WO2007071196A1 - Procede d'exploration directe de gisements de petrole, de gaz naturel et de gaz de houille - Google Patents

Procede d'exploration directe de gisements de petrole, de gaz naturel et de gaz de houille Download PDF

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WO2007071196A1
WO2007071196A1 PCT/CN2006/003529 CN2006003529W WO2007071196A1 WO 2007071196 A1 WO2007071196 A1 WO 2007071196A1 CN 2006003529 W CN2006003529 W CN 2006003529W WO 2007071196 A1 WO2007071196 A1 WO 2007071196A1
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reflectance
oil
gas
saturated
seismic
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PCT/CN2006/003529
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Chinese (zh)
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Xinping Chen
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Xinping Chen
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
    • G01V1/30—Analysis

Definitions

  • the invention relates to a method for directly detecting oil, natural gas and coalbed methane. Specifically, the present invention relates to a method for determining the reflectance of elastic modulus of a subterranean formation, and using these reflectivity as a basic parameter to constitute a direct hydrocarbon detection factor A method of directly detecting oil, natural gas and coalbed methane, especially a method of directly detecting oil.
  • Oil and gas exploration has undergone a process from structural exploration to lithology exploration to direct exploration of oil and gas.
  • Early oil and gas exploration uses seismic data to determine the structural form of the subterranean formation. The main purpose is to determine the location of the well based on the law that the density of oil and natural gas is less than that of water and thus accumulate in the high part of the structure. This is called the tectonic exploration stage.
  • people Since the 1960s, people have used information such as seismic wave velocity and density extracted from seismic data and logging data to determine the properties and characteristics of underground rocks, for example, distinguishing sandstone, shale, predicting porosity, etc., based on lithology.
  • the feature of judging the hydrocarbon-bearing potential of a structural trap is called the lithology exploration stage.
  • a method for directly detecting underground petroleum, natural gas and coalbed methane first determines the Lame constant reflectance ⁇ /( ⁇ +2 ⁇ ), the shear modulus reflectivity ⁇ /( ⁇ +2 ⁇ ) or ⁇ /[ ⁇ + (4/3) ⁇ ], Volume Compression Modulus Reflectance ⁇ / [ ⁇ + (4/3) ⁇ ], Lame Constant Reflectance and Shear Modulus Reflectance [ ( ⁇ - ⁇ ) / ( ⁇ +2 ⁇ )], the sum of the Lame constant reflectance and the shear modulus reflectivity [ ( ⁇ + ⁇ ) / ( ⁇ + 2 ⁇ ) ], as a direct hydrocarbon detection factor; and using the determined direct hydrocarbon detection factor Detection of underground oil, natural gas and coalbed methane;
  • the method for determining the direct hydrocarbon detection factor consists of the following steps:
  • Paste II + M - 2sin 2 ⁇ +- 2(2 + ⁇ ) ⁇ + 2 2 + ⁇
  • step (b) of collecting multiple times of the common center point seismic gather data includes the requirement that the maximum incident angle of the seismic wave at the reflective interface of the subterranean formation as the exploration target is reached and only needs to reach a range of 20° to 25°.
  • step (c) of preprocessing the seismic data prohibits the use of processing techniques that change the true amplitude energy relationship, and includes amplitude recovery, surface consistency correction, deconvolution, noise cancellation, static correction, motion correction, and residual Static correction, pre-stack offset.
  • the foregoing method of use wherein the characteristic of determining the modulus of elasticity and the reflectivity of the elastic modulus and the step (k) of determining the threshold value are characterized by including the longitudinal wave velocity, the shear wave velocity, and the density determined by the logging data, and each of the calculations is obtained. Flexibility The log curve of the modulus is determined according to the characteristics of the elastic modulus reflectivity of the target layer under water saturation, oil saturation and gas saturation, and the water saturation layer, the oil saturated reservoir and/or the gas saturated reservoir are determined. The threshold of the layer.
  • step (1) of drawing a direct hydrocarbon detection factor map is performed, for the sectional view, the horizontal coordinates and the diurnal composition are plotted, or the horizontal distance and the depth are used to form the drawing coordinates;
  • Figure, the horizontal and horizontal distances constitute the drawing coordinates; for the spatial perspective, the drawing coordinates are selected as two horizontal axes are horizontal distance, and the vertical axis is time or depth.
  • the present invention alters the method of using information on the amplitude of seismic data as a function of offset in current oil and gas exploration.
  • the invention provides a new approximate relationship between the seismic longitudinal wave reflection coefficient and the reflectance of the Lame constant of the underground rock layer and the reflectivity of the shear modulus, and provides a new method for obtaining the reflectance of the Lame constant and the reflectivity of the shear modulus of the underground rock layer. method.
  • the present invention can comprehensively use the difference between the reflectance of the Lame constant and the reflectance of the shear modulus [( ⁇ - ⁇ ) / ( ⁇ + 2 ⁇ )], the sum of the reflectance of the Lame constant and the reflectance of the shear modulus [ ( ⁇ ) + ⁇ )/( ⁇ +2 ⁇ ) ], Lame constant reflectance ⁇ /( ⁇ +2 ⁇ ), shear modulus reflectance ⁇ /( ⁇ +2 ⁇ ) or ⁇ /[ ⁇ + (4/3) ⁇ ]
  • the volumetric compressive modulus reflectivity ⁇ /[ ⁇ + (4/3) ⁇ ] predicts that the energy of the oil and gas reservoir can clearly distinguish between water-saturated sandstone, oil-saturated sandstone and gas-saturated sandstone.
  • the method of the invention has strong anti-interference ability, and can ensure the global optimal solution when inverting the Lame constant reflectance, the shear modulus reflectivity, and the volume compression modulus reflectivity.
  • the method for obtaining the reflectance of the elastic modulus provided by the present invention requires that the maximum incident angle of the seismic wave on the reflecting surface of the subterranean formation as the target of exploration reaches and only needs to reach a range of 20° to 25°.
  • the method of the invention reduces the requirement of the maximum incident angle, can save the cost of collecting and processing seismic resources, and reduces the influence of the approximation error.
  • the method provided by the present invention can be implemented only by preparing an appropriate computer program, using existing seismic data or using existing seismic data acquisition technology, and using existing seismic data processing software, so that it is particularly easy to implement.
  • Figure 1 is a plot of the Lame constant of a reservoir rock as a function of pore fluid properties
  • Figure 2 is a graph showing the relative variation of the Lame constant of the reservoir rock as a function of the pore fluid properties
  • Figure 3 is a schematic diagram showing the generation of a reflected longitudinal wave, a reflected transverse wave, a transmitted longitudinal wave, and a transmitted transverse wave when a planar longitudinal wave is incident on a horizontal elastic interface;
  • Figure 4 is the curve of the intercept term coefficient and the gradient term coefficient with the incident angle 9 in the Shuey approximation and the reflection coefficient of the reflection interface between the shale and the low-impedance gas-saturated sandstone under the Aki- Richards approximation.
  • Figure 5 is a graph showing the variation of the Lame constant reflectance term coefficient and the shear modulus reflectance term coefficient with the incident angle ⁇ in the first approximation of the present invention
  • Figure 6 is a graph showing the reflection coefficient of the reflection interface between the shale and the low-impedance gas-saturated sandstone calculated by the first approximation of the present invention, that is, the equation (16) and the accurate Zeoppritz equation, as a function of the incident angle ;
  • Figure 7 shows five sets of logging curves. From (a) to (e) are three oil-saturated sandstone reservoirs with crude oil specific gravity index APIs equal to 30, 60, and 90, and natural gas saturated sandstone reservoirs.
  • Well curve; each group of three curves, from left to right, is a schematic diagram of density, longitudinal wave velocity, and shear wave velocity;
  • Figure 8 is a set of five common-center synthetic seismic traces calculated according to the five sets of log data in Figure 7, respectively representing the arrangement of seismic observation systems on the ground according to the steps of the present invention, and water-saturated sandstone and crude oil when collecting seismic data.
  • Figure 9 is a cross-sectional view of predicted oil and gas obtained using the Lame constant reflectance ⁇ ⁇ /( ⁇ +2 ⁇ ) as a direct hydrocarbon detection factor according to the seismic data of Figure 8;
  • Figure 10 is a cross-sectional view showing the predicted rock properties obtained by using the shear modulus reflectance ⁇ / ( ⁇ + 2 ⁇ ) as a direct hydrocarbon detecting factor according to the seismic data of Figure 8;
  • Figure 11 is a prediction of oil and gas obtained from the seismic data of Figure 8 using the sum of the Lame constant reflectance and the shear modulus reflectance [( ⁇ ⁇ + ⁇ ) / ( ⁇ + 2 ⁇ )] as a direct hydrocarbon detection factor. a comprehensive inspection profile of natural gas;
  • Figure 12 is a seismic trace set obtained after the random noise is added to the common center point synthesis seismic trace of Fig. 8 so that the signal-to-noise ratio of the seismic data is equal to 0.3;
  • Figure 13 is a cross-sectional view of predicted oil and gas obtained from the seismic data of Figure 12 using a Lame constant reflectance ⁇ ⁇ /( ⁇ + 2 ⁇ ) as a direct hydrocarbon detection factor;
  • Figure 14 is a cross-sectional view showing the predicted rock properties obtained from the direct hydrocarbon detection using the shear modulus reflectance ⁇ /( ⁇ +2 ⁇ ) according to the seismic data of Fig. 12;
  • Figure 15 is a prediction of oil and gas obtained from the direct hydrocarbon detection factor using the sum of the Lame constant reflectance and the shear modulus reflectance [( ⁇ ⁇ + ⁇ ) / ( ⁇ + 2 ⁇ )] according to the seismic data of Figure 12.
  • the direct hydrocarbon detection factor provided by the present invention is a Lame constant reflectance ⁇ /( ⁇ +2 ⁇ ), a shear modulus reflectance ⁇ /( ⁇ +2 ⁇ ), and ⁇ /[ ⁇ + (4/3) ⁇ ], The difference between the volumetric compressive modulus reflectance ⁇ /[ ⁇ + (4/3) ⁇ ], the Lame constant reflectance and the shear modulus reflectance [ ( ⁇ - ⁇ ) / ( ⁇ +2 ⁇ ) ], the Lame constant The sum of reflectance and shear modulus reflectivity [ ( ⁇ + ⁇ ) / ( ⁇ + 2 ⁇ ) ] ⁇
  • ⁇ is the shear modulus of the water-saturated rock
  • ⁇ is the shear modulus of the rock skeleton, ie the shear modulus of the gas-saturated rock,
  • ⁇ is the Lame constant of a water-saturated rock.
  • ⁇ . is the Lame constant of the rock skeleton, that is, the Lame constant of the gas-saturated rock.
  • ⁇ is the volumetric compressive modulus of water-saturated rocks
  • Ks is the volumetric compressive modulus of the minerals that make up the rock skeleton.
  • Kr is the volumetric compressive modulus of the fluid filled in the pores of the rock.
  • ⁇ is the porosity of the rock.
  • Equation (1) shows that the shear modulus ⁇ of the rock does not change when the pore fluid properties of the rock change.
  • the shear modulus ⁇ is a parameter that is only related to the properties of the rock. Therefore, the shear modulus ⁇ is a hydrocarbon detection factor that indicates the change in rock properties.
  • the cap layer and the reservoir can be distinguished because the shear modulus of the rock, such as mudstone, shale, gypsum, etc., as the caprock, and sandstone, limestone, dolomite, etc. as reservoirs There is a significant difference in the shear modulus of the rock.
  • the formation of the shear modulus ⁇ in the bedding layer can be used to distinguish the reservoir characteristics, for example, the porosity, etc., because when the porosity increases, the rock stiffness decreases and the shear modulus decreases.
  • the present invention uses the shear modulus reflectance ⁇ /( ⁇ +2 ⁇ ) as a direct hydrocarbon detection factor, which visually shows the change in shear modulus in the vertical and horizontal directions.
  • Equation (2) shows that for the same rock sample, the Lame constant ⁇ is a parameter that is only related to the pore fluid properties of the rock, and that when the pore fluid properties of the rock change, the Lame constant ⁇ is compressed with the volume of the pore fluid of the rock.
  • the modulus decreases and monotonically decreases.
  • the numerator of the second term at the right end of equation (2) is the square of the real number, the numerator is always a positive number. 5, and, as the rock incompressibility increases with the porosity of the rock, the rock porosity ⁇ is always less than 0.5, and the measurement results of various rock-forming minerals and various rocks are always less than 0.5.
  • the Lame constant ⁇ monotonically decreases, and the Lame constant ⁇ also monotonically decreases.
  • the change in the Lame constant ⁇ is purely due to changes in pore fluid properties, and the pore fluid properties change only. It only causes a change in the Lame constant ⁇ .
  • the present invention uses the Lame constant reflectance ⁇ /( ⁇ +2 ⁇ ) as a direct hydrocarbon detection factor, which visually shows the variation of the Lame constant in the vertical and horizontal directions.
  • the change of ⁇ may include the change of ⁇ , and the factors affecting the change of ⁇ are not single, but double, namely ⁇ and ⁇ .
  • the predictive power of the volumetric compressive modulus ⁇ is affected by complex factors, and all factors affecting ⁇ and ⁇ are inevitable! ⁇ . This increases the difficulty of using ⁇ to predict oil and gas reservoirs.
  • the present invention has a volume compressive modulus reflectance ⁇ /[ ⁇ +(4/3) ⁇ ] as one of the direct hydrocarbon detecting factors, the present invention considers that for a particular exploration area, only in the case of logging When the data proves that ⁇ /[ ⁇ 4/3) ⁇ ] has a prediction ability superior to ⁇ ⁇ /( ⁇ +2 ⁇ ), ⁇ /[ ⁇ + (4/3) ⁇ ] should be used for prediction.
  • the patented method of the present invention provides a difference between [lambda] constant reflectance and shear modulus reflectance [( ⁇ - ⁇ ) / ( ⁇ + 2 ⁇ )] as a hydrocarbon detecting factor.
  • the basis and method for using the hydrocarbon detection factor are as follows: In the oil and gas exploration, the hydrocarbon detection factor is used to predict the oil and gas reservoir, not only the elasticity difference of the reservoir rock in water saturation, oil saturation, natural gas saturation, but also the storage must be considered. The difference in elasticity between layer rock and surrounding rock. Even in the absence of oil and gas, the shear modulus of sandstone, limestone, dolomite, etc. as reservoirs is usually greater than the shear modulus of mudstones, shale, etc.
  • the plum constant is usually less than the Lame constant of the cap rock.
  • the Lame constant of the reservoir rock will be significantly reduced compared with the water saturation, which is consistent with the prediction of the Gassmann equation (2); meanwhile, the shear modulus of the reservoir rock It is likely to increase, which is inconsistent with the prediction of the Gassmann equation (1), because the structure of the rock in oil and gas exploration is not completely consistent with the assumptions underlying the Gassmann equation.
  • One of the assumptions of the Gassmann equation is that the rock is composed of a single mineral. In fact, reservoir rocks are usually composed of a variety of minerals.
  • the shear modulus of oil-saturated and gas-saturated reservoir rocks is usually greater than the shear modulus of water-saturated reservoir rocks.
  • the difference between the Lame constant reflectance and the shear modulus reflectance ( ⁇ - ⁇ ) /( ⁇ +2 ⁇ ) is taken as the hydrocarbon detection factor, and the Lame constant reflectance and the shear modulus reflectance are used to predict the oil and The ability of natural gas can highlight the anomalies caused by the occurrence of oil and natural gas.
  • Table 1 shows the elastic characteristics of three types of sandstone reservoirs, such as low impedance, near zero impedance, and high impedance. It can be seen from the table that although the Lame constant reflectance ⁇ /( ⁇ +2 ⁇ ) and the shear modulus reflectance ⁇ /( ⁇ +2 ⁇ ) have the ability to predict oil and gas reservoirs, the Lame constant reflectance and shear modulus The difference in reflectance ( ⁇ - ⁇ ) / ( ⁇ + 2 ⁇ ) enhances reservoir anomalies. In particular, for high impedance and near-zero impedance reservoirs, the difference between the Lame constant reflectance and the shear modulus reflectance is more pronounced in highlighting the reservoir anomaly, and the abnormal intensity is increased by 0.4 to 1.4 times.
  • the patented method of the present invention also provides the sum of the Lame constant reflectance and the shear modulus reflectance [( ⁇ + ⁇ ) / ( ⁇ + 2 ⁇ ) ] as a hydrocarbon detecting factor.
  • the basis and method for using the hydrocarbon detection factor are as follows: Although the Lame constant of the oil and gas reservoir is generally smaller than the Lame constant of the surrounding rock, the shear modulus of the reservoir is greater than the shear modulus of the surrounding rock, but It is also possible that the shear modulus of the reservoir is less than the shear modulus of the surrounding rock. In addition, in coalbed methane exploration, the coal seam as a reservoir of coalbed methane, its Lame constant and shear modulus are smaller than the Lame constant and shear modulus of the surrounding rock.
  • Lame constant reflectance and the shear modulus reflectance of the reservoir and the surrounding rock are the same.
  • the sum of the Lame constant reflectance and the shear modulus reflectance ( ⁇ + ⁇ ) / ( ⁇ + 2 ⁇ ) should be used as the hydrocarbon detection factor.
  • the direct hydrocarbon detection factor provided by the present invention has the ability to predict petroleum reservoirs.
  • the pressure and temperature of the formation increase with increasing depth.
  • the elastic characteristics such as density, volume compression modulus and velocity of crude oil are different from those under normal temperature and pressure.
  • Batzle and Wang see Batzle, M., and Wang, ⁇ , 1992, Seismic properties of fluids: Geophysics. 57, 1396-1408.
  • crude oils with different specific gravity indices can be calculated at underground temperature and pressure. Density and volume compression modulus under conditions.
  • Figure 1 shows the results calculated using the above calculation scheme.
  • the pore fluid water
  • the crude oil with a specific gravity index of 10 ⁇ 90 and the specific gravity index is 10
  • the relative density of natural gas is equal to 0. 6.
  • the ratio of gas to oil of various live oils is equal to one tenth of its maximum gas-oil ratio.
  • Figure 1 also shows the Lame constant of the sandstone when the reservoir sandstone pores are saturated with dead oil under subsurface temperature and pressure conditions and at a normal temperature of 1 at 6 °C at atmospheric pressure.
  • Figure 1 shows that (1) When the pores of the reservoir rock are saturated by crude oil, the Lame constant of the rock is lower than that of the water-saturated rock, and the specific gravity index of the crude oil has a significant effect on the degree of reduction of the Lame constant.
  • the Lame constant As the crude oil specific gravity index increases, it decreases monotonically and linearly.
  • Figure 2 shows the change in the relative variation of the sandstone constants with the properties of the pore fluid.
  • the lithology parameters and pore fluid parameters used in plotting Figure 2 are the same as those used to plot Figure 1.
  • the relative variation of the Lame constant is calculated as: oil saturation
  • the difference between the Lame constant of the rock and the Lame constant of the water-saturated rock is divided by the average of the Lame constant of the water-saturated rock and the Lame constant of the oil-saturated rock, expressed as a percentage.
  • Figure 2 shows that when the specific gravity index of crude oil is greater than 25, whether the crude oil dissolves natural gas, that is, whether it is live oil or dead oil, the Lame constant of oil-saturated sandstone is reduced by 10% relative to the Lame constant of water-saturated sandstone. the above.
  • the detectable elastic difference threshold is set to 10%, then oil-saturated sandstone and water-saturated sandstone with a specific gravity index greater than 25 can be distinguished according to the relative variation of the Lame constant.
  • the crude oil in most of the world's oil fields has a specific gravity index greater than 25, and only a few oil fields have a specific gravity index of less than 25. Therefore, it is possible to predict most petroleum reservoirs by using the Lame constant.
  • the crude oil in the underground state is regarded as the live oil in which a small amount of natural gas is dissolved.
  • the gas-oil ratio of the crude oil is equal to 10% of the maximum gas-oil ratio
  • the volumetric compressive modulus of the crude oil, the oil-saturated rock and the water-saturated rock are calculated.
  • the relative variation of the Lame constant, the Lame constant reflectivity of the reservoir and the surrounding rock reflection interface, and the like are suitable.
  • v PlJ V sl , Pl are the longitudinal wave velocity, shear wave velocity and density of the overlying medium 1 on the interface;
  • V P2 , V s2 , p 2 are the longitudinal wave velocity, shear wave velocity, and density of the dielectric medium 2 at the interface;
  • V, Vs, p are the average longitudinal velocity, transverse wave average velocity, and average density of the media on both sides of the interface; ⁇ ,, ⁇ , are the longitudinal wave incident angle and the refraction angle, respectively, and ⁇ is the average of the incident angle and the refraction angle.
  • the Gardner relationship in petrophysics expresses the empirical relationship between rock longitudinal velocity and density and is widely recognized and used in oil and gas exploration (see Gardner, G. H. F., Gardner, L. W., and Gregory, A. R.,
  • the formula (16) is referred to as the first approximation of the present invention, and the first term of the formula is referred to as "the Lame constant reflectance term”, and the second term of the formula is referred to as the "shear modulus reflectance term”.
  • the seismic data of the common center point collected by the multiple times are collected, and the seismic data is appropriately preprocessed, and an appropriate method is selected to calculate the average value of the incident angle and the reflection angle of the reflected signals of the sampling time of the common reflection point seismic trace set.
  • the method for obtaining the reflectance of the elastic modulus provided by the present invention requires that the maximum incident angle of the seismic wave on the reflecting surface of the subterranean formation as the target of exploration reaches and only needs to reach a range of 20° to 25°. Compared with the direct hydrocarbon detection technology currently used by the oil and gas exploration community, the method of the present invention reduces the requirement for the maximum incident angle, saves the cost of collecting and processing seismic data, and reduces the influence of the approximation error.
  • the direct hydrocarbon detection techniques and methods used in the current oil and gas exploration community require that the incident angle of the seismic wave be as large as possible, and the maximum incident angle of the reflecting surface of the exploration target should be at least 35°. This is due to the theory itself based on these technologies.
  • AVO Amplitude Versus Offset, that is, the amplitude varies with the offset
  • Shuey's Zeoppritz equations approximation (hereinafter referred to as the Shuey approximation) used by the AVO technique is:
  • Vp is the AVO gradient; the remaining parameters, V S P .
  • Figure 4 shows the variation of the intercept term coefficient and the gradient term coefficient with the incident angle S in the Slmey approximation.
  • the AVO intercept term coefficient is always equal to 1; and the gradient term coefficient varies with the incident angle ,.
  • ⁇ increases by 90° from 0°
  • AVO technology has to rely on large offset seismic data to obtain large angles of incidence.
  • the AVO gradient obtained by the AVO technique inversion is a "constant" that does not vary with the angle of incidence. In fact, the gradient of the amplitude of the seismic wave varies with the angle of incidence. In other words, the AVO technique obtains the gradient of the amplitude as a function of sin 2 ⁇ under the Shuey approximation, rather than the gradient of the amplitude as a function of the angle of incidence.
  • Figure 4 also shows a plot of the sandstone top interface reflection coefficient, ie the gradient of the amplitude as a function of the incident angle ⁇ , calculated using the low-impedance gas-saturated sandstone model parameters and the Aki- Richards approximation in Table 1.
  • AVO technology uses natural gas to predict the natural gas with a significant change in the offset.
  • the AVO gradient is actually the gradient of the amplitude at the large angle of incidence with the angle of incidence. Therefore, AVO technology has to be required.
  • the offset of the seismic data, ie the angle of incidence, is as large as possible.
  • Figure 5 shows the coefficient of the Lame constant reflectance term and the coefficient of the shear modulus reflectivity term in the equation (16) as a function of the incident angle. It can be seen from the figure that even if seismic data in the range of 0° ⁇ 10° is used for inversion, the ill-conditioned equations will not be formed due to the coefficients of the equation. Furthermore, the inversion of the elastic modulus of the present invention is a characteristic parameter of the formation reflection interface itself, which does not vary with the angle of incidence. Therefore, it is not required to use large offset seismic data.
  • the influence of noise and error is weighed, and the incident angle ⁇ corresponding to the point at which the Lame constant reflectance term coefficient is equal to the shear modulus reflectance term coefficient is used as the maximum incident angle for determining the inversion.
  • the maximum incident angle is required to be close but less than ®. Different values are obtained for the index ⁇ in different Gardner empirical relationships. According to the calculation, it is finally determined that the maximum incident angle should be reached and only needs to reach a range of 20° to 25°.
  • the method for determining the reflectance of the elastic modulus of the underground rock provided by the present invention consists of the following steps:
  • the sonic logging and density logging data are processed to obtain the longitudinal wave velocity V P and density p of the rock.
  • the well logging curve should be edited and the environmental correction of the logging curve should be done.
  • the seismic velocity is obtained, and the acoustic velocity obtained by logging is calibrated to eliminate the influence of frequency on velocity.
  • the logging data should meet the following requirements:
  • the logging response of the same lithologic layer in the same logging data of adjacent wells is basically the same, and the same lithologic layer changes in the same logging of different wells. It should reflect changes in lithology, physical properties, and pore fluid properties.
  • the best way to obtain the coefficient ⁇ and the exponent ⁇ is to use logging data, it is not limited to use logging data.
  • the longitudinal wave velocity and density of the rock obtained by any other method can be used instead of the corresponding log data to obtain the coefficient ⁇ and the exponent ⁇ in the empirical relationship.
  • the velocity obtained during velocity analysis in seismic data processing can be used instead of the acoustic logging velocity, and the density measured in the laboratory can be used instead of the logging density.
  • the maximum incident angle of the seismic wave on the reflecting surface of the subterranean formation as the exploration target is required to reach a range of 20° to 25°.
  • Preprocessing mainly includes: amplitude recovery, surface consistency correction, deconvolution, noise cancellation, static correction, motion correction, residual static correction, pre-stack migration. It is forbidden to use processing techniques that change the true amplitude energy relationship, such as inter-channel energy equalization techniques.
  • the present invention also provides a method of predicting a hydrocarbon reservoir using the subsurface rock elastic modulus reflectance determined by the above method, and in particular, a method for predicting the position of a petroleum reservoir, the prediction method comprising the steps of:
  • exploration areas with only natural gas it is only necessary to determine the difference in the water-saturated, gas-saturated state of the exploration target layer.
  • oil-only exploration areas it is only necessary to determine the difference in the water-saturated, oil-saturated state of the exploration target. If the exploration area has both oil and natural gas, or the exploration area is a new work area, possibly with both oil and natural gas, it is necessary to determine the difference between the exploration target layer in water saturation, oil saturation, and gas saturation.
  • the modulus of cut, the modulus of volume compression, and the log curve that constitutes each modulus of elasticity are determined.
  • the distance between the top plate and the bottom plate is the block thickness, and the top plate and the bottom plate are used as the starting point, and the elastic modulus logs are averaged upward and downward respectively to form an average log curve of each elastic modulus.
  • the block average logging curve of elastic modulus the positive and negative and the magnitude of the elastic modulus reflectivity of the top plate and the bottom plate of the exploration target layer under water saturation, oil saturation and gas saturation are determined, and the water saturated layer and oil are determined. Threshold for saturated reservoirs and/or gas-saturated reservoirs.
  • logging data is often lacking, either by using alternative data or by empirically converting to obtain the required information.
  • the superposition velocity obtained in seismic data processing is used to obtain the layer velocity, and then the re-sampling is used to obtain the logging velocity; in the absence of the density logging curve, the Gardner empirical relationship and the longitudinal wave velocity are used.
  • a scatter plot is plotted with the Lame constant reflectance ⁇ /( ⁇ +2 ⁇ ) as the horizontal coordinate axis and the shear modulus reflectance ⁇ /( ⁇ +2 ⁇ ) as the vertical coordinate axis. .
  • the difference between the reflectance of the Lame constant and the reflectance of the shear modulus [ ⁇ /( ⁇ +2 ⁇ ) - ⁇ /( ⁇ +2 ⁇ )] (hereinafter referred to as "difference factor"), the reflectance of the Lame constant, and Which hydrocarbon detection factor is selected for the sum of the shear modulus reflectances [( ⁇ + ⁇ ) /( ⁇ +2 ⁇ ) (hereinafter referred to as "and factor").
  • the selection principle is: According to the characteristics of the elastic modulus or the elastic modulus reflectivity of the exploration area determined above, if the Lame constant reflectance of the top layer and the bottom layer of the target layer are opposite to those of the shear modulus reflectance, respectively, the difference is selected.
  • Lame constant reflectance of the top and bottom plates of the target layer is the same as the shear modulus reflectance sign, respectively, the use factor is selected; if the Lame constant reflectance and the shear modulus reflectivity are in the top and bottom plates The sign, one opposite, and the other the same, should consider abandoning the use of the two hydrocarbon detection factors or the use of the top plate, the bottom plate reflective interface and the factor, difference factor; if the absolute value of one of the elastic modulus reflectance is very Small, you should consider abandoning the use of these two hydrocarbon detection factors.
  • the lithological changes and reservoir porosity changes are distinguished according to the shear modulus reflectance ⁇ /( ⁇ +2 ⁇ ).
  • the shear modulus represents the stiffness of the rock.
  • the method for determining the change of rock lithology according to the shear modulus reflectance ⁇ /( ⁇ +2 ⁇ ) is: Studying the change of shear modulus reflectance in the vertical direction, the positive value of shear modulus reflectivity is represented from mudstone, page Rocks such as rock and gypsum change to reservoir rocks such as sandstone and limestone, while the negative values of shear modulus reflect the opposite, representing changes from reservoir rocks such as sandstone to cap rocks such as mudstone, shale and gypsum.
  • the method for determining the change of porosity according to the shear modulus reflectance ⁇ /( ⁇ +2 ⁇ ) is: Studying the change of shear modulus reflectance in the direction of possible reservoir spread in the horizontal direction, shear modulus reflectivity
  • the relatively lower part is the part with a relatively large porosity. Attention should be paid to the opposite situation, that is, when the reservoir porosity is large, especially when the sandstone diagenesis is low, the shear modulus of the reservoir may also be lower than the shear modulus of the cap layer.
  • the change of reservoir porosity is determined by distinguishing the properties of the pore fluid according to the Lame constant reflectance ⁇ /( ⁇ +2 ⁇ ).
  • the rocky Lame constant is affected by pore fluid properties, porosity, and rock properties.
  • the effect of pore fluid on the rock's Lame constant is that the Lame constant of the same rock sample decreases in water saturation, oil saturation and gas saturation.
  • Porosity affects both the Lame constant of the rock skeleton and the Lame constant of the fluid-saturated rock. According to the results of laboratory rock measurements, as the porosity increases, the Lame constant of the rock skeleton decreases, and the Lame constant of the fluid-saturated rock also decreases. The effect of fluid properties and porosity on the Lame constant is additive.
  • the influence of rock properties on the Lame constant is opposite to the effect on shear modulus.
  • the Lame constants of mudstone, shale, gypsum, etc. are usually larger than the Lame constants of sandstone and limestone.
  • the method for predicting oil and gas reservoirs based on the Lame constant reflectance ⁇ /( ⁇ +2 ⁇ ) is: Study the change of the Lame constant reflectivity in the vertical direction, 'first First identify water-saturated sandstone, limestone and other rock formations, and determine the Lame constant threshold for distinguishing water-saturated reservoirs from petroleum reservoirs or natural gas reservoirs; then identify possible reservoirs in stratigraphic traps or lithologic traps,
  • the relatively low portion of the plum constant indicates the location where oil or natural gas is present; the change in the reflectance of the Lame constant is studied in the horizontal direction along the direction of reservoir distribution.
  • the low Lame constant indicates the porosity or petroleum and natural gas. The saturation is large and is a good reservoir.
  • the laws for the formation, migration, enrichment, and storage of coalbed methane are different from those of petroleum and natural gas. Therefore, the method of predicting the enrichment position of coalbed methane using the direct hydrocarbon detection factor provided by the present invention is also different from predicting oil or natural gas.
  • the coal seam is both a source rock that generates coalbed methane and a reservoir that stores coalbed methane.
  • the coalbed methane is distributed in the adsorption state to the surface of the joints, cracks and pores of the coal seam. Joints and fissures constitute the passage of coalbed methane migration and are one of the main controlling factors for coalbed methane enrichment and high yield.
  • the method for predicting the high-production position of coalbed methane by using the direct hydrocarbon detection factor provided by the present invention is as follows:
  • the position where the shear modulus has a low reflectance is a position where the joint density and the fracture density are large in the coal seam, and is the position where the coalbed methane is rich and high-yield. .
  • Figure 7 shows five sets of log curves, each set of three curves, namely density, longitudinal wave velocity, and shear wave velocity, where the unit of density is g/cm 3 and the unit of velocity is ys/ft or microseconds per foot.
  • the leftmost (a) set of curves is the measured log; the well confirmed, from 2533m to 2541m is a layer of sandstone, 100% water saturated, porosity 18%; sandstone cap and bottom are siliceous components and noodles Shale with more mineral components.
  • the set curve is a log of the corresponding density, longitudinal wave velocity, and shear wave velocity when the water in the pores of the sandstone is replaced by the fluid with a specific gravity index API equal to 30 using a fluid replacement technique;
  • the gas-to-oil ratio of petroleum is equal to one-tenth of its maximum gas-to-oil ratio, using the temperature and pressure of the sandstone in the underground state.
  • the method of obtaining the curves of groups (c) and (d) is the same as the method of obtaining the curves of group (b), but the specific gravity index APIs of the oils are 60 and 90, respectively.
  • the group curve is a log of the corresponding density, longitudinal wave velocity, and shear wave velocity when the water in the sandstone pores is replaced by the natural gas having a relative density equal to 0.6.
  • Figure 8 is a summary of five common-center synthetic seismic traces calculated from the five sets of well logs in Figure 7, which are water-saturated sandstones, three oil-saturated sandstones with APIs equal to 30, 60, and 90, respectively. Seismic response of sandstone.
  • the offset used in the calculation is 0m ⁇ 300 (k, the seismic track spacing is 100m; the seismic wavelet used is a zero-phase wavelet with a dominant frequency of 45Hz; assume that the structural features of the formation and the elastic characteristics of the rock meet the requirements of the Zeoppritz equation , use
  • the Zeoppritz equations calculate the reflection and transmission coefficients of various modes such as reflected longitudinal waves, transmitted longitudinal waves, reflected transverse waves, and transflective waves.
  • Figure 8 shows only the synthetic seismic record of the reflected longitudinal wave.
  • the red curve superimposed on the zero offset track of each common center point synthetic seismic trace set in Figure 8 is the longitudinal wave log used to calculate the synthetic seismic trace set.
  • the blue double line indicates the position of the sandstone top and bottom plates. .
  • the five common center point synthetic seismic traces of Figure 8 respectively contain information on water-saturated sandstones, three oil-saturated sandstones, and gas-saturated sandstones, which respectively correspond to the arrangement of seismic observation systems on the ground according to the steps of the present invention. When data are available, seismic responses of 7 saturated sandstones, three oil-saturated sandstone reservoirs, and natural gas saturated sandstone reservoirs.
  • Figure 9 is a cross-sectional view of predicted oil and gas obtained using the Lame constant reflectance ⁇ ⁇ /( ⁇ + 2 ⁇ ) as a direct hydrocarbon detection factor according to the seismic data of Figure 8.
  • the prediction results of each common center point gather are repeatedly displayed 10 times, and the CDP point numbers 1 to 10, 11 to 20, 21 to 30, 31 to 40, and 41 to 50 are respectively about water saturation.
  • Prediction of sandstone and crude oil specific gravity index API equal to 30, 60, 90 oil-saturated sandstone reservoirs and natural gas saturated sandstone reservoirs Results.
  • the black curve is the Lame constant reflectance; the different colors of the color base map represent different numerical ranges of the Lame constant inverse ratio, as shown by the color scale on the right side of the figure.
  • the left side of each set of CDP patterns is the Lame constant curve of the time domain calculated from the log curve, showing the change of the Lame constant over time, ie depth.
  • the value of the Lame constant in the range of 2493m ⁇ 2581m is segmented at intervals of 8m to average within the segment, so as to observe 2533H! ⁇ 2541m difference between the target layer and the surrounding rock constant.
  • Two orange parallel lines on the Lame constant curve indicate the location of the sandstone roof and floor.
  • the Lame constant curves in Figure 9 show that the Lame constants of the seven saturated sandstones, the three oil-saturated sandstones, and the gas-saturated sandstones are smaller than the Lame constants of the caprock and the bottom rocks, and from the water-saturated sandstone to the oil-saturated sandstone, To the gas-saturated sandstone, the Lame constant is successively reduced, which is in accordance with the theoretical calculation results of Figures 1 and 2.
  • Lame constant reflectivity between the various fluid-saturated sandstones and their cap rock is negative
  • the Lame constant reflectivity between the rock and the bottom rock is positive
  • from water-saturated sandstone to oil-saturated sandstone Then to the gas-saturated sandstone, the absolute value of the Lame constant reflectance increases successively.
  • Figure 9 shows that the Lame constant reflectance obtained by the method of the present invention is completely consistent with the variation of the Lame constant calculated according to the logging curve with depth and time, and the Lame constant reflectance of the five fluid saturated sandstone roofs is negative.
  • the reflective interface of the water-saturated sandstone roof corresponds to dark yellow-green
  • the gas saturated sandstone top corresponds to white, see the figure
  • the color code on the right shows that the absolute value of the Lame constant reflectivity of the five fluid-saturated sandstone tops increases from left to right.
  • Figure 9 also shows that the method of the present invention predicts that the Lame constant reflectivity of the five fluid-saturated sandstone bottom plates is positive, wherein the water-saturated sandstone floor reflection interface corresponds to yellow, and the crude oil specific gravity index API equals three oils of 30, 60, and 90.
  • the saturated sandstone bottom plate corresponds to orange, red and pink respectively.
  • the gas-saturated sandstone bottom plate corresponds to purple. See the color mark on the right side of the figure to see that from left to right, the reflectance of the Lame constant of the five fluid-saturated sandstone floors increases successively.
  • Lame constant reflectance obtained by the method of the invention clearly distinguishes water-saturated sandstone, saturated oil sandstone with different specific gravity index, and gas-saturated sandstone, indicating the ability of the hydrocarbon detection factor to predict the change of rock pore fluid properties.
  • Figure 10 is a cross section of predicted rock properties obtained using shear modulus reflectance ⁇ /( ⁇ +2 ⁇ ) as a direct hydrocarbon detection factor according to the seismic data of Figure 8.
  • the black curve is the shear modulus reflectance; the different colors of the color base map represent different ranges of values for the shear modulus reflectance, as indicated by the color scale on the right side of the figure.
  • the left side of each set of CDP patterns is the shear modulus curve in the time domain calculated from the log curve, showing the change in shear modulus with depth, ie time.
  • the shear modulus curves in Figure 10 show that the shear modulus of water-saturated sandstone, three oil-saturated sandstones, and gas-saturated sandstones is smaller than that of caprock and floor rocks, and shearing of various fluid-saturated sandstones.
  • the modulus is essentially constant, which is consistent with the prediction of the Gassmann equation.
  • Figure 10 shows that the shear modulus reflectance obtained by the method of the present invention is completely consistent with the change of the shear modulus calculated according to the log curve with depth, that is, the shear modulus reflectance of the five fluid saturated sandstone top plates.
  • the shear modulus reflectance of the five fluid-saturated sandstone floors is positive, and the shear modulus reflectance difference of the top plate of fluid-saturated sandstones with different properties is small, and the corresponding shear modulus reflectivity of the bottom plate The difference is also small.
  • the figure shows that the method of the present invention can accurately obtain the shear modulus reflectance and the Lame constant reflectance even when there is no noise disturbance in the seismic data, even if the difference in elasticity between the target layer and the surrounding rock is small.
  • Figure 11 is a prediction of oil and gas obtained from the seismic data of Figure 8 using the sum of the Lame constant reflectance and the shear modulus reflectance ( ⁇ ⁇ + ⁇ ⁇ ) / ( ⁇ + 2 ⁇ ) as a direct hydrocarbon detection factor.
  • the black curve is the sum of the Lame constant reflectance and the shear modulus reflectance; the different colors of the color base map represent the Lame constant inverse rate and shear modulus
  • the different numerical ranges of the amplitude envelopes of the sum of reflectances are shown by the color scales on the right side of the figure.
  • the left side of each set of CDP patterns is the Lame constant curve of the time domain calculated from the log curve.
  • This comprehensive detection profile utilizes both shear modulus reflectivity, Lame constant reflectivity, and predictive properties and capabilities of the amplitude envelope. Since the shear modulus reflectivity of the sandstone roof interface is the same as the Lame constant reflectance in this example, both of them have negative values, and the shear modulus reflectivity of the sandstone floor interface is the same as that of the Lame constant reflectance. Both are positive values. Therefore, the sum of the Lame constant reflectance and the shear modulus reflectance should be used as the hydrocarbon detection factor.
  • the amplitude envelope can simultaneously predict the pore fluid changes in the rock using information on the properties of the pore fluid implied in the reflected signals from the top and bottom plates. In Fig.
  • the reflective interface of the water-saturated sandstone floor corresponds to yellow
  • the three oil-saturated sandstone bottom plates of the crude oil specific gravity index API equal to 30, 60, and 90 correspond to orange, red, and pink, respectively
  • the gas-saturated sandstone bottom plate corresponds to purple
  • the amplitude envelope The anomalous position accurately corresponds to the location of the target layer sandstone. Comparing Fig. 11 with Fig. 9, although the Lame constant reflectance profile and the integrated detection profile both have the ability to predict the change of rock pore fluid properties, the former may not accurately indicate the position of the target layer and the bottom plate, while the latter can predict the target layer. The exact location. In FIG.
  • the peak time of the negative phase of the Lame constant reflectance corresponding to the target layer is smaller than the reflection time of the top layer of the target layer, and the peak time of the positive phase of the Lame constant reflectance of the target layer is greater than the reflection time of the top layer of the target layer.
  • the thickness of the gas-saturated sandstone indicated by the amplitude envelope anomaly is greater than the actual thickness, since the range of the color scale is not deliberately adjusted to accurately indicate the thickness of the sandstone.
  • the gauge range can be set using the log curve and the reservoir thickness of the drilling location to obtain the correct reservoir thickness.
  • the concentric point seismic trace set shown in Fig. 12 is a seismic gather obtained by adding random noise to the seismic gathers in Fig. 8 so that the signal-to-noise ratio of the seismic data is as low as 0.3. It is generally believed that a signal-to-noise ratio equal to 1 is the critical value of seismic data that can be used for oil and gas prediction. The seismic data with a signal-to-noise ratio equal to 0.3 is extremely poor in quality, so that in Fig. 12, only the reflection in-phase axis of the target layer can be observed faintly.
  • the present invention uses the seismic data of Figure 12 to demonstrate the ability of the method of the present invention to resist interference.
  • Figure 13 is a cross-sectional view of predicted oil and gas obtained from the seismic data of Figure 12 using the Lame constant reflectance ⁇ ⁇ /( ⁇ + 2 ⁇ ) as a direct hydrocarbon detection factor. Observing the profile, water-saturated sandstones, three oil-saturated sandstones, and gas-saturated sandstones are still clearly distinguished, although the anomalous morphology and quality are worse than in Figure 9.
  • Figure 14 is a cross section of predicted rock properties obtained using shear modulus reflectance ⁇ /( ⁇ +2 ⁇ ) as a direct hydrocarbon detection factor according to the seismic data of Fig. 12. Since the difference between the shear modulus of the target layer and the shear modulus of the surrounding rock is small, and the quality of the seismic data is poor, it is impossible to clearly distinguish the target sandstone from the surrounding rock according to the profile.
  • Figure 15 is a prediction of oil and gas obtained from the seismic data of Figure 12 using the sum of the Lame constant reflectance and the shear modulus reflectance (i.e., ( ⁇ ⁇ + ⁇ ) / ( ⁇ + 2 ⁇ ) as a direct hydrocarbon detection factor.
  • the mapping method of this figure is the same as the mapping method of Figure 11, the black curve is the sum of the Lame constant reflectance and the shear modulus reflectance; the different colors of the color basemap represent the Lame constant reflectivity and The different numerical ranges of the amplitude envelopes of the sum of shear modulus reflectances are shown by the color scales on the right side of the figure.
  • the left side of each set of CDP patterns is the Lame constant curve of the time domain calculated from the well log.
  • the ice-saturated sandstone, the three oil-saturated sandstones, and the gas-saturated sandstone can be clearly distinguished, and the differences between the various fluid-saturated sandstones are remarkable, and the abnormality is stable and reliable.

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Abstract

L'invention porte sur un procédé d'exploration directe de gisements de pétrole, de gaz naturel et de gaz de houille utilisant les facteurs de détection directe d'hydrocarbures qui sont: la constante de réflectivité de Lame Δλ(λ+2µ), le module de réflectivité de Shear Δµ/(λ+2µ) et Δµ/[κ+(4/3µ)], le module de réflectivité de volume Δκ/[κ+(4/3)µ], la différence entre la constante de réflectivité de Lame et le module de réflectivité de Shear [Δλ(λ+2µ) et Δµ/(λ+2µ)], et la somme de la constante de réflectivité de Lame et du module de réflectivité de Shear [Δλ(λ+2µ)+Δµ/(λ+2µ)]. Pour déterminer les facteurs directs de détection d'hydrocarbures, on admet usuellement que les expressions approximées de la réflectivité de l'onde longitudinale du groupe d'équations de Zeoppritz sont la première expression approximée (formule I) et la deuxième expression approximée (formule II), dans laquelle: L=Δλ/(λ+2µ), M=Δµ/(λ+2µ), K=Δκ/[κ+(4/3)µ] , N=Δµ/[κ+(4/3µ)].
PCT/CN2006/003529 2005-12-22 2006-12-21 Procede d'exploration directe de gisements de petrole, de gaz naturel et de gaz de houille WO2007071196A1 (fr)

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