Low-permeability conglomerate fluid property identification method based on logging two-dimensional nuclear magnetic resonance

Abstract

The invention relates to the technical field of oil exploitation and processing, in particular to a logging-based two-dimensional nuclear magnetic resonance low-permeability conglomerate fluid property identification method, which comprises the following steps of: obtaining the sum of original fluid areas in an original state of a low-permeability conglomerate core through two-dimensional nuclear magnetic resonance; obtaining the sum of manganese-saturated fluid areas of the low-permeability conglomerate core in a manganese-saturated state through two-dimensional nuclear magnetic resonance; according to the sum of the original fluid areas of the low-permeability conglomerate core in the original state and the sum of the manganese-saturated fluid areas of the low-permeability conglomerate core in the manganese-saturated state, the remaining oil index of the low-permeability conglomerate is obtained; and determining the fluid property of the low-permeability conglomerate reservoir according to the remaining oil index of the low-permeability conglomerate. According to the method, the residual oil index of the low-permeability conglomerate reservoir is established in an intuitive representation mode, the calculation formula of the residual oil index is based on extraction of parameter characteristics in a two-dimensional nuclear magnetic resonance original state and a manganese-saturated state, and the low-permeability conglomerate fluid property can be effectively recognized.

Description

Technical Field

[0001] This invention relates to the field of petroleum extraction and processing technology, and is a method for identifying the properties of low-permeability conglomerate fluids based on well logging two-dimensional nuclear magnetic resonance. Background Technology

[0002] In the field of oil and gas exploration and development, accurate identification of reservoir fluid properties is crucial for improving oil and gas field development efficiency. Traditional logging techniques, such as resistivity characteristic discrimination and sonic logging, while capable of identifying fluid properties to some extent, have limitations in low-porosity and low-permeability reservoirs, especially in complex lithological reservoirs where their application is ineffective. For core samples, one-dimensional nuclear magnetic resonance (NMR) is often used in logging to identify formation fluid properties, using the T2 cutoff value to distinguish between movable and bound fluids. While the T2 cutoff value does not affect the porosity and oil saturation of the sample, parameters such as the saturation of movable and bound fluids are directly related to the selection of the T2 cutoff value. The accuracy of its selection directly affects the accuracy of the evaluation results. Therefore, when using this method to identify formation fluid properties, the selection of the T2 cutoff value is of paramount importance.

[0003] Generally, there are two methods for defining T2 cutoff values. The first is the centrifugation method, which involves selecting a certain amount of core samples from a block or stratigraphic layer for centrifugation experiments to determine the T2 cutoff value for the region. However, this method has drawbacks such as requiring a large sample volume, complex procedures, and long processing time. The second method is the empirical method, which uses experience to define the T2 cutoff value of samples based on a large number of samples in the region. This method can only provide a rough definition and is greatly affected by human factors, making it more difficult to define. Furthermore, due to the unique pore structure of low-permeability conglomerate, its fluid properties are even more complex. When using one-dimensional nuclear magnetic resonance (NMR) T2 cutoff value to determine reservoir fluid properties, the degree of error increases significantly.

[0004] With the vigorous development of low-permeability conglomerate reservoirs, the identification of their fluid properties is becoming increasingly important. Existing one-dimensional nuclear magnetic resonance fluid property identification methods are quite difficult to evaluate and identify fluids in low-permeability conglomerate reservoirs. This necessitates the development of accurate fluid property identification methods to enhance the ability to identify formation fluid properties and solve the aforementioned problems. Summary of the Invention

[0005] This invention provides a method for identifying the fluid properties of low-permeability conglomerate based on two-dimensional nuclear magnetic resonance logging, which overcomes the shortcomings of the prior art. It does not distinguish between movable and bound fluids based on T2 cutoff values, reduces interference from human factors, and effectively identifies the fluid properties of low-permeability conglomerate reservoirs.

[0006] The technical solution of this invention is achieved through the following measures: a method for identifying the fluid properties of low-permeability conglomerate based on well logging two-dimensional nuclear magnetic resonance, comprising:

[0007] The sum of the original fluid areas in the original state of the low-permeability conglomerate core was obtained using two-dimensional nuclear magnetic resonance:

[0008] Using low-permeability conglomerate plunger cores as the original samples, two-dimensional nuclear magnetic resonance (NMR) measurements were performed on the original samples to obtain the original two-dimensional NMR spectra.

[0009] Based on the two-dimensional nuclear magnetic resonance spectrum of the original state, the original state signal is recorded as the sum of the original movable water areas ∑ Ykw The sum of the original movable oil areas ∑ Yko The sum of the original bound water areas ∑ Ysw The sum of the original bound oil areas ∑ Yso Based on the original state signal record, the sum of the original fluid areas in the original state of the low-permeability conglomerate core was obtained ∑. Yla ;

[0010] The sum of the manganese-saturated fluid areas in the manganese-saturated state of the low-permeability conglomerate core was obtained by two-dimensional nuclear magnetic resonance:

[0011] Using low-permeability conglomerate core as the original sample, the original sample was first evacuated under vacuum, and then soaked in manganese water to obtain a manganese-saturated sample. Two-dimensional nuclear magnetic resonance (NMR) measurements were performed on the manganese-saturated sample to obtain a two-dimensional NMR spectrum of the manganese-saturated state.

[0012] Based on the two-dimensional nuclear magnetic resonance spectrum of the manganese-saturated state, the obtained manganese-saturated state signal is recorded as the sum of the movable water surface areas ∑ of the manganese-saturated state. Mkw The sum of the movable oil surface area of ​​saturated manganese ∑ Mko The sum of the areas of saturated manganese-bound water ∑ Msw The sum of the areas of saturated manganese-bound oil ∑ Mso Based on the recorded manganese saturation state signal, the sum of the manganese saturated fluid areas in the low-permeability conglomerate core under manganese saturation state was obtained. Mla ;

[0013] The residual oil index of low-permeability conglomerate is obtained by summing the original fluid area in the original state of the low-permeability conglomerate core and summing the manganese-saturated fluid area in the manganese-saturated state of the low-permeability conglomerate core.

[0014] The fluid properties of low-permeability conglomerate reservoirs are determined based on the residual oil index of low-permeability conglomerate.

[0015] The following are further optimizations and / or improvements to the above-mentioned technical solution:

[0016] The residual oil index of the aforementioned low-permeability conglomerate is calculated using the following formula:

[0017] Osy=∑ Mla / ∑ Yla

[0018] In the formula, Osy is the residual oil index of low-permeability conglomerate, ∑ Mla The sum of the areas of the saturated manganese fluid, ∑ Yla This is the sum of the original fluid surface areas.

[0019] When Osy < 0.20, the low-permeability conglomerate reservoir is a water layer; when Osy is between 0.20 and 0.50, the low-permeability conglomerate reservoir is an oil-water layer; when Osy is between 0.50 and 0.85, the low-permeability conglomerate reservoir is an oil-water co-layer; and when Osy > 0.85, the low-permeability conglomerate reservoir is an oil layer.

[0020] The sum of the areas of the above-mentioned saturated manganese fluids is calculated using the following formula:

[0021] ∑ Mla =∑ Mkw +∑ Mko +∑ Msw +∑ Mso

[0022] In the formula, ∑ Mla The sum of the areas of the saturated manganese fluid, ∑ Mkw The sum of the movable water surface area saturated with manganese, ∑ Mko The sum of the movable oil surface area saturated with manganese, ∑ Msw The sum of the areas of manganese-bound water, ∑ Mso This represents the sum of the areas bound by manganese-saturated oil.

[0023] The sum of the original fluid areas mentioned above is calculated using the following formula:

[0024] ∑ Yla =∑ Ykw +∑ Yko +∑ Ysw +∑ Yso

[0025] In the formula, ∑ Yla The sum of the original fluid areas, ∑ Ykw The sum of the original bound water areas, ∑ Yko The sum of the original movable oil areas, ∑ Ysw The sum of the original movable water surface area, ∑ Yso This is the sum of the original bound oil areas.

[0026] The above ∑ Ykw ,∑ Yko ,∑ Ysw ,∑ Yso The calculation formula is as follows:

[0027]

[0028]

[0029] The above ∑Mkw ,∑ Mko ,∑ Msw ,∑ Mso The calculation formula is as follows:

[0030]

[0031] In the above formula, t T2max可动水 The maximum time of the T2 cutoff value corresponding to movable water, in milliseconds; t T2min可动水 The minimum cutoff time for movable water is T2, expressed in milliseconds (ms). T1max可动水 The maximum value of the cutoff time T1 corresponding to movable water, in milliseconds; t T1min可动水 Let T1 be the minimum cutoff time for the movable water, in ms; ∫movable water(t)*dt is the envelope area of ​​the movable water.

[0032] t T2max可动油 The maximum T2 cutoff time for movable oil, in milliseconds; t T2min可动油 The minimum cutoff time for the movable oil is T2, expressed in milliseconds (ms). T1max可动油 The maximum value of the cutoff time T1 corresponding to the movable oil, in milliseconds; t T1min可动油 The minimum cutoff time for the movable oil is T1, in ms; ∫movable oil(t)*dt is the envelope area of ​​the movable oil;

[0033] t T2max束缚水 The maximum T2 cutoff time for bound water, in milliseconds; t T2min束缚水 The minimum T2 cutoff time for bound water, in milliseconds (ms); t T1max束缚水 The maximum value of the T1 cutoff time corresponding to the bound water, in milliseconds; t T1min束缚水 Let T1 be the minimum cutoff time corresponding to the bound water, in ms; ∫bound water(t)*dt is the envelope area of ​​the bound water;

[0034] t T2max束缚油 The maximum T2 cutoff time for the binding oil is expressed in milliseconds (ms); t T2min束缚油 The minimum T2 cutoff time for the binding oil, in milliseconds (ms); t T1max束缚油 The maximum value of the T1 cutoff time corresponding to the binding oil, in milliseconds; t T1min束缚油 denoted as the minimum cutoff time T1 corresponding to the binding oil, in ms; ∫binding oil(t)*dt is the envelope area of ​​the binding oil.

[0035] This invention establishes a residual oil index for low-permeability conglomerate reservoirs using an intuitive representation. The calculation formula for the residual oil index is based on the extraction of parameter characteristics from the original and manganese-saturated states using two-dimensional nuclear magnetic resonance (NMR), which can effectively identify the fluid properties of low-permeability conglomerate. Furthermore, the method described in this invention does not require distinguishing between movable and bound fluids based on T2 cutoff values. It only needs to utilize the maximum and minimum T2 cutoff times for the same fluid based on the fluid distribution range of the two-dimensional NMR spectrum. This eliminates the need for manually distinguishing between movable and bound fluids' T2 cutoff values, thus avoiding human interference from T2 cutoff value division and making the identification of fluid properties more accurate. This method has good practical value and promising prospects for widespread application. Attached Figure Description

[0036] Appendix Figure 1 This is a flowchart of the present invention;

[0037] Appendix Figure 2 This is a schematic diagram of the two-dimensional nuclear magnetic resonance fluid property distribution range of the present invention;

[0038] Appendix Figure 3 This is a two-dimensional nuclear magnetic resonance spectrum of the original sample in an embodiment of the present invention;

[0039] Appendix Figure 4 This is a two-dimensional nuclear magnetic resonance spectrum of a manganese-saturated sample according to an embodiment of the present invention. Detailed Implementation

[0040] The present invention is not limited to the following embodiments, and the specific implementation can be determined according to the technical solution of the present invention and the actual situation.

[0041] In this invention, ppm means parts per million. Manganese water refers to an aqueous solution of manganese chloride.

[0042] Unless otherwise specified, all solutions in this invention are aqueous solutions with water as the solvent.

[0043] The present invention will be further described below with reference to embodiments:

[0044] As attached Figure 1 As shown, this method for identifying the fluid properties of low-permeability conglomerate based on well logging two-dimensional nuclear magnetic resonance includes:

[0045] The sum of the original fluid areas in the original state of the low-permeability conglomerate core was obtained using two-dimensional nuclear magnetic resonance (i.e., original fluid information was obtained):

[0046] Using low-permeability conglomerate plunger cores as the original samples, two-dimensional nuclear magnetic resonance (NMR) measurements were performed on the original samples to obtain the original two-dimensional NMR spectra.

[0047] Based on the two-dimensional nuclear magnetic resonance spectrum of the original state, the original state signal is recorded as the sum of the original movable water areas ∑ Ykw The sum of the original movable oil areas ∑ Yko The sum of the original bound water areas ∑ Ysw The sum of the original bound oil areas ∑ Yso Based on the original state signal record, the sum of the original fluid areas in the original state of the low-permeability conglomerate core was obtained ∑. Yla ;

[0048] ∑ Ykw ,∑ Yko ,∑ Ysw ,∑ Yso The calculation formula is as follows:

[0049]

[0050] This method does not require distinguishing between the T2 cutoff values ​​of movable and bound fluids. It only requires calculating the maximum T2 cutoff time minus the minimum T2 cutoff time based on the fluid distribution range in the two-dimensional nuclear magnetic resonance spectrum. For example, in the first term on the left side of the formula for calculating the sum of the original movable water areas... At that time, find the maximum and minimum T2 cutoff time values ​​for movable water. For the interval [t] T2min可动水 ,t T2max可动水 The corresponding area is the area corresponding to the maximum T2 cutoff time of the moving water minus the area corresponding to the minimum T2 cutoff time.

[0051] The sum of the original fluid surfaces is calculated using the following formula:

[0052] ∑ Yla =∑ Ykw +∑ Yko +∑ Ysw +∑ Yso .

[0053] The sum of the manganese-saturated fluid areas in the manganese-saturated state of the low-permeability conglomerate core was obtained using two-dimensional nuclear magnetic resonance (i.e., the fluid information after manganese saturation).

[0054] Using low-permeability conglomerate core as the original sample, the original sample was first evacuated under vacuum, and then soaked in manganese water to obtain a manganese-saturated sample. Two-dimensional nuclear magnetic resonance (NMR) measurements were performed on the manganese-saturated sample to obtain a two-dimensional NMR spectrum of the manganese-saturated state.

[0055] Based on the two-dimensional nuclear magnetic resonance spectrum of the manganese-saturated state, the obtained manganese-saturated state signal is recorded as the sum of the movable water surface areas ∑ of the manganese-saturated state. Mkw The sum of the movable oil surface area of ​​saturated manganese ∑ Mko The sum of the areas of saturated manganese-bound water ∑Msw The sum of the areas of saturated manganese-bound oil ∑ Mso Based on the recorded manganese saturation state signal, the sum of the manganese saturated fluid areas in the low-permeability conglomerate core under manganese saturation state was obtained. Mla ;∑ Mkw ,∑ Mko ,∑ Msw ,∑ Mso The calculation formula is as follows:

[0056]

[0057] In the formula, t T2max可动水 The maximum time of the T2 cutoff value corresponding to movable water, in milliseconds; t T2min可动水 The minimum cutoff time for movable water is T2, expressed in milliseconds (ms). T1max可动水 The maximum value of the cutoff time T1 corresponding to movable water, in milliseconds; t T1min可动水 Let T1 be the minimum cutoff time for the movable water, in ms; ∫movable water(t)*dt is the envelope area of ​​the movable water.

[0058] t T2max可动油 The maximum T2 cutoff time for movable oil, in milliseconds; t T2min可动油 The minimum cutoff time for the movable oil is T2, expressed in milliseconds (ms). T1max可动油 The maximum value of the cutoff time T1 corresponding to the movable oil, in milliseconds; t T1min可动油 The minimum cutoff time for the movable oil is T1, in ms; ∫movable oil(t)*dt is the envelope area of ​​the movable oil;

[0059] t T2max束缚水 The maximum T2 cutoff time for bound water, in milliseconds; t T2min束缚水 The minimum T2 cutoff time for bound water, in milliseconds (ms); t T1max束缚水 The maximum value of the T1 cutoff time corresponding to the bound water, in milliseconds; t T1min束缚水 Let T1 be the minimum cutoff time corresponding to the bound water, in ms; ∫bound water(t)*dt is the envelope area of ​​the bound water;

[0060] t T2max束缚油 The maximum T2 cutoff time for the binding oil is expressed in milliseconds (ms); t T2min束缚油 The minimum T2 cutoff time for the binding oil, in milliseconds (ms); t T1max束缚油 The maximum value of the T1 cutoff time corresponding to the binding oil, in milliseconds; t T1min束缚油 denoted as the minimum cutoff time T1 corresponding to the binding oil, in ms; ∫binding oil(t)*dt is the envelope area of ​​the binding oil.

[0061] The sum of the areas of saturated manganese fluids is calculated using the following formula:

[0062] ∑ Mla =∑ Mkw +∑ Mko +∑ Msw +∑ Mso

[0063] In the formula, ∑ Mla The sum of the areas of the saturated manganese fluid, ∑ Mkw The sum of the movable water surface area saturated with manganese, ∑ Mko The sum of the movable oil surface area saturated with manganese, ∑ Msw The sum of the areas of manganese-bound water, ∑ Mso This represents the sum of the areas bound by manganese-saturated oil.

[0064] The residual oil index of low-permeability conglomerate is obtained by summing the original fluid area in the original state of the low-permeability conglomerate core and summing the manganese-saturated fluid area in the manganese-saturated state of the low-permeability conglomerate core.

[0065] The fluid property distribution range is shown in the figure. Figure 2 Based on the residual oil index of low-permeability conglomerate, the fluid properties of the low-permeability conglomerate reservoir are determined (see Table 1). The residual oil index of low-permeability conglomerate is calculated using the following formula:

[0066] Osy=∑ Mla / ∑ Yla

[0067] In the formula, Osy is the residual oil index of low-permeability conglomerate, ∑ Mla The sum of the areas of the saturated manganese fluid, ∑ Yla This is the sum of the original fluid surface areas.

[0068] Example: A method for identifying fluid properties in low-permeability conglomerate based on well logging two-dimensional nuclear magnetic resonance is applied to low-permeability conglomerate reservoirs in the Mahu Depression of Xinjiang Oilfield, including the following steps:

[0069] (1) Selection of core samples

[0070] Piston samples were taken from the core section from 3120.14m to 3145.12m of the MH130 well. A total of 7 samples were taken, ranging in length from 6cm to 7cm. The selected samples were cut into two sections, namely Sample No. 1 and Sample No. 2 (Table 2).

[0071] (2) The sum of the original fluid areas in the original state of the low-permeability conglomerate core was obtained by two-dimensional nuclear magnetic resonance.

[0072] The selected samples from different well depths were used as the original samples. Two-dimensional nuclear magnetic resonance (NMR) measurements were directly performed on the original samples (NMR test parameters were set using the CPMG sequence, waiting time = 1500 ms, echo time = 0.2 ms, number of echoes = 10000, cumulative count = 64, magnetic field frequency 12 MHz). The two-dimensional NMR spectrum of one of the samples is shown below. Figure 3 Based on the above formula, the ∑ of sample No. 1 at different well depths is obtained. Ykw ,∑ Yko ,∑ Ysw ,∑ Yso And based on the results, calculate ∑ Yla (Table 3)

[0073] (3) Measurement of two-dimensional nuclear magnetic resonance manganese-saturated samples

[0074] Using the second sample from different well depths as the original sample, the original sample was evacuated for 4 hours under a vacuum pressure of -0.09 MPa. Then, Mn was used... 2+ Manganese-saturated samples were obtained by soaking in a 30,000 ppm manganese solution for 24 hours. Two-dimensional nuclear magnetic resonance (NMR) measurements were performed on the manganese-saturated samples (NMR test parameters were set using the CPMG sequence, wait time = 1500 ms, echo time = 0.2 ms, number of echoes = 10,000, cumulative count = 64, magnetic field frequency 12 MHz). The two-dimensional NMR spectrum of one of the second samples is shown below. Figure 4 Based on the above formula, the ∑ of samples at different well depths of the No. 2 well is obtained. Mkw ,∑ Mko ,∑ Msw ,∑ Mso And based on the results, calculate ∑ Mla (Table 4)

[0075] (4) Fluid property evaluation

[0076] Based on the results measured in steps (2) and (3) above, the remaining oil is calculated according to the formula for the remaining oil index of low-permeability conglomerate, and the calculation results are shown in Table 5.

[0077] Table 5 shows that the residual oil index of this core section ranges from 0.58 to 0.81. Comparing the calculated results with Table 1, the fluid properties of this section are assessed as water-bearing, and the interpretation is that the oil and water are in the same layer. Subsequent oil testing of this section yielded a daily crude oil production of 5.80 tons and a daily water production of 11.55 cubic meters. 3 This is consistent with the evaluation results of the residual oil index.

[0078] This method provides an accurate fluid property identification approach through practical application in low-permeability conglomerate reservoirs in the Xinjiang Oilfield. In practical application, two-dimensional nuclear magnetic resonance (NMR) is used to interpret fluid properties and determine the reservoir's fluid characteristics. Verification through well testing showed a fluid property evaluation accuracy rate of 88.9%, effectively improving the accuracy of fluid property identification in low-permeability conglomerate reservoirs using well logging.

[0079] The above technical features constitute the embodiments of the present invention, which have strong adaptability and implementation effect. Unnecessary technical features can be added or removed according to actual needs to meet the needs of different situations.

[0080] Table 1 Residual Oil Index Fluid Property Evaluation

[0081]

[0082] Table 2. Statistics of Core Sampling from Well MH130

[0083]

[0084] Table 3. Original measurement results of sample No. 1 at different well depths.

[0085]

[0086] Table 4. Manganese saturation measurement results for samples No. 2 at different well depths.

[0087]

[0088] Table 5 Remaining oil index of MH130 well core

[0089]

Claims

1. A method for identifying the fluid properties of low-permeability conglomerate based on well logging two-dimensional nuclear magnetic resonance, characterized in that... include: The sum of the original fluid areas in the original state of the low-permeability conglomerate core was obtained using two-dimensional nuclear magnetic resonance: Using low-permeability conglomerate plunger cores as the original samples, two-dimensional nuclear magnetic resonance (NMR) measurements were performed on the original samples to obtain the original two-dimensional NMR spectra. Based on the two-dimensional nuclear magnetic resonance spectrum of the original state, the original state signal is recorded as the sum of the original movable water areas ∑ Ykw The sum of the original movable oil areas ∑ Yko The sum of the original bound water areas ∑ Ysw The sum of the original bound oil areas ∑ Yso Based on the original state signal record, the sum of the original fluid areas in the original state of the low-permeability conglomerate core was obtained ∑. Yla ; The sum of the manganese-saturated fluid areas in the manganese-saturated state of the low-permeability conglomerate core was obtained by two-dimensional nuclear magnetic resonance: Using low-permeability conglomerate core as the original sample, the original sample was first evacuated under vacuum, and then soaked in manganese water to obtain a manganese-saturated sample. Two-dimensional nuclear magnetic resonance (NMR) measurements were performed on the manganese-saturated sample to obtain a two-dimensional NMR spectrum of the manganese-saturated state. Based on the two-dimensional nuclear magnetic resonance spectrum of the manganese-saturated state, the obtained manganese-saturated state signal is recorded as the sum of the movable water surface areas ∑ of the manganese-saturated state. Mkw The sum of the movable oil surface area of ​​saturated manganese ∑ Mko The sum of the areas of saturated manganese-bound water ∑ Msw The sum of the areas of saturated manganese-bound oil ∑ Mso Based on the recorded manganese saturation state signal, the sum of the manganese saturated fluid areas in the low-permeability conglomerate core under manganese saturation state was obtained. Mla ; The residual oil index of low-permeability conglomerate is obtained by summing the original fluid area in the original state of the low-permeability conglomerate core and summing the manganese-saturated fluid area in the manganese-saturated state of the low-permeability conglomerate core. The fluid properties of low-permeability conglomerate reservoirs are determined based on the residual oil index of low-permeability conglomerate.

2. The method for identifying the fluid properties of low-permeability conglomerate based on two-dimensional nuclear magnetic resonance logging according to claim 1, characterized in that... The residual oil index of low-permeability conglomerate is calculated using the following formula: Axes=∑ Mla / ∑ Yla In the formula, Osy is the residual oil index of low-permeability conglomerate, ∑ Mla The sum of the areas of the saturated manganese fluid, ∑ Yla This is the sum of the original fluid surface areas.

3. The method for identifying the fluid properties of low-permeability conglomerate based on well logging two-dimensional nuclear magnetic resonance as described in claim 2, characterized in that... When Osy < 0.20, the low-permeability conglomerate reservoir is a water layer; when Osy is between 0.20 and 0.50, the low-permeability conglomerate reservoir is an oil-water layer; when Osy is between 0.50 and 0.85, the low-permeability conglomerate reservoir is an oil-water co-layer; when Osy > 0.85, the low-permeability conglomerate reservoir is an oil layer.

4. The method for identifying the fluid properties of low-permeability conglomerate based on two-dimensional nuclear magnetic resonance logging according to claim 1, 2, or 3, characterized in that... The sum of the original fluid surfaces is calculated using the following formula: ∑ Yla ＝∑ Ykw +∑ Yko +∑ Ysw +∑ Yso In the formula, ∑ Yla The sum of the original fluid areas, ∑ Ykw The sum of the original bound water areas, ∑ Yko The sum of the original movable oil areas, ∑ Ysw The sum of the original movable water surface area, ∑ Yso This is the sum of the original bound oil areas.

5. The method for identifying the fluid properties of low-permeability conglomerate based on two-dimensional nuclear magnetic resonance logging according to claim 1, 2, or 3, characterized in that... The sum of the areas of saturated manganese fluid is calculated using the following formula: ∑ Mla ＝∑ Mkw +∑ Mko +∑ Msw +∑ Mso In the formula, ∑ Mla The sum of the areas of the saturated manganese fluid, ∑ Mkw The sum of the movable water surface area saturated with manganese, ∑ Mko The sum of the movable oil surface area saturated with manganese, ∑ Msw The sum of the areas of manganese-bound water, ∑ Mso This represents the sum of the areas bound by manganese-saturated oil.

6. The method for identifying the fluid properties of low-permeability conglomerate based on well logging two-dimensional nuclear magnetic resonance as described in claim 4, characterized in that... The sum of the areas of saturated manganese fluid is calculated using the following formula: ∑ Mla ＝∑ Mkw +∑ Mko +∑ Msw +∑ Mso In the formula, ∑ Mla The sum of the areas of the saturated manganese fluid, ∑ Mkw The sum of the movable water surface area saturated with manganese, ∑ Mko The sum of the movable oil surface area saturated with manganese, ∑ Msw The sum of the areas of manganese-bound water, ∑ Mso This represents the sum of the areas bound by manganese-saturated oil.

7. The method for identifying the fluid properties of low-permeability conglomerate based on well logging two-dimensional nuclear magnetic resonance as described in claim 4, characterized in that...

8. The method for identifying the fluid properties of low-permeability conglomerate based on two-dimensional nuclear magnetic resonance logging according to claim 6, characterized in that... ∑ Mkw ,∑ Mko ,∑ Msw ,∑ Mso The calculation formula is as follows:

9. The method for identifying the fluid properties of low-permeability conglomerate based on two-dimensional nuclear magnetic resonance logging according to claim 7 or 8, characterized in that... In the formula, t T2max可动水 The maximum time of the T2 cutoff value corresponding to movable water, in milliseconds; t T2min可动水 The minimum cutoff time for movable water is T2, expressed in milliseconds (ms). T1max可动水 The maximum value of the cutoff time T1 corresponding to movable water, in milliseconds; t T1min可动水 Let T1 be the minimum cutoff time for the movable water, in ms; ∫movable water(t)*dt is the envelope area of ​​the movable water. t T2max可动油 The maximum T2 cutoff time for movable oil, in milliseconds; t T2min可动油 The minimum cutoff time for the movable oil is T2, expressed in milliseconds (ms). T1max可动油 The maximum value of the cutoff time T1 corresponding to the movable oil, in milliseconds; t T1min可动油 The minimum cutoff time for the movable oil is T1, in ms; ∫movable oil(t)*dt is the envelope area of ​​the movable oil; t T2max束缚水 The maximum T2 cutoff time for bound water, in milliseconds; t T2min束缚水 The minimum T2 cutoff time for bound water, in milliseconds (ms); t T1max束缚水 The maximum value of the T1 cutoff time corresponding to the bound water, in milliseconds; t T1min束缚水 Let T1 be the minimum cutoff time corresponding to the bound water, in ms; ∫bound water(t)*dt is the envelope area of ​​the bound water; t T2max束缚油 The maximum T2 cutoff time for the binding oil is expressed in milliseconds (ms); t T2min束缚油 The minimum T2 cutoff time for the binding oil, in milliseconds (ms); t T1max束缚油 The maximum value of the T1 cutoff time corresponding to the binding oil, in milliseconds; t T1min束缚油 denoted as the minimum cutoff time T1 corresponding to the binding oil, in ms; ∫binding oil(t)*dt is the envelope area of ​​the binding oil.

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