CN116291342B - High miscible pressure reservoir CO2Mixed phase driving device and method - Google Patents
High miscible pressure reservoir CO2Mixed phase driving device and method Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 23
- 238000004146 energy storage Methods 0.000 claims abstract description 105
- 238000002347 injection Methods 0.000 claims abstract description 69
- 239000007924 injection Substances 0.000 claims abstract description 69
- 239000000498 cooling water Substances 0.000 claims abstract description 32
- 239000007788 liquid Substances 0.000 claims abstract description 16
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 15
- 230000015572 biosynthetic process Effects 0.000 claims description 11
- 239000011435 rock Substances 0.000 claims description 9
- 238000007789 sealing Methods 0.000 claims description 9
- 238000001125 extrusion Methods 0.000 claims description 7
- 239000000110 cooling liquid Substances 0.000 claims description 6
- 230000002093 peripheral effect Effects 0.000 claims description 4
- 238000010008 shearing Methods 0.000 claims description 4
- 230000009471 action Effects 0.000 claims description 2
- 241000237858 Gastropoda Species 0.000 claims 1
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 abstract description 43
- 229910002092 carbon dioxide Inorganic materials 0.000 abstract description 22
- 239000001569 carbon dioxide Substances 0.000 abstract description 21
- 238000011084 recovery Methods 0.000 abstract description 15
- 230000008569 process Effects 0.000 abstract description 5
- 239000003921 oil Substances 0.000 description 30
- 239000012071 phase Substances 0.000 description 29
- 238000006073 displacement reaction Methods 0.000 description 14
- 239000010779 crude oil Substances 0.000 description 12
- 229930195733 hydrocarbon Natural products 0.000 description 7
- 150000002430 hydrocarbons Chemical class 0.000 description 7
- 239000004215 Carbon black (E152) Substances 0.000 description 6
- 238000005516 engineering process Methods 0.000 description 5
- 239000012530 fluid Substances 0.000 description 5
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- 239000000203 mixture Substances 0.000 description 4
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- 230000008021 deposition Effects 0.000 description 3
- 238000000605 extraction Methods 0.000 description 3
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- 230000009467 reduction Effects 0.000 description 3
- 239000007790 solid phase Substances 0.000 description 3
- 239000012752 auxiliary agent Substances 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 238000000926 separation method Methods 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- JNYAEWCLZODPBN-JGWLITMVSA-N (2r,3r,4s)-2-[(1r)-1,2-dihydroxyethyl]oxolane-3,4-diol Chemical compound OC[C@@H](O)[C@H]1OC[C@H](O)[C@H]1O JNYAEWCLZODPBN-JGWLITMVSA-N 0.000 description 1
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
- 239000004721 Polyphenylene oxide Substances 0.000 description 1
- 229920006322 acrylamide copolymer Polymers 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 150000007942 carboxylates Chemical class 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 230000005465 channeling Effects 0.000 description 1
- 239000013043 chemical agent Substances 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000011549 displacement method Methods 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 229920000570 polyether Polymers 0.000 description 1
- 235000013855 polyvinylpyrrolidone Nutrition 0.000 description 1
- 229920000036 polyvinylpyrrolidone Polymers 0.000 description 1
- 239000001267 polyvinylpyrrolidone Substances 0.000 description 1
- 230000009919 sequestration Effects 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
- E21B43/164—Injecting CO2 or carbonated water
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- Chemical & Material Sciences (AREA)
- Physics & Mathematics (AREA)
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Abstract
The invention discloses a CO 2 mixed phase driving device for a high mixed phase pressure oil reservoir, which comprises the following components: the wellhead device is arranged at the wellhead of the injection well; the injection device is arranged in the injection well and is positioned at the reservoir; the wellhead assembly includes: a supercritical CO 2 inlet end, through which supercritical CO 2 inlet end supercritical CO 2 is injected into the reservoir as a pre-drive assisting slug; a cooling water inlet end and a liquid CO 2 inlet end, through which water and liquid CO 2 are alternately injected into the reservoir as a main slug; the injection device has an energy storage function. According to the invention, supercritical CO 2 is injected into the reservoir as a pre-drive assisting slug, supercritical CO 2 is used for energy storage and instant release to act on the reservoir, and the gap of the reservoir is increased by utilizing instant high-pressure impact to the reservoir. And in the alternate injection process of the water and the carbon dioxide segment, cooling water is injected to reduce the minimum mixed phase pressure of CO 2 in the oil-bearing stratum. Finally, the original fluidity is improved, and the minimum miscible pressure is reduced, so that the recovery ratio is improved.
Description
Technical Field
The application relates to the technical field of CO 2 oil extraction, in particular to a CO 2 miscible phase driving device and method for a high miscible phase pressure oil reservoir.
Background
At present, with the continuous development and progress of technology, the global warming phenomenon is becoming more and more severe. Carbon capture, CO 2 utilization and sequestration (CCUS) are one of the key technologies to cope with global climate change. Among them, CO 2 displacement of reservoir oil technology (CO 2enhanced oil recovery,CO2 -EOR) is one of the important means, can realize the sealing of CO 2 while improving the recovery ratio of crude oil, is commonly used for tertiary oil recovery.
The CO 2 displacement technique is divided into miscible and immiscible ones, the key to distinguish between the two being the minimum miscible pressure (minimum miscibility pressure, MMP). When the pressure is higher than MMP, the interface between CO 2 and crude oil disappears, the interfacial tension (INTERFACIAL TENSION, IFT) is zero, and the oil-gas two phases are miscible, so how to reduce the minimum miscible pressure of CO 2 and crude oil to be lower than the reservoir pressure is an important part of the CO 2 miscible flooding method.
Because of the crude oil composition and formation temperature factors of most of the oil fields in China, the carbon dioxide flooding miscible phase pressure is high at the original formation temperature, the carbon dioxide miscible phase flooding is difficult to realize, and the popularization and the application of the carbon dioxide flooding technology are restricted.
In recent years, many scholars at home and abroad have proposed surfactants to reduce the minimum miscible pressure of CO 2 and crude oil. For example, chinese patent CN111058816a provides a method for improving CO 2 miscible flooding recovery ratio, in the CO 2 miscible flooding process, a chemical agent capable of improving macroscopic apparent viscosity of the supercritical CO 2 miscible flooding system is added, so as to further improve the swept area of supercritical CO 2 and improve CO 2 miscible flooding recovery ratio of the hypotonic oil reservoir.
For example, chinese patent CN113881417a relates to a chemical composition containing sorbitan polyether carboxylate, a method for preparing the same and a method for reducing minimum miscible pressure of CO 2 flooding, wherein interfacial tension between CO 2 and crude oil is reduced by the chemical composition, thereby reducing minimum miscible pressure of both.
For example, chinese patent CN114876425A proposes a low permeability reservoir oil displacement method, where the driving aid is a mixture of polystyrene-acrylamide copolymer and polyvinylpyrrolidone in a mass ratio of (3:1) - (7:1), and the two are synergistic, so that gas channeling and viscous fingering during carbon dioxide oil displacement are effectively avoided, and thus the oil displacement effect of carbon dioxide is greatly improved.
Some scholars have also proposed reducing the miscible pressure by adding components such as liquefied gas or light hydrocarbons to carbon dioxide. For example, chinese patent CN114482944a proposes a method for implementing CO 2 miscible displacement by multi-stage contact separation in the pit, in which, by injecting CO 2 into an injection well, in displacement of a formation, the CO 2 displacement fluid is gradually enriched in light hydrocarbon components by contact extraction with crude oil, and enters a CO 2 crude oil separator of a production well for pressure reduction separation, the CO 2 displacement fluid enriched in light hydrocarbon components is continuously injected into the formation to implement multi-contact extraction with crude oil, and after the CO 2 displacement fluid circulates in the formation for many times, the CO 2 displacement fluid enriched in light hydrocarbon components reaches the condition of miscible phase with crude oil of the formation, thereby implementing CO 2 miscible displacement.
For example, journal articles "new method for reducing minimum miscible pressure of carbon dioxide flooding" (journal of Chongqing academy of science and technology (Nature science edition), 1 st stage: 78-51) propose a method for reducing minimum miscible pressure of CO 2 flooding, and the purpose of reducing minimum miscible pressure of CO 2 miscible flooding can be achieved by adding a certain proportion of liquefied gas into CO 2.
However, on the one hand, since the interfacial tension between crude oil and carbon dioxide is low, surfactant molecules are difficult to stably distribute between phases, and thus it is difficult to greatly reduce the miscible pressure by this method. On the other hand, the recovery difficulty of liquefied gas, light hydrocarbon and the like is high, and solid phase deposition is easy to occur.
Therefore, research on a CO 2 miscible-phase driving device and a method for a high miscible-phase pressure oil reservoir which can greatly reduce the miscible-phase pressure and does not generate solid-phase deposition is a technical problem to be solved in the field.
Disclosure of Invention
In order to solve the problems, the invention adopts the following technical scheme:
a CO 2 miscible flooding device for a high miscible pressure reservoir, comprising:
The wellhead device is arranged at the wellhead of the injection well;
the injection device is arranged in the injection well and is positioned at the reservoir;
wherein, wellhead assembly includes:
A supercritical CO 2 inlet end, through which supercritical CO 2 inlet end supercritical CO 2 is injected into the reservoir as a pre-drive assisting slug;
A cooling water inlet end and a liquid CO 2 inlet end, through which water and liquid CO 2 are alternately injected into the reservoir as a main slug;
wherein, the injection device has the energy storage effect.
Further, the injection device includes:
The side wall of the upper joint is provided with an injection hole;
The lower joint is fixedly arranged at the lower end of the upper joint;
The sliding sleeve is coaxially arranged in the upper joint, and the upper end surface of the sliding sleeve is higher than the injection hole;
the energy storage piece is fixedly arranged above the sliding sleeve, and the sliding sleeve and the energy storage piece can slide relative to the upper joint;
The energy storage reducing ring is partially positioned in the sliding sleeve and partially positioned in the lower joint;
under the action of a certain force, the energy storage reducing ring can be contracted to completely enter the sliding sleeve.
Further, the inner periphery of the energy storage reducing ring is positioned in the sliding sleeve, and the outer periphery of the energy storage reducing ring is positioned in the lower joint;
the energy storage reducing ring is a C-shaped ring body with an opening, and the energy storage reducing ring can be contracted by shearing force to seal the opening, so that a circular ring shape is formed.
Further, the section of the inner periphery is rectangular, the outer side of the sliding sleeve is also provided with an annular accommodating groove, the section of the annular accommodating groove is also rectangular, and the inner periphery is positioned in the annular accommodating groove;
The cross section of the outer periphery is of a frustum shape, the inner side wall of the lower joint is also provided with an annular extrusion groove, and the shape and the size of the cross section of the annular extrusion groove are matched with those of the cross section of the outer periphery.
Further, in the initial state, the inner side surface of the inner periphery of the energy storage reducing ring is in clearance fit with the side surface of the annular accommodating groove.
Further, the upper end of the sliding sleeve is provided with a plurality of first annular grooves, and first sealing rings are arranged in the first annular grooves;
the lower end of the sliding sleeve is provided with a plurality of second annular grooves, and second sealing rings are arranged in the second annular grooves.
Further, design parameters of the energy storage reducing ring are as follows:
Wherein Δr=r-r 1;
Wherein r is the inner diameter of the energy storage reducing ring in the initial state, and m; r 1 is the inner diameter of the energy storage reducing ring after deformation, m; θ is the angle of the opening, degrees; r is the outer diameter of the energy storage reducing ring in the initial state, and m; d is the height of the energy storage reducing ring, m; w is the length of the inclined plane in the axial direction of the energy storage reducing ring, and m; z is the length of the inclined plane in the radial direction of the energy storage reducing ring, and m; k is a pressure value corresponding to deformation of the energy storage reducing ring, and N;
wherein,
Wherein E is the elastic modulus of the energy storage reducing ring and N/m 2; μ is the poisson ratio of the energy storage reducing ring.
Further, the energy storage reducing ring is made of 42CrMo.
The method for miscible-phase driving of the high-miscible-phase pressure oil reservoir CO 2 by using the device for miscible-phase driving of the high-miscible-phase pressure oil reservoir CO 2 comprises the following steps:
s1, injecting a front slug:
Injecting supercritical CO 2 into the injection device through the inlet end of the supercritical CO 2, and releasing the supercritical CO 2 into the reservoir instantaneously when the supercritical CO 2 is pressurized to 7.5-8.5MPa in the injection device;
s2, injecting a main slug:
cooling water and liquid CO 2 are alternately injected into the reservoir as a primary slug through the cooling water inlet port and the liquid CO 2 inlet port.
Further, in S2, the injection amount of the cooling water is:
Cw＝35.3(1-φ)Cpr+35.3φ(SoCpo+SwCpw)
Wherein C w is the amount of cooling water required per 1 degree decrease in the reservoir, m 3; phi is the porosity of the rock; c pr is the heat capacity of the rock, J/(kg. Deg.C); s o is the oil saturation of the rock, kg/m 3;Cpo is the heat capacity of the oil, J/(kg. DEG C); s w is the water saturation of the formation, kg/m 3;Cpw is the heat capacity of the water, J/(kg DEG C).
The beneficial effects are that:
(1) And injecting supercritical CO 2 into the reservoir as a pre-drive assisting slug, wherein the supercritical CO 2 stores energy and instantaneously releases energy to act on the reservoir, and the gap of the reservoir is increased by utilizing instantaneous high-pressure impact on the reservoir. And in the alternate injection process of the water and the carbon dioxide segment, cooling water is injected to reduce the minimum mixed phase pressure of CO 2 in the oil-bearing stratum. Finally, the original fluidity is improved, and the minimum miscible pressure is reduced, so that the recovery ratio is improved.
(2) The energy storage piece divides the internal space of the injection device into two parts, supercritical CO 2 is injected into the space above the energy storage piece in the injection device, when the pressure exceeds the load of the energy storage reducing ring, the energy storage reducing ring is subjected to shrinkage deformation and fully enters the sliding sleeve, the sliding sleeve and the energy storage piece slide downwards and open the injection hole, the supercritical CO 2 for accumulating energy enters the reservoir through the injection hole, and the gap of the reservoir is increased by the impact of the supercritical CO 2 for accumulating energy, so that the displacement of carbon dioxide is facilitated.
(3) Through setting up energy storage reducing ring to and optimize energy storage reducing ring's shape, size and material attribute, each parameter can be according to the actual conditions, reasonable configuration, and can accurately set up the pressure value that the energy storage reducing ring takes place to warp and the design value coincidence.
(4) The calculation formula of the injection amount of the cooling water is provided, and the injection amount of the cooling water can be reasonably and accurately configured according to the actual working condition of the reservoir and the temperature required to be reduced, so that the minimum CO 2 mixed-phase pressure of the oil-bearing stratum is reduced, and the recovery ratio is improved.
Drawings
Various other advantages and benefits will become apparent to those of ordinary skill in the art upon reading the following detailed description of the preferred embodiments. The drawings are only for purposes of illustrating the preferred embodiments and are not to be construed as limiting the invention. Also, like reference numerals are used to designate like parts throughout the figures. In the drawings:
FIG. 1 is an overall diagram of a CO 2 miscible-phase drive for a high miscible-phase pressure reservoir;
FIG. 2 is an enlarged view of a portion of FIG. 1 at A;
FIG. 3 is a block diagram of the overall injection device;
FIG. 4 is an exploded view of the injection device;
FIG. 5 is a cross-sectional view of an injection device;
FIG. 6 is an enlarged view of a portion of FIG. 5 at B;
FIG. 7 is an enlarged view of a portion of FIG. 5 at C;
FIG. 8 is an overall construction diagram of an energy storage reducing ring;
FIG. 9 is a diagram showing a structure of the energy storage reducing ring in a contracted and closed state;
FIG. 10 is a top view of an initial state of the energy storage reducing ring;
FIG. 11 is a top view of the energy storage reducing ring in a contracted closed state;
FIG. 12 is a cross-sectional view of an energy storage reducing ring.
The wellhead 100, the supercritical CO 2 inlet end 110, the cooling water inlet end 120, the liquid CO 2 inlet end 130, the injection device 200, the upper joint 210, the injection hole 211, the lower joint 220, the annular extrusion groove 221, the sliding sleeve 230, the annular accommodating groove 231, the first annular groove 232, the second annular groove 233, the energy storage member 240, the energy storage reducing ring 250, the inner peripheral edge 251, the outer peripheral edge 252, the opening 253, the first sealing ring 260, the second sealing ring 270, and the injection well 300.
Detailed Description
Exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. While exemplary embodiments of the present disclosure are shown in the drawings, it should be understood that the present disclosure may be embodied in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the disclosure to those skilled in the art.
Referring to fig. 1-12, the present embodiment provides a CO 2 miscible flooding device for a high miscible pressure reservoir, comprising a wellhead 100 and an injection device 200.
The wellhead device 100 is arranged at the wellhead of the injection well 300 and is used for injecting a CO 2 and other auxiliary agents into the injection well 300; the injection device 200 is disposed within the injection well 300, and the injection device 200 is located at the reservoir for injecting a CO 2 or other CO-agent into the reservoir.
It is understood that carbon dioxide injection into an oil reservoir can enhance oil recovery in an oil field, and that mechanisms for carbon dioxide displacement include viscosity reduction, miscible effect, interfacial tension reduction, and the like. The miscible effect means that the two fluids can dissolve each other without an interface, and the interfacial tension is eliminated.
In order to reduce the miscible pressure of carbon dioxide flooding, most of the prior art reduces the miscible pressure by adding a surfactant to carbon dioxide, and some of the prior art reduces the miscible pressure by adding components such as liquefied gas or light hydrocarbon to carbon dioxide.
However, since the interfacial tension between crude oil and carbon dioxide is low, surfactant molecules are difficult to be stably distributed between phases, and thus it is difficult to greatly reduce the miscible pressure by this method. In addition, the recovery difficulty of liquefied gas, light hydrocarbon and the like is high, and solid phase deposition is easy to occur.
To eliminate the above problems, in the present embodiment, the wellhead 100 includes a supercritical CO 2 inlet port 110, a cooling water inlet port 120, and a liquid CO 2 inlet port 130. Wherein, supercritical CO 2 is injected into the reservoir as a pre-drive slug through the supercritical CO 2 inlet end 110 of the wellhead 100; water and liquid CO 2 are alternately injected into the reservoir as a primary slug through the cooling water inlet end 120 and the liquid CO 2 inlet end 130 of the wellhead 100.
The injector 200 also has an energy storage function, and supercritical CO 2 is injected into the injector 200 through the supercritical CO 2 inlet 110 of the wellhead 100, so that the injector 200 stores energy to a certain extent, and the supercritical CO 2 is instantaneously released to act on the reservoir.
Thus, the high miscible pressure reservoir CO 2 miscible driving apparatus according to the present embodiment operates:
Firstly, supercritical CO 2 is injected into the injection device 200 through the supercritical CO 2 inlet end 110, energy is stored to a certain extent in the injection device 200, the supercritical CO 2 is instantaneously released to act on a reservoir, and the gap of the reservoir is increased by utilizing instantaneous high pressure to impact the reservoir, so that carbon dioxide flooding is facilitated.
Cooling water and liquid CO 2 are then injected alternately into the reservoir as a primary slug through the cooling water inlet port 120 and the liquid CO 2 inlet port 130. The minimum CO 2 miscible pressure of the oil bearing formation is reduced by injecting cooling water into the formation, improving recovery.
By the arrangement, supercritical CO 2 is injected into the reservoir as a pre-drive assisting slug, supercritical CO 2 is stored energy and released instantaneously to act on the reservoir, and the gap of the reservoir is increased by utilizing instantaneous high-pressure impact on the reservoir. And in the alternate injection process of the water and the carbon dioxide segment, cooling water is injected to reduce the minimum mixed phase pressure of CO 2 in the oil-bearing stratum. Finally, the original fluidity is improved, and the minimum miscible pressure is reduced, so that the recovery ratio is improved.
Specifically, the injection device 200 includes an upper connector 210, a lower connector 220 fixedly disposed at the lower end of the upper connector 210, and an injection hole 211 formed on the sidewall of the upper connector 210; the upper joint 210 is coaxially provided with a sliding sleeve 230 and an energy storage piece 240 fixedly arranged above the sliding sleeve 230, and the sliding sleeve 230 and the energy storage piece 240 can slide relative to the upper joint 210; the upper end surface of the sliding sleeve 230 is higher than the injection hole 211 to close the injection hole 211.
And, be provided with energy storage reducing ring 250 between sliding sleeve 230 and the lower clutch 220, and energy storage reducing ring 250 is located the sliding sleeve 230 partially, and is located the lower clutch 220 partially, in order to guarantee that sliding sleeve 230 and lower clutch 220 are fixed relatively in the axial.
Under a certain force, the energy storage reducing ring 250 can be contracted and fully enter the sliding sleeve 230.
Therefore, the energy storage member 240 divides the inner space of the injection device 200 into two parts, supercritical CO 2 is injected into the space above the energy storage member 240 in the injection device 200, when the pressure exceeds the load of the energy storage reducing ring 250, the energy storage reducing ring 250 contracts and deforms, the sliding sleeve 230 and the energy storage member 240 slide downwards and open the injection hole 211, the supercritical CO 2 for accumulating energy enters the reservoir through the injection hole 211, and the gap of the reservoir is increased by the impact of the supercritical CO 2 for accumulating energy, so that the displacement of carbon dioxide is facilitated.
In this embodiment, the inner periphery 251 of the energy storage reducing ring 250 is located in the sliding sleeve 230, and the outer periphery 252 is located in the lower joint 220, so as to ensure that the sliding sleeve 230 and the lower joint 220 are relatively fixed in the axial direction; the energy-storage reducing ring 250 is a C-shaped ring body with an opening 253, and the energy-storage reducing ring 250 is contractible under shearing force to close the opening 253, thereby forming a circular ring shape.
Therefore, when the supercritical CO 2 energy storage pressurization does not reach the threshold value, the shear force value received by the energy storage reducing ring 250 also does not reach the deformation state, the inner periphery 251 of the energy storage reducing ring is positioned in the sliding sleeve 230, the outer periphery 252 is positioned in the lower joint 220, and the sliding sleeve 230 and the lower joint 220 are kept relatively fixed. When the supercritical CO 2 energy storage pressurization reaches the threshold value, the shearing force value received by the energy storage reducing ring 250 also reaches a deformation state, the energy storage reducing ring is contracted into a ring shape, the diameter is reduced, and the energy storage reducing ring 250 completely enters the sliding sleeve 230, so that the sliding sleeve 230 and the energy storage piece 240 can slide downwards and open the injection hole 211.
It will be appreciated that the shear force corresponding to deformation of the energy storage reducing ring 250 matches the threshold value of the pressure value of the supercritical CO 2 energy storage pressurized energy storage 240.
In this embodiment, the cross section of the inner periphery 251 is rectangular, the outer side of the sliding sleeve 230 is also provided with an annular accommodating groove 231, the cross section of the annular accommodating groove 231 is also rectangular, and the inner periphery 251 is positioned in the annular accommodating groove 231; the cross section of the outer periphery 252 is in a frustum shape, the inner side wall of the lower joint 220 is also provided with an annular extrusion groove 221, and the shape and the size of the cross section of the annular extrusion groove 221 are matched with those of the cross section of the outer periphery 252.
In this embodiment, in the initial state, the inner side surface of the inner peripheral edge 251 of the energy storage reducing ring 250 is in clearance fit with the side surface of the annular accommodating groove 231, so that the energy storage reducing ring 250 can completely enter the annular accommodating groove 231 when being contracted into an annular shape.
In this embodiment, the upper end of the sliding sleeve 230 is provided with a plurality of first annular grooves 232, and a first sealing ring 260 is installed in the first annular grooves 232; the lower end of the sliding sleeve 230 is provided with a plurality of second annular grooves 233, and a second sealing ring 270 is arranged in the second annular grooves 233. Thereby, it is ensured that the space above the energy storage member 240 remains sealed.
In this embodiment, the design parameters of the energy storage reducing ring 250 are:
Wherein Δr=r-r 1;
In the formula, as shown in fig. 10-12, r is the inner diameter of the energy storage reducing ring 250 in the initial state, and m; r1 is the inner diameter of the energy storage reducing ring 250 after deformation, m; θ is the angle of the opening 253, degrees; r is the outer diameter of the energy storage reducing ring 250 in the initial state, and m; d is the height of the energy storage reducing ring 250, m; w is the length of the inclined plane in the axial direction of the energy storage reducing ring 250, and m; z is the length of the inclined plane in the radial direction of the energy storage reducing ring 250, and m; k is a pressure value corresponding to deformation of the energy storage reducing ring 250, and N; λ and G are material parameters of the energy storage reducing ring 250.
Wherein,
Wherein E is the elastic modulus of the energy storage reducing ring 250, and N/m 2; μ is the poisson's ratio of the energy storage reducing ring 250.
It will be appreciated that during supercritical CO 2 storage, the storage slip ring 250 is subjected to a pressure value approximately equal to the pressure of the supercritical CO 2 on the storage member 240, ignoring the gravity of the slip sleeve 230 and the storage member 240. That is, the pressure value K corresponding to the deformation of the energy storage reducing ring 250 has a numerical relationship with the pressure of the supercritical CO 2 energy storage.
According to the CO 2 miscible-phase driving device for the high-miscible-phase pressure oil reservoir, through arranging the energy storage reducing ring 250 and optimizing the shape, the size and the material properties of the energy storage reducing ring 250, various parameters can be reasonably configured according to actual working conditions, and the pressure value corresponding to deformation of the energy storage reducing ring 250 can be accurately set to be identical with a design value.
In this embodiment, the energy storage reducing ring 250 is made of 42CrMo, and has an elastic modulus of 2.12e+11n/m2 and a poisson ratio of 0.28.
The embodiment also provides a method for CO 2 miscible-phase driving of a high miscible-phase pressure oil reservoir, which uses the device for CO 2 miscible-phase driving of the high miscible-phase pressure oil reservoir, and comprises the following steps:
s1, injecting a front slug:
injecting supercritical CO 2 into the injection device 200 through the supercritical CO 2 inlet port 110, wherein supercritical CO 2 is instantaneously released into the reservoir when the supercritical CO 2 is pressurized to 7.5-8.5MPa in the injection device 200;
s2, injecting a main slug:
cooling water and liquid CO 2 are alternately injected into the reservoir as a primary slug through the cooling water inlet end 120 and the liquid CO 2 inlet end 130.
By the arrangement, supercritical CO 2 is injected into the reservoir as a pre-drive assisting slug, supercritical CO 2 is stored energy and released instantaneously to act on the reservoir, and the gap of the reservoir is increased by utilizing instantaneous high-pressure impact on the reservoir. And in the alternate injection process of the water and the carbon dioxide segment, cooling water is injected to reduce the minimum mixed phase pressure of CO 2 in the oil-bearing stratum. Finally, the original fluidity is improved, and the minimum miscible pressure is reduced, so that the recovery ratio is improved.
In the present embodiment, in S2, the injection amount of the cooling water is:
Cw＝35.3(1-φ)Cpr+35.3φ(SoCpo+SwCpw)
Wherein C w is the amount of cooling water required per 1 degree decrease in the reservoir, m 3; phi is the porosity of the rock; c pr is the heat capacity of the rock, J/(kg. Deg.C); s o is the oil saturation of the rock, kg/m 3;Cpo is the heat capacity of the oil, J/(kg. DEG C); s w is the water saturation of the formation, kg/m 3;Cpw is the heat capacity of the water, J/(kg DEG C).
Through this setting, can be according to the actual operating mode of reservoir and the temperature that needs to reduce, the injection rate of cooling water is rationally, accurately disposed to reduce the minimum miscible pressure of CO 2 in oil-bearing stratum, improve the recovery ratio.
In this embodiment, the ratio of the injection amount of supercritical CO 2 in S1 to the injection amount of cooling water and liquid CO 2 in S2 is 1:2-3:4.
In this embodiment, in S2, the injection ratio of the cooling water to the liquid CO 2 is 3:2 to 2:1.
In the embodiment, the injection speed of the water solution of the auxiliary agent is 1-2m 3/h; the injection rate of cooling water and liquid CO 2 is 1-2m 3/h.
The present invention is not limited to the above-mentioned embodiments, and any changes or substitutions that can be easily understood by those skilled in the art within the technical scope of the present invention are intended to be included in the scope of the present invention. Therefore, the protection scope of the present invention shall be subject to the protection scope of the claims.
Claims (8)
1. A CO2 miscible flooding device for a high miscible pressure reservoir, comprising:
a wellhead assembly (100) disposed at a wellhead of an injection well (300);
an injection device (200) disposed within the injection well (300), and the injection device (200) is located at the reservoir;
characterized in that the wellhead (100) comprises:
a supercritical CO2 inlet end (110), wherein supercritical CO2 is injected into the reservoir through the supercritical CO2 inlet end (110) as a pre-drive assisting slug;
A cooling water inlet end (120) and a liquid CO2 inlet end (130), through the cooling water inlet end (120) and the liquid CO2 inlet end (130), water and liquid CO2 are alternately injected into the reservoir as main slugs;
wherein the injection device (200) has an energy storage function;
the injection device (200) comprises:
an upper joint (210) with a side wall provided with an injection hole (211);
the lower joint (220) is fixedly arranged at the lower end of the upper joint (210);
A sliding sleeve (230) coaxially arranged in the upper joint (210), the upper end surface of the sliding sleeve (230) being higher than the injection hole (211);
The energy storage piece (240) is fixedly arranged above the sliding sleeve (230), and the sliding sleeve (230) and the energy storage piece (240) can slide relative to the upper joint (210);
the energy storage reducing ring (250), the energy storage reducing ring (250) is partially positioned in the sliding sleeve (230), and partially positioned in the lower joint (220);
Under the action of a certain force, the energy storage reducing ring (250) can be contracted to completely enter the sliding sleeve (230);
The design parameters of the energy storage reducing ring (250) are as follows:
Wherein Δr=r-r 1;
wherein r is the inner diameter of the energy storage reducing ring (250) in the initial state, and m; r 1 is the inner diameter, m of the energy storage reducing ring (250) after deformation; θ is the angle of the opening (253), degrees; r is the outer diameter of the energy storage reducing ring (250) in the initial state, and m; d is the height of the energy storage reducing ring (250), m; w is the length of the inclined plane in the axial direction of the energy storage reducing ring (250), and m; z is the length of the inclined plane in the radial direction of the energy storage reducing ring (250), and m; k is a pressure value corresponding to deformation of the energy storage reducing ring (250), and N is a pressure value corresponding to deformation of the energy storage reducing ring;
wherein,
Wherein E is the elastic modulus of the energy storage reducing ring (250), and N/m 2; μ is the poisson ratio of the energy storage reducing ring (250).
2. The CO2 miscible flooding device for a high miscible pressure reservoir of claim 1, wherein: the inner periphery (251) of the energy storage reducing ring (250) is positioned in the sliding sleeve (230), and the outer periphery (252) is positioned in the lower joint (220);
the energy storage reducing ring (250) is a C-shaped annular body with an opening (253), and the energy storage reducing ring (250) can be contracted by shearing force to seal the opening (253) so as to form a circular ring shape.
3. The CO2 miscible flooding device for a high miscible pressure reservoir of claim 2, wherein: the section of the inner periphery (251) is rectangular, an annular accommodating groove (231) is further formed in the outer side of the sliding sleeve (230), the section of the annular accommodating groove (231) is also rectangular, and the inner periphery (251) is positioned in the annular accommodating groove (231);
the cross section of the outer periphery (252) is in a frustum shape, the inner side wall of the lower joint (220) is also provided with an annular extrusion groove (221), and the shape and the size of the cross section of the annular extrusion groove (221) are matched with those of the cross section of the outer periphery (252).
4. The CO2 miscible flooding device for a high miscible pressure reservoir of claim 2, wherein: in the initial state, the inner side surface of the inner peripheral edge (251) of the energy storage reducing ring (250) is in clearance fit with the side surface of the annular accommodating groove (231).
5. The CO2 miscible flooding device for a high miscible pressure reservoir of claim 1, wherein: the upper end of the sliding sleeve (230) is provided with a plurality of first annular grooves (232), and a first sealing ring (260) is arranged in each first annular groove (232);
The lower end of the sliding sleeve (230) is provided with a plurality of second annular grooves (233), and second sealing rings (270) are arranged in the second annular grooves (233).
6. The CO2 miscible flooding device for a high miscible pressure reservoir of claim 1, wherein: the energy storage reducing ring (250) is made of 42CrMo.
7. A CO2 miscible flooding method for a high miscible pressure reservoir using the CO2 miscible flooding apparatus for a high miscible pressure reservoir as claimed in any one of claims 1 to 6, comprising the steps of:
s1, injecting a front slug:
Injecting supercritical CO2 into the injection device (200) through the supercritical CO2 inlet end (110), wherein when the supercritical CO2 is pressurized to 7.5-8.5MPa in the injection device (200), the supercritical CO2 is instantaneously released into the reservoir;
s2, injecting a main slug:
cooling water and liquid CO2 are alternately injected into the reservoir as a primary slug through a cooling water inlet port (120) and a liquid CO2 inlet port (130).
8. The CO2 miscible flooding method for a high miscible pressure reservoir of claim 7, wherein: in S2, the injection amount of the cooling water is:
Cw＝35.3(1-φ)Cpr+35.3φ(SoCpo+SwCpw)
Wherein C w is the amount of cooling water required per 1 degree decrease in the reservoir, m 3; phi is the porosity of the rock; c pr is the heat capacity of the rock, J/(kg. Deg.C); s o is the oil saturation of the rock, kg/m 3;Cpo is the heat capacity of the oil, J/(kg. DEG C); s w is the water saturation of the formation, kg/m 3;Cpw is the heat capacity of the water, J/(kg DEG C).
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