CN108590631B - Underground pump unit and underground liquid discharge testing system - Google Patents
Underground pump unit and underground liquid discharge testing system Download PDFInfo
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- CN108590631B CN108590631B CN201810395782.1A CN201810395782A CN108590631B CN 108590631 B CN108590631 B CN 108590631B CN 201810395782 A CN201810395782 A CN 201810395782A CN 108590631 B CN108590631 B CN 108590631B
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- 239000007788 liquid Substances 0.000 title claims abstract description 63
- 238000012360 testing method Methods 0.000 title claims abstract description 23
- 239000012530 fluid Substances 0.000 claims abstract description 146
- 238000010438 heat treatment Methods 0.000 claims abstract description 11
- 230000015572 biosynthetic process Effects 0.000 claims description 22
- 210000002445 nipple Anatomy 0.000 claims description 21
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 14
- 238000002347 injection Methods 0.000 claims description 13
- 239000007924 injection Substances 0.000 claims description 13
- 238000003860 storage Methods 0.000 claims description 13
- 238000006243 chemical reaction Methods 0.000 claims description 10
- 230000005540 biological transmission Effects 0.000 claims description 9
- 238000007789 sealing Methods 0.000 claims description 7
- 238000007599 discharging Methods 0.000 claims description 6
- 239000004576 sand Substances 0.000 claims description 5
- 230000000149 penetrating effect Effects 0.000 claims description 2
- 230000002265 prevention Effects 0.000 claims description 2
- 239000003921 oil Substances 0.000 description 44
- 238000010586 diagram Methods 0.000 description 5
- 238000000034 method Methods 0.000 description 5
- 238000004891 communication Methods 0.000 description 3
- 238000006073 displacement reaction Methods 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 238000005086 pumping Methods 0.000 description 3
- 238000011084 recovery Methods 0.000 description 3
- 238000012546 transfer Methods 0.000 description 3
- 238000010276 construction Methods 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- 238000012545 processing Methods 0.000 description 2
- 230000002411 adverse Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 239000000284 extract Substances 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 238000005755 formation reaction Methods 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 239000012535 impurity Substances 0.000 description 1
- 239000000314 lubricant Substances 0.000 description 1
- 239000000155 melt Substances 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 230000020477 pH reduction Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 238000000926 separation method Methods 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
- E21B47/00—Survey of boreholes or wells
- E21B47/008—Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
-
- 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
- E21B43/121—Lifting well fluids
-
- 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
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- 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)
- Geophysics (AREA)
- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
- Reciprocating Pumps (AREA)
Abstract
The application discloses an underground pump unit and an underground liquid discharge testing system, wherein the underground pump unit comprises a working string consisting of an oil pipe, a pump seat and a packer, which is arranged in an underground casing, and further comprises a liquid discharge string arranged in the working string; the packer is positioned below the pump seat; the liquid draining pipe column comprises a pump core which is arranged in the pump seat and a hollow sucker rod which is connected to the top end of the pump core. According to the technical scheme, the power fluid and the stratum fluid can be separated, and underground well closing and thick oil heating can be realized.
Description
Technical Field
The present disclosure relates generally to the field of oil well testing and testing techniques, and in particular to a downhole pump unit and a downhole drainage testing system employing hydraulic drive and closed circulation.
Background
At present, in the technical field of oil and gas well oil testing and testing, formation drainage often adopts hydraulic pump drainage or screw pump drainage, wherein the hydraulic pump mainly comprises a hydraulic jet pump and a hydraulic piston pump.
The hydraulic pump is usually used at present, whether it is a jet pump or a piston pump, the working mode is that a pump core is put into a working pipe column, the working pipe column is at least composed of an oil pipe, a pump seat, a packer and the like from top to bottom, the pump core is sent into a pump seat under the well through a ground pump, then the pump pressure is increased to drive the pump under the well to work, stratum fluid and power fluid are returned to the ground from an annular space (short for oil-sleeve ring space) between the oil pipe and a sleeve pipe together, after the ground is separated and metered, a part of mixed fluid is separated and then used as the power fluid to be pumped into the well, and the pump under the well is driven to work. When the pump is started, liquid is pumped in from the oil-sleeve ring space, and returns out from the operation oil pipe, so that the pump core is flushed out of the wellhead. Namely, the positive circulation is used for pumping down and discharging liquid, and the reverse circulation is used for pumping up. The working mode is very simple and convenient, so that the method is widely applied. However, the common disadvantages of the two are that the formation fluid and the power fluid are mixed together and discharged, which makes a bad judgment on the true liquid property of the formation fluid.
The screw pump can drain pure stratum fluid, but the lifting capacity is limited due to the torque limitation of the sucker rod and the dynamic seal leakage between the screw and the pump barrel, and the pressure difference is generally not more than 10 MPa. In addition, there are also great limitations to the application of thickened oil thermal recovery.
The hydraulic piston pump is adopted to drain the fluid, so that the power fluid and the stratum fluid can be separated, namely, the power fluid is sealed and circulated, and a circulation channel is needed to be provided for the power fluid to separate the power fluid from the stratum fluid. The common practice is that a layer of small oil pipe is arranged in the large oil pipe to form a concentric pipe column, a piston pump core is put into the small oil pipe and pumped into a seat during liquid discharge, after the piston group in the pump core is driven to reciprocate by continuous pressurization, spent power liquid returns to the ground from an annular space between the small oil pipe and the large oil pipe, and a power liquid sealing cycle is formed. Formation fluid is then discharged from the annulus between the large tubing and the casing. When the pump is started, liquid is pumped into an annular space between the small oil pipe and the large oil pipe, so that the pump core can be flushed out of the wellhead. Such as an article published in journal of Petroleum machinery, 2002, 7As described in the development application of concentric tubing closed hydraulic piston pumps.
The concentric pipe column closed hydraulic piston pump is mainly used for oil extraction technology, and mainly has the following problems in the aspects of oil testing and liquid discharging testing:
firstly, the pump core is arranged in the central tube, the central tube is required to have enough inner diameter, and if the inner diameter is too small, the pump core is smaller, so that the processing difficulty of the pump core is increased, and the liquid discharge amount is also required to be reduced. If at 5 1 / 2 "working in casing tube, the maximum central tube can only be 2 3 / 8 "oil pipe (inner diameter 50.8 mm), the maximum outer layer pipe can only be 3 1 / 2 "tubing (76 mm inside diameter), the maximum outside diameter of the pump core cannot exceed 50mm. Thus 5 1 / 2 "most commonly used 2 for casing operations 7 / 8 The oil pipe is not used, all operation oil pipes need to be replaced, and the cost is high and the universality is poor.
And secondly, a layer of spent power fluid channel is arranged between the power fluid channel and the stratum fluid channel, if thick oil is encountered, the heat energy for heating the power fluid can not directly act on the thick oil to melt the thick oil. That is, the stratum fluid channel is not closely adjacent to the power fluid channel, which is not beneficial to the realization of thickened oil thermal recovery.
Thirdly, the pump core can not realize underground well shut-in per se, and does not have a test function.
Disclosure of Invention
In view of the above-mentioned drawbacks or shortcomings in the prior art, it is desirable to provide a downhole pump unit and a downhole drainage testing system that can separate power fluid from formation fluid, have a large pumping core displacement, are low in cost, can facilitate downhole well shut-in, and can achieve heating of heavy oil.
In a first aspect, the present application provides a downhole pump unit comprising a working string comprising an oil pipe, a pump seat and a packer, which is run into a casing, and a drainage string which is run into the working string; the pump seat is positioned above the packer; the liquid draining pipe column comprises a pump core which is arranged in the pump seat and a hollow sucker rod which is connected to the top end of the pump core.
According to the technical scheme provided by the embodiment of the application, the pump seat comprises an outer cylinder and a sliding sleeve positioned in the outer cylinder; a pawl is fixed at the top end of the sliding sleeve; a pawl groove for clamping a pawl is arranged outside the pump core; the inner wall of the outer cylinder is respectively provided with an upper clamping table used for clamping the open pawl and a lower step used for supporting the bottom end of the sliding sleeve above and below the sliding sleeve, the sliding sleeve and the outer cylinder are respectively provided with a sliding sleeve circulation hole and an outer cylinder circulation hole, and the sliding sleeve circulation hole and the outer cylinder circulation hole are aligned when the sliding sleeve is positioned at the bottom dead center position and staggered when the sliding sleeve is positioned at the top dead center position.
According to the technical scheme provided by the embodiment of the application, the pressure gauge is installed at the bottom end of the pump core.
According to the technical scheme provided by the embodiment of the application, the sand prevention pipe is arranged below the packer.
According to the technical scheme provided by the embodiment of the application, the top of pump core is provided with the crossover sub with pump seat sealing connection, the crossover sub is used for leading in the annular space below the crossover sub that is located between pump core and the pump seat with the power fluid that gets into the pump core from hollow sucker rod to with the formation fluid that draws from in the pump core is discharged to the annular space above the crossover sub between pump core and the pump seat.
According to the technical scheme provided by the embodiment of the application, the pump core comprises a lower piston cylinder, an upper piston cylinder positioned below the conversion joint, a reversing nipple positioned between the upper piston cylinder and the lower piston cylinder, a reversing valve, a hollow connecting rod piston group and a lower joint fixed at the bottom end of the lower piston cylinder;
the hollow connecting rod piston group comprises a hollow connecting rod penetrating through the reversing pup joint, and an upper piston and a lower piston which are connected to two ends of the hollow connecting rod and are respectively in dynamic seal fit with the upper piston cylinder and the lower piston cylinder; the upper piston and the lower piston are hollow structures which are penetrated up and down; the lower end of the interior of the adapter is provided with a fixed valve; a shut-in valve is arranged in the lower joint; a traveling valve is arranged in the upper piston;
the reversing valve can be arranged between the reversing pup joint and the hollow connecting rod in an up-and-down sliding mode.
According to the technical scheme provided by the embodiment of the application, the reversing valve is positioned in the reversing cavity between the reversing nipple and the hollow connecting rod and radially separates the reversing cavity into a power liquid cavity and a spent power liquid cavity; the upper part of the reversing nipple is provided with a power liquid inlet for leading the power liquid flowing in from the position between the pump seat and the pump core into the power liquid cavity.
According to the technical scheme provided by the embodiment of the application, the side wall of the reversing cavity is respectively provided with an upper piston chamber inlet communicated into an upper piston cylinder, a spent power liquid outlet communicated to an outer cylinder circulation hole and a lower piston chamber inlet communicated into a lower piston cylinder from top to bottom; the middle part of the reversing valve is radially provided with a reversing port; when the reversing valve is positioned at the lower limit point, the inlet of the upper piston chamber is directly communicated with the power fluid cavity, and the spent power fluid outlet and the inlet of the lower piston chamber are simultaneously communicated with the spent power fluid cavity; when the reversing valve is positioned at the upper limit point, the inlet of the lower piston chamber is communicated with the power fluid cavity through a reversing port, and the spent power fluid outlet and the inlet of the upper piston chamber are simultaneously communicated with the spent power fluid cavity;
the bottom of the reversing cavity is tightly attached to the hollow connecting rod and extends upwards to form a valve core; the lower part of the reversing valve is inserted between the valve core and the reversing nipple; a pressure transmission hole is arranged between the bottom of the valve core and the reversing nipple; the middle part of the valve core, which faces the side surface of the hollow connecting rod, is provided with a diversion trench; the reversing nipple is provided with a pressure relief hole communicated with the outer cylinder circulation hole below the valve core; an upper reversing groove is formed in the side wall of the upper part of the hollow connecting rod, and a pair of adjacent lower reversing grooves are formed in the lower part of the hollow connecting rod;
when the hollow connecting rod is positioned at the position of the lower limit point, the upper reversing groove is simultaneously communicated with the pressure relief hole and the pressure transmission hole;
when the hollow connecting rod is positioned at the upper limit point, the protruding parts between the two lower reversing grooves correspond to the diversion grooves, so that the pressure transmission holes are communicated with the power liquid cavity.
In a second aspect, the present application further provides an underground drainage testing system, including any one of the above-mentioned underground pump unit, a power fluid circulation system, and a formation fluid metering system; the power fluid circulation system comprises a water injection pump for providing power fluid into the hollow sucker rod and a power fluid storage tank communicated with an annular cavity between the sleeve and the oil pipe; the stratum fluid metering system comprises a stratum fluid storage tank communicated with an annular cavity between the hollow sucker rod and the oil pipe; the water injection pump extracts power fluid from the power fluid storage tank.
According to the technical scheme provided by the embodiment of the application, a heating device is arranged between the power liquid storage tank and the water injection pump.
According to the method, the pump seat is connected with the oil pipe, the packer and the like in a matched manner to form a working pipe column, and the hollow sucker rod is directly connected with the pump core, so that a power liquid input channel, a power liquid discharge channel and a closed circulation channel of a stratum liquid discharge channel are formed by only putting one layer of oil pipe in the sleeve; compared with the prior art that a double-layer oil pipe is arranged in the sleeve, the outer diameter of the pump core can be larger, so that the displacement of the pump core is larger, the processing difficulty is smaller, and the production cost of the pump core is reduced.
According to the technical scheme provided by the embodiment of the application, the pump seat is internally provided with the pawl type sliding sleeve to realize the linkage with the pump core, when the pump core is seated in the sliding sleeve and the sliding sleeve is pushed to move downwards by pressurization, the pawl on the sliding sleeve contracts and is clamped in the pawl groove outside the pump core, so that the sliding sleeve is linked with the pump core until the lower dead point; at this time, the circulating channel on the pump seat is opened, so that the liquid discharging function can be realized; in normal conditions, namely when the pump core is not put into the pump seat, the pawl on the sliding sleeve is in an open state and the sliding sleeve is kept at the upper dead point position through the upper clamping table structure, at the moment, the circulating channel on the pump seat is closed, and the pump seat has full-pass performance and pressure-bearing capacity and can perform various operations on stratum, such as perforation, test, acidification, fracturing and the like.
The liquid discharge test system has the test function, after liquid discharge for a period of time, when the pressure recovery is measured by closing the liquid production channel, the power liquid circulation channel can be closed, then the pressure is exerted on the power liquid circulation channel from the stratum liquid channel, the well closing valve in the pump core is in a reverse pressurizing state and is kept, the well closing valve plugs the stratum liquid channel just like a plug at the moment, underground well closing is realized, and the pressure gauge records the pressure and temperature change of the whole liquid discharge test process.
The drainage testing system of the application is applied to thick oil exploitation in a mode that the stratum liquid channel is surrounded by the power liquid channel and the spent power liquid channel, and the heating of the thick oil can be realized by a mode of heating the power liquid.
Drawings
Other features, objects and advantages of the present application will become more apparent upon reading of the detailed description of non-limiting embodiments, made with reference to the following drawings, in which:
FIG. 1 is a schematic structural view of a first embodiment of the present application;
FIG. 2 is a schematic diagram of the structure of the pump base before the pump core is seated;
FIG. 3 is a schematic diagram of the structure of the pump base after the pump core is seated;
FIG. 4 is a schematic illustration of the structure of the adapter at the top end of the pump core;
FIG. 5 is a schematic view of the pump core with the hollow connecting rod in its top dead center position;
FIG. 6 is a schematic view of the pump core with the hollow connecting rod in its bottom dead center position;
FIG. 7 is a schematic illustration of the structure of the hollow connecting rod piston assembly of the present application;
FIG. 8 is a schematic view of the structure of the reversing nipple with the hollow link in its bottom dead center position;
FIG. 9 is a schematic view of the structure of the reversing nipple with the hollow link in its top dead center position;
FIG. 10 is a schematic diagram of a downhole drainage testing system of the present application.
Reference numerals in the drawings:
10. a sleeve; 20. a working string; 30. a liquid discharge pipe column; 40. a power fluid circulation system; 70. an oil pipe tee joint; 60. tubing hanger;
21. a pump base; 22. an oil pipe; 23. a packer; 24. a sliding sleeve; 25. a pawl; 26. an outer cylinder circulation hole; 27. a sliding sleeve circulation hole; 28. an outer cylinder; 31. a pump core; 32. a hollow sucker rod; 33. a pawl slot; 34. a conversion joint; 35. a pressure gauge; 41. a water injection pump; 42. a power fluid storage tank; 51. a formation fluid storage tank;
31-2, upper piston cylinder; 31-3, lower piston cylinder; 31-4, a hollow connecting rod; 31-5, reversing pup joint; 31-6, a reversing valve; 31-7, a fixed valve; 31-8, closing the well valve; 31-9, a traveling valve; 31-10, lower joint
34-1, an upper cylindrical section; 34-2, a lower cylindrical section; 34-3, a linking part; 34-4, a first bevel; 34-5, a second bevel;
31-4-1, upper reversing groove; 31-4-2, lower reversing groove; 31-4-3, upper piston; 31-4-4, lower piston;
31-5-1, a power fluid cavity; 31-5-2, spent power fluid chamber; 31-5-3, a power fluid inlet; 31-5-4, upper piston chamber inlet; 31-5-5, spent power fluid exhaust; 31-5-6, lower piston chamber inlet;
31-5-7, valve core; 31-5-8, pressure transmission holes; 31-5-9, pressure relief holes; 31-5-7-1, diversion trenches;
31-6-1, reversing port.
Detailed Description
The present application is described in further detail below with reference to the drawings and examples. It is to be understood that the specific embodiments described herein are merely illustrative of the invention and are not limiting of the invention. It should be noted that, for convenience of description, only the portions related to the invention are shown in the drawings.
It should be noted that, in the case of no conflict, the embodiments and features in the embodiments may be combined with each other. The present application will be described in detail below with reference to the accompanying drawings in conjunction with embodiments.
Referring to fig. 1, a schematic structural diagram of an embodiment of a downhole pump unit according to the present application includes a working string 20 consisting of an oil pipe 22, a pump seat 21 and a packer 23, which is run into a casing 10, and a drain string 30 which is run into the working string 20; the pump seat 21 is positioned above the packer 23; the drain pipe column 30 comprises a pump core 31 which is arranged in the pump seat 21 and a hollow sucker rod 32 which is connected to the top end of the pump core 31. The upper and lower ends of the pump seat 21 are respectively provided with a female buckle and a male buckle so as to be connected with an oil pipe or other well tool by screw threads.
In field operation, the designed operation pipe column 20 is firstly sequentially lowered into the casing 10 of the construction well, and the packer 23 is set at a preset position in the well; when liquid is needed to be discharged, the liquid discharge pipe column 30 is put into the operation pipe column 20, so that the pump core 31 is seated in the pump seat 21; when the liquid is discharged, power liquid enters from the hollow sucker rod 32, power for reciprocating movement is provided for the pump core 31, stratum liquid pumped by the pump core 31 from underground is discharged from an annular space between the hollow sucker rod 32 and the oil pipe 22, and spent power liquid of the pump core 31 is discharged from the annular space between the oil pipe 22 and the sleeve 10; preferably, a pressure gauge 35 may be attached to the bottom end of the pump core 31, the pressure gauge 35 being lowered downhole with the drain string 30 for monitoring pressure and temperature changes downhole at any time.
In the above embodiment, for example, the sleeve 10 is 5 1 / 2 "casing, tubing 32 is commonly used 2 7 / 8 The inner diameter of the oil pipe is 62mm, the outer diameter of the pump core in the embodiment can be 58-60 mm, and the single-stroke displacement can be improved by about 50% compared with a 50mm concentric tubular column hydraulic piston pump.
To prevent formation sand from entering the fluid production passage and adversely affecting fluid drainage, a sand control pipe may be provided in the work string 20 below the packer 23 to prevent mechanical impurities such as formation sand from entering the interior of the work string.
The power fluid can be made by adding some lubricant into clear water, and has convenient preparation and low cost.
Preferably, the pump seat 21 includes an outer barrel 28 and a sliding sleeve 24; a pawl 25 is fixed at the top end of the sliding sleeve 24; a pawl groove 33 for clamping the pawl 25 is arranged outside the pump core 31; the inner wall of the outer cylinder 28 is respectively provided with an upper clamping table for clamping the open pawl and a lower step for supporting the bottom end of the sliding sleeve 24 above and below the sliding sleeve 24, the sliding sleeve 24 and the outer cylinder 28 are respectively provided with a sliding sleeve circulation hole 27 and an outer cylinder circulation hole 26, and the sliding sleeve circulation holes 27 and the outer cylinder circulation holes 26 are aligned when the sliding sleeve 24 is positioned at the bottom dead center position and staggered when the sliding sleeve 24 is positioned at the top dead center position.
When the pump core 31 is not seated, as shown in fig. 2, the slide sleeve 24 is at its top dead center position, at which time the outer cylinder circulation hole 26 of the outer cylinder 28 is offset from the slide sleeve circulation hole 27 on the slide sleeve 24, the outer cylinder 28 is closed, and the pawls 25 on the slide sleeve 24 are in an open state to hold the slide sleeve 24 at its top dead center position. As shown in fig. 3, when the pump core 31 is seated in the pump seat 21 with the drain pipe string 30, the pawl 25 on the slide sleeve 24 is aligned with the pawl groove 33 of the pump core 31, and when the slide sleeve 24 is pushed to move downward by pressurization, the pawl 25 contracts, so that the slide sleeve 24 and the pump core 31 are interlocked until the bottom end of the slide sleeve 24 reaches its bottom dead center position. At this time, the outer cylinder circulation hole 26 on the outer cylinder 28 is aligned with the sliding sleeve circulation hole 27 on the sliding sleeve 24, the circulation passage of the pump seat 21 is opened, and the spent power fluid can enter the annular space between the oil pipe 22 and the sleeve 10 to realize the power fluid circulation.
When the pump core 31 is lifted out after the liquid discharge is finished, the top end of the liquid discharge pipe column 30 is lifted upwards, the pawl 25 on the sliding sleeve 24 in the pump seat 21 is contracted when the pump core 31 is seated, and the pawl groove 33 clamped outside the pump core 31 is linked with the pump core, so that the sliding sleeve 24 in the pump seat 21 returns to the position of the upper clamping table along with the pump core 31 when the pump core 31 is lifted out, the pump core 31 is released, and the pump core 31 is taken out, so that the circulation channel on the pump seat 21 is synchronously closed, the full-communication performance and the pressure-bearing capacity of the operation pipe column 20 are restored, and any other operation can be performed.
As shown in fig. 4, it is preferable that: the top end of the pump core 31 is provided with a conversion joint 34 in sealing connection with the pump seat 21, and the conversion joint 34 is used for guiding the power fluid entering the pump core 31 from the hollow sucker rod 32 into an annular space between the pump core 31 and the pump seat 21 and below the conversion joint 34 and discharging the stratum fluid pumped out from the pump core 31 into the annular space between the pump core 31 and the pump seat 21 and above the conversion joint 34. The adapter 34 comprises an upper cylindrical section 34-1, a lower cylindrical section 34-2 and a joint part 34-3 for connecting the upper cylindrical section 34-1 and the lower cylindrical section 34-2; the connecting part 34-3 protrudes outwards to be connected with the pump seat 21 in a sealing way, so that an annular space between the pump core 31 and the pump seat 21 is divided into an upper part and a lower part; the connecting part 34-3 is internally provided with a first inclined opening 34-4 and a second inclined opening 34-5; the power fluid introduced from the hollow sucker rod 32 is transferred into the annular space between the pump core 31 and the pump seat 21 below the joint 34-3 through the first inclined port 34-4, and the stratum fluid pumped out from the pump core 31 is discharged into the annular space between the pump core 31 and the pump seat 21 above the joint 34-3 through the second inclined port 34-5.
As shown in fig. 5 and 6, the pump core 31 includes a transfer joint 34, an upper piston cylinder 31-2, a lower piston cylinder 31-3, a reversing valve 31-6, a hollow link piston group, a reversing nipple 31-5 connected between the upper piston cylinder 31-2 and the lower piston cylinder 31-3, and a lower joint 31-10 fixed under the lower piston cylinder 31-3;
as shown in fig. 7, the hollow link piston group includes a hollow link 31-4 passing through the gap sub 31-5 and upper and lower pistons 31-4-3 and 31-4-4 connected to both ends of the hollow link 31-4 and in dynamic sealing engagement with the upper and lower piston cylinders 31-2 and 31-3, respectively; the hollow connecting rod piston group can reciprocate in the upper piston cylinder and the lower piston cylinder; the upper piston 31-4-3 and the lower piston 31-4-4 are hollow structures with upper and lower through holes; the reversing valve 31-6 is arranged in a cavity between the hollow connecting rod 31-4 and the reversing pup joint 31-5 in a vertically sliding manner;
as shown in fig. 5 and 6, the inner lower end of the adapter 34 is provided with a fixed valve 31-7; a shut-in valve 31-8 is arranged in the lower joint 31-10; a traveling valve 31-9 is arranged in the upper piston 31-4-3.
The fixed valve 31-7, the traveling valve 31-9 and the shut-in valve 31-8 are all one-way valves, and stratum fluid can only pass through the one-way valves upwards but cannot pass through the one-way valves downwards; when the hollow connecting rod piston group moves upwards, the traveling valve 31-9 is closed, the fixed valve 31-7 is opened, and the stratum fluid above the upper piston 31-4-3 is lifted to the upper part of the fixed valve 31-7, so that the stratum fluid enters an annular space between the hollow sucker rod 32 and the oil pipe 22; when the hollow connecting rod piston group moves downwards, the fixed valve 31-7 is closed, the traveling valve 31-9 is opened, and the stratum fluid enters the upper part of the upper piston through the traveling valve 31-9, so that the stratum fluid can be continuously lifted to the ground repeatedly, and the well closing valve 31-8 is always in an open state in the drainage process.
As shown in fig. 8 and 9, the reversing valve 31-6 is positioned in the reversing cavity between the reversing nipple 31-5 and the hollow connecting rod 31-4 and radially divides the reversing cavity into a power fluid cavity 31-5-1 and a spent power fluid cavity 31-5-2; the upper part of the reversing nipple 31-5 is provided with a power fluid inlet 31-5-3 for introducing the power fluid flowing in between the pump seat 21 and the pump core 31 into the power fluid chamber 31-5-1.
The side wall of the reversing cavity is respectively provided with an upper piston chamber inlet 31-5-4 communicated into the upper piston cylinder 31-2, a spent power liquid outlet 31-5-5 communicated to the outer cylinder circulation hole 26 and a lower piston chamber inlet 31-5-6 communicated into the lower piston cylinder 31-3 from top to bottom; the middle part of the reversing valve 31-6 is radially provided with a reversing port 31-6-1; as shown in fig. 7, when the reversing valve 31-6 is located at the lower limit point thereof, the upper piston chamber inlet 31-5-4 is directly connected to the power fluid chamber 31-5-1, and the spent power fluid outlet 31-5-5 and the lower piston chamber inlet 31-5-6 are simultaneously connected to the spent power fluid chamber 31-5-2; as shown in fig. 8, when the reversing valve 31-6 is located at the upper limit point thereof, the lower piston chamber inlet 31-5-6 is communicated with the power fluid chamber 31-5-1 through the reversing port 31-6-1, and the spent power fluid outlet 31-5-5 and the upper piston chamber inlet 31-5-4 are simultaneously communicated with the spent power fluid chamber 31-5-2;
the bottom of the reversing cavity is tightly attached to the hollow connecting rod 31-4 and extends upwards to form a valve core 31-5-7; the lower part of the reversing valve 31-6 is inserted between the valve core 31-5-7 and the reversing nipple 31-5; a pressure transmission hole 31-5-8 is arranged between the bottom of the valve core 31-5-7 and the reversing nipple 31-5; the middle part of the side surface of the valve core 31-5-7 facing the hollow connecting rod 31-4 is provided with a diversion trench 31-5-7-1; the reversing nipple 31-5 is provided with a pressure relief hole 31-5-9 communicated with the outer cylinder circulation hole 26 below the valve core 31-5-7; as shown in fig. 7, the upper side wall of the hollow connecting rod 31-4 is provided with an upper reversing groove 31-4-1, and the lower part is provided with a pair of adjacent lower reversing grooves 31-4-2;
as shown in fig. 8, when the hollow connecting rod 31-4 is located at the lower limit point, the upper reversing groove 31-4-1 communicates the pressure relief hole 31-5-9 and the pressure transfer hole 31-5-8 at the same time;
as shown in fig. 9, when the hollow connecting rod 31-4 is located at the upper limit position thereof, the protruding portion between the two lower reversing grooves 31-4-2 corresponds to the diversion groove 31-5-7-1, so that the pressure transmitting hole 31-5-8 is in communication with the power fluid chamber 31-5-1.
As shown in fig. 4 to 9, the power fluid pumped from the hollow sucker rod enters the annular chamber between the pump core 31 and the pump seat 21 through the first inclined port 34-4 in the joint portion 34-3 of the adapter 34. Then enters the power fluid cavity 31-5-1 through the power fluid inlet 31-5-3 of the reversing nipple 31-5 on the pump core 31;
as shown in fig. 8, when the reversing valve 31-6 is at the lower limit point, the upper piston chamber inlet 31-5-4 is directly communicated with the power fluid chamber 31-5-1, power fluid enters the upper piston cylinder 31-2 through the upper piston chamber inlet 31-5-4, the hollow connecting rod piston group is pushed to move upwards, the pressure in the lower piston cylinder 31-3 is reduced, the downhole pressure pushes the shut-in valve 31-8 to open, and formation fluid is sucked into the lower piston cylinder, at this time, the traveling valve 31-9 is closed due to the pressure increase in the formation fluid chamber of the upper piston cylinder 31-2, the fixed valve 31-7 is opened, and formation fluid in the formation fluid chamber of the upper piston cylinder 31-2 is discharged from the fixed valve 31-7; simultaneously, the spent power fluid outlet 31-5-5 and the lower piston chamber inlet 31-5-6 are communicated with the spent power fluid cavity 31-5-2 at the same time; spent power fluid in the lower piston cylinder 31-3 is discharged through the lower piston chamber inlet 31-5-6, the spent power fluid discharge port 31-5-5, and the outer cylinder circulation hole 26 in this order, and enters the annular space between the pump mount 21 and the sleeve 10.
As shown in fig. 5 and 9, when the hollow connecting rod piston assembly moves to the top dead center position, the raised part between the two lower reversing grooves 31-4-2 corresponds to the diversion groove 31-5-7-1, so that the pressure transmission hole 31-5-8 is communicated with the power fluid cavity 31-5-1, high-pressure power fluid acts on the bottom of the reversing valve 31-6 at the same time, and the reversing valve is pushed to move upwards to the upper limit position. At this time, the lower piston chamber inlet 31-5-6 is communicated with the power fluid chamber 31-5-1 through the reversing port 31-6-1, and power fluid enters the power fluid chamber of the lower piston cylinder 31-3 through the lower piston chamber inlet 31-5-6 to push the hollow connecting rod piston group to move downwards; at this time, the fixed valve 31-7 is closed, the traveling valve 31-9 is opened, and the formation fluid is sucked into the formation fluid chamber of the upper piston cylinder 31-2 through the center hole of the hollow connecting rod piston group. Simultaneously, the spent power fluid outlet 31-5-5 and the upper piston chamber inlet 31-5-4 are communicated with the spent power fluid cavity 31-5-2, and spent power fluid in the power fluid cavity of the upper piston cylinder 31-2 is sequentially discharged through the upper piston chamber inlet 31-5-4, the spent power fluid outlet 31-5-5 and the outer cylinder circulation hole 26 and enters an annular space between the pump seat 21 and the sleeve 10.
As shown in fig. 6 and 8, when the hollow connecting rod piston assembly moves to the bottom dead center position, the upper reversing groove 31-4-1 communicates the relief hole 31-5-9 with the pressure transfer hole 31-5-8; the bottom of the reversing valve 31-6 is depressurized, and the reversing valve 31-6 is pushed back to the lower limit point position; at this time, the power fluid enters the upper piston cylinder again to push the hollow connecting rod piston group to move upwards. Such reciprocation may lift formation fluid to the surface.
FIG. 10 is a schematic diagram of an underground drainage testing system according to the present application, which includes any of the above-mentioned underground pump units, a power fluid circulation system 40, and a formation fluid metering system; the power fluid circulation system 40 and the formation fluid metering system are positioned on the ground; the power fluid circulation system 40 comprises a water injection pump 41 for supplying power fluid into the hollow sucker rod 32, and a power fluid storage tank 42 communicated with the annular cavity between the sleeve 10 and the oil pipe 22; the formation fluid metering system includes a formation fluid reservoir 51 in communication with the annular cavity between the hollow sucker rod 32 and the tubing 22; the water injection pump 41 pumps the power fluid from the power fluid storage tank 42. As will be appreciated by those skilled in the art, the above-mentioned downhole drainage testing system is further provided with a pipeline for connecting the systems and components, and a valve mounted on the pipeline.
In field operation, the designed working string 20 is sequentially lowered into the construction wellbore, the packer 23 is set at a predetermined position downhole, the tubing hanger 60 is set, and the tubing tee 70 is connected. Various operations such as perforation, acidizing, fracturing, etc. may be performed on the desired layer at this time.
When liquid discharge is needed, the liquid discharge pipe column 30 is sequentially lowered into the operation pipe column 20, the pump core 21 is seated into the pump seat 31, the circulating channel on the pump seat 31 is opened by lowering and pressurizing the liquid discharge pipe column 30, and then the power liquid circulating system 40 and the stratum liquid metering system are connected. Then the water injection pump 41 is started, power fluid is conveyed to the pump core 21 through the hollow sucker rod, the hollow connecting rod piston group in the pump core 21 is driven to reciprocate, and stratum fluid is lifted to the ground through the annular space between the hollow sucker rod 32 and the oil pipe 22 for separation and metering. The spent power fluid returns to the power fluid storage tank 42 through the annular space between the oil pipe 22 and the sleeve 10, and enters the water injection pump for pressurization after being filtered to form a power fluid closed cycle, and the underground pump piston group is driven to continuously reciprocate, so that the stratum fluid is continuously lifted to the ground.
When the well is shut in, the well shut-in valve 31-8 can be pressurized in the reverse pressurizing state from the liquid producing channel, so that the liquid producing channel can be shut in, the well is shut in, and the operation is very convenient.
Preferably, a heating device is arranged between the power fluid storage tank 41 and the water injection pump 42. In the case of a thick oil well, a heating device, such as a heating furnace, is disposed between the power fluid reservoir 41 and the water injection pump 42 in the power fluid circulation system 40, and the power fluid is pumped into the well from the hollow sucker rod 32 after being heated to a certain temperature, so that the heat emitted by the hollow sucker rod 32 directly melts the thick oil, thereby smoothly discharging the liquid. The heating temperature of the power fluid is based on the fact that the thick oil can be melted.
The foregoing description is only of the preferred embodiments of the present application and is presented as a description of the principles of the technology being utilized. It will be appreciated by persons skilled in the art that the scope of the invention referred to in this application is not limited to the specific combinations of features described above, but it is intended to cover other embodiments in which any combination of features described above or equivalents thereof is possible without departing from the spirit of the invention. Such as the above-described features and technical features having similar functions (but not limited to) disclosed in the present application are replaced with each other.
Claims (7)
1. An underground pump unit, characterized in that: the well casing comprises a working string (20) which is arranged in a downhole casing (10) and consists of an oil pipe (22), a pump seat (21) and a packer (23), and further comprises a liquid draining string (30) which is arranged in the working string (20); the packer (23) is positioned below the pump seat (21); the liquid draining pipe column (30) comprises a pump core (31) which is arranged in the pump seat (21) and a hollow sucker rod (32) which is connected to the top end of the pump core (31);
the pump seat (21) comprises an outer cylinder (28) and a sliding sleeve (24) positioned in the outer cylinder (28); a pawl (25) is fixed at the top end of the sliding sleeve (24); a pawl groove (33) for clamping the pawl (25) is arranged outside the pump core (31); an upper clamping table for clamping an open pawl and a lower step for supporting the bottom end of the sliding sleeve (24) are respectively arranged above and below the sliding sleeve (24) on the inner wall of the outer cylinder (28), a sliding sleeve circulation hole (27) and an outer cylinder circulation hole (26) are respectively formed in the sliding sleeve (24) and the outer cylinder (28), and the sliding sleeve circulation hole (27) and the outer cylinder circulation hole (26) are aligned when the sliding sleeve (24) is positioned at the bottom dead center position and staggered when the sliding sleeve is positioned at the top dead center position;
the top end of the pump core (31) is provided with a conversion joint (34) which is connected with the pump seat (21) in a sealing way, and the conversion joint (34) is used for guiding power fluid entering the pump core (31) from the hollow sucker rod (32) into an annular space between the pump core (31) and the pump seat (21) and positioned below the conversion joint (34) and discharging stratum fluid pumped out from the pump core (31) into the annular space between the pump core (31) and the pump seat (21) and positioned above the conversion joint (34);
the pump core (31) comprises a lower piston cylinder (31-3), an upper piston cylinder (31-2) positioned below the adapter (34), a reversing nipple (31-5) positioned between the upper piston cylinder (31-2) and the lower piston cylinder (31-3), a reversing valve (31-6), a hollow connecting rod piston group and a lower adapter (31-10) fixed at the bottom end of the lower piston cylinder (31-3);
the hollow connecting rod piston group comprises a hollow connecting rod (31-4) penetrating through the reversing pup joint (31-5) and an upper piston (31-4-3) and a lower piston (31-4-4) which are connected to two ends of the hollow connecting rod (31-4) and are respectively in dynamic sealing fit with the upper piston cylinder (31-2) and the lower piston cylinder (31-3); the upper piston (31-4-3) and the lower piston (31-4-4) are hollow structures which are penetrated up and down; the lower end of the interior of the adapter (34) is provided with a fixed valve (31-7); a shut-in valve (31-8) is arranged in the lower joint (31-10); a traveling valve (31-9) is arranged in the upper piston (31-4-3);
the reversing valve (31-6) is arranged between the reversing pup joint (31-5) and the hollow connecting rod (31-4) in a vertically sliding mode.
2. The downhole pump assembly according to claim 1, wherein: and a pressure gauge (35) is arranged at the bottom end of the pump core (31).
3. The downhole pump assembly according to claim 1, wherein: a sand prevention pipe is arranged below the packer (23).
4. The downhole pump assembly according to claim 1, wherein:
the reversing valve (31-6) is positioned in a reversing cavity between the reversing nipple (31-5) and the hollow connecting rod (31-4) and radially separates the reversing cavity into a power liquid cavity (31-5-1) and a spent power liquid cavity (31-5-2); the upper part of the reversing nipple (31-5) is provided with a power fluid inlet (31-5-3) for leading the power fluid flowing in from the pump seat (21) to the pump core (31) to the power fluid cavity (31-5-1).
5. The downhole pump assembly of claim 4, wherein:
the side wall of the reversing cavity is respectively provided with an upper piston chamber inlet (31-5-4) communicated into the upper piston cylinder (31-2), a spent power liquid outlet (31-5-5) communicated with the outer cylinder circulation hole (26) and a lower piston chamber inlet (31-5-6) communicated into the lower piston cylinder (31-3) from top to bottom; the middle part of the reversing valve (31-6) is radially provided with a reversing port (31-6-1); when the reversing valve (31-6) is positioned at the lower limit point of the reversing valve, the upper piston chamber inlet (31-5-4) is directly communicated with the power fluid cavity (31-5-1), and the spent power fluid outlet (31-5-5) and the lower piston chamber inlet (31-5-6) are simultaneously communicated with the spent power fluid cavity (31-5-2); when the reversing valve (31-6) is positioned at the upper limit point, the lower piston chamber inlet (31-5-6) is communicated with the power fluid cavity (31-5-1) through the reversing port (31-6-1), and the spent power fluid outlet (31-5-5) and the upper piston chamber inlet (31-5-4) are simultaneously communicated with the spent power fluid cavity (31-5-2);
the bottom of the reversing cavity is tightly attached to the hollow connecting rod (31-4) and is provided with a valve core (31-5-7) in an upward extending mode; the lower part of the reversing valve (31-6) is inserted between the valve core (31-5-7) and the reversing nipple (31-5); a pressure transmission hole (31-5-8) is arranged between the bottom of the valve core (31-5-7) and the reversing nipple (31-5); the middle part of the side surface of the valve core (31-5-7) facing the hollow connecting rod (31-4) is provided with a diversion trench (31-5-7-1); the reversing nipple (31-5) is provided with a pressure relief hole (31-5-9) communicated with the outer cylinder circulation hole (26) below the valve core (31-5-7); an upper reversing groove (31-4-1) is formed in the side wall of the upper part of the hollow connecting rod (31-4), and a pair of adjacent lower reversing grooves (31-4-2) are formed in the lower part of the hollow connecting rod;
when the hollow connecting rod (31-4) is positioned at the position of the lower limit point, the upper reversing groove (31-4-1) is communicated with the pressure relief hole (31-5-9) and the pressure transmission hole (31-5-8) at the same time;
when the hollow connecting rod (31-4) is positioned at the upper limit point, the protruding part between the two lower reversing grooves (31-4-2) corresponds to the diversion groove (31-5-7-1), so that the pressure transmission hole (31-5-8) is communicated with the power liquid cavity (31-5-1).
6. A downhole drainage testing system comprising a downhole pump assembly according to any one of claims 1 to 5, a power fluid circulation system (40) and a formation fluid metering system; the power fluid circulation system (40) comprises a water injection pump (41) for providing power fluid into the hollow sucker rod (32), and a power fluid storage tank (42) communicated with the annular cavity between the sleeve (10) and the oil pipe (22); the stratum fluid metering system comprises a stratum fluid storage tank (51) communicated with the annular cavity between the hollow sucker rod (32) and the oil pipe (22); the water injection pump (41) pumps the power fluid from the power fluid storage tank (42).
7. A downhole drainage testing system according to claim 6, wherein a heating device is arranged between the power fluid reservoir (42) and the water injection pump (41).
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| CN201810395782.1A CN108590631B (en) | 2018-04-27 | 2018-04-27 | Underground pump unit and underground liquid discharge testing system |
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| CN201810395782.1A CN108590631B (en) | 2018-04-27 | 2018-04-27 | Underground pump unit and underground liquid discharge testing system |
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| CN109209309B (en) * | 2018-10-29 | 2021-03-02 | 中国石油集团渤海钻探工程有限公司 | Closed-cycle hydraulic drainage test process system |
| CN110017138A (en) * | 2019-05-08 | 2019-07-16 | 中国科学院武汉岩土力学研究所 | Air water multilayer sampling method and device in a kind of drilling |
| CN115234227B (en) * | 2022-09-21 | 2022-12-13 | 廊坊市华海石油技术开发有限公司 | Liquid drainage pipe column structure and stratum testing method based on same |
| CN115387761A (en) * | 2022-10-31 | 2022-11-25 | 廊坊市华海石油技术开发有限公司 | Oil-gas well liquid discharge pipe column device with high lift and deep pumping liquid discharge method |
| CN115749701B (en) * | 2022-12-06 | 2023-11-17 | 山东威马泵业股份有限公司 | Blowout prevention pipe type oil pump |
| CN117569778B (en) * | 2024-01-15 | 2024-04-05 | 东营垣发石油科技有限公司 | Projectile perforation and sand-carrying oil extraction integrated tubular column and process |
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