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    • 专利摘要:
    Heating System for Underground Mineral Formation and Method for Heating the Same A heating system for underground mineral formation according to the modalities of the present invention includes a coating positioned in a hole in the underground mineral formation, the coating having an outer surface and a surface internal, a heating element positioned inside the coating, a surface connection system that has a first end coupled to the heating element inside the coating and a second end on a top soil surface above the underground mineral formation, a heat transfer fluid contained within the liner, the heat transfer fluid being configured to transfer heat between the heating element and the inner surface of the liner, where at least part of the heat transfer fluid is undergoing changes in phase between liquid and gas in order to regulate r the coating temperature. Fins can be included on the outside of the jacket in order to improve heat transfer.
    公开号:BR112012027326B1
    申请号:R112012027326-4
    申请日:2011-04-27
    公开日:2020-12-01
    发明作者:James R. Mcconaghy；Len Switzer；Alan K. Burnham；Roger L. Day
    申请人:American Shale Oil, Llc；
    IPC主号:
    专利说明:

    [0001] [001] This application claims the benefit of US Provisional Patent Application no. 61 / 328.519, filed on April 27, 2010, which is incorporated herein by reference in its entirety for all purposes. TECHNICAL FIELD
    [0002] [002] The modalities of the present invention relate to systems and methods for uniform heating of underground formations to recover mineral deposits. BACKGROUND
    [0003] [003] The in situ extraction of minerals often involves the application of heat to improve the reduction of viscosity, updating and partial decomposition and solubility. Examples of fossil fuels subject to extraction in situ are oil sands, oil shale and coal. In some cases, uniformity in the application of heat is desirable, because too little heat can reduce the extent of the desired changes which facilitating extraction and too much heat can degrade the desired products into less valuable products. For example, effective heat transfer around mineral deposits promotes sufficient cracking and hydrogenation in situ for recovery of petroleum sands and petroleum shale to provide superior quality of synthetic crude oil without cracking a substantial part of the less valuable gas and coke formation.
    [0004] [004] Effective extraction of valuable products from one of these types of mineral formations involves the distribution of heat over a large volume of ore. Consequently, it is desirable to apply heat at a higher possible temperature. However, heterogeneities in geology can affect the rate at which the formation can accept and dissipate heat. If the heater power is constant throughout its length, it can cause overheating or underheating in parts of the formation that dissipate heat more quickly or more slowly than average. This overheating or overheating can cause local subcoversion or degradation of the product.
    [0005] [005] Some existing systems designed to prevent overheating involve electric heaters with limited temperatures that are designed for mineral extraction in situ. The temperature limit allows the maximum allowed power to be applied to the entire formation, even when the heat reception varies with the location in the formation. The resistance of the heating elements or dielectrics in the heaters is often dependent on the temperature, so that the power decreases as a target temperature is reached to prevent overheating. Such methods can, for example, use the driver's Curie point to change his resistance to a desired maximum temperature. SUMMARY
    [0006] [006] A heating system for an underground mineral formation according to the modalities of the present invention includes a coating positioned in a hole in the underground mineral formation, the coating having an external surface and an internal surface, a heating element positioned inside of the coating, with a surface connection system having a first end coupled to the heating element inside the coating and a second end to a top soil surface above the underground mineral formation and a heat transfer fluid inside the coating, the heat transfer fluid being configured to transfer heat between the heating element and the inner surface of the liner, where at least part of the heat transfer fluid is undergoing phase changes between the liquid and gas in order to regulate the coating temperature.
    [0007] [007] A method for heating an underground mineral formation according to the modalities of the present invention includes placing a coating inside a hole in the underground mineral formation, the coating having an outer surface and an inner surface, a heating element positioned inside the liner and a heat transfer fluid inside the liner. The method also includes supplying energy to the heating element and causing at least part of the heat transfer fluid to undergo phase changes between the liquid and gas in order to regulate the coating temperature, transferring the transfer fluid heat from the heating element to the coating.
    [0008] [008] A heating system for an underground mineral formation according to another embodiment of the present invention includes a coating positioned in a hole in the underground mineral formation, the coating having an outer surface and an inner surface, a heating element positioned in the interior of the coating, where the coating is at least partially immersed in a boiling fluid in the hole of the underground mineral formation, where the boiling fluid intensifies the heat transfer from the outer surface of the coating to the underground mineral formation and a plurality of fins on the outer surface of the coating, the plurality of fins being configured to intensify the rate of heat transfer between the coating and the underground mineral formation.
    [0009] [009] Although various embodiments are described, still other embodiments of the present invention will be apparent to those skilled in the art from the detailed description which follows, which shows and describes illustrative embodiments of the invention. Therefore, the drawings and detailed description should be considered as illustrative in nature and not restrictive. BRIEF DESCRIPTION OF THE DRAWINGS
    [0010] [0010] FIG. 1 illustrates a partial side sectional view of a heating system for an underground mineral formation, according to the modalities of the present invention.
    [0011] [0011] FIG. 2A illustrates a partial side sectional view of another heating system for an underground mineral formation, in accordance with embodiments of the present invention.
    [0012] [0012] FIG. 2B illustrates a front cross-sectional view of the heating system of FIG. 2A taken at a location of the heating element, in accordance with embodiments of the present invention.
    [0013] [0013] FIG. 3 illustrates a side and front perspective view of a heating system cover according to the modalities of the present invention.
    [0014] [0014] FIG. 4 illustrates a front and side perspective view of an alternative heating system cover according to the modalities of the present invention.
    [0015] [0015] FIG. 5 illustrates a graph showing a relationship between the heat transfer efficiency and the height of the fin for fins of two different thicknesses, according to the modalities of the present invention.
    [0016] [0016] FIG. 6 illustrates a front and side perspective view of the coating heating system of FIG. 3 with spacers, according to the modalities of the present invention.
    [0017] [0017] FIG. 7 illustrates a front elevation view of the jacket of the heating system of FIG. 6 positioned inside a well hole, according to the modalities of the present invention.
    [0018] [0018] FIG. 8 illustrates a front and side perspective view of the jacket of the heating system of FIG. 6 positioned inside a well hole, according to the modalities of the present invention.
    [0019] [0019] FIG. 9 illustrates a partial side sectional view of the heating system of FIG. 1 with a cover applied around the covering of the heating system, according to the modalities of the present invention.
    [0020] [0020] FIG. 10 illustrates a diagram of a heater test station control system, in accordance with embodiments of the present invention.
    [0021] [0021] FIG. 11 illustrates a heat transfer fluid filling diagram and a level control system, in accordance with embodiments of the present invention.
    [0022] [0022] FIG. 12 shows a flow chart illustrating a heat transfer fluid filling and leveling method, in accordance with embodiments of the present invention.
    [0023] [0023] Although the invention is susceptible to several modifications and alternative forms, the specific modalities have been shown by way of example in the drawings and are described in detail below. The intention, however, is not to limit the invention to the particular modalities described. On the contrary, the invention is intended to cover all modifications, equivalent and alternative, that fall within the scope of the invention as defined by the appended Claims. DETAILED DESCRIPTION
    [0024] [0024] FIG. 1 illustrates a heating system 1 for an underground mineral formation 50, in accordance with embodiments of the present invention. The heating system 1 includes a coating 2 positioned in a hole 10 in the underground mineral formation 50, and the coating 2 has an outer surface and an inner surface 12. A heating element 3 is positioned inside the coating 2. A heating fluid heat transfer fluid 140 is also contained within the liner 2, with the upper level of heat transfer fluid 140 being indicated by reference number 14. Heat transfer fluid 140 may be a heat transfer fluid selected from among listed in Table 1 or it may be another type of suitable heat transfer fluid. The heat transfer fluid 140 transfers heat between the heating element 3 and the inner surface 12 of the liner 2.
    [0025] [0025] According to some embodiments of the present invention, well bore 10 can be drilled at an angle to join a production well 11. Various systems and methods for extracting liquid shale oil or shale oil vapors are described in US Patent No. 7,921. 907, granted on April 12, 2011, which is incorporated herein by reference in its entirety for all purposes. The gravitational forces, for example, the primary downward gravitational force of the earth indicated by the arrow 15, the liquid shale oil forces 20 below the production well 11 and down to a bottom of the heater well 10 also . A higher level of liquid shale oil 20 is indicated in reference 13. The coating 2 has a distal end 8 and a proximal end 9 and the heating set 1 can be inserted and / or implanted inside the well 10, with the distal end 8 closer to the production well 11 than the proximal end 9, according to the modalities of the present invention. The elements of the heating assembly 1 of FIGs. 1, 2 and 9 can be substantially cylindrical or tubular, in order to facilitate their insertion in the holes and implantation in the well 10, according to the modalities of the present invention. As such, a longitudinal dimension of the heating system 1 is substantially aligned with the longitudinal dimension of the well hole 10, as illustrated in FIG. 1, according to embodiments of the present invention.
    [0026] [0026] The coating 2 is at least partially immersed in a boiling fluid 20 in the hole 10 of the underground mineral formation, according to the modalities of the present invention. The boiling fluid 20 intensifies the heat transfer from the outer surface of the coating 2 to the underground mineral formation 50 (for example, the mineral formation and / or kerogen around the well bore 10). According to some embodiments of the present invention, the boiling fluid 20 is shale oil. The boiling fluid 20 can, for example, be boiled at a temperature above 300 ° C. If there is no fluid 20 present in bore 10 or in places where fluid 20 is not present in the bore (for example, above level 13), heating system 1 heats the underground mineral formation 50 by thermal conduction through the coating 2 and in the underground mineral formation 50. In situations where the fluid 20 is present in the hole 10, the heating system 1 heats the underground mineral formation 50 by convection. In situations where the fluid 20 is boiling, the heating system 1 heats the underground mineral formation 50 by convection and reflux, according to the modalities of the present invention. This convection occurs along the direction of the arrows 16 as the heat rises, and at the liquid / gas interface 13, the shale oil vapors rise (indicated by the arrow 17), while some of the shale oil vapors condense and reflux in accordance with the present invention. According to some embodiments of the present invention, the heat transfer between the coating 2 and the surrounding underground formation 50 can be optimized (for example, to obtain the highest heat transfer coefficients) by adjusting the height differences between the levels 13 and 14.
    [0027] [0027] Within the liner 2, the heating element 3 has a distal end 7 and a proximal end 6, with the distal end 7 positioned closest to the distal end 8 of the liner 2 and the proximal end 6 positioned closest to the end proximal 9, according to the modalities of the present invention. A surface connection system 5, which can also be referred to as an "umbilical", has a first end coupled to the proximal end 6 of the heating element 3, and a second end on a top soil surface above the underground mineral formation. 50. The heating element 3 can be an electrical heating element, and the surface connection system 5 can supply electrical energy from an above-ground source. The surface connection system 5 can also include cables or other control or detection mechanisms connected to computers or other interface devices on the top surface, to allow monitoring and / or control of the heating element 3 and conditions in the interior of the heater 1 system and the well bore 10, according to the modalities of the present invention. The surface connection system 5 may also include one or more tubes or pipes to allow heat transfer fluid 140 to be added, subtracted or sampled from the top soil surface, in accordance with the modalities of the present invention. The surface connection system 5 can be flexible. According to some embodiments of the present invention, the surface connection system 5 can be used to remove and / or replace heat transfer fluid 140 and / or gases from the liner 2 to optimize performance. According to other embodiments of the present invention, the heat of the transfer fluid 140 can be circulated from the surface or with an internal or adjacent pump. According to some embodiments of the present invention, the level 13 of the heat transfer fluid 140 is higher, for example, less than five percent higher than the greater extent of the heating elements, for the electric heating elements.
    [0028] [0028] The heating element 3 may include one or more sets of heater elements or electric heaters, consisting of cables, strips and / or heating bars. For example, one or more electric heaters like Calrod® or mineral insulated (MI) cables. The energy supplied to the heating element 3 can be varied in order to adjust the heat transfer rate. If the heating elements are connected in a three-phase Wye configuration, it may be advantageous if the number of elements is a multiple of three.
    [0029] [0029] The modalities of the present invention involve the use of an intermediate boiling heat transfer fluid ("HTF") between the heating element and the formation to be heated to regulate the temperature at which the heat is distributed. Examples of fluids and their working temperature ranges are shown in Table 1. The temperature of the heat distribution is determined by the balance of heat input and extraction from HFT, and the pressure inside the heater varies with temperature. The heating element can be an electric heater or a burner, or any other heat transfer device or downhole heat generator, for example, a device that does not inherently include a mechanism to provide a uniform temperature throughout the part of the mineral formation to be heated. This may include, for example, a heat exchanger that has a non-uniform temperature along its length but, due to the intermediate heat transfer fluid, provides a more uniform temperature for the formation of oil shale or shale oil boiling.
    [0030] [0030] Table 1. Examples of heat transfer fluids:
    [0031] [0031] Within the liner 2, at least part of the heat transfer fluid 140 is undergoing phase changes between the liquid and gas in order to regulate the temperature of the liner 2. Once the heat transfer fluid 140 is subjected to a certain temperature and / or pressure, which causes it to boil, the heat transfer fluid vapors rise above level 14, in the direction of arrow 18, after which the vapors condense and return to the pool of liquid heat transfer fluid in the direction of arrow 19. As such, at least part of the heat transfer fluid 140 is undergoing a phase change between the liquid and gas, which serves to regulate the temperature of the coating 2. In in other words, the fluctuations in energy generated by the heating element 3 are absorbed by the heat transfer fluid 140, which uses the energy for the phase change process, keeping the heat transfer fluid at a temperature su substantially constant 140, thus uniformly heating coating 2 and preventing overheating coating 2 and thus liquid shale oil 20.
    [0032] [0032] The modalities of the present invention heat the shale oil 20 hot enough to distribute heat at a temperature suitable for the retort, in the desired period of time, but not so high that the shale oil 20 is cooked on the surface heater liner 2 or cracked for less valuable gas. The arrangement and use of heat transfer fluid 140 within the coating 2 allows the shale oil 20 to boil at a well-controlled and uniform temperature, according to the modalities of the present invention. FIG. 1 illustrates a heater system 1, in which a space between the heating element 3 and the coating 2 is unrestricted, to allow heat transfer from the heating element 3 to the coating 2 by free convection with the heat transfer fluid 140. In accordance with embodiments of the present invention, heat transfer fluid 140 is not aqueous, and a heat extraction rate from heating element 3 meets or exceeds 30 watts per square inch at temperatures above 350 ° C. In accordance with embodiments of the present invention, the heat transfer fluid 140 is non-aqueous, and the heat extraction rate of the heating element 3 exceeds 26 watts per square inch at temperatures greater than 300 ° C.
    [0033] [0033] Although FIG. 1 illustrates a longitudinal dimension of heating system 1 that extends at an angle to the gravitational force 15, according to some embodiments of the present invention, the longitudinal dimension of heating system 1 extends perpendicularly or substantially perpendicular to the direction of the gravitational force 15 (for example, in a "horizontal" direction) and, according to other embodiments of the present invention, the longitudinal dimension of the heating system 1 extends parallel or substantially parallel to the direction of the gravitational force 15 (for example , in a “vertical” direction). Numerous other orientations of the longitudinal dimension of the heating system 1, in relation to the gravitational force 15 can be used.
    [0034] [0034] FIGS. 2A and 2B illustrate another heating system 25, in an underground mineral formation 50, according to the modalities of the present invention. System 25 is similar to system 1, except that system 25 includes an optional guide tube 21 inside the liner 2. Guide tube 21 guides the convection of heat transfer fluid 140 away from heating element 3 in the inside the guide tube 21, as indicated by the arrows 22, and back to the heating element 3 on an external part of the guide tube 21, as indicated by the arrows 24, according to the modalities of the present invention. At the proximal end of the guide tube 21, the boiling heat transfer fluid 140 moves from the inside of the guide tube 21 out of the guide tube 21 as it condenses, as indicated by the arrows 23. Towards the distal end 8 of the liner 2, the heat transfer fluid 140 contacts the heating element 3, which may be a plurality of separate heating bars with spaces between them or that otherwise allow flow through the heating elements in direction 22 and again travels through the interior of the guide tube 21. This arrangement in system 25 results from a channeled convection, which can be a variation of the free convection of system 1.
    [0035] [0035] An absorption material (not shown), similar to that used in a conventional heat pipe, can be positioned between the outside of the guide tube 21 and the inner surface 12 of the liner to intensify the flow of fluid transfer fluid. condensed heat 140 back to the heating element 3, according to embodiments of the present invention. Such an absorbent material could force the condensed liquid heat transfer fluid 140 to flow into the boiling pool around heating element 3. As illustrated in FIGS. 1 and 2, the relative longitudinal lengths of the heated section and the condensation section (the level below the longitudinal length 14 (heated section) and above level 14 (condensation section)) can be varied. This can be achieved by, for example, adding or removing heat transfer fluid 140 from the coating 2. In system 1 of FIG. 1, most of the heat exchange occurs in the boiling heat transfer section below level 14. In system 1 of FIG. 1 and / or system 25 of FIG. 2, an optional circulation pump can be used to help circulate the heat transfer fluid 140 within the liner 2, in accordance with embodiments of the present invention.
    [0036] [0036] If the medium directly external to the liner 2 is a fluid instead of a solid, the fins can be placed outside the heater liner 2 to facilitate the transfer of heat to the fluid, especially if that fluid is used for heat distribution through convection formation. FIG. 3 illustrates a coating 32 whose outer surface includes a plurality of fins 33, 34, 35, which are configured to increase the heat transfer rate between the coating 32 and the underground mineral formation 50 according to the modalities of the present invention. The outer surface of the liner 32 is substantially cylindrical, on a longitudinal axis 38, and each fin among the plurality of fins 33, 34, 35 extends along the outer surface substantially parallel to the longitudinal axis 38, according to the modalities of the present invention. The fins may include gaps 36, 37 formed at longitudinal intervals. As illustrated in FIG. 3, the longitudinal intervals between the gaps 36 for a fin are the same, but longitudinally offset from the longitudinal intervals between the gaps 37 for an adjacent fin. The fins 33, 34, 35 intensify the heat transfer rate between the coating 32 and the underground mineral formation 50. According to an embodiment of the present invention, the fins 33 can be one inch high and 1/4 inch thick. width, the liner 32 can include 8 to 12 rows of fins 33, evenly spaced (equal radial angles between each row), with 12 to 24 inch fin sections separated by 3/4 inch gaps and / or with an offset gap of six inches between the rows. The fins 33 can be welded at both ends to fix them to the liner 32, according to the modalities of the present invention.
    [0037] [0037] FIG. 4 illustrates a coating 42 whose outer surface is substantially cylindrical, and from which a plurality of fins 43, 44, 45 protrude in a helical configuration. Each of the plurality of fins 43, 44, 45 may also include gaps 46 formed at longitudinal intervals, in accordance with embodiments of the present invention. According to an embodiment of the present invention, helical fins 43 are formed in segments that are 12 to 24 inches longitudinally, with the longitudinal segments being separated by a gap from half an inch to an inch.
    [0038] [0038] According to some embodiments of the present invention, the fins of a coating 2 are vertical strips in the coating orientations in which the longitudinal dimension of the coating 2 is vertical. According to other embodiments of the present invention, the fin configuration in which the fins are vertical discs (not shown) is used when the orientation of the liner 2 is horizontal or slightly inclined. According to still other embodiments of the present invention, if the coating 2 is positioned at an intermediate angle in relation to the horizontal and vertical positions, the fins 33 are strips with periodic gaps 36, as illustrated in FIG. 3, or helical strips 43 as illustrated in FIG. 4, to allow transversal and axial flow.
    [0039] [0039] According to the modalities of the present invention, the height of each fin is between 0.5 δ and 0.755δ, where δ is the height of the gap between the outer surface of the liner 2 and the inner surface 10 of the well, when the heater system 1 is centered in the well, according to the modalities of the present invention. The thickness of a fin can be selected by calculating the heat transfer efficiency for a fin and using an 80 to 90 percent efficiency point. FIG. 5 illustrates calculation examples for the heat transfer efficiency for a range of heat transfer coefficients and two fin thicknesses, as a function of the fin height, according to the modalities of the present invention. The 1/4 ”thick fin data is indicated by line 52, as well as the upper limit 53 and the lower limit 54, while the 1/8” thickness fin data is indicated by line 55, as well as upper limit 56 and lower limit 57. The desired design range is indicated by parenthesis 50.
    [0040] [0040] Due to the difficulty often encountered in perfectly centering a finned heater liner 62 in a well 10 of interest, the height of the fins or portions of the fins can be increased in order to create a gap for the passage of fluid around the fins lower. This is illustrated in FIGS. 6, 7, and 8. The fins 63 each include a spacer 64 that allows fluid to flow in at least one of a plurality of fins 63 when the spacer 64 is leaning against well 10, according to modalities of the present invention. Each fin 63 can include 64 multiple spacers, separated by a distance that is relatively greater than the length of the longitudinal gap between the gaps 36, 37, in accordance with embodiments of the present invention. For example, each of the spacers 64 can be 2 to 8 inches long (longitudinally), and the first set of spacers 64 can be placed on the fins 63 near the distal end of the fins 63, as illustrated in FIG. 6. The next set of spacers 64 can be placed on the fins 10 to 40 feet apart (longitudinally), according to the modalities of the present invention. According to one embodiment of the present invention, spacers 64 are 1/8 inches high and are positioned circumferentially around each fin 63. According to other embodiments, spacers 64 are placed in less than all fins 63, in particular, for liners 62, which can be oriented so that spacers 64 are oriented downwards for contact with well 10. Spacers 64 can be made by a weld bead, machined sheet metal, and / or a protrusion similar, and its longitudinal positioning can be selected to not allow the liner 62 to sag (thus closing the gap between fins 63 and well 10). FIGS. 7 and 8 illustrate the deployment of liner tubes 62 with eccentric positioning inside a well 10, and FIG. 8 illustrates a gap 82 at the bottom for the fluid to flow under the fins 63, in accordance with embodiments of the present invention.
    [0041] [0041] If the underground formation 50 is subject to rubblization (debris reduction), a cover 90 can be positioned on the coating 2 between the coating 2 and the well 10, as illustrated in FIG 9. Coverage 90 can be configured to prevent debris from depositing directly against the coating 2, which can reduce the heat transfer coefficient for the heating system 1, according to the modalities of the present invention. The cover 90 can be a solid tube or tube with open ends, and / or can have openings and / or perforations to enhance the desired convection pathways, in accordance with the modalities of the present invention. A debris-filled annular space decreases the heat transfer coefficient by a factor of 2 to 6 compared to an unobstructed annular space, according to the modalities of the present invention.
    [0042] [0042] In accordance with some embodiments of the present invention, a control system may be used to prevent overheating and overpressurization of the heat transfer fluid 140. Such a control system may include the ability to measure the temperature in one or more more locations within the heater 1 system, for example, one or more thermocouples and / or a high temperature fiber optic sensor, and / or a pressure gauge.
    [0043] [0043] The flow of heat distributable through the heater system 1 may depend on the ability of the surrounding material (eg formation 50) to dissipate the heat to the operating temperature. When immersed in a liquid 20, the highest heat transfer coefficients can be obtained. A test post was built to measure these heat transfer coefficients. A specific heater configuration using six 3/4 inch heating rods (as heating element 3) in a 4 inch diameter tube (as liner 2), has been tested on a diameter of 8 inches by 40 feet in length simulated well, as illustrated in FIG. 10. Heat transfer coefficients up to 26 W / m2-K were obtained when using Therminol® VP-1 as the heat transfer fluid 140 and immersing the heater in boiling fuel oil at 300 ° C. Dowtherm ATM can also be used as a heat transfer fluid.
    [0044] [0044] FIG. 10 also illustrates a VFD variable frequency drive pump that can be used in a closed circuit system to circulate the simulated fluid to be extracted (for example, diesel fuel used to simulate shale oil), and can also include a circuit refrigeration as shown to help condense any simulated extraction fluid boiling prior to its return to the system.
    [0045] [0045] FIG. 11 illustrates a diagram of a heat transfer fluid filler and an 1100 level control system, in accordance with embodiments of the present invention. System 1100 can be used to fill the liner with two heat transfer fluids 140 and includes a fill tube and a “spill” tube. The filler tube sends the heat transfer fluid to the heating system (eg heating system 1 or 25) and the “spill tube” can be used to assess head space and any excess transfer fluid of heat. A drain pipe, which can be attached to the bottom of the heating system, can be used to empty the heat transfer fluid by filling the gas heater and pushing the heat transfer fluid out, according to modalities of the present invention.
    [0046] o FECHAR V-5000, V-5010, & V-5012 o ABRIR NV-5000 a PI-5000 o QUEBRAR A ABERTURA DA VÁLVULA VAC / P DA CABEÇA DO POÇO [0046] FIG. 12 illustrates a flow chart 1200 illustrating a heat transfer fluid filling and leveling method, using the system 1100 of FIG 11, in accordance with embodiments of the present invention. In block 1202, the heater can be filled, for example, using the following steps: - CHECKING THE HEATER STATUS o CLOSE V-5000, V-5010, & V-5012 o OPEN NV-5000 to PI-5000 BREAK THE OPENING OF THE VAC / P VALVE OF THE WELL HEAD
    [0047] - SE PRESSIONADO, VENTILAR ATRAVÉS DE V-5000, V-5001 & V-5001 A - FECHAR V-5000 E OBSERVAR PI-5000 - SE HOUVER UM AUMENTO DE PRESSÃO EM 1 HORA HÁ UM VAZAMENTO DO INVÒLUCRO DO AQUECEDOR. PARAR! - SE NÃO HOUVER AUMENTO DE PRESSÃO - PROSSEGUIR [0047] In block 1204, the pressure indicator can be checked, for example, using the following steps: - IF PRESSED, VENT THROUGH V-5000, V-5001 & V-5001 A - CLOSE V-5000 AND OBSERVE PI-5000 - IF THERE IS AN INCREASE IN PRESSURE IN 1 HOUR THERE IS A LEAK IN THE HEATER HOUSING. STOP! - IF THERE IS NO PRESSURE INCREASE - PROCEED
    [0048] - ABRIR V-5000 E FECHAR V-5001 & V -5001 A - ABRIR O FORNECIMENTO DE N2 PARA V-5020 COM A PRESSÃO DE REGULADOR DE RECIPIENTE DE N2 A 50 PSI - FECHAR V-5012 & ABRIR NV-5004 PARA PI-5004 - QUEBRAR A ABERTURA V-5020 PARA PERMITIR O FLUXO DE N2. [0048] In block 1206, a continuity check can be performed, for example, using the following steps: - OPEN V-5000 AND CLOSE V-5001 & V -5001 A - OPEN N2 SUPPLY FOR V-5020 WITH N2 CONTAINER REGULATOR PRESSURE AT 50 PSI - CLOSE V-5012 & OPEN NV-5004 TO PI-5004 - BREAK OPENING V-5020 TO ALLOW N2 FLOW.
    [0049] - VERIFICAR PI-5004 - AUMENTAR O FLUXO DE N2 ATRAVÉS DE V-5020 ATÉ PI-5004 MOSTRAR 10 PSI OU A VÁLVULA SER COMPLETAMENTE ABERTA - VERIFICAR O FLUXO N2 NA VENTILAÇÃO DE TAMBOR E CONEXÕES, QUANDO O FLUXO É ESTABELECIDO, DESLIGAR O FORNECIMENTO DE N2 - A PRESSÃO DE PI-5004 DEVE CAIR PARA 0 PSIG. - SE SIM, A VERIFICAÇÃO É CONCLUÍDA. DESLIGAR O FORNECIMENTO DE N2. - FECHAR V-5020, V-5012 e NV-5004 - EVACUAR O REVESTIMENTO DE AQUECEDOR E INTERROMPER COM N2. [0049] In block 1208, the flow of nitrogen gas through the heater can be confirmed, for example, using the following steps: - CHECK PI-5004 - INCREASE N2 FLOW THROUGH V-5020 UNTIL PI-5004 SHOW 10 PSI OR THE VALVE IS COMPLETELY OPEN - CHECK THE N2 FLOW IN THE DRUM VENTILATION AND CONNECTIONS, WHEN THE FLOW IS ESTABLISHED, TURN OFF THE N2 SUPPLY - PI-5004 PRESSURE SHOULD FALL TO 0 PSIG. - IF YES, THE CHECK IS COMPLETED. TURN OFF THE N2 SUPPLY. - CLOSE V-5020, V-5012 and NV-5004 - EVACUATE THE HEATER COATING AND INTERRUPT WITH N2.
    [0050] [0050] In block 1210, the system can be preheated, for example, using the following steps: - FIX THE HEATED VP-1 DRUM TO THE FILLING COLLECTOR. KEEP A ~ 100F. - PRE-HEAT THE VP-1 LINES 5010, 501 1, 5012, 5013 AND 5015 FOR ~ 100F 1 WITH TRACKING. - PRE-HEAT THE WELL HEAD WITH HEATER BLANKET. - USE 200 F OF N2 TO PRE-HEAT THE 3/8 ”VP-1 FILLING LINE INSIDE THE WELL.
    [0051] - FECHAR NV-5000. AJUSTAR O REGULADOR DE FORNECIMENTO DE N2 PARA 100 PSIG. - ABRIR AS VÁLVULAS DE ENCHIMENTO & VCA/P NA CABEÇA DE POÇO. - INICIAR O FLUXO DE N2 PARA LINHA 5000. CONFIRMAR O FLUXO. - AJUSTAR TIC-5020 PARA 250F. - OBSERVAR TEMPERATURAS DE AQUECEDOR DE FUNDO DE POÇO (TI-XXX. TL-XXX) - QUANDO TODAS AS LINHAS ESTÃO QUENTES - COMEÇAR A ENCHER VP-1 (HTF). [0051] In block 1212, preheating can be carried out with hot nitrogen, for example, using the following steps: - CLOSE NV-5000. SET THE SUPPLY REGULATOR FROM N2 TO 100 PSIG. - OPEN THE FILLING VALVES & VCA / P IN THE WELL HEAD. - START THE FLOW FROM N2 TO LINE 5000. CONFIRM THE FLOW. - ADJUST TIC-5020 TO 250F. - OBSERVE WELL BACKGROUND TEMPERATURES (TI-XXX. TL-XXX) - WHEN ALL LINES ARE HOT - START FILLING VP-1 (HTF).
    [0052] ○ DESLIGAR P-5013 ○ FECHAR BV-5013, BV-5008E BV-5015 - REMOVER O TAMBOR “VAZIO” ○ PEGAR QUALQUER VAZAMENTO HTF E RETORNAR AO TAMBOR VAZIO. - PODE SER POSSÍVEL VER O NÍVEL NO SENSOR DE FIBRA ÓPTICA.[0052] In block 1214, the heat transfer process of the filling fluid can be carried out, for example, using the following steps: - ENSURE THAT V-5013 IS OPEN - OPEN BV-5008, BV-5015, & BV-5013. OBSERVE THE LEVEL IN THE GLASS DISPLAY, LI-5008. - OPEN V-5012 AND OPEN V-5010 1 TIME. - START P-5010, PI-5013 MUST INDICATE <30 PSI - OPEN V-5010 - WHEN PI-5008 IS READING "EMPTY": ○ TURN OFF P-5013 ○ CLOSE BV-5013, BV-5008E BV-5015 - REMOVE THE “EMPTY” DRUM ○ TAKE ANY HTF LEAK AND RETURN TO EMPTY DRUM. - IT MAY BE POSSIBLE TO SEE THE LEVEL ON THE FIBER OPTIC SENSOR.
    [0053] [0053] In block 1216, a determination is made as to whether the filling is complete (for example, if sufficient heat transfer fluid has been supplied to the heating system). If so, then the process moves to block 1218. If not, then the process repeats block 1214 as shown.
    [0054] - FECHAR BV-5013, V-5010, V-5000 & NV-5004 - ABRIR V-5012 - USAR O FORNECIMENTO DE N2 DE ALTA PRESSÃO ATRAVÉS DE V-5020, COM O REGULADOR DE FORNECIMENTO FIXO EM 100 PSIG, Y ABRIR LENTAMENTE V-5020 [0054] In block 1218, the level of the heat transfer fluid can be attenuated, for example, using the following steps: - CLOSE BV-5013, V-5010, V-5000 & NV-5004 - OPEN V-5012 - USE THE HIGH PRESSURE N2 SUPPLY THROUGH V-5020, WITH THE FIXED SUPPLY REGULATOR AT 100 PSIG, AND SLOWLY OPEN V-5020
    [0055] - NA MEDIDA EM QUE V-5020 É CRAQUEADO, OBSERVAR A PRESSÃO SOBRE PI-5000, SE A MESMA PÁRA DE SUBIR, O ENCHIMENTO DE HTF PODE NÃO ESTAR COBRINDO A ABERTURA DO TUBO DE ENCHIMENTO NO REVESTIMENTO DO AQUECEDOR -VERIFIQUE - SE N2 ESTIVER VENTILANDO DA VENTILAÇÃO DO TAMBOR, RETORNAR AO BLOCO 1214. - QUANDO A PRESSÃO ESTABILIZA EM 100 PSIG, COMEÇAR A ELEVAR A PRESSÃO DO REGULADOR EM INCREMENTOS DE 50 PSIG. - VERIFICAR LI-5008 PARA UM AUMENTO INDICADO NO NÍVEL DO TAMBOR DE HTF - QUANDO A ELEVAÇÃO DO NÍVEL HTF FOR OBSERVADA PELA PRIMEIRA VEZ, FECHAR V-5020. - OBSERVAR A PRESSÃO SOBRE PI-5000. AJUSTAR O REGULADOR DE N2 DE ALTA PRESSÃO PARA ESSA PRESSÃO E SE QUEBRAR A ABERTURA V-5020 - AJUSTAR O REGULADOR DE N2 PARA DAR UM AUMENTO DENÍVEL GRADUAL DO NÍVEL DE TAMBOR DE FORNECIMENTO VP-1 (LI-5013). - ESPERAR QUE CERCA DE 940 PSIG SEJA NECESSARIO PARA REMOVER O EXCESSO DE VP-1 DO AQUECEDOR. - NÃO PERMITIR QUE O TAMBOR TENHA EXCESSO DE FLUXO! - ASSIM QUE N2 COMEÇAR A VENTILAR DA LINHA DE TAMBOR VP-1 OU SE A PRESSÃO SOBRE O PI-5000 COMEÇAR A CAIR, FECHAR A VÁLVULA V-5020. - O HTF NO AQUECEDOR ESTÁ AGORA NO NÍVEL DESEJADO. [0055] In block 1220, the excess heat transfer fluid can be removed, for example, using the following steps: - TO THE EXTENT V-5020 IS SCRATCHED, OBSERVE THE PRESSURE ON PI-5000, IF THE SAME STOP RISING, HTF FILLING MAY NOT BE COVERING THE OPENING OF THE FILLING TUBE IN THE HEATER COATING - CHECK - IF N2 IS VENTILATING THE DRUM VENTILATION, RETURN TO BLOCK 1214. - WHEN PRESSURE STABILIZES AT 100 PSIG, START RAISING THE REGULATOR PRESSURE IN INCREASES OF 50 PSIG. - CHECK LI-5008 FOR AN INDICATED INCREASE IN HTF DRUM LEVEL - WHEN THE HTF LEVEL RISE IS OBSERVED FOR THE FIRST TIME, CLOSE V-5020. - OBSERVE THE PRESSURE ON PI-5000. ADJUST THE HIGH PRESSURE N2 REGULATOR TO THAT PRESSURE AND BREAK THE V-5020 OPENING - ADJUST N2 REGULATOR TO GIVE A GRADUALLY DENSITIVE INCREASE IN VP-1 SUPPLY DRUM LEVEL (LI-5013). - WAIT THAT ABOUT 940 PSIG IS NECESSARY TO REMOVE EXCESS VP-1 FROM THE HEATER. - DO NOT ALLOW THE DRUM TO HAVE EXCESS FLOW! - AS SOON AS N2 BEGINS TO VENTILATE THE VP-1 DRUM LINE OR IF THE PRESSURE ON THE PI-5000 BEGINS TO FALL, CLOSE THE V-5020 VALVE. - The HTF IN THE HEATER IS NOW AT THE DESIRED LEVEL.
    [0056] - FECHAR A VÁLVULA V-5012 - ASSEGURAR QUE V-5001 & V-5001A ESTÃO CHEIAS E ABERTAS - MUITO LENTAMENTE, QUEBRAR A ABERTURA V-5000 - VERIFICAR PI-5000 - AJUSTAR V-5000 PARA QUEDA DE PRESSÃO EM 10 PSI/MIN OU MENOS - SE FOR OBSERVADA ESPUMA NA VENTILAÇÃO, FECHAR V-5000 E TENTAR NOVAMENTE APÓS 10 MINUTOS. - QUANDO O AQUECEDOR ESTIVER À PRESSÃO ATMOSFÉRICA, FECHAR AS VÁLVULAS DE BLOQUEIO NAS VÁLVULAS NO ENCHIMENTO E VÁLVULAS DE VAC/PRESSÃO NA CABEÇA DO POÇO - ABRIR V-5000 TOTALMENTE. [0056] In block 1222, the heater can be fixed, for example, using the following steps: - CLOSE VALVE V-5012 - ENSURE THAT V-5001 & V-5001A ARE FULL AND OPEN - VERY SLOWLY, BREAK THE V-5000 OPENING - CHECK PI-5000 - ADJUST V-5000 FOR PRESSURE FALL AT 10 PSI / MIN OR LESS - IF FOAM IS OBSERVED IN THE VENTILATION, CLOSE V-5000 AND TRY AGAIN AFTER 10 MINUTES. - WHEN THE HEATER IS AT ATMOSPHERIC PRESSURE, CLOSE THE BLOCKING VALVES ON THE FILLING VALVES AND VAC / PRESSURE VALVES AT THE WELL HEAD - OPEN V-5000 FULLY.
    [0057] [0057] In block 1224, the heater is ready to start, according to the modalities of the present invention.
    [0058] [0058] Various modifications and additions can be made to the exemplary modalities discussed without departing from the scope of the present invention. For example, although the modalities described above refer to particular characteristics, the scope of the present invention also includes modalities that have different combinations of characteristics and modalities that do not include all the functions described. Therefore, the scope of the present invention is intended to encompass all alternatives, modifications and variations as being part of the scope of the Claims, together with all their equivalents.
    权利要求:
    Claims (3)
    [0001]
    Underground Mineral Formation Heating System, the heating system comprising: a coating positioned in a hole in the underground mineral formation, the coating having a longitudinal axis, an external surface and an internal surface, a heating element positioned inside the coating; characterized in that the coating is at least partially immersed in a boiling fluid in the hole of the underground mineral formation, in which the boiling fluid intensifies the heat transfer from the outer surface of the coating to the underground mineral formation; and a plurality of fins on the outer surface of the liner extending in a direction parallel to the longitudinal axis, wherein each of the plurality of fins includes unobstructed gaps formed at longitudinal intervals; wherein a length of the longitudinal intervals for a first fin of the plurality of fins is the same as, but longitudinally offset, from the length of the longitudinal intervals of a second fin radially adjacent the plurality of fins.
    [0002]
    Underground Mineral Formation Heating System according to Claim 1, characterized in that at least one of the plurality of fins comprises a spacer, so that a fluid is allowed to flow under at least one among the plurality of fins when the spacer rests against the hole.
    [0003]
    Underground Mineral Formation Heating System according to Claim 2, characterized in that the spacer is a first spacer and in which at least one of the plurality of fins comprises a second spacer, and in which the distance between the first spacer and the second spacer is larger than each of the longitudinal intervals.
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    同族专利:
    公开号 | 公开日
    CA2797536C|2019-04-23|
    BR112012027662A2|2016-08-16|
    WO2011137196A1|2011-11-03|
    IL222732D0|2012-12-31|
    IL222732A|2015-09-24|
    US9464513B2|2016-10-11|
    CA2797655A1|2011-11-10|
    AU2011248918A1|2012-11-29|
    JO3186B1|2018-03-08|
    WO2011139434A3|2012-02-02|
    US8464792B2|2013-06-18|
    US20130199786A1|2013-08-08|
    AU2011245362B2|2016-02-25|
    CN102947539B|2016-01-06|
    WO2011139434A2|2011-11-10|
    CA2797536A1|2011-11-03|
    MA34256B1|2013-05-02|
    US20110259590A1|2011-10-27|
    JO3294B1|2018-09-16|
    IL222641A|2016-12-29|
    IL222641D0|2012-12-31|
    CN102947539A|2013-02-27|
    MA34231B1|2013-05-02|
    BR112012027662B1|2020-02-11|
    CN102906369A|2013-01-30|
    BR112012027326A2|2019-10-29|
    CA2797655C|2019-05-14|
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    法律状态:
    2019-11-12| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2020-03-31| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-08-11| B09A| Decision: intention to grant|
    2020-12-01| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 27/04/2011, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US32851910P| true| 2010-04-27|2010-04-27|
    US61/328,519|2010-04-27|
    PCT/US2011/034213|WO2011137196A1|2010-04-27|2011-04-27|System for providing uniform heating to subterranean formation for recovery of mineral deposits|
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