CN112459754B - CO after dry fracturing and soaking 2 Reservoir fluid displacement rule experimental method - Google Patents
CO after dry fracturing and soaking 2 Reservoir fluid displacement rule experimental method Download PDFInfo
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- CN112459754B CN112459754B CN202011214999.1A CN202011214999A CN112459754B CN 112459754 B CN112459754 B CN 112459754B CN 202011214999 A CN202011214999 A CN 202011214999A CN 112459754 B CN112459754 B CN 112459754B
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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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
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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
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- 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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- 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
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Abstract
The invention belongs to the technical field of oil well fracturing, and particularly relates to dry fracturing stewed well CO 2 And reservoir fluid displacement rule experimental method. The method comprises the steps of selecting a plunger core sample in a target area, pressing the plunger core sample into a crack, placing the plunger core sample in a CT holder, saturating the treated plunger core sample with formation water, displacing the formation water in the crack core, establishing the saturation of the bound water, saturating the treated plunger core sample with the formation crude oil, and measuring the saturated oil volume V 0 Acquiring the initial pore structure and fluid distribution characteristics of the processed plunger core sample, and injecting CO according to preset pressure 2 Back scanning and soaking the well, performing CT scanning within a preset soaking time until the soaking is finished, performing back flow, and measuring the back flow oil volume V 1 And calculating the replacement efficiency; CT scanning for obtaining CO of fractured core 2 Pore structure and fluid distribution characteristics after displacement; will inject CO 2 And comparing and analyzing the front and back pore structures and the fluid distribution characteristics to obtain a reservoir fluid displacement rule of the target area.
Description
Technical Field
The invention belongs to the technical field of oil well fracturing development, and particularly relates to dry fracturing stewed well CO 2 And reservoir fluid displacement rule experimental method.
Background
In the prior art, fracturing is mainly completed by a hydraulic fracturing mode mainly based on dialysis, and the fracturing is performed by adopting the method, mainly considering the problems of fracturing, sand carrying and the like, but not considering the replacement efficiency. By adopting the hydraulic fracturing mode, because water is insoluble in oil, the back-flowing efficiency is poor, the supporting effect is not strong, and the development effect of crude oil is poor. Therefore, a method capable of improving the reservoir fluid displacement law and improving the crude oil development effect is needed.
Disclosure of Invention
The invention provides a dry fracturing stewed well CO 2 An experimental method for reservoir fluid displacement rules, aiming at providing a method capable of realizingDefinition of CO 2 The efficiency of displacing reservoir fluid and the distribution of the reservoir fluid in the core after soaking for different time are determined, so that CO after dry fracturing and soaking is determined 2 The law of displacement with reservoir fluid is CO 2 Scheme design and CO improvement of dry fracturing 2 Experimental methods for providing a basis for dry fracturing recovery.
In order to realize the purpose, the invention adopts the technical scheme that:
CO after dry fracturing and soaking 2 The experimental method for reservoir fluid displacement law comprises the following steps
The method comprises the following steps: selecting a plunger rock core sample in a target area, and installing the plunger rock core sample into a CT holder after artificially pressing the plunger rock core sample into a crack;
step two: saturating the formation water of the plunger core sample treated in the step one, and establishing the saturation of the irreducible water by adopting the formation water in the displacement fracture core;
step three: measuring the volume V of the original saturated crude oil quantity of the plunger core sample saturated formation crude oil processed in the step two under the condition of experiment temperature and pressure 0 ；
Step four: acquiring initial pore structure characteristics and fluid distribution characteristics of the plunger core sample processed in the third step through CT scanning;
step five: CO injection at a predetermined pressure 2 Carrying out CT scanning, simultaneously carrying out soaking, setting different scanning time according to preset soaking time, and carrying out CT scanning at preset different scanning time points until the soaking is finished;
step six: after completion of the soaking, the flow was reversed, and the volume V of the displaced oil was measured under the standard condition 1 And calculating the replacement efficiency;
step seven: obtaining crack core CO through CT scanning analysis 2 The pore structure characteristics and fluid distribution characteristics after displacement;
step eight: comparing and analyzing the pore structure characteristics and the fluid distribution characteristics obtained in the fourth step and the seventh step to obtain a reservoir fluid displacement rule of the target area;
step nine: and e, applying the reservoir fluid displacement rule of the target area obtained in the step eight to crude oil development.
In the second step, an evacuation pressurization saturation method is adopted for saturating the formation water of the plunger core sample treated in the first step.
The initial pore structure characteristics in the fourth step and the seventh step comprise pore size distribution and throat size distribution parameters; the fluid distribution characteristics include the saturation of oil, gas, water in the pores.
And step five, setting different scanning time at equal intervals in preset soaking time.
CO injected in the fifth step 2 The purity was 99.999%.
The calculated replacement efficiency in the sixth step is calculated by adopting the following formula
Wherein: e D To the efficiency of the displacement;
B 0 is the volume coefficient of the crude oil in the stratum;
V 0 the volume of the original saturated crude oil under the experimental temperature and pressure conditions is adopted;
V 1 the volume of oil displaced under standard conditions.
And in the step eight, the method for comparing and analyzing the parameters of the pore structure characteristics and the parameters of the fluid distribution characteristics obtained in the step four and the step seven is to perform SEM experiments and EDS experiments on the processed plunger core samples, and obtain reservoir fluid displacement rules of the target area by comparison according to experimental results.
Has the advantages that:
the invention adopts a method combining an in-situ CT experiment and core displacement, saturates original formation fluid after artificially pressing a target reservoir core into a fracture, and injects CO with certain pressure into the fracture 2 After soaking, the CO is determined by CT scanning, the volume of the produced fluid and the composition analysis of the produced substances 2 Replacement ofThe efficiency of reservoir fluid and the distribution of the reservoir fluid in the rock core after soaking for different time, thereby defining the CO after dry fracturing soaking 2 The research result can be applied to CO according to the reservoir fluid displacement rule 2 The scheme design of the dry fracturing is CO 2 The application of the dry fracturing enhanced oil recovery technology provides a foundation.
The foregoing description is only an overview of the technical solutions of the present invention, and in order to clearly understand the technical solutions of the present invention and to implement the technical solutions according to the contents of the description, the following detailed description is given with reference to the preferred embodiments of the present invention and the accompanying drawings.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings required in the embodiments will be briefly described below, it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art that other drawings can be obtained according to the drawings without creative efforts.
FIG. 1 is a scanning comparison of pore structure features before and after displacement according to the present invention;
FIG. 2 is a comparison graph of the scanning results of the fluid distribution characteristics before and after displacement according to the present invention;
FIG. 3 is a comparison graph of pore structure characteristics of different positions scanned before and after replacement.
Detailed Description
The technical solutions of the present invention are described below clearly and completely by way of examples, and it is obvious that the described examples are only a part of the examples of the present invention, and not all of the examples. 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.
The first embodiment is as follows:
CO after dry fracturing soaking 2 The experimental method for reservoir fluid displacement law comprises the following steps
The method comprises the following steps: selecting a plunger rock core sample in a target area, and installing the plunger rock core sample into a CT holder after artificially pressing the plunger rock core sample into a crack;
step two: performing saturated formation water on the plunger core sample treated in the step one, and establishing the saturation of the bound water by displacing the formation water in the fracture core;
step three: measuring the volume V of the original saturated crude oil quantity of the plunger core sample saturated formation crude oil processed in the step two under the condition of experiment temperature and pressure 0 ；
Step four: acquiring initial pore structure characteristics and fluid distribution characteristics of the plunger rock core sample processed in the third step through CT scanning;
step five: CO injection at a predetermined pressure 2 Carrying out CT scanning, simultaneously carrying out soaking, setting different scanning time according to preset soaking time, and carrying out CT scanning at preset different scanning time points until the soaking is finished;
step six: after completion of the soaking, the flow was reversed, and the volume V of the displaced oil was measured under the standard condition 1 And calculating the replacement efficiency;
step seven: obtaining crack core CO through CT scanning analysis 2 The pore structure characteristics and fluid distribution characteristics after displacement;
step eight: comparing and analyzing the pore structure characteristics and the fluid distribution characteristics obtained in the fourth step and the seventh step to obtain a reservoir fluid displacement rule of the target area;
step nine: and e, applying the reservoir fluid displacement rule of the target area obtained in the step eight to crude oil development.
The invention can determine CO through eight steps 2 The efficiency of displacing reservoir fluid and the distribution of the reservoir fluid in the core after soaking for different time are determined, so that CO after dry fracturing and soaking is determined 2 The law of displacement with reservoir fluid is CO 2 Scheme design and CO improvement of dry fracturing 2 The dry fracturing recovery provides the basic experimental method.
By using CO 2 Method of dry fracturing, CO 2 The pore structure of the rock is changed, the porosity is increased, and the fluid seepage channel is improved. CO 2 2 Is easy to dissolve in crude oil and diffuse, makes crude oil expand, enters cracks and is pumped out through backflow, thereby achieving the purpose of replacing crude oil, and utilizes CO 2 Dry fracturing is also performed without contaminating the formation.
Example two:
CO after dry fracturing and soaking 2 Compared with the reservoir fluid displacement law experimental method, the difference of the first embodiment is that: in the second step, an evacuation pressurization saturation method is adopted for saturating the formation water of the plunger core sample treated in the first step.
Further, the initial pore structure characteristics in step four and step seven include pore size distribution and throat size distribution; the fluid distribution characteristics include the saturation of oil, gas, and water in the pores.
Further, the setting of different scanning times in the fifth step is setting at equal intervals within a preset soaking time.
Further, the CO injected in the fifth step 2 The purity was 99.999%.
Further, the calculation of the substitution efficiency in the sixth step is calculated by adopting the following formula
Wherein: e D To the efficiency of the displacement;
B 0 is the volume coefficient of the crude oil in the stratum;
V 0 the volume of the original saturated crude oil under the experimental temperature and pressure conditions is adopted;
V 1 the volume of oil displaced under standard conditions.
And in the step eight, the method for comparing and analyzing the parameters of the pore structure characteristics and the parameters of the fluid distribution characteristics obtained in the step four and the step seven is to perform SEM experiments and EDS experiments on the processed plunger core samples, and obtain reservoir fluid displacement rules of the target area by comparison according to experimental results.
In concrete embodimentsDuring testing, firstly selecting a plunger core sample in a target research area, manually fracturing a crack on the selected plunger core sample, then placing the cracked plunger core sample in a CT special core holder in the prior art for saturating formation water, and replacing the formation water in the crack core by adopting displacement to establish irreducible water saturation; meanwhile, CT scanning is carried out, and the pore structure distribution and the fluid distribution characteristics of the fracture core are determined; then injecting CO into the fracture under the design pressure of construction fracture 2 And (5) stewing after saturation, and carrying out CT scanning when the stewing lasts for different preset time. In CO 2 In the injection process, the position of the core holder in the CT special core holder is unchanged so as to ensure that in-situ CT scanning is carried out and further to clarify the pore structure distribution and the fluid distribution characteristics of the fracture core; according to the pressure change after different soaking time, calculating CO according to the prior art 2 Distribution after diffusion. Carrying out a backflow experiment after soaking for different time, determining the backflow amount and the composition of backflow fluid under different pressures, and further calculating the replacement efficiency; then, SEM and EDS experiments are carried out on the rock core after the experiment, and CO is analyzed 2 The pore structure characteristics before and after replacement and the change rule of rock components.
The invention can complete CO 2 Efficiency of displacement of reservoir fluids, CO 2 Influence on reservoir pore structure characteristics and rock composition, CO 2 The distribution characteristic change rule experiment of the displaced fluid in the pores shows that the research result can be applied to CO 2 Scheme design of dry fracturing is CO 2 The application of the dry fracturing enhanced oil recovery technology provides a foundation.
SEM and EDS experiments were performed on the cores in this example, wherein SEM is english abbreviation of scanning electron microscope, and wherein the text means scanning electron microscope; EDS is an English abbreviation of Energy Dispersive Spectrometer, wherein the text means electron probe Spectrometer. Through the two experiments, the pore structure characteristics and rock composition information of the rock core can be accurately and efficiently obtained, and CO can be subsequently improved 2 Dry fracturing recovery provides technical support.
Example three:
with reference to FIGS. 1-3Indication, CO after dry fracturing and soaking 2 An experimental method related to the reservoir fluid displacement law,
the method comprises the following steps: selecting a plunger core sample in a certain target area, and installing the plunger core sample into a CT holder after artificially pressing the plunger core sample into a crack;
step two: performing saturated formation water on the plunger core sample treated in the step one, and establishing the saturation of the bound water by displacing the formation water in the fracture core;
step three: measuring the volume V of the original saturated crude oil under the experimental temperature and pressure conditions for the crude oil of the saturated stratum of the plunger core sample treated in the second step 0 ，V 0 ＝1.216mL；
Step four: acquiring initial pore structure characteristics and fluid distribution characteristics of the plunger core sample processed in the third step through CT scanning; the pore throat size distribution is 0-158 μm, the pore throat size distribution is mainly between 20-100 μm, the porosity at a position 5mm away from the crack is 6.12%, the porosity at a position 10mm away from the crack is 4.06%, and the porosity at a position 15mm away from the crack is 4.42%; the oil gas water saturation respectively is: 59%, 0% and 41%
Step five: CO injection at a predetermined pressure 2 Then CT scanning is carried out, soaking is carried out simultaneously, the preset soaking time is 24 hours, and scanning is carried out once every 6 hours within the preset soaking time until the soaking is finished;
step six: after completion of the soaking, flowback was performed, and the volume V1=0.314mL of the displaced oil amount under the standard condition was measured, and the displacement efficiency was calculated to be 25.8%;
step seven: fracture core CO acquisition by CT scanning analysis 2 The pore structure characteristics and the fluid distribution characteristics after replacement are specifically as follows: the pore throat size distribution is 0-160 μm, the pore throat size distribution is mainly 26-100 μm, the porosity at a position 5mm away from the crack is 6.39%, the porosity at a position 10mm away from the crack is 5.08%, and the porosity at a position 15mm away from the crack is 4.33%; the oil gas water saturation respectively is: 46.5%, 12% and 41.5%;
step eight: comparing and analyzing the pore structure characteristics and the fluid distribution characteristics obtained in the fourth step and the seventh step to obtain reservoir fluid of the target areaThe replacement rule is as follows: the farther from the crack, the poorer the substitution effect, and the more moderate the substitution efficiency, CO 2 The replaced crude oil mainly replaces the crude oil at the middle/near crack part, the replaced crude oil mainly flows out through a large pore passage, and the primary replacement efficiency can reach 25.8 percent;
step nine: and e, applying the reservoir fluid displacement rule of the target area obtained in the step eight to crude oil development.
As can be seen from FIGS. 1-3, CO 2 The pore structure of the rock is changed, the porosity is increased, and the fluid seepage channel is improved.
Experiment 1 well:
CO 2 13 grades of front-mounted energy storage fracturing, 8915.5 square of fracturing fluid, 940 square of sand and CO 2 Filled with 1400 prescriptions of CO 2 The discharge capacity is 2 square/minute, the well is stewed for 48 days, the oil is found in the 2 nd day of well opening, the accumulated production lasts for 524 days, the daily average produced liquid is 18.1 tons, the daily average produced oil is 12.4 tons, and the accumulated produced oil is 5699 tons.
Experiment 2 well:
CO 2 front-mounted energy storage fracturing 17-grade, accumulated injection fracturing fluid 11685.8 square, sand 1240 square and CO 2 Accumulated 1800 Fang, CO 2 The discharge capacity is 2 square/minute, the well is stewed for 28 days, the oil is produced in the 3 rd day of well opening, the accumulated production lasts for 2019.11.30, the daily average liquid yield is 19.5 tons, the daily average oil yield is 11.7 tons, and the accumulated oil yield is 5184 tons.
Experiment 3 well:
CO 2 front-mounted energy storage fracturing 18 grades, injecting fracturing fluid 12453.4 square, adding sand 1300 square and CO 2 Recall that 1976 is 2 The discharge capacity is 2 square/minute, the well is stewed for 15 days, oil is produced when the well is opened, the production is cut to 2019.11.30, the cumulative production is 66 days, the daily average produced liquid is 13.9 tons, the daily average produced oil is 11.6 tons, and the cumulative produced oil is 5834 tons.
The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents, improvements and the like that fall within the spirit and principle of the present invention are intended to be included therein.
In the case of no conflict, a person skilled in the art may combine the relevant technical features in the foregoing examples with each other according to an actual situation to achieve a corresponding technical effect, and details of various combining situations are not described herein again.
It should be noted that all directional indicators (such as upper, lower, left, right, front, and rear … …) in the embodiment of the present invention are only used to explain the relative position relationship between the components, the movement situation, and the like in a specific posture (as shown in the drawing), and if the specific posture is changed, the directional indicator is changed accordingly.
The foregoing is illustrative of the preferred embodiments of the present invention, and the present invention is not to be limited to the embodiments shown herein but is to be accorded the widest scope consistent with the principles and novel features disclosed herein. Any simple modification, equivalent change and modification of the above embodiments according to the technical spirit of the present invention still fall within the scope of the technical solution of the present invention.
Claims (5)
1. CO after dry fracturing and soaking 2 The experimental method for reservoir fluid displacement law is characterized by comprising the following steps
The method comprises the following steps: selecting a plunger rock core sample in a target area, carrying out artificial fracturing on the plunger rock core sample to form a crack, and then installing the crack into a CT holder;
step two: performing saturated formation water on the plunger core sample treated in the step one, and establishing the saturation of the bound water by displacing the formation water in the fracture core;
step three: measuring the volume V of the original saturated crude oil quantity of the plunger core sample saturated formation crude oil processed in the step two under the condition of experiment temperature and pressure 0 ；
Step four: acquiring initial pore structure characteristics and fluid distribution characteristics of the plunger core sample processed in the third step through CT scanning;
step five: CO injection at a predetermined pressure 2 Carrying out CT scanning, simultaneously carrying out soaking, setting different scanning time according to preset soaking time, and carrying out CT scanning at preset different scanning time points until the soaking is finished;
step (ii) ofSixthly, the method comprises the following steps: after completion of the soaking, the flow was reversed, and the volume V of the displaced oil was measured under the standard condition 1 And calculating the replacement efficiency;
step seven: plunger core CO acquisition by CT scanning analysis 2 Displaced pore structure characteristics and fluid distribution characteristics;
step eight: comparing and analyzing the pore structure characteristics and the fluid distribution characteristics obtained in the fourth step and the seventh step to obtain a reservoir fluid displacement rule of the target area;
step nine: applying the reservoir fluid displacement rule of the target region obtained in the step eight to crude oil development;
the initial pore structure characteristics in the fourth step comprise pore size distribution and throat size distribution parameters; CO in the seventh step 2 The pore structure characteristics after replacement comprise pore size distribution and throat size distribution parameters; the fluid distribution characteristics in the fourth step and the seventh step comprise the saturation degree of oil, gas and water in pores;
CO injected in the fifth step 2 The purity was 99.999%.
2. The dry frac post-soak CO of claim 1 2 The reservoir fluid displacement rule experimental method is characterized by comprising the following steps: in the second step, an evacuation pressurization saturation method is adopted for saturating the formation water of the plunger core sample treated in the first step.
3. The dry frac post-soak CO of claim 1 2 The reservoir fluid displacement rule experimental method is characterized by comprising the following steps: and step five, setting different scanning time at equal intervals in preset soaking time.
4. The dry frac post-soak CO of claim 1 2 The reservoir fluid displacement rule experimental method is characterized by comprising the following steps: the calculation of the replacement efficiency in the sixth step is obtained by adopting the following formula
Wherein: e D To the efficiency of the displacement;
B 0 is the volume coefficient of the crude oil in the stratum;
V 0 the volume of the original saturated crude oil under the condition of experiment temperature and pressure is adopted;
V 1 the volume of oil displaced under standard conditions.
5. The dry frac post-soak CO of claim 1 2 And the experimental method for reservoir fluid displacement rules is characterized in that in the step eight, the parameters of the pore structure characteristics and the parameters of the fluid distribution characteristics obtained in the steps four and seven are compared and analyzed, and the reservoir fluid displacement rules in the target area are obtained by performing SEM experiments and EDS experiments on the processed plunger core samples and comparing according to the experimental results.
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| CN113984531B (en) * | 2021-10-22 | 2022-08-19 | 中国石油大学(北京) | Experimental method for researching influence of hydration on fracturing energy storage efficiency |
| CN114482969B (en) * | 2022-04-14 | 2022-08-19 | 西南石油大学 | Experimental device for simulating stewing fracturing fluid flowback of multistage fracturing in unequal time |
| CN116502557B (en) * | 2023-05-04 | 2024-01-30 | 西南石油大学 | Method for calculating saturation of movable fluid after reservoir fracturing based on grid analysis method |
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