CN103477026A - Wellbore injection system - Google Patents
Wellbore injection system Download PDFInfo
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- CN103477026A CN103477026A CN2012800080664A CN201280008066A CN103477026A CN 103477026 A CN103477026 A CN 103477026A CN 2012800080664 A CN2012800080664 A CN 2012800080664A CN 201280008066 A CN201280008066 A CN 201280008066A CN 103477026 A CN103477026 A CN 103477026A
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- 238000002347 injection Methods 0.000 title claims abstract description 52
- 239000007924 injection Substances 0.000 title claims abstract description 52
- 239000012530 fluid Substances 0.000 claims abstract description 60
- 238000004519 manufacturing process Methods 0.000 claims abstract description 44
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 40
- 238000000034 method Methods 0.000 claims abstract description 29
- 238000005755 formation reaction Methods 0.000 claims description 37
- 239000007921 spray Substances 0.000 claims description 16
- 238000005507 spraying Methods 0.000 claims description 11
- 238000010796 Steam-assisted gravity drainage Methods 0.000 claims description 8
- 230000008878 coupling Effects 0.000 claims description 4
- 238000010168 coupling process Methods 0.000 claims description 4
- 238000005859 coupling reaction Methods 0.000 claims description 4
- 238000003754 machining Methods 0.000 claims description 4
- 238000010793 Steam injection (oil industry) Methods 0.000 claims description 2
- 239000012634 fragment Substances 0.000 claims description 2
- 230000000881 depressing effect Effects 0.000 claims 1
- 239000000203 mixture Substances 0.000 claims 1
- 238000007789 sealing Methods 0.000 description 22
- 239000003921 oil Substances 0.000 description 15
- 238000009826 distribution Methods 0.000 description 12
- 239000004576 sand Substances 0.000 description 8
- 230000000875 corresponding effect Effects 0.000 description 6
- 239000000295 fuel oil Substances 0.000 description 6
- 238000011084 recovery Methods 0.000 description 4
- 238000013461 design Methods 0.000 description 3
- 238000010586 diagram Methods 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 3
- 238000002955 isolation Methods 0.000 description 3
- 239000002904 solvent Substances 0.000 description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- 229910000997 High-speed steel Inorganic materials 0.000 description 2
- 238000010795 Steam Flooding Methods 0.000 description 2
- -1 comprises steam Substances 0.000 description 2
- 230000001276 controlling effect Effects 0.000 description 2
- 238000004880 explosion Methods 0.000 description 2
- 238000009434 installation Methods 0.000 description 2
- 238000003801 milling Methods 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 238000010794 Cyclic Steam Stimulation Methods 0.000 description 1
- 208000034189 Sclerosis Diseases 0.000 description 1
- 229910000831 Steel Inorganic materials 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 230000000295 complement effect Effects 0.000 description 1
- 239000012141 concentrate Substances 0.000 description 1
- 230000002596 correlated effect Effects 0.000 description 1
- 230000018044 dehydration Effects 0.000 description 1
- 238000006297 dehydration reaction Methods 0.000 description 1
- 239000002283 diesel fuel Substances 0.000 description 1
- 230000003292 diminished effect Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 239000012467 final product Substances 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 238000003780 insertion Methods 0.000 description 1
- 230000037431 insertion Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 239000003305 oil spill Substances 0.000 description 1
- 238000005192 partition Methods 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 239000000047 product Substances 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
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- 238000012546 transfer Methods 0.000 description 1
- 238000009827 uniform distribution Methods 0.000 description 1
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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
-
- 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
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
-
- 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
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/06—Sleeve valves
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- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Nozzles (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Jet Pumps And Other Pumps (AREA)
- Physical Or Chemical Processes And Apparatus (AREA)
- Apparatus For Disinfection Or Sterilisation (AREA)
Abstract
A device is provided for delivering and distributing injection fluids into a subsurface formation from a horizontal wellbore. The device includes one or more steam pups having an outer sleeve and an inner sliding sleeve in concentric relationship. One or more sets of nozzles are arranged on the outer sleeve. A means is provided for actuating movement of the inner sliding sleeve within the outer sleeve, to at least partially cover one or more sets of nozzles on the outer sleeve. A method is also provided for delivering injection fluids into a subsurface formation from a horizontal wellbore. First, one or more steam pups are introduced into the horizontal well, said steam pups having an outer sleeve and an inner sliding sleeve with one or more sets of nozzles arranged on the outer sleeve. Next the inner sliding sleeve is moved inside the outer sleeve to at least partially cover one or more sets of nozzles on the outer sleeve. Finally, injection fluid is injected through the steam pup nozzles into formation. A further method is provided that comprises introducing into a heel location of the wellbore a first and second pairs of flow control hangers and polished bore receptacles, connected to an intermediate casing and cemented in place. The first pair of flow control hanger and polished bore receptacle are connected to an injection/production liner and one or more steam pups are then connected to the second pair of flow control hanger and polished bore receptacle.
Description
Technical field
The present invention relates to a kind of injection apparatus and method of carrying out the hydrocarbon produced in situ from the down-hole well.
Background technology
Although heavy oil and pitch reservoir are worldwide very general, usually there is difficulty from subsurface formations extraction heavy oil and pitch, and there are many challenges aspect efficiency and cost benefit.A kind of well-known method be by steam or Fluid injection in horizontal hole to strengthen loose fugitive reservoir and oil, the heavy oil of subsurface formations, or the exploitation of loose pitch reservoir.Normally spray steam into the high viscosity that reduces original position heavy oil and pitch in heavy oil and pitch stratum and increase the mobility that oil flows out stratum.Although SAGD (SAGD), steam soak (CSS) and steam flooding are all the exploitation methods of the raising oil recovery technique commonly used.Yet, even comprising even outflow distribution mode, put specially the preferred mode of formula spray distribution mode and skewed distribution mode, spray steam in horizontal hole the steam that also can not always distribute equably.Present technology is the slotted liner uperize lower by sealing and by inner list or double tube tubing string delivering vapor, and wherein 1% of slotted liner is sealing.These methods can increase with sand control screen or bushing pipe the Radial resistant force of vapor stream usually, and promote that steam is uniformly distributed in whole stratum steam along the horizontal well axial distribution.Yet there is a problem in the use of this technology: the sealing of injection/production liner is often too large, can not provide enough Radial resistant forces for vapor stream, thereby has caused the distribution of steam in the stratum inhomogeneous.
The design of injection/production liner sealing aims to provide a kind of for controlling and preventing that gravel from directly or indirectly stopping up the means of the reservoir pore space that is positioned at injections/production liner top usually, and sealing production phase of also can recovering the oil in position prevents that gravel from infiltrating and obstruction injection/production liner surface.Be used for the sealing area of sand control between 1.5% to 5%, be generally 3%, this area is uniformly distributed required sealing area much larger than steam, and required sealing area, between from 0.001% to 1%, is less than 0.05 usually.
Single oil pipe conveying-type vapor injection system is arranged at the unlimited position near the well end usually, the vaporium with a distribution of steam inequality, and this steam chamber is larger at the position of the most close well end cavity, and the steam distributed on top is few.
Double tube conveying-type vapor injection system provides an oil pipe near end feed steam and another oil pipe near horizontal well top delivering vapor.Although solved in single tubing system, the problem of a large steam chamber is only arranged like that endways.But double tube conveying-type system has formed two large vaporiums, one unlimited near the horizontal well end, and another is unlimited near the horizontal well top.
Therefore, need to have a kind ofly provides and is uniformly distributed formula steam or other and sprays fluid along the whole length of well, and can realize the apparatus and method that steam distributes as required.
Summary of the invention
The invention provides and a kind ofly for spraying fluid, carry and be distributed to the device of subsurface formations from horizontal hole.Described device comprises one or more detachable steam pump that is positioned horizontal hole inside.Described steam pump comprises coaxial an outer sleeve and a slides within sleeve.One or organize nozzle arrangement on the steam pump outer sleeve more, spray fluid and be conveyed into described subsurface formations by described nozzle.The invention provides a kind of device for the slides within sleeve is externally turned round in sleeve.The slides within sleeve externally interior running of sleeve can cover at least in part one on outer sleeve or organize nozzle more, thereby control, sprays fluid inflow place sub-surface.
The invention provides and a kind ofly for spraying fluid, carry and be distributed to the method for subsurface formations from horizontal hole.Described method comprises to be inserted one or more steam pump in described horizontal hole, and described steam pump comprises coaxial an outer sleeve and a slides within sleeve.By one or organize nozzle arrangement on described outer sleeve more.Secondly, described slides within sleeve is turned round in described outer sleeve and cover at least in part one on described outer sleeve or organize nozzle more, flow in described subsurface formations thereby control the injection fluid.Finally, provide the injection fluid through described horizontal hole to steam pump and enter described subsurface formations so that the injection fluid passes described nozzle ejection.
Finally, the invention provides and a kind ofly for spraying fluid, from a well, carry and be distributed to a subsurface formations or for described subsurface formations is produced to the method that fluid is delivered to described well.Described method comprises to a terminal position of described well inserts one first and second pair of flow-control hanging pipe and PBR, wherein described PBR is connected to an intermediate casing and it is adhered on a position.Described first pair of flow-control hanging pipe and PBR are connected to an injection/production liner.Then one or more steam pump is connected to described second pair of flow-control hanging pipe and PBR, described steam pump comprises coaxial an outer sleeve and a slides within sleeve, and one or more nozzle arrangement is on described outer sleeve.Described slides within sleeve is turned round in described outer sleeve to be covered at least in part one on described outer sleeve or organizes nozzle more; Thereby control the fluid inflow or flow out described subsurface formations.Finally, making to spray or produce fluid by described steam pump passes described nozzle inflow or flows out described subsurface formations.
The accompanying drawing explanation
Describe below with reference to accompanying drawings the present invention in detail, wherein:
The sectional drawing that Fig. 1 is steam pump of the present invention (pup) device example;
Fig. 2 is the sectional drawing of the steam pump device example of the present invention of use erecting tools installation of the present invention;
The phantom drawing that Fig. 3 is erecting tools example of the present invention;
Fig. 4 is the sectional drawing of the steam pump device example of the present invention of demonstration sealing inclined position nozzle example;
Fig. 5 is the sectional drawing of the steam pump device example of the present invention of demonstration fastening position angled nozzle example;
Fig. 6 is the flow chart of an embodiment of explanation the inventive method;
Fig. 7 is the schematic diagram that use traffic of the present invention is controlled the first embodiment of seal and PBR joint; And
Fig. 8 is the schematic diagram that use traffic of the present invention is controlled the second embodiment of seal and PBR joint.
The specific embodiment
The present invention relates to one or more steam pump in detachable insertion horizontal hole, for controlling that steam or other spray that fluid is spurted into well and at subsurface formations, to well, producing fluid, although mention in this article and be preferably horizontal hole, but the present invention is equally applicable to vertical boreholes and inclined borehole, and should be understood that the present invention also comprises their application scenarios.Although the device in the present invention refers to steam pump, it will be understood by those skilled in the art that the present invention can be used for the injection of steam and any other known injection fluid, and also be used in subsurface formations to produce and be delivered to the fluid in well.
More specifically, described device is for managing steam or other the production fluids that sprays fluid and flow out from well that flows into well.Steam pump is designed to can arrange and can be operated from surface, without from well, it being removed.Preferably steam pump comprises the mobile setting of two or more fluids.One arranges the partition flow region and stops the fluid inflow or flow out well.Flow rate range that provides maximum magnitude to flow into or flow out well is provided for another.More preferably, can operate separately or arrange each steam pump, thus, the operator can arrange identical flow rate by whole steam pumps, or turns off selectively the traffic flow of specific steam pump, thus the specific part of isolation well.
Although steam is the term of the most often mentioning, should be understood that described apparatus and method provide a kind of means of spraying any applicable injection fluid to subsurface formations.It is a lot of that known in the art this type of sprays fluid, comprises steam, water, varsol, diesel oil, solvent.Therefore, should be understood that all this type of known fluid all is applicable to the present invention.
The present invention, by conjunction with suitably sand control control, provides uniform distribution of steam along well, helps lend some impetus to steam and carries and be distributed in formation at target locations.Recovery system of the present invention can be in conjunction with SAGD, steam flooding, CSS or other steam exploitation operation and/or in conjunction with as other Fluid injections such as solvents.Based on purpose of the present invention, solvent should comprise and contribute to reduce the original position oil viscosity, improves the steam conveying capacity or increase any chemicals and the biochemical substances that the useful assets of reservoir are exploited.It is a kind of by axial hole drag is associated with the radially layer resistance of injection that the present invention also provides, standardization equably delivering vapor to the means on stratum.
In native system, determine when whole borehole length scope inner fluid sprays required sealing area, must consider fluid properties.By fluid properties is associated with well specification and stratum characteristic, thereby the number of the jet size corresponding with spraying the sealing area and sealing nozzle is specialized, steam is uniformly distributed along horizontal hole.More preferably, native system also can be designed to be applicable to the characteristic of the different fluid in injection and manufacturing process, thereby makes the range of application of native system wider.
Referring to Fig. 1, steam pump 2 comprises outer sleeve 2 and slides within sleeve 6.Outer sleeve 4 and slides within sleeve 6 are preferably by hardened material, as other hardened steels that generally use in high-speed steel (HSS) and downhole tool and directional drill tool are made.
Steam pump can be designed to the size of all size, from industry standard oil pipe size to common normal sleeve size.More specifically, the steam pump diameter range is 1 inch to 113/4 inch.The length of steam pump is the difference in response to the difference by situation also, and its minimum length is 1m, and maximum length is 13.5m.
Slides within sleeve 6 adopts the axle shape, and its slidingtype embeds in the internal diameter of outer sleeve 4.Slides within sleeve 6 comprises one group of Europe shape (O) and encircles 14, uses so that the fragment flow between the internal diameter of the external diameter of slides within sleeve 6 and outer sleeve 4 is minimum and stop it to flow.
The external diameter of slides within sleeve 6 comprises two or more grooves 16 with machining, and its and lock ring 12 closely cooperate with at several diverse locations arrangement slides within sleeves, and it is corresponding that its position number and nozzle sealing 8 arrange number.The internal diameter of slides within sleeve 6 also includes one or more pin 18.
Figure 2 shows that the preferred disposition that instrument 20 is set in steam pump 2, Fig. 3 is its more detailed schematic diagram.Referring to these accompanying drawings, top female coupling (not shown) and lower through-hole 22 that instrument 20 comprises corresponding work string joint are set.
The external diameter that instrument 20 is set comprises one or more groove or slide rail 24, and described groove or slide rail 24 extensions spread all over whole instrument 20 length corresponding with the pin 18 on slides within sleeve 6 that arrange.Only when slide rail 24 aligns with pin 18, the external diameter that instrument 20 is set is just understood slidingtype and is received in slides within sleeve 6.When slide rail 24 fails to align with pin 18, the through hole 22 of instrument 20 is set near pin 18 and promotion pin 18.
Selectively, the running of the slides within sleeve 6 in the outer sleeve 4 of steam pump 2 can be driven and be controlled by surperficial Remote Hydraulic, in this case, does not need the instrument that arranges 20.
As shown in Figure 1 or 2, nozzle 8 orientations are perpendicular to the orientation of steam pump 2 axles, or selectively, as shown in Figure 4 and Figure 5, adjustable angle.For nozzle, the present invention is applicable to and can comprises any angle.
Referring to Fig. 4 and Fig. 5, preferably, nozzle sets can become with the axle of steam pump 2 60 ° of angles to arrange.More preferably, but in nozzle sets, the orientation of each nozzle is the orientation change at random of each nozzle selectively or in nozzle sets, thereby help lend some impetus to the steam be delivered in stratum, is uniformly distributed.
Angled orientation also can reduce during vapor flow because often carrying out 90 ° of frictional dissipations of turn-taking and causing.Preferably angled orientation also can reduce around nozzle 8 wearing and tearing that cause because of steam or other high viscositys of spraying fluids.As shown in the figure, nozzle 8 can be through machining to outer sleeve 4.Optionally, nozzle 8 can be also the part that is mounted to the independent component of described outer sleeve 4.In a preferred embodiment, the nozzle 8 for the steam pump 2 of well end preferably carries out particular design in order to provide best radial flow resistance along horizontal hole according to the characteristic of steam.
The configuration of nozzle 8 and the preferential means that open or close nozzle 8 make steam to be uniformly distributed along horizontal hole.More preferably, nozzle geometry can be different and can be comprised circle, taper, taper shape, ellipse, square, rectangle or flute profile.At the steam injection phase, the nozzle of different geometries provides a kind of flexible and whippy means of adjusting the potential heat requirement of nozzle and plastic strain under high pressure and high temperature, also can select at random geometry to control flow resistance, pressure and flow rate.
Referring to Fig. 4 and Fig. 5, spray fluid and can flow through and mark graduated slope 28 when the nozzle 8 from steam pump 2 flows out.Sclerosis explosion plate 30 is placed in nozzle 8 tops, for injection/production liner (not shown) protected from wear that prevents steam pump 2 places.
The large I of nozzle geometry and steam pump is designed for several different steam and sprays pressure or speed.For example, can lower than, be equal to or higher than uperize under the situation that reservoir splits pressure.Also can be under subsonic speed/subcritical or the velocity of sound/critical fluidised form uperize.
Preferably, steam pump 2 is recyclable systems, its can be positioned at the larger injection/production liner be connected with stratum and can adhere at random installation, through or otherwise be connected to the larger injection/production liner be connected with stratum.Steam pump 2 can also be closed or open system.More preferably, the steam pump group can be joined together to form the steam pump tubing string by the atresia casing length, thereby makes injection and the production operation variation of carrying out along whole well, and can preferably to the length-specific of well, be isolated.In this way, can in water flood operations, use native system, produce the steam isolated area simultaneously in the dehydration application.
In the situation of individual well design, the accessory of steam pump 2 can be positioned over injections/production liner inside and at production phase production original position fluid after injection phase always.In this case, the production fluid in opposite direction can flow back in steam pump 2 by nozzle 8.In process of production, explosion plate 30 for reducing its resistance when the production fluid enters steam pump 2.
Sand control screen used in the present invention or lining pipe are to be the sand control screen of any type known in the art, and it includes but not limited to free coiling, slotted liner and Mace Rui Te (meshrite
tM) screen casing or other sand control screens.
Injection/production liner preferably contacts whole reservoir, but not be only part reservoir wherein, therefore there do not is the length of run of pipeline in horizontal hole, thereby the less pressure produced along horizontal hole while being conducive to reduce fluid production, radial inflow effect better, with whole reservoir, contact better, prevent that grittiness is higher, reach distribution of steam better.
Preferably, the present invention also provides a kind of method of settling and preferably concentrate steam pump 2 by connecting one or more packer in injection/production liner, the size of described one or more packer is greater than the external diameter of steam pump 2, and enough little with closely matching (snuggly) in the internal diameter of the injection/production liner be connected with subsurface formations.
As required, packer can be designed to have the space for milling and recovery, and has certain pressure control and distribution of steam control.Preferably, packer can be arranged at terminal position and injection/production liner inside along radial bore length 1/3rd and 2/3rds positions, place or other positions of selecting selectively along well, thereby controls and the control of convection cell distribution by the pressure that sealing subsurface formations and annular space between injection/production liner, steam pump maintain the opposing jet body.Alternatively, if do not use packer, the present inventor thinks that the high viscosity by original position oil also can provide essential fluid pressure to control and the control of convection cell distribution.
In operation, instrument 20 preferably being set and usually using in this type of application commonly used 27/8 " work string operates in well.Arrange instrument 20 move to a position directly over steam pump 2 can stop mobile, corresponding to the through hole 22 that instrument 20 is set during near pin 18.
Under few situation, when the slide rail 24 that instrument 20 is set by chance when pin 18 on slides within sleeve 6 aligns, instrument 20 is set may be near slides within sleeve 6, but walk around steam pump 2, in this case, tubing string can be risen to the position of steam pump 2 tops, and the distance (offset) that it turned round together with pin 18 so that itself and slide rail 24 stagger, and then it is highly descended.
For steam pump 2 being arranged to required nozzle placement, need apply power or weight to instrument 20 is set.Once weight exceeds the resistance of lock ring 12, slides within sleeve 6 will glide, until lock ring 12 arrives next lock ring groove 16, or until slides within sleeve 6 near below back-up ring 10.
Alternatively, also can upwards draw high the instrument of setting 20 steam pump 2 is set to required nozzle placement.In this case, instrument 20 being set at first must return by slides within sleeve 6.The rotation work tubing string, until slide rail 24 is in line with pin 18, then moves down the instrument of setting 20 by slides within sleeve 6.
Again rotate and instrument 20 is set so that it staggers side by side with slide rail 24, the lifting work string is until feel that resistance, this expression arrange instrument 20 near pin 18.Then promote work string and take in new lock ring groove 16 until overcome the resistance and the lock ring 12 that carry out self-locking ring 12, or until slides within sleeve 6 near top back-up ring 10.
In optional embodiment, the present invention also can operate under the situation of injection/production liner not having, as the SAGD operational scenario.In this case, without using packer also not need to use two-flow to control hanging pipe, only use the single current amount to control hanging pipe and get final product.In SAGD application, " preheating " stage or " circulation " stage are arranged usually, the described stage need to be heated pitch between gusher and producing well or heavy oil reservoir so that improve mobility, expansion steam chamber cavity, production and fluid control.
Emitted dose and the pressure of the injection-production phase fully of a pair of SAGD well that the steam emitted dose that this warm-up phase needs usually and pressure are significantly less than abundant running.Under these situations, the first steam pump system can preferably be designed at warm-up phase and provide evenly and the distribution of steam of optimizing, then can optionally make the first steam pump system set back, the second steam pump system of inserting to be to be provided for the high steam of complete injection phase, or can optionally make the first steam pump system keep original position and by adjusting slides within sleeve 6 to realize spraying fully by nozzle 8 under the prerequisite not removing initial steam pump system.
Preferably, steam pump 2 flow set provide sealing through machining, and all flow set is as the highest order setting, abbreviation position " A ", flow cut off and are provided as middle equipotential setting, be called for short position " B ", and partial discharge is provided as the lowest order setting, abbreviation position " C ".Pre-determine the sealing area in high-order and low level setting (position " A " and " C ") according to fluid properties (comprising pressure, quality, temperature and loss).The removable whole steam pump tubing string that comprises packer also re-starts setting when needed.
By produce equally distributed steam along horizontal hole, whole reservoir can preferentially contact with steam, thereby the ratio of larger oil production, reduction steam-oil is provided, and can transfer the energy in stratum more efficiently.
In a preferred embodiment, the present invention can be designed in the injection higher or lower than splitting pressure and depress and carry out Fluid injection, or the present invention is also applicable to subcritical or critical fluidised form.
In optional embodiment, can steam pump 2 be installed in the injection/production liner of well and go.In this case, preferably use paired flow-control hanging pipe to and PBR (PBR).Paired flow-control hanging pipe and PBR are installed together, and place up and down in the position of intermediate casing.PBR is connected to intermediate casing and it is adhered on a certain position.
Then native system is arranged on to the terminal position of horizontal hole so that oil spill rate minimizes and control the pressure loss of being crossed the uperize that high steam that the flow-control hanging pipe produces bypass causes by position endways.Because the first flow control hanging pipe and the PBR that are positioned at apart from the well highest distance position are connected to injection/production liner, provide thus the seal that prevents leakage of oil to maintain the pressure of terminal position.The second flow-control hanging pipe and PBR are connected to steam pump, and are positioned at first flow control hanging pipe and PBR top, and do not need to be connected to first flow, control hanging pipe and PBR, and identical pressure and leakage of oil seal also can be provided.
In another preferred embodiment, also can under the situation of not using the packer for concentrating steam pump or steam pump tubing string, operate the present invention.As shown in Figure 7 and Figure 8, the present embodiment use one or multipair PBR (PBR) joint 26 and flow-control (FC) seal 28, but not packer is isolated steam pump.
For example, at one or multipair PBR joint 26 of down-hole operation, between these PBR joints 26, operation has one or more slotted liner 30.The use number of slotted liner 30 used depends on following factor: formation characteristics, borehole length and cost consideration.In some cases, slotted liner 30 can move between each PBR joint 26 in tubing string, so that the area of each isolated area equates.Under other situations, may only need 2 to 3 slotted liners 30.Although use this term of slotted liner herein, those skilled in the art will be understood that can use any sand control screen for achieving the above object under the condition that does not break away from the scope of the invention.
Can without hole sleeve, steam bushing pipe and one or more steam pump 2 be linked together by one or more, all steam bushing pipes all are positioned between FC seal 28.By setting be fixed in the slotted liner tubing string distance between PBR joint 26 so that its with steam bushing pipe tubing string between FC seal 28 apart from being complementary.By the seal that can remember, FC seal 28 and PBR joint 26 are agreed with mutually, the mismatch error scope allowed between them is 0.001 " to 0.002 ", in this scope, can not cause obvious steam loss.More preferably, from wellbore surface to its bottom, PBR joint 26 and FC seal 28 that internal diameter is constantly diminished are arranged in the slotted liner tubing string, thereby while making underground work, whole PBR joints 26 all can leave gap with FC seal 28.When reaching borehole bottom, each FC seal 28 all can contact by its corresponding PBR joint 26, and sealing belongs to sealing fully.In this way, steam pressure can be realized homogenising, and maintains in the borehole length scope, and the possibility of generating steam bypass is minimum.
Under the situation of not using packer, in the time of can avoiding sealing, packer produces too many pressure or causes wearing and tearing then the inefficacy packer to be carried out to milling and recovery it because of steam.In addition, in the formation isolation district, use the PBR joint can not cause undesirable restriction to borehole diameter, as for identical purpose, using packer the same with the combination of pipeline.The limited type that can produce frictional dissipation, obstruction distribution of steam, increase pipeline demand and limit the down-hole used tool of borehole diameter.The function mode of preferred PBR/FC sealing system should configure similar with packer, like that, if the zone that well has a place to isolate, can directly turn off two steam pumps between the FC seal so simply so that sealing area can not produce fluid and other zones of itself and well are intercepted mutually.
Example
Following instance is only for further illustrating embodiments of the invention, and unrestricted limited range of the present invention.
Example 1:
A well has an intermediate casing in the degree of depth of 600m, be referred to as build section, and the total depth of well is 1500m.The horizontal section length of oil-producing formation or production area is 900m.Three different steam pump groups together with three packers together for steam treatment.The first packer is arranged on the position of dark 1200m, in 1200m to 1500m depth bounds, isolates 3/4 of nozzle quantity in the first steam pump.The second packer is arranged on the position of dark 900m, in the 1200m depth bounds at the 900m degree of depth to the first packer place the isolation the second steam pump nozzle quantity 1/2.The 3rd packer is arranged on the position of the 600m degree of depth, is positioned at intermediate casing bottom, in the 900m depth bounds at the 600m degree of depth and the second packer place, isolates 1/4 of nozzle quantity in the 3rd steam pump.
The sleeve pipe of predetermined quantity and steam pump together move the length that reaches required between packer.By the setting device of different spray nozzles on steam pump between the use packer, the operator can be sent to steam or other injection fluid well-distributings in stratum.
In the production cycle of needs, can maybe can be by the production sealing region division of steam pump for carrying out more greatly completion by same nozzle.If one of them isolated area is producing undesirable product, as water or sand, can be by the flow set of the steam pump of being correlated with at reduced levels or can turn off relevant steam pump fully.
In conjunction with specific embodiment the present invention described in the content of describing in the above; But, obviously can carry out various modifications and changes to the present invention under the prerequisite of spirit and scope more widely not breaking away from the present invention.
Claims (27)
1. carry and be distributed to a subsurface formations or, for described subsurface formations is produced to fluid and it is delivered to the device of described well, described device comprises for spraying fluid from a well for one kind:
A. one or more is positioned at the detachable steam pump of described well inside, and described each steam pump comprises coaxial an outer sleeve and a slides within sleeve;
B. one or many groups of described outer sleeves that are arranged at described steam pump on nozzle, by described nozzle ejection fluid or produce fluid and be conveyed into or send out described subsurface formations by described nozzle; And
C. the device for driving described slides within sleeve to turn round in described outer sleeve;
Wherein be positioned at the described slides within sleeve running of described outer sleeve to cover at least in part one on described outer sleeve or to organize nozzle more, thereby control the fluid inflow or flow out described subsurface formations.
2. device according to claim 1, wherein said one or more steam pump is by being joined together to form a steam pump cylinder without hole sleeve.
3. device according to claim 1, wherein said one or more steam pump is connected to the injection/production liner be connected with described subsurface formations removably.
4. device according to claim 3, in the group that wherein said injection/production liner choosing is comprised of free coiling, slotted liner and/or Mace Rui Te (meshrite) screen casing.
5. device according to claim 3, wherein said injection/described entirely sub-surface of production liner contact.
6. device according to claim 3, also comprise for one or more packer of steam pump described in the union of location in described injection/production liner, the size of described one or more packer is greater than the external diameter of described steam pump, and enough little of in the internal diameter that is fit to securely described injection/production liner.
7. device according to claim 6, wherein said one or more packer is arranged at a terminal position of described injection/production liner inside, and along described borehole length 1/3rd and 2/3rds places, thereby seal the annular space between described subsurface formations and described injection/production liner, described one or more steam pump.
8. device according to claim 1, at least one back-up ring that also comprises an inner surface that is arranged in described outer sleeve, described back-up ring is for limiting described slides within sleeve and turn round in described outer sleeve and preventing described slides within sleeve from passing described outer sleeve and lose.
9. device according to claim 1, an inner surface of wherein said outer sleeve also comprises one or more lock ring, described lock ring meshes with the corresponding lock ring groove coupling of an external surface that is positioned described slides within ring, to locate the described slides within sleeve in described outer sleeve.
10. device according to claim 1, an external surface of wherein said slides within sleeve also comprises one group of Europe shape (O) ring, with so that the fragment flow between the internal diameter of the external diameter of described slides within sleeve and described inner sleeve minimizes and stops, it is mobile.
11. device according to claim 1, wherein said for making the device that described slides within sleeve turns round in described outer sleeve comprise an erecting tools, insert described erecting tools, and with in the slides within sleeve of described device, be connected, thereby in described outer sleeve the described slides within sleeve of running.
12. device according to claim 11, the external diameter of wherein said erecting tools comprises that extension spreads all over one or more groove of described erecting tools length, described groove aligns with one or more pin coupling on being positioned described slides within sleeve, thereby make when described one or more groove aligns with described one or more pin, described erecting tools turns round in described slides within sleeve, and makes described erecting tools near described slides within sleeve when described one or more groove fails to align with described one or more pin.
13. device according to claim 1 is wherein said for making the device that described slides within sleeve turns round in described outer sleeve comprise that Remote Hydraulic drives.
14. device according to claim 1, wherein said one or organize nozzle more and be arranged at axle with described outer sleeve with respect to becoming 1 ° of orientation to 90 ° of angles.
15. device according to claim 14, wherein said one or organize nozzle more and be arranged at and become 60 ° of angles with the axle of outer sleeve.
16. device according to claim 14, in wherein said nozzle sets, the described orientation of each nozzle changes.
17. device according to claim 14, wherein said one or organize more nozzle with machining in described outer sleeve.
18. device according to claim 14, wherein said one or organize nozzle more and form a part that is mounted to the independent component of described outer sleeve.
19. device according to claim 14, wherein said one or organize nozzle more and there is a freely sectional drawing of the group of circle, taper, taper shape, ellipse, square and rectangle composition of choosing.
20. carry and be distributed to a subsurface formations or, for producing the method that fluid is delivered to described well at described subsurface formations, said method comprising the steps of from a well for spraying fluid for one kind:
D. one or more steam pump is inserted to described well, described steam pump comprises coaxial outer sleeve and a slides within sleeve and is disposed at one on described outer sleeve or organizes nozzle more;
E. make described slides within sleeve turn round in described outer sleeve, to cover at least in part one on described outer sleeve or to organize nozzle more; And control the fluid inflow or flow out described subsurface formations; And
F. make to spray or produce fluid by steam pump and be conveyed into or send out described subsurface formations through described nozzle.
21. method according to claim 20, wherein make described slides within sleeve turn round in described outer sleeve to comprise an erecting tools is inserted in described outer sleeve and with described slides within sleeve and is connected, thus in described outer sleeve the described slides within sleeve of running.
22. method according to claim 21, wherein in described outer sleeve, the described slides within sleeve of running comprises: described erecting tools is inserted in described outer sleeve until described erecting tools near described slides within sleeve; And promote described erecting tools in described slides within sleeve, thereby turn round described slides within sleeve in described outer sleeve.
23. method according to claim 21, wherein in described outer sleeve, the described slides within sleeve of running comprises and is inserted in described outer sleeve by described erecting tools and makes it to pass described slides within sleeve; And described erecting tools is retracted to described slides within sleeve, thereby turn round described slides within sleeve in described outer sleeve.
24. method according to claim 20, wherein make described slides within sleeve turn round in described outer sleeve to comprise from remote location to turn round with hydraulic-driven.
25. method according to claim 20, wherein said method is for SAGD (SAGD) application, described method also comprises a cycle stage before Fluid injection, wherein said slides within sleeve through be provided for covering on described slide outside sleeve half or more than one or organize nozzle more, thereby the heat production fluid in described subsurface formations provides the steam under low-pressure state, the cavity that improves mobility and expand steam chamber with this is thereafter steam injection phase and a production phase under higher pressure.
26. method according to claim 20, wherein said method is for depressing Fluid injection to described subsurface formations in the injection of splitting pressure higher than described subsurface formations.
27. carry and be distributed to a subsurface formations or, for described subsurface formations is produced to the method that fluid is delivered to described well, described method comprises step for spraying fluid from a well for one kind:
A. the terminal position to described well inserts one first and second pair of flow-control hanging pipe and PBR, wherein described PBR is connected to an intermediate casing and it is adhered on a position;
B. described first pair of flow-control hanging pipe and PBR are connected to an injection/production lining chapter;
C. one or more steam pump is connected to described second pair of flow-control hanging pipe and PBR, described steam pump comprises coaxial an outer sleeve and a slides within sleeve, and is arranged at one or more nozzle on described outer sleeve;
D. make described slides within sleeve turn round in described outer sleeve, to cover at least in part one on described outer sleeve or to organize nozzle more; Control the fluid inflow or flow out described subsurface formations; And
E. make to spray or produce fluid passes described nozzle inflow or flows out described subsurface formations by described steam pump.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2,730,875 | 2011-02-07 | ||
| CA2730875A CA2730875C (en) | 2011-02-07 | 2011-02-07 | Wellbore injection system |
| PCT/CA2012/000105 WO2012106804A1 (en) | 2011-02-07 | 2012-02-07 | Wellbore injection system |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN103477026A true CN103477026A (en) | 2013-12-25 |
Family
ID=46634652
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN2012800080664A Pending CN103477026A (en) | 2011-02-07 | 2012-02-07 | Wellbore injection system |
Country Status (11)
| Country | Link |
|---|---|
| EP (1) | EP2673461A1 (en) |
| JP (1) | JP2014507580A (en) |
| CN (1) | CN103477026A (en) |
| AP (1) | AP2013007059A0 (en) |
| BR (1) | BR112013020136A2 (en) |
| CA (1) | CA2730875C (en) |
| CO (1) | CO6781556A2 (en) |
| EA (1) | EA201370174A1 (en) |
| MX (1) | MX2013009052A (en) |
| SG (1) | SG192263A1 (en) |
| WO (1) | WO2012106804A1 (en) |
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN105113991A (en) * | 2015-09-22 | 2015-12-02 | 中国矿业大学(北京) | Steam jet drill bit |
| CN105709321A (en) * | 2016-01-12 | 2016-06-29 | 成都迅德科技有限公司 | Oxygen mask |
| CN112392433A (en) * | 2020-11-14 | 2021-02-23 | 中国石油天然气股份有限公司 | Continuous cable laying pipe switch sliding sleeve for oil extraction and use method |
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| US20160326843A1 (en) * | 2013-12-20 | 2016-11-10 | Absolute Completion Technologies Ltd. | Nozzle, wellbore tubular and method |
| US10487621B2 (en) | 2014-05-20 | 2019-11-26 | Interra Energy Services Ltd. | Method and apparatus of steam injection of hydrocarbon wells |
| US9957788B2 (en) | 2014-05-30 | 2018-05-01 | Halliburton Energy Services, Inc. | Steam injection tool |
| US10087711B2 (en) | 2014-10-01 | 2018-10-02 | Torsch Inc. | Fracking valve and method for selectively isolating a subterranean formation |
| WO2018184093A1 (en) * | 2017-04-04 | 2018-10-11 | Interra Energy Services Ltd. | Methods and apparatuses for steam injection in wellbores for hydrocaron recovery |
| CA2972203C (en) | 2017-06-29 | 2018-07-17 | Exxonmobil Upstream Research Company | Chasing solvent for enhanced recovery processes |
| CA2974712C (en) | 2017-07-27 | 2018-09-25 | Imperial Oil Resources Limited | Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes |
| CA2978157C (en) | 2017-08-31 | 2018-10-16 | Exxonmobil Upstream Research Company | Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation |
| CA2983541C (en) | 2017-10-24 | 2019-01-22 | Exxonmobil Upstream Research Company | Systems and methods for dynamic liquid level monitoring and control |
| CN112963129B (en) * | 2021-04-08 | 2024-06-07 | 中海石油(中国)有限公司 | Marine thickened oil exploitation turbine-driven centrifugal pump system and steam injection and oil exploitation method |
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- 2012-02-07 AP AP2013007059A patent/AP2013007059A0/en unknown
- 2012-02-07 WO PCT/CA2012/000105 patent/WO2012106804A1/en active Application Filing
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Also Published As
| Publication number | Publication date |
|---|---|
| BR112013020136A2 (en) | 2017-02-07 |
| EA201370174A1 (en) | 2014-02-28 |
| WO2012106804A1 (en) | 2012-08-16 |
| CA2730875A1 (en) | 2012-08-07 |
| MX2013009052A (en) | 2013-12-16 |
| CO6781556A2 (en) | 2013-10-31 |
| EP2673461A1 (en) | 2013-12-18 |
| SG192263A1 (en) | 2013-09-30 |
| CA2730875C (en) | 2015-09-08 |
| JP2014507580A (en) | 2014-03-27 |
| AP2013007059A0 (en) | 2013-08-31 |
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