Method, device, equipment and medium for predicting imbibition utilization efficiency of interlayer type shale oil

Abstract

The invention relates to the technical field of unconventional shale oil and gas reservoir exploration, in particular to a method, a device, equipment and a medium for predicting the imbibition utilization efficiency of interlayer type shale oil. According to the method disclosed by the invention, the imbibition utilization efficiency of the interlayer type shale oil can be quickly predicted, and an effective means is provided for revealing an interaction reaction mechanism of shale oil reservoir rock and an injected medium, a shale oil reservoir rock imbibition oil extraction mechanism, a shale oil reservoir recovery efficiency improving mechanism and the like. According to the present invention, the imbibition oil discharge indoor test under the oil reservoir temperature and pressure condition is combined with the two-dimensional nuclear magnetic analysis, and the use conditions of the crude oil in different aperture spaces are distinguished according to the two-dimensional nuclear magnetic T1 and T2 spectrograms of the nuclear magnetic diagnosis, such that the respective imbibition oil discharge efficiency functions and the overall critical use lower limit of different aperture intervals are established so as to be adopted as the data volume model; the invention provides a method for rapidly predicting the imbibition utilization efficiency of the interlayer type shale oil by using a two-dimensional nuclear magnetic technology under the conditions of rapidness, accuracy and no damage to the rock core.

Description

Technical Field

[0001] This disclosure relates to the field of unconventional shale oil and gas reservoir exploration technology, and in particular to methods, apparatus, equipment and media for predicting the permeation and mobilization efficiency of interlayered shale oil. Background Technology

[0002] Shale oil and gas resources are widely distributed and have enormous potential, making them an important strategic alternative energy source. However, achieving large-scale, efficient development remains the biggest challenge. Shale oil reservoirs exhibit multi-scale pore-throat structures, with widespread micro- and nano-scale pores and throats. Compared to conventional reservoirs, they possess higher capillary forces and more pronounced adsorption-driven oil recovery. Adsorption-driven oil recovery refers to the process where, when fractures surrounding the matrix rock block are filled with water, the injected water from the fractures or large pores is drawn into the matrix rock block by capillary forces, displacing the crude oil in the matrix and thus achieving a redistribution of oil and water outside the matrix. Adsorption occurs in several key stages of shale oil reservoir development, including volumetric fracturing and water injection, and is one of the important factors affecting shale oil production capacity. Clarifying the characteristics of adsorption and evaluating its utilization efficiency are of great significance for improving shale oil recovery rates.

[0003] Interlayer shale oil belongs to the source-reservoir coexistence type of shale oil. Its shale strata are generally oil-bearing, and thin sand layers are powerful reservoirs that capture oil near the source to form "sweet spots". Therefore, its sweet spot reservoirs are mostly thin sandstone layers.

[0004] In existing technologies, the evaluation of shale oil percolation efficiency is mainly characterized by laboratory tests of self-percolation oil discharge, which are categorized into mass method, volume method, and nuclear magnetic resonance (NMR) method. The mass method involves treating shale cores and placing them in a pre-prepared percolation solution. During percolation, the core mass changes, and this change is monitored over time using an electronic balance. The volume method utilizes a self-made laboratory water absorption instrument. The treated core is placed in the pre-prepared percolation solution, and the volume of oil discharged is recorded over time. The NMR method uses the T2 spectrum obtained during the percolation experiment to distinguish the fluid movement in different pore sizes. The mass and volume methods involve relatively cumbersome manual measurement and are prone to significant errors. While NMR provides precise measurement, a single-dimensional NMR signal cannot distinguish between oil and water signals, requiring the addition of heavy water or soaking in strong water to eliminate the water signal. Furthermore, these methods require relatively long percolation experiments (more than one month) to determine percolation efficiency, and the cores subjected to chemical percolation experiments are contaminated and damaged, making further experiments impossible.

[0005] In summary, there is an urgent need for a technical solution for rapidly predicting the percolation and utilization efficiency of interlayered shale oil. Summary of the Invention

[0006] To address the aforementioned issues, this disclosure provides a method, apparatus, equipment, and medium for predicting the adsorption and mobilization efficiency of interlayered shale oil, thus resolving the problems of excessively long experimental cycles and core contamination damage in existing shale oil adsorption and mobilization efficiency evaluation methods.

[0007] In a first aspect, a method for predicting the adsorption and utilization efficiency of interlayered shale oil, the method comprising:

[0008] Samples were taken from the sweet spot reservoir of interlayered shale oil, and several rock samples were prepared for testing.

[0009] Two-dimensional nuclear magnetic resonance (NMR) was measured on several rock samples to establish a two-dimensional NMR map of the work area;

[0010] Determine the original oil content signal under saturated oil conditions and the residual oil signal at each measurement point after permeation;

[0011] The permeability of the rock sample was obtained by measuring the original oil-bearing signal in the saturated oil state and the remaining oil signal at each measurement point after permeation.

[0012] Fresh core samples of interbedded shale oil from the target block to be predicted are drilled, and the oil-bearing signal intensity of the fresh samples is determined; the total oil signal intensity of the fresh samples is determined based on the oil-bearing signal intensity of the fresh samples.

[0013] The total oil signal after permeation of shale oil cores is determined based on the oil signal quantity of fresh samples and the permeation rate of rock samples.

[0014] The efficiency of the fresh sample core permeation was determined by summing the oil signal quantities of the fresh sample and summing the oil signal quantities of the shale oil core after permeation.

[0015] Furthermore, two-dimensional nuclear magnetic resonance (NMR) analyses were performed on several rock samples, including:

[0016] For all samples, the selected measurement mode was IR-CPMG mode, and two-dimensional NMR was measured to determine the following locations:

[0017] Determine the location of kerogen, clay-bound water, and structural water;

[0018] Determine the location of the water;

[0019] Determine the location of capillary-bound water and movable water;

[0020] Determine the location of the oil;

[0021] Determine the positions of the movable oil and the restraining oil.

[0022] Furthermore, the two-dimensional nuclear magnetic resonance (NMR) measurements of several rock samples also included:

[0023] Two-dimensional nuclear magnetic resonance (NMR) values ​​T1 and T2 were obtained for the rock samples, and the locations of oil and water were identified based on T1, T2, and the T1 / T2 ratio.

[0024] Further, the location of kerogen, clay-bound water, and structural water was determined, including:

[0025] The sample was washed with oil and dried, and two-dimensional NMR was measured to determine the location of kerogen, clay-bound water, and structural water.

[0026] Further, determining the location of the water includes:

[0027] The sample was washed with oil and saturated with water, and two-dimensional NMR was measured to determine the location of the water.

[0028] Further, the location of capillary-bound and mobile water was determined, including:

[0029] After washing the sample with oil and saturated water, centrifuge it. After centrifugation, NMR is measured to distinguish the location of capillary bound water and mobile water.

[0030] Further, determining the location of the oil includes:

[0031] The sample was dried and saturated with oil, and two-dimensional NMR was measured to determine the location of the oil.

[0032] Further, the locations of the movable and restraining oils are determined, including:

[0033] The sample was dried and saturated with oil before centrifugation. Two-dimensional NMR was measured to distinguish the location of mobile and bound oil.

[0034] Furthermore, a two-dimensional NMR map of the work area is established, including:

[0035] The locations of kerogen, clay-bound water and structural water, water, capillary-bound water and movable water, oil, and movable and bound oil were plotted on a two-dimensional graph with T1 spectrum as the ordinate and T2 spectrum as the abscissa, resulting in a two-dimensional NMR plate.

[0036] Furthermore, the original oil content signal under saturated oil conditions is determined, including:

[0037] After washing the oil, the core was placed into a piston container, vacuumed for M1 hours, saturated with simulated shale oil under pressure K, aged in a constant temperature chamber for M2 hours, and then the core was taken out and weighed.

[0038] Two-dimensional nuclear magnetic resonance (NMR) was used to determine the T1 and T2 spectra after oil saturation without damaging the core. Oil-water regions were divided on the two-dimensional NMR chart, and the oil signal display area containing bound oil and mesoporous oil was selected. Software quantified the oil signal quantity W in different pore sizes of each core under oil saturation conditions. xy，饱和, where x is the coordinate value of T2 and y is the coordinate value of T1.

[0039] Furthermore, the residual oil signal at each measurement point after absorption includes:

[0040] Saturated oil cores were placed in piston containers, and permeation media were added. The piston containers were then placed in a constant temperature chamber, set to the formation temperature, and pressurized to the reservoir pressure to conduct permeation experiments. After day 1 of the experiment, the cores were removed and weighed, and the T1 and T2 spectra after permeation were tested using two-dimensional nuclear magnetic resonance technology.

[0041] Software quantifies the amount of oil signal W in different pore sizes after permeation of each core sample. xy，渗吸后 , where x is the coordinate value of T2 and y is the coordinate value of T1.

[0042] Furthermore, the permeability of the rock sample is obtained by using the original oil-bearing signal in the saturated oil state and the residual oil signal at each measurement point after permeation, including:

[0043] Saturated oil state signal W for each aperture space xy，饱和 And the oil signal quantity W after absorption xy，渗吸后 The difference before and after is the change in seepage at this coordinate position before and after, and the change is related to W. xy，饱和 The ratio is the rock sample permeability, where x is the T2 coordinate value and y is the T1 coordinate value.

[0044] Furthermore, the change is related to W. xy，饱和 The ratio is the rock sample permeability, including:

[0045] The permeation rate I at each oil signal location in the two-dimensional nuclear magnetic resonance image at different T1 and T2 coordinates is calculated using the following formula. xy :

[0046] I xy =(W xy，饱和 -W xy，渗吸后 ) / W xy，饱和 ;

[0047] Among them, I xy This represents the permeation rate of the rock sample at points T2 = x and T1 = y; W xy，渗吸后 W represents the oil signal quantity after seepage at points T2 = x and T1 = y; xy，饱和 This represents the oil signal quantity under saturated oil conditions at points T2 = x and T1 = y.

[0048] Furthermore, the permeability of the rock sample is obtained by using the original oil-bearing signal in the saturated oil state and the remaining oil signal at each measurement point after permeation. This also includes:

[0049] Based on the permeability of each shale reservoir core at different T1 and T2 coordinates, the average value of the permeability at the same T1 and T2 coordinates is calculated to obtain the final permeability of the rock sample, as shown in the following formula:

[0050]

[0051] Among them, I xy,最终 This represents the final absorption rate at point T2 = x, T1 = y; x n This represents the nth value; n represents the total number of valid data samples.

[0052] Furthermore, fresh samples of interlayered shale oil from the target block to be predicted are drilled, the oil-bearing signal intensity of the fresh samples is determined, and the total oil signal intensity of the fresh samples is determined based on the oil-bearing signal intensity, including:

[0053] Fresh samples of interbedded shale oil from the target block were drilled, and the T1 and T2 spectra of the fresh samples were determined using two-dimensional nuclear magnetic resonance technology without damaging the core.

[0054] Software quantifies the amount of oil signal W in different pore sizes of each fresh core sample. xy，新鲜 Then, the oil signal data of all fresh sample oil signal points are summed to obtain the oil content signal W of the fresh sample. 总和，新鲜 , where x is the coordinate value of T2 and y is the coordinate value of T1.

[0055] Furthermore, based on the oil signal intensity of the fresh sample and the permeability of the rock sample, the total oil signal intensity after permeation in the shale oil core is determined, including:

[0056] Calculate the oil signal quantity W after seepage at different T1 and T2 coordinates. xy，渗吸后 The formula is as follows:

[0057] W xy，渗吸后 =W xy，新鲜 -W xy，新鲜 ×I xy,最终 ;

[0058] Among them, I xy,最终 W represents the final absorption rate at points T2 = x and T1 = y. xy，新鲜 W represents the oil signal quantity at points T2 = x and T1 = y for fresh samples; xy，渗吸后 This represents the oil signal quantity at points T2=x and T1=y after percolation.

[0059] W xy，渗吸后 Summing all the oil signal data after infiltration yields the total oil signal W from the shale oil core after infiltration. 总和，渗吸后 .

[0060] Furthermore, the efficiency of the fresh sample core adsorption was determined by summing the oil signal quantities of the fresh sample and summing the oil signal quantities of the shale oil core after adsorption, including:

[0061] The sum of the signal quantities of the fresh sample oil W 总和，新鲜 The sum of oil signal quantities W after permeation and adsorption of shale oil cores 总和，渗吸后 The data was used to calculate the seepage and mobilization efficiency I of the shale oil core in this block. The formula is as follows:

[0062]

[0063] Among them, W 总和，新鲜 W represents the sum of the signal quantities of the fresh sample oil; 总和，渗吸后 This represents the total oil signal after seepage into the shale oil core; I represents the seepage utilization efficiency of this core.

[0064] Secondly, an apparatus for predicting the permeation and utilization efficiency of interlayered shale oil includes: a rock sample preparation unit, a two-dimensional nuclear magnetic resonance plate establishment unit, a rock sample permeation rate determination unit, and a permeation and utilization efficiency determination unit.

[0065] The rock sample preparation unit is used to sample the sweet spot reservoir of interlayered shale oil and prepare several rock samples for testing.

[0066] The two-dimensional NMR plate establishment unit is used to measure the two-dimensional NMR of several rock samples to establish a two-dimensional NMR plate for the work area.

[0067] The rock sample permeability determination unit is used to determine the original oil-bearing signal quantity under saturated oil conditions and the remaining oil signal quantity at each measurement point after permeation.

[0068] The rock sample permeability determination unit is also used to obtain the rock sample permeability by using the original oil-bearing signal quantity under saturated oil conditions and the remaining oil signal quantity at each measurement point after permeation.

[0069] The percolation efficiency determination unit is used to drill fresh core samples of interlayered shale oil in the target block to be predicted, determine the oil-bearing signal of the fresh sample, and determine the total oil signal of the fresh sample based on the oil-bearing signal of the fresh sample.

[0070] The permeation mobilization efficiency determination unit is also used to determine the total oil signal after permeation of shale oil core based on the oil signal quantity of fresh sample and the permeation rate value of rock sample;

[0071] The infiltration efficiency determination unit is also used to determine the infiltration efficiency of fresh sample cores by using the sum of oil signal quantities of fresh sample cores and the sum of oil signal quantities after infiltration of shale oil cores.

[0072] Thirdly, an electronic device includes a processor, a communication interface, a memory, and a communication bus, wherein the processor, the communication interface, and the memory communicate with each other through the communication bus;

[0073] Memory, which stores computer programs;

[0074] When a processor executes a computer program stored in memory, it implements the above-described method for predicting the percolation and mobilization efficiency of interlayer shale oil.

[0075] Fourthly, a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method for predicting the percolation and utilization efficiency of interlayer shale oil.

[0076] This disclosure includes at least the following beneficial effects:

[0077] This disclosure rapidly quantifies the oil content in different pore size ranges of shale oil cores after pressurization and saturation (fresh samples) without damaging the core, using two-dimensional nuclear magnetic resonance (NMR) technology. Furthermore, by utilizing the adsorption and drainage efficiency functions for different pore size ranges of shale oil under formation conditions established in this disclosure, as well as the overall critical utilization lower limit, the overall adsorption and drainage efficiency of shale oil cores can be rapidly and accurately quantitatively characterized. This method enables rapid, accurate, and non-destructive determination of shale oil core adsorption and utilization efficiency. It provides an effective means to elucidate the interaction mechanism between shale oil reservoir rocks and the injection medium, the adsorption and recovery mechanism of shale oil reservoir rocks, and the enhanced oil recovery mechanism of shale oil reservoirs. This method has significant engineering value and scientific significance for promoting the effective and economical development of shale reservoirs.

[0078] Other features and advantages of this disclosure will be set forth in the following description and will be apparent in part from the description or may be learned by practicing the disclosure. The objects and other advantages of this disclosure may be realized and obtained by means of the structures pointed out in the description and the accompanying drawings. Attached Figure Description

[0079] To more clearly illustrate the technical solutions in the embodiments of this disclosure or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are some embodiments of this disclosure. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0080] Figure 1 This is a schematic diagram of the prediction method flow according to an embodiment of the present disclosure;

[0081] Figure 2 A schematic diagram of a representative core sample from a layered shale reservoir in a certain block;

[0082] Figure 3 A schematic diagram of a representative core sample from a two-layered shale reservoir in a certain block;

[0083] Figure 4 This is a schematic diagram of the two-dimensional nuclear magnetic fluid distribution location template;

[0084] Figure 5 This is a schematic diagram of a two-dimensional nuclear magnetic resonance (NMR) plot of fluid distribution in a pre-determined interlayer shale oil study area.

[0085] Figure 6 This is a schematic diagram of a two-dimensional nuclear magnetic resonance image of fluid distribution in a certain interlayered shale oil study area after measurement.

[0086] Figure 7 A schematic diagram showing the results of two-dimensional nuclear magnetic resonance quantification of oil content in different pore size ranges for pressurized saturated oil in a certain rock core;

[0087] Figure 8 A schematic diagram showing the results of two-dimensional nuclear magnetic resonance quantification of the remaining oil content in different pore size ranges after percolation of a certain rock core;

[0088] Figure 9 This is a schematic diagram of the predictive device structure according to an embodiment of the present disclosure;

[0089] Figure 10 This is a schematic diagram of the electronic device structure according to an embodiment of the present disclosure. Detailed Implementation

[0090] To make the objectives, technical solutions, and advantages of the embodiments of this disclosure clearer, the technical solutions of the embodiments of this disclosure will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this disclosure, and not all embodiments. Based on the embodiments of this disclosure, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this disclosure.

[0091] like Figure 1 As shown, a method for predicting the adsorption and utilization efficiency of interlayered shale oil is provided, the method comprising:

[0092] S101, samples were taken from the sweet spot reservoir of interlayered shale oil, and several rock samples were prepared for testing;

[0093] S102, Two-dimensional nuclear magnetic resonance (NMR) was measured on several rock samples to establish a two-dimensional NMR map of the work area;

[0094] S103, determine the original oil content signal under saturated oil conditions and the remaining oil signal at each measurement point after permeation;

[0095] S104, the permeability of the rock sample is obtained by using the original oil-bearing signal in the saturated oil state and the remaining oil signal at each measurement point after permeation;

[0096] S105, drill fresh core samples of interbedded shale oil in the target block to be predicted, and determine the oil-bearing signal of the fresh samples; determine the total oil signal of the fresh samples based on the oil-bearing signal of the fresh samples.

[0097] S106, Based on the oil signal quantity of fresh samples and the permeability of rock samples, determine the total oil signal quantity after permeation of shale oil cores;

[0098] S107. The efficiency of the fresh sample core permeation is determined by the sum of the oil signal quantities of the fresh sample and the sum of the oil signal quantities after the shale oil core permeation.

[0099] The specific implementation details are as follows:

[0100] This disclosed method can rapidly predict the adsorption and recovery efficiency of interlayered shale oil. It provides an effective means to elucidate the interaction mechanism between shale oil reservoir rocks and the injection medium, the adsorption and recovery mechanism of shale oil reservoir rocks, and the enhanced oil recovery mechanism of shale oil reservoirs. This disclosure combines laboratory tests of adsorption and drainage under reservoir temperature and pressure conditions with two-dimensional nuclear magnetic resonance (NMR) analysis. Based on the T1 and T2 NMR spectra obtained from the NMR diagnosis, the recovery of crude oil in different pore sizes is distinguished. Furthermore, adsorption and drainage efficiency functions for different pore size ranges and the overall critical recovery lower limit are established. Using this as a data volume model, a rapid, accurate, and non-core-damaging method for quickly predicting the adsorption and recovery efficiency of interlayered shale oil using two-dimensional NMR technology is presented.

[0101] This disclosure describes a rapid, accurate, and non-destructive method for predicting shale oil adsorption and utilization efficiency using two-dimensional nuclear magnetic resonance (NMR) technology. The following detailed description, in conjunction with the accompanying drawings, further illustrates this disclosure.

[0102] I. Rock Sample Preparation:

[0103] S101, an interlayered shale oil, belongs to the source-reservoir coexisting type of shale oil. Its shale formations are generally oil-bearing, with thin sandstone layers acting as powerful reservoirs near the source, forming "sweet spots" where oil is captured. Therefore, its sweet spot reservoirs are mostly thin sandstone layers. Based on the reservoir properties of an interlayered shale oil in a specific target block, well logging facies technology is used to identify the properties at different locations along the wellbore, such as... Figure 2 and Figure 3 As shown, Figure 2 This is a schematic diagram of a representative core sample from a layered shale reservoir in a certain block. Figure 3 This is a schematic diagram of a representative core from a two-layered shale reservoir in a certain block. Several cores of each physical property level (core diameter 2.5cm, core length approximately 8cm) were drilled, and the porosity and permeability of the cores under overburden conditions were accurately measured using a high-precision overburden porosimeter.

[0104] II. Establishment of a two-dimensional NMR template:

[0105] One-dimensional T2 spectroscopy provides a good description of pore structure, porosity, permeability, and saturation; however, it has limitations in identifying fluid properties because T2 values ​​may overlap between different fluids. Therefore, conventional one-dimensional NMR cannot separate oil and water. Two-dimensional NMR introduces a T1 coordinate, forming a T1-T2 two-dimensional coordinate series. Shale oil samples typically contain fluids with varying molecular weights (e.g., heavy oil, light oil, water). When the molecular weights of hydrogen components in different fluids differ significantly, the T1 / T2 ratio will also vary considerably. Higher molecular weights generally correspond to higher viscosity, resulting in a larger T1 / T2 ratio. Therefore, two-dimensional NMR can be used to identify oil and water, such as... Figure 4 As shown, it can be finely divided into clay-bound water, bituminous substances, bound oil, capillary-bound water, movable water, and movable oil.

[0106] S102, Establish a two-dimensional NMR chart for the work area: NMR mode parameter settings: The selected measurement mode is IR-CPMG mode.

[0107] Two-dimensional NMR plot of fluid distribution in a certain interlayer shale oil study area before measurement is shown below. Figure 5 As shown, a parallel sample was selected, washed, dried, and subjected to two-dimensional NMR analysis to determine the locations of kerogen, clay-bound water, and structural water. Then, saturated water was analyzed, and its location was determined using two-dimensional NMR. The sample was then centrifuged, and NMR was measured after centrifugation to distinguish the locations of capillary-bound water and mobile water. Next, saturated oil was dried, and its location was determined using two-dimensional NMR. This was followed by centrifugation and NMR analysis to distinguish the locations of mobile and bound oil. This completed the establishment of the two-dimensional NMR map for the work area. The fluid distribution two-dimensional NMR map of a certain interlayer shale oil research area after measurement is shown below. Figure 6 As shown.

[0108] III. Conducting experiments combining adsorption agent adsorption and two-dimensional nuclear magnetic resonance imaging:

[0109] S103: Each core sample was routinely washed with oil. The washed cores were then placed in a piston container, vacuumed for 48 hours, saturated with simulated shale oil (5 MPa injection pressure), and aged in a constant temperature chamber for 48 hours. The cores were then removed and weighed. Two-dimensional nuclear magnetic resonance (NMR) technology was used to determine the T1 and T2 spectra after oil saturation without damaging the cores. Figure 7As shown, based on the previously established two-dimensional NMR chart, oil and water regions were divided. ① and ② represent structural water (hydroxyl groups) and bound water, respectively, which are the water signal regions of the rock and do not require data processing. The oil signal display regions (③ bound oil and ④ mesopore oil) were selected, and the oil signal quantity W in different pore sizes (x is the T2 coordinate value, y is the T1 coordinate value) of each core under saturated oil conditions was quantified using software. xy，饱和 This determined the original oil content signal under saturated oil conditions.

[0110] Each core sample was placed in a piston container, and an adsorption medium was added. The piston container was then placed in a constant temperature chamber set to the formation temperature and pressurized to the reservoir pressure to conduct an adsorption experiment. After 30 days of experimentation, the core samples were removed, weighed, and the post-adsorption T1 and T2 spectra were tested using two-dimensional nuclear magnetic resonance (NMR) technology. Figure 8 As shown. Similarly, software was used to quantify the oil signal quantity W in different pore sizes (x is the T2 coordinate value, y is the T1 coordinate value) of each core sample after permeation. xy，渗吸后 No signal data processing of the water signal range is required. This allows for the determination of the remaining oil signal quantity at each measurement point after seepage.

[0111] III. Experimental Data Processing and Data Volume Establishment:

[0112] The two-dimensional NMR spectra of interlayered shale oil, specifically the T1 and T2 NMR spectra, show that the main oil signal regions are bound oil and mesoporous oil, such as... Figure 7 As shown, both have the same properties and the same migration law under the action of percolation. Therefore, the same data processing mode is adopted. It is only necessary to establish a function relationship between pore size and percolation efficiency for the display areas of bound oil and mesoporous oil.

[0113] 1) Establishment of a two-dimensional data volume for single-sample percolation rate:

[0114] S104, the saturated oil state signal W for each aperture space (x is the T2 coordinate value, y is the T1 coordinate value). xy，饱和 And the oil signal quantity W after absorption xy，渗吸后 The difference before and after is the change in permeation at that coordinate position. Therefore, by substituting it into formula (1), the permeation rate (I) at each oil signal position (different T1, T2 coordinates) in the two-dimensional nuclear magnetic resonance image can be calculated. xy This generates a two-dimensional data volume of permeability for each core sample at different T1 and T2 coordinates.

[0115] I xy =(W xy，饱和 -W xy，渗吸后 ) / W xy , saturated...........(1)

[0116] Among them, I xy —The permeability value at points T2=x, T1=y of this rock sample; Wxy，渗吸后 —Oil signal quantity after absorption at points T2=x, T1=y; W xy，饱和 —Oil signal quantity at point T2=x, T1=y under saturated oil conditions.

[0117] 2) Establishment of a two-dimensional data volume function model for the permeation efficiency of interlayer shale oil in blocks:

[0118] Considering that shale cores of different physical property levels have different pore size ranges (i.e., the distribution ranges of T2 and T1 are different), based on the two-dimensional data volume of permeability at different T1 and T2 coordinates of each shale reservoir core, the permeability values ​​with the same T1 and T2 coordinates are averaged using data processing software, and the permeability values ​​with different T1 and T2 coordinates are directly merged into the final two-dimensional data volume of permeability. In this way, a two-dimensional data volume of the permeability efficiency of the blocky shale oil is obtained. As shown in formula (2):

[0119]

[0120] Among them, I xy,最终 —The final absorption rate at point T2 = x, T1 = y; x n —The nth value; n—The total number of valid data samples.

[0121] As the number of actual experimental samples increases, the two-dimensional data volume of percolation efficiency can be continuously updated. At the same time, two-dimensional data volumes of percolation efficiency under different percolating agent conditions can be established to adapt to the field requirements under different development conditions.

[0122] IV. Determining the percolation and mobilization efficiency of fresh interlayered shale oil samples

[0123] S105, fresh samples of interbedded shale oil were drilled from the target block. Two-dimensional nuclear magnetic resonance (NMR) was used to determine the T1 and T2 spectra of the fresh samples without damaging the core. Software was used to quantify the oil signal quantity W in different pore sizes (x = T2 coordinates, y = T1 coordinates) of each fresh core sample. xy , 新鲜 Then, the oil signal data of all fresh sample oil signal points are summed to obtain W. 总和，新鲜 Based on the two-dimensional data volume of the permeability of the blocky shale in this area, the oil signal quantity W after permeation at different T1 and T2 coordinates was calculated. xy，渗吸后 As shown in formula (3):

[0124] W xy，渗吸后 =W xy，新鲜 -W xy，新鲜 ×I xy,最终 ................(3)

[0125] Among them, I xy,最终—The final absorption rate at point T2 = x, T1 = y; W xy，新鲜 —Oil signal quantity at points T2=x, T1=y for fresh samples; W xy，渗吸后 —Oil signal quantity at points T2=x and T1=y after percolation.

[0126] W xy，渗吸后 Sum all the oil signal data after absorption in the data body to obtain W. 总和，渗吸后 ,

[0127] S106, W obtained through the above method 总和，新鲜 and W 总和，渗吸后 The data was used to calculate the permeation efficiency I of the shale oil core, as shown in formula (4):

[0128]

[0129] Among them, W 总和，新鲜 —Sum of signal quantities in fresh sample oil; W 总和，渗吸后 —The total oil signal after seepage into the shale oil core; I—The seepage utilization efficiency of the core.

[0130] S107, based on the established two-dimensional data volume (different T1, T2) of the permeation efficiency of interbedded shale oil under the formation conditions of the target block, a method for predicting the permeation efficiency of massive shale under formation conditions using two-dimensional nuclear magnetic resonance technology without damaging the core was formed, and corresponding calculation software was developed, thus realizing the prediction of permeation efficiency under interbedded shale oil formation conditions without damaging the core.

[0131] like Figure 9 As shown, an apparatus for predicting the permeation and utilization efficiency of interlayered shale oil includes: a rock sample preparation unit 901, a two-dimensional nuclear magnetic resonance plate establishment unit 902, a rock sample permeation rate value determination unit 903, and a permeation and utilization efficiency determination unit 904.

[0132] The rock sample preparation unit 901 is used to sample the sweet spot reservoir of interlayered shale oil and prepare several rock samples for testing.

[0133] Two-dimensional NMR plate establishment unit 902 is used to measure the two-dimensional NMR of several rock samples to establish a two-dimensional NMR plate for the work area;

[0134] The rock sample permeability determination unit 903 is used to determine the original oil-bearing signal quantity under saturated oil conditions and the remaining oil signal quantity at each measurement point after permeation.

[0135] The rock sample permeability determination unit 903 is also used to obtain the rock sample permeability by using the original oil-bearing signal quantity under saturated oil conditions and the remaining oil signal quantity at each measurement point after permeation.

[0136] The permeation and mobilization efficiency determination unit 904 is used to drill fresh core samples of interlayered shale oil in the target block to be predicted, determine the oil-bearing signal of the fresh sample, and determine the total oil signal of the fresh sample based on the oil-bearing signal of the fresh sample.

[0137] The permeation mobilization efficiency determination unit 904 is also used to determine the total oil signal after permeation of shale oil core based on the oil signal quantity of fresh sample and the permeation rate value of rock sample;

[0138] The infiltration efficiency determination unit 904 is also used to determine the infiltration efficiency of fresh sample cores by using the sum of oil signal quantities of fresh sample cores and the sum of oil signal quantities after infiltration of shale oil cores.

[0139] like Figure 10 As shown, this disclosure provides an electronic device, including a processor 1001, a communication interface 1002, a memory 1003, and a communication bus 1004, wherein the processor 1001, the communication interface 1002, and the memory 1003 communicate with each other through the communication bus 1004.

[0140] Memory 1003 stores computer programs;

[0141] When the processor 1001 executes the computer program stored in the memory 1003, it implements the above-described method.

[0142] This disclosure provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method.

[0143] The computer-readable storage medium may be included in the device / apparatus described in the above embodiments; or it may exist independently and not assembled into the device / apparatus. The computer-readable storage medium carries one or more programs that, when executed, implement the method according to the embodiments of this disclosure.

[0144] According to embodiments of this disclosure, the computer-readable storage medium can be a non-volatile computer-readable storage medium, such as including, but not limited to: portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof. In this disclosure, the computer-readable storage medium can be any tangible medium that contains or stores a program that can be used by or in conjunction with an instruction execution system, apparatus, or device.

[0145] Although the present disclosure has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features; and such modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present disclosure.

Claims

1. A method for predicting the adsorption and utilization efficiency of interlayered shale oil, characterized in that, The method includes: Samples were taken from the sweet spot reservoir of interlayered shale oil, and several rock samples were prepared for testing. Two-dimensional nuclear magnetic resonance (NMR) was measured on several rock samples to establish a two-dimensional NMR map of the work area; Determine the original oil content signal under saturated oil conditions and the residual oil signal at each measurement point after permeation; The permeability of the rock sample was obtained by measuring the original oil-bearing signal in the saturated oil state and the remaining oil signal at each measurement point after permeation. Fresh core samples of interbedded shale oil from the target block to be predicted are drilled, and the oil-bearing signal intensity of the fresh samples is determined; the total oil signal intensity of the fresh samples is determined based on the oil-bearing signal intensity of the fresh samples. The total oil signal after permeation of shale oil cores is determined based on the oil signal quantity of fresh samples and the permeation rate of rock samples. The efficiency of the fresh sample core permeation was determined by summing the oil signal quantities of the fresh sample and summing the oil signal quantities of the shale oil core after permeation.

2. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 1, characterized in that, Two-dimensional nuclear magnetic resonance (NMR) measurements were performed on several rock samples, including: For all samples, the selected measurement mode was IR-CPMG mode, and two-dimensional NMR was measured to determine the following locations: Determine the location of kerogen, clay-bound water, and structural water; Determine the location of the water; Determine the location of capillary-bound water and movable water; Determine the location of the oil; Determine the positions of the movable oil and the restraining oil.

3. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 2, characterized in that, The two-dimensional nuclear magnetic resonance (NMR) measurements of several rock samples also included: Two-dimensional nuclear magnetic resonance (NMR) values ​​T1 and T2 were obtained for the rock samples, and the locations of oil and water were identified based on T1, T2, and the T1 / T2 ratio.

4. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 2, characterized in that, Determine the location of kerogen, clay-bound water, and structural water, including: The sample was washed with oil and dried, and two-dimensional NMR was measured to determine the location of kerogen, clay-bound water, and structural water.

5. The method for predicting the permeation and utilization efficiency of interlayered shale oil according to claim 2, characterized in that, Determining the location of the water includes: The sample was washed with oil and saturated with water, and two-dimensional NMR was measured to determine the location of the water.

6. The method for predicting the permeation and utilization efficiency of interlayered shale oil according to claim 2, characterized in that, Determining the location of capillary-bound and mobile water includes: After washing the sample with oil and saturated water, centrifuge it. After centrifugation, NMR is measured to distinguish the location of capillary bound water and mobile water.

7. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 2, characterized in that, Determining the location of the oil includes: The sample was dried and saturated with oil, and two-dimensional NMR was measured to determine the location of the oil.

8. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 2, characterized in that, Determine the location of the movable and restraining oil, including: The sample was dried and saturated with oil before centrifugation. Two-dimensional NMR was measured to distinguish the location of mobile and bound oil.

9. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 2, characterized in that, Establish a two-dimensional NMR map of the work area, including: The locations of kerogen, clay-bound water and structural water, water, capillary-bound water and movable water, oil, and movable and bound oil were plotted on a two-dimensional graph with T1 spectrum as the ordinate and T2 spectrum as the abscissa, resulting in a two-dimensional NMR plate.

10. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 1, characterized in that, Determine the original oil content signal under saturated oil conditions, including: After washing the oil, the core was placed into a piston container, vacuumed for M1 hours, saturated with simulated shale oil under pressure K, aged in a constant temperature chamber for M2 hours, and then the core was taken out and weighed. Two-dimensional nuclear magnetic resonance (NMR) was used to determine the T1 and T2 spectra after oil saturation without damaging the core. Oil-water regions were divided on the two-dimensional NMR chart, and the oil signal display area containing bound oil and mesoporous oil was selected. Software quantified the oil signal quantity W in different pore sizes of each core under oil saturation conditions. xy，饱和 , where x is the coordinate value of T2 and y is the coordinate value of T1.

11. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 1, characterized in that, The remaining oil signal at each measurement point after absorption includes: Saturated oil cores were placed in piston containers, and permeation media were added. The piston containers were then placed in a constant temperature chamber, set to the formation temperature, and pressurized to the reservoir pressure to conduct permeation experiments. After day 1 of the experiment, the cores were removed and weighed, and the T1 and T2 spectra after permeation were tested using two-dimensional nuclear magnetic resonance technology. Software quantifies the amount of oil signal W in different pore sizes after permeation of each core sample. xy，渗吸后 , where x is the coordinate value of T2 and y is the coordinate value of T1.

12. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 1, characterized in that, The permeability of the rock sample is obtained by measuring the original oil-bearing signal in the saturated oil state and the residual oil signal at each measurement point after permeation, including: Saturated oil state signal W for each aperture space xy，饱和 And the oil signal quantity W after absorption xy，渗吸后 The difference before and after is the change in seepage at this coordinate position before and after, and the change is related to W. xy，饱和 The ratio is the rock sample permeability, where x is the T2 coordinate value and y is the T1 coordinate value.

13. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 12, characterized in that, Change and W xy，饱和 The ratio is the rock sample permeability, including: The permeation rate I at each oil signal location in the two-dimensional nuclear magnetic resonance image at different T1 and T2 coordinates is calculated using the following formula. xy : I xy =(W xy，饱和 -W xy，渗吸后 ) / W xy，饱和 ; Among them, I xy This represents the permeation rate of the rock sample at points T2 = x and T1 = y; W xy，渗吸后 W represents the oil signal quantity after seepage at points T2 = x and T1 = y; xy，饱和 This represents the oil signal quantity under saturated oil conditions at points T2 = x and T1 = y.

14. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 12, characterized in that, The permeability of the rock sample is obtained by measuring the original oil-bearing signal in the saturated oil state and the residual oil signal at each measurement point after permeation. This also includes: Based on the permeability of each shale reservoir core at different T1 and T2 coordinates, the average value of the permeability at the same T1 and T2 coordinates is calculated to obtain the final permeability of the rock sample, as shown in the following formula: Among them, I xy,最终 This represents the final absorption rate at point T2 = x, T1 = y; x n This represents the nth value; n represents the total number of valid data samples.

15. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 1, characterized in that, Fresh samples of interlayered shale oil from the target block to be predicted are drilled, and the oil-bearing signal intensity of the fresh samples is determined. Based on the oil-bearing signal intensity of the fresh samples, the total oil signal intensity of the fresh samples is determined, including: Fresh samples of interbedded shale oil from the target block were drilled, and the T1 and T2 spectra of the fresh samples were determined using two-dimensional nuclear magnetic resonance technology without damaging the core. Software quantifies the amount of oil signal W in different pore sizes of each fresh core sample. xy，新鲜 Then, the oil signal data of all fresh sample oil signal points are summed to obtain the oil content signal W of the fresh sample. 总和，新鲜 , where x is the coordinate value of T2 and y is the coordinate value of T1.

16. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 1, characterized in that, Based on the oil signal intensity of fresh samples and the permeability of rock samples, the total oil signal intensity after permeation in shale oil cores is determined, including: Calculate the oil signal quantity W after seepage at different T1 and T2 coordinates. xy，渗吸后 The formula is as follows: IN xy，渗吸后 =In xy，新鲜 -IN xy，新鲜 ×I xy,最终 ; Among them, I xy,最终 W represents the final absorption rate at points T2 = x and T1 = y. xy，新鲜 W represents the oil signal quantity at points T2 = x and T1 = y for fresh samples; xy，渗吸后 This represents the oil signal quantity at points T2=x and T1=y after percolation. W xy，渗吸后 Summing all the oil signal data after infiltration yields the total oil signal W from the shale oil core after infiltration. 总和，渗吸后 .

17. The method for predicting the adsorption and utilization efficiency of interlayered shale oil according to claim 1, characterized in that, The efficiency of oil resorption in fresh sample cores was determined by summing the oil signal intensity of fresh samples and summing the oil signal intensity after resorption in shale oil cores, including: The sum of the signal quantities of the fresh sample oil W 总和，新鲜 The sum of oil signal quantities W after permeation and adsorption of shale oil cores 总和，渗吸后 The data was used to calculate the seepage and mobilization efficiency I of the shale oil core in this block. The formula is as follows: Among them, W 总和，新鲜 W represents the sum of the signal quantities of the fresh sample oil; 总和，渗吸后 This represents the total oil signal after seepage into the shale oil core; I represents the seepage utilization efficiency of this core.

18. A device for predicting the percolation and mobilization efficiency of interlayer shale oil, characterized in that, include: Rock sample preparation unit, two-dimensional NMR plate creation unit, rock sample permeability determination unit, and permeability utilization efficiency determination unit; The rock sample preparation unit is used to sample the sweet spot reservoir of interlayered shale oil and prepare several rock samples for testing. The two-dimensional NMR plate establishment unit is used to measure the two-dimensional NMR of several rock samples to establish a two-dimensional NMR plate for the work area. The rock sample permeability determination unit is used to determine the original oil-bearing signal quantity under saturated oil conditions and the remaining oil signal quantity at each measurement point after permeation. The rock sample permeability determination unit is also used to obtain the rock sample permeability by using the original oil-bearing signal quantity under saturated oil conditions and the remaining oil signal quantity at each measurement point after permeation. The percolation efficiency determination unit is used to drill fresh core samples of interlayered shale oil in the target block to be predicted, determine the oil-bearing signal of the fresh sample, and determine the total oil signal of the fresh sample based on the oil-bearing signal of the fresh sample. The permeation mobilization efficiency determination unit is also used to determine the total oil signal after permeation of shale oil core based on the oil signal quantity of fresh sample and the permeation rate value of rock sample; The infiltration efficiency determination unit is also used to determine the infiltration efficiency of fresh sample cores by using the sum of oil signal quantities of fresh sample cores and the sum of oil signal quantities after infiltration of shale oil cores.

19. An electronic device, characterized in that, It includes a processor, a communication interface, a memory, and a communication bus, wherein the processor, the communication interface, and the memory communicate with each other through the communication bus; Memory, which stores computer programs; A processor, when executing a computer program stored in memory, implements a method for predicting the percolation and mobilization efficiency of interlayer shale oil as described in any one of claims 1-17.

20. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by a processor, it implements a method for predicting the percolation and mobilization efficiency of interlayered shale oil as described in any one of claims 1-17.

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