CN115961923A - Deep profile control and flooding method for fractured reservoir - Google Patents
Deep profile control and flooding method for fractured reservoir Download PDFInfo
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Abstract
The invention provides a deep profile control and flooding method for a fractured reservoir, which comprises the following steps: judging the development characteristics of reservoir seams among injection wells and production wells by using the propulsion speed of a tracer; (II) selecting a profile control agent according to the development characteristics of the reservoir pore gaps among the injection and production wells, and determining the dosage of the profile control agent; and (III) performing profile control and flooding on the fractured reservoir. The method for controlling and driving the deep part of the fractured reservoir has the advantages of high maturity, good accuracy, quantitative analysis of development characteristics of stratum fractures and the like, so that a calculation result is more fit with the real condition of the reservoir, the production absorption profile can be effectively improved, the swept volume can be enlarged, the macroscopic swept range and the microscopic oil displacement efficiency can be improved, the scientific and efficient design of the dosage of the control and driving agent of the fractured carbonate reservoir is realized for the first time, and the method has important practical significance for guiding field control and driving operation.
Description
Technical Field
The invention belongs to the technical field of oil exploitation, and relates to an oil reservoir profile control and flooding method, in particular to a fractured reservoir deep profile control and flooding method.
Background
For a fractured reservoir, because the permeability distribution difference is large, injected water or bottom water flows along a high-permeability fracture, a fracture system with high water saturation and a matrix system with high oil saturation coexist in an interweaving mode in the later stage of water flooding, a large amount of residual oil in a matrix rock block cannot be extracted, an oil well quickly sees water and quickly reaches high water content, and the reservoir development faces a severe situation that the oil well is subjected to violent flooding and the yield is quickly reduced. Particularly, the internal dominant channel of the fractured carbonate reservoir develops, the water channeling is serious, the injected water is circulated inefficiently or inefficiently, and the utilization rate of the injected water is low. It is therefore necessary to characterize the development of channels within a reservoir.
CN 105631078A discloses a numerical simulation method of a natural fractured reservoir adaptive medium, the numerical simulation method comprising: determining an oil reservoir numerical simulation research area according to research needs, and establishing a boundary track file of the research area; forming crack information files with different scales according to geological conditions; classifying the cracks in the boundary range of the simulation area; classifying the grid cells; establishing an oil reservoir numerical simulation static model based on the obtained grid cells; obtaining various grid cell attributes, and establishing an oil reservoir simulation model based on the grid cell attributes. The method determines the development characteristics of the internal channel of the oil reservoir in a numerical simulation mode, but the numerical simulation method has high requirement on model precision, and the history fitting consumes a lot of time, so that the method is not suitable for actual work.
Aiming at fractured reservoirs, the plugging adjusting technology is an important means for improving the water drive effect, namely, the plugging of the water flow dominant channel by injecting chemical agents can play a role in adjusting the liquid production profile, relieving the internal contradiction of the reservoir and improving the oil field development effect. Therefore, the reasonable design of the plugging regulating method and the dosage of the chemical agents is very important for achieving the optimal development effect.
The existing plugging regulation technology is widely applied to oil field development, but the carbonate reservoir plugging regulation technology is not mature enough, the adopted process and the selected medicament are single, and the purpose of graded regulation is difficult to realize. Meanwhile, the design method of the dosage of the profile control and flooding agent mainly comprises the following steps: the method comprises the steps of firstly, adopting a profile control and flooding radius method, namely, assuming that a profile control and flooding stratum is a homogeneous stratum, and calculating the dosage of a medicament according to a set profile control and flooding radius, wherein the method does not consider the characteristics of an actual stratum, so that the uncertainty is large; secondly, a numerical simulation calculation method has high requirements on model precision and consumes a large amount of time for history fitting; thirdly, a medicament dosage design method based on PI (Pressure Index) and RE (Reservoir Engineering) decision technology needs on-site test injection to determine a dosage coefficient; fourthly, a front and back water absorption capacity ratio method, the ratio of the water absorption capacities before and after the treatment of the profile control layer section needs to be determined in advance, the workload is large, and the flexibility is poor.
CN111963100A discloses a method for plugging water in a fractured reservoir, comprising the following steps: firstly, preparing a water plugging agent; secondly, determining the dosage of the water shutoff agent, the injection speed, the injection pressure and the injection slug; and thirdly, plugging water in the target oil reservoir. The dosage of the water shutoff agent is determined by adopting an empirical formula and a volume formula method, and the average value of the calculation results according to the empirical formula and the volume formula method is used as the dosage of the water shutoff agent. The method determines the dosage of the water shutoff agent through an empirical formula, and the phenomenon that the dosage does not accord with the actual situation exists, so that the method can be only used for data research mostly and has difference with the actual situation, and cannot be applied to the technical field of actual oil exploitation.
CN 102052067A discloses an isobaric gradient step-by-step deep profile control and flooding method, which comprises screening suitable profile control and flooding agents according to the actual conditions of an experimental block, and determining the breakthrough pressure gradients of profile control and flooding agents with different formulas; carrying out hierarchical division according to a stratum pressure drop curve, dividing the stratum into a near wellbore zone, a far wellbore zone and a stratum deep part, wherein the pressure gradient of each zone is different, so that slugs with different strengths are required; screening the formula of each slug according to an isobaric pressure drop gradient principle that the breakthrough pressure gradient of the profile control agent is equal to the formation pressure gradient, and combining the profile control slugs; the slug combination is optimized according to cost. The method divides areas according to a stratum pressure drop curve, and the development condition of an internal channel of an oil reservoir cannot be reflected, so that the profile control agent cannot be adjusted according to the development condition of the channel, the low-efficiency or ineffective circulation of injected water can be caused, and the exploitation of petroleum can be influenced.
Therefore, determining the development conditions of internal channels and determining the use types and the use amounts of profile control and flooding agents for oil reservoirs with complex development conditions of the internal channels is one of the problems to be solved in the field.
Disclosure of Invention
The invention aims to provide a deep profile control and flooding method for a fractured reservoir, which judges the development characteristics of reservoir seams among injection and production wells by using the propulsion speed of a tracer, selects a proper profile control and flooding agent according to the development characteristics and determines the dosage of the profile control and flooding agent. The method can determine the development characteristics of the deep part of the fractured reservoir, determine the type and the dosage of the profile control and flooding agent according to the actual development condition, and has stronger pertinence of the calculation result and longer validity period.
In order to achieve the purpose, the invention adopts the following technical scheme:
the invention provides a deep profile control and flooding method for a fractured reservoir, which comprises the following steps:
judging the development characteristics of reservoir seams among injection wells and production wells by using the propulsion speed of a tracer;
(II) selecting a profile control agent according to the development characteristics of the reservoir pore gaps among the injection and production wells, and determining the dosage of the profile control agent;
(III) performing profile control and flooding on the fractured reservoir.
The method of the invention describes the formation development characteristics by using the dynamic monitoring result of the chemical tracer, the method is accurate and good, and the development characteristics of the formation fractures are quantitatively analyzed, so that the calculation result is more suitable for the real condition of the oil reservoir. The method has stronger pertinence and longer aging period.
Preferably, the development characteristics of the reservoir pore gaps among the injection wells in step (i) include any one of or a combination of at least two of large-scale medium gaps, medium-scale medium gaps or micro-scale medium gaps, for example, the development characteristics may be a combination of large-scale medium gaps and medium-scale medium gaps, a combination of large-scale medium gaps and scale medium gaps, a combination of medium-scale medium gaps and micro-scale medium gaps, or a combination of large-scale medium gaps, medium-scale medium gaps and micro-scale medium gaps.
Preferably, the advancing speed of the tracer in the large-scale medium fracture is more than 90m/d, such as 91m/d, 92m/d, 93m/d, 94m/d, 95m/d, 96m/d, 97m/d, 98m/d, 99m/d or 100m/d, but is not limited to the enumerated values, and other unrecited values in the numerical range are also applicable.
Preferably, the rate of advancement of the tracer in the mesoscale fractures is from 30 to 90m/d, and may be, for example, 30m/d, 40m/d, 50m/d, 60m/d, 70m/d, 80m/d or 90m/d, but is not limited to the recited values, and other values not recited in the numerical ranges are equally applicable.
Preferably, the advancing speed of the tracer in the micro-scale medium fracture is less than 30m/d, for example 29m/d, 25m/d, 20m/d, 18m/d, 16m/d, 14m/d, 10m/d, 8m/d, 6m/d or 4m/d, but is not limited to the values listed, and other values not listed in the range of values are also applicable.
The propulsion speed v of the tracer according to the invention f The calculation formula is as follows: v. of f ＝d/t，
In the formula, d is the linear distance between oil-water wells, and t is the time for the tracer to be seen in the injection well and the production well.
Preferably, the profile control agent adopted by the large-scale medium fracture comprises a low-molecular strong gel slug.
The low molecular weight strong gel slug is compounded by 4.5-5wt% of hydroxyethyl propylene, 3-4wt% of carboxyl-hydroxyl starch, 0.1-0.5wt% of ultra-short fiber and other auxiliary agents.
The low molecular weight strong gel system slug of the present invention is a viscous fluid, the viscosity of which is equivalent to 0.10% of HPAM solution, easy to inject and easy to transport in deep parts; the low-molecular strong gel system has good salt resistance and dilution resistance, and the curing behavior is less influenced by a medium; the low-molecular strong gel system has higher strength after being cured, and the pressure bearing capacity of the low-molecular strong gel system can reach 8-10MPa/m; the strength of the low-molecular strong gel system after curing can be adjusted and released.
Preferably, the profile control agent adopted by the mesoscale medium fracture comprises a nano-polymer microsphere slug.
The nano polymer microsphere slug comprises an organic polymer and an inorganic polymer, wherein the organic polymer is generally polyacrylamide.
The nano polymer microsphere has the following advantages: (1) microscopically, the nano polymer microspheres are retained after entering pores, so that the molecular acting force of a liquid-solid interface is stronger, the starting pressure is higher, and the permeability is reduced; (2) macroscopically: the specific surface area in the reservoir is increased, and the permeability is reduced; (3) can slowly expand 2-3 times under the condition of high mineralization degree (10 x 104 mg/L); (4) the particle size and the expansion time of the nano polymer microspheres are controllable: the primary particle size is nano-sized or micro-sized, the expansion time is adjustable, and the primary particle size can be injected into a stratum; the microspheres have strength, and after expansion, the pore throats can be plugged directly or through a plurality of bridges, so that the stratum can be plugged; the microspheres have elasticity, can break through migration for multiple times, are shear-resistant, have long service life and can move in the stratum; (5) in the injection mode, the nano polymer microspheres can be injected on line, can be injected in a single well, and can also be injected in a block centralized manner.
Preferably, the modifying and driving agent adopted by the micro-scale medium fracture is a wettability modifier slug.
The wettability modifier slug is a nano emulsion substance, and aims to change the wettability of reservoir rock.
The wettability modifier can change oil humidity of an oil reservoir into strong hydrophilicity, and improves the matrix utilization capacity; the wettability modifier can be injected into rock pores strongly adsorbed by water in the cracks under the action of pressure gradient, and is uniformly promoted to delay water channeling; the wettability modifier dialyzes water into the matrix in the capillary under the action of capillary forces.
Preferably, the dosage Q of the profile control agent in the large-scale medium fracture 1 The calculation formula of (2) is as follows:
Q 1 ＝q d t d +∑(qD′ j )t d
in the formula, q d Injection water distribution, qD, for large scale medium fracture injection and production wells j ' is the sum of the distribution amount of injected water of the medium-scale medium fracture injection and production well and the micro-scale medium fracture injection and production well, t d The injection time of the profile control agent in the large-scale medium fracture injection and production well is set.
Preferably, the injection water distribution q of the large-scale medium fracture injection and production well d The calculation formula of (2) is as follows:
q d ＝qD′ d
wherein q is the water injection amount of the water injection well, D' d And (4) injecting a real distribution coefficient of water into the large-scale medium fracture injection and production well.
Preferably, the calculation formula of the real distribution coefficient D' is:
in the formula, m ip The total amount of the tracer on the injection and production wells which is any corresponding to the water injection well; sigma m ip The total amount of tracer is injected for the injection well.
Ideally, the distribution coefficient D of the injection water of the injection and production well is calculated by the following formula: d = m ip And M is the total amount of the tracer injected into the water injection well. However, the tracer is actually generated due to the adsorption retention phenomenon of the tracer in the reservoirIn the production process, the water injection amount of the injection and production well is usually calculated by adopting a real distribution coefficient D'.
Preferably, the total amount m of the tracer on the injection and production well corresponding to any water injection well ip The calculation formula of (c) is:
m ip ＝∫C(Q ip )dQ
in the formula, Q ip The total water injection quantity on the injection and production wells corresponding to the water injection wells at will.
According to the concentration curve of the tracer agent of the injection and production well, the total amount of the tracer agent on the injection and production well is obtained by combining the accumulated water production. Considering the discontinuity of the concentration curve, the optimal method for calculating the total amount of the tracer is as follows:
m ip '＝∑C(Q ip )ΔQ
preferably, the dosage Q of the profile control and flooding agent in the mesoscale medium fracture 2 The calculation formula of (c) is:
Q 2 ＝ε 2 ×(Q t －Q 1 )
in the formula, Q t For the injection water swept volume of the injection well, epsilon 2 To adjust the plugging correction factor.
The injected water swept volume is calculated by an externally connected device in a way that the injected water swept volume = daily water injection quantity multiplied by water injection time.
Preferably, the plugging correction factor is 0.7 to 0.9, for example 0.7, 0.72, 0.74, 0.76, 0.78, 0.8, 0.82, 0.84, 0.86, 0.88 or 0.9, but is not limited to the recited values, and other values in the range of values are equally applicable; preferably 0.8.
Preferably, the dosage Q of the modifying and flooding agent in the micro-scale medium fracture 3 The calculation formula of (2) is as follows:
Q 3 ＝0.1×Q b +0.5×Q m +Q e
in the formula, Q b 、Q m And Q e The water injection swept volumes of the large-scale medium fracture, the medium-scale medium fracture and the micro-scale medium fracture are respectively.
Preferably, the profile control in step (iii) is: and injecting a profile control agent into the target profile control well through the water injection line.
Preferably, the injection modifying and flooding agent is a low molecular gel slug, a nano polymer slug and a wettability modifier slug which are injected in turn in batches.
Preferably, the batch is ≧ 2 times, such as 2 times, 3 times, 4 times or 5 times, but not limited to the recited values, other unrecited values within the numerical range are equally applicable.
When the modifying and flooding agent is added in batches, the dosage of the modifying and flooding agent added every time is the same until the total amount of the modifying and flooding agent added is equal to the dosage of the modifying and flooding agent calculated by the invention.
The number of times of the batches is more than or equal to 2, and if all the profile control agents are injected into the profile control well at one time, the vicinity of the oil reservoir water injection well is completely blocked, so that the aim of deep profile control cannot be fulfilled.
The invention injects the profile control agent into the stratum fractures in batches, and has the advantages of blocking fractures of different grades in a grading and batching manner, effectively improving the production and absorption profile, pushing the injected profile control agent to the deep part of an oil reservoir by water injection after each batch, effectively expanding the profile control range, and improving the macroscopic swept volume and the microscopic oil displacement efficiency.
As a preferable technical method, the deep profile control and flooding method for the fractured reservoir provided by the invention comprises the following steps:
judging the development characteristics of reservoir seams among injection wells and production wells by using the propulsion speed of a tracer; when the propelling speed of the tracer is greater than 90m/d, the development characteristic of the reservoir pore gaps among the injection and production wells is large-scale medium cracks; when the advancing speed of the tracer is 30-90m/d, the development characteristic of the reservoir pore gaps among the injection and production wells is medium-scale medium cracks; when the advancing speed of the tracer is less than 30m/d, the development characteristic of the reservoir pore gaps among the injection and production wells is micro-scale medium cracks;
(II) the large-scale medium crack adopts a modifying and flooding agent which is a low-molecular strong gel slug, and the dosage Q of the modifying and flooding agent 1 The calculation formula of (2) is as follows:
Q 1 ＝q d t d +∑(qD′ j )t d
mesoscale mediaThe profile control agent adopted by the crack is a nano polymer microsphere slug, and the dosage Q of the profile control agent 2 The calculation formula of (c) is:
Q 2 ＝ε 2 ×(Q t －Q 1 )
the profile control agent adopted by the micro-scale medium crack is a wettability modifier slug, and the dosage Q of the profile control agent 3 The calculation formula of (c) is:
Q 3 ＝0.1×Q b +0.5×Q m +Q e
(III) sequentially injecting a low-molecular gel slug, a nano polymer slug and a wettability modifier slug into the target drive and adjustment well in batches through a water injection line; the batch is more than or equal to 2 times.
The numerical ranges set forth herein include not only the recited values but also any values between the recited numerical ranges not enumerated herein, and are not intended to be exhaustive or otherwise clear from the intended disclosure of the invention in view of brevity and clarity.
Compared with the prior art, the invention has the following beneficial effects:
(1) Aiming at a fractured reservoir, firstly, the development characteristics of reservoir pore gaps among injection wells and production wells are dynamically monitored by using a tracer, then, a proper profile control and flooding agent is selected, the profile control and flooding agent required for plugging different-level dominant channels is designed, the calculation result is stronger in pertinence, and the effective period is longer;
(2) The method for controlling and driving the deep part of the fractured reservoir has the advantages of high maturity, good accuracy, quantitative analysis of development characteristics of stratum fractures and the like, so that a calculation result is more fit with the real condition of the reservoir, the production absorption profile can be effectively improved, the swept volume can be enlarged, the macroscopic swept range and the microscopic oil displacement efficiency can be improved, the scientific and efficient design of the dosage of the control and driving agent of the fractured carbonate reservoir is realized for the first time, and the method has important practical significance for guiding field control and driving operation.
Drawings
FIG. 1 is a schematic diagram of a procedure for profile control of a fractured reservoir provided in example 1 of the present invention;
fig. 2 is a schematic diagram illustrating the explanation result of the tracer for fractured reservoirs provided in example 1 of the present invention.
Detailed Description
The technical solution of the present invention is further explained by the following embodiments. It should be understood by those skilled in the art that the examples are only for the understanding of the present invention and should not be construed as the specific limitations of the present invention.
Example 1
The embodiment provides a deep profile control and flooding method for a fractured reservoir, wherein the fractured reservoir is a fractured carbonate reservoir, and the deep profile control and flooding method for the fractured reservoir comprises the following steps:
judging the development characteristics of reservoir seams among injection wells and production wells by using the propulsion speed of a tracer; as shown in fig. 2, B59 is a water injection well, and according to the tracer test result, tracers are tracked to a B55 well, a B58 well, a B59 well and a B95 well, wherein the fracture directions of the B55 well and the B95 well are the same, the advancing speed of the tracers between injection and production well groups is calculated, and as shown in table 1, the development characteristics of reservoir fractures are determined, namely a large-scale medium fracture B55 well, a medium-scale medium fracture B58 well, a B95 well and a micro-scale medium fracture B59 well;
(II) selecting a profile control agent according to the development characteristics of the reservoir pore gaps among the injection and production wells, and determining the dosage of the profile control agent:
the dosage parameters of the profile control agent used in the present example are shown in table 1;
actually measuring that the linear well spacing between the B55 well and the B56 well is 700m, the arrival time of the tracer is 700/112.1=6.25 days, the profile control agent adopted by the large-scale medium fracture is a low-molecular strong gel slug, and the dosage Q of the profile control agent is used 1 ＝6.25×22.6+(5.1+26+27.2)×6.25＝505.63m 3 ；
The modifying and flooding agent adopted by the mesoscale medium crack is a nano polymer microsphere slug, and the dosage Q of the modifying and flooding agent 2 ＝ε 2 ×(Q t －Q 1 )＝0.8×(17568.3+2091.1+4350.5+11674.2-505.63)＝2.81×10 4 m 3 ；
The profile control agent adopted by the micro-scale medium crack is a wettability changing agent slug, and the dosage Q of the profile control agent 3 ＝0.1×Q b +0.5×Q m +Q e ＝0.1×17563.8+0.5×(2091.1+11674.2)+4350.5＝1.30×10 4 m 3 ；
(III) injecting a low-molecular gel slug, a nano-polymer slug and a wettability modifier slug into the target flooding and regulating well in turn in batches through a water injection line as shown in FIG. 1; the number of times of the batch was 2.
The reservoir production before and after profile control by the method described in this example is shown in table 2.
TABLE 1
TABLE 2
As can be seen from Table 2, after the displacement control measures, the daily production fluid and the daily oil production of each injection and production well are obviously increased, the water content is reduced, and the daily oil increase of the corresponding average injection and production well is 18.5m 3 The water content is reduced by 10.6%, and the oil well development effect is obviously improved.
Example 2
This example provides a method for deep profile control of fractured reservoirs, which is the same as example 1 except that the number of batches in step (iii) is changed to 3.
The reservoir production before and after the profile control by the method described in this example is shown in table 3.
TABLE 3
As can be seen from Table 3, the daily fluid production and the daily oil production of each injection and production well are significantly increased after the flooding control measures are taken, and the oil contentThe water is all reduced, and the daily oil increase of the corresponding average injection and production well is 23m 3 The water content is reduced by 12.525%, and the oil well development effect is obviously improved.
Example 3
This example provides a method for deep profile control of fractured reservoirs, which is the same as example 1 except that the number of batches in step (iii) is changed to 1.
The reservoir production before and after profile control by the method described in this example is shown in table 4.
TABLE 4
As can be seen from Table 4, after the flooding control measures, the daily production fluids and daily oil production of each well are slightly increased, the water content is reduced, and the daily oil production of the corresponding average injection and production well is increased by 8.5m 3 The water content is reduced by 5.45%, the oil well development effect is improved to a certain extent, but the oil increment difference of the whole oil production is larger than that of 2 batches, and the oil production is necessary to increase the profile control and flooding batches.
Example 4
The embodiment provides a deep profile control and flooding method for a fractured reservoir, which is the same as that in the embodiment 1 except that the profile control and flooding agent adopted in the medium-scale medium fracture in the step (II) is replaced by a low-molecular strong gel slug.
The reservoir production before and after the profile control by the method described in this example is shown in table 5.
TABLE 5
As can be seen from Table 5, after the profile control and flooding measures are taken, the daily produced fluids of all wells are reduced, the daily oil production is slightly increased, the water content is increased to a certain extent, the injected profile control and flooding agent has a certain plugging effect on the stratum, but the oil well development effect is not effectively improved.
Example 5
The embodiment provides a deep profile control and flooding method for a fractured reservoir, which is the same as that in embodiment 1 except that profile control and flooding agents adopted in the medium-scale medium fractures and the micro-scale medium fractures in the step (II) are all replaced by low-molecular strong gel plugs.
The reservoir production before and after the profile control by the method of this example is shown in table 6.
TABLE 6
As can be seen from Table 6, after the profile control and flooding measures are taken, daily produced fluids of all wells are reduced, daily oil production is reduced to some extent, water content is increased to a certain extent, the injected profile control and flooding agent not only has a plugging effect on a large pore passage, but also plugs a passage for supplementing energy to a stratum so that energy cannot be supplemented, the fluid production capacity is greatly reduced, and the oil well development effect is poor.
Comparative example 1
The present comparative example provides a method for plugging water in a fractured reservoir proposed in the specific implementation manner of patent CN111963100A, the method includes the following steps:
(1) Preparing a water plugging agent;
(2) Determining the dosage of the water shutoff agent, the injection speed, the injection pressure and the injection slug by adopting an empirical formula method and a volume formula method;
(3) And (5) plugging water for the target oil reservoir.
By adopting the method for oil reservoir profile control and flooding, the development characteristics of the reservoir pore joints cannot be accurately judged, and a proper water shutoff agent cannot be selected for profile control and flooding, so that the waste of water shutoff agent resources is caused, the profile control and flooding error is large, and the purpose of accurate profile control and flooding cannot be achieved.
In conclusion, the method for controlling and driving the deep part of the fractured reservoir provided by the invention has the advantages that the maturity is high, the accuracy is good, the development characteristics of formation fractures and the like are quantitatively analyzed, the calculation result is more fit with the real condition of the reservoir, the production absorption profile can be effectively improved, the swept volume is enlarged, the macroscopic swept range and the microscopic oil displacement efficiency are improved, the scientific and efficient design of the dosage of the control and driving agent of the fractured carbonate reservoir is realized for the first time, and the method has important practical significance for guiding the field control and driving operation.
The applicant declares that the above description is only a specific embodiment of the present invention, but the scope of the present invention is not limited thereto, and it should be understood by those skilled in the art that any changes or substitutions that can be easily conceived by those skilled in the art within the technical scope of the present invention are within the scope and disclosure of the present invention.
Claims (10)
1. A deep profile control and flooding method for a fractured reservoir is characterized by comprising the following steps:
(I) Judging the development characteristics of the reservoir seams among injection wells and production wells by using the propulsion speed of the tracer;
(II) selecting a profile control agent according to the development characteristics of the reservoir pore gaps among injection wells and production wells, and determining the dosage of the profile control agent;
(III) performing profile control on the fractured reservoir.
2. The method for deep profile control of fractured reservoirs according to claim 1, wherein the developmental characteristics of the reservoir fractures between injection wells in the step (I) comprise any one or a combination of at least two of large-scale medium fractures, medium-scale medium fractures or micro-scale medium fractures;
preferably, the advancing speed of the tracer in the large-scale medium fracture is more than 90m/d;
preferably, the advancing speed of the tracer in the mesoscale medium fracture is 30-90m/d;
preferably, the advancing speed of the tracer in the micro-scale medium fracture is less than 30m/d.
3. The method for deep profile control and flooding of fractured reservoirs according to claim 2, wherein the profile control and flooding agent adopted by the large-scale medium fractures comprises low-molecular strong gel plugs;
preferably, the modifying and flooding agent adopted by the mesoscale medium fracture comprises a nano polymer microsphere slug;
preferably, the modifying and driving agent adopted by the micro-scale medium fracture is a wettability modifier slug.
4. The method for deep profile control and displacement of fractured reservoirs according to any one of claims 1 to 3, wherein the dosage Q of the profile control and displacement agent in the large-scale medium fractures 1 The calculation formula of (2) is as follows:
Q 1 ＝q d t d +∑(qD′ j )t d
in the formula, q d The distribution quantity of injection water, qD ', of the injection and production well with large-scale medium cracks' j The sum of the injection water distribution of the medium-scale medium fracture injection and production well and the micro-scale medium fracture injection and production well, t d And the injection time of the profile control agent in the large-scale medium fracture injection and production well is set.
5. The method for deep profile control of fractured reservoir according to claim 4, wherein the injection water distribution q of the large-scale medium fractured injection and production well is characterized in that d The calculation formula of (2) is as follows:
q d ＝qD′ d
wherein q represents the amount of water injected into the water injection well, D' d And (4) injecting a real distribution coefficient of water into the large-scale medium fracture injection and production well.
6. The method for deep profile control of fractured reservoirs according to claim 5, wherein the calculation formula of the real distribution coefficient D' is as follows:
in the formula, m ip The total amount of the tracer on the injection well and the production well corresponding to the water injection well is selected; sigma m ip The total amount of tracer injected for the injection well.
7. The method of claim 6, wherein the total amount m of tracer in any corresponding injection well and production well of the water injection well is m ip The calculation formula of (2) is as follows:
m ip ＝∫C(Q ip )dQ
in the formula, Q ip The total water injection quantity on the injection and production wells corresponding to the water injection wells at will.
8. The method for deep profile control and displacement of fractured reservoirs according to any one of claims 1 to 7, wherein the dosage Q of the profile control and displacement agent in the medium-scale fractures 2 The calculation formula of (2) is as follows:
Q 2 ＝ε 2 ×(Q t -Q 1 )
in the formula, Q t For the injection water swept volume of the injection well, epsilon 2 Adjusting the blockage correction coefficient;
preferably, the blockage adjusting correction coefficient is 0.7-0.9, and preferably 0.8.
9. The method for modifying and flooding the deep part of a fractured reservoir according to any one of claims 1 to 8, wherein the amount Q of modifying and flooding agent used in the micro-scale medium fracture 3 The calculation formula of (c) is:
Q 3 ＝0.1×Q b +0.5×Q m +Q e
in the formula, Q b 、Q m And Q e The water injection swept volumes of the large-scale medium fracture, the medium-scale medium fracture and the micro-scale medium fracture are respectively.
10. The method for deep profile control of fractured reservoirs according to any one of claims 1 to 9, wherein the profile control in the step (III) is as follows: injecting a profile control agent into the target profile control well through a water injection line;
preferably, the injection modifying and flooding agent is a low molecular gel slug, a nano polymer slug and a wettability modifier slug which are injected in turn in batches;
preferably, the batch is ≧ 2.
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