WO2025000751A1 - 一种提高泡沫油冷采采收率的方法 - Google Patents

一种提高泡沫油冷采采收率的方法 Download PDF

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Publication number
WO2025000751A1
WO2025000751A1 PCT/CN2023/124947 CN2023124947W WO2025000751A1 WO 2025000751 A1 WO2025000751 A1 WO 2025000751A1 CN 2023124947 W CN2023124947 W CN 2023124947W WO 2025000751 A1 WO2025000751 A1 WO 2025000751A1
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oil
production
well
gas injection
gas
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English (en)
French (fr)
Inventor
张新元
武凡皓
陈东明
路达
黄元辉
丁怀宇
冯恩库
田淑芳
王超
李若懿
尹慧
陈璐
王思博
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Petrochina Co Ltd
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Petrochina Co Ltd
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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
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing 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
    • 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
    • G—PHYSICS
    • G06—COMPUTING OR CALCULATING; COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
    • G06F30/00—Computer-aided design [CAD]
    • G06F30/20—Design optimisation, verification or simulation
    • G—PHYSICS
    • G06—COMPUTING OR CALCULATING; COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q50/00—Information and communication technology [ICT] specially adapted for implementation of business processes of specific business sectors, e.g. utilities or tourism
    • G06Q50/02—Agriculture; Fishing; Forestry; Mining

Definitions

  • the invention relates to the technical field of petroleum exploitation, and in particular to a method for improving the recovery rate of foam oil cold recovery.
  • Foamy oil is a gas-containing crude oil, in which the gas phase is dispersed in the oil phase in the form of tiny bubbles. This special state makes the foamy oil highly fluid and has a high yield.
  • the dissolved gas in the foamy oil reservoir is released from the oil phase only when the formation pressure of the foamy oil reservoir drops below the bubble point pressure. Initially, the gas phase exists in the form of tiny bubbles. As time goes by and the pressure drops, the bubbles formed at different locations continue to grow and gradually gather to form a continuous gas phase.
  • the purpose of the embodiment of the present invention is to provide a method for improving the recovery rate of foam oil cold production, which increases the production in the cold production stage and achieves effective treatment of low-yield wells and long-stopped wells.
  • an embodiment of the present invention provides a method for improving the recovery rate of foam oil cold production, the method comprising the following steps:
  • oil production data of the oil well to be produced wherein the oil production data at least includes the gas-oil ratio of the oil well production, the original gas-oil ratio of the oil reservoir, the formation pressure of the oil reservoir, the pseudo-bubble point pressure, the oil production of the oil well, the peak production, and the proportion of foam in the oil sample;
  • screening oil wells with poor foam oil development effects according to the oil production data includes:
  • the oil well is an oil well with poor foam oil development effect.
  • the method further includes:
  • the oil well and the adjacent wells are subjected to combined gas injection and huff-and-puff;
  • the combined gas injection and huff-and-puff method allows the production of oil from multiple oil wells to be performed synchronously.
  • the gas injection amount is:
  • L is the production length of the horizontal well section
  • h is the oil layer thickness
  • R is the volume of gas dissolved in unit volume of crude oil under formation conditions
  • ⁇ is the surface density of gas
  • A is the increase in gas injection volume, and n is the number of oil production rounds.
  • the gas injection volume is increased by 5%-30%.
  • the row spacing of horizontal wells in the reservoir is twice the throughput radius.
  • the maximum rounds of gas injection throughput are 6, and the throughput radius under the maximum rounds is the maximum throughput radius.
  • the duration of soaking is related to the nature of the injected gas, the injection volume, the nature of the crude oil, the formation temperature and the formation pressure.
  • the gas injection pressure is lower than the fracture pressure of the formation in which the oil well is located.
  • the liquid production rate is 1.0%-4.0% of the controlled reserves of a single well.
  • the present invention provides a device for improving the recovery rate of foam oil cold production, the device comprising:
  • An acquisition module is used to acquire oil production data of the oil well to be produced, wherein the oil production data at least includes the gas-oil ratio of the oil well production, the original gas-oil ratio of the oil reservoir, the formation pressure of the oil reservoir, the pseudo-bubble point pressure, the oil production of the oil well, the peak production, and the proportion of foam in the oil sample;
  • a screening module used for screening oil wells with poor foam oil development effects according to the oil production data
  • An oil production module used for performing oil production actions on the oil well according to the oil production data, wherein the oil production actions include gas injection, well soaking and pumping back;
  • the gas injection, well soaking and pumping are repeated in sequence until the oil well reaches the cold production limit production, and the gas injection volume in the gas injection increases with the increase of oil production rounds.
  • screening oil wells with poor foam oil development effects according to the oil production data includes:
  • the oil well is an oil well with poor foam oil development effect.
  • the oil production module is further used to perform combined gas injection huff-and-puff on the oil well and the adjacent well if the adjacent well of the oil well has not reached the cold production limit production;
  • the combined gas injection and huff-and-puff method allows the production of oil from multiple oil wells to be performed synchronously.
  • the gas injection amount is:
  • L is the production length of the horizontal well section
  • h is the oil layer thickness
  • R is the volume of gas dissolved in unit volume of crude oil under formation conditions
  • ⁇ is the surface density of gas
  • A is the increase in gas injection volume, and n is the number of oil production rounds.
  • the gas injection volume is increased by 5%-30%.
  • the row spacing of horizontal wells in the reservoir is twice the throughput radius.
  • the maximum rounds of gas injection throughput are 6, and the throughput radius under the maximum rounds is the maximum throughput radius.
  • the duration of soaking is related to the nature of the injected gas, the injection volume, the nature of the crude oil, the formation temperature and the formation pressure.
  • the gas injection pressure is lower than the fracture pressure of the formation in which the oil well is located.
  • the liquid production rate is 1.0%-4.0% of the controlled reserves of a single well.
  • the present invention further provides a machine-readable storage medium having instructions stored thereon, the instructions being used to enable a machine to execute the above-mentioned method for improving the recovery rate of foamed oil cold recovery.
  • a method for improving the recovery rate of foam oil cold production of the present invention comprises the following steps: S1: obtaining the oil production data of the oil well to be produced, the oil production data at least including the oil well production gas-oil ratio, the original gas-oil ratio of the oil reservoir, the formation pressure of the oil reservoir, the pseudo-bubble point pressure, the oil production of the oil well, the peak production, and the proportion of foam in the oil sample; S2: screening the oil well with poor foam oil development effect according to the oil production data; S3: performing oil production actions on the oil well according to the oil production data, the oil production actions including gas injection, well soaking and pumping back; S4: repeating gas injection, well soaking and pumping back in sequence until the oil well reaches the cold production limit production, and the gas injection amount in the gas injection increases with the increase of the oil production round.
  • the present invention achieves the reduction of the viscosity of the crude oil after degassing, increases the formation pressure, and reduces the interfacial tension of the crude oil by screening the oil well with poor foam oil development effect and determining the timing of gas injection, thereby extending the life cycle of foam oil cold production by forming similar foam oil, continuing to exert the foam oil production capacity, improving the production in the cold production stage, and achieving effective treatment of low-yield wells and long-stopped wells.
  • FIG1 is a schematic flow diagram of a method for improving the recovery rate of foamed oil cold recovery according to the present invention
  • FIG2 is a schematic plan view of the vertical well gas injection coverage of the present invention.
  • FIG3 is a schematic plan view of the horizontal well gas injection coverage of the present invention.
  • FIG4 is a diagram showing an optimal radius of horizontal well gas injection sweep according to the present invention.
  • FIG5 is a diagram showing the optimal time for gas injection and shut-in of a horizontal well according to the present invention.
  • FIG6 is a diagram showing the preferred gas injection and liquid production rates for horizontal wells according to the present invention.
  • FIG. 7 is a diagram showing an optimal increase in gas injection in a horizontal well compared to the previous gas injection according to the present invention.
  • FIG1 is a flow diagram of a method for improving the recovery rate of foam oil cold production of the present invention.
  • step S1 is to obtain the oil production data of the oil well to be produced, and the oil production data at least includes the gas-oil ratio of the oil well production, the original gas-oil ratio of the oil reservoir, the formation pressure of the oil reservoir, the pseudo-bubble point pressure, the oil production of the oil well, the peak production, and the proportion of foam in the oil sample.
  • the oil reservoir is a foam oil reservoir.
  • the oil well to be produced is generally a long-stopped oil well.
  • the oil production data of the long-stopped oil well such as the oil well production gas-oil ratio, the original gas-oil ratio of the reservoir, the reservoir formation pressure, the pseudo-bubble point pressure, the oil well production, the peak production, and the proportion of foam in the oil sample, are obtained.
  • the preliminary data of the oil field are searched to determine the value of the original gas-oil ratio of the crude oil in the block; the value of the production gas-oil ratio of the oil well is determined by the volume of gas and crude oil produced by the oil well in a period of time before gas injection; the ratio of the current production gas-oil ratio and the original gas-oil ratio of the oil well to be produced before gas injection is calculated, and the ratio of the production gas-oil ratio and the original gas-oil ratio before the shutdown of the shutdown well is determined according to the same method.
  • the pseudo-bubble point pressure and reservoir formation pressure of the oil field crude oil are determined by the preliminary data, and the pseudo-bubble point pressure and reservoir formation pressure are compared to determine the relationship between the two.
  • the peak oil production of the oil well is the oil production (generally cubic meters/day) during the production period (at least 2 months) when the oil well has a higher production, and the oil production of the oil well is the average oil production in a period of time before gas injection (at least 15 days).
  • the original gas-oil ratio is also called the original dissolved gas-oil ratio, which refers to the amount of natural gas dissolved in a unit volume or weight of crude oil under the original formation conditions.
  • the oil formation pressure refers to the formation pressure of a certain period after the oil reservoir is put into development.
  • the bubble point pressure is the pressure at which the liquid mixture begins to vaporize and the first bubble appears when the system pressure is gradually reduced under constant temperature conditions.
  • Heavy oil cold production technology is a development technology that uses the effect of foamy oil to exploit heavy oil reservoirs.
  • the pressure range for foam generation is from the bubble point pressure to the pseudo-bubble point pressure.
  • the pseudo-bubble point pressure is used to describe the depletion recovery of heavy oil reservoirs and describes the foam oil fluid properties based on conventional indoor pressure, volume, and temperature data.
  • Step S2 is to screen the oil wells with poor foam oil development effect according to the oil production data.
  • the oil wells with poor foam oil development effect are oil wells with low cold production output, high production gas-oil ratio or stopped production oil wells.
  • the oil wells with poor foam oil development effect are screened according to the oil production data, including: when the oil well production gas-oil ratio> the original gas-oil ratio of the oil reservoir*10, and the reservoir formation pressure ⁇ the pseudo-bubble point pressure, and the oil well oil production ⁇ *20% of the peak production, and the foam proportion in the oil sample ⁇ the foam proportion threshold, then the oil well is an oil well with poor foam oil development effect.
  • the foam oil well production gas-oil ratio rises to more than 10 times the original gas-oil ratio, the formation pressure is lower than the pseudo-bubble point pressure, the oil well oil production is lower than 20% of the peak production, and the foam proportion in the oil sample is significantly reduced, it can be determined that the production effect of the foam oil well has significantly deteriorated, and gas injection is required to extend the foam oil cold production life cycle to improve the foam oil cold production development.
  • Step S3 is to perform oil production actions on the oil well according to the oil production data, and the oil production actions include gas injection, well shut-down and pumping back.
  • the gas injection amount is:
  • r is the throughput radius
  • L is the horizontal well section production length
  • h is the oil layer thickness
  • h is the porosity of the oil layer
  • So is the oil saturation
  • R is the volume of gas dissolved in a unit volume of crude oil under formation conditions
  • ⁇ is the surface density of gas
  • A is the amplitude of the increase in gas injection volume
  • n is the number of oil production rounds.
  • the amplitude of the increase in gas injection volume is 5%-30%.
  • the oil production data is related to the average oil saturation of the oil well control range.
  • the row spacing of the horizontal wells in the oil reservoir is twice the throughput radius.
  • the maximum number of gas injection throughput rounds is 6, and the throughput radius under the maximum round is the maximum throughput radius.
  • the amount of gas injection is determined by the thickness of the oil layer encountered by the oil well to be produced, the porosity of the oil layer, the swept radius and the solubility of the gas in the crude oil.
  • the oil production data is related to the solubility of the oil.
  • the swept range of a vertical well can be considered as a cylinder, as shown in Figure 2; and the swept range of a horizontal well gas injection is a rectangular parallelepiped + two semi-cylinders, as shown in Figure 3.
  • the injected gas should be appropriate. Too much injection will cause the gas to be unable to dissolve in the affected crude oil, causing difficulties and waste in the later pumping.
  • the inventors have found that after the gas was injected, the formation pressure at the bottom of the oil well within the swept radius increased by 0.5MPa, and the viscosity of the crude oil decreased. 50%-80%, the driving force of the formation and the fluidity of crude oil are significantly enhanced.
  • the amount of cold production fluid is related to the reservoir pressure and the degree of crude oil degassing, and is related to the dissolution of gas in crude oil after later gas injection and the length of well soaking.
  • the length of the well soaking is related to the nature of the gas injection, the injection amount, the nature of the crude oil, the formation temperature and the formation pressure. For example, the greater the gas injection amount within a certain range, the longer the well soaking time.
  • the gas injection pressure is lower than the fracture pressure of the formation where the oil well is located.
  • Step S4 is to repeat gas injection, well shut-down and pumping in sequence until the oil well reaches the cold production limit production, and the gas injection volume in the gas injection increases with the increase of oil production rounds.
  • the oil well stage production effect is that as the injection volume increases, the oil production of the oil well increases, but the oil change rate decreases.
  • the throughput radius is 50m, the decrease in the oil change rate slows down. Therefore, the preferred first-round throughput radius of this application is 50m, as shown in Figure 4.
  • the soaking time is generally based on the injected gas being fully dissolved in the crude oil and being utilized. As shown in Figure 5, if the soaking time is too short, the gas will be directly recovered without being dissolved, which will cause waste; if the soaking time is too long, it will lead to low production rate of the oil well, affecting the production within a certain period of time, and may also cause the injected gas to be far away from the bottom of the well and cause waste. The inventors have found that as the soaking time increases, the gas oil exchange rate becomes lower, so the preferred soaking time is 10 days.
  • the speed of liquid production can reflect the magnitude of the gas's drainage effect in the formation.
  • a too high liquid discharge speed will cause the pressure near the bottom of the well to drop too quickly, and the viscosity of the crude oil will increase, which is not conducive to the flow of crude oil. Too low a liquid discharge volume will result in low production per well, and the purpose of increasing production cannot be achieved. Therefore, the liquid production speed of this application is 1.0%-4.0%. After the liquid production speed reaches 2.0%, the oil change rate decreases faster, and at this time, a higher production of a single well can be guaranteed. Therefore, the preferred liquid production speed of this application is 2.0%.
  • the gas injection volume in the gas injection increases with the increase in the number of oil production rounds. Specifically, according to the need to increase the radius of the gas injection, the gas injection volume is increased by a certain proportion compared with the previous time. According to the on-site production effect, if the gas injection volume is too large, it will not be able to be recovered in time during the withdrawal, and if the gas injection volume is too small, it will lead to the inability to exert the reservoir capacity, affecting the overall production increase effect.
  • the liquid production rate is 1.0%-4.0% of the single well controlled reserves.
  • the single well controlled reserves are the geological reserves within the flow range of the single well controlled fluid. It can be calculated based on the results data obtained from the oil test using the formation test data processing and interpretation method.
  • the gas injection volume increases by 20%, the oil change rate decreases. Therefore, the gas injection volume of the new injection in this application is increased by 20% compared with the previous injection volume, as shown in FIG7 .
  • the preferred maximum round of gas injection throughput in this application is 6 rounds, at which time the limit radius of gas injection throughput is obtained.
  • the oil production method of the present application also includes: if the adjacent wells of the oil well have not reached the cold production limit, then the oil well and the adjacent wells are subjected to combined gas injection and huff; the combined gas injection and huff are performed synchronously for the oil production actions of multiple oil wells.
  • the combined gas injection and huff include: if the adjacent oil wells all reach the time when gas injection is required to extend the life cycle of foam oil cold production, the adjacent oil wells should be gas injected and opened for oil production at the same time, so as to avoid the injected gas from flowing into the adjacent wells that are recovering, thereby causing waste of injected gas and affecting the production of the adjacent wells.
  • a method for improving the recovery rate of foam oil cold production of the present invention comprises the following steps: S1: obtaining the oil production data of the oil well to be produced, the oil production data at least including the oil well production gas-oil ratio, the original gas-oil ratio of the oil reservoir, the formation pressure of the oil reservoir, the pseudo-bubble point pressure, the oil production of the oil well, the peak production, and the proportion of foam in the oil sample; S2: screening the oil well with poor foam oil development effect according to the oil production data; S3: performing oil production actions on the oil well according to the oil production data, the oil production actions including gas injection, well soaking and pumping back; S4: repeating gas injection, well soaking and pumping back in sequence until the oil well reaches the cold production limit production, and the gas injection amount in the gas injection increases with the increase of the oil production round.
  • the present invention achieves the reduction of the viscosity of the crude oil after degassing, increases the formation pressure, and reduces the interfacial tension of the crude oil by screening the oil well with poor foam oil development effect and determining the timing of gas injection, thereby extending the life cycle of foam oil cold production by forming similar foam oil, continuing to exert the foam oil production capacity, improving the production in the cold production stage, and achieving effective treatment of low-yield wells and long-stopped wells.
  • the present invention also provides a device for improving the recovery rate of foam oil cold production, the device comprising: an acquisition module, used to acquire oil production data of an oil well to be produced, the oil production data at least including the oil well production gas-oil ratio, the original gas-oil ratio of the reservoir, the reservoir formation pressure, the pseudo-bubble point pressure, the oil production of the oil well, the peak production, and the proportion of foam in the oil sample; a screening module, used to screen oil wells with poor foam oil development effects according to the oil production data; an oil production module, used to perform oil production actions on the oil wells according to the oil production data, the oil production actions including gas injection, well shut-in and pumping back; gas injection, well shut-in and pumping back are repeated in sequence until the oil well reaches the cold production limit, and the gas injection amount in the gas injection increases with the increase in the number of oil production rounds.
  • an acquisition module used to acquire oil production data of an oil well to be produced, the oil production data at least including the oil well production gas-oil ratio, the original
  • the bubble point pressure is the pressure at which the first bubble appears when the liquid mixture begins to vaporize by gradually reducing the system pressure under constant temperature.
  • Heavy oil cold production technology is a development technology that uses the effect of foam oil to produce heavy oil reservoirs.
  • the pressure range of foam generation is from the bubble point pressure to the pseudo-bubble point pressure.
  • the pseudo-bubble point pressure is used to describe the depletion-type production of heavy oil reservoirs, and describes the characteristics of foam oil fluids based on conventional indoor pressure, volume, and temperature data.
  • the method of screening the oil wells with poor foam oil development effect according to the oil production data includes: when the production gas-oil ratio of the oil well> the original gas-oil ratio of the oil reservoir*10, and the formation pressure of the oil reservoir ⁇ the pseudo-bubble point pressure, and the oil production of the oil well ⁇ *20% of the peak production, and the foam proportion in the oil sample ⁇ the foam proportion threshold, then the oil well is an oil well with poor foam oil development effect.
  • the gas injection volume is:
  • r is the throughput radius
  • L is the horizontal well section production length
  • h is the oil layer thickness
  • porosity of the oil layer is the porosity of the oil layer
  • So is the oil saturation
  • R is the volume of gas dissolved in a unit volume of crude oil under formation conditions
  • ⁇ is the surface density of gas
  • A is the increase in gas injection volume
  • n is the number of oil production rounds.
  • the increase in gas injection volume is 5%-30%.
  • the amount of gas injection is related to the thickness of the oil layer encountered by the oil well to be produced, the porosity of the oil layer, the swept radius and the solubility of the gas in the crude oil.
  • the swept range of a vertical well can be considered as a circle; while the swept range of a horizontal well gas injection is similar to an ellipse (rectangle + two semicircles).
  • the injected gas should be appropriate. Too much injection will cause the gas to be unable to dissolve in the affected crude oil, causing difficulties and waste in the later pumping. Too little injection will result in the inability to achieve the desired effect of pressurization, viscosity reduction, and improvement of oil recovery efficiency.
  • the inventors have found that after the gas is injected, the formation pressure at the bottom of the oil well within the swept radius increased by 0.5MPa, the crude oil viscosity decreased by 50%-80%, and the formation driving force and crude oil fluidity were significantly enhanced.
  • the oil production module is also used to perform combined gas injection and huffing on the oil well and the adjacent wells if the adjacent wells of the oil well have not reached the cold production limit production; the combined gas injection and huffing is the synchronization of oil production actions of multiple oil wells. conduct.
  • the combined gas injection and huff-and-puff includes: if adjacent oil wells all reach the time when gas injection is required to extend the life cycle of foam oil cold production, the adjacent oil wells should be injected with gas and opened for oil production at the same time, so as to avoid the injected gas from flowing along the high-permeability channel to the adjacent well that is recovering, thereby causing waste of injected gas, affecting the production of adjacent wells, and causing the current well to fail to meet the expected gas injection requirements, and also affecting the production effect of the current well.
  • the present application selectively injects gas into the oil well, which can expand the crude oil to increase the formation pressure, improve the oil displacement efficiency, reduce the viscosity of crude oil, form the effect of dissolved gas drive, and even form secondary foam, and continue to apply the foam oil mechanism to play a role in increasing production and resuming production.
  • the injected gas enters the bottom of the well and gradually dissolves in the crude oil after contacting with the crude oil.
  • the length of the dissolution time is related to the gas properties, the gas injection amount, the crude oil properties and the temperature and pressure of the formation.
  • the oil well will be closed, that is, the well soaking time is related to the nature of the gas injection, the injection amount, the crude oil properties, the formation temperature and the formation pressure.
  • the oil well After a period of soaking, when the gas and the crude oil are fully dissolved (the bottom hole pressure is relatively stable), the oil well can be organized to be pumped back at a certain liquid production rate in a timely manner, so that the oil well production should be improved to a certain extent compared with before the gas injection, and the production of the shut-down well will also increase significantly compared with before the shutdown; after a period of production, the oil well production gradually decreases (generally not higher than before the gas injection), the oil well can be shut down and the next round of gas injection can be carried out, and the gas injection amount is increased by a certain proportion compared with the previous time; repeat the gas injection, soaking, and pumping until the oil well reaches the cold production limit production.
  • This method not only achieves the extension of the foam oil cold production life cycle and improves the effect of cold production stage development, but also achieves the effect of enhancing fluid drive, reducing crude oil viscosity, and improving oil washing efficiency.
  • the soaking time is generally based on the injected gas being fully dissolved in the crude oil and being utilized. If the soaking time is too short, the gas will be directly recovered without being dissolved, which will cause waste; if the soaking time is too long, it will lead to low production rate of the oil well, affecting the production within a certain period of time, and may also cause the injected gas to be far away from the bottom of the well and cause waste.
  • the inventors have found that as the soaking time increases, the gas oil exchange rate becomes lower, so the preferred soaking time is 10 days.
  • the liquid production rate can reflect the extent of the gas's drainage effect in the formation. Under the condition of equal liquid volume, excessive liquid discharge speed will cause the pressure near the bottom of the well to drop too quickly, increase the viscosity of crude oil, and be unfavorable for crude oil flow. Too low liquid discharge will lead to low single well production and fail to achieve the purpose of increasing production. Therefore, the liquid production speed of this application is 1.0%-4.0%. After the liquid production speed reaches 2.0%, the oil change rate decreases faster, and at this time, a higher single well production can be guaranteed. Therefore, the preferred liquid production speed of this application is 2.0%.
  • the gas injection volume in the gas injection increases with the increase in the number of oil production rounds. Specifically, according to the need to increase the radius of the gas injection, the gas injection volume is increased by a certain proportion compared with the previous time. According to the on-site production effect, if the gas injection volume is too large, it will not be able to be recovered in time during the withdrawal, and if the gas injection volume is too small, it will lead to the inability to exert the reservoir capacity, affecting the overall production increase effect.
  • the inventors have found that the production effect is best when the gas injection volume is increased by 5%-30% compared with the first round, and as the increment becomes larger, the oil production of the second round gradually increases. When the gas injection volume increases by 20%, the oil change rate decreases slowly. Therefore, the new gas injection volume of this application is increased by 20% compared with the previous time.
  • the preferred maximum number of gas injection throughput rounds in this application is 6 rounds, at which time the gas injection throughput limit radius is obtained.
  • a certain oil reservoir is a heavy oil reservoir
  • the oil well production shows the characteristics of foam oil.
  • the oil reservoir is buried at a depth of 800m
  • the average thickness of the oil layer is 22m
  • the work area is a pure oil reservoir
  • the original gas-oil ratio of the oil reservoir is 15 cubic meters.
  • the oil reservoir is developed by horizontal well cold production.
  • the peak production of the horizontal well is 122 tons/day. After 11 years of production, the production before suspension dropped to 23.4 tons/day.
  • the production gas-oil ratio is 21.7 times the original gas-oil ratio, and the cold production effect is poor.
  • the method for improving the recovery rate of foam oil cold production of the present invention is to inject a certain amount of gas into the oil well when the foam oil cold production effect is poor or has been stopped, so that the gas is in contact with the crude oil for a certain period of time and dissolved into the crude oil, so that the crude oil expands and thus increases the formation pressure, reduces the viscosity of the formation crude oil, and the crude oil The interfacial tension is reduced and the residual oil saturation is lowered, thereby increasing the oil recovery efficiency, increasing the oil well recovery production, extending the foam oil cold production time, and improving the effect of cold production development.
  • the present invention also provides an electronic device, which includes: at least one processor; a memory connected to the at least one processor; wherein the memory stores instructions that can be executed by the at least one processor, and the at least one processor implements the above-mentioned method for improving the recovery rate of foam oil cold recovery by executing the instructions stored in the memory.
  • the processor includes a kernel, which retrieves the corresponding program unit from the memory.
  • One or more kernels can be set, and the production in the cold production stage is increased by adjusting the kernel parameters, thereby achieving effective treatment of low-yield wells and long-stopped wells.
  • the memory may include non-permanent memory in a computer-readable medium, in the form of random access memory (RAM) and/or non-volatile memory, such as read-only memory (ROM) or flash RAM, and the memory includes at least one memory chip.
  • RAM random access memory
  • ROM read-only memory
  • flash RAM flash random access memory
  • An embodiment of the present invention provides a storage medium on which a program is stored.
  • the program is executed by a processor, the method for improving the recovery rate of foam oil cold recovery is implemented.
  • An embodiment of the present invention provides a processor, which is used to run a program, wherein the program executes a method for improving the recovery rate of foam oil cold recovery when running.
  • the embodiment of the present invention provides a device, which includes a processor, a memory, and a program stored in the memory and executable on the processor.
  • the processor executes the program, the following steps are implemented: (method claim steps, exclusive rights + subordinate rights).
  • the device in this article can be a server, a PC, a PAD, a mobile phone, etc.
  • the present application also provides a computer program product, which, when executed on a data processing device, is suitable for executing a program that is initialized with the following method steps: obtaining oil production data of the well to be produced, the oil production data at least including the oil well production gas-oil ratio, the original gas-oil ratio of the reservoir, the reservoir formation pressure, the pseudo-bubble point pressure, the oil well oil production, the peak production, and the proportion of foam in the oil sample; screening the oil wells with poor foam oil development effect according to the oil production data; performing oil production actions on the oil wells according to the oil production data, the oil production actions including gas injection, well shut-in and pumping back; repeating gas injection, well shut-in and pumping back in sequence until the oil well reaches the cold production limit production, and the gas injection volume in the gas injection increases with the increase in the number of oil production rounds.
  • the screening of oil wells with poor foam oil development effect according to the oil production data includes: when the oil well production gas-oil ratio> the original gas-oil ratio of the reservoir*10, and the reservoir formation pressure ⁇ the pseudo-bubble point pressure, and the oil well oil production ⁇ *20% of the peak production, and the foam proportion in the oil sample ⁇ the foam proportion If the oil well is lower than the threshold, the oil well is an oil well with poor foam oil development effect.
  • the method also includes: if the adjacent wells of the oil well have not reached the cold production limit production, the oil well and the adjacent wells are subjected to combined gas injection and huff-and-puff; the combined gas injection and huff-and-puff is a synchronous oil production action of multiple oil wells.
  • the embodiments of the present application may be provided as methods, systems, or computer program products. Therefore, the present application may adopt the form of a complete hardware embodiment, a complete software embodiment, or an embodiment in combination with software and hardware. Moreover, the present application may adopt the form of a computer program product implemented in one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) that include computer-usable program code.
  • a computer-usable storage media including but not limited to disk storage, CD-ROM, optical storage, etc.
  • These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing device to work in a specific manner, so that the instructions stored in the computer-readable memory produce a manufactured product including an instruction device that implements the functions specified in one or more processes in the flowchart and/or one or more boxes in the block diagram.
  • These computer program instructions may also be loaded onto a computer or other programmable data processing device so that a series of operational steps are executed on the computer or other programmable device to produce a computer-implemented process, whereby the instructions executed on the computer or other programmable device provide steps for implementing the functions specified in one or more processes in the flowchart and/or one or more boxes in the block diagram.
  • a computing device includes one or more processors (CPU), input/output interfaces, network interfaces, and memory.
  • processors CPU
  • input/output interfaces network interfaces
  • memory volatile and non-volatile memory
  • Memory may include non-permanent storage in a computer-readable medium, random access memory (RAM) and/or non-volatile memory in the form of read-only memory (ROM) or flash memory (flash RAM). Memory is an example of a computer-readable medium.
  • RAM random access memory
  • ROM read-only memory
  • flash RAM flash memory
  • Computer-readable media include permanent and non-permanent, removable and non-removable media that can be stored in any computer. Any method or technology to achieve information storage. Information can be computer-readable instructions, data structures, modules of programs or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technology, compact disk read-only memory (CD-ROM), digital versatile disk (DVD) or other optical storage, magnetic cassettes, magnetic tape magnetic disk storage or other magnetic storage devices or any other non-transmission media that can be used to store information that can be accessed by a computing device. As defined herein, computer-readable media does not include transitory media such as modulated data signals and carrier waves.
  • PRAM phase change memory
  • SRAM static random access memory
  • DRAM dynamic random access memory
  • RAM random access memory
  • ROM

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Abstract

本发明实施例提供一种提高泡沫油冷采采收率的方法、装置及存储介质，该方法包括以下步骤：S1：获取待采油井的采油数据，所述采油数据至少包括油井生产气油比、油藏原始气油比、油藏地层压力、拟泡点压力、油井产油量、高峰产量、油样中泡沫占比；S2：根据所述采油数据筛选泡沫油开发效果差的油井；S3：根据所述采油数据对所述油井进行采油动作，所述采油动作包括注气、焖井和回抽；S4：依次重复注气、焖井、回抽，直至该油井达到冷采极限产量，所述注气中的注气量随采油轮次的增加而增加。该方法提高了冷采阶段的产量，实现了低产井及长停井的有效治理。

Description

一种提高泡沫油冷采采收率的方法
相关申请的交叉引用
本申请要求2023年06月26日提交的中国专利申请202310762016.5的权益，该申请的内容通过引用被合并于本文。
技术领域
本发明涉及石油开采技术领域，具体地涉及一种提高泡沫油冷采采收率的方法。
背景技术
泡沫油是一种含气原油，其中气相以微小气泡的形式分散于油相中，这种特殊的状态使得泡沫油流动性强，产量高。在现有的石油开采中，只有当泡沫油油藏的地层压力下降至泡点压力以下，所述泡沫油油藏中的溶解气才从油相中得以释放。最初气相以微小气泡的状态存在，随着时间的推移和压力的下降，在不同位置形成的气泡不断增大并逐渐聚集形成连续的气相。
然而随着油井附近压力降低(低至拟泡点压力)，原油脱气后逐渐形成自由相，泡沫油作用下降，油相粘度升高，油井产量降低，生产气油比增大，影响了油井的正常生产。
发明内容
本发明实施例的目的是提供一种提高泡沫油冷采采收率的方法，该方法提高了冷采阶段的产量，实现了低产井及长停井的有效治理。
为了实现上述目的，本发明实施例提供一种提高泡沫油冷采采收率的方法，该方法包括以下步骤：
S1：获取待采油井的采油数据，所述采油数据至少包括油井生产气油比、油藏原始气油比、油藏地层压力、拟泡点压力、油井产油量、高峰产量、油样中泡沫占比；
S2：根据所述采油数据筛选泡沫油开发效果差的油井；
S3：根据所述采油数据对所述油井进行采油动作，所述采油动作包括注气、焖井和回抽；
S4：依次重复注气、焖井、回抽，直至该油井达到冷采极限产量，所述注气中的注气量随采油轮次的增加而增加。
可选的，所述根据所述采油数据筛选泡沫油开发效果差的油井，包括：
当油井生产气油比>所述油藏原始气油比*10，且油藏地层压力<拟泡点压力，且油井产油量<高峰产量的*20％，且油样中泡沫占比<泡沫占比阈值，则该油井为泡沫油开发效果差的油井。
可选的，该方法还包括：
如果所述油井的邻井未达到冷采极限产量，则对该油井和邻井进行组合式注气吞吐；
所述组合式注气吞吐为多口油井的采油动作同步进行。
可选的，所述注气量为：
其中，r为吞吐半径，
L为水平井段生产长度，
h为油层厚度，
为油层的孔隙度，
So为含油饱和度，
R为地层条件下单位体积原油溶解气体体积，
ρ为气体地面密度，
A为注气量增加的幅度,n为采油轮次。
可选的，所述注气量增加的幅度为5％-30％。
可选的，油藏水平井的排距为吞吐半径的2倍。
可选的，注气吞吐最大轮次为6，最大轮次下的吞吐半径为最大吞吐半径。
可选的，所述焖井的时长与注气的性质、注入量、原油性质、地层温度及地层压力有关。
可选的，注气过程中，注气压力低于油井所处地层的破裂压力。
可选的，回抽过程中，采液速度为单井控制储量的1.0％-4.0％。
另一方面，本发明提供一种提高泡沫油冷采采收率的装置，该装置包括：
获取模块，用于获取待采油井的采油数据，所述采油数据至少包括油井生产气油比、油藏原始气油比、油藏地层压力、拟泡点压力、油井产油量、高峰产量、油样中泡沫占比；
筛选模块，用于根据所述采油数据筛选泡沫油开发效果差的油井；
采油模块，用于根据所述采油数据对所述油井进行采油动作，所述采油动作包括注气、焖井和回抽；
依次重复注气、焖井、回抽，直至该油井达到冷采极限产量，所述注气中的注气量随采油轮次的增加而增加。
可选的，所述根据所述采油数据筛选泡沫油开发效果差的油井，包括：
当油井生产气油比>所述油藏原始气油比*10，且油藏地层压力<拟泡点压力，且油井产油量<高峰产量的*20％，且油样中泡沫占比<泡沫占比阈值，则该油井为泡沫油开发效果差的油井。
可选的，所述采油模块还用于如果所述油井的邻井未达到冷采极限产量，则对该油井和邻井进行组合式注气吞吐；
所述组合式注气吞吐为多口油井的采油动作同步进行。
可选的，所述注气量为：
其中，r为吞吐半径，
L为水平井段生产长度，
h为油层厚度，
为油层的孔隙度，
So为含油饱和度，
R为地层条件下单位体积原油溶解气体体积，
ρ为气体地面密度，
A为注气量增加的幅度,n为采油轮次。
可选的，所述注气量增加的幅度为5％-30％。
可选的，油藏水平井的排距为吞吐半径的2倍。
可选的，注气吞吐最大轮次为6，最大轮次下的吞吐半径为最大吞吐半径。
可选的，所述焖井的时长与注气的性质、注入量、原油性质、地层温度及地层压力有关。
可选的，注气过程中，注气压力低于油井所处地层的破裂压力。
可选的，回抽过程中，采液速度为单井控制储量的1.0％-4.0％。
另一方面，本发明还提供一种机器可读存储介质，该机器可读存储介质上存储有指令，该指令用于使得机器执行上述所述的提高泡沫油冷采采收率的方法。
本发明的一种提高泡沫油冷采采收率的方法包括以下步骤：S1：获取待采油井的采油数据，所述采油数据至少包括油井生产气油比、油藏原始气油比、油藏地层压力、拟泡点压力、油井产油量、高峰产量、油样中泡沫占比；S2：根据所述采油数据筛选泡沫油开发效果差的油井；S3：根据所述采油数据对所述油井进行采油动作，所述采油动作包括注气、焖井和回抽；S4：依次重复注气、焖井、回抽，直至该油井达到冷采极限产量，所述注气中的注气量随采油轮次的增加而增加。本发明通过筛选泡沫油开发效果差的油井，并对其进行注气时机的判定，实现了降低脱气后原油的粘度，增大地层压力，减小原油界面张力，进而通过形成类似泡沫油来延长泡沫油冷采生命周期，继续发挥泡沫油生产能力，提高了冷采阶段的产量，实现了低产井及长停井的有效治理。
本发明实施例的其它特征和优点将在随后的具体实施方式部分予以详细说明。
附图说明
附图是用来提供对本发明实施例的进一步理解，并且构成说明书的一部分，与下面的具体实施方式一起用于解释本发明实施例，但并不构成对本发明实施例的限制。在附图中：
图1是本发明的一种提高泡沫油冷采采收率的方法的流程示意图；
图2为本发明的直井注气波及范围平面示意图；
图3为本发明的水平井注气波及范围平面示意图；
图4为本发明的水平井注气波及半径优选图；
图5为本发明的水平井注气焖井时间优选图；
图6为本发明的水平井注气采液速度优选图；
图7为本发明的水平井注气较上次注气增量优选图。
具体实施方式
以下结合附图对本发明实施例的具体实施方式进行详细说明。应当理解的是，此处所描述的具体实施方式仅用于说明和解释本发明实施例，并不用于限制本发明实施例。
图1是本发明的一种提高泡沫油冷采采收率的方法的流程示意图，如图1所示，步骤S1为获取待采油井的采油数据，所述采油数据至少包括油井生产气油比、油藏原始气油比、油藏地层压力、拟泡点压力、油井产油量、高峰产量、油样中泡沫占比。所述油藏为泡沫油油藏。
具体的，所述待采油井一般为长停油井。获取所述长停油井的油井生产气油比、油藏原始气油比、油藏地层压力、拟泡点压力、油井产油量、高峰产量、油样中泡沫占比等采油数据。
按照一种具体的实施方式，查找油田前期资料以确定区块原油原始气油比的值；通过注气前一段时间内油井所产气体和原油体积确定油井生产气油比的值；计算所述待采油井注气前的当前生产气油比和原始气油比的比值，根据同样的方法确定到停产井停产前生产气油比和原始气油比的比值。通过前期资料确定油田原油的拟泡点压力和油藏地层压力，对比拟泡点压力和油藏地层压力以确定二者的关系。油井高峰期产油量为油井产量较高的生产期(至少2个月)产油量(一般为方/天)，油井产油量为注气前一段时间内(至少15天)的平均产油量。具体的，原始气油比又称原始溶解气油比，指在原始地层条件下，单位体积或重量原油所溶解的天然气量。油层压力是指油藏投入开发后某一时期的地层压力。
泡点压力是在恒温条件下逐步降低系统压力，当液体混合物开始汽化出现第一个汽泡时的压力。稠油冷采技术是借助于泡沫油的作用来开采稠油油藏的开发技术。泡沫产生的压力区间就是泡点压力至拟泡点压力。拟泡点压力是用来描述稠油油藏的衰竭式开采，根据常规室内压力、体积、温度数据描述泡沫油流体特性。当地层压力低于热力学平衡泡点压力以下，原油中的溶解气会以扩散气的形式析出，形成一个自由移动气相，直到更低的压力，即拟泡点压力。在拟泡点压力以下，部分扩散的气体会变成自由气体，随着压力的递减，扩散在原油中的 气体会减少直到全部变为自由气体。随着泡沫油油藏冷采开发的深入，地层压力进一步降低(低于拟泡点压力)，溶解气逐渐逸出成连续相，泡沫油优势发挥殆尽，油井生产气油比上升，产油量下降，甚至导致油井关停。
步骤S2为根据所述采油数据筛选泡沫油开发效果差的油井。所述泡沫油开发效果差的油井为冷采产量低、生产气油比高的油井或停产油井。
具体的，所述根据所述采油数据筛选泡沫油开发效果差的油井，包括：当油井生产气油比>所述油藏原始气油比*10，且油藏地层压力<拟泡点压力，且油井产油量<高峰产量的*20％，且油样中泡沫占比<泡沫占比阈值，则该油井为泡沫油开发效果差的油井。当泡沫油井生产气油比上升至原始气油比10倍以上、地层压力低于拟泡点压力、油井产油量低于高峰产量20％且油样中泡沫占比明显减少时，则可以确定泡沫油井生产效果明显变差，则需要进行注气以延长泡沫油冷采生命周期以改善泡沫油冷采开发。
步骤S3为根据所述采油数据对所述油井进行采油动作，所述采油动作包括注气、焖井和回抽。
具体的，所述注气量为：
其中，r为吞吐半径，L为水平井段生产长度，h为油层厚度，为油层的孔隙度，So为含油饱和度，R为地层条件下单位体积原油溶解气体体积，ρ为气体地面密度，A为注气量增加的幅度,n为采油轮次。优选的，所述注气量增加的幅度为5％-30％。采油数据与油井控制范围的平均含油饱和度有关。优选的，油藏水平井的排距为吞吐半径的2倍。注气吞吐最大轮次为6，最大轮次下的吞吐半径为最大吞吐半径。
按照一种具体的实施方式，注气量由待采油井钻遇油层厚度、油层孔隙度、波及半径及气体在原油中的溶解度决定。采油数据与溶解度油有关。通常，直井波及范围可以认为是一个圆柱体，如图2所示；而水平井注气波及范围则是一个长方体+两个半圆柱体，如图3所示。注入气体应适量，注入过多会导致气体无法溶解在所波及的原油中，对后期转抽造成困难且造成浪费，注入过少会造成无法达到想要的增压、降粘、提高驱油效率的效果。经发明人研究发现，在注入气体后波及半径范围内油井井底的地层压力上升了0.5MPa，原油粘度下降了 50％-80％，地层驱动力及原油流动性明显增强。冷采液量高低关系到油藏压力以及原油脱气程度，与后期注气后气体在原油中的溶解状况及焖井时长有关。所述焖井的时长与注气的性质、注入量、原油性质、地层温度及地层压力有关，例如注气量在一定范围内越大，则焖井时长越长。注气过程中，注气压力低于油井所处地层的破裂压力。
步骤S4为依次重复注气、焖井、回抽，直至该油井达到冷采极限产量，所述注气中的注气量随采油轮次的增加而增加。
按照一种具体的实施方式，首轮吞吐半径为30-110m时油井阶段生产效果，随着注入量的增大，油井产油量增加，但换油率下降，吞吐半径在50m时换油率下降幅度减缓，因此本申请优选的首轮吞吐半径为50m，具体如图4所示。
焖井的时间一般以注入气体充分溶解于原油得到利用为准，如图5所示，如果焖井时间过短，气体未溶解直接就回采会造成浪费；如果焖井时间过长，则会导致油井生产时率低，影响一定时间内的产量，也可造成注入的气体远离井底造成浪费。经发明人研究发现，随着焖井时间延长气体换油率变低，因此优选焖井时间为10天。
其中，采液速度的高低可反映气体在地层中助排作用的大小。如图6所示，在周期总排液量相当的情况下，排液速度过大会导致井底附近压力过快下降，原油粘度增大，不利于原油流动。排液量过低将会导致单井产量低，不能达到提高产量目的。因此本申请的发采液速度为1.0％-4.0％，在采液速度2.0％以后阶段换油率下降加快，且此时可以保证单井有较高产量，因此本申请的优选采液速度为2.0％。
所述注气中的注气量随采油轮次的增加而增加。具体的，根据注气波及半径增大的需要，注气量较前一次增加一定比例。照现场生产效果实施，注气量过大会在回抽时无法及时回采，注气量少会导致无法发挥油藏能力，影响总体增产效果。优选的，回抽过程中，采液速度为单井控制储量的1.0％-4.0％。单井控制储量为单井控制流体流动范围内的地质储量。可根据试油取得的成果数据，采用地层测试资料处理解释方法进行计算。
经发明人研究发现，注气量较首轮增加幅度为5％-30％时的生产效果最佳，并且随着增量变大，二轮次产油量逐渐增加，在注气量增加20％时换油率下降减 缓，因此本申请的新一次较前一次注气量增加20％，如图7所示。
而且，随着注气轮次增加，井底含油饱和度降低，周期产油量下降达到冷采极限产量，本申请优选的注气吞吐最大轮次为6轮次，此时得到注气吞吐极限半径。通过确定注气吞吐极限半径，可初步确定泡沫油油藏水平井最优排距应为吞吐半径的2倍。根据泡沫油油藏水平井开发现状，判定前期井距适应性，指导后期井网井距调整，实现泡沫油经济有效开发。排距就是水井井排与油井井排之间的距离。
本申请的采油方法还包括：如果所述油井的邻井未达到冷采极限产量，则对该油井和邻井进行组合式注气吞吐；所述组合式注气吞吐为多口油井的采油动作同步进行。具体的，所述组合式注气吞吐包括：如果相邻的油井均达到需注气来延长泡沫油冷采生命周期时机，应使相邻油井同时注气同时开井采油，可以避免注入的气体窜至正回采的邻井，从而导致注入气体浪费，影响邻井生产。
本发明的一种提高泡沫油冷采采收率的方法包括以下步骤：S1：获取待采油井的采油数据，所述采油数据至少包括油井生产气油比、油藏原始气油比、油藏地层压力、拟泡点压力、油井产油量、高峰产量、油样中泡沫占比；S2：根据所述采油数据筛选泡沫油开发效果差的油井；S3：根据所述采油数据对所述油井进行采油动作，所述采油动作包括注气、焖井和回抽；S4：依次重复注气、焖井、回抽，直至该油井达到冷采极限产量，所述注气中的注气量随采油轮次的增加而增加。本发明通过筛选泡沫油开发效果差的油井，并对其进行注气时机的判定，实现了降低脱气后原油的粘度，增大地层压力，减小原油界面张力，进而通过形成类似泡沫油来延长泡沫油冷采生命周期，继续发挥泡沫油生产能力，提高了冷采阶段的产量，实现了低产井及长停井的有效治理。
本发明还提供一种提高泡沫油冷采采收率的装置，该装置包括：获取模块，用于获取待采油井的采油数据，所述采油数据至少包括油井生产气油比、油藏原始气油比、油藏地层压力、拟泡点压力、油井产油量、高峰产量、油样中泡沫占比；筛选模块，用于根据所述采油数据筛选泡沫油开发效果差的油井；采油模块，用于根据所述采油数据对所述油井进行采油动作，所述采油动作包括注气、焖井和回抽；依次重复注气、焖井、回抽，直至该油井达到冷采极限产量，所述注气中的注气量随采油轮次的增加而增加。
泡点压力是在恒温条件下逐步降低系统压力，当液体混合物开始汽化出现第一个汽泡时的压力。稠油冷采技术是借助于泡沫油的作用来开采稠油油藏的开发技术。泡沫产生的压力区间就是泡点压力至拟泡点压力。拟泡点压力是用来描述稠油油藏的衰竭式开采，根据常规室内压力、体积、温度数据描述泡沫油流体特性。当地层压力低于热力学平衡泡点压力以下，原油中的溶解气会以扩散气的形式析出，形成一个自由移动气相，直到更低的压力，即拟泡点压力。在拟泡点压力以下，部分扩散的气体会变成自由气体，随着压力的递减，扩散在原油中的气体会减少直到全部变为自由气体。随着泡沫油油藏冷采开发的深入，地层压力进一步降低(低于拟泡点压力)，溶解气逐渐逸出成连续相，泡沫油优势发挥殆尽，油井生产气油比上升，产油量下降，甚至导致油井关停。
所述根据所述采油数据筛选泡沫油开发效果差的油井，包括：当油井生产气油比>所述油藏原始气油比*10，且油藏地层压力<拟泡点压力，且油井产油量<高峰产量的*20％，且油样中泡沫占比<泡沫占比阈值，则该油井为泡沫油开发效果差的油井。
所述注气量为：
其中，r为吞吐半径，L为水平井段生产长度，h为油层厚度，为油层的孔隙度，So为含油饱和度，R为地层条件下单位体积原油溶解气体体积，ρ为气体地面密度，A为注气量增加的幅度，n为采油轮次。优选的，所述注气量增加的幅度为5％-30％。
按照一种具体的实施方式，注气量和待采油井钻遇油层厚度、油层孔隙度、波及半径及气体在原油中的溶解度有关。通常，直井波及范围可以认为是一个圆；而水平井注气波及范围则是一个类似椭圆(长方形+两个半圆)。注入气体应适量，注入过多会导致气体无法溶解在所波及的原油中，对后期转抽造成困难且造成浪费，注入过少会造成无法达到想要的增压、降粘、提高驱油效率的效果。经发明人研究发现，在注入气体后波及半径范围内油井井底的地层压力上升了0.5MPa，原油粘度下降了50％-80％，地层驱动力及原油流动性明显增强。
所述采油模块还用于如果所述油井的邻井未达到冷采极限产量，则对该油井和邻井进行组合式注气吞吐；所述组合式注气吞吐为多口油井的采油动作同步 进行。
具体的，所述组合式注气吞吐包括：如果相邻的油井均达到需注气来延长泡沫油冷采生命周期时机，应使相邻油井同时注气同时开井采油，可以避免注入的气体沿高渗通道窜至正回采的邻井，从而导致注入气体浪费，影响邻井生产，也导致本井达不到预期注气要求，也影响本经生产效果。
在泡沫油井冷采过程中，由于泡沫油作用，阶段产量较高，但随着生产延续，部分井因生产时间长，井底附近地层亏空较大，压力降低(低于拟泡点压力)，原来分散于油相中的气泡会逐渐逸出形成自由状态的游离气。而原油在脱气后粘度增大，原油流动性变差，油井产量会下降，甚至有些油井会因生产气油比过高而关井，这导致油井总体生产效果变差。本申请在油井中有选择性的注入气体，可使原油膨胀增大地层压力，提高驱油效率、降低原油粘度、形成溶解气驱的效果，甚至可形成二次泡沫，继续应用泡沫油机理起到增产复产作用。
按照一种具体的实施方式，注入的气体进入井底，与原油接触后会逐步溶解于原油中。溶解时间的长短与气体性质、气体注入量、原油性质以及地层的温度压力有关，这个溶解过程中，油井会关闭，即所述焖井时间与注气的性质、注入量、原油性质、地层温度及地层压力有关。经过一段时间焖井后，待气体与原油充分溶解(井底压力相对稳定)，可适时组织油井以一定的采液速度回抽，使得油井产量较注气前应有一定的提升，该停产井产量较停产前也会有较大幅度的上升；待经过一段时间生产，油井产量逐渐降低后(一般不高于注气前)，可关停油井，进行下一轮注气，注气量较前一次增加一定比例；重复注气、焖井、回抽直至该油井达到冷采极限产量，该方法不仅实现了延长泡沫油冷采生命周期，改善冷采阶段开发的效果，还实现了增强流体驱动、降低原油粘度、提高洗油效率的效果。
焖井的时间一般以注入气体充分溶解于原油得到利用为准，如果焖井时间过短，气体未溶解直接就回采会造成浪费；如果焖井时间过长，则会导致油井生产时率低，影响一定时间内的产量，也可造成注入的气体远离井底造成浪费。经发明人研究发现，随着焖井时间延长气体换油率变低，因此优选焖井时间为10天。
其中，采液速度的高低可反映气体在地层中助排作用的大小。在周期总排 液量相当的情况下，排液速度过大会导致井底附近压力过快下降，原油粘度增大，不利于原油流动。排液量过低将会导致单井产量低，不能达到提高产量目的。因此本申请的发采液速度为1.0％-4.0％，在采液速度2.0％以后阶段换油率下降加快，且此时可以保证单井有较高产量，因此本申请的优选采液速度为2.0％。
所述注气中的注气量随采油轮次的增加而增加。具体的，根据注气波及半径增大的需要，注气量较前一次增加一定比例。照现场生产效果实施，注气量过大会在回抽时无法及时回采，注气量少会导致无法发挥油藏能力，影响总体增产效果。经发明人研究发现，注气量较首轮增加幅度为5％-30％时的生产效果最佳，并且随着增量变大，二轮次产油量逐渐增加，在注气量增加20％时换油率下降减缓，因此本申请的新一次较前一次注气量增加20％。
而且，随着注气轮次增加，井底含油饱和度降低，周期产油量下降达到冷采极限产量，本申请优选的注气吞吐最大轮次为6轮次，此时得到注气吞吐极限半径。通过确定注气吞吐极限半径，可初步确定泡沫油油藏水平井最优排距应为吞吐半径的2倍。根据泡沫油油藏水平井开发现状，判定前期井距适应性，指导后期井网井距调整，实现泡沫油经济有效开发。
本申请还提出了一种具体的实施例，具体的：某油藏为稠油油藏，油井生产表现为泡沫油特征。其中，油藏埋深800m，油层平均厚度22m，工区范围内为纯油藏，油藏原始气油比为15方/方。对该油藏采用水平井冷采开发。水平井的高峰期产量为122吨/天，投产11年后，停产前产量降至23.4吨/天，生产气油比为原始气油比21.7倍，冷采效果较差。
在停产两年后，为复产该井注入气体，测算首周期波及半径为50m左右，然后注入气体焖井10天后开井生产，在控制采液速度2.5％的情况下，初期日产油达到95吨，在产量下降至停产前产量时关井。第二次注气量在第一次的基础上增加20％，继续生产，可循环注气生产6个轮次，循环注气阶段产量占前期泡沫油冷采产量的40％以上。该实施例可以得出本发明的延长泡沫油冷采生命周期的方法有效延长了泡沫油井的冷采阶段。
本发明的一种提高泡沫油冷采采收率的方法在油井在泡沫油冷采效果变差或者已经停产的情况下，在油井中通过注入一定量的气体，使气体与原油接触一定时间而溶入原油，使得原油膨胀进而增加地层压力、地层原油粘度降低、原油 界面张力减小、残余油饱和度降低，进而增大驱油效率，使得油井回抽产量提升，延长了泡沫油冷采时长，改善了冷采开发的效果。
另一方面，本发明还提供一种电子设备，该电子设备包括：至少一个处理器；存储器，与所述至少一个处理器连接；其中，所述存储器存储有能被所述至少一个处理器执行的指令，所述至少一个处理器通过执行所述存储器存储的指令实现上述所述的提高泡沫油冷采采收率的方法。
所述处理器中包含内核，由内核去存储器中调取相应的程序单元。内核可以设置一个或以上，通过调整内核参数来提高了冷采阶段的产量，实现了低产井及长停井的有效治理。
存储器可能包括计算机可读介质中的非永久性存储器，随机存取存储器(RAM)和/或非易失性内存等形式，如只读存储器(ROM)或闪存(flash RAM)，存储器包括至少一个存储芯片。
本发明实施例提供了一种存储介质，其上存储有程序，该程序被处理器执行时实现所述提高泡沫油冷采采收率的方法。
本发明实施例提供了一种处理器，所述处理器用于运行程序，其中，所述程序运行时执行提高泡沫油冷采采收率的方法。
本发明实施例提供了一种设备，设备包括处理器、存储器及存储在存储器上并可在处理器上运行的程序，处理器执行程序时实现以下步骤：(方法权项步骤，独权+从权)。本文中的设备可以是服务器、PC、PAD、手机等。
本申请还提供了一种计算机程序产品，当在数据处理设备上执行时，适于执行初始化有如下方法步骤的程序：获取待采油井的采油数据，所述采油数据至少包括油井生产气油比、油藏原始气油比、油藏地层压力、拟泡点压力、油井产油量、高峰产量、油样中泡沫占比；根据所述采油数据筛选泡沫油开发效果差的油井；根据所述采油数据对所述油井进行采油动作，所述采油动作包括注气、焖井和回抽；依次重复注气、焖井、回抽，直至该油井达到冷采极限产量，所述注气中的注气量随采油轮次的增加而增加。所述根据所述采油数据筛选泡沫油开发效果差的油井，包括：当油井生产气油比>所述油藏原始气油比*10，且油藏地层压力<拟泡点压力，且油井产油量<高峰产量的*20％，且油样中泡沫占比<泡沫占 比阈值，则该油井为泡沫油开发效果差的油井。该方法还包括：如果所述油井的邻井未达到冷采极限产量，则对该油井和邻井进行组合式注气吞吐；所述组合式注气吞吐为多口油井的采油动作同步进行。
本领域内的技术人员应明白，本申请的实施例可提供为方法、系统、或计算机程序产品。因此，本申请可采用完全硬件实施例、完全软件实施例、或结合软件和硬件方面的实施例的形式。而且，本申请可采用在一个或多个其中包含有计算机可用程序代码的计算机可用存储介质(包括但不限于磁盘存储器、CD-ROM、光学存储器等)上实施的计算机程序产品的形式。
本申请是参照根据本申请实施例的方法、设备(系统)、和计算机程序产品的流程图和/或方框图来描述的。应理解可由计算机程序指令实现流程图和/或方框图中的每一流程和/或方框、以及流程图和/或方框图中的流程和/或方框的结合。可提供这些计算机程序指令到通用计算机、专用计算机、嵌入式处理机或其他可编程数据处理设备的处理器以产生一个机器，使得通过计算机或其他可编程数据处理设备的处理器执行的指令产生用于实现在流程图一个流程或多个流程和/或方框图一个方框或多个方框中指定的功能的装置。
这些计算机程序指令也可存储在能引导计算机或其他可编程数据处理设备以特定方式工作的计算机可读存储器中，使得存储在该计算机可读存储器中的指令产生包括指令装置的制造品，该指令装置实现在流程图一个流程或多个流程和/或方框图一个方框或多个方框中指定的功能。
这些计算机程序指令也可装载到计算机或其他可编程数据处理设备上，使得在计算机或其他可编程设备上执行一系列操作步骤以产生计算机实现的处理，从而在计算机或其他可编程设备上执行的指令提供用于实现在流程图一个流程或多个流程和/或方框图一个方框或多个方框中指定的功能的步骤。
在一个典型的配置中，计算设备包括一个或多个处理器(CPU)、输入/输出接口、网络接口和内存。
存储器可能包括计算机可读介质中的非永久性存储器，随机存取存储器(RAM)和/或非易失性内存等形式，如只读存储器(ROM)或闪存(flash RAM)。存储器是计算机可读介质的示例。
计算机可读介质包括永久性和非永久性、可移动和非可移动媒体可以由任 何方法或技术来实现信息存储。信息可以是计算机可读指令、数据结构、程序的模块或其他数据。计算机的存储介质的例子包括，但不限于相变内存(PRAM)、静态随机存取存储器(SRAM)、动态随机存取存储器(DRAM)、其他类型的随机存取存储器(RAM)、只读存储器(ROM)、电可擦除可编程只读存储器(EEPROM)、快闪记忆体或其他内存技术、只读光盘只读存储器(CD-ROM)、数字多功能光盘(DVD)或其他光学存储、磁盒式磁带，磁带磁磁盘存储或其他磁性存储设备或任何其他非传输介质，可用于存储可以被计算设备访问的信息。按照本文中的界定，计算机可读介质不包括暂存电脑可读媒体(transitory media)，如调制的数据信号和载波。
还需要说明的是，术语“包括”、“包含”或者其任何其他变体意在涵盖非排他性的包含，从而使得包括一系列要素的过程、方法、商品或者设备不仅包括那些要素，而且还包括没有明确列出的其他要素，或者是还包括为这种过程、方法、商品或者设备所固有的要素。在没有更多限制的情况下，由语句“包括一个……”限定的要素，并不排除在包括要素的过程、方法、商品或者设备中还存在另外的相同要素。
以上仅为本申请的实施例而已，并不用于限制本申请。对于本领域技术人员来说，本申请可以有各种更改和变化。凡在本申请的精神和原理之内所作的任何修改、等同替换、改进等，均应包含在本申请的权利要求范围之内。

Claims (21)

  1. 一种提高泡沫油冷采采收率的方法，其特征在于，该方法包括以下步骤：
    S1：获取待采油井的采油数据，所述采油数据至少包括油井生产气油比、油藏原始气油比、油藏地层压力、拟泡点压力、油井产油量、高峰产量、油样中泡沫占比；
    S2：根据所述采油数据筛选泡沫油开发效果差的油井；
    S3：根据所述采油数据对所述油井进行采油动作，所述采油动作包括注气、焖井和回抽；
    S4：依次重复注气、焖井、回抽，直至该油井达到冷采极限产量，所述注气中的注气量随采油轮次的增加而增加。
  2. 根据权利要求1所述的方法，其特征在于，所述根据所述采油数据筛选泡沫油开发效果差的油井，包括：
    当油井生产气油比>所述油藏原始气油比*10，且油藏地层压力<拟泡点压力，且油井产油量<高峰产量的*20％，且油样中泡沫占比<泡沫占比阈值，则该油井为泡沫油开发效果差的油井。
  3. 根据权利要求1或2所述的方法，其特征在于，该方法还包括：
    如果所述油井的邻井未达到冷采极限产量，则对该油井和邻井进行组合式注气吞吐；所述组合式注气吞吐为多口油井的采油动作同步进行。
  4. 根据权利要求1-3中任意一项所述的方法，其特征在于，
    所述注气量为：
    其中，r为吞吐半径，
    L为水平井段生产长度，
    h为油层厚度，
    为油层的孔隙度，
    So为含油饱和度，
    R为地层条件下单位体积原油溶解气体体积，
    ρ为气体地面密度，
    A为注气量增加的幅度,n为采油轮次。
  5. 根据权利要求4所述的方法，其特征在于，
    所述注气量增加的幅度为5％-30％。
  6. 根据权利要求1-5中任意一项所述的方法，其特征在于，
    油藏的水平井的排距为吞吐半径的2倍。
  7. 根据权利要求1-6中任意一项所述的方法，其特征在于，
    注气吞吐最大轮次为6，最大轮次下的吞吐半径为最大吞吐半径。
  8. 根据权利要求1-7中任意一项所述的方法，其特征在于，
    所述焖井的时长与注气的性质、注入量、原油性质、地层温度及地层压力有关。
  9. 根据权利要求1-8中任意一项所述的方法，其特征在于，
    注气过程中，注气压力低于油井所处地层的破裂压力。
  10. 根据权利要求1-9中任意一项所述的方法，其特征在于，
    回抽过程中，采液速度为单井控制储量的1.0％-4.0％。
  11. 一种提高泡沫油冷采采收率的装置，其特征在于，该装置包括：
    获取模块，用于获取待采油井的采油数据，所述采油数据至少包括油井生产气油比、油藏原始气油比、油藏地层压力、拟泡点压力、油井产油量、高峰产量、油样中泡沫占比；
    筛选模块，用于根据所述采油数据筛选泡沫油开发效果差的油井；
    采油模块，用于根据所述采油数据对所述油井进行采油动作，所述采油动作包括注气、焖井和回抽；
    依次重复注气、焖井、回抽，直至该油井达到冷采极限产量，所述注气中的注气量随采油轮次的增加而增加。
  12. 根据权利要求11所述的装置，其特征在于，所述根据所述采油数据筛选泡沫油开发效果差的油井，包括：
    当油井生产气油比>所述油藏原始气油比*10，且油藏地层压力<拟泡点压力，且油井产油量<高峰产量的*20％，且油样中泡沫占比<泡沫占比阈值，则该油井为泡沫油开发效果差的油井。
  13. 根据权利要求11或12所述的装置，其特征在于，
    所述采油模块还用于如果所述油井的邻井未达到冷采极限产量，则对该油井和邻井进行组合式注气吞吐；
    所述组合式注气吞吐为多口油井的采油动作同步进行。
  14. 根据权利要求11-13中任意一项所述的装置，其特征在于，
    所述注气量为：
    其中，r为吞吐半径，
    L为水平井段生产长度，
    h为油层厚度，
    为油层的孔隙度，
    So为含油饱和度，
    R为地层条件下单位体积原油溶解气体体积，
    ρ为气体地面密度，
    A为注气量增加的幅度,n为采油轮次。
  15. 根据权利要求14所述的装置，其特征在于，
    所述注气量增加的幅度为5％-30％。
  16. 根据权利要求11-15中任意一项所述的装置，其特征在于，
    油藏水平井的排距为吞吐半径的2倍。
  17. 根据权利要求11-16中任意一项所述的装置，其特征在于，
    注气吞吐最大轮次为6，最大轮次下的吞吐半径为最大吞吐半径。
  18. 根据权利要求11-17中任意一项所述的装置，其特征在于，
    所述焖井的时长与注气的性质、注入量、原油性质、地层温度及地层压力有关。
  19. 根据权利要求11-18中任意一项所述的装置，其特征在于，
    注气过程中，注气压力低于油井所处地层的破裂压力。
  20. 根据权利要求11-19中任意一项所述的装置，其特征在于，
    回抽过程中，采液速度为单井控制储量的1.0％-4.0％。
  21. 一种机器可读存储介质，该机器可读存储介质上存储有指令，该指令用于使得机器执行上述权利要求1至10中任意一项所述的提高泡沫油冷采采收率的方法。
PCT/CN2023/124947 2023-06-26 2023-10-17 一种提高泡沫油冷采采收率的方法 Ceased WO2025000751A1 (zh)

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