CN111679343A - Seismic electromagnetic composite data acquisition system and underground reservoir oil and gas reserve prediction method - Google Patents
Seismic electromagnetic composite data acquisition system and underground reservoir oil and gas reserve prediction method Download PDFInfo
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Abstract
The invention provides a seismic electromagnetic composite data acquisition system and a method for predicting oil and gas reserves of an underground reservoir, which utilize three-dimensional seismic and electromagnetic data, core measurement data, acoustic and electromagnetic logging data, the burial depth and thickness of a hydrocarbon reservoir, underground three-dimensional spread and total volume of the hydrocarbon reservoir, wave impedance of the acoustic logging data to calibrate the porosity of the hydrocarbon reservoir, resistivity of the electromagnetic logging data to calibrate the hydrocarbon saturation of the hydrocarbon reservoir, and three-dimensional seismic data to invert the wave impedance of the hydrocarbon reservoir, and calculate the total porosity distribution of the reservoir according to the porosity calibrated by the wave impedance; the three-dimensional electromagnetic data inverts the resistivity of the oil-gas-containing reservoir, and the total oil-gas saturation of the reservoir is calculated according to the oil-gas saturation calibrated by the resistivity; calculating the total fluid volume of the hydrocarbon-bearing reservoir according to the volume of the hydrocarbon-bearing reservoir and the total porosity; and calculating the volume or weight of the total oil gas according to the saturation of the total oil gas, and predicting the total oil gas reserve of the oil gas reservoir.
Description
Technical Field
The invention belongs to the technical field of geophysical exploration, and particularly relates to a seismic electromagnetic composite data acquisition system and a method for predicting oil and gas reserves of an underground oil and gas reservoir.
Background
Seismic exploration refers to a geophysical exploration method for deducing the properties and forms of underground rock strata by observing and analyzing the propagation rule of seismic waves generated by artificial earthquake in the underground by utilizing the difference between the elasticity and the density of underground media caused by artificial excitation. Seismic exploration is the most important method in geophysical exploration and is the most effective method for solving the problem of oil and gas exploration. It is an important means for surveying petroleum and natural gas resources before drilling, and is widely applied to the aspects of coal field and engineering geological exploration, regional geological research, crust research and the like.
Seismic exploration is a geophysical exploration method which uses the differences of elasticity and density of underground media to infer the nature and form of underground rock formations by observing and analyzing the response of the earth to artificially excited seismic waves. The method uses the elastic waves excited by a manual method to position the mineral deposits and acquire engineering geological information. Seismic exploration is an important means for surveying geology and prospecting petroleum, natural gas resources and solid resources before drilling, and is widely applied to the aspects of geological exploration of coal fields and engineering, regional geological research, crustal research and the like.
Seismic exploration is characterized in that the earth crust vibration (such as explosive explosion and vibroseis vibration) is caused by an artificial method, the vibration information of each receiving point on the ground after explosion is recorded by a precise instrument according to a certain observation mode, and the characteristics of the underground geological structure are deduced by using result data obtained after a series of processing on the original recorded information. The seismic waves are excited artificially on the earth surface, and when the waves propagate underground, the waves are reflected and refracted when encountering rock stratum interfaces with different medium properties, and the waves are received by a detector on the earth surface or in a well. The received seismic signals are related to the seismic source characteristics, the location of the geophone points, and the nature and structure of the subterranean strata through which the seismic waves pass. By processing and interpreting seismic wave recordings, the nature and morphology of the subterranean formation can be inferred. Seismic exploration is superior to other geophysical exploration methods in both the detail of stratification and the accuracy of exploration. Seismic surveys typically range in depth from tens of meters to tens of kilometers. The difficulty in seismic exploration is the improvement of resolution, which facilitates the study of fine structures in the subsurface, thereby providing a more detailed understanding of the formation and distribution.
The electromagnetic prospecting method is an electric prospecting method which takes the electromagnetic difference of a medium as a material basis and achieves certain prospecting purposes by observing and researching the change rule of an artificial or natural alternating electromagnetic field along with the space distribution rule or along with time.
The mineral exploration principle of electromagnetic exploration is based on the change of electrical properties among different rocks and minerals, and the corresponding change of the spatial distribution state of an electromagnetic field (artificial and natural) is caused. Therefore, people can utilize instruments with different performances to survey mineral resources or find out the existing state of a geological target in the crust through observation and research on the spatial and temporal distribution state of a field, thereby realizing the geological target of electrical prospecting.
Induction electromagnetic prospecting methods are generally classified into two categories: one type is an electromagnetic method for directly searching oil gas, and at present, an induced polarization method, a magnetoelectric method, an electric field difference method and the like are mainly used. The other is a method for searching oil-gas-containing structures, and at present, the methods mainly comprise an earth electromagnetic Method (MT), an electromagnetic array profile method (EMAP), a field building and depth measurement method and the like.
The difference between the electromagnetic survey data acquisition and the data acquisition of other geophysical prospecting methods lies in the diversity of the electromagnetic survey data acquisition, which is indistinguishable from the diversity of the electromagnetic survey methods. The electromagnetic prospecting method is many, and the working method diverse, the device is different, and the characteristics in field are different, and the sensor is different for it is various to gather the form. It has both natural and artificial source methods. The electric field can be measured by adopting a grounding electrode, and the magnetic field can also be measured by adopting a non-grounding coil; both relative and absolute quantities can be measured; either scalar or vector measurements can be made; the amplitude and the phase can be measured, and real and imaginary components can be measured; both the total field and the pure anomalous field can be measured.
The oil and gas reserves are one of the important contents of oil and gas resource management and planning, and also are the basis for guiding the work of each stage of the oil enterprises (companies) and compiling medium and long-term development plans. The result of reserve evaluation is directly related to the development scale of the oil and gas field, the reliability of each development index prediction and the overall benefit, and is an important basis for development decision. Therefore, the research on the petroleum and natural gas reserve evaluation method is a necessary work. At present, petroleum and natural gas reserves commonly used at home and abroad are eight practical and effective resource quantity evaluation methods of four categories, namely a Weng's convolution prediction model, a Weibull prediction model, a lognormal distribution prediction model, a logistic prediction model, a Hu-Chen-Zhang prediction model, a gray system prediction method, an oil field scale sequence method and a Monte Carlo method.
The ascertained reserves of oil and gas are also called confirmed reserves. Is the calculated reserve after completion of the field evaluation drilling phase. In modern technological and economic conditions, reliable reserves can be provided for mining and economic benefits. The exploration of reserves is the basis for compiling oil and gas field development schemes, making oil and gas field development construction investment decisions and development analysis. The ascertained reserves can be further divided into three categories according to the degree of exploration and development and the complexity of the hydrocarbon reservoir: developed proven reserves, undeveloped proven reserves, basic proven reserves. Unexplored exploratory reserves (class ii for short, class B relative to other species) which refer to reserves calculated after evaluation drilling has been completed and reliable reserve parameters have been obtained. The method is a basis for compiling a development scheme and making development and construction investment decisions, and the relative error of the method cannot exceed plus or minus 20 percent. The relative error of the basic ascertained reserves (class iii for short, relative to class C of other mine species) is less than plus or minus 30%. After the earthquake detailed investigation or three-dimensional earthquake is completed and an evaluation well is drilled, the calculated reserves are the basic exploratory reserves under the conditions that the reserve parameters are basically full and the oil-bearing area is basically controlled. This reserve is the basis for "rolling exploration development". In the process of rolling exploration and development, part of development wells have the task of detection, and various parameters of accurate reserves are compensated. Within 3 years after the rolling exploration and development are put into, the reservoir can be directly upgraded to the developed and proven reserve after rechecking.
The oil and gas resource prediction method is mainly used for estimating the undiscovered oil and gas resource prediction method. The calculation methods are many and mainly include: an area yield method; constructing an average method; reserve density method; a proportional method; the eltak-suadei method; the least factor (weakest link) method; image recognition (scoring); quantitative ratio method; a deposition volume rate method; reservoir volumetric productivity; the trapping volume method; barrel/acre-foot method (unit volume yield method); volumetric methods (canadian geological survey); oil gas concentration coefficient method; an aggregation coefficient method; migration coefficient method; an organic carbon method; a hydrocarbon process; the asphalt method is improved by a formula method; erdemann-hunter method; a kerogen thermal degradation mathematical simulation method; the Zapu method; the habert method (historical statistics, trend extrapolation); the Menard method; oil reservoir scale distribution; field scale sequencing (oilfield sequencing); delphi method (expert review); the pedicle screw method; classification analysis (statistical comparison); a geological comparison method; a proportional method; comparing the exploration degrees; linear density method, etc. Some of these methods are heterogeneous and can be broadly classified into four major groups: analyzing and analogy geological conditions; analysis and analogy of deposition conditions; analysis and analogy of raw oil and migration conditions; and fourthly, statistical analysis of historical data.
At present, the most used oil and gas resource reserve prediction method in the industry is mostly obtained by a statistical analysis and analogy method based on well logging data interpretation results and actual production data of oil and gas wells. These methods are essentially reliable in evaluating hydrocarbon resource reserves obtained at well and hydrocarbon production well locations. However, the number of evaluation wells and oil and gas production wells in an oil field is limited, and it is difficult to accurately evaluate and predict the oil and gas resource reserves in the whole oil field reservoir only by relying on a few evaluation wells and oil and gas production wells in the oil field, and particularly in an oil field distant view area with few or few evaluation wells and oil and gas production wells, there is almost no way to evaluate and predict the oil and gas resource reserves in the oil field range by using well logging data interpretation results and production data of actual oil and gas wells.
Disclosure of Invention
In order to evaluate and predict the oil gas resource reserves accurately and reliably in the oil field remote areas with few or missing evaluation wells and oil gas production wells, the invention provides a seismic electromagnetic composite data acquisition system and a method for predicting the oil gas reserves of underground reservoirs, which adopts three-dimensional seismic and electromagnetic data synchronously acquired on the ground or in the ground and wells, combines with laboratory rock physical measurement data, acoustic wave and electromagnetic logging data, and utilizes the three-dimensional seismic data to explain the burial depth, thickness and underground three-dimensional spread and total volume of the oil gas reservoirs obtained by results; calibrating the porosity of the oil-gas reservoir in the well by using the wave impedance of the acoustic logging data, and finding a relational expression between the longitudinal wave impedance and the porosity of the oil-gas reservoir; calibrating the oil-gas saturation of the oil-gas reservoir in the well by using the resistivity of the electromagnetic logging data, and obtaining a relational expression between the resistivity of the oil-gas reservoir and the oil-gas saturation; inverting the wave impedance of the oil-gas reservoir through three-dimensional seismic data, and calculating the total porosity and the distribution of the reservoir according to a relational expression between the longitudinal wave impedance and the porosity of the oil-gas reservoir and the wave impedance distribution value of the oil-gas reservoir; inverting the resistivity of the hydrocarbon-bearing reservoir through three-dimensional electromagnetic data, and calculating the total hydrocarbon saturation and the distribution of the hydrocarbon-bearing saturation of the reservoir according to a relational expression between the resistivity and the hydrocarbon saturation of the hydrocarbon-bearing reservoir and the resistivity distribution value of the hydrocarbon-bearing reservoir; the total fluid volume in the hydrocarbon-bearing reservoir and the distribution of the total fluid volume in the hydrocarbon-bearing reservoir in a three-dimensional space can be calculated according to the volume of the hydrocarbon-bearing reservoir and the total porosity distribution; the total oil and gas volume or weight (reserve) in the oil and gas reservoir and the distribution thereof on a three-dimensional space can be calculated according to the total oil and gas saturation distribution of the oil and gas reservoir, so that the total oil and gas reserve of the oil and gas reservoir can be evaluated and predicted.
The specific technical scheme is as follows:
a seismic electromagnetic composite data acquisition system comprising: the system comprises a ground three-dimensional distributed artificial seismic source, a ground controllable electromagnetic source, a ground three-dimensional distributed seismic data acquisition device, a ground three-dimensional distributed electromagnetic data acquisition device and an underground seismic electromagnetic composite signal receiving and acquiring short circuit;
the underground seismic electromagnetic composite signal receiving and acquiring short circuit is connected with a ground seismic electromagnetic composite data acquisition control instrument and a laser modulation and demodulation instrument in a work area or near a wellhead through an armored photoelectric composite cable, and the armored photoelectric composite cable controls the underground seismic electromagnetic composite signal receiving and acquiring short circuit at the depth position in the well;
the artificial seismic sources are seismic sources excited on the ground according to pre-designed seismic source lines and seismic source points, the seismic sources are uniformly or non-uniformly distributed, and the seismic sources are heavy hammer seismic sources, explosive seismic sources, air gun seismic sources, electric spark seismic sources or controllable seismic sources;
the ground controllable electromagnetic source comprises a high-power dipole current source or a large loop electromagnetic source which is distributed on the ground according to a pre-design;
the ground three-dimensional distributed seismic data acquisition device comprises a wired or wireless node type seismic data acquisition unit and a ground detector which are distributed according to a pre-designed measuring line and measuring points, wherein the ground detector is one of a single-component or three-component moving coil type detector, a piezoelectric type detector, an acceleration type detector, an MEMS detector and an optical fiber detector; the ground seismic data acquisition device is connected with the seismic electromagnetic composite data acquisition control instrument and the laser modulation and demodulation instrument;
the electromagnetic data acquisition device distributed in three dimensions on the ground comprises wired or wireless node type electromagnetic data acquisition units, three-component magnetic field sensors and non-polarized electrode pairs (electric field sensors), wherein the wired or wireless node type electromagnetic data acquisition units, the three-component magnetic field sensors and the non-polarized electrode pairs are distributed according to pre-designed measuring lines and measuring points. The three-component magnetic field sensor is one of an induction coil type magnetic field sensor, a fluxgate type magnetic field sensor, an MEMS (micro-electromechanical systems) magnetic field sensor, a superconducting magnetic field sensor and an optical fiber magnetic field sensor; the electric field sensor is one of copper sulfate, silver chloride, nano materials, tantalum capacitance non-polarized electrode pairs and an optical fiber electric field sensor; the ground electromagnetic data acquisition device is connected with the seismic electromagnetic composite data acquisition control instrument and the laser modulation and demodulation instrument;
the borehole seismic electromagnetic composite signal receiving and collecting short circuit is connected with a plurality of short circuits, and the short circuits are distributed in an array mode in a borehole.
The invention provides a method for predicting the oil and gas reserves of an underground reservoir, which adopts the seismic electromagnetic composite data acquisition system and comprises the following steps:
(a) the ground seismic data acquisition device (3), the ground electromagnetic data acquisition device (4) and the borehole seismic electromagnetic composite signal receiving acquisition short circuit (5) are arranged on the ground or on the ground and in the borehole according to the pre-design, a ground artificial seismic source (1) and a ground controllable electromagnetic source (2) are excited on the ground, and three-dimensional seismic and three-dimensional electromagnetic data in the ground or on the ground and in the borehole are synchronously acquired;
(b) carrying out amplitude preservation processing on ground three-dimensional seismic data or well-drive amplitude preservation processing on well-ground combined acquisition three-dimensional seismic data to finish anisotropic migration, reverse time depth migration and Q migration;
(c) comprehensively interpreting the results of amplitude preservation processing and deviation of ground three-dimensional seismic data or well-ground combined mining three-dimensional seismic data to obtain the burial depth and thickness of the oil-gas reservoir and the underground three-dimensional distribution and total volume;
(d) obtaining a wave impedance three-dimensional distribution value of the oil-gas reservoir by performing attribute inversion on the amplitude-preserved three-dimensional seismic data;
(e) preprocessing and processing the three-dimensional electromagnetic data acquired on the ground or on the ground and in the well, and constraining inversion of the three-dimensional electromagnetic data acquired on the ground or on the ground and in the well by utilizing the burial depth and the thickness of the hydrocarbon-bearing reservoir obtained in the step (c) and the underground three-dimensional space distribution to obtain a three-dimensional resistivity distribution value of the hydrocarbon-bearing reservoir;
(f) measuring the physical parameters of rocks in a laboratory on the rock core of the oil-gas reservoir to obtain the porosity and wave impedance of the rock core of the oil-gas reservoir and the resistivity of the rock core under different oil-gas saturation conditions;
(g) processing acoustic logging data of the hydrocarbon-bearing reservoir, and calibrating the porosity of the hydrocarbon-bearing reservoir at the drilling location using the wave impedance of the acoustic logging data and the wave impedance of the hydrocarbon-bearing reservoir core obtained in step (f); searching a curve of the data distribution rule on the cross plot and a mathematical expression thereof by the distribution rule of the data on the cross plot and the longitudinal wave impedance curve to obtain a relation (linearity) of the longitudinal wave impedance and the porosity of the hydrocarbon-bearing reservoir;
(h) processing electromagnetic logging data of the hydrocarbon-bearing reservoir, and calibrating the hydrocarbon saturation of the hydrocarbon-bearing reservoir at the drilling position by using the resistivity of the electromagnetic logging data and the resistivity of the core of the hydrocarbon-bearing reservoir obtained in the step (f) under different hydrocarbon saturation conditions; searching a curve of the data distribution rule on the cross plot and a mathematical expression thereof according to the distribution rule of the data on the resistivity curve and the oil and gas saturation cross plot, and obtaining a relational expression (nonlinearity) of the resistivity and the oil and gas saturation of the oil and gas reservoir;
(i) calculating the total porosity and the distribution of the reservoir according to the porosity of the oil-gas reservoir at the drilling position calibrated in the step (g), the obtained relational expression of the longitudinal wave impedance and the porosity of the oil-gas reservoir and the wave impedance three-dimensional distribution value of the inverted oil-gas reservoir in the step (d);
(j) calculating the total hydrocarbon saturation and the distribution thereof of the reservoir according to the hydrocarbon saturation of the hydrocarbon reservoir at the drilling position calibrated in the step (h), the obtained relational expression between the resistivity of the hydrocarbon reservoir and the hydrocarbon saturation and the resistivity three-dimensional distribution value of the hydrocarbon reservoir inverted in the step (e);
(k) (ii) calculating the total fluid volume of the hydrocarbon reservoir and its distribution in three dimensions from the volume of the hydrocarbon reservoir obtained in step (c) and the calculated total porosity of the reservoir and its distribution in step (i);
(l) And (c) calculating the total oil and gas saturation and distribution of the reservoir calculated in the step (j) and the total fluid volume of the hydrocarbon-bearing reservoir calculated in the step (k) and the distribution of the total fluid volume of the hydrocarbon-bearing reservoir in the three-dimensional space, so that the total oil and gas volume or weight (reserve) in the hydrocarbon-bearing reservoir and the distribution of the total fluid volume in the hydrocarbon-bearing reservoir in the three-dimensional space can be calculated, and the total oil and gas reserve of the hydrocarbon-bearing reservoir can be predicted.
The invention has the beneficial effects that: the method adopts three-dimensional seismic and electromagnetic data synchronously acquired on the ground or in the ground and a well, combines the physical measurement data of rocks in a laboratory, acoustic waves and electromagnetic logging data, and utilizes the three-dimensional seismic data to explain the depth, thickness, total volume and underground three-dimensional distribution of an oil-gas reservoir obtained by results; calibrating the porosity of the oil-gas reservoir in the well by using the wave impedance of the acoustic logging data, and finding a relational expression between the longitudinal wave impedance and the porosity of the oil-gas reservoir; calibrating the oil-gas saturation of the oil-gas reservoir in the well by using the resistivity of the electromagnetic logging data, and obtaining a relational expression between the resistivity of the oil-gas reservoir and the oil-gas saturation; inverting the wave impedance of the oil-gas reservoir through three-dimensional seismic data, and calculating the total porosity and the distribution of the reservoir according to a relational expression between the longitudinal wave impedance and the porosity of the oil-gas reservoir and the wave impedance and the distribution value of the oil-gas reservoir; inverting the resistivity of the hydrocarbon-bearing reservoir through three-dimensional electromagnetic data, and calculating the total hydrocarbon saturation and the distribution thereof of the reservoir according to a relational expression between the resistivity and the hydrocarbon saturation of the hydrocarbon-bearing reservoir and the resistivity and the distribution value of the hydrocarbon-bearing reservoir; the total fluid volume of the hydrocarbon-bearing reservoir and the distribution of the total fluid volume in the three-dimensional space can be calculated according to the total volume and the total porosity of the hydrocarbon-bearing reservoir and the distribution of the total porosity; the total oil gas volume or weight (reserve) in the oil gas reservoir and the distribution of the total oil gas volume or weight (reserve) in the oil gas reservoir in a three-dimensional space can be calculated according to the total oil gas saturation distribution of the oil gas reservoir, so that the total oil gas reserve of the oil gas reservoir can be accurately and reliably evaluated and predicted.
Drawings
FIG. 1 is a flow chart of a seismic electromagnetic complex data acquisition process and hydrocarbon resource reserve prediction method of the present invention.
FIG. 2 is a schematic structural diagram of a ground three-dimensional seismic electromagnetic composite data acquisition system with a ground electromagnetic source being a high-power dipole current source.
FIG. 3 is a schematic structural diagram of a ground three-dimensional seismic electromagnetic composite data acquisition system with a ground electromagnetic source as a large loop electromagnetic source according to the present invention.
FIG. 4 is a schematic structural diagram of a ground-well three-dimensional seismic electromagnetic composite data acquisition system with a ground electromagnetic source as a high-power dipole current source.
FIG. 5 is a schematic structural diagram of an earth-well three-dimensional seismic electromagnetic complex data acquisition system with a ground electromagnetic source as a large loop electromagnetic source according to the present invention.
FIG. 6a is a schematic representation of a portion of a log (density/porosity, gas saturation, compressional wave impedance, shale content) of the present invention through a gas bearing reservoir.
FIG. 6b is a schematic diagram of a linear relationship between the compressional wave impedance and the porosity obtained from the intersection of the compressional wave impedance and the porosity inverted from the sonic logging data according to the present invention.
Figure 7a is a schematic representation of a portion of a log (gas saturation, resistivity) of the invention through a gas bearing reservoir.
FIG. 7b is a schematic diagram of a nonlinear relation between resistivity and hydrocarbon saturation obtained by a resistivity and hydrocarbon saturation crossplot obtained by inverting electromagnetic logging data according to the present invention.
Detailed Description
In order to facilitate the understanding of the technical contents of the present invention by those skilled in the art, the present invention will be further explained with reference to the accompanying drawings.
The seismic electromagnetic composite data acquisition system of the invention refers to a synchronous acquisition system for seismic and ground three-dimensional distributed excitation and ground three-dimensional distributed electromagnetic data, as shown in fig. 1 and fig. 2, or a synchronous acquisition system for seismic and electromagnetic data distributed in a well, as shown in fig. 3 and fig. 4, in which the ground three-dimensional distributed excitation and ground three-dimensional distributed electromagnetic data, or a synchronous acquisition system for seismic and electromagnetic data distributed in a well, in which multiple points are excited and ground three-dimensional distributed.
Specifically, the seismic electromagnetic composite data acquisition system includes: the earthquake monitoring system comprises an artificial seismic source 1 in ground three-dimensional distribution, a ground controllable electromagnetic source 2, a seismic data acquisition device 3 in ground three-dimensional distribution, an electromagnetic data acquisition device 4 in ground three-dimensional distribution and a borehole seismic electromagnetic composite signal receiving and acquiring short circuit 5;
the underground seismic electromagnetic composite signal receiving and acquiring short circuit 5 is connected with a ground seismic electromagnetic composite data acquisition control instrument and a laser modulation and demodulation instrument 7 in a work area or near a wellhead through an armored photoelectric composite cable 6, and the armored photoelectric composite cable 6 controls the depth position of the underground seismic electromagnetic composite signal receiving and acquiring short circuit 5 in a well;
the artificial seismic sources 1 are seismic sources excited on the ground according to pre-designed seismic source lines and seismic source points, the seismic sources are uniformly or non-uniformly distributed, and the seismic sources are heavy hammer seismic sources, explosive seismic sources, air gun seismic sources, electric spark seismic sources or controllable seismic sources;
the ground controllable electromagnetic source 2 comprises a high-power dipole current source which is distributed on the ground according to a preset design, such as the electromagnetic source shown in figures 1 and 3, or a large loop electromagnetic source, such as the electromagnetic source shown in figures 2 and 4;
the ground three-dimensional distributed seismic data acquisition device 3 comprises a wired or wireless node type seismic data acquisition unit and a ground detector which are distributed according to a pre-designed measuring line and measuring point, wherein the ground detector is one of a single-component or three-component moving coil type detector, a piezoelectric type detector, an acceleration type detector, an MEMS detector and an optical fiber detector; the ground seismic data acquisition device 3 is connected with a seismic electromagnetic composite data acquisition control instrument and a laser modulation and demodulation instrument 7;
the electromagnetic data acquisition device 4 distributed in three dimensions on the ground comprises wired or wireless node type electromagnetic data acquisition units, three-component magnetic field sensors and non-polarized electrode pairs (electric field sensors) which are distributed according to pre-designed measuring lines and measuring points. The three-component magnetic field sensor is one of an induction coil type magnetic field sensor, a fluxgate type magnetic field sensor, an MEMS (micro-electromechanical systems) magnetic field sensor, a superconducting magnetic field sensor and an optical fiber magnetic field sensor; the electric field sensor is one of copper sulfate, silver chloride, nano materials, tantalum capacitance non-polarized electrode pairs and an optical fiber electric field sensor; the ground electromagnetic data acquisition device 4 is connected with the seismic electromagnetic composite data acquisition control instrument and the laser modulation and demodulation instrument 7;
the borehole seismic electromagnetic composite signal receiving and collecting short circuits 5 are multiple and distributed in an array mode in the borehole.
The borehole seismic electromagnetic composite signal receiving and acquiring short circuit 5 is a four-component seismic and six-component electromagnetic signal receiving and acquiring short circuit 5, a plurality of short circuits are distributed in a borehole in an array manner, and the borehole seismic electromagnetic composite signal receiving and acquiring short circuit 5 is provided with a three-component moving coil type detector or a piezoelectric type detector or an acceleration type detector or an MEMS detector or an optical fiber detector, a piezoelectric or optical fiber hydrophone, a three-component induction coil type magnetic field sensor or a flux gate type magnetic field sensor or an MEMS magnetic field sensor or a superconducting magnetic field sensor or an optical fiber magnetic field sensor, a three-component copper sulfate or silver chloride or nano material or tantalum capacitance unpolarized electrode pair or a three-component optical fiber electric field sensor, a three-component electronic or optical fiber attitude sensor and an electronic or optical fiber inertial navigation gyroscope.
The method for predicting the oil and gas reserves of the underground reservoir by using the seismic electromagnetic composite data acquisition system comprises the following steps, as shown in figure 5:
(a) the ground seismic data acquisition device 3, the ground electromagnetic data acquisition device 4 and the borehole seismic electromagnetic composite signal receiving acquisition short circuit 5 are arranged on the ground or on the ground and in a well according to the pre-design, the ground artificial seismic source 1 and the ground controllable electromagnetic source 2 are excited on the ground, and the three-dimensional seismic and three-dimensional electromagnetic data in the ground or on the ground and in the well are synchronously acquired;
(b) carrying out amplitude preservation processing on ground three-dimensional seismic data or well-drive amplitude preservation processing on well-ground combined acquisition three-dimensional seismic data to finish anisotropic migration, reverse time depth migration and Q migration;
(c) comprehensively interpreting the results of amplitude preservation processing and deviation of ground three-dimensional seismic data or well-ground combined mining three-dimensional seismic data to obtain the buried depth, thickness, total volume and underground three-dimensional distribution of the oil-gas reservoir;
(d) performing attribute inversion on the ground three-dimensional seismic data subjected to amplitude preservation processing in the step (b) to obtain a wave impedance three-dimensional distribution value of the oil-gas reservoir;
(e) preprocessing and processing the three-dimensional electromagnetic data acquired on the ground or on the ground and in the well, and constraining inversion of the three-dimensional electromagnetic data acquired on the ground or on the ground and in the well by utilizing the burial depth and the thickness of the hydrocarbon-bearing reservoir obtained in the step (c) and the underground three-dimensional space distribution to obtain a three-dimensional resistivity distribution value of the hydrocarbon-bearing reservoir;
(f) measuring the physical parameters of rocks in a laboratory on the rock core of the oil-gas reservoir to obtain the porosity and wave impedance of the rock core of the oil-gas reservoir and the resistivity of the rock core under different oil-gas saturation conditions;
(g) figure 6a shows a partial log (density/porosity, gas saturation, longitudinal wave impedance, shale content) through a hydrocarbon reservoir to calibrate the porosity of the hydrocarbon reservoir at the drilling location based on the wave impedance of the sonic log and the wave impedance of the core of the hydrocarbon reservoir obtained in step (f) by processing the sonic log of the hydrocarbon reservoir. Then, by means of the distribution rule of the data on the intersection graph of the longitudinal wave impedance curve and the porosity, searching the curve of the distribution rule of the data on the intersection graph which is best fitted in the early stage and a mathematical expression thereof, and obtaining a relational expression of the longitudinal wave impedance and the porosity of the hydrocarbon-containing reservoir, as shown by a fitted solid straight line (linear relational expression) in fig. 6 b;
(h) FIG. 7a shows a partial log (gas saturation, resistivity) through a hydrocarbon reservoir to calibrate the hydrocarbon saturation of the hydrocarbon reservoir at the drilling location based on the resistivity of the electromagnetic log and the resistivity of the core of the hydrocarbon reservoir obtained in step (f) at different hydrocarbon saturations by processing the electromagnetic log of the hydrocarbon reservoir. Then, by means of the distribution rule of the data on the intersection graph of the resistivity curve and the oil and gas saturation, searching the curve of the data distribution rule on the intersection graph which is best fitted in the early stage and the mathematical expression thereof, and obtaining the relational expression of the resistivity of the oil and gas reservoir and the oil and gas saturation, as shown by the fitted solid curve (nonlinear relational expression, such as exponential relational expression or hyperbolic relational expression) of FIG. 7 b;
(i) calculating the total porosity and the distribution characteristics of the reservoir according to the porosity of the oil-gas reservoir calibrated in the step (g) at the drilling position, the obtained relational expression of the longitudinal wave impedance and the porosity of the oil-gas reservoir and the wave impedance three-dimensional distribution value of the oil-gas reservoir inverted in the step (d);
(j) calculating the total hydrocarbon saturation and the distribution characteristics of the reservoir according to the hydrocarbon saturation of the hydrocarbon reservoir at the drilling position calibrated in the step (h), the obtained relational expression between the resistivity of the hydrocarbon reservoir and the hydrocarbon saturation and the resistivity three-dimensional distribution value of the hydrocarbon reservoir inverted in the step (e);
(k) (ii) calculating the total fluid volume of the hydrocarbon reservoir and its distribution in three dimensions from the total volume of the hydrocarbon reservoir obtained in step (c) and the calculated total porosity of the reservoir and its distribution in step (i);
(l) And (c) calculating the total oil and gas saturation and the distribution thereof of the reservoir stratum calculated in the step (j) and the total fluid volume of the hydrocarbon-bearing reservoir stratum calculated in the step (k) and the distribution thereof in the three-dimensional space, so as to calculate the total oil and gas volume or weight (reserve) in the hydrocarbon-bearing reservoir stratum and the distribution thereof in the three-dimensional space, thereby realizing accurate and reliable evaluation and prediction of the total oil and gas reserve of the hydrocarbon-bearing reservoir stratum.
It will be appreciated by those of ordinary skill in the art that the embodiments described herein are intended to assist the reader in understanding the principles of the invention and are to be construed as being without limitation to such specifically recited embodiments and examples. Various modifications and alterations to this invention will become apparent to those skilled in the art. Any modification, equivalent replacement, or improvement made within the spirit and principle of the present invention should be included in the scope of the claims of the present invention.
Claims (2)
1. A seismic electromagnetic composite data acquisition system, comprising: the earthquake monitoring system comprises artificial earthquake sources (1) distributed in a three-dimensional manner on the ground, controllable electromagnetic sources (2) on the ground, earthquake data acquisition devices (3) distributed in a three-dimensional manner on the ground, electromagnetic data acquisition devices (4) distributed in a three-dimensional manner on the ground, and a well earthquake electromagnetic composite signal receiving and acquiring short circuit (5);
the underground seismic electromagnetic composite signal receiving and acquiring short circuit (5) is connected with a ground seismic electromagnetic composite data acquisition control instrument and a laser modulation and demodulation instrument (7) in a work area or near a wellhead through an armored photoelectric composite cable (6), and the armored photoelectric composite cable (6) controls the depth position of the underground seismic electromagnetic composite signal receiving and acquiring short circuit (5) in a well;
the artificial seismic sources (1) are seismic sources excited on the ground according to pre-designed seismic source lines and seismic source points, the seismic sources are uniformly or non-uniformly distributed, and the seismic sources are heavy hammer seismic sources, explosive seismic sources, air gun seismic sources, electric spark seismic sources or controllable seismic sources;
the ground controllable electromagnetic source (2) comprises a high-power dipole current source or a large loop electromagnetic source which is distributed on the ground according to a pre-design;
the ground three-dimensional distributed seismic data acquisition device (3) comprises a wired or wireless node type seismic data acquisition unit and a ground detector which are distributed according to a pre-designed measuring line and measuring point, wherein the ground detector is one of a single-component or three-component moving coil type detector, a piezoelectric type detector, an acceleration type detector, an MEMS detector and an optical fiber detector; the ground seismic data acquisition device (3) is connected with a seismic electromagnetic composite data acquisition control instrument and a laser modulation and demodulation instrument (7);
the electromagnetic data acquisition devices (4) distributed in three dimensions on the ground comprise wired or wireless node type electromagnetic data acquisition units, three-component magnetic field sensors and electric field sensors which are distributed according to pre-designed measuring lines and measuring points; the three-component magnetic field sensor is one of an induction coil type magnetic field sensor, a fluxgate type magnetic field sensor, an MEMS (micro-electromechanical systems) magnetic field sensor, a superconducting magnetic field sensor and an optical fiber magnetic field sensor; the electric field sensor is one of copper sulfate, silver chloride, nano materials, tantalum capacitance non-polarized electrode pairs and an optical fiber electric field sensor; the ground electromagnetic data acquisition device (4) is connected with the seismic electromagnetic composite data acquisition control instrument and the laser modulation and demodulation instrument (7);
the borehole seismic electromagnetic composite signal receiving and collecting short circuits (5) are multiple and distributed in an array mode in the borehole.
2. A method for predicting hydrocarbon reserves in underground reservoirs, wherein the seismic electromagnetic complex data acquisition system of claim 1 is used, comprising the steps of:
(a) the ground seismic data acquisition device (3), the ground electromagnetic data acquisition device (4) and the borehole seismic electromagnetic composite signal receiving acquisition short circuit (5) are arranged on the ground or on the ground and in the borehole according to the pre-design, a ground artificial seismic source (1) and a ground controllable electromagnetic source (2) are excited on the ground, and three-dimensional seismic and three-dimensional electromagnetic data in the ground or on the ground and in the borehole are synchronously acquired;
(b) carrying out amplitude preservation processing on ground three-dimensional seismic data or well-drive amplitude preservation processing on well-ground combined acquisition three-dimensional seismic data to finish anisotropic migration, reverse time depth migration and Q migration;
(c) comprehensively interpreting results of amplitude preservation processing and deviation of ground three-dimensional seismic data or well-ground combined mining three-dimensional seismic data to obtain the burial depth and thickness of the oil-gas reservoir and the underground three-dimensional distribution and total volume;
(d) obtaining a wave impedance three-dimensional distribution value of the oil-gas reservoir by performing attribute inversion on the amplitude-preserved three-dimensional seismic data;
(e) preprocessing and processing the three-dimensional electromagnetic data acquired on the ground or on the ground and in the well, and constraining inversion of the three-dimensional electromagnetic data acquired on the ground or on the ground and in the well by utilizing the burial depth and the thickness of the hydrocarbon-containing reservoir obtained in the step (c) and the underground three-dimensional space distribution to obtain a three-dimensional resistivity distribution value in the hydrocarbon-containing reservoir;
(f) measuring the physical parameters of rocks in a laboratory on the rock core of the oil-gas reservoir to obtain the porosity and wave impedance of the rock core of the oil-gas reservoir and the resistivity of the rock core under different oil-gas saturation conditions;
(g) processing the sonic logging data of the hydrocarbon-bearing reservoir, and calibrating the porosity of the hydrocarbon-bearing reservoir at the drilling location using the wave impedance of the sonic logging data and the porosity and wave impedance of the hydrocarbon-bearing reservoir core obtained in step (f); searching a curve of the data distribution rule on the cross plot and a mathematical expression thereof by the distribution rule of the data on the cross plot of the longitudinal wave impedance curve and the porosity to obtain a linear relation between the longitudinal wave impedance and the porosity of the hydrocarbon-bearing reservoir;
(h) processing electromagnetic logging data of the hydrocarbon-bearing reservoir, and calibrating the hydrocarbon saturation of the hydrocarbon-bearing reservoir at the drilling position by using the resistivity of the electromagnetic logging data and the resistivity of the core of the hydrocarbon-bearing reservoir obtained in the step (f) under different hydrocarbon saturation conditions; searching a curve of the data distribution rule on the cross plot and a mathematical expression thereof according to the distribution rule of the data on the resistivity curve and the oil and gas saturation cross plot, and obtaining a nonlinear relation between the resistivity of the oil and gas reservoir and the oil and gas saturation;
(i) calculating the total porosity and the distribution of the reservoir according to the porosity of the oil-gas reservoir at the drilling position calibrated in the step (g), the obtained relational expression of the longitudinal wave impedance and the porosity of the oil-gas reservoir and the wave impedance three-dimensional distribution value of the inverted oil-gas reservoir in the step (d);
(j) calculating the total hydrocarbon saturation and the distribution thereof of the reservoir according to the hydrocarbon saturation of the hydrocarbon reservoir at the drilling position calibrated in the step (h), the obtained relational expression between the resistivity of the hydrocarbon reservoir and the hydrocarbon saturation and the resistivity three-dimensional distribution value of the hydrocarbon reservoir inverted in the step (e);
(k) calculating the total fluid volume of the hydrocarbon reservoir and the distribution rule of the total fluid volume in the three-dimensional space according to the volume of the hydrocarbon reservoir obtained in the step (c) and the total porosity and the distribution of the reservoir calculated in the step (i);
(l) And (c) calculating the total oil and gas saturation and distribution of the reservoir calculated in the step (j) and the total fluid volume of the hydrocarbon-bearing reservoir calculated in the step (k) and the distribution of the total fluid volume of the hydrocarbon-bearing reservoir calculated in the step (k) on a three-dimensional space to calculate the total oil and gas volume or weight, namely the reserve and the distribution of the total oil and gas volume in the hydrocarbon-bearing reservoir on the three-dimensional space, thereby realizing the total oil and gas reserve prediction of the hydrocarbon-bearing reservoir.
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| CN112031743A (en) * | 2020-09-28 | 2020-12-04 | 中油奥博(成都)科技有限公司 | Underground fluid identification device and measurement method based on distributed optical fiber sensing technology |
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