US20110094750A1 - Systems and methods for producing oil and/or gas - Google Patents
Systems and methods for producing oil and/or gas Download PDFInfo
- Publication number
- US20110094750A1 US20110094750A1 US12/937,966 US93796609A US2011094750A1 US 20110094750 A1 US20110094750 A1 US 20110094750A1 US 93796609 A US93796609 A US 93796609A US 2011094750 A1 US2011094750 A1 US 2011094750A1
- Authority
- US
- United States
- Prior art keywords
- formation
- gas
- oil
- well
- formulation
- 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
- 238000000034 method Methods 0.000 title claims description 86
- QGJOPFRUJISHPQ-UHFFFAOYSA-N Carbon disulfide Chemical compound S=C=S QGJOPFRUJISHPQ-UHFFFAOYSA-N 0.000 claims abstract description 377
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 177
- 239000000203 mixture Substances 0.000 claims abstract description 169
- 238000009472 formulation Methods 0.000 claims abstract description 134
- JJWKPURADFRFRB-UHFFFAOYSA-N carbonyl sulfide Chemical compound O=C=S JJWKPURADFRFRB-UHFFFAOYSA-N 0.000 claims abstract description 102
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 52
- 230000007246 mechanism Effects 0.000 claims abstract description 36
- 239000007789 gas Substances 0.000 claims description 128
- 150000001875 compounds Chemical class 0.000 claims description 53
- 238000004519 manufacturing process Methods 0.000 claims description 52
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims description 37
- 229910000037 hydrogen sulfide Inorganic materials 0.000 claims description 35
- 238000011084 recovery Methods 0.000 claims description 24
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 20
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims description 18
- 239000001301 oxygen Substances 0.000 claims description 18
- 229910052760 oxygen Inorganic materials 0.000 claims description 18
- 239000003570 air Substances 0.000 claims description 10
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- 239000000126 substance Substances 0.000 claims description 8
- 239000000446 fuel Substances 0.000 claims description 7
- 229920000642 polymer Polymers 0.000 claims description 7
- 238000010438 heat treatment Methods 0.000 claims description 6
- -1 steam Substances 0.000 claims description 6
- 150000001412 amines Chemical class 0.000 claims description 4
- 229910052757 nitrogen Inorganic materials 0.000 claims description 4
- 239000003502 gasoline Substances 0.000 claims description 3
- 239000000314 lubricant Substances 0.000 claims description 3
- 239000000463 material Substances 0.000 claims description 3
- 238000005755 formation reaction Methods 0.000 description 154
- 239000003921 oil Substances 0.000 description 107
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 70
- 239000011593 sulfur Substances 0.000 description 67
- 229910052717 sulfur Inorganic materials 0.000 description 60
- 239000007788 liquid Substances 0.000 description 41
- RAHZWNYVWXNFOC-UHFFFAOYSA-N Sulphur dioxide Chemical class O=S=O RAHZWNYVWXNFOC-UHFFFAOYSA-N 0.000 description 34
- 238000006243 chemical reaction Methods 0.000 description 27
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 22
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- 230000008569 process Effects 0.000 description 20
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- 229930195733 hydrocarbon Natural products 0.000 description 16
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- 239000003054 catalyst Substances 0.000 description 15
- 238000003860 storage Methods 0.000 description 15
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- 229910002092 carbon dioxide Inorganic materials 0.000 description 11
- 229910052799 carbon Inorganic materials 0.000 description 10
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- 239000003345 natural gas Substances 0.000 description 10
- 238000007254 oxidation reaction Methods 0.000 description 10
- 239000001569 carbon dioxide Substances 0.000 description 9
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 8
- 239000002904 solvent Substances 0.000 description 7
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- 150000001722 carbon compounds Chemical class 0.000 description 6
- TXKMVPPZCYKFAC-UHFFFAOYSA-N disulfur monoxide Inorganic materials O=S=S TXKMVPPZCYKFAC-UHFFFAOYSA-N 0.000 description 6
- 239000012018 catalyst precursor Substances 0.000 description 5
- 238000002347 injection Methods 0.000 description 5
- 239000007924 injection Substances 0.000 description 5
- 239000007787 solid Substances 0.000 description 5
- VYZAMTAEIAYCRO-UHFFFAOYSA-N Chromium Chemical compound [Cr] VYZAMTAEIAYCRO-UHFFFAOYSA-N 0.000 description 4
- ZOKXTWBITQBERF-UHFFFAOYSA-N Molybdenum Chemical compound [Mo] ZOKXTWBITQBERF-UHFFFAOYSA-N 0.000 description 4
- KDLHZDBZIXYQEI-UHFFFAOYSA-N Palladium Chemical compound [Pd] KDLHZDBZIXYQEI-UHFFFAOYSA-N 0.000 description 4
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 4
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 4
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 description 4
- QGJOPFRUJISHPQ-NJFSPNSNSA-N carbon disulfide-14c Chemical compound S=[14C]=S QGJOPFRUJISHPQ-NJFSPNSNSA-N 0.000 description 4
- 229910052804 chromium Inorganic materials 0.000 description 4
- 239000011651 chromium Substances 0.000 description 4
- 229910052742 iron Inorganic materials 0.000 description 4
- 229910052750 molybdenum Inorganic materials 0.000 description 4
- 239000011733 molybdenum Substances 0.000 description 4
- BASFCYQUMIYNBI-UHFFFAOYSA-N platinum Chemical compound [Pt] BASFCYQUMIYNBI-UHFFFAOYSA-N 0.000 description 4
- 150000003839 salts Chemical class 0.000 description 4
- 239000000243 solution Substances 0.000 description 4
- 150000004763 sulfides Chemical class 0.000 description 4
- 229910052720 vanadium Inorganic materials 0.000 description 4
- GPPXJZIENCGNKB-UHFFFAOYSA-N vanadium Chemical compound [V]#[V] GPPXJZIENCGNKB-UHFFFAOYSA-N 0.000 description 4
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- 229910017052 cobalt Inorganic materials 0.000 description 3
- 239000010941 cobalt Substances 0.000 description 3
- GUTLYIVDDKVIGB-UHFFFAOYSA-N cobalt atom Chemical compound [Co] GUTLYIVDDKVIGB-UHFFFAOYSA-N 0.000 description 3
- 239000000295 fuel oil Substances 0.000 description 3
- 150000004820 halides Chemical class 0.000 description 3
- WPBNNNQJVZRUHP-UHFFFAOYSA-L manganese(2+);methyl n-[[2-(methoxycarbonylcarbamothioylamino)phenyl]carbamothioyl]carbamate;n-[2-(sulfidocarbothioylamino)ethyl]carbamodithioate Chemical compound [Mn+2].[S-]C(=S)NCCNC([S-])=S.COC(=O)NC(=S)NC1=CC=CC=C1NC(=S)NC(=O)OC WPBNNNQJVZRUHP-UHFFFAOYSA-L 0.000 description 3
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 3
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- 238000005086 pumping Methods 0.000 description 3
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- RYGMFSIKBFXOCR-UHFFFAOYSA-N Copper Chemical compound [Cu] RYGMFSIKBFXOCR-UHFFFAOYSA-N 0.000 description 2
- KJTLSVCANCCWHF-UHFFFAOYSA-N Ruthenium Chemical compound [Ru] KJTLSVCANCCWHF-UHFFFAOYSA-N 0.000 description 2
- GWEVSGVZZGPLCZ-UHFFFAOYSA-N Titan oxide Chemical compound O=[Ti]=O GWEVSGVZZGPLCZ-UHFFFAOYSA-N 0.000 description 2
- RTAQQCXQSZGOHL-UHFFFAOYSA-N Titanium Chemical compound [Ti] RTAQQCXQSZGOHL-UHFFFAOYSA-N 0.000 description 2
- QCWXUUIWCKQGHC-UHFFFAOYSA-N Zirconium Chemical compound [Zr] QCWXUUIWCKQGHC-UHFFFAOYSA-N 0.000 description 2
- 229910052802 copper Inorganic materials 0.000 description 2
- 239000010949 copper Substances 0.000 description 2
- 229910052741 iridium Inorganic materials 0.000 description 2
- GKOZUEZYRPOHIO-UHFFFAOYSA-N iridium atom Chemical compound [Ir] GKOZUEZYRPOHIO-UHFFFAOYSA-N 0.000 description 2
- 229910052751 metal Inorganic materials 0.000 description 2
- 239000002184 metal Substances 0.000 description 2
- 230000001473 noxious effect Effects 0.000 description 2
- 229910052762 osmium Inorganic materials 0.000 description 2
- SYQBFIAQOQZEGI-UHFFFAOYSA-N osmium atom Chemical compound [Os] SYQBFIAQOQZEGI-UHFFFAOYSA-N 0.000 description 2
- 230000003647 oxidation Effects 0.000 description 2
- 229910052763 palladium Inorganic materials 0.000 description 2
- 150000002978 peroxides Chemical class 0.000 description 2
- 229910052697 platinum Inorganic materials 0.000 description 2
- 239000002243 precursor Substances 0.000 description 2
- 239000001294 propane Substances 0.000 description 2
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- 238000005067 remediation Methods 0.000 description 2
- 229910052702 rhenium Inorganic materials 0.000 description 2
- WUAPFZMCVAUBPE-UHFFFAOYSA-N rhenium atom Chemical compound [Re] WUAPFZMCVAUBPE-UHFFFAOYSA-N 0.000 description 2
- 229910052703 rhodium Inorganic materials 0.000 description 2
- 239000010948 rhodium Substances 0.000 description 2
- MHOVAHRLVXNVSD-UHFFFAOYSA-N rhodium atom Chemical compound [Rh] MHOVAHRLVXNVSD-UHFFFAOYSA-N 0.000 description 2
- 229910052707 ruthenium Inorganic materials 0.000 description 2
- 239000000741 silica gel Substances 0.000 description 2
- 229910002027 silica gel Inorganic materials 0.000 description 2
- 239000002002 slurry Substances 0.000 description 2
- 239000004094 surface-active agent Substances 0.000 description 2
- 239000000725 suspension Substances 0.000 description 2
- 229910052715 tantalum Inorganic materials 0.000 description 2
- GUVRBAGPIYLISA-UHFFFAOYSA-N tantalum atom Chemical compound [Ta] GUVRBAGPIYLISA-UHFFFAOYSA-N 0.000 description 2
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- 239000010936 titanium Substances 0.000 description 2
- WFKWXMTUELFFGS-UHFFFAOYSA-N tungsten Chemical compound [W] WFKWXMTUELFFGS-UHFFFAOYSA-N 0.000 description 2
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- 239000010937 tungsten Substances 0.000 description 2
- 229910052726 zirconium Inorganic materials 0.000 description 2
- FCEHBMOGCRZNNI-UHFFFAOYSA-N 1-benzothiophene Chemical class C1=CC=C2SC=CC2=C1 FCEHBMOGCRZNNI-UHFFFAOYSA-N 0.000 description 1
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- BWGNESOTFCXPMA-UHFFFAOYSA-N Dihydrogen disulfide Chemical compound SS BWGNESOTFCXPMA-UHFFFAOYSA-N 0.000 description 1
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 1
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- 229910052779 Neodymium Inorganic materials 0.000 description 1
- 229910052777 Praseodymium Inorganic materials 0.000 description 1
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- 229910052772 Samarium Inorganic materials 0.000 description 1
- 235000015076 Shorea robusta Nutrition 0.000 description 1
- 244000166071 Shorea robusta Species 0.000 description 1
- XUIMIQQOPSSXEZ-UHFFFAOYSA-N Silicon Chemical compound [Si] XUIMIQQOPSSXEZ-UHFFFAOYSA-N 0.000 description 1
- BQCADISMDOOEFD-UHFFFAOYSA-N Silver Chemical compound [Ag] BQCADISMDOOEFD-UHFFFAOYSA-N 0.000 description 1
- 238000010795 Steam Flooding Methods 0.000 description 1
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 description 1
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- 230000002411 adverse Effects 0.000 description 1
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- ZMIGMASIKSOYAM-UHFFFAOYSA-N cerium Chemical compound [Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce] ZMIGMASIKSOYAM-UHFFFAOYSA-N 0.000 description 1
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Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
-
- 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
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- C09K8/528—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
- C09K8/532—Sulfur
-
- 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
-
- 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
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/20—Hydrogen sulfide elimination
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/40—Separation associated with re-injection of separated materials
Definitions
- the present disclosure relates to systems and methods for producing oil and/or gas.
- EOR Enhanced Oil Recovery
- thermal thermal
- chemical/polymer chemical/polymer
- gas injection gas injection
- Thermal enhanced recovery works by adding heat to the reservoir.
- the most widely practised form is a steamdrive, which reduces oil viscosity so that it can flow to the producing wells.
- Chemical flooding increases recovery by reducing the capillary forces that trap residual oil.
- Polymer flooding improves the sweep efficiency of injected water.
- Miscible gas injection works in a similar way to chemical flooding. By injecting a fluid that is miscible with the oil, trapped residual oil can be recovered.
- System 100 includes underground formation 102 , underground formation 104 , underground formation 106 , and underground formation 108 .
- Production facility 110 is provided at the surface.
- Well 112 traverses formations 102 and 104 , and terminates in formation 106 .
- the portion of formation 106 is shown at 114 .
- Oil and gas are produced from formation 106 through well 112 , to production facility 110 .
- Gas and liquid are separated from each other, gas is stored in gas storage 116 and liquid is stored in liquid storage 118 .
- Gas in gas storage 116 may contain hydrogen sulfide, which must be processed, transported, disposed of, or stored.
- Co-Pending Patent Application Publication U.S. 2006/0254769 discloses a system including a mechanism for recovering oil and/or gas from an underground formation, the oil and/or gas comprising one or more sulfur compounds; a mechanism for converting at least a portion of the sulfur compounds from the recovered oil and/or gas into a carbon disulfide formulation; and a mechanism for releasing at least a portion of the carbon disulfide formulation into a formation.
- Publication U.S. 2006/0254769 is herein incorporated by reference in its entirety.
- carbon disulfide is a common chemical with applications ranging from use as a commercial solvent for the production of rayon, to a raw material for the production of agricultural insecticides.
- the carbon disulfide manufacturing process involves the purchase and transport of both solid sulfur and natural gas (or another carbon source), often from long distances, to the manufacturing site and produces carbon disulfide at very high purity. These two factors—the high purchase and shipping costs of the raw materials, and the high purity of the final product—result in a relatively high production cost for carbon disulfide.
- the manufacturing process for converting sour gas into solid sulfur involves a solvent unit to first remove hydrogen sulfide, other sulfur compounds, and contaminants such as carbon dioxide from the natural gas stream, followed by a Claus unit to convert the hydrogen sulfide into sulfur, which is then allowed to solidify prior to transport or transported as a liquid.
- the manufacturing process for manufacturing carbon disulfide entails the heating, melting, and vaporization of solid or liquid sulfur and reacting its vapors with heated natural gas or another carbon source.
- the invention provides a system for producing oil and/or gas comprising a formation comprising a mixture of oil and/or gas and a carbon disulfide formulation and/or a carbon oxysulfide formulation; a mechanism for releasing a separating agent into the formation, the separating agent adapted to separate the oil and/or gas from the carbon disulfide formulation and/or the carbon oxysulfide formulation.
- the invention provides a method for producing oil and/or gas comprising providing a formation comprising a mixture of oil and/or gas and a carbon disulfide formulation and/or a carbon oxysulfide formulation; releasing a separating agent into a formation; and separating the oil and/or gas from the carbon disulfide formulation and/or the carbon oxysulfide formulation.
- FIG. 1 illustrates an oil and/or gas production system.
- FIG. 2 illustrates an oil and/or gas production process
- FIGS. 3 a - 3 e illustrate oil and/or gas production systems.
- FIG. 4 illustrates a carbon disulfide formulation production process
- Process A for producing oil and/or gas, which includes disposing of a sulfur compound is illustrated.
- Process A includes step 1 where sulfur and/or a sulfur-containing compound is obtained, and optionally released into a formation.
- step 2 at least a portion of the sulfur compound is converted into a carbon disulfide formulation and/or a carbon oxysulfide formulation, optionally within the formation.
- step 3 at the conclusion of an EOR operation, oil and/or gas may be separated from the carbon disulfide formulation and/or the carbon oxysulfide formulation, and the oil recovered from the underground formation, and the carbon disulfide formulation and/or a carbon oxysulfide formulation may be converted into another compound within the formation.
- the obtaining of the sulfur containing compound may be accomplished by any known method. Suitable methods include purchasing gaseous, liquid and/or solid elemental sulfur or sulfur containing compounds; recovering such compounds from an underground formation; and/or recovering such compounds as a stream from surface processes. The selection of the method used to obtain the sulfur containing compound into the underground formation is not critical.
- Such compounds may be injected into a formation with any known method. Suitable methods include vertical and horizontal wells, perforating the formation, injecting liquid and/or vaporized elemental sulfur, or other methods for injecting liquids and gases into a formation as are known in the art. The selection of the method used to release the sulfur containing compound into the underground formation is not critical.
- the sulfur compound may include elemental sulfur, hydrogen sulfide, mercaptans, sulfides and disulfides other than hydrogen disulfide, or heterocyclic sulfur compounds for example thiophenes, benzothiophenes, or substituted and condensed ring dibenzothiophenes, or mixtures thereof.
- Releasing at least a portion of the sulfur containing compound and/or other liquids and/or gases may be accomplished by any known method.
- One suitable method is injecting sulfur containing compound into a single conduit in a single well, allowing sulfur containing compound to soak, and then pumping out at least a portion of the gases and/or liquids.
- Another suitable method is injecting sulfur containing compound into a first conduit in a single well, and pumping out at least a portion of the gases and/or liquids through a second conduit in the single well.
- Another suitable method is injecting sulfur containing compound into a first well, and pumping out at least a portion of the gases and/or liquids through a second well.
- the selection of the method used to inject at least a portion of the sulfur containing compound and/or other liquids and/or gases is not critical.
- the order of injection and conversion may be reversed.
- the sulfur containing compound may be converted into another compound in a surface process, and then the other compound injected into the formation.
- the other compound may be injected by any known method, for example those discussed above or other methods as are known in the art.
- a sulfur containing compound and/or other liquids and/or gases such as a solvent or a liquid or gas miscible with the oil in place, may be left to soak in a formation for a period of time from about 1 hour to about 15 days, for example from about 5 to about 50 hours.
- sulfur containing compound and/or other liquids and/or gases may be pumped into a formation at a pressure above the fracture pressure of the formation.
- sulfur containing compound or sulfur containing compound mixed with other components may be miscible in oil (or other liquids) and/or gases in a formation. In some embodiments, sulfur containing compound or sulfur containing compound mixed with other components may be immiscible in oil and/or gas in formation.
- sulfur containing compound may be heated prior to being injected into the formation to lower the viscosity of fluids in the formation, for example heavy oils, paraffins, asphaltenes, etc.
- sulfur containing compound may be heated and/or boiled while within the formation, with the use of a heated fluid or a heater, to lower the viscosity of fluids in the formation.
- heated water and/or steam may be used to heat and/or vaporize the sulfur containing compound in the formation.
- a nonaqueous fluid could be substituted for steam or hot water as the heat medium to heat sulfur containing compound, for example a heavy aromatic solvent which may have its own solubilizing effect on reservoir hydrocarbons.
- one or more catalysts for example as a slurry or suspension, oxygen or an oxygen containing gas, and one or more hydrocarbons may also be injected into the formation.
- Suitable catalysts, gases, and hydrocarbons which may be used in reactions within the formation are set forth below with regard to Step 2 .
- the conversion of at least a portion of the sulfur compound into a carbon disulfide and/or carbon oxysulfide formulation may be accomplished by any known method. Suitable methods may include an oxidation reaction of the sulfur compound to sulfur and/or sulfur dioxides, and by reaction of sulfur and/or sulfur dioxide with carbon and/or a carbon containing compound to form the carbon disulfide formulation. The selection of the method used to convert at least a portion of the sulfur compound into a carbon disulfide formulation is not critical.
- the carbon disulfide and/or carbon oxysulfide formulation may include carbon disulfide, carbon oxysulfide, and/or carbon disulfide derivatives for example, thiocarbonates, xanthates and mixtures thereof; and optionally one or more of the following: hydrogen sulfide, sulfur, carbon dioxide, hydrocarbons, and mixtures thereof.
- a carbon disulfide formulation is defined as a formulation having a molar ratio of carbon disulfide to carbon oxysulfide of greater than about 1.
- a carbon oxysulfide formulation is defined as a formulation having a molar ratio of carbon disulfide to carbon oxysulfide of about 1 or less.
- a carbon disulfide formulation may be used interchangeably with a carbon oxysulfide formulation, as the terms are defined above.
- the carbon disulfide formulation may be substituted with a carbon oxysulfide formulation.
- carbon disulfide formulation and/or carbon oxysulfide formulation production may have an input of a sulfur compound, for example injected directly into the formation.
- the sulfur compound may be converted into sulfur dioxide and/or sulfur by an oxidation reaction, for example by the Claus process, catalytic selective oxidation reaction, or by reaction with a metal as described hereinafter.
- the oxidation reaction may include reacting a sulfur compound with an oxygen containing gas in a reaction zone to yield sulfur dioxide and/or sulfur, among other components.
- the oxygen containing gas may be oxygen, air, oxygen-enriched air, or oxygen depleted air.
- the sulfur compound may be oxidized in the presence of a catalyst.
- Suitable catalysts may be present within or as part of the formation, including mineral compounds of elements such as aluminum, antimony, barium, bismuth, calcium, cerium, chromium, cobalt, copper, gallium, germanium, hafnium, iridium, iron, lanthanum, lead, magnesium, manganese, molybdenum, neodymium, nickel, niobium, osmium, palladium, platinum, praseodymium, rhenium, rhodium, ruthenium, samarium, scandium, silicon, silver, tantalum, tin, titanium, tungsten, vanadium, yttrium, zinc, zirconium, like oxides, sulfides, or carbides of these elements, and/or combinations or mixtures of two or more of the above.
- suitable catalysts, or precursors thereof might be added to the formation or used in a surface conversion process.
- Suitable delivery methods to add catalyst precursors to the formation are via fluid injection, the fluid containing the catalyst precursor.
- the catalyst precursor can be part of the injection fluid as a liquid, a solution, a slurry, or a gas.
- Suitable catalyst precursors may contain elements such as titanium, vanadium, chromium, manganese, iron, cobalt, nickel, copper, zirconium, niobium, molybdenum or mixtures thereof.
- Suitable gaseous catalyst precursors may be compounds of the elements above such as halides and carbonyls or mixtures thereof.
- Suitable liquids include molten salts of carbonates, hydroxides and or halides or mixtures thereof such as eutectic melts.
- Suitable solutions may be aqueous solutions of the water-soluble salts of the elements above as nitrates, sulfates, and halides.
- the oxidation reaction may take place in the formation or a surface process in a reaction zone having a temperature of less than about 500° C., for example from about 150 to about 500° C., or from about 200 to about 300° C., or above the dew point of sulfur, for given process conditions, so that sulfur does not condense onto the catalyst or in the reaction zone.
- the oxidation reaction may take place in the formation or in a surface process in a reaction zone having a pressure from about 100 to about 1000 kilopascals, for example from about 200 to about 500 kilopascals (absolute).
- a sulfur compound may be converted to sulfur and/or sulfur dioxide, for which processes are disclosed in U.S. patent application publication Nos. 2004/0096381, 2004/0022721, 2004/0159583, 2003/0194366, 2001/0008619, 2002/0134706, 2004/0096381, 2004/0022721, 2004/0159583, and 2001/0008619, the disclosures of which are herein incorporated by reference in their entirety.
- Sulfur and/or sulfur dioxide may be reacted with carbon or a carbon containing compound in the formation or in a surface process in a reaction zone to produce a carbon disulfide or carbon oxysulfide formulation.
- the carbon compound comprises carbon in any form, for example graphite, coal, charcoal, carbon monoxide, hydrocarbons for example natural gas, methane, ethane, propane, or heavier hydrocarbons, such as heavy oil, tar, tar sands, shales, asphaltenes, and/or bitumen.
- hydrocarbons for example natural gas, methane, ethane, propane, or heavier hydrocarbons, such as heavy oil, tar, tar sands, shales, asphaltenes, and/or bitumen.
- sulfur and/or sulfur dioxide may be combined with a carbon compound at temperatures from about 500 to about 900° C., for example from about 550 to 700° C.
- sulfur and/or sulfur dioxide may be combined with a carbon compound at a pressure from about 100 to about 500 kilopascals.
- sulfur and/or sulfur dioxide may be combined with a carbon compound in the presence of a catalyst.
- Suitable catalysts include silica-alumina catalysts, for example those containing from 2 to 10 percent by weight of silica; silica gel; bauxite; activated alumina; and in general those types of clay which are effective in the removal of color bodies and gum forming bodies from petroleum oils.
- the catalysts may additionally comprise one or more of vanadium, niobium, tantalum, chromium, molybdenum, tungsten, manganese, technetium, rhenium, iron, ruthenium, osmium, cobalt, rhodium, iridium, nickel, palladium, and/or platinum; in their elemental form, as compounds of the metals, or as oxides and sulfides.
- oxides and sulfides of iron, vanadium, chromium, molybdenum, and manganese may be used as promoters in combination with silica gel, fuller's earth and/or activated alumina catalysts.
- a carbon disulfide formulation may be produced by reacting carbon with sulfur.
- the carbon may be obtained from hydrocarbons within the formation such as natural gas, crude oil, heavy oils, shale, tar sands, tar, asphalt, bitumen, and/or other hydrocarbons within the formation.
- Sulfur may be reacted with the carbon so as to produce carbon disulfide formulation, for example, sulfur in the liquid or vapor phase may be used for this reaction.
- sulfur and/or sulfur dioxide and a carbon compound may be converted to carbon disulfide formulation, processes for which are disclosed in U.S. Pat. Nos. 4,963,340, 2,636,810, 3,927,185, 4,057,613, and 4,822,938, and U.S. patent application publication No. 2004/0146450, the disclosures of which are herein incorporated by reference in their entirety.
- One suitable method of converting liquid sulfur and a hydrocarbon into a carbon disulfide formulation in the absence of oxygen is disclosed in WO 2007/131976.
- WO 2007/131976 is herein incorporated by reference in its entirety.
- reaction inputs and/or catalysts may be used in a surface process or found within the formation or injected into the formation in order to convert a sulfur containing compound into a carbon disulfide formulation and/or a carbon oxysulfide formulation.
- Carbon disulfide formulation and/or a carbon oxysulfide formulation may be produced in a surface process and/or produced within a formation.
- the carbon disulfide formulation and/or a carbon oxysulfide formulation may then be used in an enhanced oil recovery (EOR) process to boost the production of oil from the formation, for example as disclosed in co-pending patent application TH2616, which is herein incorporated by reference in its entirety.
- EOR enhanced oil recovery
- a mixture of oil and the carbon disulfide formulation may be produced to the surface, the carbon disulfide formulation separated, and optionally recycled to be injected into the formation or into another formation.
- At the conclusion of the EOR process there will be a volume of carbon disulfide formulation within the formation.
- the carbon disulfide formulation may be separated from oil, the oil produced to the surface, and the carbon disulfide formulation converted into another sulfur containing compound.
- the separation of oil and/or gas from a carbon disulfide and/or carbon oxysulfide formulation may be accomplished by any known method. Suitable methods include boiling off the carbon disulfide and/or carbon oxysulfide formulation, by increasing the temperature of the oil mixture. This will leave behind an elevated temperature oil with an increased mobility and lower viscosity to be produced.
- the temperature of the mixture can be increased by injecting steam or hot water, the use of in-situ heaters, or injecting another hot substance such as a liquid or a gas.
- Another suitable method to separate the oil mixture is to hydrolyze the carbon disulfide and/or carbon oxysulfide formulation. This can be accomplished by injecting steam and/or hot water into contact with the oil mixture. This will leave behind an elevated temperature oil with an increased mobility and lower viscosity to be produced.
- the steam and/or hot water may be basic or alkaline, for example by adding amines or ammonia or other bases to the water or steam.
- Another suitable method to separate the oil mixture is to oxidize the carbon disulfide and/or carbon oxysulfide formulation. This can be accomplished by injecting oxygen, air, or other oxygen containing gases into contact with the oil mixture. This will leave behind an elevated temperature oil with an increased mobility and lower viscosity to be produced.
- Another suitable method to separate the oil mixture is to strip the carbon disulfide and/or carbon oxysulfide formulation from the oil. This can be accomplished by injecting nitrogen or other suitable stripping gases or liquids into contact with the oil mixture. This will leave behind an oil to be produced.
- the recovery of oil and/or gas from an underground formation may be accomplished by any known method. Suitable methods include subsea production, surface production, primary, secondary, or tertiary production. The selection of the method used to recover the oil and/or gas from the underground formation is not critical.
- oil and/or gas may be recovered from a formation into a well, and flow through the well and flowline to a facility.
- enhanced oil recovery with the use of an agent for example steam, water, a surfactant, a polymer flood, and/or a miscible agent such as a carbon disulfide formulation, may be used to increase the flow of oil and/or gas from the formation.
- Any carbon disulfide and/or carbon oxysulfide present in the formation may be converted into another compound while within the formation by any suitable method.
- the selection of the method to convert the carbon disulfide and/or carbon oxysulfide is not critical. Suitable methods to convert the carbon disulfide and/or carbon oxysulfide include the formation of hydrogen sulfide and oxidation, which are set forth below.
- the miscible solvent may include a carbon disulfide and/or carbon oxysulfide formulation.
- the carbon disulfide may be hydrolyzed within the formation into hydrogen sulfide and/or carbon oxysulfide formulation, for example by reaction with water and/or steam.
- one or more catalysts such as alumina and/or titania, for example in a solution, as a powder, or as a suspension in water or other fluids may be introduced into the formation in order to catalyze the reaction from carbon disulfide to hydrogen sulfide.
- the carbon disulfide can be hydrolyzed to hydrogen sulfide and/or carbon oxysulfide by any reaction or mechanism.
- the selection of the reaction or mechanism is not critical.
- One suitable mechanism by which the carbon disulfide is hydrolyzed to hydrogen sulfide is a known reaction, which has the formula:
- the carbon disulfide may be hydrolyzed further within the formation into carbon dioxide and hydrogen sulfide, for example by reaction with water or steam.
- the carbon oxysulfide can be hydrolyzed to hydrogen sulfide and carbon dioxide by any reaction or mechanism.
- the selection of the reaction or mechanism is not critical.
- One suitable mechanism by which the carbon oxysulfide is hydrolyzed to hydrogen sulfide is a known reaction, which has the formula:
- the hydrogen sulfide may then be recovered from one or more wells.
- water, air, carbon dioxide, or one or more other liquids or gases or remediation agents may be injected into the formation to aid in the recovery of the hydrogen sulfide from a well.
- the miscible solvent may include an alcohol and/or hydrocarbon such as natural gas, propane, butane, and/or pentane.
- the miscible solvent may be burned in place within the formation into primarily water and carbon dioxide, for example by the addition of oxygen, steam, peroxides, and/or heat.
- the miscible solvent may include a carbon disulfide formulation.
- the carbon disulfide may be combusted or oxidized within the formation into sulfur dioxide and/or carbon dioxide, for example by the addition of oxygen, peroxides, and/or heat.
- the carbon disulfide can be oxidized by any reaction or mechanism.
- the selection of the reaction or mechanism is not critical.
- One suitable mechanism by which the carbon disulfide is oxidized to sulfur dioxide is a known reaction, which has the formula:
- the sulfur dioxide may then be recovered from one or more wells, or left in place within the formation.
- water, air, carbon dioxide, or one or more other liquids or gases or remediation agents may be injected into the formation to aid in the recovery of the sulfur dioxide from a well.
- System 200 includes underground formation 202 , underground formation 204 , underground formation 206 , and underground formation 208 .
- Production facility 210 is provided at the surface.
- Well 212 traverses formations 202 and 204 , and has openings in formation 206 .
- Portions 214 of formation 206 may optionally be fractured and/or perforated.
- Oil and gas from formation 206 is produced into portions 214 , into well 212 , and travels up to production facility 210 .
- Production facility may then separate gas, which is sent to gas processing 216 , and liquid, which is sent to liquid storage 218 .
- Production facility also includes carbon disulfide formulation storage 230 .
- Carbon disulfide, hydrogen sulfide and/or other sulfur containing compounds produced from well 212 may be sent to carbon disulfide formulation production 230 .
- Carbon disulfide, hydrogen sulfide and/or other sulfur containing compounds may be pumped down well 212 that is shown by the down arrow and is pumped into formation 206 , and is then separated and the oil and gas produced back up well 212 to production facility 210 .
- System 200 includes underground formation 202 , underground formation 204 , underground formation 206 , and underground formation 208 .
- Production facility 210 is provided at the surface.
- Well 212 traverses formations 202 and 204 , and has openings in formation 206 .
- Portions 214 of formation 206 may be optionally fractured and/or perforated.
- oil and gas from formation 206 is produced into portions 214 , into well 212 , and travels up to production facility 210 .
- Production facility then separates gas, which is sent to gas processing 216 , and liquid, which is sent to liquid storage 218 .
- Production facility also includes carbon disulfide formulation storage 230 .
- Carbon disulfide formulation, hydrogen sulfide and/or other sulfur containing compounds may be separated from oil and/or gas within the formation, before the oil and/or gas is produced into well 212 , or after the oil and/or gas is produced into well 212 and to a surface facility.
- sulfur containing compound, other liquids, gases, and/or catalysts may be pumped down well 212 that is shown by the down arrow and pumped into formation 206 .
- Sulfur containing compound formulation may be left to soak in formation for a period of time from about 1 hour to about 15 days, for example from about 5 to about 50 hours, in order to react with hydrocarbons to form a miscible sulfur compound-oil formulation.
- carbon disulfide formulation may be produced with the oil and/or gas, back up well 212 to production facility 210 .
- sulfur containing compound may be pumped into formation 206 above the fracture pressure of the formation, for example from about 120% to about 200% of the fracture pressure.
- Sulfur containing compound may be pumped into formation 206 at a temperature from about 200 to about 1000° C., for example from about 400 to about 800° C., or from about 500 to about 700° C.
- Sulfur containing compound may be pumped into formation 206 at a pressure from about 2 to about 200 bars, for example from about 3 to about 100 bars, or from about 5 to about 50 bars.
- System 300 includes underground formation 302 , formation 304 , formation 306 , and formation 308 .
- Production facility 310 is provided at the surface.
- Well 312 traverses formation 302 and 304 has openings at formation 306 .
- Portions of formation 314 may be optionally fractured and/or perforated.
- Gas and liquid may be separated, and gas may be sent to gas storage 316 , and liquid may be sent to liquid storage 318 .
- Production facility 310 is able to store and/or produce carbon disulfide formulation, which may be produced and stored in carbon disulfide formulation production 330 .
- Carbon disulfide formulation, hydrogen sulfide and/or other sulfur containing compounds may be separated from oil and/or gas, after the oil and/or gas is produced to well 312 and to surface facilities.
- Carbon disulfide formulation may also be optionally recycled back to the formation, or to another formation.
- a carbon disulfide and/or a carbon oxysulfide formulation, and optionally other liquids, gases, and/or catalysts may be pumped down well 332 , to portions 334 of formation 306 .
- the carbon disulfide and/or the carbon oxysulfide formulation traverses formation 306 and reacts with one or more hydrocarbons to make a miscible oil mixture with the carbon disulfide and/or carbon oxysulfide formulation, which aids in the production of oil and gas, and then the mixture may be produced to well 312 and to production facilities 310 , and then the carbon disulfide formulation and oil and/or gas may be separated.
- Carbon disulfide formulation may then be recycled and reinjected into the formation or to another target formation.
- carbon disulfide formulation or carbon disulfide formulation mixed with other components may be miscible in oil and/or gas in formation 306 .
- carbon disulfide formulation or carbon disulfide formulation mixed with other components may be mixed in with oil and/or gas in formation 306 to form a miscible mixture. The mixture may then be produced to well 312 , then separated.
- carbon disulfide formulation or carbon disulfide formulation mixed with other components may not mix in with oil and/or gas in formation 306 , so that carbon disulfide formulation or carbon disulfide formulation mixed with other components travels as a plug across formation 306 to force oil and/or gas to well 312 .
- a quantity of carbon disulfide formulation or carbon disulfide formulation mixed with other components may be injected into well 332 , followed by another component to force carbon disulfide formulation or carbon disulfide formulation mixed with other components across formation 306 , for example air; water in gas or liquid form; water mixed with one or more salts, polymers, and/or surfactants; carbon dioxide; other gases; other liquids; and/or mixtures thereof.
- FIG. 3 e illustrates the system of FIG. 3 d at the conclusion of an EOR process.
- System 300 may be used to separate and/or convert carbon disulfide formulation within underground formation 302 .
- System 300 includes underground formation 302 , formation 304 , formation 306 , and formation 308 .
- Production facility 310 is provided at the surface.
- Well 312 traverses formation 302 and 304 has openings at formation 306 .
- Portions of formation 314 may be optionally fractured and/or perforated.
- a separating agent may be injected into well 332 and into formation 306 as shown by the arrows.
- a separating agent may also be injected into well portion 332 and out of the bottom of well portion 332 as shown by the arrows and into formation 306 .
- the separating agent may act to separate the oil and/or gas from the carbon disulfide formulation, and/or to raise the temperature and mobility of the oil.
- Suitable separating agents include steam, water, air, oxygen containing gases, nitrogen, amines, and other liquids and gases known in the art to separate oil/carbon disulfide formulation mixtures.
- separated oil and/or gas 344 may be produced to well potion 312 as shown by arrows, for example at a point in the well above where the separating agent was injected.
- carbon disulfide formulation, separating agent, converted carbon disulfide formulation, and/or a mixture thereof may form a lower density blanket 342 above oil and/or gas 344 .
- Blanket 342 may be used to force oil and/or gas 344 towards well portion 312 .
- blanket 342 may be produced to well portion 312 or left in formation 306 .
- well 312 may be used to inject separating agent for a first time period, and then well 312 may be used to produce oil and/or gas for a second time period. In some embodiments, well 312 may be alternatively cycled between injecting the separating agent and producing oil and/or gas, for example from about 2 to about 100 cycles, for example from about 5 to about 10 cycles.
- Carbon disulfide formulation production 430 has an input of hydrogen sulfide and/or other sulfur containing compounds. Hydrogen sulfide may be converted into sulfur dioxide by oxidation reaction 432 . Hydrogen sulfide and sulfur dioxide may be converted to sulfur at 434 . Sulfur may be combined with a carbon compound to produce carbon disulfide formulation at 436 . The carbon disulfide formulation and hydrogen sulfide produced at 436 may be the output. Carbon disulfide formulation and/or a carbon disulfide formulation containing mixture may be the output from carbon disulfide formulation production 430 .
- carbon disulfide derived salts can be dissolved in water, and the resulting solution pumped into formations 206 and/or 306 .
- the dissolved carbon disulfide formulations may decompose, yielding carbon disulfide in formations 206 and/or 306 .
- gas and liquid produced from well 212 and/or 312 may be separated, for example with a gravity separator or a centrifuge, or with other methods known in the art.
- the gas portion may be sent to carbon disulfide formulation production 230 and/or 330 .
- all of the components of system 200 and/or system 300 may be within about 10 km of each other, for example about 5, 3, or 1 km.
- oil and/or gas produced from well 212 and/or 312 may be transported to a refinery and/or a treatment facility.
- the oil and/or gas may be processed to produced to produce commercial products such as transportation fuels such as gasoline and diesel, heating fuel, lubricants, chemicals, and/or polymers.
- Processing may include distilling and/or fractionally distilling the oil and/or gas to produce one or more distillate fractions.
- the oil and/or gas, and/or the one or more distillate fractions may be subjected to a process of one or more of the following: catalytic cracking, hydrocracking, hydrotreating, coking, thermal cracking, distilling, reforming, polymerization, isomerization, alkylation, blending, and dewaxing.
- any of the embodiments to complete Step 1 may be combined with any of the embodiments to complete Step 2 , which may be combined with any of the embodiments to complete Step 3 .
- a system for producing oil and/or gas comprising a formation comprising a mixture of oil and/or gas and a carbon disulfide formulation and/or a carbon oxysulfide formulation; a mechanism for releasing a separating agent into the formation, the separating agent adapted to separate the oil and/or gas from the carbon disulfide formulation and/or the carbon oxysulfide formulation.
- the system also includes a mechanism for recovering the oil and/or gas from the formation.
- the mechanism for recovering comprises a well in the underground formation and a recovery facility at a topside of the well.
- the mechanism for recovering comprises a first well drilled in the underground formation for recovering the oil and/or gas, and a production facility at a topside of the first well; and the mechanism for releasing the separating agent comprises a second well in the underground formation for releasing the separating agent into the formation.
- the mechanism for recovering comprises a first well drilled in the underground formation for recovering the oil and/or gas, and a production facility at a topside of the first well; and the mechanism for releasing the separating agent comprises the first well in the underground formation for releasing the separating agent into the formation.
- the first well comprises a first portion for recovering the oil and/or gas, and a second portion for releasing the separating agent.
- the first well is used for releasing the separating agent for a first time period, and then used for recovering the oil and/or gas for a second time period.
- the system also includes a heater within the formation adapted to heat at least one of the separating agent, oil, and/or gas.
- the system also includes a mechanism adapted to convert the carbon disulfide formulation and/or the carbon oxysulfide formulation into another compound within the formation.
- the mechanism to convert comprises a mechanism to produce hydrogen sulfide and/or a mechanism to oxidize.
- the separating agent is selected from the group of air, oxygen, oxygen containing gases, nitrogen, amines, steam, water, and mixtures thereof.
- a method for producing oil and/or gas comprising providing a formation comprising a mixture of oil and/or gas and a carbon disulfide formulation and/or a carbon oxysulfide formulation; releasing a separating agent into a formation; and separating the oil and/or gas from the carbon disulfide formulation and/or the carbon oxysulfide formulation.
- the method also includes recovering oil and/or gas from the underground formation.
- the recovering is done from a first well and the releasing the separating agent is done from the first well.
- the recovering is done from a first well and the releasing the separating agent is done from a second well.
- the recovering is done from a higher point in the formation, and the releasing the separating agent is done from a lower point in the formation.
- the method also includes heating the separating agent prior to injecting the separating agent into the formation, or while within the formation.
- the method also includes converting the carbon disulfide formulation and/or a carbon oxysulfide formulation into another compound within the formation.
- the method also includes converting at least a portion of a recovered oil and/or gas from the formation into a material selected from the group consisting of transportation fuels such as gasoline and diesel, heating fuel, lubricants, chemicals, and/or polymers.
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Abstract
A system for producing oil and/or gas comprising a system for producing oil and/or gas comprising a formation comprising a mixture of oil and/or gas and a carbon disulfide formulation and/or a carbon oxysulfide formulation; a mechanism for releasing a separating agent into the formation, the separating agent adapted to separate the oil and/or gas from the carbon disulfide formulation and/or the carbon oxysulfide formulation.
Description
- The present disclosure relates to systems and methods for producing oil and/or gas.
- Substantial amounts of sour natural gas are currently being produced from natural gas wells, oil wells (for example, as associated gas), and from natural gas storage reservoirs that have been infected with hydrogen sulfide-producing bacteria. The presence of hydrogen sulfide and other sulfur compounds in fuel and other gases has long been of concern for both the users and the producers of such gases. In addition to the corrosive and other adverse effects that such impurities have upon equipment and processes, noxious emissions are commonly produced from combustion of the natural gas as a result of oxidation of the sulfur compounds. The resulting sulfur oxides can be a major contributor to air pollution and may have detrimental impact upon the environment. Increasingly stringent federal and state regulations have accordingly been promulgated in an effort to reduce or eliminate sulfurous emissions, and a concomitant interest exists in efficiently removing from natural gas and the like the hydrogen sulfide that comprises a significant precursor of noxious emissions. In addition, one method of disposing of hydrogen sulfide has been to convert it into solid sulfur, for storage. Due to environmental and aesthetic concerns, many countries are now outlawing the formation of such sulfur stores.
- Enhanced Oil Recovery (EOR) may be used to increase oil recovery in fields worldwide. There are three main types of EOR, thermal, chemical/polymer and gas injection, which may be used to increase oil recovery from a reservoir, beyond what can be achieved by conventional means—possibly extending the life of a field and boosting the oil recovery factor.
- Thermal enhanced recovery works by adding heat to the reservoir. The most widely practised form is a steamdrive, which reduces oil viscosity so that it can flow to the producing wells. Chemical flooding increases recovery by reducing the capillary forces that trap residual oil. Polymer flooding improves the sweep efficiency of injected water. Miscible gas injection works in a similar way to chemical flooding. By injecting a fluid that is miscible with the oil, trapped residual oil can be recovered.
- Referring to
FIG. 1 , there is illustratedprior art system 100.System 100 includesunderground formation 102,underground formation 104,underground formation 106, andunderground formation 108.Production facility 110 is provided at the surface. Well 112 traversesformations formation 106. The portion offormation 106 is shown at 114. Oil and gas are produced fromformation 106 throughwell 112, toproduction facility 110. Gas and liquid are separated from each other, gas is stored ingas storage 116 and liquid is stored inliquid storage 118. Gas ingas storage 116 may contain hydrogen sulfide, which must be processed, transported, disposed of, or stored. - Co-Pending Patent Application Publication U.S. 2006/0254769 discloses a system including a mechanism for recovering oil and/or gas from an underground formation, the oil and/or gas comprising one or more sulfur compounds; a mechanism for converting at least a portion of the sulfur compounds from the recovered oil and/or gas into a carbon disulfide formulation; and a mechanism for releasing at least a portion of the carbon disulfide formulation into a formation. Publication U.S. 2006/0254769 is herein incorporated by reference in its entirety.
- There is a need in the art for improved systems and methods for processing, transportation, disposal, or storage of hydrogen sulfide from a liquid and/or gas. There is a need in the art for improved systems and methods for processing, transportation, disposal, or storage of sulfur from a liquid and/or gas. There is a further need in the art for improved systems and methods for enhanced oil recovery. There is a further need in the art for improved systems and methods for enhanced oil recovery using a sulfur compound, for example through viscosity reduction, chemical effects, and miscible flooding. There is a further need in the art for improved systems and methods for making sulfur containing enhanced oil recovery agents.
- In addition, carbon disulfide is a common chemical with applications ranging from use as a commercial solvent for the production of rayon, to a raw material for the production of agricultural insecticides. The carbon disulfide manufacturing process involves the purchase and transport of both solid sulfur and natural gas (or another carbon source), often from long distances, to the manufacturing site and produces carbon disulfide at very high purity. These two factors—the high purchase and shipping costs of the raw materials, and the high purity of the final product—result in a relatively high production cost for carbon disulfide.
- The manufacturing process for converting sour gas into solid sulfur involves a solvent unit to first remove hydrogen sulfide, other sulfur compounds, and contaminants such as carbon dioxide from the natural gas stream, followed by a Claus unit to convert the hydrogen sulfide into sulfur, which is then allowed to solidify prior to transport or transported as a liquid. The manufacturing process for manufacturing carbon disulfide, on the other hand, entails the heating, melting, and vaporization of solid or liquid sulfur and reacting its vapors with heated natural gas or another carbon source.
- There is a need in the art for improved systems and methods for carbon disulfide manufacturing. There is a need in the art for improved systems and methods for more energy efficient carbon disulfide manufacturing. There is a need in the art for improved systems and methods for removing carbon disulfide from a reservoir at the conclusion of an EOR process.
- In one aspect, the invention provides a system for producing oil and/or gas comprising a formation comprising a mixture of oil and/or gas and a carbon disulfide formulation and/or a carbon oxysulfide formulation; a mechanism for releasing a separating agent into the formation, the separating agent adapted to separate the oil and/or gas from the carbon disulfide formulation and/or the carbon oxysulfide formulation.
- In another aspect, the invention provides a method for producing oil and/or gas comprising providing a formation comprising a mixture of oil and/or gas and a carbon disulfide formulation and/or a carbon oxysulfide formulation; releasing a separating agent into a formation; and separating the oil and/or gas from the carbon disulfide formulation and/or the carbon oxysulfide formulation.
- Advantages of the invention include one or more of the following:
- Improved systems and methods for disposing of hydrogen sulfide, sulfur, and/or other sulfur based compounds.
- Improved systems and methods for enhanced recovery of hydrocarbons from a formation with a carbon disulfide formulation.
- Improved systems and methods for enhanced recovery of hydrocarbons from a formation with a fluid containing a carbon disulfide formulation.
- Improved systems and methods for producing a carbon disulfide formulation.
- Improved carbon disulfide containing compositions for secondary recovery of hydrocarbons.
- Improved systems and methods for processing, transportation, disposal, or storage of a sulfur compound from a liquid and/or gas.
- Improved systems and methods for enhanced oil recovery.
- Improved systems and methods for enhanced oil recovery using a sulfur compound.
- Improved systems and methods for enhanced oil recovery using a compound which is miscible with oil in place.
- Improved systems and methods for making and/or using sulfur containing enhanced oil recovery agents.
- Improved systems and methods for removing carbon disulfide from a formation at the conclusion of an enhanced oil recovery process.
-
FIG. 1 illustrates an oil and/or gas production system. -
FIG. 2 illustrates an oil and/or gas production process. -
FIGS. 3 a-3 e illustrate oil and/or gas production systems. -
FIG. 4 illustrates a carbon disulfide formulation production process. - Referring now to
FIG. 2 , in one embodiment of the invention, process A for producing oil and/or gas, which includes disposing of a sulfur compound is illustrated. Process A includesstep 1 where sulfur and/or a sulfur-containing compound is obtained, and optionally released into a formation. Instep 2, at least a portion of the sulfur compound is converted into a carbon disulfide formulation and/or a carbon oxysulfide formulation, optionally within the formation. Instep 3, at the conclusion of an EOR operation, oil and/or gas may be separated from the carbon disulfide formulation and/or the carbon oxysulfide formulation, and the oil recovered from the underground formation, and the carbon disulfide formulation and/or a carbon oxysulfide formulation may be converted into another compound within the formation. - The obtaining of the sulfur containing compound may be accomplished by any known method. Suitable methods include purchasing gaseous, liquid and/or solid elemental sulfur or sulfur containing compounds; recovering such compounds from an underground formation; and/or recovering such compounds as a stream from surface processes. The selection of the method used to obtain the sulfur containing compound into the underground formation is not critical.
- Such compounds may be injected into a formation with any known method. Suitable methods include vertical and horizontal wells, perforating the formation, injecting liquid and/or vaporized elemental sulfur, or other methods for injecting liquids and gases into a formation as are known in the art. The selection of the method used to release the sulfur containing compound into the underground formation is not critical.
- In some embodiments of the invention, the sulfur compound may include elemental sulfur, hydrogen sulfide, mercaptans, sulfides and disulfides other than hydrogen disulfide, or heterocyclic sulfur compounds for example thiophenes, benzothiophenes, or substituted and condensed ring dibenzothiophenes, or mixtures thereof.
- Releasing at least a portion of the sulfur containing compound and/or other liquids and/or gases may be accomplished by any known method. One suitable method is injecting sulfur containing compound into a single conduit in a single well, allowing sulfur containing compound to soak, and then pumping out at least a portion of the gases and/or liquids. Another suitable method is injecting sulfur containing compound into a first conduit in a single well, and pumping out at least a portion of the gases and/or liquids through a second conduit in the single well. Another suitable method is injecting sulfur containing compound into a first well, and pumping out at least a portion of the gases and/or liquids through a second well. The selection of the method used to inject at least a portion of the sulfur containing compound and/or other liquids and/or gases is not critical.
- Alternatively, the order of injection and conversion may be reversed. The sulfur containing compound may be converted into another compound in a surface process, and then the other compound injected into the formation. The other compound may be injected by any known method, for example those discussed above or other methods as are known in the art.
- A sulfur containing compound and/or other liquids and/or gases, such as a solvent or a liquid or gas miscible with the oil in place, may be left to soak in a formation for a period of time from about 1 hour to about 15 days, for example from about 5 to about 50 hours.
- In some embodiments, sulfur containing compound and/or other liquids and/or gases may be pumped into a formation at a pressure above the fracture pressure of the formation.
- In some embodiments, sulfur containing compound or sulfur containing compound mixed with other components may be miscible in oil (or other liquids) and/or gases in a formation. In some embodiments, sulfur containing compound or sulfur containing compound mixed with other components may be immiscible in oil and/or gas in formation.
- In some embodiments, sulfur containing compound may be heated prior to being injected into the formation to lower the viscosity of fluids in the formation, for example heavy oils, paraffins, asphaltenes, etc.
- In some embodiments, sulfur containing compound may be heated and/or boiled while within the formation, with the use of a heated fluid or a heater, to lower the viscosity of fluids in the formation. In some embodiments, heated water and/or steam may be used to heat and/or vaporize the sulfur containing compound in the formation. Alternatively, a nonaqueous fluid could be substituted for steam or hot water as the heat medium to heat sulfur containing compound, for example a heavy aromatic solvent which may have its own solubilizing effect on reservoir hydrocarbons.
- In some embodiments of the invention, in addition to injecting a sulfur containing compound into the formation, one or more catalysts for example as a slurry or suspension, oxygen or an oxygen containing gas, and one or more hydrocarbons may also be injected into the formation. Suitable catalysts, gases, and hydrocarbons which may be used in reactions within the formation are set forth below with regard to
Step 2. - The conversion of at least a portion of the sulfur compound into a carbon disulfide and/or carbon oxysulfide formulation may be accomplished by any known method. Suitable methods may include an oxidation reaction of the sulfur compound to sulfur and/or sulfur dioxides, and by reaction of sulfur and/or sulfur dioxide with carbon and/or a carbon containing compound to form the carbon disulfide formulation. The selection of the method used to convert at least a portion of the sulfur compound into a carbon disulfide formulation is not critical.
- In some embodiments of the invention, the carbon disulfide and/or carbon oxysulfide formulation may include carbon disulfide, carbon oxysulfide, and/or carbon disulfide derivatives for example, thiocarbonates, xanthates and mixtures thereof; and optionally one or more of the following: hydrogen sulfide, sulfur, carbon dioxide, hydrocarbons, and mixtures thereof.
- In some embodiments of the invention, a carbon disulfide formulation is defined as a formulation having a molar ratio of carbon disulfide to carbon oxysulfide of greater than about 1.
- In some embodiments of the invention, a carbon oxysulfide formulation is defined as a formulation having a molar ratio of carbon disulfide to carbon oxysulfide of about 1 or less.
- In some embodiments of the invention, a carbon disulfide formulation may be used interchangeably with a carbon oxysulfide formulation, as the terms are defined above. For example, where the production, storage, and/or use of a carbon disulfide formulation are described below, the carbon disulfide formulation may be substituted with a carbon oxysulfide formulation.
- In some embodiments of the invention, carbon disulfide formulation and/or carbon oxysulfide formulation production may have an input of a sulfur compound, for example injected directly into the formation.
- In some embodiments of the invention, the sulfur compound may be converted into sulfur dioxide and/or sulfur by an oxidation reaction, for example by the Claus process, catalytic selective oxidation reaction, or by reaction with a metal as described hereinafter.
- In some embodiments of the invention, the oxidation reaction may include reacting a sulfur compound with an oxygen containing gas in a reaction zone to yield sulfur dioxide and/or sulfur, among other components.
- In some embodiments of the invention, the oxygen containing gas may be oxygen, air, oxygen-enriched air, or oxygen depleted air.
- In some embodiments of the invention, the sulfur compound may be oxidized in the presence of a catalyst. Suitable catalysts may be present within or as part of the formation, including mineral compounds of elements such as aluminum, antimony, barium, bismuth, calcium, cerium, chromium, cobalt, copper, gallium, germanium, hafnium, iridium, iron, lanthanum, lead, magnesium, manganese, molybdenum, neodymium, nickel, niobium, osmium, palladium, platinum, praseodymium, rhenium, rhodium, ruthenium, samarium, scandium, silicon, silver, tantalum, tin, titanium, tungsten, vanadium, yttrium, zinc, zirconium, like oxides, sulfides, or carbides of these elements, and/or combinations or mixtures of two or more of the above.
- In some embodiments, suitable catalysts, or precursors thereof, might be added to the formation or used in a surface conversion process. Suitable delivery methods to add catalyst precursors to the formation are via fluid injection, the fluid containing the catalyst precursor. The catalyst precursor can be part of the injection fluid as a liquid, a solution, a slurry, or a gas. Suitable catalyst precursors may contain elements such as titanium, vanadium, chromium, manganese, iron, cobalt, nickel, copper, zirconium, niobium, molybdenum or mixtures thereof. Suitable gaseous catalyst precursors may be compounds of the elements above such as halides and carbonyls or mixtures thereof. Suitable liquids include molten salts of carbonates, hydroxides and or halides or mixtures thereof such as eutectic melts. Suitable solutions may be aqueous solutions of the water-soluble salts of the elements above as nitrates, sulfates, and halides.
- In some embodiments of the invention, the oxidation reaction may take place in the formation or a surface process in a reaction zone having a temperature of less than about 500° C., for example from about 150 to about 500° C., or from about 200 to about 300° C., or above the dew point of sulfur, for given process conditions, so that sulfur does not condense onto the catalyst or in the reaction zone.
- In some embodiments of the invention, the oxidation reaction may take place in the formation or in a surface process in a reaction zone having a pressure from about 100 to about 1000 kilopascals, for example from about 200 to about 500 kilopascals (absolute).
- In some embodiments, a sulfur compound may be converted to sulfur and/or sulfur dioxide, for which processes are disclosed in U.S. patent application publication Nos. 2004/0096381, 2004/0022721, 2004/0159583, 2003/0194366, 2001/0008619, 2002/0134706, 2004/0096381, 2004/0022721, 2004/0159583, and 2001/0008619, the disclosures of which are herein incorporated by reference in their entirety.
- Sulfur and/or sulfur dioxide may be reacted with carbon or a carbon containing compound in the formation or in a surface process in a reaction zone to produce a carbon disulfide or carbon oxysulfide formulation.
- In some embodiments, the carbon compound comprises carbon in any form, for example graphite, coal, charcoal, carbon monoxide, hydrocarbons for example natural gas, methane, ethane, propane, or heavier hydrocarbons, such as heavy oil, tar, tar sands, shales, asphaltenes, and/or bitumen.
- In some embodiments, sulfur and/or sulfur dioxide may be combined with a carbon compound at temperatures from about 500 to about 900° C., for example from about 550 to 700° C.
- In some embodiments, sulfur and/or sulfur dioxide may be combined with a carbon compound at a pressure from about 100 to about 500 kilopascals.
- In some embodiments, sulfur and/or sulfur dioxide may be combined with a carbon compound in the presence of a catalyst. Suitable catalysts include silica-alumina catalysts, for example those containing from 2 to 10 percent by weight of silica; silica gel; bauxite; activated alumina; and in general those types of clay which are effective in the removal of color bodies and gum forming bodies from petroleum oils. The catalysts may additionally comprise one or more of vanadium, niobium, tantalum, chromium, molybdenum, tungsten, manganese, technetium, rhenium, iron, ruthenium, osmium, cobalt, rhodium, iridium, nickel, palladium, and/or platinum; in their elemental form, as compounds of the metals, or as oxides and sulfides. For example, oxides and sulfides of iron, vanadium, chromium, molybdenum, and manganese may be used as promoters in combination with silica gel, fuller's earth and/or activated alumina catalysts.
- In some embodiments, a carbon disulfide formulation may be produced by reacting carbon with sulfur. The carbon may be obtained from hydrocarbons within the formation such as natural gas, crude oil, heavy oils, shale, tar sands, tar, asphalt, bitumen, and/or other hydrocarbons within the formation. Sulfur may be reacted with the carbon so as to produce carbon disulfide formulation, for example, sulfur in the liquid or vapor phase may be used for this reaction.
- In some embodiments, sulfur and/or sulfur dioxide and a carbon compound may be converted to carbon disulfide formulation, processes for which are disclosed in U.S. Pat. Nos. 4,963,340, 2,636,810, 3,927,185, 4,057,613, and 4,822,938, and U.S. patent application publication No. 2004/0146450, the disclosures of which are herein incorporated by reference in their entirety. One suitable method of converting liquid sulfur and a hydrocarbon into a carbon disulfide formulation in the absence of oxygen is disclosed in WO 2007/131976. WO 2007/131976 is herein incorporated by reference in its entirety.
- One suitable method of converting liquid sulfur and a hydrocarbon into a carbon disulfide formulation in the presence of oxygen is disclosed in WO 2007/131977. WO 2007/131977 is herein incorporated by reference in its entirety.
- Other suitable methods for converting sulfur compounds into a carbon disulfide formulation and/or a carbon oxysulfide formulation are disclosed in co-pending patent applications: U.S. Patent Publication 2006/0254769 having attorney docket number TH2616; U.S. Provisional Application 61/031,832 having attorney docket number TH3448; U.S. Provisional Application 61/024,694 having attorney docket number TH3443; PCT Patent Publication WO 2007/131976 having attorney docket number TS1746; PCT Patent Publication WO 2008/003732 having attorney docket number TS1818; PCT Patent Publication WO 2007/131977 having attorney docket number TS1833; and PCT Patent Application PCT/EP2007/059746 having attorney docket number TS9597, which are all herein incorporated by reference in their entirety.
- As discussed above, the reaction inputs and/or catalysts may be used in a surface process or found within the formation or injected into the formation in order to convert a sulfur containing compound into a carbon disulfide formulation and/or a carbon oxysulfide formulation.
- Carbon disulfide formulation and/or a carbon oxysulfide formulation may be produced in a surface process and/or produced within a formation. The carbon disulfide formulation and/or a carbon oxysulfide formulation may then be used in an enhanced oil recovery (EOR) process to boost the production of oil from the formation, for example as disclosed in co-pending patent application TH2616, which is herein incorporated by reference in its entirety. A mixture of oil and the carbon disulfide formulation may be produced to the surface, the carbon disulfide formulation separated, and optionally recycled to be injected into the formation or into another formation. At the conclusion of the EOR process, there will be a volume of carbon disulfide formulation within the formation. The carbon disulfide formulation may be separated from oil, the oil produced to the surface, and the carbon disulfide formulation converted into another sulfur containing compound.
- The separation of oil and/or gas from a carbon disulfide and/or carbon oxysulfide formulation may be accomplished by any known method. Suitable methods include boiling off the carbon disulfide and/or carbon oxysulfide formulation, by increasing the temperature of the oil mixture. This will leave behind an elevated temperature oil with an increased mobility and lower viscosity to be produced. The temperature of the mixture can be increased by injecting steam or hot water, the use of in-situ heaters, or injecting another hot substance such as a liquid or a gas.
- Another suitable method to separate the oil mixture is to hydrolyze the carbon disulfide and/or carbon oxysulfide formulation. This can be accomplished by injecting steam and/or hot water into contact with the oil mixture. This will leave behind an elevated temperature oil with an increased mobility and lower viscosity to be produced. In some embodiments, the steam and/or hot water may be basic or alkaline, for example by adding amines or ammonia or other bases to the water or steam.
- Another suitable method to separate the oil mixture is to oxidize the carbon disulfide and/or carbon oxysulfide formulation. This can be accomplished by injecting oxygen, air, or other oxygen containing gases into contact with the oil mixture. This will leave behind an elevated temperature oil with an increased mobility and lower viscosity to be produced.
- Another suitable method to separate the oil mixture is to strip the carbon disulfide and/or carbon oxysulfide formulation from the oil. This can be accomplished by injecting nitrogen or other suitable stripping gases or liquids into contact with the oil mixture. This will leave behind an oil to be produced.
- The recovery of oil and/or gas from an underground formation may be accomplished by any known method. Suitable methods include subsea production, surface production, primary, secondary, or tertiary production. The selection of the method used to recover the oil and/or gas from the underground formation is not critical.
- In one embodiment, oil and/or gas may be recovered from a formation into a well, and flow through the well and flowline to a facility. In some embodiments, enhanced oil recovery, with the use of an agent for example steam, water, a surfactant, a polymer flood, and/or a miscible agent such as a carbon disulfide formulation, may be used to increase the flow of oil and/or gas from the formation.
- Any carbon disulfide and/or carbon oxysulfide present in the formation may be converted into another compound while within the formation by any suitable method. The selection of the method to convert the carbon disulfide and/or carbon oxysulfide is not critical. Suitable methods to convert the carbon disulfide and/or carbon oxysulfide include the formation of hydrogen sulfide and oxidation, which are set forth below.
- In one example, the miscible solvent may include a carbon disulfide and/or carbon oxysulfide formulation. The carbon disulfide may be hydrolyzed within the formation into hydrogen sulfide and/or carbon oxysulfide formulation, for example by reaction with water and/or steam. Optionally, one or more catalysts such as alumina and/or titania, for example in a solution, as a powder, or as a suspension in water or other fluids may be introduced into the formation in order to catalyze the reaction from carbon disulfide to hydrogen sulfide.
- The carbon disulfide can be hydrolyzed to hydrogen sulfide and/or carbon oxysulfide by any reaction or mechanism. The selection of the reaction or mechanism is not critical. One suitable mechanism by which the carbon disulfide is hydrolyzed to hydrogen sulfide is a known reaction, which has the formula:
-
CS2+H2O→H2S+COS   (Formula 1) - The carbon disulfide may be hydrolyzed further within the formation into carbon dioxide and hydrogen sulfide, for example by reaction with water or steam.
- The carbon oxysulfide can be hydrolyzed to hydrogen sulfide and carbon dioxide by any reaction or mechanism. The selection of the reaction or mechanism is not critical. One suitable mechanism by which the carbon oxysulfide is hydrolyzed to hydrogen sulfide is a known reaction, which has the formula:
-
COS+H2O→H2S+CO2   (Formula 2) - The hydrogen sulfide may then be recovered from one or more wells. In order to recover the hydrogen sulfide from the formation, water, air, carbon dioxide, or one or more other liquids or gases or remediation agents may be injected into the formation to aid in the recovery of the hydrogen sulfide from a well.
- In one example, the miscible solvent may include an alcohol and/or hydrocarbon such as natural gas, propane, butane, and/or pentane. The miscible solvent may be burned in place within the formation into primarily water and carbon dioxide, for example by the addition of oxygen, steam, peroxides, and/or heat.
- In another example, the miscible solvent may include a carbon disulfide formulation. The carbon disulfide may be combusted or oxidized within the formation into sulfur dioxide and/or carbon dioxide, for example by the addition of oxygen, peroxides, and/or heat.
- The carbon disulfide can be oxidized by any reaction or mechanism. The selection of the reaction or mechanism is not critical. One suitable mechanism by which the carbon disulfide is oxidized to sulfur dioxide is a known reaction, which has the formula:
-
CS2+3O2→2SO2+CO2   (Formula 3) - The sulfur dioxide may then be recovered from one or more wells, or left in place within the formation. In order to recover the sulfur dioxide from the formation, water, air, carbon dioxide, or one or more other liquids or gases or remediation agents may be injected into the formation to aid in the recovery of the sulfur dioxide from a well.
- Referring now to
FIG. 3 a, in one embodiment of the invention,system 200 is illustrated.System 200 includesunderground formation 202,underground formation 204,underground formation 206, andunderground formation 208.Production facility 210 is provided at the surface. Well 212 traversesformations formation 206.Portions 214 offormation 206 may optionally be fractured and/or perforated. Oil and gas fromformation 206 is produced intoportions 214, into well 212, and travels up toproduction facility 210. Production facility may then separate gas, which is sent togas processing 216, and liquid, which is sent toliquid storage 218. Production facility also includes carbondisulfide formulation storage 230. Carbon disulfide, hydrogen sulfide and/or other sulfur containing compounds produced from well 212 may be sent to carbondisulfide formulation production 230. Carbon disulfide, hydrogen sulfide and/or other sulfur containing compounds may be pumped down well 212 that is shown by the down arrow and is pumped intoformation 206, and is then separated and the oil and gas produced back up well 212 toproduction facility 210. - Referring now to
FIGS. 3 b and 3 c, in some embodiments of the invention,system 200 is illustrated.System 200 includesunderground formation 202,underground formation 204,underground formation 206, andunderground formation 208.Production facility 210 is provided at the surface. Well 212 traversesformations formation 206.Portions 214 offormation 206 may be optionally fractured and/or perforated. During primary production, oil and gas fromformation 206 is produced intoportions 214, into well 212, and travels up toproduction facility 210. Production facility then separates gas, which is sent togas processing 216, and liquid, which is sent toliquid storage 218. Production facility also includes carbondisulfide formulation storage 230. Carbon disulfide formulation, hydrogen sulfide and/or other sulfur containing compounds may be separated from oil and/or gas within the formation, before the oil and/or gas is produced into well 212, or after the oil and/or gas is produced into well 212 and to a surface facility. As shown inFIG. 3 b, sulfur containing compound, other liquids, gases, and/or catalysts may be pumped down well 212 that is shown by the down arrow and pumped intoformation 206. Sulfur containing compound formulation may be left to soak in formation for a period of time from about 1 hour to about 15 days, for example from about 5 to about 50 hours, in order to react with hydrocarbons to form a miscible sulfur compound-oil formulation. - After the soaking/reaction period, as shown in
FIG. 3 c, carbon disulfide formulation may be produced with the oil and/or gas, back up well 212 toproduction facility 210. - In some embodiments, sulfur containing compound may be pumped into
formation 206 above the fracture pressure of the formation, for example from about 120% to about 200% of the fracture pressure. - Sulfur containing compound may be pumped into
formation 206 at a temperature from about 200 to about 1000° C., for example from about 400 to about 800° C., or from about 500 to about 700° C. - Sulfur containing compound may be pumped into
formation 206 at a pressure from about 2 to about 200 bars, for example from about 3 to about 100 bars, or from about 5 to about 50 bars. - Referring now to
FIG. 3 d, in some embodiments of the invention,system 300 is illustrated.System 300 includesunderground formation 302,formation 304,formation 306, andformation 308.Production facility 310 is provided at the surface. Well 312 traversesformation formation 306. Portions offormation 314 may be optionally fractured and/or perforated. As oil and gas is produced fromformation 306 it entersportions 314, and travels up well 312 toproduction facility 310. Gas and liquid may be separated, and gas may be sent togas storage 316, and liquid may be sent toliquid storage 318.Production facility 310 is able to store and/or produce carbon disulfide formulation, which may be produced and stored in carbondisulfide formulation production 330. Carbon disulfide formulation, hydrogen sulfide and/or other sulfur containing compounds may be separated from oil and/or gas, after the oil and/or gas is produced to well 312 and to surface facilities. Carbon disulfide formulation may also be optionally recycled back to the formation, or to another formation. - A carbon disulfide and/or a carbon oxysulfide formulation, and optionally other liquids, gases, and/or catalysts may be pumped down well 332, to
portions 334 offormation 306. The carbon disulfide and/or the carbon oxysulfide formulation traversesformation 306 and reacts with one or more hydrocarbons to make a miscible oil mixture with the carbon disulfide and/or carbon oxysulfide formulation, which aids in the production of oil and gas, and then the mixture may be produced to well 312 and toproduction facilities 310, and then the carbon disulfide formulation and oil and/or gas may be separated. Carbon disulfide formulation may then be recycled and reinjected into the formation or to another target formation. - In some embodiments, carbon disulfide formulation or carbon disulfide formulation mixed with other components may be miscible in oil and/or gas in
formation 306. - In some embodiments, carbon disulfide formulation or carbon disulfide formulation mixed with other components may be mixed in with oil and/or gas in
formation 306 to form a miscible mixture. The mixture may then be produced to well 312, then separated. - In some embodiments, carbon disulfide formulation or carbon disulfide formulation mixed with other components may not mix in with oil and/or gas in
formation 306, so that carbon disulfide formulation or carbon disulfide formulation mixed with other components travels as a plug acrossformation 306 to force oil and/or gas to well 312. In some embodiments, a quantity of carbon disulfide formulation or carbon disulfide formulation mixed with other components may be injected into well 332, followed by another component to force carbon disulfide formulation or carbon disulfide formulation mixed with other components acrossformation 306, for example air; water in gas or liquid form; water mixed with one or more salts, polymers, and/or surfactants; carbon dioxide; other gases; other liquids; and/or mixtures thereof. -
FIG. 3 e illustrates the system ofFIG. 3 d at the conclusion of an EOR process. There is a volume of carbon disulfide formulation mixed with oil and/or gas withinunderground formation 302.System 300 may be used to separate and/or convert carbon disulfide formulation withinunderground formation 302. -
System 300 includesunderground formation 302,formation 304,formation 306, andformation 308.Production facility 310 is provided at the surface. Well 312 traversesformation formation 306. Portions offormation 314 may be optionally fractured and/or perforated. - A separating agent may be injected into well 332 and into
formation 306 as shown by the arrows. A separating agent may also be injected intowell portion 332 and out of the bottom ofwell portion 332 as shown by the arrows and intoformation 306. As discussed above, the separating agent may act to separate the oil and/or gas from the carbon disulfide formulation, and/or to raise the temperature and mobility of the oil. Suitable separating agents include steam, water, air, oxygen containing gases, nitrogen, amines, and other liquids and gases known in the art to separate oil/carbon disulfide formulation mixtures. - After the separating agent has been injected for a period of time, separated oil and/or
gas 344 may be produced towell potion 312 as shown by arrows, for example at a point in the well above where the separating agent was injected. In addition, carbon disulfide formulation, separating agent, converted carbon disulfide formulation, and/or a mixture thereof may form alower density blanket 342 above oil and/orgas 344.Blanket 342 may be used to force oil and/orgas 344 towardswell portion 312. - After the oil and/or
gas 344 is produced,blanket 342 may be produced towell portion 312 or left information 306. - In some embodiments, well 312 may be used to inject separating agent for a first time period, and then well 312 may be used to produce oil and/or gas for a second time period. In some embodiments, well 312 may be alternatively cycled between injecting the separating agent and producing oil and/or gas, for example from about 2 to about 100 cycles, for example from about 5 to about 10 cycles.
- Referring now to
FIG. 4 , in some embodiments of the invention, carbondisulfide formulation production 430 is illustrated. Carbondisulfide formulation production 430 has an input of hydrogen sulfide and/or other sulfur containing compounds. Hydrogen sulfide may be converted into sulfur dioxide byoxidation reaction 432. Hydrogen sulfide and sulfur dioxide may be converted to sulfur at 434. Sulfur may be combined with a carbon compound to produce carbon disulfide formulation at 436. The carbon disulfide formulation and hydrogen sulfide produced at 436 may be the output. Carbon disulfide formulation and/or a carbon disulfide formulation containing mixture may be the output from carbondisulfide formulation production 430. - In some embodiments, carbon disulfide derived salts can be dissolved in water, and the resulting solution pumped into
formations 206 and/or 306. The dissolved carbon disulfide formulations may decompose, yielding carbon disulfide informations 206 and/or 306. - In some embodiments of the invention, gas and liquid produced from well 212 and/or 312 may be separated, for example with a gravity separator or a centrifuge, or with other methods known in the art. The gas portion may be sent to carbon
disulfide formulation production 230 and/or 330. - In some embodiments of the invention, all of the components of
system 200 and/orsystem 300 may be within about 10 km of each other, for example about 5, 3, or 1 km. - In some embodiments, oil and/or gas produced from well 212 and/or 312 may be transported to a refinery and/or a treatment facility. The oil and/or gas may be processed to produced to produce commercial products such as transportation fuels such as gasoline and diesel, heating fuel, lubricants, chemicals, and/or polymers. Processing may include distilling and/or fractionally distilling the oil and/or gas to produce one or more distillate fractions. In some embodiments, the oil and/or gas, and/or the one or more distillate fractions may be subjected to a process of one or more of the following: catalytic cracking, hydrocracking, hydrotreating, coking, thermal cracking, distilling, reforming, polymerization, isomerization, alkylation, blending, and dewaxing.
- It is to be appreciated that any of the embodiments to complete
Step 1 may be combined with any of the embodiments to completeStep 2, which may be combined with any of the embodiments to completeStep 3. - The selection of a method to complete any of Steps 1-3 is not critical.
- In one embodiment of the invention, there is disclosed a system for producing oil and/or gas comprising a formation comprising a mixture of oil and/or gas and a carbon disulfide formulation and/or a carbon oxysulfide formulation; a mechanism for releasing a separating agent into the formation, the separating agent adapted to separate the oil and/or gas from the carbon disulfide formulation and/or the carbon oxysulfide formulation. In some embodiments, the system also includes a mechanism for recovering the oil and/or gas from the formation. In some embodiments, the mechanism for recovering comprises a well in the underground formation and a recovery facility at a topside of the well. In some embodiments, the mechanism for recovering comprises a first well drilled in the underground formation for recovering the oil and/or gas, and a production facility at a topside of the first well; and the mechanism for releasing the separating agent comprises a second well in the underground formation for releasing the separating agent into the formation. In some embodiments, the mechanism for recovering comprises a first well drilled in the underground formation for recovering the oil and/or gas, and a production facility at a topside of the first well; and the mechanism for releasing the separating agent comprises the first well in the underground formation for releasing the separating agent into the formation. In some embodiments, the the first well comprises a first portion for recovering the oil and/or gas, and a second portion for releasing the separating agent. In some embodiments, the first well is used for releasing the separating agent for a first time period, and then used for recovering the oil and/or gas for a second time period. In some embodiments, the system also includes a heater within the formation adapted to heat at least one of the separating agent, oil, and/or gas. In some embodiments, the system also includes a mechanism adapted to convert the carbon disulfide formulation and/or the carbon oxysulfide formulation into another compound within the formation. In some embodiments, the mechanism to convert comprises a mechanism to produce hydrogen sulfide and/or a mechanism to oxidize. In some embodiments, the separating agent is selected from the group of air, oxygen, oxygen containing gases, nitrogen, amines, steam, water, and mixtures thereof.
- In one embodiment of the invention, there is disclosed a method for producing oil and/or gas comprising providing a formation comprising a mixture of oil and/or gas and a carbon disulfide formulation and/or a carbon oxysulfide formulation; releasing a separating agent into a formation; and separating the oil and/or gas from the carbon disulfide formulation and/or the carbon oxysulfide formulation. In some embodiments, the method also includes recovering oil and/or gas from the underground formation. In some embodiments, the recovering is done from a first well and the releasing the separating agent is done from the first well. In some embodiments, the recovering is done from a first well and the releasing the separating agent is done from a second well. In some embodiments, the recovering is done from a higher point in the formation, and the releasing the separating agent is done from a lower point in the formation. In some embodiments, the method also includes heating the separating agent prior to injecting the separating agent into the formation, or while within the formation. In some embodiments, the method also includes converting the carbon disulfide formulation and/or a carbon oxysulfide formulation into another compound within the formation. In some embodiments, the method also includes converting at least a portion of a recovered oil and/or gas from the formation into a material selected from the group consisting of transportation fuels such as gasoline and diesel, heating fuel, lubricants, chemicals, and/or polymers.
- Those of skill in the art will appreciate that many modifications and variations are possible in terms of the disclosed embodiments of the invention, configurations, materials and methods without departing from their spirit and scope. Accordingly, the scope of the claims appended hereafter and their functional equivalents should not be limited by particular embodiments described and illustrated herein, as these are merely exemplary in nature.
Claims (19)
1. A system for producing oil and/or gas comprising:
a formation comprising a mixture of oil and/or gas and a carbon disulfide formulation and/or a carbon oxysulfide formulation;
a mechanism for releasing a separating agent into the formation, the separating agent adapted to separate the oil and/or gas from the carbon disulfide formulation and/or the carbon oxysulfide formulation.
2. The system of claim 1 , further comprising a mechanism for recovering the oil and/or gas from the formation.
3. The system of claim 2 , wherein the mechanism for recovering comprises a well in the underground formation and a recovery facility at a topside of the well.
4. The system of claim 2 ,
wherein the mechanism for recovering comprises a first well drilled in the underground formation for recovering the oil and/or gas, and a production facility at a topside of the first well; and
wherein the mechanism for releasing the separating agent comprises a second well in the underground formation for releasing the separating agent into the formation.
5. The system of claim 2 ,
wherein the mechanism for recovering comprises a first well drilled in the underground formation for recovering the oil and/or gas, and a production facility at a topside of the first well; and
wherein the mechanism for releasing the separating agent comprises the first well in the underground formation for releasing the separating agent into the formation.
6. The system of claim 5 , wherein the first well comprises a first portion for recovering the oil and/or gas, and a second portion for releasing the separating agent.
7. The system of claim 5 , wherein the first well is used for releasing the separating agent for a first time period, and then used for recovering the oil and/or gas for a second time period.
8. The system of claim 1 , further comprising a heater within the formation adapted to heat at least one of the separating agent, oil, and/or gas.
9. The system of claim 1 , further comprising a mechanism adapted to convert the carbon disulfide formulation and/or the carbon oxysulfide formulation into another compound within the formation.
10. The system of claim 9 , wherein the mechanism to convert comprises a mechanism to produce hydrogen sulfide and/or a mechanism to oxidize.
11. The system of claim 1 , wherein the separating agent is selected from the group of air, oxygen, oxygen containing gases, nitrogen, amines, steam, water, and mixtures thereof.
12. A method for producing oil and/or gas comprising:
providing a formation comprising a mixture of oil and/or gas and a carbon disulfide formulation and/or a carbon oxysulfide formulation;
releasing a separating agent into a formation; and
separating the oil and/or gas from the carbon disulfide formulation and/or the carbon oxysulfide formulation.
13. The method of claim 12 , further comprising recovering oil and/or gas from the underground formation.
14. The method of claim 13 , wherein the recovering is done from a first well and the releasing the separating agent is done from the first well.
15. The method of claim 13 , wherein the recovering is done from a first well and the releasing the separating agent is done from a second well.
16. The method of claim 13 , wherein the recovering is done from a higher point in the formation, and the releasing the separating agent is done from a lower point in the formation.
17. The methods of claim 12 , further comprising heating the separating agent prior to injecting the separating agent into the formation, or while within the formation.
18. The method of claim 12 , further comprising converting the carbon disulfide formulation and/or a carbon oxysulfide formulation into another compound within the formation.
19. The method of claim 13 , further comprising converting at least a portion of a recovered oil and/or gas from the formation into a material selected from the group consisting of transportation fuels such as gasoline and diesel, heating fuel, lubricants, chemicals, and/or polymers.
Priority Applications (1)
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US12/937,966 US20110094750A1 (en) | 2008-04-16 | 2009-04-14 | Systems and methods for producing oil and/or gas |
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Application Number | Priority Date | Filing Date | Title |
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US4534608P | 2008-04-16 | 2008-04-16 | |
PCT/US2009/040478 WO2009129219A2 (en) | 2008-04-16 | 2009-04-14 | Systems and methods for producing oil and/or gas |
US12/937,966 US20110094750A1 (en) | 2008-04-16 | 2009-04-14 | Systems and methods for producing oil and/or gas |
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CN (1) | CN102027194B (en) |
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EP2867455A4 (en) * | 2012-06-27 | 2016-04-06 | Shell Int Research | Petroleum recovery process and system |
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RU2525406C2 (en) | 2014-08-10 |
CN102027194B (en) | 2015-04-01 |
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CN102027194A (en) | 2011-04-20 |
CA2721264A1 (en) | 2009-10-22 |
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