• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    thermal combustion generator and systems and methods for improved oil recovery. this is an apparatus for generating combustion vapor which includes a combustion chamber having an inlet end and an emission end; a piping at the inlet end configured to introduce a fuel and an oxidant into the combustion chamber; an outer shell defining a cooling chamber between the outer shell and the combustion chamber; and a plurality of converging refrigerant inlets for conveying refrigerant from the refrigerant chamber into the combustion chamber at or near the emission end of the combustion chamber. the converging refrigerant inlets are radially disposed around the combustion chamber and preferably configured to produce a converging-diverging nozzle from the refrigerant led into the combustion chamber. the device can be used in systems and methods for improved recovery of underground hydrocarbons by positioning and operating in a wellbore, where the steam and flue gases produced are injected into a hydrocarbon formation in order to improve the recovery of hydrocarbon.
    公开号:BR112013012709B1
    申请号:R112013012709-0
    申请日:2011-11-22
    公开日:2021-06-29
    发明作者:James Andrew Prentice Iii
    申请人:Advanced Combustion Energy Systems,Inc；
    IPC主号:
    专利说明:

    CROSS REFERENCE TO RELATED ORDERS
    [0001] This patent application claims the benefit of U.S. Provisional Application No. 61/415,892, filed November 22, 2010, which is incorporated herein by reference in its entirety. BACKGROUND
    [0002] This invention relates, in general, to combustion devices, systems, and methods, including, but not limited to, devices, systems, and methods for generating steam, for example, for use in hydrocarbon production, and , in particular, improved production of heavy hydrocarbons from hydrocarbon subsurface formation.
    [0003] The development of oil fields generally takes place in three stages. The first stage of oil field development is primary recovery. During primary recovery, one or more holes are drilled from the surface below towards the hydrocarbon reservoir. The pressure present in the underground hydrocarbon reservoir forces the hydrocarbons through the wellbore to the surface. Primary recovery continues until the pressure in the hydrocarbon reservoir is insufficient to force the hydrocarbons through the wellbore to the surface. Typically, only 5 percent to 15 percent of the original oil in the reservoir can be recovered during the primary recovery stage.
    [0004] The second stage of oil field development is secondary recovery. During secondary recovery, various techniques can be used to recover hydrocarbons from pressure-depleted reservoirs. One technique, known as reservoir flow, involves injecting fluids, such as water, to increase reservoir pressure in order to force hydrocarbons through the wellbore to the surface. An alternative technique, known as a gas lift, involves injecting gases, such as carbon dioxide, to reduce the total fluid density in the wellbore. The formation pressure is then sufficient to force the less dense fluid through the wellbore. Pumps can sometimes be used to extract surface oil from the hydrocarbon reservoir. Typically, only 20 percent to 40 percent of an original reservoir oil can be extracted by primary and secondary recovery.
    [0005] The third stage of oil field development is tertiary recovery, also known as enhanced oil recovery (EOR). Following secondary recovery, a large percentage of hydrocarbons remains trapped in the reservoir. During EOR, various methods are used to increase oil mobility in order to increase extraction. The most common method of EOR is steam injection. Typically, steam is produced using a surface steam generator, often part of a combined generation facility. Steam is then injected into the reservoir through a well hole where it heats the oil, thereby reducing its viscosity and making it easier to extract. Current steam-based oil recovery methods are only effective at about 762 meters (2500 feet) due to heat and pressure losses. Surface steam production also undesirably generates substantial greenhouse gas emissions.
    [0006] An alternative method of EOR is carbon dioxide flooding, in which carbon dioxide is injected into an oil reservoir where it mixes with the oil, reducing its viscosity and making it easier to extract . Carbon dioxide flooding is particularly effective in reservoirs deeper than 609.6 meters (2,000 feet) where carbon dioxide is in a very critical state. Other alternative EOR methods include injection fluids that reduce viscosity and increase flow into the hydrocarbon reservoir. Such fluids can include gases that are miscible with oil, air, oxygen, polymer solutions, gels, polymer surfactant formulations, alkaline polymer surfactant formulations, or microorganism formulations. Current EOR methods typically allow only an additional 5 percent to 15 percent of a reservoir oil to be recovered.
    [0007] The amount of hydrocarbons that are recoverable is determined by a number of factors including reservoir depth, rock permeability, and the strength of natural agents, such gas pressure, adjacent water pressure, or gravity. A significant factor is the viscosity of hydrocarbons in the reservoir. The viscosity of hydrocarbons ranges extensively from light to heavy. Lighter oils typically result in higher extraction rates. On the other hand, heavy oil, bitumen, and methane hydrate are highly viscous or solids and almost impossible to extract using conventional oil production methods. Heavy oil is typically classified as an oil that has an API gravity of about 10 to about 20 and a viscosity greater than about 100 cP. Bitumen is a semi-solid or solid hydrocarbon substance that typically has an API of less than about 10 and a viscosity of more than about 10,000 cP. Methane hydrate is a solid form of methane trapped within a crystal structure of water. Heating methane hydrate can release gaseous methane from its crystal lattice structure.
    [0008] Heavy oil and bitumen reserves below 762 meters (2,500 feet) on land and all depths offshore cannot be produced using current steam technology. According to a study by the National Institute for Petroleum and Energy Research (NIPER), more than half of the remaining 68 billion barrels of heavy oil reserves in the United States are below 762 meters (2,500 feet). A Technical, Economic, and Legal Assessment of North American Heavy Oil, Oil Sands, and Oil Shale Resources, US Department of Energy, http://fossil.energy.gov/programs/oilgas/publications/oilshale/HeavyOilLowRes.pdf . If half of the heavy oil and oil sands deposits in the US and Canada were brought to market, they alone could satisfy the current demand for crude oil in both countries for over 150 years. America's Oil Shale: A Roadmap from Federal Decision Making, US Department of Energy, http://fossil.energy.gov/programs/reserves/npr/publications/oil_shale_roadmap.pdf.
    [0009] Accordingly, it would be highly desirable to provide devices, systems, and methods for the improved production of hydrocarbons from hydrocarbon subsurface formation. It would be particularly desirable to provide devices, systems, and methods for extracting heavy oil, bitumen, and/or methane hydrate deposits, especially at depths greater than 762 meters (2,500 feet).
    U.S. Patent Documents 4,604,988 and 7,780,152 disclose efforts to solve this problem by providing a well interior steam generator. However, improvements are needed to provide combustion devices that are more efficient, reliable, and/or durable in long-term continuous use. SUMMARY
    [0011] In one aspect, a combustion vapor generating apparatus is provided. In one embodiment, the device includes a combustion chamber having an inlet end and an outlet end; a piping housing connected to the inlet end and configured to introduce a fuel and an oxidizer into the combustion chamber; an outer coating defining a cooling chamber between an inner surface of the outer coating and an outer surface of the combustion chamber; and a plurality of converging refrigerant inlets for conveying refrigerant from the refrigerant chamber to the combustion chamber at or near the combustion chamber outlet end, wherein a plurality of converging refrigerant inlets are radially disposed about the combustion chamber. A plurality of converging refrigerant inlets can be configured to produce a converging-diverging nozzle from the refrigerant conducted in the combustion chamber. The apparatus may further include an exit flame diffuser located in fluid communication with the exit end of the combustion chamber. The apparatus is preferably sized to fit within industry standard well casings and/or to pass through the standard helical sweeps used in horizontal wells.
    [0012] In another aspect, systems and methods are provided for extracting oil from an oil formation that includes a first well bore to deliver steam and/or other hot gases to a hydrocarbon reservoir; and an advanced thermal combustion generator device, wherein the apparatus can be located inside the well in the first well hole. The device can be located deeper than 2500 feet (762 meters) in the first well hole. The system may include a second wellbore to extract hydrocarbons from the hydrocarbon reservoir.
    [0013] In a further aspect, methods are provided for producing steam. Methods can include introducing a fuel and an oxidizer into an inlet end of a combustion chamber; combust the fuel and the oxidant in the combustion chamber to produce a combustion product; flowing water into a refrigerant chamber defined between an outer casing and an outer surface of the combustion chamber at or near the inlet end of the combustion chamber; draining water from the refrigerant chamber, through a plurality of converging refrigerant inlets arranged radially around the combustion chamber, and in the combustion chamber at or near the combustion chamber outlet end, so that the water forms a nozzle convergence-divergence through which the product of combustion flows, with the water becoming heated by the product of combustion to form steam.
    [0014] In yet another aspect, methods are provided for extracting hydrocarbons from a hydrocarbon formation. Methods may include arranging an apparatus having a combustion chamber in a wellbore; introducing a fuel and an oxidizer into an inlet end of a combustion chamber; combusting the fuel and oxidant in the combustion chamber to produce a combustion product; flowing water into a refrigerant chamber defined between an outer casing and an outer surface of the combustion chamber at or near the inlet end of the combustion chamber; draining water from the refrigerant chamber, through a plurality of converging refrigerant inlets arranged radially around the combustion chamber, and in the combustion chamber at or near the combustion chamber outlet end, so that the water forms the neck a convergence-divergence nozzle through which the combustion product flows, whereby water becomes heated by the combustion product to form steam; injecting the combustion product and/or steam in the hydrocarbon formation; and extracting the hydrocarbons from hydrocarbon formation. In a variation, the apparatus having a combustion chamber is disposed in a wellbore at a depth of at least 762 meters (2,500 feet) below the surface.
    [0015] In yet another aspect, a method is provided for forming a convergence-divergence nozzle. The method can include combusting a fuel and an oxidant in a cylindrical combustion chamber to form a combustion product; and injecting water into a rear end of the cylindrical combustion chamber through a plurality of water inlets radially disposed around the cylindrical combustion chamber. In a particular embodiment, the flux rate of the combustion product accelerates the speed of sound as it converges.
    [0016] In yet another aspect, a convergence-divergence nozzle device is provided which includes an elongated annular tube having a tube wall defining a flow channel; and a nozzle located at least partially within the elongated annular tube, the nozzle having a converging section, a neck, and a diverging section, wherein the nozzle is formed by a gas flowing through the tube and a liquid flowing through a plurality of openings radially disposed around the tube wall and extending therethrough, the longitudinal axis of each opening extending at an angle in the direction of gas flow. BRIEF DESCRIPTION OF THE DRAWINGS
    [0017] Figure 1 is a plan view, with a sectioned portion, describing an embodiment for a combustion vapor generating apparatus, as described herein.
    [0018] Figure 2 is a cross-sectional view of an embodiment of an apparatus for generating combustion vapor, as described herein.
    [0019] Figure 3 is an exploded view of an embodiment of a combustion apparatus for generating steam, as described herein.
    [0020] Figure 4 is a perspective view of an outer end portion of one embodiment of a piping housing of an apparatus for generating combustion steam, as described herein. (Only the piping housing is shown; other components are omitted for clarity.)
    [0021] Figure 5 is a perspective view of the opposite side of the pipe housing of Figure 4.
    [0022] Figure 6 is a graph illustrating temperature, pressure, and velocity curves through a convergence-divergence nozzle according to an embodiment of the present disclosure.
    [0023] Figure 7 is a close-up perspective view of a portion of an embodiment of a combustion apparatus for generating steam, wherein the outer coating is omitted to reveal the exterior of the combustion chamber and a plurality of refrigerant inlets convergent.
    [0024] Figure 8 is a perspective view of the combustion chamber outlet end portion according to one embodiment of an apparatus for generating combustion vapor, as described herein.
    [0025] Figure 9 is a schematic diagram illustrating a system for extracting oil from an oil formation according to one embodiment of the systems and methods described in this document.
    [0026] Figure 10 is a schematic diagram illustrating a system for extracting oil from an oil formation according to another embodiment of the systems and methods described in this document.
    [0027] Figure 11 is a graph illustrating the cost per barrel of oil produced using steam injection at varying well depths.
    [0028] Figure 12 is a cross-sectional view of one embodiment of a convergence-divergence nozzle device as described herein. DETAILED DESCRIPTION
    [0029] The present devices, systems and methods may be more clearly understood by reference to the following detailed description of preferred embodiments of the invention, and by reference to the drawings in which like numerals indicate similar elements in all separate views.
    [0030] Devices, systems, and methods for producing steam are provided that include an improved design of a combustion apparatus that introduces refrigerant into the exit end portion of the combustion chamber to advantageously blend the refrigerant with the combustion product gases , to efficiently produce a high-speed, high-quality steam. The design can beneficially cause the soda to form a convergence-divergence nozzle, which, unlike the solid continuous-use nozzle subjected to continuous use, will not wear out (due to the fact that the water in the nozzle is shaped to water is continually replaced). This is a substantial advantage in terms of durability and commercial viability. In a preferred embodiment, the present steam generating devices and systems are advantageously operable continuously or continuously over an extended period, such as several days, months, or even years.
    [0031] Among other possible uses, these devices, systems, and methods are particularly useful for improved hydrocarbon extraction from the hydrocarbon reservoir or hydrocarbon formation. The device can be placed inside the well in a well casing to produce steam at the interface of a hydrocarbon formation, thereby efficiently distributing steam, carbon dioxide, and other flue gases to the hydrocarbon formation while minimizing losses of surface. These devices, systems, and methods are also useful for dislodging and fluidizing oil in existing oil wells that are considered dry (non-economic, minimally productive, or non-productive) or that are unrecoverable through any other existing technology.
    These devices, systems, and methods are particularly useful for extracting heavy oil, bitumen, and/or methane hydrate deposits. As used herein, "heavy oil" is a highly viscous oil that has an API gravity of about 10 to about 20 and a viscosity greater than about 100 cP. As used herein, "bitumen" is a semi-solid or solid hydrocarbon substance that has an API of less than about 10 and a viscosity greater than about 10,000 cP. The devices, systems, and methods of the present invention are not depth-limited and can be useful for extracting hydrocarbons at all depths, including depths greater than 762 meters (2,500 feet). The devices, systems, and methods can be used either on land or offshore. I. Combustion Apparatus/Steam Generator
    [0033] In one embodiment, apparatus for generating combustion vapor is provided which includes: (a) a combustion chamber having an inlet end and an outlet end; (b) a piping housing connected to the inlet end of the combustion chamber that is configured to introduce a fuel and an oxidizer into the combustion chamber; (c) an outer coating defining a cooling chamber between an inner surface of the outer coating and an outer surface of the combustion chamber; and (d) a plurality of converging refrigerant inlets for conveying refrigerant from the refrigerant chamber to the combustion chamber. In certain embodiments, a plurality of converging refrigerant inlets may be configured to produce a refrigerant convergence-divergence nozzle led to the combustion chamber. Such an apparatus or device may be referred to herein as an advanced thermal combustion generator (“ACTG”) device.
    [0034] As shown in Figure 1, the ACTG 10 device is generally cylindrical in shape. The ACTG device 10 includes an outer casing 11, a pipe housing 12, and an outlet flame diffuser 13. The outer casing 11, the pipe housing 12, and the outlet flame diffuser 13 are assembled and formed together. the outer portion of the ACTG device 10. The tubing housing 12 can be connected to the outer casing 11 in any suitable way. In one embodiment, the tubing housing 12 includes a threaded portion that is screwed together with a threaded inner portion of the outer casing 11 to form a gas and fluid seal. The outgoing flame diffuser 13 can also be connected to the outer casing 11 in any suitable way. In the embodiment shown, the trailing end of the outer casing 11 is connected to the outgoing flame diffuser 13 by a plurality of screws 14 radially disposed around the trailing end of the outer casing 11. The screws engage threaded holes in the flame diffuser of outlet 13 thereby creating a gas and fluid seal between the outer casing 11 and the outlet flame diffuser 13.
    [0035] The piping housing 12 of the ACTG 10 device is connected to a control line 15 that connects the ACTG 10 device to the surface (above the ground). Control line 15 can optionally be a coiled tubing control line made of armored steel umbilical cable. Control line 15 includes a fuel line 16, an oxidizer line 17, and a coolant line 18. The fuel line 16, oxidant line 17, and coolant line 18 are connected to a fuel source, and an oxidant source, and a coolant source, respectively, which can be located on the surface. In one embodiment, fuel line 16, oxidizer line 17, and coolant line 18 are inch stainless steel tubes. The control line can optionally also include one or more data and power lines. The control line can also optionally include one or more lines for lubricants or other miscellaneous needs.
    [0036] The ACTG 10 device is compact and can be sized for positioning inside the hole in the wellbore of an oil well. The ACTG 10 device can be used in both vertical and horizontal wells. The ACTG 10 device can be sized to fit industry standard well casings. Well casings are high strength steel cables that are typically 6 to 12 meters (20 to 40 feet) in length. Well casings are bolted together to form a casing string and are inserted into the bore of a wellbore. Typically, well casings are held in place with cement. Industry standard oil well casing includes, without limitation, 12.7 cm(5 inches), 15.2 cm(6 inches), and 17.7 cm(7 inches) standard liners. The ACTG 10 device can also be compact enough to accommodate standard helical sweeps used in horizontal wells, such as the horizontal wells used in steam-assisted gravity drainage (see Figure 9, described below). Steam-assisted gravity drainage is an improved oil recovery technique in which a pair of horizontal wells are drilled into an oil reservoir. One of the horizontal wells is located above the other well. The low pressure vapor is continuously injected into the upper wellbore to heat the oil and reduce its viscosity, causing the heated oil to drain into the lower wellbore where it is pumped to the surface.
    [0037] As shown in Figure 2, the ACTG device 10 may be disposed in a wellbore 19 that has a wellbore wall 20. A wellbore casing 21 covers the outside of the wellbore 19. A plug 22 is located in the annular space between the ACTG device 10 and the wellbore casing 21. The plugs seal the devices used to isolate zones within the well casings. The plug provides an annular seal between the outer casing 11 and the wellbore casing 21 to prevent the flow of steam, flue gases, oil or other fluids above the casing string towards the surface. The plug also holds the ACTG 10 device in place in the center of the wellbore. In other embodiments of the invention, the plug may provide an annular seal between the outer casing and a wall of a wellbore. Standard oil well plugs can be used in accordance with embodiments of the invention.
    [0038] The piping housing 12 of the ACTG device 10 is connected at one end to a fuel line 16 and an oxidizer line 17. The fuel line 16 is connected to a fuel source, which may be located on the surface. The term "fuel" as used herein means any substance or material that is consumed to produce energy, including, without limitation, natural gas, hydrogen, methane, ethane, propane, butane, gasoline, diesel fuel, kerosene, fuel oil , methanol, or alcohol, or combinations thereof. In a preferred modality, the fuel is methane or natural gas. The oxidizer line 17 is connected to an oxidizer source, which may be located on the surface. In accordance with the embodiments of the invention, the oxidant may include any source of gaseous or liquid oxidant, including, without limitation, air, gaseous oxygen (GOX), liquid oxygen (LOX), O, O3, H2O2, or HAN, or combinations of the same. In a preferred embodiment, the oxidant is GOX.
    [0039] An oxidizer, such as GOX, travels through the oxidizer line 17 to a peg 23, which is secured to the pipe housing 12. The peg 23 can be generally cylindrical in shape and can fit into a cylindrical hole through piping housing 12. Pin 23 can be secured to the piping housing in any suitable manner. In one embodiment, pin 23 includes a threaded portion that is screwed together with a threaded inner portion of tubing housing 12 to form a gas-fluid seal. Oxidant flows through pin 23 at an inlet end of a combustion chamber 24. Combustion chamber 24 may be cylindrical in shape. A fuel, such as methane, travels through the fuel line 16, which is connected to the piping housing 12. An inner surface of the piping housing 12 and an outer surface of the pin 23 defines a fuel runner 25. The fuel flows from fuel line 16 through fuel corridor 25 at an inlet end of combustion chamber 24. Fuel and oxidant may mix at or near an inlet end of combustion chamber 24.
    [0040] The components of the ACTG 10 device can be formed from any suitable material, examples of which include metals and high temperature alloys, which include, but are not limited to, nickel chromium alloys known in the art. In one embodiment, one or more of the components are made from Hanyes™ 230™ Alloy (Haynes International, Kokomo, Indiana, U.S.A.).
    [0041] The pipe housing 12 of the ACTG device 10 is also connected at one end to a power line 26. The power line 26 is connected to a power source, which may be located on the surface. In an alternative embodiment, the invention may include an integrated power supply, such as a battery. An embodiment of the invention may also optionally include one or more power and/or data lines. A power or data line may comprise one or more optical power or data fiber lines. The power line 26 is connected to an ignitor system 27. The ignitor system may comprise a multiple spark arrester (MSD) ignition systems. The ignitor system may comprise a spark plug, oxidant supply, and/or fuel supply. An embodiment of the invention may optionally include a fiber optic data line to control the ignitor at the point of combustion. The fiber optic data line can transfer data to a computer control program on the surface. The ACTG device 10 may also include one or more sensors, for example temperature and/or pressure sensors, which are known in the art. The fiber optic data line can also transfer data from such sensors to a computer control program on the surface. When the ignitor system 27 is activated, a spark or flame passes through the ignition flame torch aisle 28. The spark or flame causes the fuel and oxidant to ignite in the combustion chamber 24. The combustion of the fuel and oxidant in the chamber of combustion 24 produces a product of combustion. The combustion product can include carbon dioxide and steam. Combustion of fuel and oxidant in combustion chamber 24 also produces thermal energy.
    [0042] The piping housing 12 of the ACTG device 10 is also connected at one end to a refrigerant line 18. The refrigerant line 18 is connected to a source of refrigerant, which may be located on the surface. In accordance with embodiments of the invention, the refrigerant may include water or another substance or material that has suitable refrigerating properties. In a preferred embodiment, the soda is water. Refrigerant can be injected through a series of refrigerant paths 29 in pipe housing 12. Refrigerant can pass through a series of refrigerant paths 29 in a refrigerant chamber 30. The refrigerant chamber 30 is defined by an inner surface of the coating. external 11 of the ACTG device 10 and an external surface of the combustion chamber 24.
    [0043] The coolant passes through the coolant chamber 30 and thereby provides cooling to the combustion chamber 24. An inner surface of the outer casing 11 and/or an outer surface of the combustion chamber 24 may have helical grooves or flutes. Such grooves or ridges include any helical pattern, both raised and lowered, on the surface of a wall of refrigerant chamber 30. Such helical grooves can promote a helical, or spiral, flow path of refrigerant through refrigerant chamber 30. A helical flow path or spiral provides more distribution/linear flow of refrigerant in the refrigerant chamber and/or can increase turbulence, thereby reducing unwanted critical points that may otherwise have a tendency to form in the combustion chamber 24 and/or refrigerant chamber. 30.
    [0044] A plurality of converging refrigerant inlets 31 is provided at or near an outlet end of the combustion chamber 24 thereto. The converging refrigerant inlets are holes extending through a wall of the combustion chamber 24 that form a flow path for conveying refrigerant from the refrigerant chamber 30 to the combustion chamber 24. The converging refrigerant inlets 31 are radially disposed around the refrigerant chamber. combustion 24. Refrigerant flows through the converging refrigerant inlets 31 to the combustion chamber 24 at or near the combustion chamber outlet end 24. The converging refrigerant inlets 31 are configured to produce a convergence-divergence nozzle 9 of the driven refrigerant to the combustion chamber 24. The convergence-divergence nozzle is described in more detail in section II below. Coolant flows through converging coolant inlets 31 in combustion chamber 24 at an angle to the flux path of combustion product through combustion chamber 24. In a preferred embodiment, the angle is between about 25 and about 35 degrees in flow path (i.e., between about 25 and about 35 degrees to the geometric axis of the combustion chamber 24). In another preferred embodiment, the angle is about 30 degrees to the flow path (i.e., about 30 degrees to the geometric axis of combustion chamber 24).
    [0045] The combustion product accelerates through the convergence-divergence nozzle formed by the flow of refrigerant in the combustion chamber 24 and passes through the combustion chamber outlet end 24. The combustion chamber outlet end is connected to a The outgoing flame diffuser 13 by a plurality of screws 14 radially arranged around the rear end of the outer casing 11. The outgoing flame diffuser 13 is in fluid communication with the outgoing end of the combustion chamber 24. The flame diffuser output 13 is generally cylindrical in shape. A plurality of holes 32 are provided in the walls of the outgoing flame diffuser 13. The combustion chamber 24 and/or outgoing flame diffuser 13 form a diverging section 33 of the convergence-divergence nozzle formed by the flow of coolant through the converging water inlets 31. The outgoing flame diffuser 13 can control the impact of the flame from the combustion chamber 24 to the well casing 21. The outgoing flame diffuser 13 can also provide cooling to the combustion chamber 24, thereby providing a homogeneous mixture to the exhaust flame. The outgoing flame diffuser 13 can also provide transfer of additional thermal energy from the combustion product to the refrigerant, thereby increasing steam production. A mixture of combustion product and steam may exit through the exit flame diffuser holes 32 and/or an exit end of the exit flame diffuser to the well bore 19.
    [0046] Figure 3 provides another view to understand the components of the ACTG device 10. Specifically, Figure 3 shows a pin 23, a pipe housing 12, a combustion chamber 24, an outer casing 11 and a flame diffuser of outlet 13. The ACTG device 10 can exist as an assembly, as shown in Figures 1 to 2. The ACTG device 10 is assembled by connecting the bolt 23 into the pipe housing 12, for example, by screwing in an external threaded portion of the bolt 23 in an inner threaded portion of the pipe housing 12. The pipe housing 12 is connected to the combustion chamber 24, for example, by bolting an inner threaded portion of the combustion chamber 24 to an outer threaded portion of the pipe housing 12. The surface of the combustion chamber 24 has helical grooves 39 in accordance with a preferred embodiment. Alternatively or additionally, an inner surface of the outer coating 11 may have helical grooves in accordance with the preferred embodiment of the invention. The outer casing 11 fits by the combustion chamber 24 and connects to the pipe housing 12, for example, by bolting a threaded inner portion of the outer casing 11 to a threaded outer portion of the pipe housing 12. When assembled, the space annular between the outer casing 11 and the combustion chamber 24 defines a cooling chamber (not shown). The output flame diffuser 13 connects to the outer shell by a plurality of screws 14 radially arranged around the rear end of the outer shell 11. The screws engage with threaded holes 34 in the output flame diffuser 13, which creates such a forms a gas and fluid seal between the outer casing 11 and the outgoing flame diffuser 13. When assembled, the outgoing flame diffuser 13 is in fluid communication with the combustion chamber 24.
    [0047] Details of one embodiment of the pipe housing 12 are shown in Figures 4 and 5. The pipe housing 12 includes a fuel inlet 35, an oxidant inlet 36, a coolant inlet 37 and a power systems inlet and data 38. Fuel inlet 35 may be connected to a fuel line. The fuel line can, in turn, be connected to a fuel source, which can be located on the surface of the well. The oxidizer input 36 can be connected to an oxidizer line. The oxidizer line can, in turn, be connected to an oxidizer source, which can be located on the surface. Refrigerant inlet 37 can be connected to a refrigerant line. The refrigerant line can, in turn, be connected to a refrigerant source, which can be located on the surface. Input from power and data systems 38 may be connected to power and/or data lines. The power and/or data lines can, in turn, be connected to a power source, computer, and/or control systems, which can be located on the surface. It is anticipated that the number and/or placement of any of these entries may vary.
    [0048] As shown in Figure 5, the pipe housing 12 is connected to a pin 23. Oxidant flows from an oxidizer line through the pin 23 in the combustion chamber. The pipe housing 12 and pin 23 together form a fuel corridor 25 through which fuel flows from a fuel line in the combustion chamber. Refrigerant flows from a refrigerant line through a series of refrigerant paths 29 in piping housing 12 into a refrigerant chamber formed by the outer casing and the combustion chamber. The piping housing 12 also includes an ignition flame torch path 28. An ignitor system may be located within the piping housing 12. When the ignitor system is activated, a spark or flame may pass through the flame torch path. 28 and can cause fuel and oxidant to ignite in the combustion chamber. II. Convergence-divergence nozzle
    [0049] The ACTG device can be configured so as to produce a convergence-divergence nozzle from the coolant conducted in the combustion chamber. A convergence-divergence nozzle, also known as a Laval (or DeLaval) nozzle, is a device that accelerates a high-temperature, high-pressure gas to a supersonic velocity. Typically, this is a tube that is compressed in half to form a balanced asymmetrical hourglass shape. An exemplary convergence-divergence nozzle is shown and described in U.S. Patent No. 4,064,977, which is incorporated herein by reference in its entirety.
    [0050] Generally, a convergence-divergence nozzle includes a convergence section, a neck and a divergence section. It is usually made of steel, copper, graphite or another type of ablative material that is susceptible to wear over time.
    [0051] A convergence-divergence nozzle operates by forcing a constant mass flow rate of gas through an orifice with a small cross section. From the point of view of the gas in the convergence section, the nozzle is a hole or “bottleneck” that leads to an area of low pressure. As the gas approaches the bottleneck, it starts to accelerate. The gas continues to accelerate towards the neck, finally reaching the speed of sound in the neck. “Velocity of sound”, as used herein, is the speed of sound in hot gas, not the speed of sound in air at ground level under ambient conditions. The speed of sound in hot gas is typically 2-3 times faster than the speed of sound in air at ground level at ambient conditions, depending on temperature.
    [0052] After the gas reaches a sonic velocity at the neck, it flows into the divergence section, where the gas expands and cools, pushes laterally at an oblique angle to the wall and accelerates to supersonic velocities. A bell-shaped divergence section of the nozzle provides maximum efficiency, but a simple cone-shaped divergence section provides 99 percent efficiency and can provide a more cost-effective construction. The divergence section of the nozzle can increase the gas velocity by 2.7 times the speed of sound or more, depending on the exact ratio of the cross-sectional area at the neck to the cross-sectional area at the outlet from the nozzle.
    [0053] The nozzle works to convert the potential energy of high temperature and high pressure gas into kinetic energy. Due to the high temperature and high velocity of the gases passing through the neck of a common convergence-divergence nozzle, the nozzle neck can corrode, which results in unwanted increases in neck diameter and decreases in chamber pressure and gas velocity . Corrosion in the nozzle neck essentially limits the life of the nozzle and the runtime of the device incorporating the nozzle.
    [0054] Advantageously, the advanced combustion thermal generators described herein use convergence-divergence nozzles formed by the flow of coolant, which is preferably water, rather than by mechanical means such as a metal neck. According to the above, the device can operate for years underground without needing to replace components such as the device mouthpiece.
    [0055] In one aspect, a method is provided for forming a convergence-divergence nozzle by combustion of a fuel and an oxidant in a cylindrical combustion chamber to form a combustion product and by injecting water into a rear end of the chamber. cylindrical combustion through a plurality of converging water inlets radially disposed around the cylindrical combustion chamber. Water is injected into the combustion chamber at an angle to the geometric axis of the cylindrical combustion chamber in an effective manner to cause the combustion product to converge by decreasing the effective cross-sectional area of the combustion chamber. The water being pushed through the combustion chamber eventually reaches a density such that the gas can no longer be compressed and the water thus establishes the neck of the Laval nozzle. In a preferred embodiment water may be injected at an angle between about 25 degrees and about 35 degrees to the geometric axis of the cylindrical combustion chamber. In another preferred embodiment, water can be injected at an angle of about 30 degrees to the geometric axis of the combustion chamber. In another preferred embodiment, the flux rate of the combustion product accelerates to the speed of sound as it converges.
    [0056] Figure 6 is a graph illustrating temperature, pressure and velocity curves along a convergence-divergence nozzle according to an embodiment of the devices and systems described in this document. As the combustion product flows through the combustion chamber, it approaches the exit end of the combustion chamber and enters the converging section of the nozzle. As it converges, the combustion product accelerates and the temperature and pressure begin to decrease. In the neck that is formed by the flow of water in the combustion chamber, the velocity increases significantly for sonic velocities and the temperature and pressure of the gases drop accordingly. As the combustion product exits the neck and enters the divergence section of the combustion chamber and/or outgoing flame diffuser, velocity increases to supersonic speeds and pressure and temperature drop further.
    [0057] Therefore, it will be noted that the refrigerant can serve at least two purposes in the device. First, the refrigerant provides cooling to the combustion chamber as it flows through the refrigerant chamber. Second, injecting refrigerant into the combustion chamber at an angle to the geometric axis of the combustion chamber can create a convergence-divergence nozzle to accelerate the velocity of the combustion product and vapor discharged from the ACTG. It will also be appreciated that the refrigerant, fuel and/or oxidant flow rate may be variable and adjustable so that as the pressure of hydrocarbons in the hydrocarbon formation changes, the refrigerant flow rate may change in accordance with the above to compensate for these changes. Therefore, the flow rate of coolant, fuel, and/or oxidizer can be adjusted to provide an injectable flow rate of gases in optimal formation and performance of device modalities. It will also be appreciated that the flow of combustion product and coolant causes minimal or no corrosion to the surfaces of the device embodiments.
    [0058] The water injected into the cylindrical chamber through the converging water inlets can exit the outgoing flame diffuser and mix with the combustion product. There, water can convert to steam and exit the ACTG device in the wellbore or hydrocarbon formation.
    [0059] The exit end of the combustion chamber 24 is detailed in Figures 7 and 8. As shown in Figure 7, an exit end of a combustion chamber 24 is connected to an exit flame diffuser 13. The outer jacket that would normally confine the combustion chamber 24 and define a refrigerant chamber is not shown for the purpose of simplifying the fundamental structures. A plurality of converging coolant inlets 31 are radially disposed around the combustion chamber 24. A plurality of converging coolant inlets 31 extend through the combustion chamber wall 24 at an angle to the direction of combustion product flow through the combustion chamber. combustion 24. The converging refrigerant inlets are configured to produce a convergence-divergence nozzle from the refrigerant conducted in the combustion chamber. In a preferred embodiment, the angle of the converging refrigerant inlets is between about 25 degrees and about 35 degrees. In another preferred embodiment, the angle of the converging refrigerant inlets is about 30 degrees.
    [0060] In Figure 8, the outgoing flame diffuser that would normally connect the outgoing end of the combustion chamber is omitted to show the inner wall at the outgoing end of the combustion chamber 24. The converging refrigerant inlets 31 are configured to produce a convergence-divergence nozzle of the refrigerant injected into the combustion chamber 24. To form a convergence-divergence nozzle, water (refrigerant) is injected through the converging water inlets 31 at an angle to the geometric axis of the cylindrical combustion chamber 24 The flowing combustion product pushes water through the outer end of the combustion chamber 24. The water reduces the effective cross-sectional area of the combustion chamber 24 and establishes the neck of a convergence-divergence nozzle. In a preferred embodiment, the flux rate of the combustion product accelerates to the speed of sound as it converges. As the combustion product exits the neck, it enters a divergence section 33 of the combustion chamber and/or exit flame diffuser. In the divergence section 33, the internal diameter of the flow path increases and the gas velocity can increase to supersonic velocities. III. Systems and Methods for Improved Oil Recovery
    [0061] Systems and methods for producing steam and extracting hydrocarbons from the hydrocarbon reservoir or hydrocarbon formation are provided in accordance with certain embodiments described herein. Such systems include the ACTG devices described herein positioned within the well to produce steam and carbon dioxide for improved recovery of oil or other hydrocarbons.
    [0062] ACTG devices can be used to reduce or eliminate surface vapor losses that occur in common vapor injection enhanced oil recovery systems and methods. Advantageously, ACTG devices can deliver steam directly to a reservoir interface. Such modalities may be particularly useful for reservoirs at depths above 762 meters (2500 feet) and/or reservoirs comprising heavy oil or bitumen. Such modalities are also used in offshore or near offshore reservoirs and to extract heavy oil or bitumen under pergesol conditions. The quality of steam produced by ACTG devices can be controlled as needed. For example, modalities can produce steam qualities between about 10 percent and about 95 percent or more. In one embodiment, the quality of steam produced is from about 75 percent to about 95 percent, such as from about 85 percent to about 95 percent. In preferred embodiments, the ACTG device produces steam at a steam quality between 90 percent and 100 percent, available for hydrocarbon formation.
    [0063] Systems are provided to extract hydrocarbons from a hydrocarbon formation. Systems for improved oil recovery include a first wellbore to deliver steam and/or other hot gases to a hydrocarbon reservoir and an advanced combustion thermal generating device of an embodiment of the present invention (see descriptions in sections I and II above ). The ACTG device can be located inside the well in the first hole of the well. Steam and/or other hot gases can provide heating for the hydrocarbons in the formation to reduce viscosity and/or vaporize some of the hydrocarbons. In a preferred embodiment, the hydrocarbon reservoir can include heavy oil, bitumen, methane hydrate or a combination thereof.
    [0064] Systems for improved oil recovery optionally may additionally include a second wellbore to extract hydrocarbons from a hydrocarbon reservoir. Either or both of the first and second wellbore holes may be vertical wellbore in accordance with various embodiments of the devices, systems and methods disclosed herein. Alternatively, either or both of the first and second wellbore holes may include at least one horizontal section. An ACTG device can be located at any point in the wellbore that includes either a vertical section or a horizontal wellbore section. An ACTG device can also be located at any depth in the wellbore. The ACTG device is particularly advantageous in uses where the ACTG device is positioned to a depth below the surface of more than 762 meters (2,500 feet).
    [0065] Systems for improved oil recovery optionally may additionally include a casing string extending from about the top of the first wellbore to about the bottom of the first wellbore. In a preferred embodiment, an ACTG device can be located within the casing string.
    [0066] Systems for improved oil recovery may additionally include a fuel source, an oxidant source and/or a coolant source. The fuel source, oxidizer source, and/or coolant source may be connected to an ACTG device by a coiled tubing control line. The wound tubing control line can optionally include a fuel feed line and oxidizer feed line and/or a coolant feed line. The wound tubing control line can optionally also include a fiber optic data line and/or a power line.
    [0067] As shown in Figure 9, a steam assisted gravity drainage system using an ACTG device as described in this document can be used. The system includes a first wellbore 50 for delivering steam and/or other hot gases to a hydrocarbon reservoir 51 (the “Steam Injection Well Bore”). In a preferred embodiment, the hydrocarbon reservoir includes heavy oil, bitumen and/or methane hydrate. The system also includes a second wellbore 52 to extract hydrocarbons from hydrocarbon reservoir 51 (the “Production Wellhole”). An ACTG device 10 is located inside the well in the casing string of the first wellbore 50. The ACTG device is connected to a source of water, fuel and surface oxidants through a control line 58 which includes a supply line of water 59, a fuel feed line 60 and an oxidant feed line 61. In alternative embodiments, the control line may further comprise a fiber optic data line and/or a power line.
    [0068] The first wellbore includes a vertical section 53 and a horizontal section 54. The ACTG device 10 is sized to fit within the wellbore 50 and sized to pass through the helical sweep 55 used in the horizontal wellbore. The second wellbore hole also includes a vertical section 56 and a horizontal section 57. The horizontal section of the second wellbore hole is located under the horizontal section of the first wellbore hole.
    [0069] The ACTG device 10 can generate steam and flue gas by the methods described in this document. For example, the ACTG device 10 can generate steam and flue gas by introducing a fuel and an oxidant into an inlet end of a combustion chamber, combusting the fuel and oxidant in the combustion chamber to produce a combustion product, flowing water into a refrigerant chamber defined between an outer casing and an external surface of the combustion chamber at or near the inlet end of the combustion chamber and flowing water from the refrigerant chamber, through a plurality of radially disposed converging refrigerant inlets around of the combustion chamber, and in the combustion chamber at or near the exit end of the combustion chamber, such that the water forms a convergence-divergence nozzle through which the combustion product flows, the water becomes heated by the product of combustion to form vapour. In a preferred embodiment, fuel, oxidant, and water can be metered to produce steam at a pressure of about 827 KPa (120 psig) to about 20.3 MPa (2,950 psig). In another preferred embodiment, fuel, oxidant, and water can be metered to produce steam at a steam quality of about 75 percent to about 99 percent, such as about 85 percent to about 95 percent. cent.
    [0070] The steam and flue gas can be injected into the wellbore 50 and/or hydrocarbon formation 51 by the ACTG device 10. In a preferred embodiment, the ACTG device 10 is positioned at a depth greater than 762 meters ( 2,500 feet) and the steam and flue gas are injected into wellbore 50 and/or hydrocarbon formation 51 to a depth greater than 762 meters (2,500 feet). In a preferred embodiment, steam is injected into the hydrocarbon formation 51 at a pressure of about 827 KPa (120 psig) to about 20.3 MPa (2,950 psig). In another preferred embodiment, steam is injected into the hydrocarbon formation 51 at a steam quality of between about 75 percent and about 95 percent. In another preferred embodiment, the combustion product comprises at least 50 percent carbon dioxide. In another preferred embodiment, carbon dioxide is a supercritical fluid. In another preferred embodiment, carbon dioxide is injected into the hydrocarbon formation in an amount effective to decrease the viscosity of the hydrocarbons in the hydrocarbon formation 51. In another embodiment, the carbon dioxide swells the oil and/or increases the flow transmission of the oil.
    [0071] The injection of steam and flue gas (which includes carbon dioxide) in the hydrocarbon reservoir 51 causes a decrease in the viscosity of the hydrocarbons in the reservoir 51. The less viscous hydrocarbons flow to the horizontal portion 57 of the second hole of well 52. A production plant 62 on the surface of the second hole of well 52 extracts hydrocarbons from the hydrocarbon formation.
    [0072] Figure 10 shows a steam flood system that uses an ACTG device as described in this document. The system includes a first wellbore 63 for delivering steam and/or other hot gases to a hydrocarbon reservoir 64. In a preferred embodiment, the hydrocarbon reservoir includes heavy oil, bitumen, and/or methane hydrate. The system also includes a second wellbore 65 for extracting hydrocarbons from hydrocarbon reservoir 64. Both the first wellbore 63 and the second wellbore 65 are vertical wellboreholes.
    [0073] An ACTG device (not shown) is located inside the well in the casing string of the first hole of well 63. In a preferred embodiment, the ACTG device is located at a depth of at or greater than 762 meters (2500 feet). ). The steam and combustion product produced by the ACTG device are injected into the hydrocarbon reservoir 64. In this mode, the steam and hot gases form a steam front that heats the hydrocarbons, lowers the viscosity of the hydrocarbons and pushes the hydrocarbons towards the borehole. production well 65. A production plant 66 on the surface of production well hole 65 extracts hydrocarbons from the hydrocarbon formation.
    [0074] Unlike common vapor-based improved oil recovery techniques, the present devices and systems are not limited by depth. In accordance with the above, the devices, systems and methods can reduce the cost of producing oil, particularly at depths below about 457 meters (1,500 feet). Figure 11 is a graph illustrating the cost per barrel of oil produced by using steam injection at varying well depths. Curves a, b and c reveal the cost per barrel of oil recovered using surface steam in varying steam qualities. Curve a reveals the cost per barrel of oil recovered using surface steam at 40 percent quality and 0.92 kg/sec injection rate. Curve b reveals the cost per barrel of oil recovered using surface steam at 80 percent quality and 0.92 kg/sec injection rate. Curve c reveals the cost per barrel of oil recovered using surface steam at 80 percent quality and an injection rate of 2.75 kg/sec.
    [0075] Curve d reveals the cost per barrel of oil recovered by using a modality of the systems and devices described in this document. Unlike surface steam, the cost per barrel of oil recovered using the present devices and systems does not vary appreciably with well depth. Therefore, these devices, systems, and methods offer cost advantages over common improved oil recovery methods, particularly for deep or heavy deposits.
    [0076] Figure 12 shows the flow of refrigerant to form a convergence-divergence nozzle in an ACTG device 10. As described in section I above, the ACTG device 10 includes a combustion chamber 24 and an outer shell 11 defining a refrigerant chamber 30. In operation, refrigerant fills refrigerant chamber 30. A plurality of converging refrigerant inlets 31 are radially disposed around combustion chamber 24. Refrigerant flows from refrigerant chamber 30 through converging refrigerant inlets 31 in the combustion chamber 24 at or near the outlet end of the combustion chamber 24. The converging coolant inlets 31 are configured to produce a convergence-divergence nozzle 9 from coolant conducted in the combustion chamber 24. The convergence-divergence nozzles are described in more details in section II above. After flowing in the combustion chamber 24, the coolant initially converges towards the centerline of the axis of the combustion chamber 24, but is forced outward to the wall of the combustion chamber by the force of the combustion product flow. The refrigerant, being an incompressible fluid, forms a layer of water concentric with a wall of the combustion chamber. This concentric water layer serves as a bottleneck through which the combustion product must flow. The Combustion Product, from the combustion chamber, can accelerate through the convergence section and the neck to sonic or supersonic velocities. After the neck, combustion product and refrigerant flow to a divergence section 33 and an outlet flame diffuser 13. A plurality of holes 32 are provided in the walls of the outlet flame diffuser 13. In the divergence section 33 and in the 13 output flame diffuser, the combustion product can continue to accelerate to supersonic speeds. In one embodiment, the refrigerant is water and is heated by the combustion product in the divergence section 33 and/or the outgoing flame diffuser 13. In another embodiment, the divergence section 33 is integrated with or forms a part of the diffuser. exit flame 13. The conversion of water to steam is revealed by the shading in Figure 12. A mixture of combustion product and steam may exit the ACTG device 10 and be injected into a wellbore and/or a hydrocarbon formation.
    [0077] Devices and systems for improved oil recovery may optionally include other standard well production equipment; shutter(s); a controller system for measuring process conditions (eg temperature, pressure) and adjusting pressures and fluid flow rates for an ACTG device. Advantageously, the device or system can be controlled to manage production from the reservoir. For example, the flow of oxidizer, fuel, and coolant can be regulated to deliver the desired amount of steam and pressure (eg, steam can be delivered from 827 KPa (120 psig) to 20.3 MPa (2,950 psig)).
    [0078] The devices, systems, and methods disclosed here can also be used in a large-scale surface steam configuration for shallow wells, tar sands, and gravel. Fuel to steam thermal conversion efficiencies above 99 percent, almost penalty-free compression, and 50 percent ratio of pure carbon dioxide as a combustion by-product can be achieved by such a model.
    [0079] The devices and systems for improved oil recovery of the present invention optionally can also deliver chemical payloads into the well for formation as needed. For example, depositors may include flame front control, oxidant delivery for in situ combustion and underground coal gasification. Such modifications and adaptations are within the skill of a person skilled in the art and are intended to be within the scope of the appended claims.
    [0080] The publications cited herein and the materials to which they are cited are specifically incorporated by reference in their entirety without admission that such document is prior art. Modifications and variations of the devices, systems, and devices described herein will be obvious to those skilled in the art from the foregoing detailed description. Such modifications and variations are intended to be within the scope of the appended claims.
    权利要求:
    Claims (18)
    [0001]
    1. Apparatus for generating combustion vapor within the well, comprising: a combustion chamber (24) having an inlet end and an outlet end; a piping housing (12) connected to the inlet end and configured for introducing a fuel and an oxidant into the interior of the combustion chamber (24); an outer coating (11) defining a cooling chamber (30) between an inner surface of the outer coating and an outer surface of the combustion chamber (24); plurality of converging refrigerant inlets (31) for conducting refrigerant from the refrigerant chamber (30) into the combustion chamber (24) at or near the combustion chamber outlet end (24), the plurality of inlets being converging coolants is radially disposed around the combustion chamber (24); the apparatus is further characterized by: an outgoing flame diffuser (13) located in fluid communication with the end combustion chamber outlet (24), wherein the plurality of converging refrigerant inlets (31) is configured to produce a converging and neck section of a converging-diverging nozzle (9) from the refrigerant conducted in the combustion chamber. (24), and wherein the combustion chamber (24) and/or the outgoing flame diffuser (13) has a divergence section (33) configured to produce the divergence section of the convergence-divergence nozzle (9) .
    [0002]
    2. Apparatus according to claim 1, characterized in that the plurality of converging refrigerant inlets (31) extends through a combustion chamber wall (24) at an angle to the combustion product flow direction through the combustion chamber (24).
    [0003]
    3. Apparatus according to claim 2, characterized in that the angle is between 25 and 35 degrees.
    [0004]
    4. Apparatus according to any one of claims 1 to 3, characterized in that the outgoing flame diffuser (13) is cylindrical in shape and comprises a plurality of inlets in its walls.
    [0005]
    5. Apparatus according to any one of claims 1 to 3, characterized in that it additionally comprises a bolt (23) to deliver the oxidant inside the combustion chamber (24).
    [0006]
    6. Apparatus according to any one of claims 1 to 3, characterized in that it additionally comprises an ignitor system (27) to burn the fuel in the combustion chamber (24).
    [0007]
    7. Apparatus according to any one of claims 1 to 3, characterized in that an inner surface of the outer casing (11) and/or an outer surface of the combustion chamber (24) have helical grooves to generate a trajectory of helical flow of refrigerant through the refrigerant chamber.
    [0008]
    8. Apparatus according to any one of claims 1 to 3, characterized in that it further comprises a shutter (22) wherein the shutter provides an annular seal between the outer casing (11) of the apparatus and a bore casing the well or wellbore wall (21).
    [0009]
    9. A system for extracting oil from an oil formation, characterized in that it comprises: a first well hole for delivering steam and/or other hot gases to a hydrocarbon reservoir; and the apparatus as defined in claim 1, wherein the apparatus is located within the well in the first well bore.
    [0010]
    10. System according to claim 9, characterized in that it further comprises a second well hole to extract hydrocarbons from the hydrocarbon reservoir.
    [0011]
    11. System according to claim 9 or 10, characterized in that the device is located at a depth greater than 760 meters.
    [0012]
    12. System according to claim 9 or 10, characterized in that it further comprises a coiled tubing control line, wherein the coiled tubing control line comprises a fuel supply line, a fuel supply line oxidizer and a coolant supply line.
    [0013]
    13. System according to claim 12, characterized in that the coiled tubing control line further comprises fiber optic data line.
    [0014]
    14. Method for producing steam, characterized in that it comprises: introducing a fuel and an oxidant into an inlet end of a combustion chamber of the apparatus for generating combustion steam as defined in any one of claims 1 to 13; combust the fuel and oxidant in the combustion chamber to produce a combustion product; drain water into a refrigerant chamber defined between an outer shell and an outer surface of the combustion chamber at or near the inlet end of the combustion chamber; water from the refrigerant chamber, through a plurality of converging refrigerant inlets radially disposed around the combustion chamber, and into the combustion chamber at or near the outlet end of the combustion chamber, such that water form a convergence-divergence nozzle through which the combustion product flows, the water becoming heated by the combustion product. are to form the vapor.
    [0015]
    15. Method according to claim 14, characterized in that it further comprises passing water from the convergence-divergence nozzle and the combustion product into an outgoing flame diffuser, which is connected to one end combustion chamber outlet.
    [0016]
    16. Method for extracting hydrocarbons from a hydrocarbon formation, characterized in that it comprises injecting the combustion product and/or steam produced by the method defined in claim 14 into the hydrocarbon formation, in which the combustion chamber is part of an apparatus positioned within a wellbore; and extract hydrocarbons from hydrocarbon formation.
    [0017]
    17. Method according to claim 16, characterized in that the apparatus is disposed in the wellbore at a depth equal to or greater than 762 meters (2500 feet).
    [0018]
    18. Method according to claim 16 or 17, characterized in that the steam is injected into the hydrocarbon formation at a pressure of about 827 KPa (gauge) (120 psig) to about 20.3 MPa (gauge ) (2950 psig).
    类似技术:
    公开号 | 公开日 | 专利标题
    BR112013012709B1|2021-06-29|THERMAL COMBUSTION GENERATOR AND SYSTEMS AND METHODS FOR IMPROVED OIL RECOVERY
    US9528359B2|2016-12-27|Downhole steam generator and method of use
    US4366860A|1983-01-04|Downhole steam injector
    CN106062307B|2019-06-04|Oil-producing system and method
    US20160123128A1|2016-05-05|Gas injection apparatus with controllable gas injection point, gas injection process, and gasification method
    CA2782308A1|2013-01-13|Geometry of steam assisted gravity drainage with oxygen gas
    CN103917744A|2014-07-09|Steam flooding with oxygen injection, and cyclic steam stimulation with oxygen injection
    EA024367B1|2016-09-30|Process and apparatus for enhancing recovery of hydrocarbons from wells
    WO1996003566A2|1996-02-08|Improvements in or relating to drilling with gas liquid swirl generator hydrocyclone separation combustion thermal jet spallation
    RU2571120C2|2015-12-20|Underground heating device
    CN204476383U|2015-07-15|Heat storage type combustion heater in a kind of well
    US20170247994A1|2017-08-31|Thermally Assisted Oil Production Wells
    CN103313798B|2016-11-30|Combustion heat generator and the system and method for the oil exploitation for strengthening
    CN104653158B|2018-03-23|Heat storage type combustion heater in a kind of well
    US20140166279A1|2014-06-19|Extended reach steam assisted gravity drainage with oxygen |
    RU2567583C1|2015-11-10|Method of viscous oil development, device for its implementation and bottomhole gas generator
    RU2579061C1|2016-03-27|Method for mine production-wells of hard | oil and system of equipment therefor
    CN106996285A|2017-08-01|Underground mixed phase heated fluid generator and its application method
    RU159925U1|2016-02-20|DEVICE FOR HEATING PRODUCTIVE OIL-CONTAINING LAYER
    RU2693098C1|2019-07-01|Method of gas-hydraulic impact on formation
    CN205383646U|2016-07-13|Ignition device
    CA2835759C|2021-05-25|Extended reach steam assisted gravity drainage with oxygen |
    CN112302598A|2021-02-02|System and method for generating steam underground in ultra-deep heavy oil reservoir
    Hascakir et al.2018|Heavy Oil Extraction in Texas with a Novel Downhole Steam Generation Method: A Field-Scale Experiment
    OA11815A|2005-08-16|Pulsed combustion device and method.
    同族专利:
    公开号 | 公开日
    US20140008063A1|2014-01-09|
    RU2586561C2|2016-06-10|
    WO2012071444A1|2012-05-31|
    CA2818692A1|2012-05-31|
    PL2643093T3|2020-04-30|
    MX2013005748A|2013-12-06|
    RU2013126047A|2014-12-27|
    US8544545B2|2013-10-01|
    CN103313798A|2013-09-18|
    EP2643093B1|2019-08-21|
    MX336102B|2016-01-08|
    DK2643093T3|2019-11-18|
    US8794321B2|2014-08-05|
    BR112013012709A2|2016-09-06|
    US20120125610A1|2012-05-24|
    EP2643093A4|2017-10-11|
    CA2818692C|2019-02-19|
    EP2643093A1|2013-10-02|
    引用文献:
    公开号 | 申请日 | 公开日 | 申请人 | 专利标题
    DE2310614C2|1973-03-02|1986-10-23|Douglas P. Grand Island N.Y. Taylor|Hydraulic shock absorber|
    US4079784A|1976-03-22|1978-03-21|Texaco Inc.|Method for in situ combustion for enhanced thermal recovery of hydrocarbons from a well and ignition system therefor|
    US4456068A|1980-10-07|1984-06-26|Foster-Miller Associates, Inc.|Process and apparatus for thermal enhancement|
    US4385661A|1981-01-07|1983-05-31|The United States Of America As Represented By The United States Department Of Energy|Downhole steam generator with improved preheating, combustion and protection features|
    US4452309A|1982-09-13|1984-06-05|Texaco Inc.|Method and means for uniformly distributing both phases of steam on the walls of a well|
    US4604988A|1984-03-19|1986-08-12|Budra Research Ltd.|Liquid vortex gas contactor|
    RU2046933C1|1992-04-01|1995-10-27|Рузин Леонид Михайлович|High viscous oil production method|
    GB2364383A|1997-05-02|2002-01-23|Baker Hughes Inc|Avoiding injection induced fracture growth in a formation during hydrocarbon production|
    NZ567052A|2003-04-24|2009-11-27|Shell Int Research|Thermal process for subsurface formations|
    US7028478B2|2003-12-16|2006-04-18|Advanced Combustion Energy Systems, Inc.|Method and apparatus for the production of energy|
    US7640987B2|2005-08-17|2010-01-05|Halliburton Energy Services, Inc.|Communicating fluids with a heated-fluid generation system|
    CA2641727C|2006-01-09|2013-07-30|Direct Combustion Technologies|Direct combustion steam generator|
    RU2316648C1|2006-07-18|2008-02-10|Открытое акционерное общество "Российская инновационная топливно-энергетическая компания" |Downhole steam-gas generator|
    US7712528B2|2006-10-09|2010-05-11|World Energy Systems, Inc.|Process for dispersing nanocatalysts into petroleum-bearing formations|
    US7983886B2|2007-09-10|2011-07-19|Chevron U.S.A. Inc.|Methods for performing simulation of surfactant flooding of a hydrocarbon reservoir|
    US7938183B2|2008-02-28|2011-05-10|Baker Hughes Incorporated|Method for enhancing heavy hydrocarbon recovery|US9732605B2|2009-12-23|2017-08-15|Halliburton Energy Services, Inc.|Downhole well tool and cooler therefor|
    CA2760312A1|2010-12-09|2012-06-09|Mgm Energy Corp.|In situ process to recover methane gas from hydrates|
    US10119374B2|2012-03-12|2018-11-06|Total Sa|Method for simulating fluid flows, a computer program and a computer readable medium|
    US8827176B2|2012-07-05|2014-09-09|James A. Browning|HVOF torch with fuel surrounding oxidizer|
    CN102818250B|2012-08-13|2014-09-03|山东华曦石油技术服务有限公司|Method and device for improving steam dryness of steam injection boiler|
    WO2014107159A1|2013-01-04|2014-07-10|Pratt & Whitney Rocketdyne, Inc.|Direct steam generator co2 removal system|
    US20150083388A1|2013-09-25|2015-03-26|Megat Ltd.|Steam-impulse pressure generator for the treatment of oil wells|
    CA2853115C|2014-05-29|2016-05-24|Quinn Solutions Inc.|Apparatus, system, and method for controlling combustion gas output in direct steam generation for oil recovery|
    US9828842B2|2014-09-30|2017-11-28|Elwha Llc|Systems and methods for releasing methane from clathrates|
    US20160265410A1|2015-03-10|2016-09-15|Borgwarner Inc.|Exhaust heat recovery and storage system|
    CN105222150A|2015-10-22|2016-01-06|上海华之邦科技股份有限公司|A kind of mist vapour mixing arrangement reducing NOx emission|
    EP3394538A4|2015-12-22|2019-09-04|Eastman Chemical Company|Supersonic separation of hydrocarbons|
    WO2017112419A1|2015-12-22|2017-06-29|Eastman Chemical Company|Supersonic treatment of vapor streams for separation and drying of hydrocarbon gases|
    CN106917615B|2015-12-28|2019-09-10|中国石油天然气股份有限公司|The recovery method and device of heavy crude reservoir|
    AU2016420451A1|2016-08-24|2019-01-24|ZhongweiEnergy Technology Co. Ltd|Production well apparatus for underground coal gasification and use thereof|
    US10352120B2|2016-11-01|2019-07-16|Baker Hughes, A Ge Company, Llc|Liquid fuel powered packer setting tool|
    US10352119B2|2016-11-01|2019-07-16|Baker Hughes, A Ge Company, Llc|Hydrocarbon powered packer setting tool|
    CN106761680B|2017-01-17|2019-08-02|西南石油大学|A kind of judgment method of chemical viscosity reduction auxiliary threaded rod pump lifting heavy oil process|
    CN106996283A|2017-06-10|2017-08-01|大庆东油睿佳石油科技有限公司|The oil production method of spontaneous mixed phase hot fluid under a kind of hydrothermal cracking surge well|
    CN107013198A|2017-06-10|2017-08-04|大庆东油睿佳石油科技有限公司|A kind of cluster horizontal well net mixed phase hot fluid gravity drainage oil production method|
    CN106988717B|2017-06-10|2019-11-05|利辛县雨若信息科技有限公司|A kind of ground supply system for underground mixed phase heated fluid generator|
    CN106996284A|2017-06-10|2017-08-01|大庆东油睿佳石油科技有限公司|One kind utilizes oleic acid mixture upgrading combination mixed phase hot fluid oil flooding method|
    CN106988716A|2017-06-10|2017-07-28|大庆东油睿佳石油科技有限公司|A kind of row's formula horizontal-well network combines spontaneous underground mixed phase hot fluid oil production method|
    CN107023281A|2017-06-10|2017-08-08|大庆东油睿佳石油科技有限公司|A kind of spontaneous underground mixed phase hot fluid gravity drainage oil production method|
    US20190017696A1|2017-07-12|2019-01-17|Lawrence Bool|Method for Enhancing Combustion Reactions in High Heat Transfer Environments|
    WO2019123571A1|2017-12-20|2019-06-27|日揮株式会社|Methane gas production equipment and methane gas production method|
    US20190353185A1|2018-05-17|2019-11-21|Q.E.D. Environmental Systems, Inc.|Bi-directional, water separating flow nozzle|
    CN111664447A|2020-06-01|2020-09-15|贺克平|Combustion heater for thick oil thermal recovery|
    RU2759477C1|2020-10-13|2021-11-15|Общество с Ограниченной Ответственностью "МЕГАТ"|Steam pulse pressure generator|
    法律状态:
    2018-12-18| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2020-03-10| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2021-01-19| B06A| Patent application procedure suspended [chapter 6.1 patent gazette]|
    2021-05-18| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2021-06-29| B16A| Patent or certificate of addition of invention granted [chapter 16.1 patent gazette]|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 22/11/2011, OBSERVADAS AS CONDICOES LEGAIS. |
    2022-02-22| B16C| Correction of notification of the grant [chapter 16.3 patent gazette]|Free format text: REF. RPI 2634 DE 29/06/2021 QUANTO AO ENDERECO. |
    优先权:
    申请号 | 申请日 | 专利标题
    US41589210P| true| 2010-11-22|2010-11-22|
    US61415892|2010-11-22|
    PCT/US2011/061905|WO2012071444A1|2010-11-22|2011-11-22|Combustion thermal generator and systems and methods for enhanced oil recovery|
    [返回顶部]