Patent Application
20110094750
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
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.
a-3e illustrate oil and/or gas production systems.
Referring now to
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
Referring now to
After the soaking/reaction period, as shown in
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
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.
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 across formation 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 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.
e illustrates the system of
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. 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 to well 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 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.
After the oil and/or gas 344 is produced, blanket 342 may be produced to well portion 312 or left in formation 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
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 in formations 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/or system 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 complete Step 2, which may be combined with any of the embodiments to complete Step 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.
| Filing Document | Filing Date | Country | Kind | 371c Date |
|---|---|---|---|---|
| PCT/US09/40478 | 4/14/2009 | WO | 00 | 12/16/2010 |
| Number | Date | Country | |
|---|---|---|---|
| 61045346 | Apr 2008 | US |
