CN111608643A - Evaluation method for matching of pre-crosslinked gel particle profile control agent and reservoir parameters - Google Patents

Evaluation method for matching of pre-crosslinked gel particle profile control agent and reservoir parameters Download PDF

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CN111608643A
CN111608643A CN202010499387.5A CN202010499387A CN111608643A CN 111608643 A CN111608643 A CN 111608643A CN 202010499387 A CN202010499387 A CN 202010499387A CN 111608643 A CN111608643 A CN 111608643A
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ppg
permeability
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侯健
吴德君
周康
安志斌
宋考平
曹绪龙
郭兰磊
元福卿
赵方剑
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China University of Petroleum East China
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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
    • 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
    • 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
    • E21B43/20—Displacing by water
    • 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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Abstract

The invention provides an evaluation method for matching of a pre-crosslinked gel particle (PPG) profile control agent and reservoir parameters, which mainly adopts a sand-packed pipe displacement experimental device and comprises the following steps: injecting a PPG sample into sand filling pipes with different permeabilities through a single sand filling pipe displacement experiment, monitoring the change of injection pressure along with the volume of injection pores, and determining the injectable permeability limit of the PPG according to the change trend of the injection pressure; on the basis, establishing a heterogeneous parallel double sand-packed pipe model with different permeability grade differences, ensuring that the permeability of a relative hypertonic pipe is not less than the injectable permeability limit of PPG, injecting a PPG sample into the heterogeneous parallel double sand-packed pipe model, acquiring the change of double-pipe flow along with the volume of an injection pore, calculating the water absorption section improvement rate of the double-pipe model before and after PPG injection, and taking the permeability grade difference corresponding to the maximum value of the section improvement rate as the matching grade difference of the PPG; in the same way, the matching relation charts of different types of PPG and permeability grade difference can be obtained. The evaluation method for the matching of the pre-crosslinked gel particle profile control agent and the reservoir parameters is based on an indoor displacement experiment, and can provide a scientific and reliable evaluation method for selecting the optimal type of PPG profile control agent for different heterogeneous reservoirs in a mine field.

Description

Evaluation method for matching of pre-crosslinked gel particle profile control agent and reservoir parameters
Technical Field
The invention relates to an evaluation method for the matching of a pre-crosslinked gel particle profile control agent and reservoir parameters, belonging to the technical field of oil development.
Background
Old oil fields in the east of China have entered the ultra-high water-cut period after development for over fifty years, and half of crude oil remains underground even if a polymer flooding technology is implemented. The mine application shows that the PPG can further improve the crude oil recovery of a high-water-content oil field and a polymer flooding oil field. After PPG is injected into a reservoir, the PPG can selectively and preferentially enter a high-permeability area to block a water channeling channel, and the subsequent injected fluid is forced to generate liquid flow steering and reach a low-permeability area, so that the swept volume is effectively enlarged, and the crude oil recovery rate is improved. However, the reservoir heterogeneity is large, the PPG particle size and the elastic modulus are not properly selected, and the profile control effect is limited or even destructive plugging is easily caused. Therefore, considering the matching of different types of PPG and different heterogeneous reservoirs, the invention provides an evaluation method for the matching of the pre-crosslinked gel particle profile control agent and reservoir parameters based on the PPG injectable permeability limit and the profile improvement rate.
Disclosure of Invention
The invention provides an evaluation method for the matching of a pre-crosslinked gel particle profile control agent and reservoir parameters.
The technical scheme of the invention is as follows:
the method for evaluating the matching of the pre-crosslinked gel particle profile control agent and reservoir parameters is characterized in that the injectable permeability limit of PPG is determined according to the pressure curve change characteristics of the sand-filled pipe with different permeability injected by PPG, and then the matching relationship between different types of PPG and the reservoir permeability is obtained; on the basis, the section improvement rate is calculated according to the change of the flow rate of the heterogeneous parallel double sand-packed pipe with different permeability grades injected by PPG, and the matching relation between different types of PPG and the reservoir permeability grade is obtained according to the judgment standard that the maximum section improvement rate is the matching of PPG and the permeability grade. The method specifically comprises the following steps:
(1) for PPG samples with the same mesh and elastic modulus, respectively carrying out different sand-packed pipe displacement experiments according to the sequence of permeability from large to small, monitoring the change rule of injection pressure along with the volume of injected pores by using a pressure acquisition system, and when the injection pressure at a certain permeability finally fluctuates stably and the injection pressure at a lower permeability continuously rises and cannot be stable, the corresponding stable pressure at the permeability is the ultimate stable pressure of the PPG adopted in the experiment, and the permeability is the injectable permeability limit corresponding to the PPG adopted in the experiment;
(2) on the basis, establishing a heterogeneous parallel double sand-packed pipe model with different permeability grade differences, wherein the permeability of a relative hypertonic pipe is ensured to be larger than the injectable permeability limit of PPG adopted in the experiment;
(3) adopting a heterogeneous parallel double sand-packed pipe model, sequentially carrying out water drive, PPG drive and subsequent water drive experiments, collecting and measuring the flow split at the outlet end of a relatively high-permeability and low-permeability sand-packed pipe in the experiment process, taking the flow split as a vertical coordinate, taking the injection pore volume multiple as a horizontal coordinate, and drawing a double-pipe flow split change curve;
(4) and calculating the section improvement rate of a PPG injection front and rear double-pipe model based on a double-pipe flow rate change curve, and obtaining the matching relation between different types of PPG and the reservoir permeability grade difference according to the judgment standard that the maximum section improvement rate is PPG and the permeability grade difference.
The evaluation method for the matching of the pre-crosslinked gel particle profile control agent and the reservoir parameters is characterized in that the PPG particle size is 20-40 meshes, 40-60 meshes, 60-80 meshes, 80-100 meshes, 100-120 meshes and 120-150 meshes respectively, and the PPG elastic modulus is 2-4Pa and 12-16Pa respectively.
The method for evaluating the matching performance of the pre-crosslinked gel particle profile control agent and reservoir parameters is characterized in that the PPG suspension liquid mass concentration is 2000mg/L, the experiment temperature is 70 ℃, the experiment injection speed of a single sand-packed pipe is 0.5mL/min, and the experiment injection speed of a heterogeneous parallel double sand-packed pipe is 1 mL/min.
The method for evaluating the matching of the pre-crosslinked gel particle profile control agent and reservoir parameters is characterized in that the matching comprises injectable permeability limits of PPG of different types; and the matching relationship between different types of PPG and different permeability level differences.
The method for evaluating the matching of the pre-crosslinked gel particle profile control agent and the reservoir parameters is characterized in that the ultimate stable pressure is the maximum stable pressure of PPG which can be injected into sand-filled pipes with different permeabilities.
The method for evaluating the matching of the pre-crosslinked gel particle profile control agent and the reservoir parameters is characterized in that the PPG injectable permeability limit is the corresponding minimum permeability when the PPG can be stably injected into a sand-pack pipe.
The method for evaluating the matching of the pre-crosslinked gel particle profile control agent and reservoir parameters is characterized in that the permeability of a relative hypertonic pipe in the heterogeneous parallel double sand-packed pipe is required to be ensured to be not lower than an injectable permeability limit adopting PPG.
The method for evaluating the matching between the pre-crosslinked gel particle profile control agent and the reservoir parameters is characterized in that the profile improvement rate is represented by the ratio of the cumulative flow ratio difference of the relative hypotonic tubes before and after PPG injection to the cumulative flow ratio of the relative hypotonic tubes before PPG injection, and the calculation formula is as follows:
Figure BDA0002524215870000021
in the formula: f is the profile improvement rate; qhbThe cumulative flow of the relative hypertonic tubing before PPG injection is mL; qhaThe cumulative flow of the relative hypertonic tubing after PPG injection is mL; qlbThe cumulative flow of the relative hypotonic tube before PPG injection is mL; qlaCumulative flow in the relatively hypotonic tube after PPG infusion, mL.
The method for evaluating the matching between the pre-crosslinked gel particle profile control agent and the reservoir parameters is characterized in that the section improvement rates of the displacement experiments of the heterogeneous parallel double sand-packed pipe model with different permeability grades carried out by adopting the same type of PPG are different in calculation result, and the permeability grade corresponding to the maximum value of the section improvement rate is selected as the permeability grade matched with the type of PPG.
The invention has the advantages that:
by utilizing the evaluation method for the matching of the pre-crosslinked gel particle profile control agent and the reservoir parameters, based on a sand-packed tube core displacement experiment, and taking the ultimate stable pressure and the profile improvement rate as evaluation indexes, the invention provides a practical and effective PPG and reservoir parameter matching judgment method, and provides a scientific and reliable evaluation method for selecting the optimal PPG profile control agent, improving the water absorption profile in the maximum range and improving the crude oil recovery ratio for different heterogeneous reservoirs in a mine field.
Drawings
Fig. 1 is a structural diagram of a displacement experimental device used in an evaluation method for matching of a pre-crosslinked gel particle profile control agent and reservoir parameters, and the structural diagram is marked with the following reference numbers: 1-distilled water, 2-ISCO pump, 3-intermediate container, 4-six-way valve, 5-pressure sensor, 6-pressure acquisition system, 7-low-permeability sand filling pipe, 8-high-permeability sand filling pipe, 9-collection measuring cylinder and 10-constant temperature box.
FIG. 2 is a pressure curve diagram of PPG with particle size of 80-100 mesh and elastic modulus of 2-4Pa injected into sand-packing pipes with different permeability.
FIG. 3 is a graph of the flow rate of relatively high and low permeability tubing.
FIG. 4 is a histogram of the results of the profile improvement calculations.
Detailed Description
In order to make the aforementioned and other objects, features and advantages of the present invention comprehensible, preferred embodiments accompanied with figures are described in detail below.
According to the sequence of permeability from large to small, injecting PPG suspension into sand filling pipes with different permeability to obtain a change curve of injection pressure along with injection pore volume, wherein when the injection pressure at a certain permeability finally fluctuates stably and the injection pressure at a smaller permeability continuously rises unstably, the corresponding stable pressure at the permeability is the ultimate stable pressure of the PPG adopted in the experiment, and the permeability is the injectable permeability limit corresponding to the PPG adopted in the experiment; on the basis, designing a heterogeneous parallel double sand-packed pipe model to ensure that the permeability of a relative high permeability pipe is not lower than an injectable permeability limit adopting PPG; injecting suspensions of different types of PPG into sand filling pipes with different permeability grade differences, and calculating the section improvement rate according to the experimental result; and taking the permeability grade difference corresponding to the maximum value of the profile improvement rate as the permeability grade difference matched with the PPG of the type, thereby obtaining the matching relation between the PPG of different types and the permeability grade differences.
In the present invention, for the research of the injection permeability limit of different types of PPG, the PPG sample with particle size of 80-100 mesh and elastic modulus of 2-4Pa is taken as an example, the experimental result curve of injection pressure in dependence on the injection pore volume multiple is shown in FIG. 2, the injection permeability of the PPG sample is 7644 × 10-3μm2The injection pressure is basically in a stable fluctuation state after about 4.3PV is injected into the sand-filled pipe, the injection pressure is about 1MPa, PPG can be stably injected, the permeability of the sand-filled pipe is reduced, and the permeability of the PPG sample injected into the sand-filled pipe is 2007 × 10-3μm2The injection pressure rises slowly when the sand filling pipe is filled, after about 4.8PV is injected, the injection pressure is basically in a stable fluctuation state, about 1.62MPa, the PPG can not only be stably injected, but also the plugging pressure is relatively large, the permeability of the sand filling pipe is continuously reduced, and the injection permeability of the PPG sample is 1129 × 10-3μm2When the sand filling pipe is filled, the injection pressure rises all the time along with the increase of the injection amount, and finally, the exponential increase appears, which indicates that PPG causes the sand filling pipe with the permeabilityTherefore, the injectable permeability limit of the PPG sample with the particle size of 80-100 meshes and the elastic modulus of 2-4Pa can be judged to be 2007 × 10-3μm2。
In the invention, for researching the matching relationship between different types of PPG and permeability grade differences, taking a PPG sample with the particle size of 80-100 meshes and the elastic modulus of 2-4Pa as an example, heterogeneous sand-packed pipes with different permeability grade differences are arranged for carrying out a flow-dividing experiment, wherein the permeability of the low-permeability pipe packed in the experiment is about 1000 × 10-3μm2The permeability of the hypertonic tubes is designed not to be lower than the injection permeability limit of the PPG sample (2007 × 10)-3μm2) The actual permeability of the filled hypertonic pipes is 2120 × 10-3μm2、4540×10-3μm2And 6250 × 10-3μm2The permeability level differences were 2.12, 4.54 and 6.25, respectively. FIG. 3 is a plot of the split flow rate of PPG samples during injection into a heterogeneous sand pack with a permeability step of 4.54. From the collected flow data, the cross-sectional improvement rates of the sand-packed pipe for this permeability level difference were calculated to be 8%, 92%, and 26% for each sample, respectively, as shown in fig. 4. It can be seen that the section improvement rate of the PPG sample in the heterogeneous sand-packed pipe with the permeability level difference of 4.54 is the largest, and the PPG sample with the particle size of 80-100 meshes and the elastic modulus of 2-4Pa can be judged to be best matched with the heterogeneous sand-packed pipe with the permeability level difference of 4.52.
The invention provides an evaluation method of the matching of a pre-crosslinked gel particle profile control agent and reservoir parameters aiming at the difference of reservoir heterogeneity. The reservoir physical property parameters considered by the invention are closely combined with the actual mine field, and the optimal PPG can be simply and conveniently screened out for profile control and flooding application for the given reservoir parameters. The method is high in practicability, and an effective method is provided for reasonable screening of the PPG of the heterogeneous reservoir.

Claims (9)

1. The invention provides an evaluation method for the matching of a pre-crosslinked gel particle profile control agent and reservoir parameters, which is characterized in that the injectable permeability limit of PPG is determined according to the pressure curve change characteristics of the PPG injected into sand-filled pipes with different permeabilities, so that the matching relationship between different types of PPG and the reservoir permeability is obtained; on the basis, the section improvement rate is calculated according to the change of the flow rate of the heterogeneous parallel double sand-packed pipe with different permeability grades injected by PPG, and the matching relation between different types of PPG and the reservoir permeability grade is obtained according to the judgment standard that the maximum section improvement rate is the matching of PPG and the permeability grade. The method specifically comprises the following steps:
(1) for PPG samples with the same mesh and elastic modulus, respectively carrying out different sand-packed pipe displacement experiments according to the sequence of permeability from large to small, monitoring the change rule of injection pressure along with the volume of injected pores by using a pressure acquisition system, and when the injection pressure at a certain permeability finally fluctuates stably and the injection pressure at a lower permeability continuously rises and cannot be stable, the corresponding stable pressure at the permeability is the ultimate stable pressure of the PPG adopted in the experiment, and the permeability is the injectable permeability limit corresponding to the PPG adopted in the experiment;
(2) on the basis, establishing a heterogeneous parallel double sand-packed pipe model with different permeability grade differences, wherein the permeability of a relative hypertonic pipe is ensured to be larger than the injectable permeability limit of PPG adopted in the experiment;
(3) adopting a heterogeneous parallel double sand-packed pipe model, sequentially carrying out water drive, PPG drive and subsequent water drive experiments, collecting and measuring the flow split at the outlet end of a relatively high-permeability and low-permeability sand-packed pipe in the experiment process, taking the flow split as a vertical coordinate, taking the injection pore volume multiple as a horizontal coordinate, and drawing a double-pipe flow split change curve;
(4) and calculating the section improvement rate of a PPG injection front and rear double-pipe model based on a double-pipe flow rate change curve, and obtaining the matching relation between different types of PPG and the reservoir permeability grade difference according to the judgment standard that the maximum section improvement rate is PPG and the permeability grade difference.
2. The method as claimed in claim 1, wherein the PPG particle size is 20-40 mesh, 40-60 mesh, 60-80 mesh, 80-100 mesh, 100-120 mesh, 120-150 mesh, and the elastic modulus of PPG is 2-4Pa and 12-16 Pa.
3. The method for evaluating the matching between the pre-crosslinked gel particle profile control agent and the reservoir parameters as claimed in claim 1, wherein the mass concentration of the PPG suspension is 2000mg/L, the experimental temperature is 70 ℃, the injection speed of the single sand-packed pipe experiment is 0.5mL/min, and the injection speed of the heterogeneous parallel double sand-packed pipe experiment is 1 mL/min.
4. The method of claim 1, wherein the matching comprises injectable permeability limits for different types of PPG; and the matching relationship between different types of PPG and different permeability level differences.
5. The method for evaluating the matching of the pre-crosslinked gel particle profile control agent and the reservoir parameters as claimed in claim 1, wherein the ultimate stable pressure is the maximum stable pressure at which PPG can be injected into sand packs with different permeabilities.
6. The method for evaluating the matching of the pre-crosslinked gel particle profile control agent and the reservoir parameters as claimed in claim 1, wherein the PPG injectable permeability limit is the corresponding minimum permeability when the PPG can be stably injected into the sand pack.
7. The method for evaluating the matching of the pre-crosslinked gel particle profile control agent and the reservoir parameters as claimed in claim 1, wherein the permeability of the heterogeneous parallel double sand pack pipe is ensured to be not lower than the injectable permeability limit using PPG.
8. The method for evaluating the matching between the pre-crosslinked gel particle profile control agent and the reservoir parameters as claimed in claim 1, wherein the profile improvement rate is represented by the ratio of the cumulative flow ratio difference of the relatively hypotonic tubes before and after PPG injection to the cumulative flow ratio of the relatively hypotonic tubes before PPG injection, and the calculation formula is as follows:
Figure FDA0002524215860000021
in the formula: f is the profile improvement rate; qhbThe cumulative flow of the relative hypertonic tubing before PPG injection is mL; qhaThe cumulative flow of the relative hypertonic tubing after PPG injection is mL; qlbThe cumulative flow of the relative hypotonic tube before PPG injection is mL; qlaCumulative flow in the relatively hypotonic tube after PPG infusion, mL.
9. The method for evaluating the matching between the pre-crosslinked gel particle profile control agent and the reservoir parameters according to claim 1, wherein the section improvement rates of the heterogeneous parallel double sand-packed pipe model displacement experiments with different permeability grades performed by using the same type of PPG are different in calculation result, and the permeability grade corresponding to the maximum value of the section improvement rate is selected as the permeability grade matched with the type of PPG.
CN202010499387.5A 2020-06-04 2020-06-04 Evaluation method for matching of pre-crosslinked gel particle profile control agent and reservoir parameters Pending CN111608643A (en)

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Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN113790046A (en) * 2021-08-24 2021-12-14 中国石油大学(北京) Heterogeneous system evaluation method and device, electronic device and storage medium
CN113982546A (en) * 2021-10-21 2022-01-28 中国科学院武汉岩土力学研究所 Evaluation method for carbon dioxide injection profile of horizontal well

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN113790046A (en) * 2021-08-24 2021-12-14 中国石油大学(北京) Heterogeneous system evaluation method and device, electronic device and storage medium
CN113982546A (en) * 2021-10-21 2022-01-28 中国科学院武汉岩土力学研究所 Evaluation method for carbon dioxide injection profile of horizontal well

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