CN110568490B - Identification method for high-speed stratum top thin reservoir - Google Patents
Identification method for high-speed stratum top thin reservoir Download PDFInfo
- Publication number
- CN110568490B CN110568490B CN201910774904.2A CN201910774904A CN110568490B CN 110568490 B CN110568490 B CN 110568490B CN 201910774904 A CN201910774904 A CN 201910774904A CN 110568490 B CN110568490 B CN 110568490B
- Authority
- CN
- China
- Prior art keywords
- frequency
- seismic
- seismic data
- time
- thin
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
Images
Classifications
-
- 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
- G01V1/282—Application of seismic models, synthetic seismograms
-
- 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
- G01V1/306—Analysis for determining physical properties of the subsurface, e.g. impedance, porosity or attenuation profiles
Landscapes
- Engineering & Computer Science (AREA)
- Remote Sensing (AREA)
- Physics & Mathematics (AREA)
- Life Sciences & Earth Sciences (AREA)
- Acoustics & Sound (AREA)
- Environmental & Geological Engineering (AREA)
- Geology (AREA)
- General Life Sciences & Earth Sciences (AREA)
- General Physics & Mathematics (AREA)
- Geophysics (AREA)
- Geophysics And Detection Of Objects (AREA)
Abstract
The invention provides a method for identifying a high-speed stratum top thin reservoir, belonging to the technical field of oil exploration. The method comprises the following steps: for a plurality of drilling wells in an exploration area, obtaining effective lowest frequency of thin reservoir layers on a high-speed layer in each drilling well when the thin reservoir layers can be identified, and obtaining effective lowest frequency distribution on the exploration area by utilizing an interpolation method in combination with the effective lowest frequency of each drilling well; acquiring seismic data of an exploration area, and performing time-frequency decomposition on the seismic data to obtain a time-frequency spectrum channel set; eliminating the low-frequency part in the time-frequency spectrum channel set by utilizing the effective lowest frequency distribution to obtain a time-frequency spectrum of the high-frequency component of the seismic data; performing inverse transformation of time-frequency decomposition on the time-frequency spectrum of the seismic data high-frequency component to obtain the seismic data high-frequency component; and reflecting the distribution characteristics of the high-speed stratum top thin reservoir in the exploration area by using the amplitude value in the high-frequency component of the seismic data. The method can accurately identify the thin reservoir above the high-speed layer and reflect the transverse change characteristics of the thin reservoir.
Description
Technical Field
The invention relates to a method for identifying a high-speed stratum top thin reservoir, belonging to the technical field of oil exploration.
Background
At present, there are two main methods for identifying thin reservoirs above a high-speed layer (i.e. high-speed layer top thin reservoir), one is: according to the method, the seismic amplitude is directly utilized to reflect the top thin reservoir of the high-speed layer, but the seismic reflection formed by the thin reservoir is often submerged in the strong seismic reflection waveform formed by the high-speed layer, so that the distribution of the thin reservoir cannot be accurately reflected by utilizing the seismic amplitude; the second method comprises the following steps: the method is based on the fact that high-frequency components in seismic data are closely related to the response of a thin reservoir, firstly, frequency division processing is carried out on the seismic data through a frequency division signal processing method (such as Fourier transform, wavelet transform, S transform and the like) to obtain seismic data bodies with different main frequencies, and then seismic data bodies with higher frequency bands are selected from the seismic data bodies to carry out seismic interpretation so as to identify the thin reservoir. However, the frequency band of the data volume selected by this method is usually narrow, which causes the following problems: 1) when a narrow high-frequency-band seismic data volume is used for seismic interpretation, waveform distortion often occurs due to too high frequency, so that a thin reservoir cannot be accurately identified; 2) since the lithological structure of a high-speed thin-topped reservoir usually changes rapidly in the lateral direction, the seismic data volume of a narrow frequency band cannot accurately reflect the lateral changes.
In summary, the current thin reservoir identification method cannot accurately identify the thin reservoir above the high-speed layer.
Disclosure of Invention
The invention aims to provide a method for identifying a thin top reservoir of a high-speed layer, which is used for solving the problem that the thin reservoir above the high-speed layer cannot be accurately identified by the conventional thin reservoir prediction method.
In order to achieve the above object, the present invention provides a method for identifying a high-speed thin-topped reservoir, comprising the steps of:
for any well in an exploration area, generating a series of synthetic seismic records of the well according to well logging information and a series of set seismic wavelets with different main frequencies, and analyzing the series of synthetic seismic records of the well to obtain the effective lowest frequency of the thin reservoir layer on the high-speed layer in the well when the thin reservoir layer can be identified;
for a plurality of drilling wells in the exploration area, obtaining the effective lowest frequency of each drilling well, and obtaining the effective lowest frequency distribution on the exploration area by utilizing an interpolation method in combination with the effective lowest frequency of each drilling well;
acquiring seismic data of an exploration area, and performing time-frequency decomposition on the seismic data to obtain a time-frequency spectrum channel set;
eliminating the low-frequency part in the time-frequency spectrum channel set by utilizing the effective lowest frequency distribution to obtain a time-frequency spectrum of the high-frequency component of the seismic data;
performing inverse transformation of time-frequency decomposition on the time-frequency spectrum of the seismic data high-frequency component to obtain the seismic data high-frequency component;
and reflecting the distribution characteristics of the high-speed stratum top thin reservoir in the exploration area by using the amplitude value in the high-frequency component of the seismic data.
The invention has the beneficial effects that: the seismic data high-frequency component for reflecting the distribution characteristics of the high-speed layer top thin reservoir in the exploration area is obtained through effective lowest frequency distribution in the exploration area. Firstly, the method comprises the following steps: because the frequency in the effective lowest frequency distribution is the effective lowest frequency when the thin reservoir on the high-speed layer can be identified, when the effective lowest frequency distribution is used for removing, only the low-frequency part which is concentrated in the time frequency spectrum channel and is lower than the effective lowest frequency is removed, and the rest high-frequency part is completely reserved, the frequency section of the high-frequency component of the obtained seismic data can be ensured to be wider, so that when the thin reservoir is identified by the high-frequency component of the seismic data with the wider frequency section, the waveform distortion is not easy to occur, and the thin reservoir on the high-speed layer can be accurately identified; secondly, the method comprises the following steps: because the effective lowest frequency values corresponding to different positions in the effective lowest frequency distribution are different, when the low-frequency part in the time frequency channel set is removed by utilizing the effective lowest frequency distribution, the high-frequency bands reserved at different positions are different, the high-frequency components of the obtained seismic data are ensured to contain a plurality of high-frequency band components, and thus, the transverse change characteristics of the thin reservoir can be reflected when the thin reservoir in the whole area is identified. In conclusion, the thin reservoir stratum identification method can accurately identify the thin reservoir stratum above the high-speed layer and reflect the transverse change characteristics of the thin reservoir stratum, and the thin reservoir stratum identification result obtained by the method can provide a basis for oil and gas exploration.
Further, the initial dominant frequency value of the series of seismic wavelets with different dominant frequencies is lower than the lowest frequency value of the effective frequency range of the seismic data.
Further, for any well in the exploration area, the step of obtaining the effective lowest frequency of thin reservoirs on the high-speed layer in the well which can be identified is as follows: in the synthetic seismic record of the well, in which the dominant frequency values of a series of seismic wavelets are sequentially increased, when the upper part of a strong seismic reflection waveform formed by a high-speed layer just begins to appear an obvious complex wave form, the dominant frequency of the seismic wavelet corresponding to the corresponding synthetic seismic record is extracted as the effective lowest frequency of the well.
The method has the advantages that the complex wave form which is just obvious and appears on the upper part of the strong seismic reflection waveform formed by the high-speed layer is used as the identification of the developing thin reservoir layer on the high-speed layer, on one hand, the waveform change is used as the identification, and the defect that the distribution of the thin reservoir layer cannot be accurately reflected by the seismic amplitude can be overcome; on the other hand, the main frequency of the seismic wavelet corresponding to the synthetic seismic record when the obvious complex wave form just appears is used as the effective lowest frequency, so that the effective lowest frequency can be ensured to be in the effective bandwidth of the seismic data, and the thin reservoir above the high-speed layer can be identified by the seismic data.
Further, the time frequency spectrum of the seismic data high frequency component is obtained by using a frequency division formula, wherein the frequency division formula is as follows:
wherein, feRespectively representing the frequency in the time-frequency spectrum channel set corresponding to a certain line channel in the seismic data, and the effective lowest frequency in the effective lowest frequency distribution, Ghigh(f) Representing the time spectrum of the high frequency components of the seismic data.
And screening the frequencies in the time-frequency channel set corresponding to all the channels in the seismic data one by using the effective lowest frequency in the effective lowest frequency distribution, eliminating the low-frequency part, and only keeping the high-frequency part. On one hand, because the frequency in the effective lowest frequency distribution is the effective lowest frequency when the thin reservoir on the high-speed layer can be identified, only the low-frequency part which is lower than the effective lowest frequency in the time spectrum channel concentration is removed, and the rest high-frequency part is completely reserved, so that the frequency section of the reserved high-frequency part is ensured to be wider, namely the frequency section of the high-frequency component of the seismic data is ensured to be wider; on the other hand, in the effective lowest frequency distribution, the effective lowest frequency values corresponding to different positions are different, so that the high frequency bands reserved at different positions are also different, and the high frequency components of the seismic data are ensured to contain a plurality of high frequency band components.
Further, the main frequency values of the seismic wavelets are sequentially increased from the initial main frequency value according to an increasing step length, and the increasing step length is 3 Hz-5 Hz.
Further, the seismic wavelet is a Rake wavelet.
Further, the interpolation method is a kriging interpolation method.
Drawings
FIG. 1 is a flow chart of a method for identifying a high-speed thin-topped reservoir in an embodiment of the invention;
FIG. 2-1 is a synthetic seismic trace for a borehole A having a seismic wavelet dominant frequency of 20Hz to 55Hz in an embodiment of the present invention;
FIG. 2-2 is a synthetic seismic trace for a borehole A having a seismic wavelet dominant frequency of 60Hz to 95Hz in an embodiment of the present invention;
2-3 are synthetic seismic traces corresponding to seismic wavelets for well A having a dominant frequency of 100Hz to 135Hz in embodiments of the present invention;
FIG. 3-1 is a geological model map of a reference well in an embodiment of the invention;
FIG. 3-2 is a forward seismic profile of a reference well in an embodiment of the present invention;
3-3 are high frequency component plots of forward seismic profiles of reference wells in an embodiment of the present invention;
FIG. 4-1 is a seismic section of a through borehole A, B and C in an embodiment of the invention;
fig. 4-2 is a high frequency component profile of a seismic section through boreholes A, B and C in an embodiment of the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, the present invention will be described in further detail with reference to the accompanying drawings and specific embodiments.
The embodiment provides a method for identifying a high-speed stratum top thin reservoir (hereinafter referred to as thin reservoir identification method), which can effectively identify the thin reservoir in an exploration area and can reveal the transverse change characteristics of the thin reservoir.
In the embodiment, the basement of the exploration area is the carboniferous tuff, and the seismic speed is high (4500-5500 m/s). The top of the carboniferous system develops a set of thin reservoir, the thickness of the bottom is smaller and is mostly smaller than 10m, and the thickness of a mudstone interlayer between the carboniferous system and the high-speed layer of the carboniferous system is also smaller. The thin reservoir development characteristics are complex, and the transverse continuity is not strong, and the change is rapid. Seismic reflections formed by the thin reservoirs are submerged in accompanying reflection wave troughs of strong reflection at the top of the carboniferous system to form strong wave trough seismic reflection together, so that the distribution of the thin reservoirs cannot be accurately reflected by using seismic amplitude.
As shown in fig. 1, the thin reservoir identification method of the present embodiment is used to identify a thin reservoir at the top of a high-speed layer in an exploration area, and includes steps 1 to 6:
step 1, for any well in an exploration area, generating a series of synthetic seismic records of the well according to well logging information and a series of set seismic wavelets with different main frequencies, and analyzing the series of synthetic seismic records of the well to obtain the effective lowest frequency of the thin reservoir on the high-speed layer in the well when the thin reservoir can be identified.
In this embodiment, three wells (wells A, B and C) in the exploration area are taken as an example to describe the thin reservoir identification method of this embodiment, and the implementation process of the method when the number of wells is changed is similar to that of three wells, and is not described here again.
The synthetic seismic record manufacturing process is the prior art, and the manufacturing process of a series of synthetic seismic records of the well a in this embodiment includes:
1) calculating the main frequency f of the well-side seismic channel of the well A by using the well-side seismic channel set data of the well Amain；
2) Logging information (including sonic logs and densities) using borehole ADegree curve) and the dominant frequency f of the seismic channel beside the wellmainDetermining an accurate time-depth relation through well seismic calibration by using the consistent standard Rake wavelets;
3) gradually increasing the dominant frequency value of the seismic wavelet from low to high from the initial dominant frequency value to obtain a series of seismic wavelets with different dominant frequencies; and calculating by using the series of seismic wavelets with different dominant frequencies through a conventional method to obtain a synthetic seismic record corresponding to each dominant frequency value, thereby obtaining a series of synthetic seismic records of the well A.
In this embodiment, the seismic data has a high dominant frequency of about 60Hz, and the frequency range of the seismic data effective signal (i.e., the seismic data effective frequency range) is 30Hz to 85Hz, and since the lowest frequency value of the seismic data effective frequency range is 30Hz, in this embodiment, the initial dominant frequency value of the seismic wavelet is set to 20Hz, which is slightly lower than the lowest frequency value, and the increment step length of the seismic wavelet dominant frequency value is 5Hz, and a series of synthetic seismic records of the well a obtained as shown in fig. 2-1 to 2-3 are shown, in which the highest dominant frequency value of the seismic wavelet in the figure is 135Hz, which exceeds the highest frequency value of the seismic data effective frequency range, so as to ensure that the response frequency of the thin reservoir can be accurately determined. As other embodiments, the step size of the increase of the main frequency value of the seismic wavelet can be selected from 3Hz to 5 Hz.
The seismic wavelets in this embodiment are rake wavelets, and as another embodiment, other types of seismic wavelets may be selected according to the actual situation of the exploration area.
In this example, the process of obtaining the effective lowest frequency of well a is as follows:
as shown in fig. 2-1 through 2-3, the dominant frequencies of the seismic wavelets for each synthetic seismic record are labeled below the graph. As can be seen from the figure, the lowest strong reflection is formed by the high-speed layer. Because the thin reservoir on the high-speed layer can not accurately identify the top-bottom reflection within the effective frequency band range of the earthquake, the waveform change is used as an identification mark, and the thin reservoir on the high-speed layer can be identified when the obvious complex wave form appears on the upper part of the strong earthquake reflection waveform formed on the high-speed layer on the synthetic earthquake records with different earthquake wavelet main frequencies.
In conjunction with fig. 2-1 to 2-3, it can be seen that: with the increasing of the dominant frequency of the seismic wavelet, the characterization of the seismic waveform in the synthetic seismic record on the thin reservoir layer is more obvious, and the formed seismic waveform can accurately identify the thin reservoir layer at the top of the high-speed layer only when the dominant frequency of the seismic wavelet reaches more than 100 Hz. But this frequency has exceeded the effective bandwidth of seismic data (30Hz to 85 Hz). Because the frequency bandwidth of the seismic data is limited, in order to identify the thin reservoir stratum at the top of the high-speed stratum by using the seismic data, the embodiment selects the sign for identifying the thin reservoir stratum when the obvious complex wave form just appears on the upper part of the strong seismic reflection waveform formed by the high-speed stratum in the synthetic seismic record, as shown in the rectangular frame in fig. 2-2, and uses the main frequency of the seismic wavelet corresponding to the synthetic seismic record when the obvious complex wave form just appears as the effective lowest frequency f of the well Aea. The primary frequency of the corresponding seismic wavelet in the newly appearing obvious complex wave form in fig. 2-2 is 80Hz, and is within the effective bandwidth of the seismic data.
For different operators, if they have different locations for complex wave forms in the same synthetic seismic record, the size of the effective lowest frequency obtained by them may be different, but all the effective lowest frequencies are required to be within the effective bandwidth of the seismic data.
Step 2, obtaining the effective lowest frequency of each drilling well for a plurality of drilling wells in the exploration area, and obtaining the effective lowest frequency distribution F on the exploration area by utilizing an interpolation method by combining the effective lowest frequency of each drilling wellarea。
The effective lowest frequency of each well in the exploration area can be obtained by using the step 1, and the effective lowest frequency corresponding to the well A, B, C in the embodiment is fea，feb，fecShowing that the effective lowest frequency distribution F on the exploration area is obtained by combining the effective lowest frequencies of the well A, B and the well C and utilizing the common interpolation method of Critical gold and the like to perform transverse interpolation on the effective lowest frequencies of all positions of the exploration areaarea。
Step 3, acquiring seismic data M of the exploration area0The seismic data M0Performing time-frequency decomposition to obtain a time-frequency spectrum channel set G0。
Step 4, utilizing effective lowest frequency distribution FareaRejecting time-frequency spectrum gather G0The middle low frequency part to obtain the time frequency spectrum G of the high frequency component of the seismic datahigh。
Wherein, the time frequency spectrum G of the high-frequency component of the seismic data is obtained by using a frequency division formulahighThe division formula is expressed as:
in the formula, f represents the frequency in the time-frequency spectrum channel set corresponding to a certain line channel in the seismic data, feRepresents the effective lowest frequency distribution F corresponding to the lineareaEffective lowest frequency of middle, Ghigh(f) I.e. the time-frequency spectrum G of the high-frequency components of the seismic datahigh。
Step 5, time frequency spectrum G of high frequency component of seismic datahighInverse transformation of time-frequency decomposition is carried out to obtain seismic data high-frequency component Mhigh。
Step 6, utilizing the high-frequency component M of the seismic datahighThe amplitude value in the test table reflects the distribution characteristics of the high-speed stratum top thin reservoir of the well to be tested.
In the thin reservoir identification method of the embodiment, in the implementation process, the sequence among the steps can be adjusted according to actual needs, for example, an effective lowest frequency distribution F is obtainedareaAnd obtaining a time-frequency spectrum trace set G0The order between can be adjusted.
The validity of the thin reservoir identification method of the present embodiment is verified below.
Firstly, a geological model is constructed, the geological model is subjected to forward earthquake modeling to obtain an earthquake section, high-frequency components are extracted from the earthquake section, and the recognition effect of the earthquake section on thin reservoirs above a high-speed layer is analyzed. Wherein, the actual drilling well is used as a reference well, a geological model close to the actual geological characteristics is established as shown in figure 3-1, a seismic profile obtained by seismic forward modeling is shown in figure 3-2, and a high-frequency component diagram of the seismic profile is shown in figure 3-3.
The curve of the reference well in fig. 3-1 is a natural potential curve, and can reflect characteristics of sandstone reservoirs, mudstones, tuff and the like. The geological model built has three thin reservoirs: the upper part of the sandstone reservoir is a thin layer and develops between thick layers of mudstones, and the lower part of the sandstone reservoir is two sets of thin sandstone reservoirs with super-coverage pinch-out; the lowermost reservoir develops on top of the tuff.
In the seismic section shown in fig. 3-2, two sets of strong seismic reflections and one set of weaker seismic reflections are visible: the upper part is strong reflection formed by a thin reservoir; the reflection of the middle thin reservoir becomes weaker due to the tuning effect; the lower part is mainly a strong reflection formed by the tuff base, which is submerged in the reflection formed by the sandstone reservoir.
3-3, it is apparent that the reflection morphology and the sharp vanishing point of the overburden film can be accurately determined by using the high frequency component of the seismic section.
Secondly, after the identification effect of identifying the high-speed stratum top thin reservoir by using the high-frequency component of the seismic data is tested by constructing a geological model, the method is applied to a research area to obtain a result capable of meeting the production requirement.
The seismic profile of the through-drilled wells A, B and C and its high frequency component profile are shown in FIGS. 4-1 and 4-2, with the lower weak clutter reflections in the figure being the response of the carbo-tuff formation. In the seismic section shown in fig. 4-1, A, B, C three wells each correspond to a set of strong valley reflections at the top of the high velocity zone of the peat system, which is indicated by the dashed lines. The set of strong trough reflections cannot effectively characterize the thin reservoir layer developing on top of the carboniferous high-speed layer in three-hole drilling. While in the high frequency component profile shown in fig. 4-2, the strong reflections at the top of the carbonium series are attenuated, and the remaining seismic reflections can correspond to thin reservoirs at the top of the carbonium series in three wells. Thin reservoirs in the well A, B, C are not connected, and two sets of thin reservoirs develop in the well C, the characteristics are highlighted in the high-frequency component profile, and the transverse pinch-out change of the thin reservoirs can also be highlighted.
Claims (6)
1. A method of identifying a high-speed thin-topped reservoir, the method comprising the steps of:
for any well in an exploration area, generating a series of synthetic seismic records of the well according to well logging information and a series of set seismic wavelets with different main frequencies, and analyzing the series of synthetic seismic records of the well to obtain the effective lowest frequency of the thin reservoir layer on the high-speed layer in the well when the thin reservoir layer can be identified; for any well in the exploration area, the steps of obtaining the effective lowest frequency of thin reservoirs on the high-speed layer in the well which can be identified are as follows: in the synthetic seismic record in which the main frequency values of a series of seismic wavelets of the well are sequentially increased, when the upper part of a strong seismic reflection waveform formed by a high-speed layer just begins to appear an obvious complex wave form, extracting the main frequency of the seismic wavelet corresponding to the corresponding synthetic seismic record as the effective lowest frequency of the well;
for a plurality of drilling wells in the exploration area, obtaining the effective lowest frequency of each drilling well, and combining the effective lowest frequency of each drilling well, utilizing an interpolation method to transversely interpolate the effective lowest frequency of each position in the exploration area to obtain the effective lowest frequency distribution on the exploration area; the effective lowest frequency values corresponding to different positions in the exploration area are different;
acquiring seismic data of an exploration area, and performing time-frequency decomposition on the seismic data to obtain a time-frequency spectrum channel set;
eliminating the low-frequency part in the time-frequency spectrum channel set by utilizing the effective lowest frequency distribution to obtain a time-frequency spectrum of the high-frequency component of the seismic data;
performing inverse transformation of time-frequency decomposition on the time-frequency spectrum of the seismic data high-frequency component to obtain the seismic data high-frequency component;
and reflecting the distribution characteristics of the high-speed stratum top thin reservoir in the exploration area by using the amplitude value in the high-frequency component of the seismic data.
2. The method of identifying a high-speed stratigraphic thin-top reservoir of claim 1, wherein the initial dominant frequency values of the series of seismic wavelets of different dominant frequencies are lower than the lowest frequency values of the effective frequency band of seismic data.
3. The method for identifying a high-speed thin-topped reservoir of claim 1, wherein the time-frequency spectrum of the high-frequency components of the seismic data is obtained by using a frequency division formula, and the frequency division formula is as follows:
wherein, feRespectively representing the frequency in the time-frequency spectrum channel set corresponding to a certain line channel in the seismic data, and the effective lowest frequency in the effective lowest frequency distribution, Ghigh(f) Time-frequency spectrum, G, representing high-frequency components of seismic data0Is a time-frequency spectrum channel set.
4. The method for identifying a high-speed stratigraphic top-thin reservoir as claimed in claim 1, wherein the dominant frequency values of the seismic wavelets are sequentially increased from an initial dominant frequency value according to an increase step size, the increase step size being 3Hz to 5 Hz.
5. The method of identifying a high-speed thin-topped reservoir of any one of claims 1-4, wherein the seismic wavelets are Rake wavelets.
6. The method for identifying a high-speed thin-topped reservoir as claimed in any one of claims 1 to 4, wherein the interpolation method is a kriging interpolation method.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201910774904.2A CN110568490B (en) | 2019-08-21 | 2019-08-21 | Identification method for high-speed stratum top thin reservoir |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201910774904.2A CN110568490B (en) | 2019-08-21 | 2019-08-21 | Identification method for high-speed stratum top thin reservoir |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN110568490A CN110568490A (en) | 2019-12-13 |
| CN110568490B true CN110568490B (en) | 2021-09-17 |
Family
ID=68775789
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201910774904.2A Active CN110568490B (en) | 2019-08-21 | 2019-08-21 | Identification method for high-speed stratum top thin reservoir |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN110568490B (en) |
Families Citing this family (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN111444154B (en) * | 2020-03-26 | 2020-11-27 | 涵涡智航科技(玉溪)有限公司 | Method for efficiently storing log files in single chip microcomputer system |
| CN112180464B (en) * | 2020-11-03 | 2024-05-24 | 中国石油化工股份有限公司 | Reservoir physical property identification method |
Family Cites Families (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2002088774A1 (en) * | 2001-04-30 | 2002-11-07 | The Regents Of The University Of California | Frequency-dependent processing and interpretation (fdpi) of seismic data for identifying, imaging and monitoring fluid-saturated underground reservoirs |
| CN104991270A (en) * | 2015-06-08 | 2015-10-21 | 中国石油化工股份有限公司 | Superimposed sand body identification method based on seismic forward modeling |
| CN106707339B (en) * | 2016-11-22 | 2018-09-25 | 中国石油天然气集团有限公司 | A kind of phased inversion method of Depth Domain |
| CN106405647B (en) * | 2016-12-22 | 2018-04-13 | 成都晶石石油科技有限公司 | A kind of tuning inversion method on sedimentary formation thickness |
-
2019
- 2019-08-21 CN CN201910774904.2A patent/CN110568490B/en active Active
Also Published As
| Publication number | Publication date |
|---|---|
| CN110568490A (en) | 2019-12-13 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN105334535B (en) | A kind of method for identifying the thin hidden lithologic deposit of reservoir | |
| CN106842307B (en) | Reservoir stratum fine prediction method based on waveform classification and retrieval under forward constraint | |
| CN103728659B (en) | A kind of method improving detection of karst cave precision | |
| CN106526670A (en) | Description and evaluation method for spatial distribution of sand bodies, of seismic attribute, in clastic rock reservoir | |
| CN101349764B (en) | A Method for Seismic Cycle Analysis | |
| CN109738951B (en) | Time-varying deconvolution method based on seismic event sub-spectrum | |
| CN107065013B (en) | A method and device for determining layer velocity at seismic scale | |
| CN109188520A (en) | Thin reservoir thickness prediction method and device | |
| CN114994758B (en) | Wave impedance extraction and structure characterization method and system for carbonate rock fracture control reservoir | |
| CN110568490B (en) | Identification method for high-speed stratum top thin reservoir | |
| CN110927817B (en) | Method for optimally designing and controlling thin-layer superposed riverway horizontal well track | |
| CN108254785B (en) | Reservoir determination method and device | |
| CN113109875A (en) | Inversion method of carbonate rock reservoir under full waveform velocity field constraint | |
| CN111090117B (en) | Effective reservoir prediction method and system under phase control forward constraint | |
| CN115629417B (en) | Multi-scale Fusion and Facies-Controlled Grain Bank Characterization Method Based on Seismic Sedimentology | |
| CN113589365B (en) | Reservoir pinch-out line description method based on time-frequency domain information | |
| CN112180464B (en) | Reservoir physical property identification method | |
| US11852768B2 (en) | Multimodal approach to target stratigraphic plays through seismic sequence stratigraphy, rock physics, seismic inversion and machine learning | |
| CN113671565B (en) | Earthquake multi-scale reservoir prediction method for gas reservoir development of huge thick reservoir | |
| Jafari et al. | Estimation of acoustic-impedance model by using model-based seismic inversion on the Ghar Member of Asmari Formation in an oil field in southwestern Iran | |
| CN110673211B (en) | A Quality Factor Modeling Method Based on Logging and Seismic Data | |
| Blumentritt | Highlight volumes: Reducing the burden in interpreting spectral decomposition data | |
| CN110632660B (en) | Thin sand body characterization method and device based on seismic data body | |
| CN110568491B (en) | Quality factor Q estimation method | |
| CN110389381B (en) | Sand reservoir prediction method and device based on seismic attributes |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |