CN115983734B - Consider CO 2 Model and method for evaluating storage capacity of depleted gas reservoir serving as pad gas - Google Patents
Consider CO 2 Model and method for evaluating storage capacity of depleted gas reservoir serving as pad gas Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 59
- 238000003860 storage Methods 0.000 title claims abstract description 48
- 238000013210 evaluation model Methods 0.000 claims abstract description 22
- 238000004519 manufacturing process Methods 0.000 claims abstract description 9
- 238000012360 testing method Methods 0.000 claims abstract description 4
- 230000000704 physical effect Effects 0.000 claims abstract description 3
- 239000007789 gas Substances 0.000 claims description 150
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 130
- 239000003345 natural gas Substances 0.000 claims description 65
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 56
- 230000015572 biosynthetic process Effects 0.000 claims description 27
- 238000002347 injection Methods 0.000 claims description 21
- 239000007924 injection Substances 0.000 claims description 21
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- 238000012937 correction Methods 0.000 claims description 9
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- 238000011156 evaluation Methods 0.000 claims description 7
- 230000033558 biomineral tissue development Effects 0.000 claims description 6
- 230000006835 compression Effects 0.000 claims description 6
- 238000007906 compression Methods 0.000 claims description 6
- 239000004215 Carbon black (E152) Substances 0.000 claims description 5
- 229930195733 hydrocarbon Natural products 0.000 claims description 5
- 150000002430 hydrocarbons Chemical class 0.000 claims description 5
- 229920000642 polymer Polymers 0.000 claims description 3
- 238000013461 design Methods 0.000 abstract description 3
- 238000005457 optimization Methods 0.000 abstract description 2
- 238000010586 diagram Methods 0.000 description 7
- 229910052799 carbon Inorganic materials 0.000 description 5
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 4
- 238000004364 calculation method Methods 0.000 description 3
- 230000008859 change Effects 0.000 description 3
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- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 229910002091 carbon monoxide Inorganic materials 0.000 description 1
- 239000003054 catalyst Substances 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- 238000004090 dissolution Methods 0.000 description 1
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Abstract
The application discloses a method for considering CO 2 The method for evaluating the storage capacity of the exhausted gas reservoir serving as the pad gas comprises the following steps: s1: establishing an exhausted gas reservoir capacity evaluation model taking CO2 as a pad gas in the method of claim 1; s2: obtaining physical parameters in a target depleted gas reservoir storage capacity evaluation model according to geology, test and production data of the depleted gas reservoir; s3: calculating variable parameters in the depleted gas reservoir capacity evaluation model according to physical properties of the target depleted gas reservoir; s4: substituting the parameters obtained in step S2 and step S3 into the consideration CO described in step S1 2 And in the potential evaluation model of the depleted gas reservoir gas storage serving as the pad gas, calculating the target depleted gas reservoir to reconstruct the reservoir capacity of the gas reservoir. The application can consider the CO 2 And under the conditions of gas cushion and water-soluble gas, the storage capacity of the depleted gas storage is rapidly and effectively evaluated, and technical support is provided for the design and production operation optimization of the underground gas storage.
Description
Technical Field
The application relates to the technical field of oilfield development, in particular to a method for considering CO 2 A model and a method for evaluating the storage capacity of a depleted gas reservoir serving as a cushion gas.
Background
Underground gas storage is an energy infrastructure integrating seasonal peak shaving, emergency gas supply and national energy strategic reserves. With the rapid increase of natural gas consumption, the contradiction between insufficient gas storage capacity and safe and stable supply of natural gas is further aggravated, and when designing an underground gas storage, the gas storage capacity of the gas storage is a key factor considered by design engineers, and the storage capacity is an important index for measuring the performance of the gas storage. It is important to account for the storage capacity of underground reservoirs in real time and to determine the amount of working gas at different pressures.
Compared with developed countries, the basic construction of the gas storage in China is relatively lagged, the reserve capacity is insufficient, and the gas storage is not matched with the rapid increase of the natural gas consumption demand in China at present, so that the safe and stable supply of natural gas in China is restricted. Depleted gas reservoirs are the most common and economical form of domestic construction of underground gas reservoirs, which still use virgin natural gas as a blanket. In the form of inexpensive CO 2 Replace precious natural gas cushion gas, not only reduce the loss of natural gas, but also achieve the purpose of carbon sequestration and CO construction 2 The gas storage used as the cushion gas realizes carbon reduction on one hand and improves the utilization rate of low-carbon energy on the other hand. With primary cushion gas, N 2 In contrast, CO 2 Has stronger compressibility and improves the CO of exhausted gas reservoirs 2 Storage capacity and enhanced natural gas recovery during natural gas production; CO 2 Compared with the original cushion gas, N 2 The water-based gas storage tank also has stronger dissolving capacity in stratum water, on one hand, a large amount of carbon is sealed, on the other hand, the gas-based gas is dissolved, so that more storage capacity can be provided for a gas storage, and a large amount of CO is produced by Cheng Xichu 2 But also can provide energy. During production, the blanket gas is critical to maintaining proper reservoir pressure and stable production operations.
Disclosure of Invention
In view of the above, the present application aims to provide a method for considering CO 2 Model and method for evaluating storage capacity of exhausted gas reservoir as pad gas so as to quickly and effectively perform CO 2 And (5) performing gas storage capacity evaluation on the exhausted gas reservoir serving as the gas storage cushion.
The technical scheme of the application is as follows:
in one aspect, a method is provided for accounting for CO 2 An exhausted gas reservoir capacity evaluation model as a pad gas, the model being used for evaluating the reservoir capacity of an exhausted gas reservoir, and the exhausted gas reservoir being in CO 2 As a cushion gasThe model is as follows:
wherein: v (V) inj 、V i 、V w_p The natural gas volume injected under standard conditions, the original hydrocarbon-containing volume of the stratum and the accumulated water yield are respectively, m 3 ；
p、p i 、p dep 、p sc The pressure is respectively the formation pressure, the original formation pressure, the depleted formation pressure and the standard condition pressure, and the pressure is MPa;
a is the proportion of natural gas with water invasion part removed to occupy the air pore space, and the method is dimensionless;
c eff for effective compression coefficient, MPa -1 ；
B w 、B w_dep 、B wi The method comprises the steps of respectively obtaining a stratum water volume coefficient in the injection process, a stratum water volume coefficient in the depleted gas reservoir state and a stratum water volume coefficient in the original stratum state, wherein the stratum water volume coefficient is dimensionless;
W e 、W e_dep respectively the water invasion amount in the injection process and the water invasion amount in the depleted gas reservoir state, m 3 ；
Z H 、Z dep 、Z sc The natural gas deviation factors of the current stratum condition, the depleted stratum condition and the standard condition are respectively dimensionless;
T、T dep 、T sc the temperature of the stratum, the depleted stratum and the standard condition temperature are respectively K;
R H 、R H_dep the solubility of natural gas in the injection process and the solubility of natural gas in the depleted gas reservoir state are respectively m 3 /m 3 。
In another aspect, a method for accounting for CO is also provided 2 The method for evaluating the capacity of the exhausted gas reservoir as the pad gas comprises the following steps:
s1: build the above consideration of CO 2 As an exhausted gas reservoir capacity evaluation model of the pad gas;
s2: obtaining physical parameters in a target depleted gas reservoir storage capacity evaluation model according to geology, test and production data of the depleted gas reservoir;
s3: calculating variable parameters in the depleted gas reservoir capacity evaluation model according to physical parameters of the target depleted gas reservoir;
s4: substituting the parameters obtained in step S2 and step S3 into the consideration CO described in step S1 2 And in the potential evaluation model of the depleted gas reservoir gas storage serving as the pad gas, calculating the target depleted gas reservoir to reconstruct the reservoir capacity of the gas reservoir.
Preferably, in step S2, the physical properties include an original geological reserve, a water saturation, a water body size, a depleted formation temperature, a depleted formation pressure, a formation water invasion amount in a depleted state, an accumulated water yield, a gas composition, and a formation water mineralization degree.
Preferably, in step S3, the variable parameters include formation water volume factor, natural gas bias factor, CO 2 Deviation factor, natural gas solubility, CO 2 Solubility of the polymer.
Preferably, the formation water volume factor is calculated by:
wherein: b is the stratum water volume coefficient, dimensionless; deltaV wp 、ΔV wT The method is a stratum water volume coefficient pressure correction term and a stratum water volume coefficient temperature correction term respectively, and is dimensionless.
Preferably, the natural gas bias factor is calculated by the following formula:
wherein: z is a deviation factor, dimensionless; t (T) pr 、p pr The temperature and the pressure are respectively observed and contrasted, and the dimensionless is achieved; ρ pr To specially defineIs dimensionless; p is p pc Is apparent critical pressure, MPa; t (T) pc K is the critical temperature.
Preferably, the CO is calculated 2 When the factor is deviated, the method is to perform CO 2 The method for correcting the critical temperature and the critical pressure comprises the following specific steps:
wherein: t'. pc K is the corrected apparent critical temperature; y is CO2 Is CO 2 Mole fraction, dimensionless; p's' pc The corrected apparent critical pressure, MPa.
Preferably, the natural gas solubility is calculated by the formula:
wherein: s is natural gas solubility, m 3 /m 3 The method comprises the steps of carrying out a first treatment on the surface of the m is the mineralization degree of stratum water and g/L.
Preferably, the CO 2 The solubility is calculated by the following formula:
wherein: r is R CO2 Is CO 2 Solubility, m 3 /m 3 。
The beneficial effects of the application are as follows:
the application can consider CO 2 And under the conditions of gas cushion and water-soluble gas, the storage capacity of the depleted gas storage is rapidly and effectively evaluated, and technical support is provided for the design and production operation optimization of the underground gas storage.
Drawings
In order to more clearly illustrate the embodiments of the application or the technical solutions of the prior art, the drawings which are used in the description of the embodiments or the prior art will be briefly described, it being obvious that the drawings in the description below are only some embodiments of the application, and that other drawings can be obtained according to these drawings without inventive faculty for a person skilled in the art.
FIG. 1 is CO 2 Gas storage CO as cushion gas 2 An injection stage and a natural gas injection stage schematic diagram;
FIG. 2 is a schematic diagram of gas distribution during injection;
FIG. 3 is a schematic diagram of an embodiment of CO 2 The air filling amount is 15000 multiplied by 10 4 m 3 A schematic diagram of natural gas injection amount and formation pressure change under the condition;
FIG. 4 is a schematic diagram of a CO embodiment 2 The air quantity is 20000 x 10 4 m 3 A schematic diagram of natural gas injection amount and formation pressure change under the condition;
FIG. 5 is a schematic diagram of a CO embodiment 2 The cushion gas volume is 25000 multiplied by 10 4 m 3 The natural gas injection amount under the condition and the formation pressure change are shown schematically.
Detailed Description
The application will be further described with reference to the drawings and examples. It should be noted that, without conflict, the embodiments of the present application and the technical features of the embodiments may be combined with each other. It is noted that all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs unless otherwise indicated. The use of the terms "comprising" or "includes" and the like in this disclosure is intended to cover a member or article listed after that term and equivalents thereof without precluding other members or articles.
In one aspect, the present application provides a method of accounting for CO 2 An exhausted gas reservoir capacity evaluation model as a pad gas, the model being used for evaluating the reservoir capacity of an exhausted gas reservoir, and the exhausted gas reservoir being in CO 2 As a cushion, the model is:
wherein: v (V) inj 、V i 、V w_p The natural gas volume injected under standard conditions, the original hydrocarbon-containing volume of the stratum and the accumulated water yield are respectively, m 3 ；
p、p i 、p dep 、p sc The pressure is respectively the formation pressure, the original formation pressure, the depleted formation pressure and the standard condition pressure, and the pressure is MPa;
a is the proportion of natural gas with water invasion part removed to occupy the air pore space, and the method is dimensionless;
c eff for effective compression coefficient, MPa -1 ；
B w 、B w_dep 、B wi The method comprises the steps of respectively obtaining a stratum water volume coefficient in the injection process, a stratum water volume coefficient in the depleted gas reservoir state and a stratum water volume coefficient in the original stratum state, wherein the stratum water volume coefficient is dimensionless;
W e 、W e_dep respectively the water invasion amount in the injection process and the water invasion amount in the depleted gas reservoir state, m 3 ；
Z H 、Z dep 、Z sc The natural gas deviation factors of the current stratum condition, the depleted stratum condition and the standard condition are respectively dimensionless;
T、T dep 、T sc the temperature of the stratum, the depleted stratum and the standard condition temperature are respectively K;
R H 、R H_dep the solubility of natural gas in the injection process and the solubility of natural gas in the depleted gas reservoir state are respectively m 3 /m 3 。
In the form of CO 2 Gas storage CO as cushion gas 2 The injection stage and the natural gas injection stage and the gas distribution in the injection stage are shown in fig. 1-2, and the model of the application is obtained by the following steps according to the gas distribution in the injection process:
establishing a material balance equation considering water-soluble gas on the basis of depleted gas reservoirs with water bodies according to molar mass conservation;
considering the presence of water-soluble gas, the molar conservation relationship is: injected natural gas molar amount = natural gas molar amount in the formation at hand (including dissolved amount) -depleted formation natural gas molar amount (including dissolved amount), i.e.:
n H_inj ＝n H +n H_dis -n dis -n dis_dep (7)
the material balance equation is:
wherein: r is ideal gas constant, 0.00831451 J.mol -1 ·k -1 The method comprises the steps of carrying out a first treatment on the surface of the V is the hydrocarbon volume in the stratum under the stratum condition of different pressure, m 3 ；V H 、V H_dis 、V dep 、V dep_dis The natural gas volume in the stratum, the dissolved natural gas volume in the stratum, the natural gas volume in the depleted gas reservoir stratum and the dissolved natural gas volume in the depleted gas reservoir stratum are respectively, m 3 。
Formation real-time gas (natural gas and CO) 2 ) The pore space is:
V＝V i [1-c eff (p i -p)]+V w_p B w -W e (9)
hydrocarbon-bearing pore volume V of the original formation i The method comprises the following steps:
wherein G is i For the original formation reserves, m 3 ；B i Is the natural gas volume coefficient under the original stratum condition, and is dimensionless; z is Z i Is the natural gas deviation factor of the original stratum, and is dimensionless; t (T) i Is the original formation temperature, K.
The pore volume of the natural gas in the stratum is as follows:
V H ＝aV (11)
the volume of natural gas dissolved in the formation is:
in the initial state of the gas storage, namely the depleted gas reservoir stratum, the natural gas volume is as follows:
V dep ＝V i [1-c eff (p i -p dep )]+V w_p B w_dep -W e_dep (13)
the volume of dissolved natural gas in the depleted gas reservoir formation is:
wherein: m is a multiple of the water body, and is dimensionless.
The effective compression coefficient is expressed as:
wherein: c f 、c w Rock compression coefficient, stratum water compression coefficient, MPa respectively -1 ；s w Average water saturation for the formation, dimensionless;
formation water (including water body and bound water, etc.):
the value of the ratio a of the displaced water intrusion volume of natural gas to the void-containing space is calculated. From injected CO 2 Molar mass material balance of (2) to give:
wherein: v (V) CO2_inj 、V CO2 、V CO2_dis Respectively injecting CO 2 Volume, formation pore CO 2 Volumetric, dissolved CO 2 Volume, m 3 。
CO in formation pores 2 The volume is as follows:
dissolved CO in a formation 2 The volume is as follows:
wherein: r is R CO2 Is CO 2 Solubility, m 3 /m 3 。
By sorting the formulas (17) to (19), the formula (20) is obtained, and the value of a can be calculated by the newton iterative method.
After obtaining the value of a, the formulas (7) - (16) are arranged to obtain the CO-considered formula (1) 2 As an exhausted gas reservoir capacity evaluation model of the pad gas. The water-soluble gas considered depleted gas reservoir capacity evaluation model can be used for rapidly and effectively evaluating the water-soluble gas considered depleted gas reservoir capacity of the application 2 As a gas reservoir volume for the cushion gas.
In another aspect, the present application also provides a method for considering CO 2 The method for evaluating the capacity of the exhausted gas reservoir as the pad gas comprises the following steps:
s1: build the above consideration of CO 2 As an exhausted gas reservoir capacity evaluation model of the pad gas.
S2: obtaining physical parameters in a target depleted gas reservoir storage capacity evaluation model according to geology, test and production data of the depleted gas reservoir; the physical parameters comprise original geological reserves, water saturation, water body size, depleted stratum temperature, depleted stratum pressure, stratum water invasion under depleted state, accumulated water yield, gas composition and stratum water mineralization.
S3: calculating variable parameters in the depleted gas reservoir capacity evaluation model according to physical parameters of the target depleted gas reservoir; the variable parameters comprise formation water volume coefficient, natural gas deviation factor and CO 2 Deviation factor, natural gas solubility, CO 2 Solubility of the polymer.
In a specific embodiment, the formation water volume factor is calculated by:
wherein: b is the stratum water volume coefficient, dimensionless; deltaV wp 、ΔV wT The method is a stratum water volume coefficient pressure correction term and a stratum water volume coefficient temperature correction term respectively, and is dimensionless.
The natural gas bias factor is calculated by the following formula:
wherein: z is a deviation factor, dimensionless; t (T) pr 、p pr The temperature and the pressure are respectively observed and contrasted, and the dimensionless is achieved; ρ pr Dimensionless for a specifically defined contrast density; p is p pc Is apparent critical pressure, MPa; t (T) pc K is the critical temperature.
Calculating the CO 2 When the factor is deviated, the method is to perform CO 2 The correction is carried out according to the critical temperature and the pressure, and the concrete method for the correction is as follows:
wherein: t'. pc To the corrected visual acuityTemperature, K; y is CO2 Is CO 2 Mole fraction, dimensionless; p's' pc The corrected apparent critical pressure, MPa.
The natural gas solubility is calculated by the formula:
wherein: s is natural gas solubility, m 3 /m 3 The method comprises the steps of carrying out a first treatment on the surface of the m is the mineralization degree of stratum water and g/L.
The CO 2 The solubility is calculated by the following formula:
wherein: r is R CO2 Is CO 2 Solubility, m 3 /m 3 。
The formation water volume factor, the natural gas deviation factor, the natural gas solubility, and the CO of the above embodiment 2 The calculation formula of the solubility is only a preferred calculation method of the application, and more accurate stratum water volume coefficient, natural gas deviation factor and natural gas solubility can be obtained. Other calculation methods for calculating the corresponding parameters in the prior art can also be applied to the application, for example, a method for calculating the volume coefficient of formation water, including McCain formula and Hewlett formula; method for calculating natural gas deviation factor, which is summarized by regression analysis and has Beggs, gopal, kumar, azizi, salarabadi, heidaryan and Moghadasi et al proposed expression, aiming at CO 2 The deviation factor correction method comprises CKB model, WAJ model, guo Xujiang model and the like, and the implicit relation is generally derived from a state equation, and comprises a Van derWaals equation, RK equation, SRK equation, PR equation and other state equations; method for calculating solubility of natural gas with gamma (activity coefficient)(fugacity coefficient) model, ">The model and solubility were calculated using an air gap filling dissolution mechanism.
S4: substituting the parameters obtained in step S2 and step S3 into the consideration CO described in step S1 2 And in the potential evaluation model of the depleted gas reservoir gas storage serving as the pad gas, calculating the target depleted gas reservoir to reconstruct the reservoir capacity of the gas reservoir.
In a specific embodiment, the CO is considered using the application 2 And carrying out reservoir capacity evaluation on the target reservoir by using the depleted reservoir capacity evaluation method for the pad gas. The basic parameters of the target gas reservoir are shown in table 1:
TABLE 1 basic parameters of target gas reservoirs
| Parameters (parameters) | Value of | Parameters (parameters) | Value of |
| Gas reservoir component | 100％CH 4 | Injection component | 100％CH 4 |
| G i | 37000×10 4 [m 3 ] | p dep | 6[MPa] |
| p i | 37[MPa] | V w_p | 12000[m 3 ] |
| M | 10 | T i | 353.15[K] |
| T | 353.15[K] | T dep | 353.15[K] |
| c f | 0.00092[Mpa -1 ] | p sc | 0.101325[Mpa] |
| c w | 0.000455[Mpa -1 ] | T sc | 293.15[K] |
| s w | 0.45 | Z sc | 1 |
| m | 10[g/L] | W e_dep | 200000[m 3 ] |
| R | 0.00831451[J·mol -1 ·k -1 ] | V CO2_inj | 15000/20000/25000×10 4 [m 3 ] |
As shown in fig. 3-5, the existing data is utilized for CO 2 Performing storage capacity evaluation on the gas storage under the gas filling capacity, and performing CO (carbon monoxide) 2 The cushion gas amounts are 15000 multiplied by 10 respectively 4 m 3 、15000×10 4 m 3 、15000×10 4 m 3 When the stratum pressure reaches the original pressure, the natural gas injection amounts are 26921.410 respectively 4 m 3 、22389.910 4 m 3 、17858.310 4 m 3 . Absorbing 18.3 kg of CO according to a tree year 2 Calculated as 15000×10 4 m 3 CO of (c) 2 The absorption capacity of the gas storage cushion gas equivalent to about 1595 ten thousand trees for one year is significant for realizing carbon reduction.
In summary, the application can be used for preparing the catalyst by CO 2 The gas storage used as the gas storage cushion is subjected to the storage capacity evaluation, and the influence of water-soluble gas on the storage capacity is considered in the evaluation process, so that the storage capacity evaluation result is more accurate. Compared with the prior art, the application has obvious progress.
The present application is not limited to the above-mentioned embodiments, but is intended to be limited to the following embodiments, and any modifications, equivalents and modifications can be made to the above-mentioned embodiments without departing from the scope of the application.
Claims (8)
1. Consider CO 2 A method for evaluating the capacity of a depleted gas reservoir as a pad gas, characterized by using a method taking CO into consideration 2 Performing reservoir capacity evaluation as a depleted gas reservoir capacity evaluation model of pad gas, wherein the consideration of CO 2 The depleted gas reservoir storage capacity evaluation model as the pad gas is:
wherein: v (V) inj 、V i 、V w_p The natural gas volume injected under standard conditions, the original hydrocarbon-containing volume of the stratum and the accumulated water yield are respectively, m 3 ；
p、p i 、p dep 、p sc The pressure is respectively the formation pressure, the original formation pressure, the depleted formation pressure and the standard condition pressure, and the pressure is MPa;
a is the proportion of natural gas with water invasion part removed to occupy the air pore space, and the method is dimensionless;
c eff for effective compression coefficient, MPa -1 ；
B w 、B w_dep 、B wi The method comprises the steps of respectively obtaining a stratum water volume coefficient in the injection process, a stratum water volume coefficient in the depleted gas reservoir state and a stratum water volume coefficient in the original stratum state, wherein the stratum water volume coefficient is dimensionless;
W e 、W e_dep respectively the water invasion amount in the injection process and the water invasion amount in the depleted gas reservoir state, m 3 ；
Z H 、Z dep 、Z sc The natural gas deviation factors of the current stratum condition, the depleted stratum condition and the standard condition are respectively dimensionless;
T、T dep 、T sc the temperature of the stratum, the depleted stratum and the standard condition temperature are respectively K;
R H 、R H_dep the solubility of natural gas in the injection process and the solubility of natural gas in the depleted gas reservoir state are respectively m 3 /m 3 ；
s w Average water saturation for the formation, dimensionless; m is a multiple of the water body, and is dimensionless.
2. Consider CO 2 The method for evaluating the capacity of the exhausted gas reservoir as the pad gas is characterized by comprising the following steps of:
s1: establishing the CO-considered of claim 1 2 As an exhausted gas reservoir capacity evaluation model of the pad gas;
s2: obtaining physical parameters in a target depleted gas reservoir storage capacity evaluation model according to geology, test and production data of the depleted gas reservoir;
s3: calculating variable parameters in the depleted gas reservoir capacity evaluation model according to physical parameters of the target depleted gas reservoir;
s4: substituting the physical property parameters obtained in the step S2 and the variable parameters obtained in the step S3 into the consideration CO described in the step S1 2 And in the potential evaluation model of the depleted gas reservoir gas storage serving as the pad gas, calculating the target depleted gas reservoir to reconstruct the reservoir capacity of the gas reservoir.
3. Consideration of CO according to claim 2 2 A method for evaluating the capacity of exhausted gas reservoir as pad gas is characterized in that in step S3, the variable parameters comprise formation water volume coefficient, natural gas deviation factor and CO 2 Deviation factor, natural gas solubility, CO 2 Solubility of the polymer.
4. A CO-considering as claimed in claim 3 2 The method for evaluating the capacity of the depleted gas reservoir as the pad gas is characterized in that the stratum water volume coefficient is calculated by the following formula:
wherein: b is the stratum water volume coefficient, dimensionless; deltaV wp 、ΔV wT Respectively stratum waterA volume coefficient pressure correction term, a formation water volume coefficient temperature correction term, dimensionless.
5. A CO-considering as claimed in claim 3 2 The method for evaluating the capacity of the depleted gas reservoir as the pad gas is characterized in that the natural gas deviation factor is calculated by the following formula:
wherein: z is a deviation factor, dimensionless; t (T) pr 、p pr The temperature and the pressure are respectively observed and contrasted, and the dimensionless is achieved; ρ pr Dimensionless for a specifically defined contrast density; p is p pc Is apparent critical pressure, MPa; t (T) pc K is the critical temperature.
6. Consideration of CO according to claim 5 2 The method for evaluating the capacity of the exhausted gas reservoir as the pad gas is characterized by calculating the CO 2 When the factor is deviated, the method is to perform CO 2 The method for correcting the critical temperature and the critical pressure comprises the following specific steps:
wherein: t'. pc K is the corrected apparent critical temperature; y is CO2 Is CO 2 Mole fraction, dimensionless; p's' pc The corrected apparent critical pressure, MPa.
7. A CO-considering as claimed in claim 3 2 The method for evaluating the capacity of the depleted gas reservoir as the pad gas is characterized in that the solubility of the natural gas is calculated by the following formula:
wherein: s is natural gas solubility, m 3 /m 3 The method comprises the steps of carrying out a first treatment on the surface of the m is the mineralization degree of stratum water and g/L.
8. A CO-considering as claimed in claim 3 2 The method for evaluating the capacity of the exhausted gas reservoir as the pad gas is characterized in that the CO 2 The solubility is calculated by the following formula:
wherein: r is R CO2 Is CO 2 Solubility, m 3 /m 3 The method comprises the steps of carrying out a first treatment on the surface of the m is the mineralization degree of stratum water and g/L.
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