AU2009267249B2

AU2009267249B2 - Systems and methods for producing oil and/or gas

Info

Publication number: AU2009267249B2
Application number: AU2009267249A
Authority: AU
Inventors: Andreas Nicholas Matzakos
Original assignee: Shell Internationale Research Maatschappij BV
Current assignee: Shell Internationale Research Maatschappij BV
Priority date: 2008-07-02
Filing date: 2009-06-25
Publication date: 2012-06-14
Anticipated expiration: 2029-06-25
Also published as: WO2010002693A2; NO20110165A1; BRPI0913864A2; CN102099544B; GB2473383A; US20110272151A1; CN103742112A; CN102099544A; CN103742112B; GB201021472D0; WO2010002693A3; AU2009267249A1

Abstract

A method comprising recovering a carbon source from a formation; converting at least a portion of the carbon source to a synthesis gas; converting at least a portion of the synthesis gas to an ether; and injecting at least a portion of the ether into the formation.

Description

WO 2010/002693 PCT/US2009/048626 SYSTEMS AND METHODS FOR PRODUCING OIL AND/OR GAS Field of the Invention The present disclosure relates to systems and methods for producing oil and/or 5 gas. Background of the Invention 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 10 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 practiced form is a steam drive, which reduces oil viscosity so that it can flow to the producing wells. Chemical flooding increases recovery by reducing the 15 capillary forces that trap residual oil. Polymer flooding improves the sweep efficiency of injected water. Miscible 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 Figure 1, there is illustrated prior art system 100. System 100 includes underground formation 102, underground formation 104, underground 20 formation 106, and underground formation 108. Production facility 110 is provided at the surface. Well 112 traverses formations 102 and 104, and terminates in formation 106. The portion of formation 106 is shown at 114. Oil and gas are produced from formation 106 through well 112, to production facility 110. Gas and liquid are separated from each other, gas is stored in gas storage 116 and liquid is stored in 25 liquid storage 118. U.S. Patent Number 5,826,656 discloses a method for recovering waterflood residual oil from a waterflooded oil-bearing subterranean formation penetrated from an earth surface by at least one well by injecting an oil miscible solvent into a waterflood residual oil-bearing lower portion of the oil-bearing subterranean formation 30 through a well completed for injection of the oil miscible solvent into the lower portion of the oil-bearing formation; continuing the injection of the oil miscible solvent into the 1 WO 2010/002693 PCT/US2009/048626 lower portion of the oil-bearing formation for a period of time equal to at least one week; recompleting the well for production of quantities of the oil miscible solvent and quantities of waterflood residual oil from an upper portion of the oil-bearing formation; and producing quantities of the oil miscible solvent and waterflood residual oil from 5 the upper portion of the oil-bearing formation. The formation may have previously been both waterflooded and oil miscible solvent flooded. The solvent may be injected through a horizontal well and solvent and oil may be recovered through a plurality of wells completed to produce oil and solvent from the upper portion of the oil-bearing formation. U.S. Patent Number 5,826,656 is herein incorporated by reference in its 10 entirety. Co-pending U.S. Patent Application Publication Number 2006/0254769, published November 16, 2006, and having attorney docket number TH2616, 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 hydrocarbons; a 15 mechanism for converting at least a portion of the hydrocarbons 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. U.S. Patent Application Publication Number 2006/0254769 is herein incorporated by reference in its entirety. 20 Co-pending PCT Patent Application Publication Number WO 2008/141051, published November 20, 2008, and having attorney docket number TH3276, discloses a system for producing oil and/or gas from an underground formation including a well above the formation; a mechanism to inject an enhanced oil recovery formulation into the formation, the enhanced oil recovery formulation including 25 dimethyl ether; and a mechanism to produce oil and/or gas from the formation. Co pending PCT Patent Application Publication Number WO 2008/141051 is herein incorporated by reference in its entirety. There is a 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 30 enhanced oil recovery using a solvent, for example through viscosity reduction, 2 3 chemical effects, and miscible flooding. There is a further need in the art for improved systems and methods for solvent miscible flooding. Object of the Invention It is the object of the present invention to substantially overcome or at least ameliorate one or more of the above disadvantages or to provide a useful alternative. Summary of the Invention In a first aspect of the present invention there is disclosed herein a system for producing oil and/or gas from an underground formation comprising: a well above the formation; a mechanism to inject an enhanced oil recovery formulation into the formation, the enhanced oil recovery formulation comprising a mixture of water and from 5% to 90% by weight of an ether, where the ether is selected from dimethyl ether, methyl tertiary butyl ether (MTBE), ethyl tertiary butyl ether (ETBE), tertiary amyl methyl ether (TAME), dimethoxy methane, polydimethoxy methane, and/or diethyl ether; and a mechanism to produce oil and/or gas from the formation. In a second aspect of the invention there is disclosed herein a method for producing oil and/or gas comprising: injecting an ether formulation comprising a mixture of water and an ether selected from dimethyl ether, methyl tertiary butyl ether (MTBE), ethyl tertiary butyl ether (ETBE), tertiary amyl methyl ether (TAME), dimethoxy methane, polydimethoxy methane, and/or diethyl ether into a formation from a first well; and producing oil and/or gas from the formation from a second well. In a third aspect of the invention there is disclosed herein a method comprising: recovering a carbon source from a formation; converting at least a portion of the carbon source to a synthesis gas; converting at least a portion of the synthesis gas to an ether; and injecting at least a portion of the ether and/or other liquids and/or gases into the formation at a pressure up to the fracture pressure of the formation.

4 Brief Description of the Drawings Preferred embodiments of the present invention will now be described, by way of examples only, with reference to the accompanying drawings wherein: Figure 1 illustrates an oil and/or gas production system. Figure 2a illustrates a well pattern. Figures 2b and 2c illustrate the well pattern of Figure 2a during enhanced oil recovery processes. Figures 3a-3c illustrate oil and/or gas production systems. Figure 4 illustrates an oil and/or gas production method. Figure 5 illustrates an EOR agent production process. Description of Preferred Embodiments Well Spacing Referring now to Figure 2a, in some embodiments, an array of wells 200 is illustrated. Array 200 includes well group 202 (denoted by horizontal lines) and well group 204 (denoted by diagonal lines). Each well in well group 202 has horizontal distance 230 from the adjacent well in well group 202. Each well in well group 202 has vertical distance 232 from the adjacent well in well group 202. Each well in well group 204 has horizontal distance 236 from the adjacent well in well group 204. Each well in well group 204 has vertical distance 238 from the adjacent well in well group 204. Each well in well group 202 is distance 234 from the adjacent wells in well group 204. Each well in well group 204 is distance 234 from the adjacent wells in well group 202. In some embodiments, each well in well group 202 is surrounded by four wells in well group 204. In some embodiments, each well in well group 204 is surrounded by four wells in well group 202.

WO 2010/002693 PCT/US2009/048626 In some embodiments, horizontal distance 230 is from about 5 to about 1000 meters, or from about 10 to about 500 meters, or from about 20 to about 250 meters, or from about 30 to about 200 meters, or from about 50 to about 150 meters, or from about 90 to about 120 meters, or about 100 meters. 5 In some embodiments, vertical distance 232 is from about 5 to about 1000 meters, or from about 10 to about 500 meters, or from about 20 to about 250 meters, or from about 30 to about 200 meters, or from about 50 to about 150 meters, or from about 90 to about 120 meters, or about 100 meters. In some embodiments, horizontal distance 236 is from about 5 to about 1000 10 meters, or from about 10 to about 500 meters, or from about 20 to about 250 meters, or from about 30 to about 200 meters, or from about 50 to about 150 meters, or from about 90 to about 120 meters, or about 100 meters. In some embodiments, vertical distance 238 is from about 5 to about 1000 meters, or from about 10 to about 500 meters, or from about 20 to about 250 meters, 15 or from about 30 to about 200 meters, or from about 50 to about 150 meters, or from about 90 to about 120 meters, or about 100 meters. In some embodiments, distance 234 is from about 5 to about 1000 meters, or from about 10 to about 500 meters, or from about 20 to about 250 meters, or from about 30 to about 200 meters, or from about 50 to about 150 meters, or from about 90 20 to about 120 meters, or about 100 meters. In some embodiments, array of wells 200 may have from about 10 to about 1000 wells, for example from about 1 to about 500 wells in well group 202, and from about 1 to about 500 wells in well group 204. In some embodiments, array of wells 200 is seen as a top view with well group 25 202 and well group 204 being vertical wells spaced on a piece of land. In some embodiments, array of wells 200 is seen as a cross-sectional side view with well group 202 and well group 204 being horizontal wells spaced within a formation. Referring now to Figure 2b, in some embodiments, array of wells 200 is illustrated. Array 200 includes well group 202 (denoted by horizontal lines) and well 30 group 204 (denoted by diagonal lines). 5 WO 2010/002693 PCT/US2009/048626 In some embodiments, a miscible enhanced oil recovery agent is injected into well group 204, and oil is recovered from well group 202. As illustrated, the miscible enhanced oil recovery agent has injection profile 208, and oil recovery profile 206 is being produced to well group 202. 5 In some embodiments, a miscible enhanced oil recovery agent is injected into well group 202, and oil is recovered from well group 204. As illustrated, the miscible enhanced oil recovery agent has injection profile 206, and oil recovery profile 208 is being produced to well group 204. In some embodiments, well group 202 may be used for injecting a miscible 10 enhanced oil recovery agent, and well group 204 may be used for producing oil and/or gas from the formation for a first time period; then well group 204 may be used for injecting a miscible enhanced oil recovery agent, and well group 202 may be used for producing oil and/or gas from the formation for a second time period, where the first and second time periods comprise a cycle. 15 In some embodiments, multiple cycles may be conducted which include alternating well groups 202 and 204 between injecting a miscible enhanced oil recovery agent, and producing oil and/or gas from the formation, where one well group is injecting and the other is producing for a first time period, and then they are switched for a second time period. 20 In some embodiments, a cycle may be from about 12 hours to about 1 year, or from about 3 days to about 6 months, or from about 5 days to about 3 months. In some embodiments, each cycle may increase in time, for example each cycle may be from about 5% to about 10% longer than the previous cycle, for example about 8% longer. 25 In some embodiments, a miscible enhanced oil recovery agent or a mixture including a miscible enhanced oil recovery agent may be injected at the beginning of a cycle, and an immiscible enhanced oil recovery agent or a mixture including an immiscible enhanced oil recovery agent may be injected at the end of the cycle. In some embodiments, the beginning of a cycle may be the first 10% to about 80% of a 30 cycle, or the first 20% to about 60% of a cycle, the first 25% to about 40% of a cycle, and the end may be the remainder of the cycle. 6 WO 2010/002693 PCT/US2009/048626 Referring now to Figure 2c, in some embodiments, array of wells 200 is illustrated. Array 200 includes well group 202 (denoted by horizontal lines) and well group 204 (denoted by diagonal lines). In some embodiments, a miscible enhanced oil recovery agent is injected into 5 well group 204, and oil is recovered from well group 202. As illustrated, the miscible enhanced oil recovery agent has injection profile 208 with overlap 210 with oil recovery profile 206, which is being produced to well group 202. In some embodiments, a miscible enhanced oil recovery agent is injected into well group 202, and oil is recovered from well group 204. As illustrated, the miscible 10 enhanced oil recovery agent has injection profile 206 with overlap 210 with oil recovery profile 208, which is being produced to well group 204. Enhanced Oil Recovery Methods The recovery of oil and/or gas with array of wells 200 from an underground formation may be accomplished by any known method. Suitable methods include 15 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 some embodiments, 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, 20 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 dimethyl ether formulation, a diethyl ether formulation or carbon dioxide, may be used to increase the flow of oil and/or gas from the formation. Releasing at least a portion of the miscible enhanced oil recovery agent and/or 25 other liquids and/or gases may be accomplished by any known method. One suitable method is injecting the miscible enhanced oil recovery formulation into a single conduit in a single well, allowing an ether formulation to soak, and then pumping out at least a portion of the ether formulation with gas and/or liquids. Another suitable method is injecting the miscible enhanced oil recovery formulation into a first well, and 30 pumping out at least a portion of the miscible enhanced oil recovery formulation with gas and/or liquids through a second well. The selection of the method used to inject 7 WO 2010/002693 PCT/US2009/048626 at least a portion of the miscible enhanced oil recovery formulation and/or other liquids and/or gases is not critical. In some embodiments, the miscible enhanced oil recovery formulation and/or other liquids and/or gases may be pumped into a formation at a pressure up to the 5 fracture pressure of the formation. In some embodiments, the miscible enhanced oil recovery formulation may be mixed in with oil and/or gas in a formation to form a mixture which may be recovered from a well. In some embodiments, a quantity of the miscible enhanced oil recovery formulation may be injected into a well, followed by another component to force the 10 formulation across the formation. For example air, water in liquid or vapor form, carbon dioxide, nitrogen, alcohols, other gases, other liquids, and/or mixtures thereof may be used to force the miscible enhanced oil recovery formulation across the formation. In some embodiments, the miscible enhanced oil recovery formulation may be 15 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, the miscible enhanced oil recovery formulation 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 20 water and/or steam may be used to heat and/or vaporize the miscible enhanced oil recovery formulation in the formation. In some embodiments, the miscible enhanced oil recovery formulation may be heated and/or boiled while within the formation, with the use of a heater. One suitable heater is disclosed in copending United States Patent Application having serial 25 number 10/693,816, filed on October 24, 2003, and having attorney docket number TH2557. United States Patent Application having serial number 10/693,816 is herein incorporated by reference in its entirety. Figures 3a - 3b: Referring now to Figures 3a and 3b, in some embodiments of the invention, 30 system 300 is illustrated. System 300 includes underground formation 302, underground formation 304, underground formation 306, and underground formation 8 WO 2010/002693 PCT/US2009/048626 308. Facility 310 is provided at the surface. Well 312 traverses formations 302 and 304, and has openings in formation 306. Portions 314 of formation 306 may be optionally fractured and/or perforated. During primary production, oil and gas from formation 306 is produced into portions 314, into well 312, and travels up to facility 5 310. Facility 310 then separates gas, which is sent to gas processing 316, and liquid, which is sent to liquid storage 318. Facility 310 also includes miscible enhanced oil recovery formulation storage 330. As shown in Figure 3a, miscible enhanced oil recovery formulation may be pumped down well 312 that is shown by the down arrow and pumped into formation 306. Miscible enhanced oil recovery formulation may be 10 left to soak in formation for a period of time from about 1 hour to about 15 days, for example from about 5 to about 50 hours. After the soaking period, as shown in Figure 3b, miscible enhanced oil recovery formulation and oil and/or gas is then produced back up well 312 to facility 310. Facility 310 is adapted to separate and/or recycle miscible enhanced oil 15 recovery formulation, for example by boiling the formulation, condensing it or filtering or reacting it or extracting it with water, then re-injecting the formulation into well 312, for example by repeating the soaking cycle shown in Figures 3a and 3b from about 2 to about 5 times. In some embodiments, miscible enhanced oil recovery formulation may be 20 pumped into formation 306 below the fracture pressure of the formation, for example from about 40% to about 90% of the fracture pressure. In some embodiments, well 312 as shown in Figure 3a injecting into formation 306 may be representative of a well in well group 202, and well 312 as shown in Figure 3b producing from formation 306 may be representative of a well in well group 25 204. In some embodiments, well 312 as shown in Figure 3a injecting into formation 306 may be representative of a well in well group 204, and well 312 as shown in Figure 3b producing from formation 306 may be representative of a well in well group 202. 30 Fiqure 3c: 9 WO 2010/002693 PCT/US2009/048626 Referring now to Figure 3c, in some embodiments of the invention, system 400 is illustrated. System 400 includes underground formation 402, formation 404, formation 406, and formation 408. Production facility 410 is provided at the surface. Well 412 traverses formation 402 and 404 has openings at formation 406. Portions of 5 formation 414 may be optionally fractured and/or perforated. As oil and gas is produced from formation 406 it enters portions 414, and travels up well 412 to production facility 410. Gas and liquid may be separated, and gas may be sent to gas storage 416, and liquid may be sent to liquid storage 418. Production facility 410 is able to produce and/or store miscible enhanced oil recovery formulation, which may 10 be produced and stored in production / storage 430. Dimethyl ether, diethyl ether, and/or other ethers from well 412 may be sent to miscible enhanced oil recovery formulation production / storage 430. Miscible enhanced oil recovery formulation is pumped down well 432, to portions 434 of formation 406. Miscible enhanced oil recovery formulation traverses formation 406 to aid in the production of oil and gas, 15 and then the miscible enhanced oil recovery formulation, oil and/or gas may all be produced to well 412, to production facility 410. Miscible enhanced oil recovery formulation may then be recycled, for example by boiling the formulation, condensing it or filtering or reacting it or extracting it with water, then re-injecting the formulation into well 432. 20 In some embodiments, a quantity of miscible enhanced oil recovery formulation or miscible enhanced oil recovery formulation mixed with other components may be injected into well 432, followed by another component to force miscible enhanced oil recovery formulation or miscible enhanced oil recovery formulation mixed with other components across formation 406, for example air; water in gas or liquid form; water 25 mixed with one or more salts, polymers, and/or surfactants; carbon dioxide; nitrogen; alcohols; other gases; other liquids; and/or mixtures thereof. In some embodiments, well 412 which is producing oil and/or gas is representative of a well in well group 202, and well 432 which is being used to inject miscible enhanced oil recovery formulation is representative of a well in well group 30 204. 10 WO 2010/002693 PCT/US2009/048626 In some embodiments, well 412 which is producing oil and/or gas is representative of a well in well group 204, and well 432 which is being used to inject miscible enhanced oil recovery formulation is representative of a well in well group 202. 5 Fiqure 4: Referring now to Figure 4, in some embodiments of the invention, method 500 is illustrated. Method 500 includes injecting a miscible enhanced oil recovery formulation indicated by checkerboard pattern; injecting an immiscible enhanced oil recovery formulation indicated by diagonal pattern; and producing oil and/or gas from 10 a formation indicated by white pattern. Injection and production timing for well group 202 is shown by the top timeline, while injection and production timing for well group 204 is shown by the bottom timeline. In some embodiments, at time 520, miscible enhanced oil recovery formulation 15 is injected into well group 202 for time period 502, while oil and/or gas is produced from well group 204 for time period 503. Then, miscible enhanced oil recovery formulation is injected into well group 204 for time period 505, while oil and/or gas is produced from well group 202 for time period 504. This injection / production cycling for well groups 202 and 204 may be continued for a number of cycles, for example 20 from about 5 to about 25 cycles. In some embodiments, at time 530, there may be a cavity in the formation due to oil and/or gas that has been produced during time 520. During time 530, only the leading edge of cavity may be filled with a miscible enhanced oil recovery formulation, which is then pushed through the formation with an immiscible enhanced oil recovery 25 formulation. Miscible enhanced oil recovery formulation may be injected into well group 202 for time period 506, then immiscible enhanced oil recovery formulation may be injected into well group 202 for time period 508, while oil and/or gas may be produced from well group 204 for time period 507. Then, miscible enhanced oil recovery formulation may be injected into well group 204 for time period 509, then 30 immiscible enhanced oil recovery formulation may be injected into well group 204 for time period 511, while oil and/or gas may be produced from well group 202 for time 11 WO 2010/002693 PCT/US2009/048626 period 510. This injection / production cycling for well groups 202 and 204 may be continued for a number of cycles, for example from about 5 to about 25 cycles. In some embodiments, at time 540, there may be a significant hydraulic communication between well group 202 and well group 204. Miscible enhanced oil 5 recovery formulation may be injected into well group 202 for time period 512, then immiscible enhanced oil recovery formulation may be injected into well group 202 for time period 514 while oil and/or gas may be produced from well group 204 for time period 515. The injection cycling of miscible and immiscible enhanced oil recovery formulations into well group 202 while producing oil and/or gas from well group 204 10 may be continued as long as desired, for example as long as oil and/or gas is produced from well group 204. In some embodiments, periods 502, 503, 504, and/or 505 may be from about 6 hours to about 10 days, for example from about 12 hours to about 72 hours, or from about 24 hours to about 48 hours. 15 In some embodiments, each of periods 502, 503, 504, and/or 505 may increase in length from time 520 until time 530. In some embodiments, each of periods 502, 503, 504, and/or 505 may continue from time 520 until time 530 for about 5 to about 25 cycles, for example from about 10 to about 15 cycles. 20 In some embodiments, period 506 is from about 10% to about 50% of the combined length of period 506 and period 508, for example from about 20% to about 40%, or from about 25% to about 33%. In some embodiments, period 509 is from about 10% to about 50% of the combined length of period 509 and period 511, for example from about 20% to about 25 40%, or from about 25% to about 33%. In some embodiments, the combined length of period 506 and period 508 is from about 2 days to about 21 days, for example from about 3 days to about 14 days, or from about 5 days to about 10 days. In some embodiments, the combined length of period 509 and period 511 is 30 from about 2 days to about 21 days, for example from about 3 days to about 14 days, or from about 5 days to about 10 days. 12 WO 2010/002693 PCT/US2009/048626 In some embodiments, the combined length of period 512 and period 514 is from about 2 days to about 21 days, for example from about 3 days to about 14 days, or from about 5 days to about 10 days. In some embodiments, oil and/or gas produced may be transported to a 5 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 10 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. Enhanced Oil Recovery Aqents In some embodiments, oil and/or gas may be recovered from a formation with 15 methanol and/or one or more methanol derivatives, such as dimethyl ether, acetic acid, formaldehyde, and olefins, other ethers such as methyl tertiary butyl ether (MTBE), ethyl tertiary butyl ether (ETBE), tertiary amyl methyl ether (TAME) and the like, dimethoxy methane, polydimethoxy methane, and other chemical products produced from methanol, hereinafter referred to as a methanol compound. The 20 methanol compound may include dimethyl ether. In some embodiments, oil and/or gas may be recovered from a formation with nitrogen; glycols, such as mono-ethylene glycol, di-ethylene glycol, tri-ethylene glycol, and tetra-ethylene glycol; ethanol, methanol, or other alcohols; acetals; polyols; methyl isobutyl carbinol; butyl propionate, methyl acetate, ethyl acetate tertiary butyl 25 acetate, or other esters; methyl ethyl ketone, methyl isobutyl ketone, or other ketones; and/or one or more methanol derivatives, such as dimethyl ether and dimethyl carbonate, and/or one or more ethanol derivatives, such as diethyl ether and diethyl carbonate. In some embodiments, a hydrocarbon from the formation may be converted 30 into a dimethyl ether formulation. The conversion of at least a portion of the hydrocarbon into a dimethyl ether formulation may be accomplished by any known 13 WO 2010/002693 PCT/US2009/048626 method. Suitable methods may include reacting steam and natural gas at high temperatures and moderate pressures over a reduced nickel-containing catalyst so as to produce synthesis gas, where the natural gas may contain C1 to C6 compounds, such as C1 to C4 compounds. The synthesis gas production may be sent to a 5 methanol reactor to generate methanol, which can be dehydrated to generate the dimethyl ether formulation. The selection of the method used to convert at least a portion of the hydrocarbon into a dimethyl ether formulation is not critical. U.S. Patent Numbers 7,168,265, 7,100,692, and 7,083,662 disclose the production of dimethyl ether from natural gas. U.S. Patent Numbers 7,168,265, 10 7,100,692, and 7,083,662 are herein incorporated by reference in their entirety. In some embodiments, a suitable miscible enhanced oil recovery agent may be a dimethyl ether formulation. The dimethyl ether formulation may include dimethyl ether and/or dimethyl ether derivatives and/or precursors for example, methanol and mixtures thereof; and optionally one or more of the following: carbon dioxide, C1-C6 15 hydrocarbons, water, nitrogen, and mixtures thereof. In some embodiments, suitable miscible enhanced oil recovery agents include dimethyl ether, hydrogen sulfide, carbon dioxide, octane, pentane, LPG, C2-C6 aliphatic hydrocarbons, nitrogen, diesel, mineral spirits, naptha solvent, asphalt solvent, kerosene, acetone, xylene, trichloroethane, or mixtures of two or more of the 20 preceding, or other miscible enhanced oil recovery agents as are known in the art. In some embodiments, suitable miscible enhanced oil recovery agents are first contact miscible or multiple contact miscible with oil in the formation. Figure 5: Referring now to Figure 5, a miscible enhanced oil recovery agent production 25 process 600 is illustrated. Starting at 602, a carbon source is obtained. Suitable carbon sources include produced natural gas, crude oil, bitumen, oil shale, tar sands, coke, coal, and animal or vegetable fats, or other carbon sources as are known in the art. The selection of the carbon source is not critical. At 604, the carbon source is converted to synthesis gas (syn gas), but any 30 known method in the art. One suitable method to convert methane to syn gas is disclosed in U.S. Patent Publication Number U.S. 2004/0256116, which is herein 14 WO 2010/002693 PCT/US2009/048626 incorporated by reference in its entirety. The selection of the method used to convert the carbon source to syn gas is not critical. At 606, the syn gas is converted to an alcohol, for example methanol. One suitable method to convert syn gas to an alcohol is disclosed in U.S. Patent 5 Publication Number U.S. 2004/0256116, which is herein incorporated by reference in its entirety. The selection of the method used to convert the syn gas to an alcohol is not critical. At 608, the alcohol is converted to an ether, for example ethanol to ethyl ether, methanol to methyl ether, or a mixture of ethanol and methanol to methylethyl ether. 10 One suitable method to convert one or more alcohols to ethers is catalytic distillation, which is disclosed in U.S. Patent Application Publication Number U.S. 2004/0204614, which is herein incorporated by reference in its entirety. Suitable methods to convert ethanol to diethyl ether are disclosed in JP63310841, JP63253043, and JP60215642, which are herein incorporated by reference in their entirety. Other suitable methods 15 for converting alcohols to ethers are disclosed in U.S. Patent Numbers 5,684,213, 5,750,799, and 6,740,783; U.S. Patent Application Publication Numbers 2004/0034255, 2004/0064002, 2006/0020155, 2006/0135823, 2006/0224012, 2007/0066855, and 2007/0078285; and International Publication Numbers WO 2006/041253, and 2008/026887; which are all herein incorporated by reference in 20 their entirety. The selection of the method used to convert the alcohol to an ether is not critical. At 610, the ether is injected into a formation to aid in the recovery of oil and/or gas. Suitable methods to inject liquids and gases are disclosed above and are known in the art. The selection of the method used to inject the ether is not critical. 25 In some embodiments, 606 and 608 can be combined where the syngas is converted an ether in a single process. Suitable methods for converting syn gas to ethers are disclosed in U.S. Patent Numbers 5,218,003, 5,908,963, 6,069,180, 6,191,175, and 6,458,856; U.S. Patent Application Publication Numbers 2005/0038129, 2006/0020155, and 2007/0078285; International Publication Number 30 WO 99/21814; European Patent Application Numbers 0 324 475, 0 409 086, 0 483 609; and UK Patent Application Number 2 253 623; which are all herein incorporated 15 WO 2010/002693 PCT/US2009/048626 by reference in their entirety. The selection of the method used to convert the syngas to an ether is not critical. In some embodiments, process 600 may have an input of produced natural gas, crude oil, or other carbon sources from a local formation, for example the same 5 formation that the ether will be injected into. In some embodiments, process 600 may skip steps 602 and 604, and may have an input of ethanol, produced from corn, sugar cane, cellulose, or other sugar sources as are known in the art. In some embodiments, suitable ethers produced at 608 include ethers having 10 from about 2 to about 20 carbons, for example from about 3 to about 10, or from about 4 to about 8 carbons. Suitable ethers include dimethyl ether, methyl-ethyl ether, diethyl ether, dipropyl ether, methyl-propyl ether, ethyl-propyl ether (primary or secondary), dibutyl ether (primary or secondary or tertiary), diamyl ether, tertiary-amyl methyl ether (TAME), ethyl tertiary butyl ether (ETBE), methyl tertiary-butyl ether 15 (MTBE) and other ethers as are known in the art having from about 2 to about 20 carbons. In some embodiments, process step 608 may produce ethers and one or more byproducts such as alcohols, water, carbon dioxide, nitrogen, and possibly other liquids and/or gases. These byproducts may also be injected in a mixture with the 20 ether, or as an immiscible enhanced oil recovery agents to push the ether through the formation. In some embodiments, suitable immiscible enhanced oil recovery agents include water in gas or liquid form, air, nitrogen, mixtures of two or more of the preceding, or other immiscible enhanced oil recovery agents as are known in the art. 25 In some embodiments, suitable immiscible enhanced oil recovery agents are not first contact miscible or multiple contact miscible with oil in the formation. In some embodiments, immiscible and/or miscible enhanced oil recovery agents injected into the formation may be recovered from the produced oil and/or gas and re-injected into the formation. 30 In some embodiments, oil as present in the formation prior to the injection of any enhanced oil recovery agents has a viscosity of at least about 0.01 centipoise, or 16 WO 2010/002693 PCT/US2009/048626 at least about 0.1 centipoise, or at least about 0.5 centipoise, or at least about 1 centipoise, or at least about 2 centipoise, or at least about 5 centipoise. In some embodiments, oil as present in the formation prior to the injection of any enhanced oil recovery agents has a viscosity of up to about 500 centipoise, or up to about 100 5 centipoise, or up to about 50 centipoise, or up to about 25,000 centipoise. Illustrative Embodiments: In one embodiment of the invention, there is disclosed a system for producing oil and/or gas from an underground formation comprising a well above the formation; a mechanism to inject an enhanced oil recovery formulation into the formation, the 10 enhanced oil recovery formulation comprising an ether, the ether comprising from 2 to 20 carbons; and a mechanism to produce oil and/or gas from the formation. In some embodiments, the system also includes a second well a distance from the first well, wherein the mechanism to produce oil and/or gas from the formation is located at the second well. In some embodiments, the mechanism to inject is located at the well, 15 and wherein the mechanism to produce oil and/or gas from the formation is located at the well. In some embodiments, the underground formation is beneath a body of water. In some embodiments, the system also includes a mechanism for injecting an immiscible enhanced oil recovery formulation into the formation, after the enhanced oil recovery formulation has been released into the formation. In some embodiments, 20 the enhanced oil recovery formulation further comprises one or more of hydrogen sulfide, carbon disulfide, carbon dioxide, carbon monoxide, octane, pentane, LPG, propane, C2-C6 aliphatic hydrocarbons, nitrogen, diesel, mineral spirits, naptha solvent, asphalt solvent, kerosene, acetone, xylene, trichloroethane, acetals, glycols, polyols, esters, ketones, aldols, alcohols, ammonia, amines, and mixtures thereof. In 25 some embodiments, the system also includes an immiscible enhanced oil recovery formulation selected from the group consisting of water in gas or liquid form, air, nitrogen, methane, and mixtures thereof. In some embodiments, the well comprises an array of wells from 5 to 500 wells. In some embodiments, the mechanism to produce oil and/or gas from the formation is located at the well. In some 30 embodiments, the system also includes a mechanism for producing a carbon source from the formation. In some embodiments, the system also includes a mechanism to 17 WO 2010/002693 PCT/US2009/048626 produce a synthesis gas from the carbon source. In some embodiments, the system also includes a mechanism to produce the ether from the synthesis gas, either directly or with an alcohol intermediate. In some embodiments, the system also includes a mechanism for producing the ether adjacent to the well. 5 In one embodiment of the invention, there is disclosed a method for producing oil and/or gas comprising injecting an ether formulation into a formation from a first well; and producing oil and/or gas from the formation from a second well. In some embodiments, the method also includes recovering the ether formulation from the oil and/or gas, if present, and then injecting at least a portion of the recovered ether 10 formulation into the formation. In some embodiments, injecting the ether formulation comprises injecting at least a portion of the ether formulation into the formation in a mixture with one or more of hydrocarbons other than the ether; carbon dioxide; carbon monoxide; nitrogen; or mixtures thereof. In some embodiments, injecting the ether formulation comprises injecting at least a portion of the ether formulation into 15 the formation in a mixture, wherein the mixture comprises from 5% to 90% ether by weight. In some embodiments, the method also includes heating the ether formulation prior to injecting the ether formulation into the formation, or while within the formation. In some embodiments, the ether formulation is injected at a pressure from 0 to 37,000 kilopascals above the initial reservoir pressure, measured prior to 20 when ether injection begins. In some embodiments, the ether formulation is injected into a reservoir having a reservoir temperature of at least 100 degrees centigrade, for example at least 250 degrees centigrade, measured prior to when ether injection begins. In some embodiments, the underground formation comprises a permeability from 0.0001 to 15 Darcies, for example a permeability from 0.001 to 1 Darcy. In 25 some embodiments, the method also includes converting at least a portion of the recovered oil and/or gas into a material selected from the group consisting of transportation fuels such as gasoline and diesel, heating fuel, lubricants, chemicals, and/or polymers. In some embodiments, the method also includes converting at least a portion of the recovered oil and/or gas into an ether, and injecting the ether into an 30 underground formation. In some embodiments, the method also includes recovering an ether formulation from the oil and/or gas, if present, and then transporting the ether 18 WO 2010/002693 PCT/US2009/048626 formulation to another location, for example by a pipeline, a vessel, a pressurized vessel, or a chilled vessel. In some embodiments, the method also includes converting at least a portion of the recovered oil and/or gas into an ether, and then transporting the ether formulation to another location, for example by a pipeline, a 5 vessel, a pressurized vessel, or a chilled vessel. In some embodiments, the underground formation comprises an oil having an API from 10 to 100. In some embodiments, injecting the ether formulation comprises injecting a mixture of the ether formulation and water. In some embodiments, the water further comprises a water soluble polymer adapted to increase a viscosity of the mixture. In some 10 embodiments, the method also includes producing the ether formulation on an offshore structure from a starting material comprising synthesis gas, methanol, or mixtures thereof. In some embodiments, the method also includes reducing a bubble point of the oil in the formation with the ether formulation. In some embodiments, the method also includes increasing a swelling factor of the oil in the formation with the 15 ether formulation. In some embodiments, the method also includes reducing a viscosity of the oil in the formation with the ether formulation. In one embodiment of the invention, there is disclosed a method comprising recovering a carbon source from a formation; converting at least a portion of the carbon source to a synthesis gas; converting at least a portion of the synthesis gas to 20 an ether; and injecting at least a portion of the ether into the formation. 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 25 limited by particular embodiments described and illustrated herein, as these are merely exemplary in nature. 19

Claims

1. A system for producing oil and/or gas from an underground formation comprising: a well above the formation; a mechanism to inject an enhanced oil recovery formulation into the formation, the enhanced oil recovery formulation comprising a mixture of water and from 5% to 90% by weight of an ether, where the ether is selected from dimethyl ether, methyl tertiary butyl ether (MTBE), ethyl tertiary butyl ether (ETBE), tertiary amyl methyl ether (TAME), dimethoxy methane, polydimethoxy methane, and/or diethyl ether; and a mechanism to produce oil and/or gas from the formation.

2. The system of claim 1, further comprising a second well a distance from the well, wherein the mechanism to produce oil and/or gas from the formation is located at the second well.

3. The system of claim 1, wherein the mechanism to inject is located at the well, and wherein the mechanism to produce oil and/or gas from the formation is located at the well.

4. The system of any one of claims I to 3, wherein the underground formation is beneath a body of water.

5. The system of any one of claims 1 to 4, further comprising a mechanism for injecting an immiscible enhanced oil recovery formulation into the formation, after the enhanced oil recovery formulation has been released into the formation.

6. The system of any one of claims 1 to 5, wherein the enhanced oil recovery formulation further comprises one or more of hydrogen sulfide, carbon disulfide, carbon dioxide, carbon monoxide, octane, pentane, LPG, propane, C2-C6 aliphatic hydrocarbons, nitrogen, diesel, mineral spirits, naphtha solvent, asphalt solvent, kerosene, acetone, xylene, thchloroethane, acetals, glycols, polyols, esters, ketones, aldols, alcohols, ammonias, and mixtures thereof.

7. The system of any one of claims I to 6, further comprising an immiscible enhanced oil recovery formulation selected from the group consisting of water in gas or liquid form, air, nitrogen, methane, and mixtures thereof. 21

8. The system of claim 1, further comprising: a mechanism for producing a carbon source from the formation; a mechanism to produce a synthesis gas from the carbon source; a mechanism to produce the ether from the synthesis gas, either directly or with an alcohol intermediate.

9. The system of claim 1, further comprising a mechanism for producing the ether adjacent to the well.

10. A method for producing oil and/or gas comprising: injecting an ether formulation comprising a mixture of water and an ether selected from dimethyl ether, methyl tertiary butyl ether (MTBE), ethyl tertiary butyl ether (ETBE), tertiary amyl methyl ether (TAME), dimethoxy methane, polydimethoxy methane, and/or diethyl ether into a formation from a first well; and producing oil and/or gas from the formation from a second well.

11. The method of claim 10, further comprising recovering the ether formulation from the oil and/or gas, if present, and then injecting at least a portion of the recovered ether formulation into the formation.

12. The method of either claim 10 or 11, wherein injecting the ether formulation comprises injecting at least a portion of the ether formulation into the formation in a mixture with one or more of hydrocarbons other than the ether; carbon dioxide; carbon monoxide; nitrogen; or mixtures thereof.

13. The method of any one of claims 10 to 12, further comprising heating the ether formulation prior to injecting the ether formulation into the formation, or while within the formation.

14. The method of any one of claims 10 to 13, wherein the underground formation comprises a permeability from 0.0001 to 15 Darcies.

15. The method of any one of claims 10 to 14, further comprising converting at least a portion of the recovered oil and/or gas into a material selected from the group consisting of 22 transportation fuels such as gasoline and diesel, heating fuel, lubricants, chemicals, and/or polymers.

16. The method of any one of claims 10 to 15, further comprising converting at least a portion of the recovered oil and/or gas into an ether, and injecting the ether into an underground formation.

17. The method of claim 16, wherein injecting the ether formulation comprises injecting a mixture of the other formulation and water, the water further comprising a water soluble polymer adapted to increase a viscosity of the mixture.

18. The method of any one of claims 10 to 17, further comprising producing the ether formulation on an offshore structure from a starting material comprising synthesis gas, methanol, or mixtures thereof.

19. The method of any one of claims 10 to 18, further comprising reducing a bubble point of the oil in the formation with the ether formulation.

20. The method of any one of claims 10 to 19, further comprising increasing the swelling of the oil in the formation with the ether formulation.

21. The method of any one of claims 10 to 20, further comprising reducing the viscosity of the oil in the formation with the ether formulation.

22. A method comprising: recovering a carbon source from a formation; converting at least a portion of the carbon source to a synthesis gas; converting at least a portion of the synthesis gas to an ether; and injecting at least a portion of the ether and/or other liquids and/or gases into the formation at a pressure up to the fracture pressure of the formation.

23. The method of claim 22, further comprising converting the ether to a material selected from the group consisting of glycols, ethanol, methanol, or other alcohols; acetals; polyols; methyl isobutyl carbinol; butyl propionate, methyl acetate, ethyl acetate tertiary butyl acetate, or 23 other esters; methyl ethyl ketone, methyl isobutyl ketone, or other ketones; and/or one or more methanol derivatives and/or one or more ethanol derivatives.

24. A system for producing oil and/or gas from an underground formation, the system being substantially as hereinbefore described with reference to the accompanying drawings.

25. A method for producing oil and/or gas, the method being substantially as hereinbefore described with reference to the accompanying drawings. Dated 30 May 2012 Shell Internationale Research Maatschappij B.V. Patent Attorneys for the Applicant/Nominated Person SPRUSON & FERGUSON