CN113982546B - Evaluation method for carbon dioxide injection profile of horizontal well - Google Patents
Evaluation method for carbon dioxide injection profile of horizontal well Download PDFInfo
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- CN113982546B CN113982546B CN202111230311.3A CN202111230311A CN113982546B CN 113982546 B CN113982546 B CN 113982546B CN 202111230311 A CN202111230311 A CN 202111230311A CN 113982546 B CN113982546 B CN 113982546B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/164—Injecting CO2 or carbonated water
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21F—SAFETY DEVICES, TRANSPORT, FILLING-UP, RESCUE, VENTILATION, OR DRAINING IN OR OF MINES OR TUNNELS
- E21F17/00—Methods or devices for use in mines or tunnels, not covered elsewhere
- E21F17/16—Modification of mine passages or chambers for storage purposes, especially for liquids or gases
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
- Y02P90/70—Combining sequestration of CO2 and exploitation of hydrocarbons by injecting CO2 or carbonated water in oil wells
Abstract
The invention discloses a horizontal well carbon dioxide injection profile evaluation method, which comprises the following steps: (1) Determining an experimental core according to the reservoir permeability distribution of the horizontal well distribution and the frequency distribution proportion; (2) Supercritical CO implementation using core 2 Displacement experiment, drawing and researching the pressure difference-permeability-CO of reservoir stratum of block 2 Inflow charts; (3) Carrying out displacement experiment by using typical rock core saturated formation water of a research block, and drawing the permeability and CO of the block 2 Injecting a plate with multiple pore volumes; (4) Selective CO injection 2 Horizontal wells according to differential pressure-permeability-CO 2 Obtaining supercritical CO at injection pressure using an inflow correlation chart 2 Inflow amount; (5) According to block permeability and CO 2 Injecting a relation chart of pore volume multiple to obtain the permeability distribution of the horizontal section after reaction; (6) Circulating to obtain CO in reservoir sections with different permeability 2 Permeability after injection. The method is easy to implement, simple and convenient to operate and wide in application range, and horizontal well CO of different reservoir types is realized 2 Evaluation of the implantation profile.
Description
Technical Field
The invention belongs to the technical field of geological utilization and sequestration of carbon dioxide, and particularly relates to horizontal well carbon dioxide (CO) 2 ) Injection profile evaluation method applicable to horizontal well CO 2 Evaluation of injection effect and horizontal well CO 2 Injection trim for CO enhancement 2 Displacement efficiency and geological sealing quantity.
Background
With CO 2 The major increase in greenhouse gas emissions has brought about a series of global environmental problems, CO 2 Emission reduction becomes a hot issue of human concern. And the human cannot get rid of the use of fossil energy in a short time. Therefore, CO 2 Capture and geological sequestration (CCS) is one of the most feasible and effective means to achieve carbon neutralization targets. At present, CO 2 Geological sequestration places mainly include: depleted oil and gas reservoirs, unexplosive coal seams and deep brine aquifers.For CO 2 The problems of geological utilization and sequestration are solved, and scholars at home and abroad do a great deal of research work and think that CO is 2 The sealing and the storage in the reservoir stratum of the oil and gas reservoir both improve the recovery ratio of the oil and gas reservoir and reduce CO 2 Emissions are considered to be the most economically viable process.
The developed low-permeability oil reservoir mainly adopts water drive, but faces the problems of low single-well yield, high injection pressure, low injection capacity, difficult formation energy supplement, difficult establishment of an effective displacement system and the like, and the final recovery ratio is generally about 20 percent. CO compared to water flooding 2 The gas suction index can be improved by 5 times, the starting pressure is reduced by 50%, the injection capability is greatly improved, and the problems of no injection, no extraction, low oil extraction speed, low recovery ratio and the like in the water drive development of the low-permeability reservoir are effectively solved. Meanwhile, compared with a vertical well, the injection amount of water/gas injected into the horizontal well can be increased, so that the sweep efficiency is greatly improved, and lower injection pressure can be kept, so that the low-permeability reservoir is mostly developed by using the horizontal well at present. However, in China, most reservoirs of low-permeability reservoirs are land-phase deposits, the interlayer and in-layer heterogeneity is severe, and CO injected by horizontal wells 2 The failure cycle is easily formed by premature breakthrough along the high permeable layer, and the CO is seriously influenced 2 Greatly reduces CO by affecting the volume 2 Oil displacement final recovery ratio and geological storage. Therefore, horizontal well CO was evaluated effectively 2 The injection effect is a necessary condition for realizing injection-production adjustment optimization and realizing efficient oil displacement and geological sequestration. For horizontal well carbon dioxide injection profile, due to CO 2 The corrosion of the horizontal well and the complex conditions of deformation of the well shaft, reduction of the well diameter and the like possibly occur in the long-term production of the well shaft, and the conventional production logging technology and equipment cannot monitor the CO of the horizontal well for a long time 2 The profile of the implant. CO prediction using numerical simulation and semi-analytic model 2 The injection profile is based on a large amount of basic data, but some of the data required to build the model is missing, and even if the CO is available 2 The implant profile also cannot be determined to be reasonable. On the other hand, low permeability reservoir horizontal well CO 2 The method for controlling the injection profile is not reported. The method needs to find a low-permeability reservoir horizontal well CO 2 Evaluation of injection Profile EffectMethod for guiding CO of horizontal well 2 And (5) adjusting and optimizing injection and production. Therefore, the method is beneficial to breaking through the CO of the horizontal well with the low-permeability reservoir 2 The bottleneck of injection profile regulation theory and technology has important scientific significance and wide production application prospect.
Therefore, aiming at the low permeability reservoir in China with strong heterogeneity, the horizontal well injects CO 2 The method is easy to break through in a high-permeability reservoir, and an injection and production well forms an ineffective cycle, so that the major bottleneck problems that the low-permeability reservoir is difficult to use and the like are caused. The key of the invention is to clear the horizontal well CO of the heterogeneous reservoir 2 The core technology of the injection profile is that the CO of a horizontal well with a heterogeneous reservoir is realized by an experimental method 2 Injecting profile, adjusting injection and production profile, and realizing heterogeneous reservoir horizontal well CO 2 Balanced injection and CO delay 2 The reserves of the hypotonic fraction are mobilized at the breakthrough time of the highly permeable reservoir.
Disclosure of Invention
Aiming at the problems, the defects in the prior art are overcome, and the invention aims to provide a horizontal well carbon dioxide (CO) based on indoor experiments 2 ) The injection profile evaluation method is easy to implement, simple and convenient to operate and wide in application range, and realizes the purpose of horizontal well carbon dioxide (CO) of different reservoir types 2 ) Evaluation of the implantation profile.
In order to achieve the purpose, the invention adopts the following technical measures:
horizontal well carbon dioxide (CO) based on indoor experiment 2 ) The injection profile evaluation method comprises the following steps:
(1) Determining the permeability distribution of a reservoir distributed along a horizontal well according to logging data, performing frequency distribution according to the permeability, and determining an experimental core in proportion;
(2) Supercritical carbon dioxide (CO) treatment with well-defined core (unsaturated formation water) 2 ) Displacement experiment to obtain supercritical CO of rock cores with different permeabilities under different pressure differences 2 The injection amount is measured, and the pressure difference-permeability-carbon dioxide (CO) of the reservoir in the research block is drawn through the displacement experiment result 2 ) Inflow relation chart; in the step, in order to realize the rationality of experimental simulation, theIn the injection of carbon dioxide (CO) 2 ) And carrying out equivalent treatment on the displacement experiment parameters by using a similar criterion. If the permeability exceeds the permeability of the experimental core in the step, the permeability and carbon dioxide (CO) can be obtained by fitting a curve under a given experimental pressure difference 2 ) The relationship of inflow, and finally the carbon dioxide (CO) at the permeability 2 ) The inflow amount.
(3) Saturating formation water by using a typical core of a research block, and then carrying out a displacement experiment to obtain carbon dioxide (CO) in the experimental process 2 ) Injecting a relationship between pore volume and permeability, and plotting the permeability and carbon dioxide (CO) for the block 2 ) Injecting a relation chart of pore volume multiples; the hypothetical carbon dioxide (CO) described in this step 2 ) The inflow time is a calculation unit (any value between 5 hours and 50 hours, and the specific time is determined according to the actual injection conditions and the existing logging profile), and carbon dioxide (CO) is in the period 2 ) The permeability of the rock core does not change during injection, and the permeability changes once after the period of time. Wherein, the time for calculating the time unit can inject carbon dioxide (CO) according to different horizontal wells 2 ) The conditions are adjusted.
(4) Selecting injected carbon dioxide (CO) 2 ) The horizontal well is used for obtaining the permeability distribution of the reservoir distributed along the horizontal well through logging information and obtaining the supercritical carbon dioxide (CO) of each section under the injection pressure according to the step (2) 2 ) The inflow amount. Assuming carbon dioxide (CO) 2 ) Inflow 5 hours is a unit of calculation (can be adjusted accordingly), during which carbon dioxide (CO) is present 2 ) The permeability of the rock core is not changed during injection, and the permeability is changed once after 5 hours. Calculating carbon dioxide (CO) during the period 2 ) Inflow and carbon dioxide (CO) 2 ) The occupied pore volume multiple;
(5) Utilizing the obtained carbon dioxide (CO) 2 ) Injecting the volume multiple, and obtaining carbon dioxide (CO) through the chart of the step (4) 2 ) Permeability of the horizontal section after 5 hours of injection, assuming carbon dioxide (CO) injected into the core at the time of the experiment 2 ) Pore volume multiple and injection of carbon dioxide (CO) into the reservoir 2 ) Pore of (2)The permeability changes the same when the volume multiples are the same, that is, if the permeability of the core and the reservoir is the same, carbon dioxide (CO) with the same volume multiple is injected 2 ) The same permeability was obtained.
(6) The step (4) and the step (5) are respectively circulated for 6 times (12 times in total) according to carbon dioxide (CO) 2 ) The injection time determines the times of circulation, and carbon dioxide (CO) of reservoir sections with different permeabilities of the horizontal well is obtained 2 ) The amount of injection and the permeability after injection.
Further, the core unsaturated formation water in the step (2) is used for carbon dioxide (CO) 2 ) No carbon dioxide (CO) is generated in the displacement process 2 ) Formation water-core reaction, obtaining injection pressure-carbon dioxide (CO) 2 ) The relationship between influx-permeability;
further, the core of step (3) is used for saturating the formation water in carbon dioxide (CO) 2 )CO 2 Formation water core reaction during displacement to obtain carbon dioxide (CO) 2 ) The relationship between influx (injected pore volume) and permeability.
Further, for sandstone oil and gas reservoirs, if the mineral composition of the reservoir is carbon dioxide (CO) 2 ) The mineral from which the weak acid solution formed reacts, is then in carbon dioxide (CO) 2 ) The change of permeability can be not considered in the inflow process, and the pressure difference-permeability-carbon dioxide (CO) of the reservoir of the research block formed by the steps (1) and (2) of the scheme 2 ) And (4) utilizing a chart of inflow relation to directly determine the injection profile of the horizontal well.
The key technology of the invention is a horizontal well CO2 injection profile evaluation method based on indoor experiments, which realizes a CO2 injection profile of a horizontal well of a heterogeneous reservoir through an experimental method, adjusts an injection and production profile, realizes CO2 balanced injection of the horizontal well of the heterogeneous reservoir, delays breakthrough time of a high-permeability reservoir during CO2, and effectively utilizes the reserve volume of the heterogeneous oil and gas reservoir or realizes efficient sealing of the heterogeneous salty water layer. The method solves the problems that the conventional production logging technology and equipment cannot monitor the CO2 injection profile of the horizontal well for a long time due to the corrosivity of CO2 and the complex conditions that the shaft is deformed and the hole diameter is reduced possibly in the long-term production of the shaft.
Compared with the prior art, the invention has the following advantages and effects:
1. the invention provides horizontal well CO based on indoor experiments 2 The injection profile evaluation method realizes the CO of the horizontal well with the heterogeneous reservoir 2 Compared with the existing method, the quantitative characterization of the injection profile can study the CO of the horizontal well in more detail 2 The injection-production section mechanism is CO 2 And a basis is provided by multiphase seepage theory and mechanism in a heterogeneous oil and gas reservoir.
2. According to the evaluation method for the horizontal well carbon dioxide injection profile, the pressure difference-permeability-CO of a reservoir stratum of a research block is drawn according to the displacement experiment result 2 Inflow dependence chart and permeability vs. CO 2 The relation chart of the injection pore volume multiple is combined with the similarity criterion to realize the CO of the horizontal well 2 Quantitative characterization of injection profile, evaluation of horizontal well CO 2 Injection effect to realize high efficiency CO 2 Compared with other methods, the method can be applied to prediction of the horizontal well injection profile of one region, and cost of horizontal well injection profile testing is reduced.
3. The invention is not only suitable for the CO of the horizontal well 2 Injection profile prediction, and can also be used for CO 2 Evaluating the injection effect, thereby realizing the CO of the horizontal well 2 Optimized design of injection profile to achieve efficient CO 2 Displacement and geological sequestration are helpful for breaking through low permeability reservoir horizontal well CO 2 The bottleneck of injection profile regulation theory and technology has important scientific significance and wide production application prospect.
4. According to the technical scheme, the horizontal well CO2 injection profile can be obtained through an experimental method, the method is easy to implement and simple and convenient to operate, and compared with production logging, the cost for obtaining the horizontal well injection profile is greatly reduced. Meanwhile, the invention has wider application range, and can also solve the problems that some well conditions are complicated and the injection profile test of the horizontal well cannot be carried out.
Drawings
FIG. 1 shows a horizontal well C based on indoor experimentsO 2 Injection differential pressure-permeability-CO of injection profile evaluation method 2 Schematic diagram of injection quantity relation.
Fig. 2 is a block schematic diagram of an evaluation method of a horizontal well carbon dioxide injection profile based on an indoor experiment.
FIG. 3 shows horizontal well CO based on indoor experiment 2 CO injection for injection profile evaluation method 2 Pore volume times and dimensionless permeability are plotted.
FIG. 4 shows a horizontal well CO based on indoor experiments 2 And (3) a horizontal well permeability distribution schematic diagram of the injection profile evaluation method.
FIG. 5 shows horizontal well CO based on indoor experiment 2 CO of injection profile evaluation method 2 And the permeability change distributed along the horizontal well section in the injection process is shown schematically.
FIG. 6 shows horizontal well CO based on indoor experiment 2 CO of injection profile evaluation method 2 CO injection into sections of horizontal well 2 The injection quantity change process is shown schematically.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
Example 1:
as can be seen from fig. 2, the method for evaluating the carbon dioxide injection profile of the horizontal well comprises the following steps:
(1) Determining the permeability distribution of a reservoir distributed along a horizontal well according to logging data, performing frequency distribution according to the permeability, and determining an experimental core in proportion;
(2) Supercritical carbon dioxide (CO) with well-defined core (unsaturated formation water) 2 ) Performing a displacement experiment to obtain supercritical carbon dioxide (C) of rock cores with different permeabilities under different pressure differencesO 2 ) The injection amount;
(3) Drawing and researching differential pressure-permeability-CO of reservoir stratum of block through displacement experiment result 2 Inflow relation chart;
(4) For carbon dioxide (CO) injection 2 ) In order to realize the rationality of the experimental simulation in the step, the displacement experimental parameters are equivalently processed by using a similarity criterion. If the permeability exceeds the permeability of the experimental core in the step, the permeability and carbon dioxide (CO) can be obtained by fitting a curve under a given experimental pressure difference 2 ) The relationship of inflow, finally obtaining the carbon dioxide (CO) under the permeability 2 ) An inflow amount;
(5) Saturating formation water by using a typical core of a research block;
(6) Carrying out displacement experiment by using rock core of saturated formation water to obtain carbon dioxide (CO) in the experimental process 2 ) Injecting a relationship between pore volume and permeability;
(7) Plotting the block permeability and carbon dioxide (CO) 2 ) Injecting a relation chart of pore volume multiples; the hypothetical carbon dioxide (CO) described in this step 2 ) Flowing into a certain time as a calculation unit, during which carbon dioxide (CO) is present 2 ) The permeability of the rock core does not change during injection, and the permeability changes once after the period of time. Wherein, the time of calculating the time unit can inject carbon dioxide (CO) according to different horizontal wells 2 ) The conditions are adjusted.
(8) Selecting injected carbon dioxide (CO) 2 ) A horizontal well, wherein the reservoir permeability distribution distributed along the horizontal well is obtained through logging information, and the supercritical carbon dioxide (CO) of each section under the injection pressure obtained in the step (2) 2 ) The inflow amount. Assuming carbon dioxide (CO) 2 ) Inflow 5 hours as a unit of calculation (which can be adjusted accordingly), during which CO 2 The permeability of the rock core does not change during injection, and carbon dioxide (CO) does not change 2 ) The permeability changed once after 5 hours of inflow. Calculating carbon dioxide (CO) during the period 2 ) Inflow and carbon dioxide (CO) 2 ) The occupied pore volume multiple; utilizing the obtained carbon dioxide (CO) 2 ) Note thatObtaining carbon dioxide (CO) by the plate in the step (4) according to the volume multiple 2 ) Permeability of the horizontal section after 5 hours of injection, assuming carbon dioxide (CO) injected into the core at the time of the experiment 2 ) Pore volume multiple and injection of carbon dioxide (CO) into the reservoir 2 ) The permeability changes the same when the pore volume factor of (a) is the same, that is, if the permeability of the core and the reservoir is the same, carbon dioxide (CO) is injected in the same volume factor 2 ) When the permeability was the same.
(9) The step (4) and the step (5) are respectively circulated for 6 times according to carbon dioxide (CO) 2 ) The injection time determines the number of times of circulation;
(10) Utilizing the circulating result to obtain the final carbon dioxide (CO) of reservoir sections with different permeabilities of the horizontal well 2 ) The amount of injection and the permeability after injection.
In step (2), in order to realize the reasonability of experimental simulation, carbon dioxide (CO) injection is carried out 2 ) The displacement experiment parameters are equivalently processed by utilizing the similarity criterion of the horizontal well. The treatment process comprises the following steps:
when carbon dioxide (CO) is carried out 2 ) During the displacement experiment, the flow velocity of fluid at the inlet end of the rock core is as follows:
in the formula: v. of rs The speed of fluid at the inlet end of the rock core is m/s; k is the average formation permeability, 10 -3 μm 2 (ii) a Mu is gas viscosity, mPa & s; p is the pressure of any point of the reservoir, MPa; l is the length of the experimental rock core, m; p is a radical of w1 The pressure at the inlet end of the rock core holder is MPa; p is a radical of formula e The pressure at the outlet end of the rock core holder is MPa; d represents a differential sign.
Injection of carbon dioxide (CO) 2 ) The well bore end fluid flow rate is:
in the formula: v. of rs The velocity of the fluid at the end of the reservoir well casing is m/s; p is a radical of w2 The bottom hole pressure during acid injection is MPa; r is the well control radius, m; r is a radical of hydrogen e Is the drainage radius, m; r is a radical of hydrogen w Is the wellbore diameter, m; k is reservoir permeability, mD; p is reservoir pressure, MPa; μ is fluid viscosity, mpa.s; ln represents the natural logarithm.
Assuming carbon dioxide (CO) 2 ) The flow velocity of the inlet end in the displacement experiment is equal to that of the injection end of the horizontal well shaft, and then CO is obtained 2 The inlet end pressure at the displacement experiment was expressed as:
in the formula: l is the length of the experimental rock core, m; p is a radical of w1 The pressure at the inlet end of the core holder is MPa; p is a radical of formula e The pressure at the outlet end of the core holder is MPa.
Further, if the permeability exceeds the permeability of the experimental core in the step (2), the permeability and carbon dioxide (CO) can be obtained by fitting a curve at a given experimental pressure difference 2 ) The relationship of inflow, finally obtaining the carbon dioxide (CO) under the permeability 2 ) The inflow amount. For example, assume a horizontal interval of 20X 10 -3 μm 2 The permeability of (2) is 3.5MPa, and the relationship between the liquid absorption amount and the permeability under the fitting experiment differential pressure of 3.5MPa (figure 1) is y =0.12x +0.83, wherein x is the permeability and y is carbon dioxide (CO) 2 ) The inflow amount. Permeability of 20X 10 -3 μm 2 Substituting into the relational expression to obtain carbon dioxide (CO) at the permeability 2 ) The inflow was 12.4mL/min.
It is to be noted that carbon dioxide (CO) is assumed 2 ) Inflow 5 hours is a unit of calculation (can be adjusted accordingly), during which carbon dioxide (CO) is present 2 ) The permeability of the rock core is not changed during injection, and the permeability is changed once after 5 hours. The time of calculating the time unit can be injected with carbon dioxide (CO) according to different horizontal wells 2 ) Adjusting the conditions to the actual gas production profile test waterThe standard is that the horizontal well is consistent.
Further, the core unsaturated formation water in the step (2) is used for carbon dioxide (CO) 2 ) No carbon dioxide (CO) generation during the displacement process 2 ) Formation water-core reaction, obtaining injection pressure-carbon dioxide (CO) 2 ) The relationship between influx-permeability; the core of the step (3) is used for saturating the formation water in carbon dioxide (CO) 2 ) Carbon dioxide (CO) generation during displacement 2 ) Formation water-core reaction, obtaining carbon dioxide (CO) 2 ) The relationship between influx (injected pore volume) and permeability.
Further, for sandstone reservoirs, if the reservoir mineral composition is not carbon dioxide (CO) 2 ) The mineral formed in the weak acid solution reacts, then in carbon dioxide (CO) 2 ) The change of permeability can be not considered in the inflow process, and the pressure difference-permeability-carbon dioxide (CO) of the reservoir of the research block formed by the steps (1) and (2) of the scheme 2 ) And (4) an inflow relation chart, and directly determining the horizontal well injection section by using the chart.
By the specific embodiment, horizontal well CO can be obtained 2 The quantitative characterization of the injection profile realizes the CO of the horizontal well with the heterogeneous reservoir 2 Evaluation of injection profile effect, and heterogeneous reservoir horizontal well CO 2 Injection profile prediction, thereby realizing horizontal well CO 2 Optimized design of injection profile to achieve efficient CO 2 Displacement and geological sequestration are helpful for breaking through low permeability reservoir horizontal well CO 2 The bottleneck of injection profile control theory and technology has important scientific significance and wide production application prospect.
Example 2:
to inject CO 2 Horizontal well CO for displacement exploitation of an oil field 2 An implant profile comprising the steps of:
(1) Supposing that the interval of the permeability is 0.2-252mD according to the well completion logging data of the horizontal well drilled in the oil field, and then obtaining the permeability of the core to be tested, which is 0.2mD, 4mD, 8mD, 12mD, 16mD, 20mD, 24mD, 28mD … mD, according to the permeability grade difference of the drilled well;
(2) Performing supercritical CO by using the rock core determined in the step (1) 2 Displacement experiment, assuming that the obtained experiment result is used to obtain the differential pressure-permeability-CO of the reservoir stratum of the block 2 Inflow relationship chart, as shown in FIG. 1;
(3) Saturating formation water by using a typical rock core of the block, and then performing a displacement experiment to obtain CO in the experimental process 2 Injecting the relationship between pore volume and permeability, and plotting the permeability and CO in the block 2 A graphical version of the relationship between pore volume fold injection, as shown in FIG. 3;
(4) Taking a horizontal well of a certain oil field as an example, assuming that the permeability distribution along the horizontal well is as shown in a horizontal well permeability distribution diagram of fig. 4, the initial inflow distribution is determined according to fig. 1. With CO 2 Inflow of 20 hours as a unit of calculation (which can be adjusted accordingly), during which CO 2 The permeability of the core did not change during injection, and once after 20 hours, the permeability changed, as shown in fig. 3.
(5) Assuming that the injection time of the horizontal well is 240 hours, the step (4) is cycled according to CO 2 The injection time determines that the times of circulation are 12 times, and the CO of reservoir sections with different permeabilities of the horizontal well are obtained 2 Determining the change process of the injection amount and the permeability after injection to determine the CO of the horizontal well 2 The injection amount of each section of the cross section is shown in FIG. 5CO 2 The permeability changes along the horizontal interval during injection are shown schematically, CO 2 Permeability after injection as shown in FIG. 6CO 2 The variation process of the CO2 injection amount of each section of the horizontal well section in the injection process is shown in a schematic diagram.
The other steps were the same as in example 1.
Through the specific embodiment, the heterogeneous reservoir horizontal well CO can be obtained 2 Injection profile to realize horizontal well CO 2 Optimized design of injection profile to achieve efficient CO 2 Displacing and delaying CO injection of horizontal well 2 Breakthrough time of time-high permeability reservoir, and realization of CO injection and production well 2 The effective circulation of the method effectively utilizes a low-permeability reservoir, and solves the problem of heterogeneous reservoir CO 2 The main bottleneck of oil displacement.
Claims (4)
1. A horizontal well carbon dioxide injection profile evaluation method based on indoor experiments comprises the following steps:
(1) Determining the permeability distribution of a reservoir distributed along a horizontal well according to logging data, performing frequency distribution according to the permeability, and determining an experimental core in proportion;
(2) Supercritical CO with defined core 2 Displacement experiment to obtain supercritical CO of rock cores with different permeabilities under different pressure differences 2 The injection amount, the differential pressure-permeability-CO of reservoir stratum of research block is drawn through the displacement experiment result 2 Inflow relation chart;
(3) Saturating formation water by using a typical rock core of a research block, and then carrying out a displacement experiment to obtain CO in the experimental process 2 The relation between the injected pore volume and the permeability is drawn to draw the permeability and the CO of the block 2 Injecting a relation chart of pore volume multiples; CO2 2 Flowing in for a certain time as a calculation unit, during which CO 2 The permeability of the rock core does not change during injection, and the permeability changes once after the period of time, wherein the time for calculating the time unit is based on the CO injection of different horizontal wells 2 Adjusting conditions;
(4) Selective CO injection 2 A horizontal well, the permeability distribution of the reservoir distributed along the horizontal well is obtained through logging information, and the supercritical CO of each section under the injection pressure is obtained according to the step (2) 2 Inflow of CO 2 Inflow 5 hours as a calculation unit, period CO 2 The permeability of the rock core is not changed during injection, the permeability is changed once after 5 hours, and CO in the period is calculated 2 Inflow and CO 2 The occupied pore volume multiple;
(5) Using the obtained CO 2 Injecting pore volume times to obtain CO through the chart of the step (3) 2 Permeability of horizontal section after injection for 5 hours, and CO injected into rock core during experiment 2 Pore volume multiple and in-reservoir CO injection 2 The pore volume multiples are the same, the change of permeability is the same, the permeability of a rock core and the permeability of a reservoir layer are the same, and CO with the same volume multiple is injected 2 Then, getThe permeability to the same;
(6) The step (4) and the step (5) are respectively circulated for 6 times according to CO 2 The injection time determines the circulation times to obtain the CO of the reservoir sections with different permeabilities of the horizontal well 2 The amount of injection and the permeability after injection.
2. The horizontal well carbon dioxide injection profile evaluation method based on the indoor experiment is characterized by comprising the following steps of: the unsaturated formation water of the core in the step (2) is in CO 2 CO does not occur in the displacement process 2 Formation water-core reaction to obtain differential pressure-permeability-CO 2 The relationship between the inflow amounts.
3. The horizontal well carbon dioxide injection profile evaluation method based on the indoor experiment is characterized by comprising the following steps of: the core in the step (3) is used for saturating the formation water in CO 2 CO generation during displacement 2 Formation water-core reaction to obtain CO 2 The relationship between the inflow and the permeability.
4. The horizontal well carbon dioxide injection profile evaluation method based on the indoor experiment is characterized by comprising the following steps of: for sandstone oil and gas reservoirs, if the mineral composition of the reservoir is a mineral which does not react with the weak acid solution formed by the carbon dioxide, the change of permeability can be not considered in the carbon dioxide inflow process, and the pressure difference-permeability-CO of the reservoir of the research block formed by the step (1) and the step (2) 2 And (4) an inflow relation chart, and directly determining the horizontal well injection section by using the chart.
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| CN115902160B (en) * | 2022-11-28 | 2024-04-09 | 新疆敦华绿碳技术股份有限公司 | Evaluation of CO in brine layer geology 2 Method for storing potential |
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