CN102046918A - Methods for generation of subsurface heat for treatment of a hydrocarbon containing formation - Google Patents
Methods for generation of subsurface heat for treatment of a hydrocarbon containing formation Download PDFInfo
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- CN102046918A CN102046918A CN2009801202510A CN200980120251A CN102046918A CN 102046918 A CN102046918 A CN 102046918A CN 2009801202510 A CN2009801202510 A CN 2009801202510A CN 200980120251 A CN200980120251 A CN 200980120251A CN 102046918 A CN102046918 A CN 102046918A
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- hydrocarbon
- hydrogen sulfide
- steam
- combustion
- heat
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- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 197
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 196
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- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 112
- 238000000034 method Methods 0.000 title claims abstract description 70
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims abstract description 121
- 229910000037 hydrogen sulfide Inorganic materials 0.000 claims abstract description 119
- 239000012530 fluid Substances 0.000 claims abstract description 96
- 239000007800 oxidant agent Substances 0.000 claims abstract description 86
- 230000001590 oxidative effect Effects 0.000 claims abstract description 86
- 239000000203 mixture Substances 0.000 claims abstract description 82
- 238000010793 Steam injection (oil industry) Methods 0.000 claims abstract description 12
- 238000002485 combustion reaction Methods 0.000 claims description 92
- RAHZWNYVWXNFOC-UHFFFAOYSA-N Sulphur dioxide Chemical compound O=S=O RAHZWNYVWXNFOC-UHFFFAOYSA-N 0.000 claims description 50
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 41
- 229910001868 water Inorganic materials 0.000 claims description 41
- 239000006227 byproduct Substances 0.000 claims description 38
- 238000010438 heat treatment Methods 0.000 claims description 27
- AKEJUJNQAAGONA-UHFFFAOYSA-N sulfur trioxide Chemical compound O=S(=O)=O AKEJUJNQAAGONA-UHFFFAOYSA-N 0.000 claims description 16
- 238000004090 dissolution Methods 0.000 claims description 8
- 238000007614 solvation Methods 0.000 claims description 6
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- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 9
- 239000001257 hydrogen Substances 0.000 description 9
- 238000009434 installation Methods 0.000 description 9
- 238000000926 separation method Methods 0.000 description 9
- 238000002347 injection Methods 0.000 description 8
- 239000007924 injection Substances 0.000 description 8
- 239000002904 solvent Substances 0.000 description 8
- 239000005864 Sulphur Substances 0.000 description 7
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- 238000012545 processing Methods 0.000 description 7
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- 238000012546 transfer Methods 0.000 description 7
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- 230000005540 biological transmission Effects 0.000 description 5
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- 238000010168 coupling process Methods 0.000 description 5
- 238000005859 coupling reaction Methods 0.000 description 5
- 229910052757 nitrogen Inorganic materials 0.000 description 5
- 239000003921 oil Substances 0.000 description 5
- 150000002898 organic sulfur compounds Chemical class 0.000 description 5
- 230000008569 process Effects 0.000 description 5
- 229910052717 sulfur Inorganic materials 0.000 description 5
- 239000011593 sulfur Substances 0.000 description 5
- 238000011144 upstream manufacturing Methods 0.000 description 5
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- -1 sulphur compound Chemical class 0.000 description 4
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 description 3
- MWUXSHHQAYIFBG-UHFFFAOYSA-N Nitric oxide Chemical compound O=[N] MWUXSHHQAYIFBG-UHFFFAOYSA-N 0.000 description 3
- YTPLMLYBLZKORZ-UHFFFAOYSA-N Thiophene Chemical compound C=1C=CSC=1 YTPLMLYBLZKORZ-UHFFFAOYSA-N 0.000 description 3
- 239000000295 fuel oil Substances 0.000 description 3
- 150000002431 hydrogen Chemical class 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 229910052751 metal Inorganic materials 0.000 description 3
- 239000003345 natural gas Substances 0.000 description 3
- QGZKDVFQNNGYKY-UHFFFAOYSA-N Ammonia Chemical compound N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 2
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 2
- LCGLNKUTAGEVQW-UHFFFAOYSA-N Dimethyl ether Chemical compound COC LCGLNKUTAGEVQW-UHFFFAOYSA-N 0.000 description 2
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- LSDPWZHWYPCBBB-UHFFFAOYSA-N Methanethiol Chemical compound SC LSDPWZHWYPCBBB-UHFFFAOYSA-N 0.000 description 2
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- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 2
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- JCVAWLVWQDNEGS-UHFFFAOYSA-N 1-(2-hydroxypropylamino)propan-2-ol;thiolane 1,1-dioxide;hydrate Chemical compound O.O=S1(=O)CCCC1.CC(O)CNCC(C)O JCVAWLVWQDNEGS-UHFFFAOYSA-N 0.000 description 1
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 description 1
- 229910000975 Carbon steel Inorganic materials 0.000 description 1
- 235000008733 Citrus aurantifolia Nutrition 0.000 description 1
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 1
- 244000287680 Garcinia dulcis Species 0.000 description 1
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- 240000007594 Oryza sativa Species 0.000 description 1
- 235000007164 Oryza sativa Nutrition 0.000 description 1
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 description 1
- 235000011941 Tilia x europaea Nutrition 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 150000001412 amines Chemical class 0.000 description 1
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- 239000003795 chemical substances by application Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
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- 125000000753 cycloalkyl group Chemical group 0.000 description 1
- ZBCBWPMODOFKDW-UHFFFAOYSA-N diethanolamine Chemical compound OCCNCCO ZBCBWPMODOFKDW-UHFFFAOYSA-N 0.000 description 1
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- 229910052736 halogen Inorganic materials 0.000 description 1
- 150000002367 halogens Chemical class 0.000 description 1
- 229910000856 hastalloy Inorganic materials 0.000 description 1
- 125000004435 hydrogen atom Chemical group [H]* 0.000 description 1
- 230000008676 import Effects 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- 239000004571 lime Substances 0.000 description 1
- 239000006028 limestone Substances 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 230000014759 maintenance of location Effects 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
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- 229910052759 nickel Inorganic materials 0.000 description 1
- 229910017464 nitrogen compound Inorganic materials 0.000 description 1
- 150000002830 nitrogen compounds Chemical class 0.000 description 1
- 239000004058 oil shale Substances 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 150000002894 organic compounds Chemical class 0.000 description 1
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- 125000004646 sulfenyl group Chemical group S(*)* 0.000 description 1
- HXJUTPCZVOIRIF-UHFFFAOYSA-N sulfolane Chemical compound O=S1(=O)CCCC1 HXJUTPCZVOIRIF-UHFFFAOYSA-N 0.000 description 1
- 238000003786 synthesis reaction Methods 0.000 description 1
- 229910052720 vanadium Inorganic materials 0.000 description 1
- GPPXJZIENCGNKB-UHFFFAOYSA-N vanadium Chemical compound [V]#[V] GPPXJZIENCGNKB-UHFFFAOYSA-N 0.000 description 1
- 239000011787 zinc oxide Substances 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/30—Specific pattern of wells, e.g. optimising the spacing of wells
- E21B43/305—Specific pattern of wells, e.g. optimising the spacing of wells comprising at least one inclined or horizontal well
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/02—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using burners
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/2406—Steam assisted gravity drainage [SAGD]
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/2406—Steam assisted gravity drainage [SAGD]
- E21B43/2408—SAGD in combination with other methods
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/243—Combustion in situ
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
Methods of generating subsurface heat for treatment of a hydrocarbon containing formation are described herein. Steam is provided to at least a portion of a hydrocarbon containing formation from a plurality of substantially horizontal steam injection wells. A mixture comprising hydrogen sulfide and an oxidant is combusted in one or more flameless distributed combustors positioned in one or more substantially vertical wellbores to generate heat. At least one of the substantially vertical wellbores is within ten meters of an end of at least one of the substantially horizontal steam injection wells, and at least a portion of the generated heat is transferred to a portion of the hydrocarbon containing formation located between at least one of the substantially horizontal steam injection wells and at least one of the substantially vertical heater wells to mobilize formation fluids for recovery.
Description
The application requires the priority at the U.S. Provisional Application 61/046172 of application on April 18th, 2008, and this application is incorporated herein by reference in full at this.
Technical field
The present invention relates to handle the method for hydrocarbon containing formation.
Background technology
The hydrocarbon that is obtained by subsurface formations is used as the energy, raw material and the consumer goods usually.Worry to obtainable hydrocarbon resource exhaustion has caused developing the more effective method of gathering, handling and/or utilize obtainable hydrocarbon resource.
Can be by several different methods processing hydrocarbons stratum to produce formation fluid.For example, heat, gas and/or liquid are used to move and/or to produce formation fluid in the hydrocarbon stratum, this method has been used for more effectively from hydrocarbon stratum recovery of hydrocarbons.The heat treatment method heating can be used in the hydrocarbon stratum (for example Tar sands or oil shale formation) that contains heavy hydrocarbon, with more effectively from containing the stratum recovery of hydrocarbons of heavy hydrocarbon.This method comprises situ heat treatment system, burning section and driving method.Usually the hydrocarbon of the using driving method of gathering comprises cyclic steam injections, steam assisted gravity oil extraction (SAGD), solvent injection, vapor solvent and SAGD and carbon dioxide injection, but is not limited to this.
The application of heat device produces high permeability area (or injection zone) in the hydrocarbon stratum in hydrocarbon is gathered driving method.Can in the hydrocarbon stratum, produce moving area or produce network by the application of heat device, so that fluid flows through the stratum in the driving process.For example, heater can be used for: produce the oil drain passage that is used for driving method between injection well and producing well; The preheated hydrocarbon stratum so that fluid in the stratum, move, thereby make fluid and/or gas can be injected in the stratum; For fluid and/or the gas that is used for driving method in the hydrocarbon stratum provides heat.Usually, with respect to the heat of driving method input, the heat that is provided by described heater is very little.
Use the burning of fossil fuel and heated the stratum, for example, in the stratum, directly injected the combustion of fossil fuel gas of heat; (for example in the burning section) combustion of fossil fuels in the stratum; Pass to other heat transfer medium such as steam from the combustion of fossil fuel gas heat of heat; Or application is arranged in the heater on hydrocarbon stratum.Combustion of fossil fuels heating stratum can be in the stratum, in the well and/or implement near the ground.Combustion of fossil fuels will produce carbon dioxide (a kind of undesirable greenhouse gases) as combustion by-products.
The burning of sulphur compound also has been used for the heat hydrocarbon stratum, and wherein the combustion product of sulfur-bearing can be used for more effectively producing hydrocarbon by the hydrocarbon stratum as drive fluid.The US4 of Rollmann, 379,489 described a kind of from the gather method of heavy oil of underground storage layer, described method be included in underground in oxygen-containing gas combustion of liquid sulphur, thereby form sulfur dioxide.Sulfur dioxide can perhaps can react with the formation carbon dioxide with limestone in the stratum, and carbon dioxide be a kind of alternative drive fluid as the drive fluid of recovery of oil.The pressure of oxygen-containing gas maintains is enough to make sulfur dioxide to remain under the liquid pressure.
Wish to have a kind of under the situation that does not produce great amount of carbon dioxide effectively, the effective processing hydrocarbons of cost stratum is with the method for recovery of hydrocarbons from the hydrocarbon stratum more effectively.
Summary of the invention
The present invention relates to the method on a kind of processing hydrocarbons stratum, comprise that the steam injection well by a plurality of basic horizontal provides steam at least a portion hydrocarbon containing formation; The mixture that comprises hydrogen sulfide and oxidant in the one or more flameless distributed combustors burning at least a portion that are arranged in one or more basic vertical well bore to be to produce heat, and wherein at least one basic vertical well bore steam of being at least one basic horizontal injects in ten meters at the well terminal; The heat that at least a portion produced passed at the steam of at least one basic horizontal inject a part of hydrocarbon containing formation between well and the heater well that at least one is vertical substantially; With at least a portion formation fluid that moves in the hydrocarbon containing formation part of heating.
Description of drawings
For a person skilled in the art, further advantage of the present invention will become clearly to detailed description of the preferred embodiments and with reference to appended accompanying drawing by means of following, wherein:
Fig. 1 has described the schematic diagram of steam drive method.
Fig. 2 has described the schematic diagram of handling the embodiment of the formation fluid that originates from the hydrocarbon stratum.
It is the sectional drawing of a part of embodiment of the flameless distributed combustor of fuel with hydrogen sulfide that Fig. 3 has described what be positioned at vertical borehole.
It is the sectional drawing of a part of embodiment of the flameless distributed combustor of fuel with hydrogen sulfide that Fig. 4 has described what have two fuel channels.
It is the sectional drawing of a part of embodiment of the flameless distributed combustor of fuel with hydrogen sulfide that Fig. 5 has described what have three fuel channels.
Fig. 6 described be arranged in vertical borehole what have incendiary source is the sectional drawing of a part of embodiment of the flameless distributed combustor of fuel with hydrogen sulfide.
It is the sectional drawing of a part of embodiment of the burner of fuel with hydrogen sulfide that Fig. 7 has described what be arranged in horizontal wellbore.
Fig. 8 has described and has injected well group with horizontal steam to close apply perpendicular be that the heater of fuel is produced the schematic diagram of the embodiment of hydrocarbon with hydrogen sulfide.
Though the present invention allows various modifications and alternative form, its specific embodiment provides by the mode of the embodiment among the figure.Accompanying drawing may not be pro rata.But should be appreciated that these figure and be not used in the present invention is defined in particular forms disclosed that on the contrary, the present invention will cover by the essence of the present invention of claims definition and all modifications, equivalent and the alternative in the scope.
The specific embodiment
The present invention relates to the hydrocarbon stratum provides underground heat, wherein said heat is produced by following method: the mixture that 1) comprises hydrogen sulfide and oxidant in the one or more flameless distributed combustor burning at least a portion that are arranged in one or more basic vertical well bore; With 2) steam of one or more basic horizontal injects well that steam is provided.The heat that offers the hydrocarbon stratum moves at least a portion formation fluid in the hydrocarbon containing formation part of heating.Because fuel stream is a sulfenyl, avoided the generation of carbon dioxide during the burning of the sulfide composition of fuel stream, therefore for the method for using the fuel stream that mainly comprises hydrocarbon, reduced the total CO 2 output of heating means.
Offer the hydrocarbon stratum owing to will comprise the heat that the fuel stream burning of hydrogen sulfide produces and the heat of steam, the inventive method provides heat for the hydrocarbon stratum effectively.Be oppositely arranged the vertical borehole that the combustion heat therefrom is provided owing to inject well, make the heat that offers the hydrocarbon stratum by the fuel stream burning that comprises hydrogen sulfide can strengthen and inject moving of the formation fluid that causes by steam with respect to steam.The heat that the mixture burns with hydrogen sulfide and oxidant produces that is provided with that the steam of basic horizontal injects well and basic vertical well bore is offering the hydrocarbon stratum at a part of hydrocarbon containing formation place that the steam at least one basic horizontal injects between well and at least one the basic vertical well bore.The heat that offers hydrocarbon ground layer for heating part moves the formation fluid of hydrocarbon ground layer for heating part, and can increase by producing well and gathered by the hydrocarbon stratum and the amount of the formation fluid of output.
The method that produces sulfuric acid by the combustion process oxidation of sulfureted hydrogen can produce the calorific value that is similar to methyl hydride combustion.For example use people such as Stull at " The Chemical Thermodynamics of Organic Compounds ", Kreiger Publishing Company, Malabar Florida, 1987,220th, the data in 229,230,233 and 234 pages can be calculated the reaction enthalpy of methane and sulfureted hydrogen burning.Methyl hydride combustion produces the accessory substance carbon dioxide, represents by following reaction equation:
CH
4+2O
2→CO
2+2H
2O(ΔH
rxn＝-191.2kcal/mol?600°K).
Compare with it, hydrogen sulfide oxidation (burning) forms sulfuric acid and has the calculating reaction enthalpy of representing by following reaction equation:
H
2S+2O
2→H
2SO
4(ΔH
rxn＝-185.4kcal/mol?600°K).
In water, mix sulfuric acid owing to the dissolution heat of sulfuric acid in water produces more heat, be expressed from the next:
H
2SO
4+H
2O→50wt％H
2SO
4(ΔH
dil＝-14.2kcal/mol?298°K).
Depend on to produce the applied water yield of sulfuric acid, the total amount of the heat that sulfureted hydrogen burning and sulfuric acid dissolution produce can for-185kcal/mol to-206kcal/mol.Therefore, according to the inventive method, hydrogen sulfide replaces methane to do fuel combustion provides heat for the hydrocarbon stratum, and the heat that provides can be suitable with methyl hydride combustion, but do not produce carbon dioxide.In addition, use hydrogen sulfide containing fuel in the methods of the invention the method for a kind of processing from the useless hydrogen sulfide of other process (for example the thing logistics is flowed out in acid gas and/or hydrotreatment) is provided, but do not produce elementary sulfur.
Here applied term definition is as follows:
" api gravity " refers to the api gravity under 15.5 ℃ (60 ℉).Api gravity is measured by ASTM method D6822 or ASTM method D1298.
" ASTM " refers to Unite States Standard test and material (American Standard Testing and Materials).
" stratum " comprises one or more layers hydrocarbon bearing formation, one or more layers nonhydrocarbon layer, superstratum and/or underlying strata." hydrocarbon layer " refers to contain the layer of hydrocarbon in the stratum.The hydrocarbon layer can contain non-hydrocarbon material and hydrocarbon material." superstratum " and/or " underlying strata " comprises the impermeable material of one or more dissimilar hydrocarbon.In some cases, superstratum and/or underlying strata may be permeable slightly to the hydrocarbon material.
" formation fluid " refers to the fluid that exists and can comprise Pintsch process fluid, synthesis gas, mobile hydrocarbon and water (steam) in the stratum.Formation fluid can comprise hydrocarbon fluid and non-hydrocarbon fluids.Term " streaming flow " refers to handle the fluid that can flow because of the stratum in the hydrocarbon containing formation." fluid of generation " refers to the fluid that removes from the stratum.
" heater " is near any system or the thermal source that produces heat in well or the well bore region.Heater can for electric heater, burner, with the stratum in material or burner that reacts by the material that produces in the stratum and/or their combination, but be not limited to this." flameless distributed combustor " refers to the heater of basic nonflame, and wherein oxidant stream and fuel stream are mixed together at least a portion distribution length at heater being equal to or higher than under the auto-ignition temperature of mixture.
" heavy hydrocarbon " is the hydrocarbon fluid of thickness.Heavy hydrocarbon can comprise very hydrocarbon fluid such as heavy oil, tar and/or the pitch of thickness.Heavy hydrocarbon can comprise sulfur-bearing, oxygen and the nitrogen compound of carbon and hydrogen and low concentration.In heavy hydrocarbon, also may there be additional element (for example nickel, iron, vanadium or their mixture).Heavy hydrocarbon can be classified by api gravity.The api gravity of heavy hydrocarbon is usually less than about 20.For example, the api gravity of heavy oil is generally about 10-20, and the api gravity of tar is usually less than about 10.The viscosity of heavy hydrocarbon is generally at least 100 centipoises under 15 ℃.Heavy hydrocarbon can comprise aromatic hydrocarbons or other complicated cyclic hydrocarbon.
" hydrocarbon " is commonly defined as the molecule that is mainly formed by carbon and hydrogen atom.Here applied hydrocarbon can also comprise metallic element and/or other compound including but not limited to halogen, nitrogen, oxygen and/or sulphur.The hydrocarbon compound that contains sulphur is called as " organosulfur compound ".Hydrocarbon can be kerogen, pitch, pyrobitumen, oil, natural mineral wax and asphalitine, but is not limited to this.Hydrocarbon can be positioned at underground mineral substrate or near.Matrix can include but not limited to sedimentary rock, sandstone, silicilyte, carbonate, kieselguhr and other porous media." hydrocarbon fluid " refers to comprise the fluid of hydrocarbon.Hydrocarbon fluid can comprise, carry non-hydrocarbon fluids secretly or be trapped in the non-hydrocarbon fluids, as hydrogen, nitrogen, carbon monoxide, carbon dioxide, hydrogen sulfide, oxysulfide, cos, nitrogen oxide, water, ammonia or their mixture.
" oxidant " refers to be suitable for to support the compound that burns.The example of oxidant comprises air, oxygen and/or oxygen-enriched air." oxygen-enriched air " refers to the mole fraction of the mole fraction of oxygen in the air greater than oxygen in the air under the normal pressure.Air is usually by the ability of enrichment with the increase air, supports combustion.
" SAGD " refers to the gravity oil extraction that steam is auxiliary.
" tar " be a kind of 15 ℃ of following viscosity usually greater than the viscous hydrocarbon of about 10,000 centipoises.The proportion of tar is usually greater than 1.000.The api gravity of tar may be less than 10.
" tar sand formation " refers to that hydrocarbon wherein is mainly to be entrained in the stratum that heavy hydrocarbon in mineral grain structure or other host's rock (as sand or carbonate) and/or tar form exist.The example of tar sand formation comprises Athabasca stratum, Grosmont stratum and Peace stratum, and above three is all in Canadian Alberta; With the Faja stratum in the Venezuela Orinoco band.
" water " refers to the liquid and gas of water.For example water, water vapour and superheated steam.
In the method for the invention, steam is offered at least a portion hydrocarbon stratum.The hydrocarbon stratum comprises the hydrocarbon material and can comprise non-hydrocarbon material, and wherein the hydrocarbon material can be gathered by the hydrocarbon stratum.The hydrocarbon stratum can comprise impermeable or permeable slightly superstratum and underlying strata to hydrocarbon.
Provide steam to the hydrocarbon stratum, thereby can increase the hydrocarbon quantity of material of gathering by the hydrocarbon stratum.Thereby the steam that offers the hydrocarbon stratum can the heat hydrocarbon stratum and the formation fluid that comprises the hydrocarbon material is moved, and wherein the formation fluid of Yi Donging can be gathered and output from the hydrocarbon stratum by producing well.Steam also can replace in the hydrocarbon stratum formation fluid and drivingly layer fluid enter producing well, thereby can from producing well, gather and the output formation fluid.
In an embodiment of the inventive method, can be in driving method steam be offered the hydrocarbon stratum, thus the processing hydrocarbons stratum.Described driving method comprises that cyclic steam injection, SAGD, solvent inject or vapor solvent and SAGD method, but be not limited to this.Method of the present invention also can be used for the hydrocarbon stratum that preheating is used for driving method, perhaps be used for during driving method or provide afterwards heat.
Fig. 1 has described the schematic diagram that wherein can use the steam drive method of the inventive method.Steam 100 enters and injects well 102.Inject well 102 and can comprise opening 104, flow into and/or be pressed into hydrocarbon layer 106 to allow steam 100.Steam 100 provides heat for the formation fluid in the hydrocarbon layer 106.Layer fluid layer fluid movably heatedly, thus promote formation fluid to being positioned at producing well 108 dischargings of injecting well 102 belows.Formation fluid 110 originates from producing well 108 and is transported to one or more treatment facilities.
Steam injection well by a plurality of (at least two) basic horizontal offers the hydrocarbon stratum with steam.Steam injects the position of well preferably with respect to one or more producing wells, thereby is moved and/or drives and flow to producing well by inject formation fluid that the well steam in jection moves and/or drive at steam, thereby can be gathered and the output formation fluid by producing well.Most preferably, steam injects well location in the position with respect to one or more producing wells and one or more basic vertical well bore, thereby optimize the formation fluid amount gather from the hydrocarbon stratum, wherein burning comprises the mixture of hydrogen sulfide and oxidant in described basic vertical well bore.Just as used herein, " basic horizontal " well or wellhole refer in the hydrocarbon stratum one or more vertical substantially wells or wellhole place or near, for example in 20 meters, and preferred in the vertical substantially well or the end of wellhole, the angle of slope is 30 ° or lower or 15 ° or lower or 10 ° or lower well or wellhole.The well of basic horizontal or wellhole can have the angle of slope greater than 30 ° well or wellhole part, and can be vertical or near vertical.For example, the well of basic horizontal or wellhole can hydrocarbon surface of stratum place or near have vertical substantially part, but, wherein comprise the mixture of hydrogen sulfide and oxidant in described basic vertical well bore internal combustion near the part that basic vertical well bore, has basic horizontal in the hydrocarbon stratum.
The temperature of steam that offers hydrocarbon containing formation is preferably than higher to the temperature of the hydrocarbon containing formation that steam wherein is provided.It is that the injection well by basic horizontal offers hydrocarbon containing formation under the 1-15MPa with pressure limit that steam can be 100-500 ℃ or 110 ℃-290 ℃ in temperature.
Can be before offering the hydrocarbon stratum with water or Steam Heating by steam injection well.Inject before well is used to inject the hydrocarbon stratum offering steam, water/steam can be in the heating of hydrocarbon surface of stratum place, and/or can be by the one or more heaters underground heating in one or more wellholes that provides in one or more wellholes.
The heat of transmitting fuel stream and oxidant burning generation by water/steam can add hot water/steam at the hydrocarbon surface of stratum.Fuel stream can be hydrocarbon containing fuels such as natural gas, and/or fuel stream can be for comprising the fuel stream of hydrogen sulfide.Oxidant can be air, compressed air, oxygen-enriched air or oxygen.Fuel stream and oxidant can burn in the combustion reactor of routine, and the heat transmission feedwater/steam that will burn and produce by the interchange of heat between combustion by-products gas and water/steam.
Before offering the hydrocarbon stratum, water/steam can underground heating in one or more wellholes.Can in one or more wellholes, provide one or more heaters, be used for before steam is offered the hydrocarbon stratum, adding hot water/steam in one or more wellholes.By near the heating steam location point that steam is offered the hydrocarbon stratum, the underground heating of water/steam makes the heat of steam more effectively pass to the hydrocarbon stratum.In one embodiment, one or more heaters that fuel stream and oxidant stream inject wellholes at one or more steam burn and before steam is offered the hydrocarbon stratum, the heat transmission feedwater/steam of the generation of will burn in wellhole.Fuel stream can be hydrocarbon containing fuels such as natural gas, and/or fuel stream can comprise hydrogen sulfide.Oxidant can be air, compressed air, oxygen-enriched air and/or oxygen.In wellhole,, water/steam can be flameless distributed combustor or burner for providing the heater of heat.
In some embodiments, the steam that one or more heaters can be placed on one or more basic horizontal injects the interior section of wellhole of well and the exterior section that steam can flow through described position wellhole, thereby heat can pass to steam from heater.Heater can be positioned at the inner passage with the external channel coupling.Two passages all can be positioned in the wellhole.Described passage can be arranged side by side.It should be understood that and by imagination and to wish to use any amount and/or envision the pipeline of constructing.
Fuel can be offered the one or more fuel channels in one or more heaters that the steam of one or more basic horizontal injects into well.The fuel stream and the oxidant that are used for heater can offer the interior one or more fuel channels of at least one heater, are used for the burning of heater.The fuel channel of can arranging, thus at least a portion fuel is introduced in the upstream portion of at least one heater and the downstream part that at least a portion fuel stream is introduced at least one heater.Fuel can be offered the one or more fuel channels at least one heater, wherein at least one pipeline can be regulated, thereby at least a portion fuel is transported to the first of heater and is delivered to the second portion of the heater in first downstream then.
Steam injection well by a plurality of basic horizontal offers the hydrocarbon stratum with steam.Steam can offer the hydrocarbon stratum under certain pressure, thereby steam can be injected the hydrocarbon stratum.Steam in jection can move formation fluid by layer fluid drivingly.Preferably, the steam that offers the hydrocarbon stratum offers the hydrocarbon stratum under the temperature higher than hydrocarbon formation temperature, thereby heat can be passed to the hydrocarbon stratum by steam.Offer the heat on the hydrocarbon stratum formation fluid in can mobile hydrocarbon stratum by steam.
The steam of a plurality of basic horizontal by entering hydrocarbon containing formation inject well to the hydrocarbon stratum provide steam to move or drivingly layer fluid to producing well.Steam can contact with formation fluid and mix, makes partially the layer fluid solvation and/or dissolve a part of hydrocarbon with layer fluid partially.The viscosity that steam and contacting of formation fluid can be reduced formation fluid and impel formation fluid to move to one or more producing wells.
In the method for the invention, comprise the mixture of hydrogen sulfide and oxidant to produce heat in the one or more flameless distributed combustor burnings that are arranged in one or more basic vertical well bore.The steam that one or more basic vertical well bore are arranged at least one basic horizontal injects in ten meters at the terminal of well.Most preferably, inject well with respect to the steam of one or more producing wells and one or more basic horizontal the basic vertical well bore that mixture burns therein is set, so that the formation fluid amount optimization of gathering from the hydrocarbon stratum.Just as used herein, " vertical substantially " well or wellhole refer in the hydrocarbon stratum steam in one or more basic horizontal inject well or wellhole one or more end or near (for example 20 meters with interior or 10 meters in), the angle of slope is 60 ° or higher or 75 ° or higher or 80 ° or higher well or wellhole.Substantially vertical well or wellhole can have the angle of slope less than 60 ° well or wellhole part and can level or near level at the some parts of well or wellhole.
The hydrogen sulfide of Ying Yonging can provide in fuel stream in the methods of the invention, described fuel stream comprises the hydrogen sulfide of 1-100vol%, 3-90vol%, 10-80vol% or 20-50vol%, perhaps can comprise 10vol% or 30vol% or 40vol% or 50vol% or 60vol% or the hydrogen sulfide of 70vol% at least at least at least at least at least at least.Hydrogen sulfide content in the logistics can be used ASTM method D2420 and measure.The fuel stream that comprises hydrogen sulfide can comprise hydrocarbon (for example methane and ethane), hydrogen, carbon dioxide or their mixture.In some embodiments, fuel can include organic sulfur compound.The example of organosulfur compound includes but not limited to methyl mercaptan, thiophene, thiophene compound, carbon disulfide, cos or their mixture.The fuel that application comprises hydrogen sulfide and/or organosulfur compound can allow to save the 0.3-1 mole of methane at every mole of atomic sulfur in the fuel.
The fuel stream that comprises hydrogen sulfide can originate from hydrocarbon containing formation.Fig. 2 has described the schematic diagram of handling the formation fluid that originates from the hydrocarbon stratum.The formation fluid 110 that is produced enters fluid separation element 112 and is separated into liquid stream 114, gas stream 116 and aqueous stream 118.The formation fluid 110 that is produced can derive from the hydrocarbon stratum that is mainly gas storage layer, perhaps derives from the hydrocarbon stratum that is mainly liquid hydrocarbon storage layer.Liquid stream 114 can be transported to other processing unit and/or storage unit.Gas stream 116 can comprise hydrocarbon, cos, hydrogen sulfide, oxysulfide, organosulfur compound, hydrogen, carbon dioxide or their mixture, but is not limited to this.Gas stream 116 can enter gas separation unit 120, to isolate at least a portion carburet hydrogen logistics 122, at least a portion hydrogen sulfide stream 124, at least a portion carbon dioxide 126, at least a portion sulfur dioxide logistics 128 and at least a portion hydrogen gas stream 130 from gas stream 116.
One or more hydrogen sulfide containing logistics from separate sources (comprising the gas stream 116 from the hydrocarbon stratum) can make up and be sent to gas separation unit, to produce the fuel stream of using in the methods of the invention that comprises hydrogen sulfide.For example, feed stream can be made up, from this logistics, the gas that is rich in hydrogen sulfide can be isolated as gas separation unit from the logistics of gas storage layer, liquid hydrocarbon storage layer and/or ground installation.The hydrogen sulfide stream 124 of gained can be stored, and/or makes up with the one or more hydrogen sulfide stream that originate from other gas separation unit and/or other treatment facility, to form the fuel stream of using in the methods of the invention that comprises hydrogen sulfide.
The gas separation unit 120 that is used to form the fuel stream of using in the methods of the invention that comprises hydrogen sulfide can comprise physical treatment system and/or chemical processing system.The physical treatment system comprises film unit, psa unit, liquid absorptive unit and/or cryogenic unit, but is not limited to this.Chemical processing system can be included in the unit of using amine (as diethanol amine or diisopropanolamine (DIPA)), zinc oxide, sulfolane, water or their mixture in the treatment process.In some embodiments, gas separation unit 120 is used Sulfinol gas treatment technology and is removed sulphur compound.Carbon dioxide can be used Catacarb
(Catacarb, Overland Park, Kansas, U.S.A.) and/or Benfield (UOP, Des Plaines, Illinois, U.S.A.) gas treatment technology removes.Gas separation unit can be rectifying absorption and high pressure distillation unit.
The fuel stream that can dry comprise hydrogen sulfide to be removing moisture, thereby improves the combustibility of fuel stream.For example, can make the fuel stream drying that comprises hydrogen sulfide by hydrogen sulfide stream being contacted with ethylene glycol remove water.
In the method for the invention, the oxidant that comprises in the mixture of hydrogen sulfide and oxidant is oxygen-containing gas or liquid.Oxidant is preferably selected from compressed air, oxygen-enriched air or oxygen.In the method for the invention, can provide compressed air as oxidant by conventional air compression method compressed air, for example, making air flow through turbocompressor can compressed air.Oxygen-enriched air can contain than air and manys the oxygen of 0.5-15vol%, can be by compressed air and the air after making compression flow through and can reduce that the film of nitrogen content produces in the air.Usually traditional air separation technology can provide oxygen as oxidant.
In some embodiments, be chosen in the ratio of hydrogen sulfide and oxidant in the mixture that burns in the basic vertical well bore, and in combustion process, control and combustion by-products gas is injected the hydrocarbon stratum by basic vertical well bore.(ratio with sulphur atom and oxygen atom is a benchmark by selecting hydrogen sulfide amount with respect to existing oxidant content, perhaps by the stoichiometry benchmark), and regulate the hydrogen sulfide amount and measure for selected, can control the composition of the amount of hydrogen sulfide in the burning and the combustion by-products that is produced (for example sulfur dioxide and/or sulfur trioxide).The amount of the fuel stream that comprises hydrogen sulfide can be controlled, and/or the amount of oxidant stream can be controlled, thus the hydrogen sulfide that comprises selected ratio that generation is used to burn and the mixture of oxidant, and then produce preferred combustion by-products logistics composition.
Can select to be provided for producing the fuel stream amount that comprises hydrogen sulfide and the oxidant stream amount of the ignition mixture in the inventive method in some way, be mainly sulfur trioxide in the combustion by-products logistics that makes mixture burns produce.In order to produce the combustion by-products logistics that is rich in sulfur trioxide, can select the ratio of hydrogen sulfide and oxidant, thereby for the hydrogen sulfide content in the mixture, there is excessive oxidant in the mixture that is used for burning.The mixture of poor hydrogen sulfide of burning produces sulfur trioxide more than sulfur dioxide as combustion by-products.Sulfur trioxide can form sulfuric acid with the water reaction in the hydrocarbon stratum.Therefore sulfur trioxide can be easy to be converted into sulfuric acid, can produce dissolution heat, and is stoichiometry with the hydrogen sulfide amount of being burnt with respect to the amount of oxidant or compares when in shortage and more promptly pass to the hydrocarbon stratum.
Alternatively, the mixture that can select in some way to be used for burning comprises the fuel stream amount and the oxidant content of hydrogen sulfide, is mainly sulfur dioxide in the combustion by-products logistics that makes mixture burns produce.In order to produce the combustion by-products logistics of rich sulfur dioxide, can select the ratio of hydrogen sulfide and oxidant in the mixture, thereby for the hydrogen sulfide content in the mixture, in mixture, have oxidant in shortage.Using excessive hydrogen sulfide at the mixture that is used for burning with respect to oxidant is rich in sulfur dioxide with generation and also contains the combustion by-products logistics of hydrogen sulfide and allow hydrogen sulfide and/or sulfur dioxide to be introduced in the hydrocarbon containing formation.A part hydrogen sulfide and/or sulfur dioxide can contacts with at least a portion formation fluid and solvation and/or dissolve part heavy hydrocarbon in the formation fluid.Solvation and/or be dissolved to the small part heavy hydrocarbon and can promote heavy hydrocarbon in producing well, to move.In addition, being introduced into the combustion by-products logistics that small part comprises sulfur dioxide in formation fluid can increase the shear rate that imposes on hydrocarbon fluid in the stratum, and reduces the viscosity of non newtonian hydrocarbon fluid in the stratum.Therefore introducing the combustion by-products logistics that is rich in sulfur dioxide in the stratum can increase part exploitation and use the stratum, and can increase stratum energy output (originating from the energy content of the product on stratum) and import ratio between (the energy consumption on processing stratum) with stratum energy.
In another replacement scheme, hydrogen sulfide amount and oxidant content in the mixture that can select to be provided for burning are with hydrogen sulfide and the oxidant that the stoichiometry equivalent amount is provided.The hydrogen sulfide of combustion stoichiometry amount and oxygen can mainly produce sulfur dioxide and water as combustion by-products by following reaction:
H
2S+1.5O
2→SO
2+H
2O(ΔH
rxn＝-124kcal/mol?600°K).
Except the calorific value that burning hydrogen sulfide obtains, the sulfur dioxide/water combustion by-products logistics after heating is introduced on the hydrocarbon stratum can promote recovery of hydrocarbons from the stratum.Heat can be passed to fluid in the stratum and the fluid after the heating can flow to producing well from the heat of sulfur dioxide.In addition, just as discussed above, the sulfur dioxide in the combustion by-products logistics can reduce the viscosity of hydrocarbon formation fluid in the hydrocarbon stratum and thereby increase the hydrocarbon amount that can gather from the stratum.Though the dissolution heat of sulfur dioxide is less than the dissolution heat of sulfuric acid, also can passes to the formation fluid in the hydrocarbon stratum, thereby formation fluid is moved.
The burning that comprises the mixture of hydrogen sulfide and oxidant is implemented to produce heat at the one or more heaters that are arranged in one or more basic vertical well bore.Heater comprises at least one flameless distributed combustor and also can comprise burner.
In a preferred embodiment, each heater is flameless distributed combustor, comprises the mixture flameless combustion of hydrogen sulfide and oxidant therein.In flameless distributed combustor, oxidant offers burner as oxidant stream with certain speed, fully improve described speed in case the mixture of oxidation agent and hydrogen sulfide forms fixing diffusion flame when burning in heater, thereby guarantee controlledly to discharge heat along the length of flameless distributed combustor.
When the heater of operation flameless distributed combustor comprises the mixture of hydrogen sulfide and oxidant stream with burning, the hydrogen sulfide that preferably provides as gas stream is mixed with oxidant, wherein the mixture with hydrogen sulfide and oxidant is heated to the auto-ignition temperature that is equal to or higher than mixture, be generally 250-800 ℃, or 300-750 ℃, or 400-700 ℃ (wherein the auto-ignition temperature of bright sulfur hydrogen fuel logistics is 260 ℃).
Hybrid oxidant logistics and comprising before the fuel stream of hydrogen sulfide in heater, oxidant stream, fuel stream or the two can be preheated to and be enough to make mixture to reach the temperature that is equal to or higher than the mixture auto-ignition temperature when mixing.Oxidant stream and/or comprise the fuel stream of hydrogen sulfide can be by coming preheating with thermal source such as steam or superheated steam heat exchange.As an alternative, fuel stream and the oxidant stream that comprises hydrogen sulfide can be mixed, and light a fire with ignition installation (as spark plug or glowing plug), described ignition installation promotes the temperature increase of mixture to the auto-ignition temperature that is equal to or higher than mixture.
Heater also can comprise the burner of one or more generation flames.In operation during burner, the fuel stream that comprises hydrogen sulfide and the oxidant stream that are provided for burning to burner.Fuel stream and oxidant stream can mix in burner, perhaps mix before offering burner.The temperature increase of the fuel stream by will comprising hydrogen sulfide and the mixture of oxidant stream to the auto-ignition temperature that is equal to or higher than mixture (for example by with ignition installation such as spark plug or glowing plug with mixture ignition) makes mixture burns.With certain speed is that burner provides oxidant stream and the fuel stream that comprises hydrogen sulfide, thereby burner can produce stable flame.Burner can be included near the flame stabilization cover the burner flame, to help the retention flame after igniting.
The mixture burns of hydrogen sulfide and oxidant produces heat.The heat that burning is produced passes to steam at least one basic horizontal and injects a part of hydrocarbon containing formation between well and at least one vertical substantially heater well.By being injected in the hydrocarbon stratum by the combustion by-products logistics that burning produces from heater well, the heat that the mixture burns of hydrogen sulfide and oxidant is produced guides to steam in heater well and basic horizontal from vertical substantially heater well and injects a part of hydrocarbon containing formation between the well, and wherein the combustion by-products logistics is gone into hydrocarbon containing formation with at least a portion from the combustion heat carrier band of heater well.In an embodiment of the inventive method, can inject the terminal of well vertical substantially heater the most nearby with combustion by-products logistics injection hydrocarbon containing formation by the steam that is positioned at basic horizontal.
By reaction heat, the heat of solvation, conduction heat or advection heat can transfer heat to the fluid introduced in the stratum, to formation fluid and/or to a part of hydrocarbon containing formation.The fluid and/or the combustion by-products that are incorporated in the stratum can pass to heat at least a portion hydrocarbon containing formation and/or formation fluid.
Convective heat transfer may take place when uncondensable unmixing gas such as nitrogen contact with formation fluid and/or hydrocarbon containing formation.When oxidant stream was formed by compressed air or oxygen-enriched air, the combustion by-products logistics may comprise nitrogen.When overheated miscible solvent steam (as hydrogen sulfide, carbon dioxide and/or sulfur dioxide steam) when contacting with formation fluid and/or hydrocarbon containing formation, also convective heat transfer may take place.When overheated unmixability solvent vapo(u)r such as water contact with formation fluid and/or hydrocarbon containing formation, also convective heat transfer may take place.
When the liquid vapour lime set of heat contacted with formation fluid and/or hydrocarbon containing formation, conduction heat transfer may take place.When the liquid miscible solvent (as hydrogen sulfide, carbon dioxide and/or sulfur dioxide) of heat when contacting with formation fluid and/or hydrocarbon containing formation, conduction heat transfer may take place.
When a kind of compound and the reaction of another kind of compound, the heat transmission of the heat that may react.For example, oxysulfide is in hydrocarbon containing formation and/or wellhole is outside and liquid water forms solution, produces reaction heat.When oxygen and hydrocarbon or sulphur compound reaction formation oxycarbide or oxysulfide, also can produce reaction heat.
When at least a component is dissolved, can produce dissolution heat in solvent.For example, when dissolving, sulfuric acid can produce heat in water.
The heat that passes to hydrocarbon containing formation from one or more vertical substantially heater well will heat steam in basic horizontal and inject at least a portion hydrocarbon containing formation between well and the vertical substantially heater well, and wherein said vertical substantially heater well is positioned in ten meters at the steam injection well terminal of described basic horizontal.By transmitting heat to the hydrocarbon stratum, at least a portion formation fluid in the hydrocarbon containing formation part of heating is moved from heater well.Can collect formation fluid that moves and the formation fluid that can comprise the formation fluid driving of being moved or being moved by heat transmission of hydrocarbon material by producing well from the hydrocarbon containing formation generation.
Fig. 3 to Fig. 7 is that what be used for underground heating is the embodiment of the heater 130 of fuel with hydrogen sulfide.It is the sectional drawing of the flameless distributed combustor of fuel that Fig. 3 to Fig. 6 has described with hydrogen sulfide.It is the sectional drawing of the burner of fuel that Fig. 7 has described with hydrogen sulfide.
It is the fragmentary cross-sectional view of the flameless distributed combustor 150 of fuel with hydrogen sulfide that Fig. 3 has described what be arranged in vertical borehole 102.The fuel stream 152 (gas stream 116 for example shown in Figure 2 and/or hydrogen sulfide stream 124, optional sulfur dioxide logistics 128, hydrogen gas stream 130 and/or the carburet hydrogen logistics 122 of comprising) that comprises hydrogen sulfide enters center cartridge 154.Oxidant stream 156 (for example air, oxygen-enriched air, oxygen or their mixture) enters combustion pipe 158.In some embodiments, the mixture of hot heating fuel logistics 152, oxidant stream 156 and/or the fuel/oxidant of water 162 causes the necessary auto-ignition temperature of fuel stream mixture burns to being equal to or higher than.In some embodiments, before entering fuel channel and/or combustion pipe, fuel stream 152 and/or oxidant stream 156 are heated to the auto-ignition temperature that is equal to or higher than mixture.Oxidant stream 156 mixes with fuel stream 152 and the fuel/oxidant mixture is being equal to or higher than reaction (burning) under the auto-ignition temperature of mixture.
The burning of the downstream part of combustion pipe 158 can pass to heat the water 162 in the external pipe 164.In some embodiments, water is heated to form steam and/or superheated steam.The space that external pipe 164 forms between can the outer wall for the inwall that injects well 102 and combustion pipe 158.External pipe 164 can comprise the perforate 104 that allows water and/or heat to enter and inject the adjacent hydrocarbon layer of well.In some embodiments, external pipe 164 is the pipelines that surround combustion pipe 158, and is coupled with flameless distributed combustor 150 or is the integrated part of flameless distributed combustor 150.Coupling external pipe 164 can help flameless distributed combustor is inserted existing injection well with flameless distributed combustor 150.
In some embodiments, fuel combustion produces the combustion by-products logistics in combustion pipe 158.The combustion by-products logistics can add hot water 162.The combustion by-products logistics can and drive, heat the formation fluid in the hydrocarbon containing formation and/or reduce its viscosity from perforate 104 outflows.In a part of stratum distance well 102 a distance water contact with the combustion by-products logistics can produce heat and the heating at least partially the layer so that fluid moves.
In some embodiments, one or more parts of center cartridge 154 can be regulated.The selected part that the ability of adjusting center cartridge 154 allows for combustion pipe 158 provides fuel.For example, place center cartridge 154 may promote to be engraved in aboveground trip part when required combustion process in the upstream portion office of flameless distributed combustor.In case burning takes place, fuel channel can be advanced forward along the length of injecting well (perhaps can open selected valve along the length of injecting well), thereby provides fuel for other burner of placing in the well.In some embodiments, can regulate perforate 160, so that fuel flows into combustion pipe 158.For example, perforate 160 can link to each other with the computer system that opens or closes described perforate on demand.
Fig. 4 has described the center cartridge 154 with inner fuel pipeline 166 and external fuel pipeline 168.Inner fuel pipeline 166 can and/or removably be coupled with 168 couplings of external fuel pipeline.Can the fit inboard of external fuel pipeline 168 of inner fuel pipeline 166, thus a space formed at two pipeline enclosures.In some embodiments, two pipelines are coaxial.In some embodiments, described pipeline is separately and parallel.
Fig. 5 has described the flameless distributed combustor 150 with an above fuel channel.As shown in the figure, cartridge is separated from each other and is parallel.In some embodiments, described pipeline is coaxial.Fuel channel 154,154 ', 154 " comprise the perforate 160,160 that is provided with different interval along fuel channel ', 160 ".Be provided with perforate 160,160 ', 160 " can make fuel seclected time section be delivered to the selected part of flameless distributed combustor 150.For example, fuel stream 152 can be delivered to the upstream portion of combustion pipe 158 by perforate 160.Can provide heat for the steam 162 of the upstream portion of external pipe 164 in the burning of the upstream portion fuel 152 of combustion pipe 158.Fuel stream 152 ' by perforate 160 ' enter the middle part of combustion pipe 158 is mixed with oxidant and reaction and provide heat for the steam at external pipe 164 middle parts then.Perforate 160 in the fuel stream 152 " by fuel channel 154 " " is carried and subsequently in the burning of the downstream part of combustion pipe 158, thereby is provided heat for the steam of external pipe 164 downstream parts.In some embodiments, fuel stream 152,152 ', the 152 " hydrogen sulfide that contain different amounts.In some embodiments, fuel stream 152,152 ', the 152 " hydrogen sulfide that contain same amount.It should be understood that the quantity and/or the position of perforate in fuel channel that can change fuel channel.In some embodiments, regulate that perforate 160,160 ' and 160 " (open and/or close) flows into the fuel of combustion pipe 158 and/or the flow of hydrogen sulfide with control.
Fig. 6 has described the sectional drawing of the flameless distributed combustor 150 with ignition installation 172.Ignition installation 172 can promote the temperature of fuel/oxidant mixture to ignition temperature in combustion pipe 158.For example, in case near ignition installation 172 with the fuel/oxidant mixture ignition, the heat of flame then is heated to the fuel/oxidant mixture auto-ignition temperature of fuel/oxidant mixture, thereby helps fuel and oxidant reaction to produce flameless combustion and heat.
It is the sectional drawing of the burner 174 of fuel with hydrogen sulfide that Fig. 7 has described.Burner 174 can comprise fuel channel 176, combustion pipe 158 and external pipe 164.Ignition installation 172 can be positioned at the bottom of combustion pipe 158.Fuel stream 152 (for example gas stream among Fig. 2 116, hydrogen sulfide stream 124, sulfur dioxide logistics 128, hydrogen gas stream 130 and/or carburet hydrogen logistics 122, (methane, natural gas, sour gas or their mixture)) enters center cartridge 176.Oxidant stream 156 (for example air, oxygen-enriched air or their mixture) enters combustion pipe 158.In some embodiments, burner 174 can comprise more than one fuel channel.For example, pipeline is used for hydrogen sulfide and a pipeline is used for fossil fuel.In some embodiments, fuel channel 176 is a fuel channel 176 for combustion pipe 158 combustion pipes.
In some embodiments, before entering fuel channel and/or combustion pipe, fuel stream 152 and/or oxidant stream 156 are heated.In some embodiments, water 162 heating fuel logistics 152 and/or oxidant stream 156.Fuel stream 152 and oxidant stream 156 mix in combustion pipe 158.Ignition installation 172 provides spark to make the fuel/oxidant mixture burns to produce flame.
In some embodiments, burner comprises one or more nozzles 178.By making at least a portion fuel and at least a portion oxidant flow through nozzle 178 fuel is mixed with oxidant.Nozzle 178 can overheavy firing pipeline 158 and/or external pipe 164 in mixing.The geometrical construction of nozzle 178 (for example size of contraction-diffusion region, length, diameter and/or the angle of flare) can be regulated according to ignition rate, fuel stream composition and/or oxidant stream composition.Nozzle divergence angle can streamwise be 1-10 degree, 2-9 degree or 3-8 degree.In some embodiments, can determine that the shape of nozzle 178 is to allow to form mobile with one heart or oppositely flow with one heart (mixture eddy current).The nozzle swirl angle can be 10-40 degree, 15-35 degree or 20-30 degree.In some embodiments, the nozzle swirl angle is 30 degree.In some embodiments, burner 174 does not comprise nozzle 178.
In some embodiments, the downstream part of fuel channel 176 can be tapered.Bevel angle can be 5-30 degree, 10-25 degree or 15-20 degree.
The fuel/oxidant mixture burns in the combustion pipe 158 of burner 174 and heat can be passed to water 162 in the external pipe 164.In some embodiments, add hot water to form steam and/or superheated steam.External pipe 164 can be for injecting the space that forms between well 102 inwalls and combustion pipe 158 outer walls.External pipe 164 can comprise the perforate 104 that allows water and/or heat to enter and inject the adjacent hydrocarbon layer of well.In some embodiments, external pipe 164 is for surrounding the pipeline of combustion pipe 158, and with burner 174 couplings or be the integrated part of burner 174.Coupling external pipe 164 can help burner is inserted existing injection well with burner 174.In some embodiments, external pipe is a fuel channel and water is carried by internal pipeline.
In some embodiments, the fuel/oxidant mixture burns in the combustion pipe 158 of burner 174 and produces the combustion by-products logistics.The combustion by-products logistics can add hot water 162.The combustion by-products logistics can and drive, heat the formation fluid in the hydrocarbon containing formation and/or reduce its viscosity from perforate 104 outflows.In a part of stratum distance well 102 a distance water contact with the combustion by-products logistics can produce heat and the heating at least partially the layer so that fluid moves.
Heater 130 (for example flameless distributed combustor and the burner of describing among Fig. 3-7) can be by the material manufacturing that is fit to the down-hole combustion process.In some embodiments, water that exists in fuel and/or hydrogen sulfide stream and hydrogen sulfide interact to form sulfurized layer on the metal surface of duct wall.The formation of sulfurized layer can suppress carbonic acid and/or other acid further corrosion to the duct wall metal surface.The formation of sulfurized layer can allow external pipe 164, center cartridge 154 and combustion pipe 158 by carbon steel or other alloy manufacturing.For example, can use a plurality of parts that alloy 230, alloy 800H, alloy 370H or Hastelloy C276 make heater 130.In some embodiments, inner fuel pipeline 166 (as shown in Figure 4) is by the material manufacturing of withstand high temperatures and/or high-concentration hydrogen sulfide.
In some embodiments, the driving mixture of hydrocarbon fuel that will contain a small amount of hydrogen sulfide or be lower than the hydrogen sulfide of stoichiometry with respect to oxidant content is incorporated in the fuel channel 154 of heater 130 (for example flameless distributed combustor 150 and/or burner 174).In some embodiments, driving fuel stream comprises at the most 1vol%, 0.5vol%, the hydrogen sulfide of 0.01vol% at the most at the most.In some embodiments, driving fuel package hydrogen and/or contain oxygen ether such as dimethyl ether to reduce firing temperature.In case caused burning, then can increase the concentration of hydrogen sulfide in the fuel stream 152.
In some embodiments, for driving and/or keeping burning, contain dispensable with respect to oxidant than the mixture of low amount hydrogen sulfide.For example, fuel stream can contain the hydrogen sulfide of 0.1-100vol%, 3-90vol%, 10-80vol% or 20-50vol%.In some embodiments, the sulfur content of fuel is every gram fuel at least 0.01 gram, at least 0.1 gram, at least 0.5 gram or at least 0.9 gram atom sulphur, presses ASTM method D4294 and measures.
Fig. 8 described with the steam of basic horizontal or inclination inject well group close application vertical substantially be that the heater of fuel is produced the schematic diagram of the system of hydrocarbon with hydrogen sulfide.Vertical heater well 186 can be positioned at horizontal steam and inject near well 102 downstream parts.For example, vertical heater well 186 can be positioned at level and inject well 102 terminal 1-10 rice.Producing well 108 extends beyond and injects well 102 and be positioned at heated well 186 belows.Vertical heater well 186 comprises that as described herein is the heater 130 of fuel with hydrogen sulfide.The heat that is produced by heater well 186 by the oxidation of hydrogen sulfide in heater 130 can make hydrocarbon move to producing well 108.Inject the conventional driving method of well with application level and compare, drive combination with heat and the logistics of injecting well 102 from steam, the heat transmission that is produced by the heater well 186 that with hydrogen sulfide is fuel can allow by the more hydrocarbon of producing well 108 outputs.
According to this manual, other of various aspects of the present invention revised and alternate embodiment will be tangible to those skilled in the art.Therefore, this manual only understand as example and purpose be the instruction those skilled in the art implement general fashion of the present invention.Will be understood that this paper form of the present invention given and that describe will be considered to the example of embodiment.Some key elements and material can replace this paper illustrated and describe those, some parts and process can be put upside down, can use separately with some feature of the present invention, all these all are tangible after benefiting from description of the invention for a person skilled in the art.Under the condition that does not depart from the described the spirit and scope of the present invention of following claim, can change key element described herein.
Claims (12)
1. method of handling hydrocarbon containing formation comprises:
Steam injection well by a plurality of basic horizontal provides steam at least a portion hydrocarbon containing formation;
The mixture that comprises hydrogen sulfide and oxidant in the one or more flameless distributed combustors burning at least a portion that are arranged in one or more basic vertical well bore to be to produce heat, and wherein at least one basic vertical well bore steam of being at least one basic horizontal injects in ten meters at the well terminal;
The heat that at least a portion produced passed at the steam of at least one basic horizontal inject a part of hydrocarbon containing formation between well and the heater well that at least one is vertical substantially; With
Move at least a portion formation fluid in the hydrocarbon containing formation part of heating.
2. the method for claim 1 also comprises by the volume output formation fluid between the steam injection well of at least one vertical substantially heater well and at least one basic horizontal.
3. claim 1 or 2 method, wherein steam conducts heat at least a portion hydrocarbon containing formation.
4. each method of claim 1-3, wherein at least a portion steam drive at least a portion formation fluid flows to one or more producing wells.
5. each method of claim 1-4, wherein burning produces combustion by-products and also comprises the steps: at least a portion combustion by-products is delivered to the stratum so that at least a portion combustion by-products provides the driving force that at least a portion formation fluid is moved.
6. the method for claim 5, wherein at least a portion steam provides the driving force that at least a portion formation fluid is moved.
7. each method of claim 1-6, wherein burning produces the combustion by-products that comprises oxysulfide, also comprises the steps: to make in the hydrocarbon stratum at least a portion combustion by-products to mix the generation dissolution heat with water, thus the generation dissolution heat.
8. each method of claim 1-7, wherein burning produces the combustion by-products that comprises sulfur dioxide, also comprise the steps: to make at least a portion combustion by-products to mix with at least a portion formation fluid to form mixture and at least a portion mixture is moved.
9. each method of claim 1-8, wherein burning produces combustion by-products logistics and described method and also comprises the steps: the heat that at least a portion produces is passed at least a portion formation fluid in the hydrocarbon containing formation; Make formation fluid solvation after at least a portion heating with the logistics of at least a portion combustion by-products; Move with the formation fluid that makes at least a portion through heating and solvation.
10. each method of claim 1-9, at least a portion of wherein burning mixture comprise the ratio of selecting the hydrogen sulfide that is used to burn and oxidant, thereby form a selected amount of hydrogen sulfide, sulfur trioxide, sulfur dioxide or their mixture in combustion process.
11. the method for claim 10, at least a portion of wherein burning mixture comprise the ratio of selecting the hydrogen sulfide be used to burn and oxidant, thereby the main sulfur trioxide that produces of burning.
12. the method for claim 10, at least a portion of wherein burning mixture comprise the ratio of selecting the hydrogen sulfide be used to burn and oxidant, thereby main sulfur dioxide and the hydrogen sulfide of producing of burning.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
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| US4617208P | 2008-04-18 | 2008-04-18 | |
| US61/046,172 | 2008-04-18 | ||
| PCT/US2009/040932 WO2009129448A1 (en) | 2008-04-18 | 2009-04-17 | Methods for generation of subsurface heat for treatment of a hydrocarbon containing formation |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN102046918A true CN102046918A (en) | 2011-05-04 |
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| CN2009801202510A Pending CN102046918A (en) | 2008-04-18 | 2009-04-17 | Methods for generation of subsurface heat for treatment of a hydrocarbon containing formation |
Country Status (5)
| Country | Link |
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| US (1) | US20090260811A1 (en) |
| EP (1) | EP2279326A1 (en) |
| CN (1) | CN102046918A (en) |
| CA (1) | CA2721306A1 (en) |
| WO (1) | WO2009129448A1 (en) |
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| CN114207355A (en) * | 2019-08-09 | 2022-03-18 | 通用能源回收公司 | Steam generator tool |
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| CN102278103B (en) * | 2011-08-25 | 2014-04-02 | 中国石油天然气股份有限公司 | Method for improving oil deposit recovery ratio of deep extremely-viscous oil by gravity drainage assisted steam flooding |
| CN102322249B (en) * | 2011-08-25 | 2014-04-02 | 中国石油天然气股份有限公司 | Method for improving oil reservoir recovery efficiency of interlayer developed deep-layer heavy oil |
| CN103958824B (en) | 2011-10-07 | 2016-10-26 | 国际壳牌研究有限公司 | Regulate for heating the thermal expansion of the circulation of fluid system of subsurface formations |
| CN104011331B (en) | 2011-10-21 | 2017-09-01 | 尼克森能源无限责任公司 | With the SAGD method of oxygenation |
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- 2009-04-17 CN CN2009801202510A patent/CN102046918A/en active Pending
- 2009-04-17 CA CA2721306A patent/CA2721306A1/en not_active Abandoned
- 2009-04-17 EP EP09733534A patent/EP2279326A1/en not_active Withdrawn
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102758603A (en) * | 2012-07-10 | 2012-10-31 | 中国石油天然气股份有限公司 | Later-period air injection exploitation method for super heavy oil reservoir using steam assisted gravity drainage (SAGD) exploitation |
| CN102758603B (en) * | 2012-07-10 | 2015-02-25 | 中国石油天然气股份有限公司 | Later-period air injection exploitation method for super heavy oil reservoir using steam assisted gravity drainage (SAGD) exploitation |
| CN114207355A (en) * | 2019-08-09 | 2022-03-18 | 通用能源回收公司 | Steam generator tool |
Also Published As
| Publication number | Publication date |
|---|---|
| EP2279326A1 (en) | 2011-02-02 |
| CA2721306A1 (en) | 2009-10-22 |
| WO2009129448A1 (en) | 2009-10-22 |
| US20090260811A1 (en) | 2009-10-22 |
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Application publication date: 20110504 |