METHOD FOR ESTABLISHING MATHEMATICAL MODEL OF RELATIONSHIP BETWEEN SPONTANEOUS IMBIBITION VOLUME AND TIME OF POROUS MEDIUM

Abstract

A method for establishing mathematical model of relationship between spontaneous imbibition volume and time of porous medium includes sample pretreatment, fully-saturation and centrifugal experiments and NMR T2 measurement. First, two rock core samples of predetermined size are selected for cleaning and drying. The first rock sample is vacuumed and injected with water to obtain a saturated sample for NMR T2 measurement. Then, spontaneous imbibition experiment is conducted on another sample, and T2 measurements are conducted to obtain the water distribution and migration characteristics during the imbibition process. Next, the calculation of the imbibition permeability, average capillary pressure and surface relaxivity are conducted based on the NMR data obtained from two samples. Finally, substitute these parameters into the Handy relationship to obtain a new NMR-based mathematical spontaneous imbibition model.

Description

TECHNICAL FIELD

The present disclosure generally relates to the reservoir evaluation in geology field and, in particular to a method for establishing mathematical model of relationship between spontaneous imbibition volume and time of porous medium on existing technologies.

BACKGROUND

Spontaneous imbibition is a natural phenomenon that the wetting phase fluid flows into the pores in porous media driven by capillary force. It has a broad research space in material science, biology and geology. In petroleum engineering, spontaneous imbibition has a complex impact on the recovery of oil and gas during reservoir development because it not only participates in the production of oil and gas, but also leads to the retention of fracturing fluid. Therefore, the evaluation of the spontaneous imbibition characteristics in tight reservoirs is of great significance to solve the problems related to hydraulic fracturing.

At present, spontaneous imbibition experiment has become a popular method to study the imbibition characteristics of porous media. Many researchers have found that the imbibition velocity is closely related to the porosity, permeability, pore shape, and fluid properties. Previous studies have integrated various parameters, such as the roundness and tortuosity of pores, the gravity of wetting phase fluids and the pore fractal dimension into their derivation process to obtain a more comprehensive imbibition model. However, most of these studies are highly dependent on the traditional methods to calculate the porosity, permeability and mineral composition data, which is difficult to directly reflect the fluid distribution and migration characteristics during imbibition process in different types of porous media. Besides, for porous media with low to ultra-low pore permeability like shales, the accuracy of physical parameters obtained by conventional experimental methods is not high. Thus, the imbibition behavior of tight reservoirs is still poorly understood.

In recent years, nuclear magnetic resonance spectroscopy (NMR) have been widely used to characterize the porosity, permeability and fluid transport in porous media, and the pore size distribution analysis based on NMR T₂ spectra has become a popular method to study imbibition behavior in porous media. The T₂ data interpreted by NMR principles can reflect the characteristics of fluids during transport and migration process, and thus the parameters related to spontaneous imbibition can be obtained directly or indirectly to establish the imbibition model.

Considering the good applicability of the Handy relationship to conventional porous media, lots of existing imbibition models are derived based on it. But for complex porous media, especially in tight reservoirs like shales, the definition of capillary pressure and permeability in the Handy relationship is unclear and hard to obtain, which affects the evaluation of imbibition process during fracturing process. Thus, a comprehensive imbibition model is in great need in the further.

SUMMARY

The present disclosure provides method for establishing mathematical model of relationship between spontaneous imbibition volume and time of porous medium1 based on modifications on a classical Handy relationship.

Specifically, the following is steps to derive a spontaneous imbibition model using rock core plug samples samples.

Step 100, selecting two parallel rock core plug samples for pretreatment, cleaning and drying the two parallel rock core plug samples, evacuating a first rock core plug sample and then injecting the first rock core plug sample with water to obtain a fully-saturated sample; then centrifuging the first rock core plug sample and recording changes of weight and nuclear magnetic resonance (NMR) T₂ distributions to obtain water distribution characteristics of the fully-saturated sample in pores.

Step 200, selecting a second rock core plug sample to conduct spontaneous imbibition experiment, conducting NMR T₂ measurements and weight measurements on the second rock core plug sample to obtain data for water distribution in pores during migration process.

Step 300, plotting cumulative volume distributions of the first rock core plug sample under fully-saturated and imbibition saturated states, calculating a T₂ value (T_2c) when a cumulative volume in fully-saturated distribution equals to a total volume of acentrifuged sample to obtain a centrifugal radius and surface relaxivity through T_2c, then calculating imbibition permeability and average pore pressure through porosity of the first rock core plug, saturation, and the T₂ distribution of the rock core plug sample under the fully-saturated state.

Step 400, inserting the imbibition permeability, the average pore pressure, and the surface relaxivity into a Handy relationship to substitute for corresponding parameters to obtain a mathematical model for the spontaneous imbibition process of porous media basing on NMR,

The present disclosure overcomes the limitations of the calculation method of permeability and capillary pressure in the existing imbibition models based on handy relationship for complex porous media like shale, and provides a new method for the imbibition evaluation in tight reservoirs.

The model proposed in the present disclosure can be applied to simulate the relationship of imbibition volume versus time in porous media, which has broad prospects in petroleum engineering, especially for the evaluation of fracturing fluid migration during hydraulic fracturing in tight reservoirs. Besides, this model can also be applied to study the imbibition behavior of carbonate, sandstone and soil. Besides, it also has wide application prospect in the evaluation of the physical property of man-made materials.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a flowchart of preliminarily obtaining a mathematical model according to one embodiment of the present disclosure.

FIG. 2 is a schematic diagram of NMR T₂ distributions of a2 under saturated and centrifuged states according to one embodiment of the present disclosure.

FIG. 3 is a schematic diagram of cumulative NMR T₂ distribution of sample a2 under saturated and centrifuged state according to one embodiment of the present disclosure.

FIG. 4 is a schematic diagram of NMR T₂ distributions of a1 after spontaneous imbibition experiment according to one embodiment of the present disclosure.

FIG. 5 is a schematic diagram of a relationship of imbibition volume and time of a1 simulated by the model according to one embodiment of the present disclosure.

DETAILED DESCRIPTION

A specific structure and implementation process of the present disclosure are described in detail below with reference to specific embodiments and drawings.

Among existing technologies, a classical Handy relationship is generally selected to derive the mathematical co-current imbibition model to simulate the relationship between imbibition volume and time:

$\begin{array}{cc}M=A\sqrt{\frac{2K\phi S_{w}P}{\mu }t};& \left(1\right)\end{array}$

where M is the volume of imbibed wetting phase fluid (cm³), A is the contact area between wetting phase and porous media (cm²), φ is the porosity, S_w is the wetting phase saturation in porous media, μ is the viscosity of wetting phase (Pa·s), t is the imbibition time (s), and K is the permeability of wetting phase (mD).

Since the Handy relationship lack applicability to the tight reservoirs, the present disclosure uses the imbibition permeability K_imb and average capillary pressure P_ave to substitute for permeability and capillary pressure in conventional imbibition models. In this way, the limitations of the Handy relationship can be solved because the acquisition of permeability and capillary pressure for tight reservoirs will no longer rely on the conventional means which is not suitable for complex porous media. Besides, the calculation methods of new parameters in the present disclosure also provide a new way for spontaneous imbibition evaluation of hydraulic fracturing process of tight reservoirs such as shale.

As shown in FIG. 1, in one embodiment of the present disclosure, a method to establish a mathematical model to evaluate the imbibition volume verses time is disclosed, which comprises the following steps:

Step 100, selecting two parallel rock core plug samples for pretreatment, cleaning and drying the two parallel rock core plug samples, evacuating a first rock core plug sample and then injecting the first rock core plug sample with water to obtain a fully-saturated sample; then centrifuging the first rock core plug sample and recording changes of weight and nuclear magnetic resonance (NMR) T₂ distributions to obtain water distribution characteristics of the fully-saturated sample in pores.

Before experiment, the original core samples need to be calibrated to obtain their NMR base signal. First, the core samples are cleaned and dried until the mass remained unchanged, and then the transverse relaxation time measurement is conducted on each sample to obtain the base signal. The base signals of samples are deducted in the following NAR measurements.

In the present disclosure, the CPMG pulse sequence is applied in NMR measurements, and parameters for all NMR T₂ measurements are set as follows: echo spacing of 0.132 ms, echo numbers of 3788, scan number of 32, and recycle delay of 750 ms.

The selection, preparation and cleaning of rock samples are conducted according to the national standard of GB/T 29172-2012 “Practices for core analysis”. Two parallel core plug samples with 2.5 cm in diameter and 5 cm in height are drilled from the rock vertical to its bedding direction. They are cleaned and dried at 105° C. for 48 hours until mass remained unchanged to remove the residual water. Then, the mass of dry samples m0 are measured using a high precise electronic balance, and their helium porosity φ and contact angle θ are then measured according to the national standard.

The processes of the saturation and centrifugal experiments for the first core sample are: put the first core sample into a vacuum pump and vacuum for 8 h, then inject 3% (about 30000 ppm) KCl solution into the pump and pressurize to 30 MPa (about 3000 psi). Maintain the pressure for 24 hours to ensure the core sample reaches fully-saturated state. The KCl solution used in this step can avoid the swelling of clay in core sample.

After fully-saturated process, the first sample is taken out from pump and the excess liquid is wiped off from surface, then it is weighed and the mass is recorded as m1. After that, the NMR analysis is conducted to obtain the T₂ distribution of pores and the mass of water m (m=m₁-m₀) for the saturated sample.

The saturated sample is then centrifugated under centrifugal pressure P_C, and the mass of sample before and after centrifugation is recorded. NMR measurements are also conducted during this process to obtain the T₂ distributions of fully-saturated and centrifugated sample to provide calculation basis for subsequent calculation.

Step 200, selecting a second rock core plug sample to conduct spontaneous imbibition experiment, conducting NMR T₂ measurements and weight measurements on the second rock core plug sample to obtain data for water distribution in pores during migration process.

Step 300, plotting cumulative volume distributions of the first rock core plug sample under fully-saturated and imbibition saturated states, calculating a T₂ value (T_2c) when a cumulative volume in fully-saturated distribution equals to a total volume of acentrifuged sample to obtain a centrifugal radius and surface relaxivity through T_{2 c}, then calculating imbibition permeability and average pore pressure through porosity of the first rock core plug, saturation, and the T₂ distribution of the rock core plug sample under the fully-saturated state.

To derive the mathematical model for the relationship of imbibition volume versus time, this step needs to calculate the imbibition permeability K_imb and the average pore pressure P_ave first, and the surface relaxivity ρ₂ is necessary to calculate the imbibition permeability K_imb.

T₂ distribution of the porous media after imbibition can directly reflect the relationship of the volume of fluid in pores and its corresponding transverse relaxation time, which is the distribution of pore volume V_{imb (T2)} to T₂ value from T_2max to T_2min. If the porosity and water saturation are known, the imbibition permeability of porous medium can be obtained using the T₂ distribution of the second rock core sample at the end of spontaneous imbibition experiment.

The surface relaxivity of porous media ρ₂ is a constant closely related to its properties, and in the present disclosure the centrifugal method is selected for its calculation, After NMR measurements on the first sample, the T₂ distribution data of fully-saturated and centrifuged states can be obtained. Due to the fluid in pores larger than centrifugal radius can be completely removed from the sample, when the first sample's cumulative amplitude of T₂ distribution of fully-saturated state from T_2min to T_2max equals its total amplitude of T₂ distribution in centrifuged state, this T₂ value is the T_2cutoff (or T_2c) corresponding to centrifugal radius r_c for rock sample.

The relationship between centrifugal pressure P_c and centrifugal radius r_c is:

$\begin{array}{cc}{r}_c=\frac{2\sigma }{P_c}.& \left(2\right)\end{array}$

Besides, according to the principle of NMR, during the measurement, T₂ distribution is affected by three possible relaxation mechanisms: bulk relaxation, surface relaxation and diffusion relaxation. Since most of the fluid in porous media is under capillary bound state and magnetic field can be neglected in this experiment, the resulting NMR measurement can be mainly attributed to surface relaxation T_2s.

$\begin{array}{cc}\frac{1}{T_2}\approx \frac{1}{T_{2S}}={\rho }_2\left(\frac{S_{\mathrm{pore}\left(r\right)}}{V_{\mathrm{pore}\left(r\right)}}\right)& \left(3\right)\end{array}$

where ρ₂ is the surface relaxivity (nm/ms), constant; S_pore(r) and V_pore(r) are the surface area and volume of pores with radius r in porous medium. It can be seen from the relationships above that T₂ is direct proportion to r, and T₂ can be used to evaluate the pore size.

Therefore, ρ₂ can be calculated by inserting r_c, T_2c into relationship (3):

$\begin{array}{cc}{\rho }_2=\frac{r_c}{F_s{T}_{2c}};& \left(4\right)\end{array}$

where Fs is the pore shape factor which is equal to 2 for a cylindrical pore and 3 for a spherical pore.

Based on the understandings above, we can further derive the calculation method for imbibition permeability K_imb:

The Kozeny Carman relationship is a semi empirical relationship frequently used to study the percolation ability of porous media:

$\begin{array}{cc}K=\frac{{\phi }^3}{C{\gamma }^2};& \left(5\right)\end{array}$

where φ is the porosity; C is the Kozeny-Carman constant, which is closely related to pore shape and is equal to 6 for capillaries; γ is the ratio of total surface area of pores to the sample volume (V_sample), which is:

$\begin{array}{cc}\gamma =\frac{S}{V_{\mathrm{sample}}};& \left(6\right)\end{array}$

where S is the total surface area of pores (m²); V_sample is the sample volume (m³).

The derivation of Kozeny-Carman relationship adopted the hypothesis that all pores on flow direction can participate in the imbibition process. However, researchers found that only some portion of the pores can participate during the imbibition process, which means although some sealed pores contribute to the total porosity, they do not participate in the imbibition. Therefore, the parameters in the Kozeny-Carman relationship should be different for the imbibition process.

In this embodiment, the porosity, volume and surface area of pores participated in imbibition in porous medium (called imbibition pores) is recorded as φ_imb, V_imb and S_imb respectively. Thus, V_imb and φ_imb have the following relationship with total porosity φ and saturation S_w:

$\begin{array}{cc}{\phi }_{\mathrm{imb}}=\frac{V_{\mathrm{imb}}}{V_{\mathrm{sample}}}=\frac{{\mathrm{VS}}_w}{V_{\mathrm{sample}}}=\phi S_w;& \left(7\right)\end{array}$

where V is the total pore volume (cm³) which can be obtained by the mass difference of fully-saturated and dry sample.

The imbibition permeability K_imb for imbibition process can be obtained by inserting φ_imb, V_imb and S_imb into the Kozeny-Carman relationship:

$\begin{array}{cc}{K}_{\mathrm{imb}}=\frac{{\phi }_{\mathrm{img}}^3}{C{\gamma }^2}=\frac{{\phi }_{\mathrm{imb}}^3{V}_{\mathrm{sample}}^2}{{\mathrm{CS}}_{\mathrm{imb}}^2}=\frac{{\phi }^3{S}_w^3{V}_{\mathrm{sample}}^2}{{\mathrm{CS}}_{\mathrm{imb}}^2}.& \left(8\right)\end{array}$

During the spontaneous imbibition process, the surface area of imbibition pores S_imb is the sum of the surface area of pores participated in imbibition process, and the volume of sample V_sample equals the ratio of total pore volume and porosity, thus:

$\begin{array}{cc}{S}_{\mathrm{imb}}=\sum _{r=r_{m\mathrm{ax}}}^{r_{\mathrm{ma}x}}{S}_{\mathrm{imb}}\left(r\right);\mathrm{and}& \left(9\right)\end{array}$ $\begin{array}{cc}{V}_{\mathrm{sample}}=\frac{V}{\phi };& \left(10\right)\end{array}$

where r_max is the maximum pore radius and r_min is the minimum pore radius in porous medium; S_imb(r) is the pore surface area of the imbibition pores with radius r. The summation form in relationship (9) means the sum of the surface area of the smallest to largest imbibition pores in porous medium. Inserting Eqs. (9) and (10) into relationship (8) to obtain:

$\begin{array}{cc}{K}_{\mathrm{imb}}=\frac{\phi S_w^3{V}^2}{{C\left(\sum _{r=r_{m\mathrm{ax}}}^{r_{\mathrm{ma}x}}{S}_{\mathrm{imb}}\left(r\right)\right)}^2}.& \left(11\right)\end{array}$

Relationship (11) is the relationship to calculate imbibition permeability.

Meanwhile, relationship (3) can be rewritten as:

$\begin{array}{cc}{S}_{\mathrm{pore}\left(r\right)}=\frac{V_{\mathrm{pore}\left(r\right)}}{{\rho }_2{T}_2}.& \left(12\right)\end{array}$

Replacing S_pore(r) and V_pore(r) with the surface area. S_imb(r) and volume V_imb(r) of imbibition pores in relationship (10) to further transform the relationship to calculate K_imb into:

$\begin{array}{cc}{K}_{\mathrm{imb}}=\frac{{\rho }_2^2\phi S_w^3{V}^2}{{C\left(\sum _{T_2=T_{2\min }}^{T_{2\max }}\frac{V_{\mathrm{imb}\left(T_2\right)}}{T_2}\right)}^2};& \left(13\right)\end{array}$

where T_2min and T_2max are the parameters corresponding to r_min and rmax; S_imb(T2) and V_imb(T2) are the parameters corresponding to S_imb(r) and V_imb(r).

Relationship (13) is the relationship to calculate the imbibition permeability of porous media based on T₂ distribution obtained from imbibition experiment.

Capillary pressure is another important parameter affecting the velocity of imbibition. Considering the complexity of pore network in porous media, the average capillary pressure is needed for the derivation of the imbibition permeability. For a capillary with radius r, its capillary pressure is:

$\begin{array}{cc}P\left(r\right)=\frac{2\mathrm{\sigma cos\theta }}{r};& \left(14\right)\end{array}$

where σ is the surface tension between wetting and non-wetting phases (mN/m); cos θ is the cosine value of the contact angle.

Essentially, the average capillary pressure P_ave is the weighted average value of capillary pressure for the pores with different sizes in porous medium, which can be obtained by:

$\begin{array}{cc}R\left(r\right)=\frac{V_{\mathrm{pore}\left(r\right)}}{Y};& \left(15\right)\end{array}$

where V_pore(r) is the volume of pores with radius r in porous medium.

Therefore, the average pore pressure is the sum of the production of capillary pressure P(r) and its corresponding proportion R(r):

$\begin{array}{cc}{P}_{\mathrm{ave}}=\sum _{r=r_{\min }}^{r_{\max }}R\left(r\right)P\left(r\right)=\frac{2\mathrm{\sigma cos\theta }}{V}\sum _{r=r_{\min }}^{r_{\max }}\frac{V_{\mathrm{pore}\left(r\right)}}{r}.& \left(16\right)\end{array}$

Similar to relationship (13), the pore radius r can be substituted by T₂ in relationship (16):

$\begin{array}{cc}{P}_{\mathrm{ave}}=\frac{2\mathrm{\sigma cos\theta }}{F_s{\rho }_{2}V}\sum _{T_2=T_{2\min }}^{T_{2\max }}\frac{V_{\mathrm{pore}\left(T_2\right)}}{T_2}.& \left(17\right)\end{array}$

Relationship (17) is the relationship to calculate the average pore pressure P_ave based on T₂ distribution of saturated porous medium.

The relationship between T₂ value and volume of pores in rock core sample can be obtained using the T₂ distribution of the first sample, and then the average pore pressure can be obtained using relationship (17).

Step 400, inserting the imbibition permeability, the average pore pressure, and the surface relaxivity into a Handy relationship to substitute for corresponding parameters to obtain a mathematical model for the spontaneous imbibition process of porous media basing on NMR.

Inserting the imbibition permeability K_imb and the average pore pressure P_ave obtained by the steps above (Eqs. 13 and 17) into relationship (1):

$\begin{array}{cc}M=A\sqrt{\frac{2K_{\mathrm{imb}}\phi S_w{P}_{\mathrm{ave}}}{\mu }t}=\frac{2A\phi S_w^{3}V}{\sum _{T_2=T_{2\min }}^{T_{2\max }}\frac{V_{\mathrm{imb}\left(T_2\right)}}{T_2}}\sqrt{\frac{{\rho }_a\sigma \cos \theta \sum _{T_2=T_{2\min }}^{T_{2\max }}\frac{V_{\mathrm{pore}\left(T_2\right)}}{T_2}}{{\mathrm{CF}}_{2}V\mu }t}.& \left(18\right)\end{array}$

In this relationship, the pore shape factor Fs equals 2 and the Kozeny-Carman constant C equals 6 for cylindrical pores;

Relationship (18) is the imbibition model for the imbibition volume versus time in porous media based on NMR theory. The calculation of this model can either be conducted by inserting K_imb and P_ave into relationship (1) or directly use relationship (18). But it should be noticed that the parameter V_imb(T2) in relationship (18) is different from V_pore(T2), which represent the pore volume corresponding to T₂ value under saturation state during spontaneous imbibition and the pore volume corresponding to T₂ value of saturated fluid sample respectively.

The following is a brief description of the step for this embodiment:

Sample Pretreatment and Basic Analysis

The selection, preparation and cleaning of rock samples are conducted according to the national standard of GB/T 29172-2012 “Practices for core analysis”. Two parallel core plug samples with 2.5 cm in diameter and 5 cm in height are drilled from the rock vertical to its bedding direction. They are cleaned and dried at 105° C. for 48 hours until mass remained unchanged to ensure there is no residual water in pores. Then, the mass of dry samples m0 is measured using a high precise electronic balance, and their helium porosity φ and contact angle θ are then measured according to the national standard.

NMR Measurement Under Saturated State for Base Signal

In this experiment, the CPMG pulse sequence is applied in NMR measurements, and parameters for all NMR T₂ measurements are set as follows: echo spacing of 0.132 ms, echo numbers of 3788, scan number of 32, and recycle delay of 750 ms. These parameters are set as default in all NMR T₂ measurements in the present disclosure.

The calibration is conducted on the rock sample for their base signal before experiment. After preparation, two dry core plug samples are conducted on NMR experiment to Obtain the samples' T₂ distributions under dry state, which are considered to be the base signal in the following experiments. Then, the first sample is conducted on the fully-saturated and centrifuged experiments. First, put the first core sample into a vacuum pump and vacuum for 8 h, then inject 3% (about 30000 ppm) KCl solution into the pump and pressurize to 30 MPa (about 3000 psi). Maintain the pressure for 24 hours to ensure the core sample reaches fully-saturated state. The KCl solution used in this step can avoid the swelling of clay in core sample.

After the fully-saturated process, the first sample is taken out from pump and the excess liquid is wiped off from surface, then it is weighed and the mass is recorded as m1. After that, the NMR analysis is conducted to obtain the T₂ distribution of pores and the mass of water m(m=m₁-m₀) for the saturated sample.

Centrifugation and the Calculation of Surface Relaxivity

The saturated sample is then centrifuged under centrifugal pressure P_c, and the mass of sample before and after centrifugation is recorded. NMR T₂ measurements are also conducted during this process to obtain the T₂ distributions under fully-saturated and centrifuged states, and the sample's T_2c is calculated using these data. Then, the centrifugal radius r_c is calculated by substituting P_c into relationship (2), and the surface relaxivity ρ₂ can be obtained using relationship (4).

The Calculation of the Mathematical Model for Spontaneous Imbibition

The imbibition permeability K_imb can be obtained by substituting T₂ distributions of the first sample under fully-saturated and centrifuged states and T₂ distribution of the second sample under imbibition saturated state into relationship (13). Then, the average pore pressure can be obtained by substituting T₂ distribution of the first sample under fully-saturated state into relationship (17). Finally, the NMR-based mathematical model for spontaneous imbibition can be obtained by inserting P_ave and K_imb into relationship (18).

The present disclosure overcomes the limitations in the traditional Handy model that the permeability and capillary pressure is hard to obtain and lacks accuracy by traditional experimental methods. Besides, the present disclosure also provides a new approach to evaluate the influence of imbibition on hydraulic fracturing during the development of tight reservoirs like shales.

The present disclosure is able to predict the relationship of imbibition volume versus time and can be used for the analysis of the performance of hydraulic fracturing of tight reservoirs in petroleum engineering, and it also has broad application prospects to study physical properties in petrology and material science. Apart from tight reservoir rocks such as shales, it is also suitable for the study of other kinds of natural porous media such as sandstones, carbonate rocks and soil. Meanwhile, it also has application prospects to evaluate the physical property of some man-made materials.

The scheme of the present disclosure is further described below with specific embodiments.

In this embodiment, the spontaneous imbibition process of shale core plug samples was taken as an example, and distilled water (with ρ=1 g/cm³ and σ=72.75 mN/m) was chosen as the working liquid. The experiment was conducted at ambient temperature (20° C.) and pressure (0.1 MPa), The helium porosity is of the rock sample was 4.52%.

Two paralleled core plug samples with 2.5 cm in diameter and 5 cm in height were drilled from the shale sample marked a1, a2. The masses of sample a1, a2 were 61.31 g and 61.88 g, and the contact angels of them were 41.11° and 44.74° respectively. The pores in shale is regarded as capillaries, and thus the pore shape factor Fs equals 2 and Kozeny-Carman constant C equals 6 in this experiment.

Sample a2 was selected to conduct the fully saturated and centrifugal experiments and sample a1 was selected to conduct the spontaneous imbibition experiment. FIG. 2 is the T₂ distributions of sample a2 under fully-saturated and centrifuged (P_c=2.74 MPa) states. According to relationship (2), the centrifugal radius r_c is:

$r_c=\frac{2\sigma }{P_c}=\frac{2\times 72.75\mathrm{mN}/m}{2.74\mathrm{MPa}}=53.1\mathrm{nm}$

The volume of water in a2 under fully-saturated state is 1.16 cm³ (similar to the volume calculated by helium porosity), and after centrifugation there is still 0.89 cm³ residual water in it. In FIG. 3, it can be seen that the cumulative volume of a2 when T₂=3.98 ms under fully-saturated state equals the total water volume under centrifuged state. Thus, T_2c equals 3.98 ms and the surface relaxivity can be calculated using relationship (4):

${\rho }_2=\frac{r_c}{F_s{T}_{2c}}=\frac{53.1\mathrm{nm}}{2\times 3.98\mathrm{ms}}=6.67\mathrm{nm}/\mathrm{ms}$

The water volume of a2 (1.16 cm³) under saturated state is its total pore volume V, and P_ave can be obtained by inserting the data of fully-saturated T₂ distribution in FIG. 2 into relationship (17):

$P_{ave}=\frac{2\mathrm{\sigma cos\theta }}{F_s{\rho }_{2}V}\sum _{T_2=T_{2\min }}^{T_{2\max }}\frac{V_{\mathrm{pore}\left(T_2\right)}}{T_2}=\frac{2\times 72.75\mathrm{mN}/m\times \cos {44.74}^{\circ }}{2\times 6.67\mathrm{nm}/\mathrm{ms}\times 1.16{\mathrm{cm}}^3}\times 0.93{\mathrm{cm}}^3/\mathrm{ms}=6.19\mathrm{MPa}$

FIG. 4 is the NMR T₂ distributions of a1 during imbibition process. It can be calculated that the maximum imbibition volume of a1 is 0.35 cm³, and the corresponding saturation S_w is 31.98% (take a2 as the standard). Based on the T₂ distribution of a1 under imbibition saturated state, the imbibition permeability K_imb of a1 can be obtained by using relationship (13):

$K_{\mathrm{imb}}=\frac{{\rho }_2^2\phi S_w^3{V}^2}{{C\left(\sum _{T_2=T_{2\min }}^{T_{2\max }}\frac{V_{\mathrm{imb}\left(T_2\right)}}{T_2}\right)}^2}=\frac{{\left(6.6\mathrm{nm}/\mathrm{ms}\right)}^2\times 00452\times {\left(0.3198\right)}^3\times {\left(1.1{\mathrm{cm}}^3\right)}^2}{6\times {\left(1.15{\mathrm{cm}}^3/\mathrm{ms}\right)}^2}=1.18\times {10}^{-5}\mathrm{mD}$

As K_imb and P_ave are known, the mathematical model of imbibition volume versus time for the rock core samples can be obtained:

$M=A\sqrt{\frac{2K_1\phi S_w{P}_{\mathrm{ave}}}{\mu }t}=4.91{\mathrm{cm}}^2\times \sqrt{\frac{2\times 1.15\times {10}^{-5}\mathrm{mD}\times 0.0452\times 1.3198\times 6.18\mathrm{MPa}}{0.89\times {10}^{-3}\mathrm{Pa}·s}t}=4.29\times {10}^{-2}{\min }^{-0.5}\times \sqrt{t}$

The simulation of new spontaneous imbibition model for a1 is shown in FIG. 5.

So far, the researchers in this field should recognize that although a plurality of exemplary embodiments of the present disclosure have been shown and described in detail, many other variants or modifications in accordance with the principles of the present disclosure can be directly determined or derived from the contents of the present disclosure without departing from the spirit and scope.

Claims

1. A method for establishing mathematical model of relationship between spontaneous imbibition volume and time of porous medium, comprising following steps: step 100, selecting two parallel rock core plug samples for pretreatment, cleaning and drying the two parallel rock core plug samples, evacuating a first rock core plug sample and then injecting the first rock core plug sample with water to obtain a fully-saturated sample; then centrifuging the first rock core plug sample and recording changes of weight and nuclear magnetic resonance (NMR) T2 distributions to obtain water distribution characteristics of the fully-saturated sample in pores;step 200, selecting a second rock core plug sample to conduct spontaneous imbibition experiment, conducting NMR T2 measurements and weight measurements on the second rock core plug sample to obtain data for water distribution in pores during migration process;step 300, plotting cumulative volume distributions of the first rock core plug sample under fully-saturated and imbibition saturated states, calculating a T2 value (T2c) when a cumulative volume in fully-saturated distribution equals to a total volume of acentrifuged sample to obtain a centrifugal radius and surface relaxivity through T2c then calculating imbibition permeability and average pore pressure through porosity of the first rock core plug, saturation, and the T2 distribution of the rock core plug sample under the fully-saturated state; andstep 400, inserting the imbibition permeability, the average pore pressure, and the surface relaxivity into a Handy relationship to substitute for corresponding parameters to obtain a mathematical model for the spontaneous imbibition process of porous media basing on NMR.

2. The method for establishing mathematical model of relationship between spontaneous imbibition volume and time of porous medium according to claim 1, wherein in step 300, an relationship to calculate the imbibition permeability Kimb of the porous medium based on the imbibition saturated T2 distribution data is as following:

3. The method for establishing mathematical model of relationship between spontaneous imbibition volume and time of porous medium according to claim 2, wherein a calculation process of the imbibition permeability Kimb is as following: predicting relationshipa semi empirical relationship frequently configued to study permeability of the porous medium according to the Kozeny-Carman relationship:

4. The method for establishing mathematical model of relationship between spontaneous imbibition volume and time of porous medium according to claim 3, wherein a calculation process of the surface relaxivity ρ2 mentioned in the calculation of the imbibition permeability Kimb is as following: satisfying a relationship between centrifugal pressure Pc and centrifugal radius rc as following:

5. The method for establishing mathematical model of relationship between spontaneous imbibition volume and time of porous medium according to claim 4, wherein a process to calculate the centrifugal radius rc under centrifugal pressure Pc using the pore radius obtained by T2 value is as following: if the pores larger than centrifugal radius in rock core sample can be completely discharged after centrifugation, obtaining the centrifugal radius through the cumulative T2 distributions of the sample, because if the total T2 signal under centrifuged state equals the cumulative T2 signal when the transverse relaxation time equals T2, regarding transverse relaxation time value as the T2 value corresponding to the centrifuged radius rc.

6. The method for establishing mathematical model of relationship between spontaneous imbibition volume and time of porous medium according to claim 1, a calculation process of Pave in step 300 is as following: regarding the pores as capillaries in the porous medium, the capillary pressure P(r) for pores with radius r satisfies a following relationship:

7. The method for establishing mathematical model of relationship between spontaneous imbibition volume and time of porous medium according to claim 1, wherein the mathematical model in step 400 is as follows: