CN115110924A - Time-sharing and quantity-controlling injection-production huff-and-puff development method suitable for shale oil reservoir - Google Patents
Time-sharing and quantity-controlling injection-production huff-and-puff development method suitable for shale oil reservoir Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 76
- 238000011161 development Methods 0.000 title claims abstract description 37
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 34
- 239000003079 shale oil Substances 0.000 title claims abstract description 22
- 238000002347 injection Methods 0.000 claims abstract description 126
- 239000007924 injection Substances 0.000 claims abstract description 126
- 239000007788 liquid Substances 0.000 claims abstract description 47
- 239000010779 crude oil Substances 0.000 claims abstract description 15
- 238000002791 soaking Methods 0.000 claims abstract description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 36
- 230000008569 process Effects 0.000 claims description 22
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 10
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 6
- 239000001569 carbon dioxide Substances 0.000 claims description 5
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 5
- 230000035699 permeability Effects 0.000 claims description 4
- 239000007864 aqueous solution Substances 0.000 claims description 3
- 238000012544 monitoring process Methods 0.000 claims description 3
- 229920006395 saturated elastomer Polymers 0.000 claims description 2
- 229910000029 sodium carbonate Inorganic materials 0.000 claims description 2
- 238000009991 scouring Methods 0.000 abstract description 4
- 239000007791 liquid phase Substances 0.000 abstract description 2
- 239000003921 oil Substances 0.000 description 18
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- 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
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- 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
- E21B43/122—Gas lift
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- 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
- E21B43/164—Injecting CO2 or carbonated water
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- 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
- E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
- E21B43/168—Injecting a gaseous medium
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- 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
- E21B43/20—Displacing by water
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Abstract
The invention provides a time-sharing and quantity-controlling injection and production throughput development method suitable for a shale oil reservoir, which utilizes a time-sharing and quantity-controlling injection and production throughput development device, wherein the time-sharing and quantity-controlling injection and production throughput development device comprises an injection pump, a plurality of stand pipes and a plurality of collecting tanks; the method comprises the following steps: (1) injecting gas into the injection well; (2) after the gas injection is finished, starting a liquid injection pump and injecting liquid into the injection well through a series passage formed by the plurality of vertical pipes; (3) after soaking for a period of time, enabling the injection liquid to enter a collecting tank through an output port of a wellhead device and collecting crude oil; (4) and (5) repeating the steps (2) to (3) to repeatedly drain and refill the liquid. The method provided by the invention adopts the principle of improving the micro-distance scouring times and carrying crude oil with liquid phase assistance, realizes time-sharing and quantity-controlling injection and production, improves the adoption efficiency of the existing huff-puff development mode, and lays a foundation for the popularization and application of the gas injection huff-puff development mode.
Description
Technical Field
The invention relates to a time-sharing and quantity-controlling injection-production huff-and-puff development method suitable for a shale oil reservoir, and belongs to the technical field of oil field development.
Background
Because the shale oil reservoir has extremely high seepage resistance due to extremely small pores, the shale oil reservoir is difficult to be injected with a medium to supplement energy for the shale oil reservoir; the shale oil reservoir is usually exploited by natural energy or by natural energy exploitation after fracturing, but the exploitation method is very low in recovery efficiency.
Because gas has the characteristics of low seepage resistance, fast formation energy supplement and the like, the gas injection technology is more and more concerned about being applied to ultra-low permeability/shale oil reservoirs. Because the permeability of a shale oil reservoir is usually in the level of 0.1mD and even less than 0.1mD, a displacement mode cannot be implemented, and a gas injection huff-puff development mode is mainly adopted at present to improve the oil extraction effect.
The huff and puff development mode requires that gas is continuously injected into a stratum (the swallow process), and the gas enters small pores as much as possible in a well-closing pressure-building mode, so that a gas medium is fully contacted and exchanged with crude oil; the crude oil production is then carried along by the rapid venting of the gas ("spitting" process). One process of swallowing and spitting becomes a throughput cycle, and after 4 cycles, the output effect is obviously reduced.
However, the throughput development method currently used also has many disadvantages, such as: the huff and puff development method of the hypotonic/shale oil reservoir generally uses carbon dioxide gas, and the exhaust gas carries part of crude oil production; compared with liquid, the crude oil carried by unit volume of gas is far lower than that of liquid;
in a gas swept area in a throughput period, gas flows in and out twice and is flushed, and the displacement efficiency is low.
Therefore, providing a time-sharing and quantity-controlling injection-production throughput development method suitable for shale oil reservoirs has become a technical problem which needs to be solved urgently in the field.
Disclosure of Invention
In order to solve the defects and shortcomings, the invention aims to provide a time-sharing control injection-production throughput development method suitable for shale oil reservoirs.
In order to achieve the aim, the invention provides a time-sharing and quantity-control injection and production throughput development method suitable for a shale oil reservoir, wherein the method utilizes a time-sharing and quantity-control injection and production throughput development device which comprises an injection pump, a plurality of vertical pipes and a plurality of collecting tanks;
the top ends or the bottom ends of two adjacent stand pipes are alternately connected in series through bent pipes, so that a plurality of stand pipes form a series-connected passage;
a plurality of collecting tanks are connected in series;
the outlet of the injection pump is connected with the inlet end of the passage through a pipeline, and the outlet end of the passage is detachably connected with the injection port of the injection well wellhead device through a pipeline;
an output port of the injection well wellhead device is connected with an inlet of a first collecting tank in a plurality of collecting tanks which are arranged in series through a pipeline, and an outlet of the last collecting tank is connected with an inlet of the injection pump through a pipeline;
the method comprises the following steps:
(1) injecting gas into the injection well;
(2) after the gas injection is finished, starting a liquid injection pump and injecting liquid into the injection well through a series passage formed by the plurality of vertical pipes;
(3) after soaking for a period of time, enabling the injection liquid to enter a collecting tank through an output port of a wellhead device and collecting crude oil;
(4) and (5) repeating the steps (2) to (3) to repeatedly drain and refill the liquid.
In a specific embodiment of the above method, the injecting gas includes injecting carbon dioxide gas.
As a specific embodiment of the above method of the present invention, the injection liquid includes injection water or a saturated aqueous sodium carbonate solution.
Wherein, the use of saturated sodium carbonate aqueous solution can reduce the CO injection during water injection 2 And (4) dissolving and absorbing.
As a specific embodiment of the above method of the present invention, wherein the step (2) comprises: monitoring the liquid levels in the vertical pipes in real time in the liquid injection process, and judging that the liquid injection process is stable if the liquid injection pump continuously works for more than 10min and a small amount of gas exists in the vertical pipe closest to the injection well;
if the gas in the vertical pipe is too much and the gas is close to the liquid injection pump, the liquid injection is stopped, the air release valve is opened to exhaust the gas, and then the liquid injection pump is opened to continue the liquid injection.
Wherein, the technicians in the field can routinely judge the amount of gas in the vertical pipe according to the actual situation on site. If the height of the gas column in the riser closest to the injection well is less than 2m as in actual production on site, then it can be judged that there is a small amount of gas in the riser.
In one embodiment of the above method of the present invention, the permeability of the shale oil reservoir is less than 0.1 mD.
As a specific embodiment of the above method of the present invention, a plurality of liquid level meters are respectively installed in the vertical pipes. The liquid level meter can be used for judging the position of gas entering the vertical pipe, if the gas in the vertical pipe is too much and the gas is close to the liquid injection pump, the inlet valve can be closed and the air release valve can be opened to discharge the gas, and after the water level in the vertical pipe is stable, the inlet valve is opened.
In a specific embodiment of the above method of the present invention, the air release valve is installed on the elbow pipe connected to the top ends of two adjacent vertical pipes in series, and the elbow pipe is the elbow pipe closest to the side of the priming pump.
In a specific embodiment of the above method of the present invention, the inner diameter of the plurality of risers is not less than 50 mm.
In the invention, in the process of supplementing injected water after gas injection, internal high-pressure gas easily reversely enters a shaft and even a vertical pipe. In order to prevent the gas from entering the liquid injection pump to cause failure, the vertical pipe is favorable for uniformly applying pressure to the gas so that the gas pushes the water in the vertical pipe to the liquid injection pump, and the effect of stopping the gas is achieved.
In an embodiment of the above method of the present invention, the number of the collection tanks is at least two.
As a specific embodiment of the above method of the present invention, wherein the collection tank is provided with an agitator.
In the invention, the used collection tanks are liquid storage tanks or transport tanks with stirrers, the number of the collection tanks is at least two, and the total amount requirement of single injection is met. The stirrer is used for discharging a certain amount of gas dissolved in the liquid, and the stirring effect can accelerate the release of the gas. In the operation process, the collecting tank close to the shaft receives the discharged fluid, the fluid is greatly disturbed in the tank and then smoothly flows into a subsequent collecting tank, the disturbance is reduced, the water phase is placed at the bottom, and the liquid injection pump takes water from the position to inject the water and circularly injects the water into the well.
In the present invention, a schematic diagram of a shaft structure of an injection well (water injection well, gas injection well) for gas injection throughput is shown in fig. 1, and as can be seen from fig. 1, the shaft comprises a casing 7 and a wellhead device 4, wherein a gas injection pipeline 8 and a packer 9 are arranged in the casing 7, and the wellhead device 4 is provided with an injection port 5 and a production port 6; because carbon dioxide has special reasons such as corrosivity, the pit shaft tubular column is mostly made of corrosion-resistant and high-pressure-resistant materials.
In the invention, the thickness of a shale oil reservoir is H, the temperature is T, and the pressure (bottom hole) is P. The oil deposit rock and the pore are uniform in each direction, and no boundary exists under the condition of single well injection. Setting the gas injection quantity of a conventional throughput method as Vg-in; by adopting the time-sharing and quantity-controlling injection-production throughput development method provided by the invention, the subsequent injection water is Vw-in.
The conventional throughput method is implemented by the following processes: injecting gas along the injection port, then holding pressure, and discharging gas from the output port. The gas is distributed radially in the reservoir, centered on the well, as shown in FIGS. 2 a-2 b, where the injection rate is Vg-inThe gas boundary radius is Rg1 and the pressure is P. During injection, the gas front moves from the well center to the boundary; when the bottom hole pressure is reduced from P to Pout during discharge, the gas reversely migrates a certain distance in the pores of the reservoir under the drive of the pressure difference, namely scouring 1 time, and the oil displacement effect is shown in fig. 3a and 3b, wherein fig. 3a shows the gas injection process and the gas (CO) is shown in fig. 3b 2 ) Carrying to the deep part of the oil reservoir along the pore canal; FIG. 3b shows the exhaust process, gas (CO) 2 ) Carrying and transporting crude oil from the oil reservoir along the pore canal to produce. From FIGS. 3a and 3b, it can be seen that the crude oil and CO are stewed 2 The dissolution and the component exchange process are carried out to a certain degree, and the physical properties (color) of the crude oil are slightly changed. The portion of the oil film previously adsorbed on the rock wall is stripped off, this portion (Qfr) contributing to enhanced recovery; but also in the reverse direction, a small fraction of the already free oil droplets is reabsorbed by the rock wall, which fraction (Qad) reduces the recovery.
The time-sharing and quantity-controlling injection-production huff-and-puff development method applicable to shale oil reservoirs adopts an implementation process of supplementing water injection after gas injection, namely injecting a certain amount of water into an injection well after gas injection. At this time, the gas boundary radius is represented by R g 1 is increased to R g 2，R g 2-R g 1 ═ d, pressure P inw Not less than P; boundary radius of water is R inw 1, see fig. 4a and 4 b.
Different from the conventional method, the method provided by the invention also carries out repeated water drainage and water re-injection after the soaking, so that the injected water repeatedly applies pressure change to the injected gas. As can be seen in FIGS. 4a and 4b, the water front (gas back boundary) is at 0-R inw 1, change; gas front boundary at R g 1-R g 2, change; bottom hole pressure in P inw -change between Pout, the number of changes being the number of flushes. The effect after multiple flushes is schematically shown in FIG. 3c, and it can be seen from FIG. 3c that most of the oil film previously adsorbed on the rock wall is stripped off, i.e., Q fr A significant increase; meanwhile, the repeated flow also greatly reduces the probability that the oil drops in the free state are adsorbed by the rock wall again, namely Q ad Obviously reduces the oil recovery rate and greatly improves the oil recovery rate.
Compared with the prior art, the technical scheme of the invention can achieve the following effects:
1. the time-sharing and quantity-controlling injection-production huff-and-puff development method provided by the invention utilizes liquid (such as water) to perform multiple variable pressure driving and reverse movement, so that the condition of low oil extraction efficiency of the conventional gas injection huff-and-puff method is improved;
2. the method provided by the invention improves the scouring times of gas in pore micro-distance, enhances the component exchange effect and has the potential of improving the oil displacement efficiency;
in conclusion, the method provided by the invention realizes time-sharing and quantity-controlling injection and production by adopting the principle of improving the micro-distance scouring times and carrying crude oil by liquid phase assistance, improves the adoption efficiency of the existing huff-puff development mode, and lays a foundation for popularization and application of the gas injection huff-puff development mode.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings required to be used in the description of the embodiments are briefly introduced below, and it is obvious that the drawings in the following description are some embodiments of the present invention, and it is obvious for those skilled in the art that other drawings can be obtained according to the drawings without creative efforts.
FIG. 1 is a schematic representation of the wellbore configuration of a gas injection huff and puff injection well of the present invention.
FIG. 2a is a schematic (top view) of the gas distribution within a reservoir in a conventional gas injection throughput process.
FIG. 2b is a schematic (cross-sectional view) of the gas distribution within the reservoir in a conventional gas injection throughput method.
FIG. 3a is a schematic diagram of the oil displacement effect (gas injection process) of the conventional gas injection throughput method.
FIG. 3b is a schematic diagram of the flooding effect (venting process) of the conventional gas injection huff-and-puff method.
Fig. 3c is a schematic view of the oil displacement effect of the time-sharing and quantity-controlling injection-production throughput development method provided by the invention.
Fig. 4a is a schematic diagram (top view) illustrating the distribution of gas and water in the oil reservoir in the time-sharing and quantity-controlling injection-production throughput development method provided by the present invention.
Fig. 4b is a schematic diagram (cross-sectional view) illustrating the distribution of gas and water in the oil reservoir in the time-sharing and quantity-controlling injection-production throughput development method provided by the present invention.
Fig. 5 is a schematic structural diagram of a time-sharing and quantity-controlling injection-production throughput development device according to an embodiment of the present invention.
Fig. 6 is a schematic structural view of the conventional injection and production throughput development apparatus provided in comparative example 1.
The main reference numbers indicate:
1-a first riser;
2-a second riser;
3-a third riser;
4-a wellhead assembly;
5-injection port;
6-production outlet;
7-a sleeve;
8-gas injection line;
9-a packer;
10-a liquid level meter;
11-a deflation valve;
12-a liquid injection pump;
13-an inlet valve;
14-a first outlet valve;
15-a second outlet valve;
16-collection tank.
Detailed Description
In order to clearly understand the technical features, objects and advantages of the present invention, the following detailed description of the technical solutions of the present invention will be made with reference to the following specific examples, which should not be construed as limiting the implementable scope of the present invention.
It should be noted that the term "comprises/comprising" and any variations thereof in the description and claims of this invention and the above-described drawings is intended to cover non-exclusive inclusions, such that a process, method, system, article, or apparatus that comprises a list of steps or elements is not necessarily limited to those steps or elements expressly listed, but may include other steps or elements not expressly listed or inherent to such process, method, article, or apparatus.
In the present invention, the terms "top", "bottom", and the like indicate orientations or positional relationships based on the orientations or positional relationships shown in the drawings. These terms are used primarily to better describe the invention and its embodiments and are not intended to limit the indicated devices, elements or components to a particular orientation or to be constructed and operated in a particular orientation.
Moreover, some of the above terms may be used to indicate other meanings besides the orientation or positional relationship, for example, the term "on" may also be used to indicate some kind of attachment or connection relationship in some cases. The specific meanings of these terms in the present invention can be understood by those skilled in the art as appropriate.
Furthermore, the terms "disposed" and "connected" should be interpreted broadly. For example, "connected" may be a fixed connection, a detachable connection, or a unitary construction; can be a mechanical connection, or an electrical connection; may be directly connected, or indirectly connected through intervening media, or may be in internal communication between two devices, elements or components. The specific meanings of the above terms in the present invention can be understood according to specific situations by those of ordinary skill in the art.
Example 1
The present embodiment provides a time-sharing control injection-production throughput development apparatus, a schematic structural diagram of which is shown in fig. 5, and as can be seen from fig. 5, the apparatus includes: a priming pump 12, a first riser pipe 1, a second riser pipe 2, a third riser pipe 3 and seven catchment tanks 16 (only one catchment tank is shown in the figure);
the top ends or the bottom ends of two adjacent stand pipes are alternately connected in series through bent pipes, so that a first stand pipe 1, a second stand pipe 2 and a third stand pipe 3 form a serial passage;
seven of the collection tanks 16 are connected in series;
the outlet of the injection pump 12 is connected with the inlet end of the passage through a pipeline, and the outlet end of the passage is detachably connected with the injection port of the injection well wellhead device through a pipeline;
the output port of the injection well wellhead is connected by tubing to the inlet of the first of seven serially arranged holding tanks 16, and the outlet of the last holding tank is connected by tubing to the inlet of the injection pump 12.
In this embodiment, level gauges 10 are installed in the first vertical pipe 1, the second vertical pipe 2, and the third vertical pipe 3, respectively.
In this embodiment, the air release valve 11 is installed on the elbow pipe at the top end of two adjacent vertical pipes connected in series, and the elbow pipe is the elbow pipe closest to the side of the liquid injection pump 12.
In this embodiment, the inner diameters of the first riser 1, the second riser 2, and the third riser 3 are not less than 50 mm.
In this embodiment, the collection tank 16 is provided with a stirrer.
In this embodiment, the wellbore of the injection well comprises a casing 7 and a wellhead device, wherein the casing 7 is internally provided with an injection pipeline 8 and a packer 9, and the wellhead device is provided with an injection port and a production port; the inlet is provided with an inlet valve 13, and the outlet is provided with a first outlet valve 14 and a second outlet valve 15.
Due to the special reasons that carbon dioxide is corrosive, the wellbore tubular column used in the embodiment is made of corrosion-resistant and high-pressure-resistant materials.
Example 2
The embodiment provides a time-sharing and quantity-controlling injection-production throughput development method suitable for a shale oil reservoir, which is realized by using the device provided by the embodiment 1, and the method comprises the following specific steps:
in this example, taking the development of a certain shale oil block huff and puff as an example, 100m of injection water (or saturated sodium carbonate aqueous solution) is designed 3 (ii) a The seven collection tanks used in this example each have a volume of 20m 3 The liquid injection pump is a high-pressure water injection pump with the pressure of 35 MPa;
1) closing an inlet valve after injecting 1000 tons of gas;
2) prepare 120m in seven collection tanks 3 Is injected with water. And (4) starting a water injection pump, and slowly opening an inlet valve when the pressure reaches 31 MPa. Monitoring by a liquid level meterIf the water injection pump works continuously for more than 10min and the liquid level meter displays that only a small amount of gas exists in the first vertical pipe, the water injection process is judged to be basically stable, and the accumulated water injection is 100m 3 The pump can be stopped, and the inlet valve is closed; if the gas in the vertical pipe is too much and approaches the water injection pump, the inlet valve and the main valve thereof are closed, the air release valve, the inlet valve and the second outlet valve on the vertical pipe are opened, and the air release valve, the inlet valve and the second outlet valve are closed after the air is exhausted. Then, a water injection pump is started, after the pressure is held to be 31MPa, an inlet valve is slowly opened, and the steps are repeated to inject water;
3) the amount of water injected is 100m 3 After the water injection process, closing the water injection pump and the inlet valve, and after closing for 1 day, opening the first outlet valve to quickly drain the injected water back into the collection tank;
4) and after the crude oil is collected, starting the next period, and repeating the steps 2) to 3) until the design repetition times or the designed pressure drop value is completed.
5) And executing a 'spitting' process including gas backflow, collecting crude oil, and finishing the gas injection design.
Comparative example 1
This comparative example provides a conventional injection-production throughput development device, a schematic structural diagram of which is shown in fig. 6, and as can be seen from fig. 6, the device includes: a holding tank 16 and an injection well wellbore;
the shaft of the injection well comprises a casing 7 and a wellhead device, wherein an injection pipeline 8 and a packer 9 are arranged in the casing 7, and the wellhead device is provided with an injection port and an output port; the inlet is provided with an inlet valve 13 and the outlet is provided with a second outlet valve 15.
Comparative example 2
The comparative example provides a conventional injection-production huff-and-puff development method which is realized by using the conventional injection-production huff-and-puff development device provided by the comparative example 1, takes the huff-and-puff development of a certain shale oil block as an example, and injects CO daily 2 100 tons of gas, 1000 tons of CO are injected into the vertical injection well through the injection hole 2 A gas; after the normal soaking well is carried out for 1 month (the pressure is reduced to 5MPa from 30MPa after the injection from the well mouth), the well mouth is vented and exhausted, and the crude oil is collected。
The above description is only exemplary of the invention and should not be taken as limiting the scope of the invention, so that the invention is intended to cover all modifications and equivalents of the embodiments described herein. In addition, the technical features and the technical inventions of the present invention, the technical features and the technical inventions, and the technical inventions can be freely combined and used.
Claims (10)
1. A time-sharing and quantity-controlling injection-production throughput development method suitable for shale oil reservoirs is characterized in that a time-sharing and quantity-controlling injection-production throughput development device is utilized, and the time-sharing and quantity-controlling injection-production throughput development device comprises an injection pump, a plurality of vertical pipes and a plurality of collecting tanks;
the top ends or the bottom ends of two adjacent stand pipes are alternately connected in series through bent pipes, so that a plurality of stand pipes form a series-connected passage;
a plurality of the collecting tanks are connected in series;
the outlet of the injection pump is connected with the inlet end of the passage through a pipeline, and the outlet end of the passage is detachably connected with the injection port of the injection well wellhead device through a pipeline;
an output port of the injection well wellhead device is connected with an inlet of a first collecting tank in a plurality of collecting tanks which are arranged in series through a pipeline, and an outlet of the last collecting tank is connected with an inlet of the injection pump through a pipeline;
the method comprises the following steps:
(1) injecting gas into the injection well;
(2) after the gas injection is finished, starting a liquid injection pump and injecting liquid into the injection well through a series passage formed by the plurality of vertical pipes;
(3) after soaking for a period of time, enabling the injection liquid to enter a collecting tank through an output port of a wellhead device and collecting crude oil;
(4) and (5) repeating the steps (2) to (3) to repeatedly drain and refill the liquid.
2. The method of claim 1, wherein the injecting gas comprises injecting carbon dioxide gas.
3. The method according to claim 1 or 2, wherein the injection comprises injecting water or a saturated aqueous solution of sodium carbonate.
4. The method of claim 1 or 2, wherein step (2) comprises: monitoring the liquid levels in a plurality of vertical pipes in real time in the liquid injection process, and judging that the liquid injection process is stable if a liquid injection pump continuously works for more than 10min and a small amount of gas exists in the vertical pipe closest to an injection well;
if the gas in the vertical pipe is too much and the gas is close to the liquid injection pump, the liquid injection is stopped, the air release valve is opened to exhaust the gas, and then the liquid injection pump is opened to continue the liquid injection.
5. The method of claim 1 or 2, wherein the permeability of the shale oil reservoir is less than 0.1 mD.
6. Method according to claim 1 or 2, characterized in that several of said risers have level gauges installed therein, respectively.
7. The method according to claim 1 or 2, wherein the air relief valve is arranged on the elbow at the top end of two adjacent vertical pipes in series, and the elbow is the elbow closest to one side of the liquid injection pump.
8. A method according to claim 1 or 2, wherein the number of risers has an internal diameter of not less than 50 mm.
9. The method of claim 1 or 2, wherein there are at least two collection tanks.
10. A method according to claim 1 or 2, characterized in that the collecting tank is provided with a stirrer.
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