CN117805914A - Method for determining fluid type through shale oil laboratory and underground nuclear magnetic signal conversion - Google Patents
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Abstract
The invention belongs to the technical field of nuclear magnetic resonance logging, and discloses a method for determining fluid type by converting shale oil laboratory and underground nuclear magnetic signals. Setting a comparison experiment of nuclear magnetic resonance signals in a laboratory and an underground, and respectively acquiring one-dimensional T2 spectrum data and two-dimensional T2-T1 spectrum data of shale oil in different saturation states; according to the peak signal position and peak variation of the one-dimensional T2 spectrum and the two-dimensional T2-T1 spectrum data, a T1 and T2 conversion model of fluid components in the shale pores of the laboratory nuclear magnetic resonance and downhole nuclear magnetic resonance signals is constructed; according to the T1 and T2 conversion models of the fluid components in shale pores, a fluid identification plate or a T2 cut-off value suitable for shale oil laboratory nuclear magnetic resonance signals is used as laboratory nuclear magnetic resonance signals, the laboratory nuclear magnetic resonance signals are input into the T1 and T2 conversion models and converted into underground nuclear magnetic resonance signals, and the fluid type in the shale oil reservoir is determined according to the conversion result of the fluid identification plate or the T2 cut-off value.
Description
Technical Field
The invention belongs to the technical field of nuclear magnetic resonance logging, and particularly relates to a method for determining a fluid type through shale oil laboratory and underground nuclear magnetic signal conversion.
Background
Shale oil reservoir pore structure is complicated, and fluid occurrence state is various, and conventional logging method is difficult to accurately evaluate reservoir information. Nuclear magnetic resonance logging is one of the effective means for evaluating shale oil reservoirs at present by directly detecting reservoir fluid signals.
In the nuclear magnetic logging interpretation process, the core is measured by a nuclear magnetic resonance core analyzer in a laboratory, and a T2-T1 two-dimensional nuclear magnetic resonance fluid identification chart is manufactured. However, in order to obtain more abundant fluid information, the measurement conditions of the nuclear magnetic resonance core analyzer in a laboratory are often more demanding than those of a nuclear magnetic logging instrument. However, the nuclear magnetic measurement result is sensitive to the measurement parameters, so that the fluid identification plate measured in the laboratory is difficult to effectively apply to the actual nuclear magnetic logging data interpretation, the underground actual fluid type cannot be accurately judged, the fluid characteristics obtained by the conventional laboratory are not completely consistent with logging data, theoretical basis cannot be provided for representing reservoir fluid component information by nuclear magnetic resonance logging, and more accurate logging interpretation can not be carried out on the actual nuclear magnetic logging data, so that the fluid type analyzed according to the experimental data in the laboratory is inconsistent with the fluid type in the underground actual application, and the difficulty of accurately evaluating the shale oil reservoir fluid is increased.
Disclosure of Invention
The invention aims to provide a method for determining the fluid type through shale oil laboratory and underground nuclear magnetic signal conversion, so as to solve the problems in the prior art;
in order to achieve the above object, the present invention provides the following technical solutions:
a method for determining fluid type by shale oil laboratory and downhole nuclear magnetic signal conversion comprises,
setting a comparison experiment of nuclear magnetic resonance signals in a laboratory and an underground, and respectively acquiring one-dimensional T2 spectrum data and two-dimensional T2-T1 spectrum data of shale oil in different saturation states;
according to the peak signal position and peak variation of the one-dimensional T2 spectrum and the two-dimensional T2-T1 spectrum data, a T1 and T2 conversion model of fluid components in the shale pores of the laboratory nuclear magnetic resonance and downhole nuclear magnetic resonance signals is constructed;
according to the T1 and T2 conversion models of the fluid components in shale pores, a fluid identification plate or a T2 cut-off value suitable for shale oil laboratory nuclear magnetic resonance signals is used as laboratory nuclear magnetic resonance signals, the laboratory nuclear magnetic resonance signals are input into the T1 and T2 conversion models and converted into underground nuclear magnetic resonance signals, and the fluid type in the shale oil reservoir is determined according to the conversion result of the fluid identification plate or the T2 cut-off value.
Further, the method for establishing the conversion model comprises the steps of,
performing laboratory and simulated underground nuclear magnetic resonance comparison experiments to obtain one-dimensional T2 spectrum and two-dimensional T2-T1 spectrum data under the comparison experiments;
respectively acquiring the peak positions and the peak sizes of each fluid component T1 and T2 in the underground nuclear magnetic resonance signals and the laboratory nuclear magnetic resonance signals according to experimental data, and establishing a data curve of the T1 and T2 peak values;
and fitting the peak data of the fluid components in the underground and laboratory nuclear magnetic resonance signals according to the acquired peak data curve to obtain underground and experimental conversion models.
Further, the experimental data are depth of fluid in shale pores, horizon and core nuclear magnetic porosity.
Further, the shale oil is measured by a 21MHz nuclear magnetic resonance core analyzer when one-dimensional T2 spectrum data and two-dimensional T2-T1 spectrum data of the shale oil under different saturation states are obtained in a laboratory.
Further, when one-dimensional T2 spectrum and two-dimensional T2-T1 spectrum data of shale oil in different saturation states are acquired underground, a 2MHz nuclear magnetic resonance core analyzer is adopted to simulate underground multidimensional nuclear magnetic instruments to acquire data.
Further, the T1 and T2 transformation model of the fluid component in the shale pores is a transformation model between saturated oil and saturated water in shale oil.
Further, the nuclear magnetic resonance signals are oil signals and water signals in a shale oil reservoir.
Further, the transformation model under the oil signal condition is:
T 1 laboratory ＝3.7296 T 1, downhole 0.8145 ；
T 2 laboratory ＝0.0737 T 2, downhole 1.3832 。
Further, the conversion model under the water signal condition is:
T 1 laboratory ＝1.3261 T 1, downhole 0.9754 ,
T 2 laboratory ＝0.2995 T 2, downhole 1.0805 。
Compared with the prior art, the invention has the advantages that:
according to the method for determining the fluid type through shale oil laboratory and underground nuclear magnetic resonance signal conversion, one-dimensional T2 spectrum and two-dimensional T2-T1 spectrum data of shale oil in different saturation states and peak signal position and peak change data of the one-dimensional T2 spectrum and the two-dimensional T2-T1 spectrum data are obtained through a comparison experiment of laboratory and underground nuclear magnetic resonance signals, and a T1 and T2 conversion model of the fluid component in shale pores is constructed; inputting a nuclear magnetic resonance signal applicable to a shale oil laboratory with a fluid identification plate or a T2 cut-off value as a laboratory nuclear magnetic resonance signal into the T1 and T2 conversion model through the constructed T1 and T2 conversion model of the fluid components in the shale pores, converting the nuclear magnetic resonance signal into an underground nuclear magnetic resonance signal, and determining the fluid type in the shale oil reservoir according to the fitting result of the fluid identification curve and the positions of various fluids in the plate; the final fluid type is determined through the position and the proportion of the fluid in the plate, so that the fluid data analyzed in the laboratory are consistent with the fluid type actually measured underground, the data of nuclear magnetic logging can be more accurately interpreted, and the difficulty of accurately evaluating the shale oil reservoir fluid is reduced.
Drawings
The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this specification, illustrate embodiments of the invention and together with the description serve to explain the invention.
In the drawings:
FIG. 1 is a T2-T1 spectrum of a fluid under different oil saturation conditions in a laboratory and under a well in a method for determining a fluid type by converting nuclear magnetic signals in the laboratory and under the well in the shale oil;
FIG. 2 is a T2-T1 spectrum of a fluid under different saturated water sample conditions in a laboratory and under a well in a method for determining the fluid type by converting nuclear magnetic signals in the laboratory and under the well in the shale oil;
FIG. 3 is a graph of the variation of laboratory and downhole fluid locations under oil signal conditions in a method of determining fluid type by shale oil laboratory and downhole nuclear magnetic signal conversion in accordance with the present invention;
FIG. 4 is a graph of the variation of laboratory and downhole fluid position under water signal conditions in a method of determining fluid type by shale oil laboratory and downhole nuclear magnetic signal conversion in accordance with the present invention;
FIG. 5 is a schematic diagram of laboratory and downhole fluid identification in a method of determining fluid type by shale oil laboratory and downhole nuclear magnetic signal conversion in accordance with the present invention;
FIG. 6 is a practical application chart of a shale oil laboratory and downhole nuclear magnetic signal fluid identification chart of a method for determining fluid type by converting downhole nuclear magnetic signals;
fig. 7 is a diagram of an example of fluid type identification application of a downhole nuclear magnetic signal fluid identification plate based on laboratory conversion in a method for determining fluid type by shale oil laboratory and downhole nuclear magnetic signal conversion according to the invention.
Detailed Description
The invention will be described in detail below with reference to the drawings in connection with embodiments. It should be noted that, without conflict, the embodiments of the present invention and features of the embodiments may be combined with each other.
The following detailed description is exemplary and is intended to provide further details of the invention. Unless defined otherwise, all technical terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs. The terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of example embodiments in accordance with the invention.
A method for determining fluid type by shale oil laboratory and downhole nuclear magnetic signal conversion comprises,
setting a comparison experiment of nuclear magnetic resonance signals in a laboratory and an underground, and respectively acquiring one-dimensional T2 spectrum data and two-dimensional T2-T1 spectrum data of shale oil in different saturation states;
according to the peak signal position and peak variation of the one-dimensional T2 spectrum and the two-dimensional T2-T1 spectrum data, a T1 and T2 conversion model of fluid components in the shale pores of the laboratory nuclear magnetic resonance and downhole nuclear magnetic resonance signals is constructed;
according to T1 and T2 conversion models of fluid components in shale pores, a fluid identification plate or a T2 cut-off value suitable for shale oil laboratory nuclear magnetic resonance signals is used as laboratory nuclear magnetic resonance signals, the laboratory nuclear magnetic resonance signals are input into the T1 and T2 conversion models and converted into underground nuclear magnetic resonance signals, and the fluid type in the shale oil reservoir is determined according to fitting results of fluid identification curves.
Specifically, the one-dimensional T2 spectrum and the two-dimensional T2-T1 spectrum of shale oil in different saturation states are obtained in a laboratory and measured by a 21MHz nuclear magnetic resonance core analyzer.
Specifically, when data of one-dimensional T2 spectrum and two-dimensional T2-T1 spectrum of shale oil in different saturation states are acquired underground, a 2MHz nuclear magnetic resonance core analyzer is adopted to simulate underground multidimensional nuclear magnetic instruments to acquire the data.
Specifically, nuclear magnetic contrast experiments under laboratory and downhole measurement conditions are included.
Specifically, according to logging and perforation data, a plurality of shale cores of the depressed shale oil reservoir are selected, and the selected shale cores need to contain main lithology of the depressed shale oil reservoir. And preparing the shale core samples for experiments into standard plunger samples.
And then, respectively measuring the nuclear magnetic information of T2 and T2-T1 on the saturated oil and saturated water states of the shale sample by using nuclear magnetic experimental instruments with different frequencies so as to determine the nuclear magnetic response characteristics of different occurrence state fluids in the shale oil reservoir under underground and laboratory measurement conditions. Here, the laboratory instrument selects 21MHz and 2MHz nuclear magnetic resonance core analyzers. The 21MHz nuclear magnetic resonance core analyzer has better signal-to-noise ratio of echo data, less time consumption and higher experimental efficiency, and is the most effective means for analyzing core fluid in a laboratory. And the 2MHz nuclear magnetic resonance core analyzer is consistent with the frequency of a downhole multidimensional nuclear magnetic instrument (CMR-magniHI) and can simulate the downhole measurement of nuclear magnetic resonance signals.
Analysis and comparison of experimental results
And (3) analyzing experimental results, and comparing relaxation response rules of different fluids under underground and laboratory conditions. Taking one core as an example (lithology is argillaceous dolomite, depth is 3536.80 m, horizon is P2l 22-2), core nuclear magnetic porosityThe T2-T1 two-dimensional nuclear magnetic resonance result is shown in fig. 1 and 2. The signal response of the core with a high T1/T2 ratio at the upper left corner in the T2-T1 two-dimensional nuclear magnetic spectrum is the response of a solid organic matter component, and the other signal in the relaxation spectrum is the response of a water/oil component. The oil signal relaxation characteristics in fig. 1 change from t2=33.4 ms, t1=155 ms, t1/t2=4.64 to t2=2.99 ms, t1=193 ms, t1/t2=64.5 as the resonance frequency of the nuclear magnetic instrument increases; the water signal relaxation characteristics changed from t2=8.96 ms, t1=21.5 ms, t1/t2=2.40 to t2=1.55 ms, t1=33.4 ms, t1/t2=21.55.
Compared with underground nuclear magnetic measurement, the transverse relaxation time T2 of oil signals and water signals under laboratory conditions is smaller, the longitudinal relaxation time T1 is larger, the ratio of T1 to T2 is larger, and signals on a T2-T1 two-dimensional spectrum are far more leftwards and upwards. This is due to the fact that the magnetic field gradient inside the rock is generated due to the difference in magnetization between the core skeleton and the fluid, and the transverse relaxation rate is accelerated due to the higher magnetic field strength, so that the transverse relaxation time is smaller. Meanwhile, the change rules of oil and water signals are different, so that oil and water fluids are respectively discussed when the underground nuclear magnetic resonance signal conversion rules and laboratory nuclear magnetic resonance signal conversion rules are summarized.
As shown in fig. 1 and 2, fig. 1 (1) is a T2-T1 spectrum of a shale core saturation sample under a downhole nuclear magnetic measurement condition, and fig. 1 (2) is a T2-T1 spectrum under a laboratory saturation sample condition; the (3) in FIG. 2 is the T2-T1 spectrum under the condition of underground water saturation sample, and (4) is the T2-T1 spectrum under the condition of laboratory water saturation sample.
Construction of laboratory nuclear magnetic resonance and underground nuclear magnetic resonance signal conversion model
And comparing and analyzing the experimental results of the underground nuclear magnetic signals and the laboratory nuclear magnetic signals, carrying out statistical analysis on the nuclear magnetic results of the core measured under underground and laboratory conditions in the water-saturated and oil-saturated states, and determining the relationship between response characteristics of a nuclear magnetic logging instrument and a laboratory nuclear magnetic core analyzer to various observation targets as shown in fig. 3 and 4, thereby establishing an underground nuclear magnetic resonance and laboratory nuclear magnetic resonance signal conversion model.
Specifically, the method for establishing the conversion model comprises the following steps of,
performing laboratory and simulated underground nuclear magnetic resonance comparison experiments to obtain one-dimensional T2 spectrum and two-dimensional T2-T1 spectrum data under the comparison experiments;
respectively acquiring the peak positions and the peak sizes of each fluid component T1 and T2 in the underground nuclear magnetic resonance signals and the laboratory nuclear magnetic resonance signals according to experimental data, and establishing a data curve of the T1 and T2 peak values;
and fitting the peak data of the fluid components in the underground and laboratory nuclear magnetic resonance signals according to the acquired peak data curve to obtain underground and experimental conversion models.
In particular, experimental data are depth of fluid in shale pores, horizon and core nuclear magnetic porosity.
Specifically, the T1 and T2 conversion model of the fluid composition within the shale pores is a conversion model between saturated oil and saturated water in shale oil.
Specifically, the nuclear magnetic resonance signals are oil signals and water signals in shale oil reservoirs.
As shown in fig. 3 and fig. 4, the change diagrams of the positions of the laboratory and the downhole fluid under the oil signal condition and the water signal condition in the method for determining the fluid type by converting the shale oil laboratory and the downhole nuclear magnetic signal according to the invention are respectively shown.
The relaxation time change rule of the oil signal and the water signal under the two measurement conditions is different, and the response of the longitudinal relaxation time and the transverse relaxation time is also different. Fitting response rules of different fluids under different relaxation times under underground and laboratory conditions can obtain an underground nuclear magnetic resonance signal conversion model and a laboratory nuclear magnetic resonance signal conversion model, wherein the response rules are represented by the following formula:
oil: t (T) 1,21MHz ＝3.7296 T 1,2MHz 0.8145 ,R 2 ＝0.9445 (1)
Oil: t (T) 2,21MHz ＝0.0737 T 2,2MHz 1.3832 ,R 2 ＝0.9663 (2)
Water: t (T) 1,21MHz ＝1.3261 T 1,2MHz 0.9754 ,R 2 ＝0.989 (3)
Water: t (T) 2,21MHz ＝0.2995 T 2,2MHz 1.0805 ,R 2 ＝0.9966 (4)
Wherein T is 1,21MHz 、T 2,21MHz Longitudinal and transverse relaxation times measured by laboratory instruments are respectively corresponding to the longitudinal and transverse relaxation times; t (T) 1,2MHz 、T 2,2MHz And respectively corresponding to the longitudinal and transverse relaxation times measured by the simulated downhole logging instrument. The model not only can convert one-dimensional T2 nuclear magnetic resonance signals, but also can convert T2-T1 two-dimensional nuclear magnetic resonance signals.
Specifically, the conversion model under the oil signal condition is the above formula (1) and formula (2), that is, the relationship between the conversion model under the laboratory condition and the downhole conversion model between oil signals is:
T 1 laboratory ＝3.7296 T 1, downhole 0.8145 ；
T 2 laboratory ＝0.0737 T 2, downhole 1.3832 。
Specifically, the conversion model under the water signal condition is the above formula (3) and formula (4), that is, the relationship between the conversion model under the laboratory condition and the downhole conversion model under the water signal condition is:
T 1 laboratory ＝1.3261 T 1, downhole 0.9754 ,
T 2 laboratory ＝0.2995 T 2, downhole 1.0805 。
The measured parameters are different downhole and laboratory due to the sensitivity of the nuclear magnetic resonance signal of shale pore fluids to the measured parameters. According to the method for determining the fluid type through shale oil laboratory and underground nuclear magnetic signal conversion, through a physical experiment, experimental results of one-dimensional T2 and two-dimensional T2-T1 of a laboratory and an underground simulated shale core are compared, and influences under two measurement conditions are clear. And quantifying peak positions and peak changes in laboratory and underground simulation experiment results, and constructing the quantitative relation under two conditions so as to form a conversion model. Finally, the model is applied, i.e. the laboratory fluid interpretation plate and T2 cut-off values are converted for downhole nuclear magnetic log data interpretation, as shown in fig. 5, 6 and 7.
It will be appreciated by those skilled in the art that the present invention can be carried out in other embodiments without departing from the spirit or essential characteristics thereof. Accordingly, the above disclosed embodiments are illustrative in all respects, and not exclusive. All changes that come within the scope of the invention or equivalents thereto are intended to be embraced therein.
Finally, it should be noted that: the above embodiments are only for illustrating the technical aspects of the present invention and not for limiting the same, and although the present invention has been described in detail with reference to the above embodiments, it should be understood by those of ordinary skill in the art that: modifications and equivalents may be made to the specific embodiments of the invention without departing from the spirit and scope of the invention, which is intended to be covered by the claims.
Claims (9)
1. A method for determining fluid type by shale oil laboratory and downhole nuclear magnetic signal conversion is characterized by comprising the following steps of,
setting a comparison experiment of nuclear magnetic resonance signals in a laboratory and an underground, and respectively acquiring one-dimensional T2 spectrum data and two-dimensional T2-T1 spectrum data of shale oil in different saturation states;
according to the peak signal position and peak variation of the one-dimensional T2 spectrum and the two-dimensional T2-T1 spectrum data, a T1 and T2 conversion model of fluid components in the shale pores of the laboratory nuclear magnetic resonance and downhole nuclear magnetic resonance signals is constructed;
according to the T1 and T2 conversion models of the fluid components in shale pores, a fluid identification plate or a T2 cut-off value suitable for shale oil laboratory nuclear magnetic resonance signals is used as laboratory nuclear magnetic resonance signals, the laboratory nuclear magnetic resonance signals are input into the T1 and T2 conversion models and converted into underground nuclear magnetic resonance signals, and the fluid type in the shale oil reservoir is determined according to the conversion result of the fluid identification plate or the T2 cut-off value.
2. The method for determining the fluid type by converting shale oil laboratory and underground nuclear magnetic signals according to claim 1, wherein the method for establishing the conversion model comprises the following steps of,
performing laboratory and simulated underground nuclear magnetic resonance comparison experiments to obtain one-dimensional T2 spectrum and two-dimensional T2-T1 spectrum data under the comparison experiments;
respectively acquiring the peak positions and the peak sizes of each fluid component T1 and T2 in the underground nuclear magnetic resonance signals and the laboratory nuclear magnetic resonance signals according to experimental data, and establishing a data curve of the T1 and T2 peak values;
and fitting the peak data of the fluid components in the underground and laboratory nuclear magnetic resonance signals according to the acquired peak data curve to obtain underground and experimental conversion models.
3. The method of determining fluid type by shale oil laboratory and downhole nuclear magnetic signal conversion of claim 2, wherein the experimental data is nuclear magnetic resonance signals assigned to different fluid components within shale pores.
4. The method for determining the fluid type by converting shale oil laboratory and underground nuclear magnetic signals according to claim 1, wherein the measurement is performed by a 21MHz nuclear magnetic resonance core analyzer when one-dimensional T2 spectrum and two-dimensional T2-T1 spectrum data of shale oil in different saturation states are acquired in the laboratory.
5. The method for determining the fluid type by converting shale oil laboratory and underground nuclear magnetic signals according to claim 1, wherein the underground multidimensional nuclear magnetic instrument is adopted for measurement when the one-dimensional T2 spectrum and the two-dimensional T2-T1 spectrum data of shale oil in different saturation states are acquired underground.
6. The method of determining fluid type by shale oil laboratory and downhole nuclear magnetic signature conversion of claim 1, wherein the T1 and T2 conversion model of fluid components in shale pores is a conversion model of oil and water signals in shale nuclear magnetic resonance signals.
7. The method of determining fluid type by shale oil laboratory and downhole nuclear magnetic signature conversion of claim 1, wherein the nuclear magnetic resonance signature is an oil signature and a water signature in a shale oil reservoir.
8. The method for determining fluid type by shale oil laboratory and downhole nuclear magnetic signal conversion according to claim 7, wherein the conversion model under the condition of oil signal is:
T 1 laboratory ＝3.7296T 1, downhole 0.8145 ；
T 2 laboratory ＝0.0737T 2, downhole 1.3832 。
9. The method for determining fluid type by shale oil laboratory and downhole nuclear magnetic signal conversion according to claim 7, wherein the conversion model under the condition of water signal is:
T 1 laboratory ＝1.3261T 1, downhole 0.9754 ,
T 2 laboratory ＝0.2995T 2, downhole 1.0805 。
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Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN118655169A (en) * | 2024-08-15 | 2024-09-17 | 东北石油大学三亚海洋油气研究院 | Fluid identification method and device based on Gaussian function affine transformation |
| CN119198453A (en) * | 2024-11-26 | 2024-12-27 | 中国石油大学(华东) | A quantitative characterization method of full-size pores for oil and water storage in tight reservoirs based on well logging nuclear magnetic resonance |
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Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN118655169A (en) * | 2024-08-15 | 2024-09-17 | 东北石油大学三亚海洋油气研究院 | Fluid identification method and device based on Gaussian function affine transformation |
| CN118655169B (en) * | 2024-08-15 | 2024-10-22 | 东北石油大学三亚海洋油气研究院 | Fluid identification method and device based on Gaussian function affine transformation |
| CN119198453A (en) * | 2024-11-26 | 2024-12-27 | 中国石油大学(华东) | A quantitative characterization method of full-size pores for oil and water storage in tight reservoirs based on well logging nuclear magnetic resonance |
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