition converts the H2S to CaSO4. Free sulfur, if present, may also react with the hydrocarbons to produce H2S. Sulfate reduction, if present in the sediments, and the related oxidation of hydrocarbons may also occur beyond 150° C., resulting in the generation of H2S and CO2.
- The inventive catalytic compound may be mixed with contaminated soil in a tank containing water and mechanically agitated with the injection of air. The contaminated soil will be remediated through the cracking and hydrogenating the impurities. The treated soil will precipitate to the bottom of the reaction vessel and the organic waste products will float on the surface of the water. The hydrocarbon layer can be decanted off and reused as a secondary fuel. Also, the catalytic compound may be injected and mixed into the soil on the ground, achieving the same end state results.
- The following examples illustrate embodiments of the invention, but are not intended to be limiting:
- Crude oil samples (about 200 to 250 grams each) were taken straight from the well at the Lloydminister oil fields, Lloydminister, Alberta, Canada (API gravity 16 to 18) and Peace River oil fields, Peace River, Alberta, Canada (API gravity 8 to 10). The samples were each placed in two-liter jars and an equal weight of water heated to 100° C. was added to facilitate mixing with the catalytic composition. The samples were allowed to cool to ambient temperature (16° C.) after treatment. The jars had screw-on gas tight lids with rubber diaphragms in place of a hole that had been drilled in the covers to allow withdrawal of headspace gas samples for analysis. The inventive composition, in powder form, was added to each of the samples in amounts of 5 and 10% by weight to weight of oil. The composition contained 48% Portland cement, 42% volcanic glasses-red scoria, 8% ferric chloride and 2% titanium dioxide, all percentages being based on the total weight of the composition.
- The following table shows the weight percent of Portland cement and volcanic ash components in the catalytic composition.
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TABLE 3 Catalytic Composition SiO2 Al2O3 Fe2O3 CaO Portland 8.65% 2.10% 1.30% 27.03% Cement Volcanic Ash 34.65% 3.97% 1.03% 0.12% - The samples were then stirred with a metal rod for 1.5 to 2 minutes and the lids were then screwed on tightly. A separate set of control samples of each crude oil without the added catalytic composition were allowed to stand for four days at ambient temperatures and pressure. Thereafter, the headspace gases were analyzed by gas chromatography for each sample.
- Significant amounts of hydrocarbon gases were found in the headspace gas of the Lloydminister samples, except for the control, in which there was only a water and oil mixture present. Specifically, compared to the control sample, the treated headspace gas contained 41 times more methane, 23 times more ethane, 14 times more propane, 10 times more isobutene, and 71 times more butane. The speed of the reaction is very fast and that for the Peace River samples, hydrocarbon gases were generated very rapidly and lost before the lid could be placed on the jar, or not generated for some reason. The composition of the headspace gases was determined by gas chromatography.
- Additional tests with crude oil from Lloydminister field showed that hydrocarbon gases were rapidly generated and the analysis indicated that 2 to 3% of the total initial carbon was converted to C1 to C4 hydrocarbon gases, with methane being the most prominent in quantity. No hydrocarbon gases were found in the headspace gases of the treated Peace River samples.
- Saturate, aromatic, polar, and pentane insoluble fractions (SAPA) analysis of the treated and untreated heavy oil showed significant changes in the Lloydminister heavy crude oil samples. The 9% and 8% increases in the saturates and aromatic fractions, respectively, and the 19% and 1% decreases in the polar and pentane insoluble fractions, respectively, represent significant improvements in the quality of that heavy oil sample.
- There was a consistent 2% lower distillation temperature across the mass spectrum of the saturates fraction for the untreated Lloydminister heavy oil relative to the saturates fraction of the untreated oil. This means the treated saturates fraction was a relatively lighter molecular weight fraction than the untreated saturates fraction.
- Samples of Syncrude bitumen were prepared to demonstrate the effectiveness of different embodiments of the present invention. Three liquid samples of Syncrude bitumen were blended with 35-50% by weight of naphtha. For two samples, the catalytic composition was prepared by adding the inorganic composition to hot tap water and mixing with a metal stirring rod the resulting colloid into the crude oil sample. The third sample received no addition of the catalytic composition and serves as the control. The catalytic composition called “Mix 1” consisted of 45% by weight Portland cement, 45% by weight volcanic scoria from British Columbia, 2% by weight titanium dioxide, and 8% by weight ferric chloride. “Mix 2” consisted of 45% Portland cement, 45% clinoptilolite zeolite from British Columbia, 2% titanium dioxide, and 8% ferric chloride.
- The following table shows the weight percent of the Portland cement and volcanic ash components in the Mix 1 and Mix 2 catalyst compositions.
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TABLE 4 Catalytic Composition SiO2 Al2O3 Fe2O3 CaO Mix 1 Portland 8.65% 2.10% 1.30% 27.03% Cement Volcanic Ash 20.70% 0% 8.10% 0% Mix 2 Portland 8.65% 2.10% 1.30% 27.03% Cement Zeolite 40.05% 0% 0.36% 0.45% - 100 grams of naphtha were added to 300 grams of hot tap water and 10 grams of the catalytic compositions described above, for those samples receiving the composition.
- The inventive treatment for each oil sample was added and mixed vigorously for about 30 seconds. The reaction was completed almost instantaneously. The liquid in the jar separated into three layers; the treated oil at the top, a water layer in the middle, and a precipitate of inorganic material at the bottom. The gas generation occurred slowly through low bubbling and was even evidenced briefly in the sample without the catalytic composition.
- When the reaction vessels were opened, measurements were conducted to determine the change in the viscosity of each sample and SAPA (Saturate, Aromatic, Polars or resins, and Pentane insolubles or asphaltenes) analyses were performed. Table 5 below uses these characteristics to demonstrate the properties of each sample.
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TABLE 5 Polars Pentane or Insolubles - Viscosity Oil Sample Saturates Aromatics Resins Asphaltenes API (centipoises) Syncrude Bitumen & 12 26.4 40.7 20.9 27.3 91.88 Naphtha - Untreated Syncrude Bitumen, 13.8 23.9 37.4 24.9 91.88 Naphtha, & Mix 1 % Change +15.0% −9.5% −8.1% +19.1% Syncrude Bitumen, 13.1 22.4 41.8 22.7 380.8 Naphtha & Mix 2 % Change +9.2% −15.2% +2.7% +8.6% - After 24 hours, headspace gases generated in each sample were analyzed. The gas analyses of the Mix 1 and Mix 2 samples showed the same compounds and relative concentrations as was found in the untreated control sample. However, the CO2 level was 91% less in the treated samples than it was in the untreated sample. It is possible that the hydrocarbon gases generated by the inventive process were reabsorbed into the treated hydrocarbon mass.
- Samples of heavy oil from the Lloydminister oil fields were prepared to demonstrate the effectiveness of different embodiments of the present invention. This sample had an initially high polar fraction, 38.7%. Polar fractions have a dramatic effect on the viscosity and density of an oil sample. Two 200-gram liquid samples of oil bitumen with an initial API gravity of 9.9 were tested. The process for addition and composition of the catalytic composition used in this example is the same as that described in mix 1 of example 2 above. The specific catalytic composition consisted of 45% by weight Portland cement, 45% by weight volcanic scoria from British Columbia, 2% by weight titanium dioxide, and 8% by weight ferric chloride. Diesel fuel and the catalytic composition were added to Sample 1. After 1 hour, the API gravity of Sample 1 had reached 22.1 and, after 24 hours, was 27.3. Sample 2 had no diesel fuel added, and reached an API gravity of 14.9 one hour after the addition of the catalytic composition, and an API gravity of 17.5 24 hours later.
- After 24 hours of reacting, the reaction vessels were opened and measurements were conducted to determine the change in the viscosity of each sample and SAPA (Saturate, Aromatic, Polars or resins, and Pentane insolubles or asphaltenes) analyses were performed. Table 6 below uses these characteristics to demonstrate the properties of each sample.
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TABLE 6 Polars Pentane Oil or Insolubles - Sample Saturates Aromatics Resins Asphaltenes API Untreated 17 25 22.0 19 9.9 Oil Sample 1 21 25 22.0 14 27.3 % Change +24% 0 0 −26% 176% Sample 2 20 26 18 17 17.5 % Change +18% +4% −18% −11% 77%
Claims (25)
1.-51. (canceled)
52. A catalytic composition for upgrading high molecular weight hydrocarbons comprising an admixture of water and the reaction products of particles of the following components: silicon dioxide, aluminum oxide, ferric oxide, calcium oxide, titanium dioxide or boron oxide, and a transition metal salt, wherein the particles have a Blaine surface area to weight ratio of at least 3000 cm2/gm.
53. A composition for the upgrading of a high molecular weight hydrocarbon composition to form a lower molecular weight hydrocarbon product, comprising the catalytic composition of claim 52 and a C5 to C25 alkane or cycloalkane.
54. The composition of claim 52 , wherein the C5 to C25 alkane or cycloalkane is diesel fuel or naphtha.
55. The catalytic composition of claim 52 , wherein the transition metal salt is one or more of the compounds selected from ferric halides, cupric halides, cobalt halides, and ferrous halides.
56. An admixture of a high molecular weight hydrocarbon and the catalytic composition of claim 52 wherein the weight ratio of the high molecular weight hydrocarbon to the catalytic composition is from 2:1 to 4:1.
57. The admixture of claim 56 wherein the high molecular weight hydrocarbon composition is one or more components selected from bitumens, asphaltenes, oils, and tars.
58. A catalytic composition comprising an admixture of water and the reaction products of particles of a cement component, a volcanic ash component, a transition metal salt, and titanium dioxide or boron oxide, wherein the particles have a Blaine surface area to weight ratio of at least 3000 cm2/gm.
59. A composition for the upgrading of a high molecular weight hydrocarbon composition to form a lower molecular weight hydrocarbon product, comprising the catalytic composition of claim 58 and a C5 to C25 alkane or cycloalkane.
60. The composition of claim 59 , wherein the C5 to C25 alkane or cycloalkane is diesel fuel or naphtha.
61. The catalytic composition of claim 58 , wherein the cement component is Portland cement.
62. The catalytic composition of claim 58 , wherein the volcanic ash component is one or more components selected from scoria, basalt, pyroclastic rock, tuff, tuffstone, volcanic glass, pumice, mafic rock, ultramafic rock, and silicate-based zeolites.
63. The catalytic composition of claim 58 , wherein the transition metal salt is one or more of the compounds selected from ferric halides, cupric halides, cobalt halides, and ferrous halides.
64. A method of making a catalytic composition for the upgrading of a high molecular weight hydrocarbon composition which comprises:
(a) admixing particles having a Blaine surface area to weight ratio of at least 3000 cm2/gm of silicon dioxide, aluminum oxide, ferric oxide, calcium oxide, titanium dioxide or boron oxide, and a transition metal salt; and
(b) blending the admixture with water.
65. The method of claim 64 , wherein the transition metal salt is one or more of the compounds selected from ferric halides, cupric halides, cobalt halides, and ferrous halides.
66. The method of claim 64 , further including blending the admixture with a C5 to C25 alkane or cycloalkane.
67. The method of claim 66 , wherein the admixture is blended with up to 50 weight percent C5 to C25 alkane or cycloalkane, based on the total weight of the admixture and the C5 to C25 alkane or cycloalkane.
68. The method of claim 66 , wherein the C5 to C25 alkane or cycloalkane is diesel fuel or naphtha.
69. A method of making a catalytic composition for the upgrading of a high molecular weight hydrocarbon composition which comprises:
(a) admixing particles having a Blaine surface area to weight ratio of at least 3000 cm2/gm of a cement component, a volcanic ash component, a transition metal salt, and titanium dioxide or boron oxide; and
(b) blending the admixture with water.
70. The method of claim 69 , wherein the cement component is Portland cement.
71. The method of claim 69 , wherein the volcanic ash component is one or more components selected from scoria, basalt, pyroclastic rock, tuff, tuffstone, volcanic glass, pumice, mafic rock, ultramafic rock, and silicate-based zeolites.
72. The method of claim 69 , wherein the transition metal salt is one or more of the compounds selected from ferric halides, cupric halides, cobalt halides, and ferrous halides.
73. The method of claim 69 , further including blending the admixture with a C5 to C25 alkane or cycloalkane.
74. The method of claim 73 , wherein the C5 to C25 alkane or cycloalkane is diesel fuel or naphtha.
75. The method of claim 69 , wherein the admixture is blended with up to 50 weight percent C5 to C25 alkane or cycloalkane, based on the total weight of the admixture and the C5 to C25 alkane or cycloalkane.
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US10/627,240 Expired - Fee Related US7371316B2 (en) | 2002-07-24 | 2003-07-24 | Production of lower molecular weight hydrocarbons |
Country Status (13)
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US (2) | US7371316B2 (en) |
EP (1) | EP1597213A1 (en) |
JP (1) | JP2006501981A (en) |
CN (1) | CN1684920A (en) |
AU (1) | AU2003263820B2 (en) |
BR (1) | BR0313036A (en) |
CA (1) | CA2493260A1 (en) |
CR (1) | CR7702A (en) |
EA (1) | EA009351B1 (en) |
MX (1) | MXPA05000949A (en) |
NO (1) | NO20050978L (en) |
WO (1) | WO2004009510A1 (en) |
ZA (1) | ZA200501625B (en) |
Families Citing this family (13)
Publication number | Priority date | Publication date | Assignee | Title |
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US7980312B1 (en) * | 2005-06-20 | 2011-07-19 | Hill Gilman A | Integrated in situ retorting and refining of oil shale |
US20070056726A1 (en) * | 2005-09-14 | 2007-03-15 | Shurtleff James K | Apparatus, system, and method for in-situ extraction of oil from oil shale |
US7845414B2 (en) * | 2006-01-06 | 2010-12-07 | Petroleum Habitats, L.L.C. | In situ conversion of heavy hydrocarbons to catalytic gas |
EA014709B1 (en) * | 2006-05-16 | 2011-02-28 | Шелл Интернэшнл Рисерч Маатсхаппий Б.В. | A process for the manufacture of carbon disulphide |
US20090155159A1 (en) * | 2006-05-16 | 2009-06-18 | Carolus Matthias Anna Maria Mesters | Process for the manufacture of carbon disulphide |
BRPI0713299A2 (en) * | 2006-07-07 | 2012-04-17 | Shell Int Research | process for the manufacture of carbon disulfide, and, use of a liquid chain |
US8205674B2 (en) | 2006-07-25 | 2012-06-26 | Mountain West Energy Inc. | Apparatus, system, and method for in-situ extraction of hydrocarbons |
EP2125995B1 (en) * | 2006-09-18 | 2017-07-05 | Jeffrey P. Newton | Production of lower molecular weight hydrocarbons |
US20080257552A1 (en) * | 2007-04-17 | 2008-10-23 | Shurtleff J Kevin | Apparatus, system, and method for in-situ extraction of hydrocarbons |
US20110224451A1 (en) * | 2008-06-11 | 2011-09-15 | Rajiv Kumar Chaturvedi | Process for production of biodiesel |
US20100132942A1 (en) * | 2008-10-23 | 2010-06-03 | Synoil Fluids Holdings Inc. | Hydrocarbon reservoir treatment method with hydrocarbons |
JP5943906B2 (en) * | 2011-03-31 | 2016-07-05 | Jxエネルギー株式会社 | Method and apparatus for producing light hydrocarbon oil |
RU2722697C1 (en) * | 2019-11-27 | 2020-06-03 | Федеральный исследовательский центр "Пущинский научный центр биологических исследований Российской академии наук" (ФИЦ ПНЦБИ РАН) | Agent for reducing arsenic mobility in soil |
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2003
- 2003-07-24 AU AU2003263820A patent/AU2003263820B2/en not_active Ceased
- 2003-07-24 EA EA200500254A patent/EA009351B1/en not_active IP Right Cessation
- 2003-07-24 CN CN03822705.3A patent/CN1684920A/en active Pending
- 2003-07-24 BR BR0313036-3A patent/BR0313036A/en not_active Application Discontinuation
- 2003-07-24 US US10/627,240 patent/US7371316B2/en not_active Expired - Fee Related
- 2003-07-24 CA CA002493260A patent/CA2493260A1/en not_active Abandoned
- 2003-07-24 MX MXPA05000949A patent/MXPA05000949A/en active IP Right Grant
- 2003-07-24 JP JP2004523410A patent/JP2006501981A/en active Pending
- 2003-07-24 WO PCT/US2003/023501 patent/WO2004009510A1/en active Application Filing
- 2003-07-24 EP EP03766035A patent/EP1597213A1/en not_active Withdrawn
-
2005
- 2005-02-23 CR CR7702A patent/CR7702A/en not_active Application Discontinuation
- 2005-02-23 NO NO20050978A patent/NO20050978L/en not_active Application Discontinuation
- 2005-02-24 ZA ZA200501625A patent/ZA200501625B/en unknown
-
2008
- 2008-04-25 US US12/109,812 patent/US20080269045A1/en not_active Abandoned
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US3403108A (en) * | 1964-06-24 | 1968-09-24 | Pullman Inc | Aluminosilicate catalyst containing a group viii metal compound and a metal halide |
US3644557A (en) * | 1968-05-30 | 1972-02-22 | Azote & Prod Chim | Catalyst compositions for preparing ethylene |
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US4300324A (en) * | 1976-11-30 | 1981-11-17 | Produits Chimiques Ugine Kuhlmann | Anhydrite cellular concrete composite building elements and their method of manufacture |
US4469588A (en) * | 1981-03-30 | 1984-09-04 | Ashland Oil, Inc. | Immobilization of vanadia deposited on sorbent materials during visbreaking treatment of carbo-metallic oils |
US4450241A (en) * | 1981-08-05 | 1984-05-22 | Ashland Oil, Inc. | Endothermic removal of coke deposited on catalytic materials during carbo-metallic oil conversion |
US4940531A (en) * | 1982-04-12 | 1990-07-10 | W. R. Grace & Co.-Conn. | Catalytic cracking process employing an acid-reacted metakaolin catalyst |
US4427539A (en) * | 1982-09-07 | 1984-01-24 | Ashland Oil, Inc. | Demetallizing and decarbonizing heavy residual oil feeds |
US4746419A (en) * | 1985-12-20 | 1988-05-24 | Amoco Corporation | Process for the hydrodemetallation hydrodesulfuration and hydrocracking of a hydrocarbon feedstock |
US4946581A (en) * | 1987-01-13 | 1990-08-07 | Akzo N.V. | Cracking process employing a catalyst composition and absorbent which contain an anionic clay |
US5238896A (en) * | 1992-09-04 | 1993-08-24 | Phillips Petroleum Company | Isomerization process and catalyst therefor |
US6225255B1 (en) * | 1997-06-06 | 2001-05-01 | Exxon Research And Engineering Company | Additive catalyst for the cracking of heavy oil |
US6511933B1 (en) * | 1997-06-13 | 2003-01-28 | Tonen Corporation | Catalyst for cracking heavy oil |
US5958370A (en) * | 1997-12-11 | 1999-09-28 | Chevron U.S.A. Inc. | Zeolite SSZ-39 |
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Also Published As
Publication number | Publication date |
---|---|
AU2003263820B2 (en) | 2009-08-06 |
EA200500254A1 (en) | 2005-08-25 |
NO20050978L (en) | 2005-04-18 |
WO2004009510A1 (en) | 2004-01-29 |
MXPA05000949A (en) | 2005-09-12 |
CN1684920A (en) | 2005-10-19 |
AU2003263820A1 (en) | 2004-02-09 |
BR0313036A (en) | 2005-07-12 |
CR7702A (en) | 2008-04-10 |
EA009351B1 (en) | 2007-12-28 |
US7371316B2 (en) | 2008-05-13 |
US20040016676A1 (en) | 2004-01-29 |
CA2493260A1 (en) | 2004-01-29 |
EP1597213A1 (en) | 2005-11-23 |
JP2006501981A (en) | 2006-01-19 |
ZA200501625B (en) | 2005-09-05 |
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