CA2857587A1 - Apparatus and method for oil sand exploitation - Google Patents
Apparatus and method for oil sand exploitation Download PDFInfo
- Publication number
- CA2857587A1 CA2857587A1 CA2857587A CA2857587A CA2857587A1 CA 2857587 A1 CA2857587 A1 CA 2857587A1 CA 2857587 A CA2857587 A CA 2857587A CA 2857587 A CA2857587 A CA 2857587A CA 2857587 A1 CA2857587 A1 CA 2857587A1
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- Canada
- Prior art keywords
- steam
- casing
- downhole apparatus
- conduit
- steam generation
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 239000003027 oil sand Substances 0.000 title claims abstract description 33
- 238000000034 method Methods 0.000 title claims description 7
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 40
- 239000010779 crude oil Substances 0.000 claims abstract description 34
- 230000002093 peripheral effect Effects 0.000 claims abstract description 9
- 238000004891 communication Methods 0.000 claims abstract description 5
- 230000006854 communication Effects 0.000 claims abstract description 5
- 239000012530 fluid Substances 0.000 claims abstract description 5
- 229940090045 cartridge Drugs 0.000 claims description 15
- 238000010438 heat treatment Methods 0.000 claims description 13
- 230000001483 mobilizing effect Effects 0.000 claims description 5
- 238000005253 cladding Methods 0.000 claims description 2
- 150000003839 salts Chemical class 0.000 claims 1
- 239000003921 oil Substances 0.000 description 26
- 238000000605 extraction Methods 0.000 description 22
- 239000004020 conductor Substances 0.000 description 6
- 239000000243 solution Substances 0.000 description 6
- 238000004519 manufacturing process Methods 0.000 description 5
- 238000010796 Steam-assisted gravity drainage Methods 0.000 description 4
- 238000011065 in-situ storage Methods 0.000 description 4
- 239000004576 sand Substances 0.000 description 4
- 239000011248 coating agent Substances 0.000 description 3
- 238000000576 coating method Methods 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 150000002484 inorganic compounds Chemical class 0.000 description 3
- 229910010272 inorganic material Inorganic materials 0.000 description 3
- 239000000203 mixture Substances 0.000 description 3
- 230000001012 protector Effects 0.000 description 3
- 238000005086 pumping Methods 0.000 description 3
- 238000013022 venting Methods 0.000 description 3
- 238000010793 Steam injection (oil industry) Methods 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 238000009826 distribution Methods 0.000 description 2
- 229910017053 inorganic salt Inorganic materials 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 239000003208 petroleum Substances 0.000 description 2
- 239000007921 spray Substances 0.000 description 2
- 230000009182 swimming Effects 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 1
- 238000009529 body temperature measurement Methods 0.000 description 1
- 238000009833 condensation Methods 0.000 description 1
- 230000005494 condensation Effects 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 239000013505 freshwater Substances 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 230000003455 independent Effects 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 239000007769 metal material Substances 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
- 239000011269 tar Substances 0.000 description 1
- 239000011275 tar sand Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/2401—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection by means of electricity
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
Oil sand exploitation is enhanced, by using a downhole apparatus comprising a casing (130) for housing a water conduit for receiving water via a water pipe, at least one steam generation chamber mounted to the peripheral surface of the casing and being in fluid communication with said water conduit and having at least one steam outlet, at least one electrical heater, being thermally connected to said steam generation chamber, if the downhole apparatus further comprises at least one crude oil conduit (125) for recovering crude oil, which has been mobilized by said steam.
Description
I
Apparatus and Method for Oil Sand Exploitation Field of the invention The invention relates to a method and an apparatus for in situ mobilizing of heavy oil or crude oil by steam injection.
Description of the related art Oil sand, as well referred to as tar sand, comprises sand grains coated with tar like petroleum crude oil, briefly referred to as crude oil. The crude oil in the oil sand has a high viscosity and must be heated or diluted to flow. In-situ exploita-tion of oil sands can be accomplished by "steam assisted gravity drainage", ab-breviated as SAGD. SAGD uses a horizontally extending steam injection well forming a steam generation chamber for mobilizing the crude oil in the oil sand.
The mobilized crude oil pours downward and is recovered by a second horizon-tally extending well, as so called production well, as disclosed in US2001/0278001A1.
The steam can be either produced by above ground facilities or downhole by an electrical heater as suggested by US-Patent 4,805,698. The water is supplied from above ground by a water supply line. The electrical steam generator heats the water to generate steam. The steam is injected into the sand and mobilizes the crude oil, which is collected by adjacent production wells.
Summary of the invention The problem to be solved by the invention is to improve in-situ oil sand exploita-tion.
Solutions of the problem are provided by a downhole apparatus and a method for exploitation of an oil sand reservoir as described by the respective independ-ent claims. The dependent claims relate to further improvements of the inven-tion.
The downhole apparatus for oil sand exploitation, comprises a least a casing which houses a water conduit for receiving water via a water pipe and at least one steam generation chamber being in fluid communication with said water conduit and having at least one steam outlet. The steam generation chamber is thermally connected to an electrical heater. The downhole apparatus further comprises at least one crude oil conduit for recovering crude oil, which has been mobilized by said steam. Such downhole apparatus permits to inject steam for mobilization of the crude oil into the oil sand and to recover the crude oil by a single apparatus, and thus requires only a single bore.
The casing may preferably house the at least one crude oil conduit. The casing may for example be or include a multiple conduit tube, wherein the at least one water conduit and the at least one crude oil conduit are each at least one of the multiple conduits. This permits a stable design of the housing.
The at least one steam generation chamber is preferably supported by the pe-ripheral surface of the casing. This position of the steam generation chamber permits a simple injection of the steam generated in said steam generation chamber into the oil sand.
Preferably there are multiple, e.g. five or nine, at least two steam generation chambers arranged around the peripheral surface of the casing defining a bundle of steam generation chambers. The downhole apparatus may have one or more bundles. In one embodiment, there is one bundle of steam generation chambers.
In another embodiment, there are two or more bundles arranged at different positions along a distal length of the casing. The one or more bundles of steam generation chambers permit homogeneous injection of steam and thus an effi-cient exploitation of the oils sand. Because the one or more bundles of steam generation chambers are arranged around the casing, the one or more bundles also act to maintain or raise a temperature of the casing which aids in removal of crude oil from a reservoir (via the crude oil conduit in the casing).
Each steam generation chamber preferably has a cladding compartment sur-rounding a heater tube. The heater tube may house at least one electrical heater cartridge. This permits on the one hand to efficiently heat the water and on the other hand a simple replacement of the electrical heater cartridge in case of fail-ure. The heater tube preferably houses at least one spare electrical heater car-tridge. This permits longer operating intervals between retracting the downhole apparatus.
The heater tube may be hollow and may have an interior containing a composi-tion of inorganic compounds and possibly pure elemental species. Examples for such a composition are described in the patents US 6,132,823, US 6,911,231, US
6916,430, US 6811720 and the application US2005/0056807, which are incorpo-rated by reference as if fully disclosed herein. Such composition acts as a ther-mally conductive material or medium to provide at least an almost perfect ho-mogenous distribution by the heater tube of the heat provided by the heater cartridge. The heater tube may as well be evacuated as suggested in the above references. In a preferred embodiment the heater tube is evacuated and an amount of a liquid inorganic compound, e.g., a solution of at least one inorganic salt is inserted into the tube. Subsequently the electrical heater is powered.
Thereby the liquid inorganic compound in the above example the solution evap-orates and the at least one inorganic salt remains coats the inner surface of the heater tube and the electrical heater, thermally connecting the electrical heater with the heater tube. Preferably the heater tube is rotated or pivoted while powering the heating element to obtain a better distribution of the solution in the heater tube and thereby to obtain a more homogeneous coating. The amount of the solution inserted into the heater tube is preferably significantly smaller than the volume of the tube, e.g. smaller as 1/10 or better smaller as 1/50 of the heater tube's volume. Preferred coating solutions are disclosed in the above cited documents. Coating of the heater tube is preferably accomplished before attaching the heater tube to the downhole apparatus.
The heater tube may extend over the steam generation chamber, e.g. extend axially. Thus, at least one section of the heater tube extends out of the steam generation chamber into the bore. The heater tube thus not only heats water inside the steam generation chamber to steam, but as well reheats steam or wa-ter that cooled in a reservoir after its injection. Therby the efficiency of the ex-ploitation is enhanced.
The method for exploitation of an oil sand reservoir comprises at least the steps of producing steam in a steam generation chamber of a downhole apparatus, injecting said steam via steam outlets into the oil sand reservoir for mobilizing crude oil of the oil sand reservoir. At least part of the mobilized crude oils is re-covered by said downhole apparatus. This method reduces the minimum num-ber of bores for in situ oil sand exploitation compared to SAGD, and thus the costs.
Description of Drawings In the following the invention will be described by way of example, without limi-tation of the general inventive concept, on examples of embodiment with refer-ence to the drawings.
Figure 1 shows a schematic depiction of an oil sand exploitation system, Figure 2 shows a perspective view of a section of downhole apparatus, Figure 3 shows section of steam generation chamber.
Figure 4 shows a schematic depiction of a second embodiment of an oil sand exploitation system.
Detailed Description The oil sand exploitation system 100 in Figure 1 has a ground station 110 for 5 housing the above ground facilities, like for example a controlling station 115 for monitoring and controlling the oil sand exploitation. Ground station 110 may also include a power source to, for example, provide power to an extraction well.
Ground station 110 may include a water source, such as a reservoir, to provide water (e.g., fresh water) to an extraction well. The ground station 110 is depicted as an onshore station, but can as well be a swimming station for exploitation of water covered oil sands.
The oil sand exploitation system 100 includes an extraction well 120 with a downhole apparatus inserted into bore 105. The downhole apparatus includes a multi conduit tube like casing 130, e.g. for a power cable 230 (see Figure 2) for supplying power to downhole equipment, for example a protector 165, and/or a motor 153 for driving a well head and a well monitor device 140, as schematical-ly depicted in Figure 1. The extraction well 120 includes a steam generator which may be mounted to the peripheral surface of the casing 130. The steam generator 200 is explained below in more detail with respect to Figures 2 and 3.
The steam generator 200 is positioned in this embodiment around casing 130 at a bottom or distal portion of casing 130, being positioned in a first preferably vertical section of the extraction bore 105. The steam generator 200 injects steam preferably laterally into oil sand as shown in Figure 1. The steam mobilizes crude oil in the oil sand.
Extraction well 120 is configured to collect oil, in particular may the extraction well be configured to collect the mobilized crude oil in the oil sand. To this end casing 130 of the extraction well 120 includes one or more oil inlets 135 along its length that allow oil to infiltrate the casing. Disposed within casing 130 is at least one oil conduit 125. The oil conduit 125 extends from the bottom or distal por-tion of casing 130 to the above ground station 110. Oil that infiltrates casing 130 may enter oil conduit 125 at the conduit's distal end, e.g. via one of the oil inlets 135 and may be pumped to the surface and fed to a production line 109 for ex-ample by a centrifugal pump 180 being preferybly arranged in the bottom or distal portion of casing 130. Before pumping the crude oil to the above ground station 110, water may be separated from the crude oil by separator 176. Also, in the bottom or distal portion of casing 130 are an Electric Cable Clip 195, a Vent-ing Valve 172, Single Flow Valve 185, a Power Cable 175, the Rotary Separator 176, a Protector 165, a Cable Head 162, a Motor 152 and Well Monitor Device 140. In between are a couple of water spray holes 145 and further oil inlets 135.
The water spray holes 145 are preferably in fluid communication with steam generation means, for example with at least one of the steam generation cham-bers 375 (cf. Figure 3) and thus permit to inject steam into the oil sand for mobi-lizing crude oil.
Figure 2 shows a section of an isometric view of casing 130 including a steam generator 200 of extraction well 120. The steam generator 200 comprises a bun-dle of heating members 300 (cf. Fig. 3.) The heating members 300 are arranged around the peripheral surface of the casing 130. The casing 130 is tube like.
Cas-ing 130 and has multiple compartments or conduits around an inner periphery which may serve as water conduit 250 (for water from ground station 110 to steam generator 200), oil conduit 125 (for oil infiltrating oil inlets 135 in casing 130) or as cable conduit (for providing power to components in the casing (e.g., centrifugal pump 180, motor 152) and to heat cartridges associated with the steam generator 200).
The steam generator 200 comprises a bundle of heating members 300 (cf. Fig-ure 3). The heating members 300 are arranged around the peripheral surface of the casing 130 and are each connected to the casing 130 by, for example, one or more weld connections. Where it is desired to have more than one bundle asso-ciated with a well like extraction well 120, the bundles may be stacked one above the other along the casing 130. Referring to Figure 3, each heating member 300 includes a heater tube 310 and a steam generation chamber 375 respectively.
The front facing (upper) side of the heater tube 310 is closed by conical cap 330, which may be weld connected to the heater tube 310. The rear facing side of the heater tube 310 may be closed by an end cap 340, which may preferably be a water tight but releasable connection, e.g. a threaded connection. Heater tube 310, conical cap 330 and end cap 340 define a volume or chamber 335.
As shown in Figure 3, chamber 335 of heating member 300 is divided into a first portion and a second portion by cap 360 of a thermally conductive material such as a metal material (e.g., steel). In one embodiment, electrical heater car-tridge 350 with positive and negative terminals located at a single end (a proxi-mal end as viewed) is positioned in a first portion of chamber 335 (proximal to cap 340). Cap 360 may divide chamber 335 at a distance from a first end to be sufficient to allow heater cartridge 350 to be disposed in a first portion of cham-ber 335 but minimizes any additional volume for the first portion. As shown in Figure 3, when heater cartridge 350 is disposed in a first portion of chamber terminals 355 may extend into a volume of end cap 340. End cap 340 preferably includes lateral opening 365 that is, for example, a threaded opening for power connection to terminals 355. A conductor is fed through a peripheral conduit of casing 130 into lateral opening 365. Current can be supplied to the conductor from an above ground power source in ground station 110.
Each steam generation chamber 375 is defined by, for example, cylindrical shell 320 a front wall 380 and a rear wall 370 connected by, for example, weld connections. The front wall 380 and the rear wall 370 each have an opening through which a heater tube 310 is disposed. The heater tube 310 extends axially through the steam generation chamber 375. The connection of the heater tube 310 and the front wall 380 and/or the rear wall 370 may be a weld connec-tion.
The electrical heater cartridge 350 is thermally connected to the heater tube and electrically connected with a power line e.g. by power cable 230. The power (e.g., electrical current) is preferably controlled by the controlling station and may be ducted via a lateral opening like lateral opening 365. A gasket may be used for sealing the cable feedthrough. Inside heater tube 310 is a thermally conductive material like it is described in the US-Patents 6,132,823;
6,911,231;
6,916,430; 7,220,365 and United States Patent Publication No. 2005/0056807.
Rear wall 370 of shell 320 includes inlet 395 for a water source to be connected thereto to provide water to steam generation chamber 375. Water is provided from a water source at, for example, ground station 110 to steam generation chamber 375 by a peripheral conduit of casing 130 that is in fluid communication with inlet 395. For heating the water to steam, power may be supplied to the electrical heater cartridge 350. The heater cartridge 350 thus produces heat, be-ing transferred to the steam generation chamber 375 via the heater tube 310.
Steam develops inside the steam generation chamber 375 and escapes through steam outlet 390 into the oil sand. A single flow pressure valve may be provided in the steam outlet 390. Thereby it can be avoided that foreign matter, like sand grains and the like enter the steam generation chamber 375. Further, the steam can be pressurized. As the heater tube 310 extends over the steam generation chamber a part of the heat provided by the electrical heater cartridge 350 is as well transferred directly to the oil sand. This heat reduces the condensation of the steam close to the extraction well 120 and thus permits the steam to heat a bigger area around the extraction well and thereby to better mobilize the crude oil. The mobilized crude oil can be collected via oil inlets 135 (see Figures 1 and 2), separated from water by rotary separator 176 and pumped by centrifugal pump 180 into the production line 109 a schematically represented in Figure 1.
Representatively, as described above with reference to Figure 1, one or more tube bundles 200 of extraction well 120 may be used to generate and discharge steam into a petroleum reserve to, in the case of oil sands, provide sufficient liquidity to the crude oil in oil sands to allow its extraction through casing and pumping conduit 125, and secondarily to heat as well the casing 130.
Prefer-ably the temperature of the steam produced in the steam generation cham-ber 375 is monitored and/or controlled by controller 115. For example, a pro-cessing protocol delivered to control computer 115 may include instructions for receiving temperature measurements from at least one temperature sensor.
Based on these measurements, instructions are provided in a machine-readable form to be executed by controller 115. Accordingly, controller 115 executes the instructions to increase or decrease the power output to one or more heating rods 350 to achieve a target temperature in a range f (e.g., 250 C to 280 C).
It is appreciated that controller 115 may be increasing power to some heating car-tridges 350 while at the same time decreasing power to other heating cartridges 350. The controller 115 may alternatively or additionally control, i.e.
enhance or reduce the water flow provided to the steam generation chamber(s) 375 to thereby control the steam temperature. Still further, controller 115 may be con-nected to pump 180 and other components in pumping conduit 125 and control the pump and/or other components based on program instructions to achieve a desired throughput from the well.
Figure 4 shows an another embodiment of an oil sand exploitation system. In this embodiment, oil sand exploitation system 400 includes ground station 410 for housing the above ground facilities, like for example, a controller 415, a power source and a water source. Similar to Figure 1, the above ground station 410 is depicted as onshore station, but can as well be a swimming station for exploitation of water covered oil sands. The system 400 includes a bore 405 into which an extraction well 420 with a downhole apparatus is inserted. In Figure 1, the extraction well was inserted vertically or approximately vertically the entire length of the well. In Figure 4, the extraction well 420 extends vertically through 5 bore 405 at a ground surface of the well, but then extends laterally into the well.
Otherwise, the construction and operation of extraction well 420 and system is similar to the construction and operation of extraction well 120 and system 100 described with reference to Figures 1-3. The downhole apparatus includes casing 430 which is, for example a multi-conduit casing configured similar to 10 casing 130 in Figure 1, and one or more bundles of steam generators 500 configured similar to steam generators 200. Figure 4 shows a single bundle disposed about and connected to a distal portion of casing 430. Water provided to each steam generation chamber of steam generator 500 is converted to steam by heat provided to the chamber by a heater tube containing a heater cartridge and a thermally conductive material as described above with reference to Figures 1-3. The steam is dispensed from steam outlets 490 of a steam generation chamber into the oil sands reservoir to mobilize oil in the oil sand.
Mobilized oil infiltrates casing 430 through oil inlets 435 and is pumped to the surface of the well.
Apparatus and Method for Oil Sand Exploitation Field of the invention The invention relates to a method and an apparatus for in situ mobilizing of heavy oil or crude oil by steam injection.
Description of the related art Oil sand, as well referred to as tar sand, comprises sand grains coated with tar like petroleum crude oil, briefly referred to as crude oil. The crude oil in the oil sand has a high viscosity and must be heated or diluted to flow. In-situ exploita-tion of oil sands can be accomplished by "steam assisted gravity drainage", ab-breviated as SAGD. SAGD uses a horizontally extending steam injection well forming a steam generation chamber for mobilizing the crude oil in the oil sand.
The mobilized crude oil pours downward and is recovered by a second horizon-tally extending well, as so called production well, as disclosed in US2001/0278001A1.
The steam can be either produced by above ground facilities or downhole by an electrical heater as suggested by US-Patent 4,805,698. The water is supplied from above ground by a water supply line. The electrical steam generator heats the water to generate steam. The steam is injected into the sand and mobilizes the crude oil, which is collected by adjacent production wells.
Summary of the invention The problem to be solved by the invention is to improve in-situ oil sand exploita-tion.
Solutions of the problem are provided by a downhole apparatus and a method for exploitation of an oil sand reservoir as described by the respective independ-ent claims. The dependent claims relate to further improvements of the inven-tion.
The downhole apparatus for oil sand exploitation, comprises a least a casing which houses a water conduit for receiving water via a water pipe and at least one steam generation chamber being in fluid communication with said water conduit and having at least one steam outlet. The steam generation chamber is thermally connected to an electrical heater. The downhole apparatus further comprises at least one crude oil conduit for recovering crude oil, which has been mobilized by said steam. Such downhole apparatus permits to inject steam for mobilization of the crude oil into the oil sand and to recover the crude oil by a single apparatus, and thus requires only a single bore.
The casing may preferably house the at least one crude oil conduit. The casing may for example be or include a multiple conduit tube, wherein the at least one water conduit and the at least one crude oil conduit are each at least one of the multiple conduits. This permits a stable design of the housing.
The at least one steam generation chamber is preferably supported by the pe-ripheral surface of the casing. This position of the steam generation chamber permits a simple injection of the steam generated in said steam generation chamber into the oil sand.
Preferably there are multiple, e.g. five or nine, at least two steam generation chambers arranged around the peripheral surface of the casing defining a bundle of steam generation chambers. The downhole apparatus may have one or more bundles. In one embodiment, there is one bundle of steam generation chambers.
In another embodiment, there are two or more bundles arranged at different positions along a distal length of the casing. The one or more bundles of steam generation chambers permit homogeneous injection of steam and thus an effi-cient exploitation of the oils sand. Because the one or more bundles of steam generation chambers are arranged around the casing, the one or more bundles also act to maintain or raise a temperature of the casing which aids in removal of crude oil from a reservoir (via the crude oil conduit in the casing).
Each steam generation chamber preferably has a cladding compartment sur-rounding a heater tube. The heater tube may house at least one electrical heater cartridge. This permits on the one hand to efficiently heat the water and on the other hand a simple replacement of the electrical heater cartridge in case of fail-ure. The heater tube preferably houses at least one spare electrical heater car-tridge. This permits longer operating intervals between retracting the downhole apparatus.
The heater tube may be hollow and may have an interior containing a composi-tion of inorganic compounds and possibly pure elemental species. Examples for such a composition are described in the patents US 6,132,823, US 6,911,231, US
6916,430, US 6811720 and the application US2005/0056807, which are incorpo-rated by reference as if fully disclosed herein. Such composition acts as a ther-mally conductive material or medium to provide at least an almost perfect ho-mogenous distribution by the heater tube of the heat provided by the heater cartridge. The heater tube may as well be evacuated as suggested in the above references. In a preferred embodiment the heater tube is evacuated and an amount of a liquid inorganic compound, e.g., a solution of at least one inorganic salt is inserted into the tube. Subsequently the electrical heater is powered.
Thereby the liquid inorganic compound in the above example the solution evap-orates and the at least one inorganic salt remains coats the inner surface of the heater tube and the electrical heater, thermally connecting the electrical heater with the heater tube. Preferably the heater tube is rotated or pivoted while powering the heating element to obtain a better distribution of the solution in the heater tube and thereby to obtain a more homogeneous coating. The amount of the solution inserted into the heater tube is preferably significantly smaller than the volume of the tube, e.g. smaller as 1/10 or better smaller as 1/50 of the heater tube's volume. Preferred coating solutions are disclosed in the above cited documents. Coating of the heater tube is preferably accomplished before attaching the heater tube to the downhole apparatus.
The heater tube may extend over the steam generation chamber, e.g. extend axially. Thus, at least one section of the heater tube extends out of the steam generation chamber into the bore. The heater tube thus not only heats water inside the steam generation chamber to steam, but as well reheats steam or wa-ter that cooled in a reservoir after its injection. Therby the efficiency of the ex-ploitation is enhanced.
The method for exploitation of an oil sand reservoir comprises at least the steps of producing steam in a steam generation chamber of a downhole apparatus, injecting said steam via steam outlets into the oil sand reservoir for mobilizing crude oil of the oil sand reservoir. At least part of the mobilized crude oils is re-covered by said downhole apparatus. This method reduces the minimum num-ber of bores for in situ oil sand exploitation compared to SAGD, and thus the costs.
Description of Drawings In the following the invention will be described by way of example, without limi-tation of the general inventive concept, on examples of embodiment with refer-ence to the drawings.
Figure 1 shows a schematic depiction of an oil sand exploitation system, Figure 2 shows a perspective view of a section of downhole apparatus, Figure 3 shows section of steam generation chamber.
Figure 4 shows a schematic depiction of a second embodiment of an oil sand exploitation system.
Detailed Description The oil sand exploitation system 100 in Figure 1 has a ground station 110 for 5 housing the above ground facilities, like for example a controlling station 115 for monitoring and controlling the oil sand exploitation. Ground station 110 may also include a power source to, for example, provide power to an extraction well.
Ground station 110 may include a water source, such as a reservoir, to provide water (e.g., fresh water) to an extraction well. The ground station 110 is depicted as an onshore station, but can as well be a swimming station for exploitation of water covered oil sands.
The oil sand exploitation system 100 includes an extraction well 120 with a downhole apparatus inserted into bore 105. The downhole apparatus includes a multi conduit tube like casing 130, e.g. for a power cable 230 (see Figure 2) for supplying power to downhole equipment, for example a protector 165, and/or a motor 153 for driving a well head and a well monitor device 140, as schematical-ly depicted in Figure 1. The extraction well 120 includes a steam generator which may be mounted to the peripheral surface of the casing 130. The steam generator 200 is explained below in more detail with respect to Figures 2 and 3.
The steam generator 200 is positioned in this embodiment around casing 130 at a bottom or distal portion of casing 130, being positioned in a first preferably vertical section of the extraction bore 105. The steam generator 200 injects steam preferably laterally into oil sand as shown in Figure 1. The steam mobilizes crude oil in the oil sand.
Extraction well 120 is configured to collect oil, in particular may the extraction well be configured to collect the mobilized crude oil in the oil sand. To this end casing 130 of the extraction well 120 includes one or more oil inlets 135 along its length that allow oil to infiltrate the casing. Disposed within casing 130 is at least one oil conduit 125. The oil conduit 125 extends from the bottom or distal por-tion of casing 130 to the above ground station 110. Oil that infiltrates casing 130 may enter oil conduit 125 at the conduit's distal end, e.g. via one of the oil inlets 135 and may be pumped to the surface and fed to a production line 109 for ex-ample by a centrifugal pump 180 being preferybly arranged in the bottom or distal portion of casing 130. Before pumping the crude oil to the above ground station 110, water may be separated from the crude oil by separator 176. Also, in the bottom or distal portion of casing 130 are an Electric Cable Clip 195, a Vent-ing Valve 172, Single Flow Valve 185, a Power Cable 175, the Rotary Separator 176, a Protector 165, a Cable Head 162, a Motor 152 and Well Monitor Device 140. In between are a couple of water spray holes 145 and further oil inlets 135.
The water spray holes 145 are preferably in fluid communication with steam generation means, for example with at least one of the steam generation cham-bers 375 (cf. Figure 3) and thus permit to inject steam into the oil sand for mobi-lizing crude oil.
Figure 2 shows a section of an isometric view of casing 130 including a steam generator 200 of extraction well 120. The steam generator 200 comprises a bun-dle of heating members 300 (cf. Fig. 3.) The heating members 300 are arranged around the peripheral surface of the casing 130. The casing 130 is tube like.
Cas-ing 130 and has multiple compartments or conduits around an inner periphery which may serve as water conduit 250 (for water from ground station 110 to steam generator 200), oil conduit 125 (for oil infiltrating oil inlets 135 in casing 130) or as cable conduit (for providing power to components in the casing (e.g., centrifugal pump 180, motor 152) and to heat cartridges associated with the steam generator 200).
The steam generator 200 comprises a bundle of heating members 300 (cf. Fig-ure 3). The heating members 300 are arranged around the peripheral surface of the casing 130 and are each connected to the casing 130 by, for example, one or more weld connections. Where it is desired to have more than one bundle asso-ciated with a well like extraction well 120, the bundles may be stacked one above the other along the casing 130. Referring to Figure 3, each heating member 300 includes a heater tube 310 and a steam generation chamber 375 respectively.
The front facing (upper) side of the heater tube 310 is closed by conical cap 330, which may be weld connected to the heater tube 310. The rear facing side of the heater tube 310 may be closed by an end cap 340, which may preferably be a water tight but releasable connection, e.g. a threaded connection. Heater tube 310, conical cap 330 and end cap 340 define a volume or chamber 335.
As shown in Figure 3, chamber 335 of heating member 300 is divided into a first portion and a second portion by cap 360 of a thermally conductive material such as a metal material (e.g., steel). In one embodiment, electrical heater car-tridge 350 with positive and negative terminals located at a single end (a proxi-mal end as viewed) is positioned in a first portion of chamber 335 (proximal to cap 340). Cap 360 may divide chamber 335 at a distance from a first end to be sufficient to allow heater cartridge 350 to be disposed in a first portion of cham-ber 335 but minimizes any additional volume for the first portion. As shown in Figure 3, when heater cartridge 350 is disposed in a first portion of chamber terminals 355 may extend into a volume of end cap 340. End cap 340 preferably includes lateral opening 365 that is, for example, a threaded opening for power connection to terminals 355. A conductor is fed through a peripheral conduit of casing 130 into lateral opening 365. Current can be supplied to the conductor from an above ground power source in ground station 110.
Each steam generation chamber 375 is defined by, for example, cylindrical shell 320 a front wall 380 and a rear wall 370 connected by, for example, weld connections. The front wall 380 and the rear wall 370 each have an opening through which a heater tube 310 is disposed. The heater tube 310 extends axially through the steam generation chamber 375. The connection of the heater tube 310 and the front wall 380 and/or the rear wall 370 may be a weld connec-tion.
The electrical heater cartridge 350 is thermally connected to the heater tube and electrically connected with a power line e.g. by power cable 230. The power (e.g., electrical current) is preferably controlled by the controlling station and may be ducted via a lateral opening like lateral opening 365. A gasket may be used for sealing the cable feedthrough. Inside heater tube 310 is a thermally conductive material like it is described in the US-Patents 6,132,823;
6,911,231;
6,916,430; 7,220,365 and United States Patent Publication No. 2005/0056807.
Rear wall 370 of shell 320 includes inlet 395 for a water source to be connected thereto to provide water to steam generation chamber 375. Water is provided from a water source at, for example, ground station 110 to steam generation chamber 375 by a peripheral conduit of casing 130 that is in fluid communication with inlet 395. For heating the water to steam, power may be supplied to the electrical heater cartridge 350. The heater cartridge 350 thus produces heat, be-ing transferred to the steam generation chamber 375 via the heater tube 310.
Steam develops inside the steam generation chamber 375 and escapes through steam outlet 390 into the oil sand. A single flow pressure valve may be provided in the steam outlet 390. Thereby it can be avoided that foreign matter, like sand grains and the like enter the steam generation chamber 375. Further, the steam can be pressurized. As the heater tube 310 extends over the steam generation chamber a part of the heat provided by the electrical heater cartridge 350 is as well transferred directly to the oil sand. This heat reduces the condensation of the steam close to the extraction well 120 and thus permits the steam to heat a bigger area around the extraction well and thereby to better mobilize the crude oil. The mobilized crude oil can be collected via oil inlets 135 (see Figures 1 and 2), separated from water by rotary separator 176 and pumped by centrifugal pump 180 into the production line 109 a schematically represented in Figure 1.
Representatively, as described above with reference to Figure 1, one or more tube bundles 200 of extraction well 120 may be used to generate and discharge steam into a petroleum reserve to, in the case of oil sands, provide sufficient liquidity to the crude oil in oil sands to allow its extraction through casing and pumping conduit 125, and secondarily to heat as well the casing 130.
Prefer-ably the temperature of the steam produced in the steam generation cham-ber 375 is monitored and/or controlled by controller 115. For example, a pro-cessing protocol delivered to control computer 115 may include instructions for receiving temperature measurements from at least one temperature sensor.
Based on these measurements, instructions are provided in a machine-readable form to be executed by controller 115. Accordingly, controller 115 executes the instructions to increase or decrease the power output to one or more heating rods 350 to achieve a target temperature in a range f (e.g., 250 C to 280 C).
It is appreciated that controller 115 may be increasing power to some heating car-tridges 350 while at the same time decreasing power to other heating cartridges 350. The controller 115 may alternatively or additionally control, i.e.
enhance or reduce the water flow provided to the steam generation chamber(s) 375 to thereby control the steam temperature. Still further, controller 115 may be con-nected to pump 180 and other components in pumping conduit 125 and control the pump and/or other components based on program instructions to achieve a desired throughput from the well.
Figure 4 shows an another embodiment of an oil sand exploitation system. In this embodiment, oil sand exploitation system 400 includes ground station 410 for housing the above ground facilities, like for example, a controller 415, a power source and a water source. Similar to Figure 1, the above ground station 410 is depicted as onshore station, but can as well be a swimming station for exploitation of water covered oil sands. The system 400 includes a bore 405 into which an extraction well 420 with a downhole apparatus is inserted. In Figure 1, the extraction well was inserted vertically or approximately vertically the entire length of the well. In Figure 4, the extraction well 420 extends vertically through 5 bore 405 at a ground surface of the well, but then extends laterally into the well.
Otherwise, the construction and operation of extraction well 420 and system is similar to the construction and operation of extraction well 120 and system 100 described with reference to Figures 1-3. The downhole apparatus includes casing 430 which is, for example a multi-conduit casing configured similar to 10 casing 130 in Figure 1, and one or more bundles of steam generators 500 configured similar to steam generators 200. Figure 4 shows a single bundle disposed about and connected to a distal portion of casing 430. Water provided to each steam generation chamber of steam generator 500 is converted to steam by heat provided to the chamber by a heater tube containing a heater cartridge and a thermally conductive material as described above with reference to Figures 1-3. The steam is dispensed from steam outlets 490 of a steam generation chamber into the oil sands reservoir to mobilize oil in the oil sand.
Mobilized oil infiltrates casing 430 through oil inlets 435 and is pumped to the surface of the well.
List of reference numerals 100 system 105 bore 108 well head 109 production line 111 valve 110 ground level station 115 controlling station 120 extraction well 125 oil conduit 130 extraction tube 135 oil inlet 140 well monitor device 150 motor 162 cable head 165 protector 170 rotary separator 172 venting valve 175 power cable 176 rotary separator 180 centrifugal pump 185 single flow valve 190 venting valve 195 electric cable clip 200 tube bundle/steam generator 230 electric cable 250 water conduit 300 heating member 310 heater tube 320 shell 330 conical cap 335 chamber 340 end cap 350 electrical heater cartridge 360 end cap of heater cartridge 365 lateral opening 370 rear wall (down facing) 375 steam generation chamber 380 front wall (up facing) 390 steam outlet 395 water inlet 400 system 405 bore 410 above ground station 415 controller 420 extraction well 430 casing 435 oil inlets 490 steam outlets 500 steam generator
Claims (10)
1. Downhole apparatus for oil sand exploitation, comprising at least:
¨ a casing (130) for housing a water conduit (250) for receiving water via a water pipe, ¨ at least one steam generation chamber (375) being in fluid commu-nication with said water conduit (250) and having at least one steam outlet (390), ¨ at least one electrical heater (350), being thermally connected to said steam generation chamber (375), characterized in that the casing further comprises at least one crude oil conduit (135) for recov-ering crude oil, which has been mobilized by said steam.
¨ a casing (130) for housing a water conduit (250) for receiving water via a water pipe, ¨ at least one steam generation chamber (375) being in fluid commu-nication with said water conduit (250) and having at least one steam outlet (390), ¨ at least one electrical heater (350), being thermally connected to said steam generation chamber (375), characterized in that the casing further comprises at least one crude oil conduit (135) for recov-ering crude oil, which has been mobilized by said steam.
2. Downhole apparatus of claim 1 characterized in that the casing (130) houses the at least one crude oil conduit (135).
3. Downhole apparatus of any one of the preceding claims characterized in that the casing (130) is a multiple conduit tube wherein the at least one water conduit (250) and the at least one crude oil conduit (125) are each one of the multiple conduits.
4. Downhole apparatus of any one of the preceding claims characterized in that the at least one steam generation chamber (375) is supported by the periph-eral surface of the casing (130).
5. Downhole apparatus of any one of the preceding claims characterized in that at least two steam generation chambers (375) are arranged in bundles ar-ranged around the peripheral surface of the casing (130).
6. Downhole apparatus of any one of the preceding claims characterized in that ¨ the steam generation chamber (130) has a cladding compartment surrounding a heater tube (310), ¨ the heater tube (310) houses at least one electrical heating car-tridge (350).
7. Downhole apparatus of claim 6 characterized in that the heater tube (310) is hollow and has an interior surface, the interior surface being coated with inorganic salts.
8. Downhole apparatus of claim 7 characterized in that the heater tube (310) is evacuated.
9. Downhole apparatus of any one of claims 6 to 8 characterized in that the heater tube (310) axially extends over the steam generation cham-ber (375).
10. A method for exploitation of an oil sand reservoir comprising at least the steps:
¨ producing steam in an steam generation chamber (375) of a down-hole apparatus according to claim 1, ¨ injecting said steam via steam outlets (390) into the oil sand reser-voir for mobilizing crude oil of the oil sand reservoir, characterized in that at least part of the mobilized crude oils is recovered by at least one crude oil conduit of said downhole apparatus.
¨ producing steam in an steam generation chamber (375) of a down-hole apparatus according to claim 1, ¨ injecting said steam via steam outlets (390) into the oil sand reser-voir for mobilizing crude oil of the oil sand reservoir, characterized in that at least part of the mobilized crude oils is recovered by at least one crude oil conduit of said downhole apparatus.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| EP12150055.7A EP2612983B1 (en) | 2012-01-03 | 2012-01-03 | Apparatus and method for oil sand exploitation |
| EP12150055.7 | 2012-01-03 | ||
| PCT/EP2012/061503 WO2013102501A1 (en) | 2012-01-03 | 2012-06-15 | Apparatus and method for oil sand exploitation |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2857587A1 true CA2857587A1 (en) | 2013-07-11 |
Family
ID=46354269
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2857587A Abandoned CA2857587A1 (en) | 2012-01-03 | 2012-06-15 | Apparatus and method for oil sand exploitation |
Country Status (9)
| Country | Link |
|---|---|
| US (1) | US20130168093A1 (en) |
| EP (1) | EP2612983B1 (en) |
| JP (1) | JP5695282B2 (en) |
| KR (1) | KR20140109477A (en) |
| CN (1) | CN104024568A (en) |
| CA (1) | CA2857587A1 (en) |
| ES (1) | ES2482668T3 (en) |
| RU (1) | RU2014131934A (en) |
| WO (1) | WO2013102501A1 (en) |
Families Citing this family (11)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US9644464B2 (en) * | 2013-07-18 | 2017-05-09 | Saudi Arabian Oil Company | Electromagnetic assisted ceramic materials for heavy oil recovery and in-situ steam generation |
| US9752422B2 (en) | 2013-11-04 | 2017-09-05 | Donaldson Engineering, Inc. | Direct electrical steam generation for downhole heavy oil stimulation |
| US10273790B2 (en) | 2014-01-14 | 2019-04-30 | Precision Combustion, Inc. | System and method of producing oil |
| CN104533365B (en) * | 2014-12-22 | 2017-01-11 | 中国石油大学(北京) | Method for exploiting oil sand through paraffin media |
| EP3045794B1 (en) * | 2015-01-16 | 2019-05-15 | Nexans | Downhole cable with integrated non-metallic tube |
| KR20160128554A (en) | 2015-04-28 | 2016-11-08 | 세종대학교산학협력단 | Apparatus and method for analysing interfacial properties of oil |
| WO2017192766A1 (en) | 2016-05-03 | 2017-11-09 | Energy Analyst LLC. | Systems and methods for generating superheated steam with variable flue gas for enhanced oil recovery |
| WO2019064043A1 (en) * | 2017-09-28 | 2019-04-04 | Total Sa | Heating a zone of a reservoir |
| CN108505977B (en) * | 2018-04-18 | 2020-04-21 | 吉林大学 | Method for exploiting natural gas hydrate by using sleeve type heater |
| CN110173679B (en) * | 2019-05-17 | 2020-08-21 | 重庆科技学院 | Implantable miniature steam generator |
| CN111502623A (en) * | 2020-05-08 | 2020-08-07 | 克拉玛依红山油田有限责任公司 | Tubular sand washing and steam injection device and process |
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| US2998069A (en) * | 1958-03-27 | 1961-08-29 | Raymond M Stephens | Oil well heater |
| US4116275A (en) * | 1977-03-14 | 1978-09-26 | Exxon Production Research Company | Recovery of hydrocarbons by in situ thermal extraction |
| US4127169A (en) * | 1977-09-06 | 1978-11-28 | E. Sam Tubin | Secondary oil recovery method and system |
| US4523644A (en) * | 1978-08-14 | 1985-06-18 | Dismukes Newton B | Thermal oil recovery method |
| US4558743A (en) * | 1983-06-29 | 1985-12-17 | University Of Utah | Steam generator apparatus and method |
| CA1248442A (en) * | 1985-09-24 | 1989-01-10 | Monroe H. Waxman | In-situ steam drive oil recovery process |
| US4694907A (en) * | 1986-02-21 | 1987-09-22 | Carbotek, Inc. | Thermally-enhanced oil recovery method and apparatus |
| US4809672A (en) * | 1987-10-13 | 1989-03-07 | Alzeta Corporation | Gas-fired bayonet-type heater |
| US4805698A (en) * | 1987-11-17 | 1989-02-21 | Hughes Tool Company | Packer cooling system for a downhole steam generator assembly |
| US5052482A (en) * | 1990-04-18 | 1991-10-01 | S-Cal Research Corp. | Catalytic downhole reactor and steam generator |
| US5085275A (en) * | 1990-04-23 | 1992-02-04 | S-Cal Research Corporation | Process for conserving steam quality in deep steam injection wells |
| US6916430B1 (en) | 1996-10-25 | 2005-07-12 | New Qu Energy Ltd. | Superconducting heat transfer medium |
| US6911231B2 (en) | 1996-10-25 | 2005-06-28 | New Qu Energy Limited | Method for producing a heat transfer medium and device |
| JP3516961B2 (en) | 1996-10-25 | 2004-04-05 | ク，ユズイ | Superconducting heat transfer medium, superconducting heat transfer device, and method of manufacturing these |
| CA2668391C (en) * | 2001-04-24 | 2011-10-11 | Shell Canada Limited | In situ recovery from a tar sands formation |
| US7220365B2 (en) | 2001-08-13 | 2007-05-22 | New Qu Energy Ltd. | Devices using a medium having a high heat transfer rate |
| US6811720B2 (en) | 2001-08-13 | 2004-11-02 | New Qu Energy Ltd. | Medium having a high heat transfer rate |
| US7147057B2 (en) * | 2003-10-06 | 2006-12-12 | Halliburton Energy Services, Inc. | Loop systems and methods of using the same for conveying and distributing thermal energy into a wellbore |
| US8265468B2 (en) * | 2004-07-07 | 2012-09-11 | Carr Sr Michael Ray | Inline downhole heater and methods of use |
| US7845411B2 (en) * | 2006-10-20 | 2010-12-07 | Shell Oil Company | In situ heat treatment process utilizing a closed loop heating system |
| JP2009046825A (en) * | 2007-08-15 | 2009-03-05 | Ihi Corp | Method and equipment for drilling heavy oil |
| CA2738804A1 (en) * | 2008-10-13 | 2010-04-22 | Shell Internationale Research Maatschappij B.V. | Circulated heated transfer fluid heating of subsurface hydrocarbon formations |
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| US20130074358A1 (en) * | 2011-09-24 | 2013-03-28 | Quantum Technology Holdings Limited | Heated body with high heat transfer rate material and its use |
| US8881799B2 (en) * | 2012-08-03 | 2014-11-11 | K2 Technologies, LLC | Downhole gas generator with multiple combustion chambers |
-
2012
- 2012-01-03 ES ES12150055.7T patent/ES2482668T3/en active Active
- 2012-01-03 EP EP12150055.7A patent/EP2612983B1/en not_active Not-in-force
- 2012-01-09 US US13/346,563 patent/US20130168093A1/en not_active Abandoned
- 2012-06-15 CN CN201280065331.2A patent/CN104024568A/en active Pending
- 2012-06-15 WO PCT/EP2012/061503 patent/WO2013102501A1/en active Application Filing
- 2012-06-15 RU RU2014131934A patent/RU2014131934A/en not_active Application Discontinuation
- 2012-06-15 JP JP2014550655A patent/JP5695282B2/en not_active Expired - Fee Related
- 2012-06-15 KR KR1020147021814A patent/KR20140109477A/en not_active Application Discontinuation
- 2012-06-15 CA CA2857587A patent/CA2857587A1/en not_active Abandoned
Also Published As
| Publication number | Publication date |
|---|---|
| JP5695282B2 (en) | 2015-04-01 |
| JP2015503690A (en) | 2015-02-02 |
| ES2482668T3 (en) | 2014-08-04 |
| EP2612983B1 (en) | 2014-05-21 |
| US20130168093A1 (en) | 2013-07-04 |
| EP2612983A1 (en) | 2013-07-10 |
| WO2013102501A1 (en) | 2013-07-11 |
| RU2014131934A (en) | 2016-02-27 |
| KR20140109477A (en) | 2014-09-15 |
| CN104024568A (en) | 2014-09-03 |
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| FZDE | Discontinued |
Effective date: 20160615 |