CN113090251B - Logging VSP composite data acquisition system based on optical fiber sensing and acquisition processing method - Google Patents
Logging VSP composite data acquisition system based on optical fiber sensing and acquisition processing method Download PDFInfo
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Abstract
The invention discloses a system and a method for acquiring and processing VSP composite data of a logging well based on optical fiber sensing. And the logging instrument starts to slowly lift up to acquire logging data, so that the high-density, high-benefit and low-cost logging and VSP data composite acquisition in one-time well logging are realized. The invention solves the problems of the prior art that the logging data and the VSP data are separately acquired by respective equipment, the equipment investment is large, the well occupying time is long, and the acquisition cost is high.
Description
Technical Field
The invention belongs to the fields of geophysical application, geophysical exploration technology, geophysical logging technology, seismic exploration and logging, and particularly relates to a logging VSP composite data acquisition system and an acquisition processing method based on optical fiber sensing.
Background
Seismic waves (Seismic Wave) are vibrations that propagate from a Seismic source to four locations, and refer to elastic waves that radiate from the Seismic source to the surroundings. The wave propagation method can be divided into three types, namely longitudinal waves (P waves), transverse waves (S waves) (both the longitudinal waves and the transverse waves belong to body waves) and surface waves (L waves). 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.
In the processing and interpretation of seismic data acquired from seismic surveys, it is one of the essential and very important steps to calculate the velocity at which various seismic waves propagate in the formation and the elastic or viscoelastic parameters (attenuation coefficients) of the subsurface medium (formation or rock formation). If the seismic wave velocity of the subsurface formations and the elastic or viscoelastic parameters of the subsurface medium (formation or rock) cannot be accurately obtained, subsequent processing and interpretation of the seismic data may be very disadvantageous or impossible. Therefore, accurate measurement and calculation of seismic wave velocity of subsurface formations and elastic or viscoelastic parameters of the subsurface medium (formation or rock formation) is one of the primary tasks for seismic data processing interpretation.
The existing Vertical Seismic Profile (VSP) data acquisition system in the well uses a general moving-coil three-component detector array in the well, and the vertical seismic profile data acquisition operation in the well is independently carried out. Because the existing moving coil type three-component detector in the well is heavy in weight and high in cost, a logging cable can put 100-grade moving coil type three-component detectors in the well at most once, seismic data in a whole well section with the depth of thousands of meters needs to be acquired by moving or lifting a moving coil type three-component detector array in the well for a plurality of times, and each time the moving coil type three-component detector array in the well is lifted, all points of a ground artificial excitation seismic source (explosive or a heavy hammer or an electric spark or an air gun or a piezoelectric crystal or a controllable seismic source) need to be excited again, so that the cost for acquiring vertical seismic section data of the whole well section is extremely high, the repeated excitation of each ground artificial seismic source point hardly ensures the energy of each excitation to be consistent, the frequency spectrum to be consistent, and each coupling of the ground artificial seismic source and the ground is also to be consistent. For these well-known reasons, it is difficult to widely popularize and apply the conventional moving-coil three-component detector array in the well for the operation of vertical seismic profile data in the well.
Disclosure of Invention
In order to solve the technical problems, the invention discloses a logging and Vertical Seismic Profile (VSP) composite data acquisition system based on an in-well distributed optical fiber sensing technology and an acquisition and well-flooding data processing method.
One of the technical schemes adopted by the invention is as follows:
a logging VSP composite data acquisition system based on optical fiber sensing comprises: the system comprises a ground artificial seismic source, a distributed optical fiber sensing armored photoelectric composite cable arranged in a full well section well, a logging instrument, a logging truck near a ground well head and a distributed optical fiber sensing modulation and demodulation instrument arranged in the logging truck, wherein the head end of the distributed optical fiber sensing armored photoelectric composite cable is connected with the logging truck near the ground well head, the tail end of the distributed optical fiber sensing armored photoelectric composite cable is connected with the logging instrument, and the logging truck near the ground well head, the distributed optical fiber sensing armored photoelectric composite cable and the logging instrument are used for collecting Vertical Seismic Profile (VSP) data and logging data in the same well by logging at one time.
The logging instrument is as follows: one or more combinations of open hole wireline logging instruments and production logging instruments in a cased hole or tubing.
The ground artificial seismic source comprises: the ground artificial seismic source is arranged near a well head (zero offset VSP) and on a plurality of circular ring lines (Walkerround VSP) at a certain distance away from the well head, and the difference of the azimuth angles of two adjacent ground artificial seismic sources on the circular ring lines is 30-90 degrees.
The distributed optical fiber sensing armored photoelectric composite cable is used for replacing a conventional logging 7-core cable or a single-core cable to connect various cable logging instruments and various production logging instruments in a sleeve or an oil pipe to perform downhole acquisition of conventional logging data. The distributed optical fiber sensing armored photoelectric composite cable is internally provided with a continuous corrosion-resistant stainless steel thin tube or an alloy thin tube or a thin tube made of a high-strength high-temperature-resistant composite material, the diameter of the continuous corrosion-resistant stainless steel thin tube or the alloy thin tube is the same as that of a lead wire in the logging cable, and a plurality of high-temperature-resistant and hydrogen-loss-resistant single-mode, multi-mode and special optical fibers are placed in the thin tube and used for acquiring borehole seismic data, borehole temperature data, borehole pressure data and high-speed transmission logging data, and can also be connected with various optical fiber sensors in a logging instrument to acquire optical fiber logging data. The tail end of one single mode fiber is provided with an extinction device or is provided with a section, and the tail ends of the two multimode fibers are welded into a U shape.
The distributed optical fiber sensing modulation and demodulation instrument arranged in the logging truck comprises a distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument, a distributed optical fiber temperature sensing (DTS) modulation and demodulation instrument and a distributed optical fiber pressure sensing (DPS) modulation and demodulation instrument, and is also provided with optical fiber modulation and demodulation instruments required by other different optical fiber sensors in the underground logging instrument, wherein all the optical fiber modulation and demodulation instruments are connected with various single-mode, multi-mode and special optical fibers at the head end of the distributed optical fiber sensing armored photoelectric composite cable.
The ground artificial seismic source is provided with wired or wireless communication equipment, is in communication connection with a distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument in the logging truck, and is used for sending a seismic source excitation pulse signal and starting the distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument to acquire Vertical Seismic Profile (VSP) data.
Other fiber optic sensors inside the logging instrument are one or more of: MEMS fiber optic three-component geophone, fiber optic hydrophone, monopole or dipole fiber optic acoustic wave sensor, fiber optic temperature sensor, fiber optic pressure sensor, fiber optic single-component or three-component electric field gradient sensor, fiber optic single-component or three-component magnetic field gradient sensor, fiber optic chemical sensor, fiber optic single-component or three-component gravity sensor, fiber optic single-component or three-component gravitational acceleration sensor, fiber optic downhole fluid component detection sensor.
The method comprises the following steps of adopting the optical fiber sensing-based logging VSP composite data acquisition system to acquire and process Vertical Seismic Profile (VSP) data in a well, and performing well drive processing on ground two-dimensional or three-dimensional seismic data:
(1) the distributed optical fiber sensing armored photoelectric composite cable on the logging truck is connected with a conventional logging instrument going into a well near a well head, and various optical fibers at the head end of the distributed optical fiber sensing armored photoelectric composite cable are connected with various optical fiber modulation and demodulation instruments in the logging truck. The high-temperature-resistant and hydrogen-loss-resistant single-mode optical fiber with the delusters mounted at the tail end is connected with the signal input end of a distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument, and the two high-temperature-resistant and hydrogen-loss-resistant multi-modes with the tail ends welded into a U shape are connected with the double-end signal input end of the distributed optical fiber temperature sensing (DTS) modulation and demodulation instrument;
(2) and laying the ground artificial seismic sources at the positions of the ground artificial seismic sources for acquiring vertical seismic section data in the well. Establishing connection with a distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument in the logging truck in a wired or wireless mode, triggering and starting the DAS modulation and demodulation instrument by an excitation signal of a ground artificial seismic source to synchronously start to acquire data when the ground artificial seismic source is excited;
(3) slowly lowering a logging instrument to the bottom of the well through a pulley on a derrick above the well mouth or on a crane through a distributed optical fiber sensing armored photoelectric composite cable;
(4) the logging instrument is put down to the bottom of the well and stops for a moment, after the logging instrument is stably and statically placed, ground artificial seismic sources of seismic source excitation points which are distributed on the ground in advance are rapidly and sequentially excited, the excitation signal of each ground artificial seismic source is synchronously transmitted to the input end of an external trigger signal of a distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument in a logging truck in a wired or wireless mode, and the distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument is triggered and started to synchronously acquire zero offset or non-zero offset or Walkeround Vertical Seismic Profile (VSP) data in a whole well section which is excited by the ground artificial seismic sources; the method comprises the steps that a distributed optical fiber temperature sensing (DTS) modulation and demodulation instrument in a logging truck is started while Vertical Seismic Profile (VSP) data are collected, real-time temperature distribution data and temperature gradient data of a whole well section are collected synchronously, and meanwhile, a distributed optical fiber pressure sensing (DPS) modulation and demodulation instrument in the logging truck is started, and real-time pressure distribution data of the whole well section are collected synchronously;
(5) after the Vertical Seismic Profile (VSP) data acquisition is finished, the logging truck immediately starts to slowly lift up the logging instrument, and open hole cable logging data or production logging data in a sleeve or an oil pipe of the whole well section or a pre-designed well section are acquired. After the acquisition of the logging data is finished, the logging instrument is lifted out of a well mouth, the logging truck is moved to the next well field to be logged, and the steps (1) to (5) are repeated to sequentially acquire Vertical Seismic Profile (VSP) data and conventional logging data of the lower well mouth;
(6) according to the first arrival travel time of longitudinal waves and transverse waves of Zero Offset Vertical Seismic Profile (VSP) data collected in a well and the distance from a ground artificial seismic source point near the well head to each detection point on an underground distributed optical fiber sensing armored photoelectric composite cable, calculating and solving accurate average longitudinal wave and transverse wave speed values of an underground medium and longitudinal wave and transverse wave layer speed values of each stratum respectively;
(7) according to the initial arrival travel time of longitudinal waves and transverse waves of non-zero Offset vertical seismic profile (Offset VSP) data or Walkeround VSP data acquired in a well and the distance from a non-zero Offset ground artificial vibration source point or a Walkeround VSP ground artificial vibration source point to each detection point on the underground distributed optical fiber sensing armored photoelectric composite cable, calculating and solving accurate average longitudinal wave and transverse wave speed values of an underground medium in different directions and longitudinal wave and transverse wave layer speed values of layers in different directions respectively;
(8) utilizing multi-azimuth non-zero offset VSP data or Walkeround VSP data in the well, obtaining accurate average longitudinal wave and transverse wave speed values of the underground medium in different azimuths and longitudinal wave and transverse wave interval speed values of each stratum in different azimuths according to the step (7), and respectively calculating and extracting longitudinal wave and transverse wave speed anisotropy parameters of the underground stratum;
(9) removing multiple waves in ground two-dimensional or three-dimensional seismic data according to the depth position of a reflecting layer of Vertical Seismic Profile (VSP) data in a well, and calibrating each seismic geological reflecting layer of the ground two-dimensional or three-dimensional seismic data;
(10) processing seismic data of a Zero Offset vertical seismic profile (Zero Offset VSP) in a well, and calculating a stratum absorption attenuation parameter Q by using a continuous spectral ratio slope method, an energy spectrum centroid frequency shift method, a peak frequency method or an attenuation travel-time chromatography method according to the attenuation characteristic of the amplitude of a descending direct wave from the well head to the well bottom;
(11) and establishing a well control velocity field for the two-dimensional or three-dimensional seismic data acquired on the ground according to a true amplitude recovery factor extracted from the vertical seismic profile data in the well, and performing amplitude recovery processing based on the velocity field. The calculation formula of the true amplitude recovery factor is as follows:
where COEF (t) represents the true amplitude recovery factor, v0Is the initial velocity or water layer velocity, v is the root mean square velocity, t is the sampling point time;
(12) performing deconvolution processing on ground acquired two-dimensional or three-dimensional seismic data according to deconvolution parameters extracted from vertical seismic profile data in a well;
(13) performing velocity, anisotropic two-dimensional or three-dimensional parameter joint modeling of each well flooding parameter constraint based on Vertical Seismic Profile (VSP) data extraction in a well;
(14) performing resolution-improving processing on well control ground two-dimensional or three-dimensional seismic data by using various well flooding parameters extracted from vertical seismic profile data in a well;
(15) performing anisotropic migration processing on the two-dimensional or three-dimensional seismic data acquired on the ground according to the anisotropic parameters of the underground stratum accurately calculated and extracted in the step (8);
(16) performing Q compensation or Q migration processing on pre-stack gather data on the two-dimensional or three-dimensional seismic data acquired on the ground according to the stratum absorption attenuation parameter Q extracted in the step (10);
(17) comparing the interval velocity of longitudinal wave and transverse wave of each stratum obtained from zero-offset VSP data with the interval velocity of longitudinal wave and transverse wave of each stratum measured by an acoustic logging instrument, wherein the corresponding difference of the longitudinal wave and transverse wave velocities is caused by the difference between VSP data frequency (low frequency) and acoustic logging data frequency (high frequency), so that the frequency dispersion effect of the longitudinal wave and transverse wave velocities of each stratum in the well can be calculated, and the method can be used as a tool for describing reservoir rock and fluid characteristics.
The invention has the beneficial effects that: the invention discloses a logging VSP composite data acquisition system based on optical fiber sensing and an acquisition processing method, which solve the problems that logging and VSP data are respectively acquired by respective equipment in the prior art, the two kinds of equipment are large in investment, the well occupying time of separate operation is long, and the acquisition cost is high; the invention replaces standard 7-core cable or single-core cable used by conventional logging instrument with distributed optical fiber sensing armored photoelectric composite cable, the distributed optical fiber acoustic wave sensing (DAS) modulation-demodulation instrument in the logging truck is connected with optical fiber in the distributed optical fiber sensing armored photoelectric composite cable at the well head, when the conventional logging instrument connected with the tail end of the distributed optical fiber sensing armored photoelectric composite cable is down to the well bottom, ground seismic sources prepared in advance at the well head and around the well are rapidly excited in sequence, the underground distributed optical fiber sensing armored photoelectric composite cable and the ground DAS, DTS and DPS modulation-demodulation instruments rapidly and synchronously acquire all the full-well section VSP data, full-well section temperature data and full-well section pressure data excited by the ground seismic sources. The conventional logging instrument then starts to lift up slowly and starts to acquire conventional logging data, and the high-density, high-benefit and low-cost composite acquisition of the same-well conventional open hole cable logging data or cased hole production logging data and Vertical Seismic Profile (VSP) data in one-time well descending is realized. The Vertical Seismic Profile (VSP) data processing result in the same well can extract wavelets, identify multiples, obtain the average and interlayer longitudinal wave velocity and transverse wave velocity of the stratum, solve the velocity anisotropy of the longitudinal wave velocity and the transverse wave velocity in different directions, calculate the attenuation coefficient of the longitudinal wave and the transverse wave propagating in the underground medium, then a two-dimensional or three-dimensional seismic wave velocity model of the underground medium around the well and a two-dimensional or three-dimensional elastic or viscoelastic parameter model of the underground medium are precisely and accurately established, and performing static correction processing, multiple wave removal processing, amplitude consistency recovery processing, subsequent resolution enhancement processing of three-dimensional ground seismic data, anisotropic migration imaging and Q compensation or Q migration imaging of pre-stack gather data on ground two-dimensional or three-dimensional seismic data, and performing fine exploration and comprehensive evaluation of oil and gas resources through a comprehensive interpretation technology.
Drawings
Fig. 1 is a schematic diagram of an open hole wireline logging and Vertical Seismic Profile (VSP) data acquisition system according to embodiment 1 of the present invention.
FIG. 2 is a schematic diagram of a cased hole production log and Vertical Seismic Profile (VSP) data acquisition system according to example 2 of the present invention.
Fig. 3 is a schematic diagram of a well-flooding processing flow of ground two-dimensional or three-dimensional seismic data corresponding to embodiments 1 and 2 of 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.
Example 1
The present invention is described in detail below with reference to the attached drawings.
Fig. 1 is a logging VSP composite data acquisition system based on optical fiber sensing, specifically a barefoot cable logging and Vertical Seismic Profile (VSP) composite data acquisition system based on distributed optical fiber sensing. The method comprises the steps of drilling a hole 11 with an open hole, arranging a distributed optical fiber sensing armored photoelectric composite cable 13 in a full well section well, a logging instrument 14, a ground artificial seismic source 15, a logging truck 16 near a ground well head, and a distributed optical fiber sensing modulation and demodulation instrument 17 arranged in the logging truck 16;
the distributed optical fiber sensing modulation and demodulation instrument 17 comprises a distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument, a distributed optical fiber temperature sensing (DTS) modulation and demodulation instrument and a distributed optical fiber pressure sensing (DPS) modulation and demodulation instrument; the recording instrument used by the distributed optical fiber acoustic wave sensing armored photoelectric composite cable 13 is a phase-sensitive optical time domain reflectometer (phi-OTDR) and is arranged in a logging truck 16.
The ground artificial seismic source 15 is a ground explosive source or a heavy hammer source or an electric spark source or a piezoelectric crystal source or an air gun source or a controllable source.
When the open hole cable logging based on distributed optical fiber sensing and the Vertical Seismic Profile (VSP) composite data acquisition operation are carried out, firstly, the distributed optical fiber sensing armored photoelectric composite cable 13 on the logging truck 16 is connected with a conventional logging instrument 14 which goes into a well near the well head, and various optical fibers at the head end of the distributed optical fiber sensing armored photoelectric composite cable 13 are connected with a distributed optical fiber sensing modulation and demodulation instrument 17 in the logging truck 16. The high-temperature-resistant and hydrogen-loss-resistant single-mode optical fiber with the delusters mounted at the tail end is connected with the signal input end of a distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument, and the two high-temperature-resistant and hydrogen-loss-resistant multi-modes with the tail ends welded into a U shape are connected with the double-end signal input end of the distributed optical fiber temperature sensing (DTS) modulation and demodulation instrument;
and laying ground artificial seismic sources 15 at the positions of the ground artificial seismic sources for acquiring vertical seismic section data in the well. Meanwhile, establishing contact with a distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument in the logging truck 16 in a wired or wireless mode, triggering and starting the distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument by using an excitation signal of a ground artificial seismic source, and synchronously starting to acquire Vertical Seismic Profile (VSP) data when the ground artificial seismic source 15 is excited;
the logging instrument 14 is slowly lowered down to the well bottom through a pulley on the derrick above the well head or on a crane by a distributed optical fiber sensing armored photoelectric composite cable 13. The logging instrument 14 is put down to the bottom of the well and stops for a moment, after the logging instrument is stable and static, ground artificial seismic sources 15 of seismic source excitation points which are distributed on the ground in advance are rapidly and sequentially excited immediately, an excitation signal of each ground artificial seismic source 15 is synchronously transmitted to an external trigger signal input end of a distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument in a logging truck in a wired or wireless mode, and the distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument is triggered and started to synchronously acquire zero offset or non-zero offset or Walkerround Vertical Seismic Profile (VSP) data in a whole well section well excited by the ground artificial seismic sources 15; the method comprises the steps that a distributed optical fiber temperature sensing (DTS) modulation and demodulation instrument in a logging truck 16 is started while Vertical Seismic Profile (VSP) data are collected, real-time temperature distribution data and temperature gradient data of a whole well section are collected synchronously, and meanwhile, a distributed optical fiber pressure sensing (DPS) modulation and demodulation instrument in the logging truck is started, and real-time pressure distribution data of the whole well section are collected synchronously;
after the Vertical Seismic Profile (VSP) data acquisition is finished, the logging truck 16 immediately starts to slowly lift up the logging instrument 14, and starts to acquire cable logging data of an open hole drilling 11 in the whole well section or a pre-designed well section or production logging data in a cased well 12 or an oil pipe. After the acquisition of the logging data is completed, the logging instrument 14 is lifted out of the well head, the logging truck 16 is moved to the next well site to be logged, and the steps described above are repeated to sequentially acquire Vertical Seismic Profile (VSP) data and conventional logging data of the lower well.
Example 2
The present invention is described in detail below with reference to the attached drawings.
Fig. 2 is a logging VSP composite data acquisition system based on optical fiber sensing, specifically a cased hole production logging and Vertical Seismic Profile (VSP) composite data acquisition system based on distributed optical fiber sensing. The system comprises a cased well 12, a distributed optical fiber sensing armored photoelectric composite cable 13 arranged in a full well section well, a logging instrument 14, a ground artificial seismic source 15, a logging truck 16 near a ground wellhead, and a distributed optical fiber sensing modulation and demodulation instrument 17 arranged in the logging truck, wherein the distributed optical fiber sensing modulation and demodulation instrument 17 comprises a distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument, a distributed optical fiber temperature sensing (DTS) modulation and demodulation instrument and a distributed optical fiber pressure sensing (DPS) modulation and demodulation instrument. The recording instrument used by the distributed optical fiber acoustic wave sensing armored photoelectric composite cable 13 is a phase-sensitive optical time domain reflectometer (phi-OTDR) and is arranged in a logging truck 16.
The procedure for performing distributed fiber optic sensing based cased hole logging and Vertical Seismic Profiling (VSP) composite data acquisition operations is the same as in example 1.
In the two embodiments of the above-mentioned embodiments, the logging instrument 14 in the system for acquiring VSP composite data based on optical fiber sensing is: the open hole borehole 11 may be formed by one or more of a combination of various wireline logging instruments 14 and cased hole 12 or various production logging instruments 14 in the tubing.
The ground artificial seismic source 15 excitation points are distributed near the well mouth (zero offset VSP) and on a plurality of circular ring lines (Walkeround VSP) at a certain distance from the well mouth, and the difference of azimuth angles of two adjacent ground artificial seismic source 15 excitation points on the circular ring lines is 30-90 degrees.
The distributed optical fiber sensing armored photoelectric composite cable 13 is adopted to replace a conventional logging 7 core or a single core cable to connect various cable logging instruments 14 and a cased well 12 or various production logging instruments 14 in an oil pipe for logging data acquisition. The distributed optical fiber sensing armored photoelectric composite cable 13 is internally provided with a continuous corrosion-resistant stainless steel thin tube or an alloy thin tube or a high-strength high-temperature-resistant composite material thin tube with the same diameter as that of a lead wire in a conventional logging cable, and a plurality of high-temperature-resistant and hydrogen-loss-resistant single-mode, multi-mode and special optical fibers are placed in the thin tube and used for acquiring borehole seismic data, borehole temperature data, borehole pressure data and high-speed transmission logging data, and can also be connected with various optical fiber sensors in the logging instrument 14 to acquire optical fiber logging data. The tail end of one of the high-temperature-resistant and hydrogen-loss-resistant single-mode optical fibers is provided with an extinction device or is provided with a section, and the tail ends of the two high-temperature-resistant and hydrogen-loss-resistant multi-mode optical fibers are welded into a U shape.
The logging truck 16 is internally provided with a distributed optical fiber sensing modulation and demodulation instrument 17, which comprises a distributed optical fiber acoustic wave sensing (DAS) modulation and demodulation instrument, a distributed optical fiber temperature sensing (DTS) modulation and demodulation instrument, a distributed optical fiber pressure sensing (DPS) modulation and demodulation instrument and optical fiber modulation and demodulation instruments required by different optical fiber sensors in other underground logging instruments, wherein all the optical fiber modulation and demodulation instruments are connected with various single-mode, multi-mode and special optical fibers at the head end of the distributed optical fiber sensing armored photoelectric composite cable 13.
In the Vertical Seismic Profile (VSP) data acquisition operation, when a ground artificial seismic source 15 excitation device or equipment excites a ground artificial seismic source 15 at a pre-laid seismic source position, a seismic source excitation pulse signal is synchronously sent to a distributed optical fiber acoustic wave sensing (DAS) modem in a logging truck 16 in a wired or wireless communication mode, and is used for triggering and starting the distributed optical fiber acoustic wave sensing (DAS) modem to synchronously acquire Vertical Seismic Profile (VSP) data.
The various fiber optic sensors inside the logging instrument 14 may be: the optical fiber single-component or three-component magnetic field gradient sensor comprises one or more of a MEMS optical fiber three-component detector, an optical fiber hydrophone, a monopole or dipole optical fiber acoustic wave sensor, an optical fiber temperature sensor, an optical fiber pressure sensor, an optical fiber single-component or three-component electric field gradient sensor, an optical fiber single-component or three-component magnetic field gradient sensor, an optical fiber chemical sensor, an optical fiber single-component or three-component gravity acceleration sensor and an optical fiber downhole fluid component detection sensor.
Fig. 3 is a schematic diagram of a well-flooding processing flow of ground two-dimensional or three-dimensional seismic data corresponding to embodiments 1 and 2 of the present invention.
The well-flooding processing method for the ground two-dimensional or three-dimensional seismic data by using the Vertical Seismic Profile (VSP) data acquired in the two embodiments comprises the following steps:
(1) according to the first arrival travel time of longitudinal waves and transverse waves of Zero Offset Vertical Seismic Profile (VSP) data collected in a well and the distance from a ground artificial seismic source 15 near the well head to each detection point on an underground distributed optical fiber sensing armored photoelectric composite cable 13, calculating and solving accurate average longitudinal wave and transverse wave speed values of an underground medium and longitudinal wave and transverse wave layer speed values of each stratum respectively;
(2) according to the initial arrival travel time of longitudinal waves and transverse waves of non-zero Offset vertical seismic profile (Offset VSP) data or Walkeround VSP data acquired in a well and the distance from a non-zero Offset ground artificial vibration source point or a Walkeround VSP ground artificial vibration source point to each detection point on an underground armored photoelectric composite cable, calculating and solving accurate average longitudinal wave and transverse wave speed values of an underground medium in different directions and longitudinal wave and transverse wave layer speed values of layers in different directions respectively;
(3) by utilizing multi-azimuth non-zero offset VSP data or Walkeround VSP data in the well, obtaining accurate average longitudinal wave and transverse wave speed values of the underground medium in different azimuths and longitudinal wave and transverse wave layer speed values of each stratum in different azimuths according to the step (2), and respectively calculating and extracting longitudinal wave and transverse wave speed anisotropy parameters eta, delta and epsilon of the underground stratum;
(4) removing multiple waves in ground two-dimensional or three-dimensional seismic data according to the depth position of a reflecting layer of Vertical Seismic Profile (VSP) data in a well, and calibrating each seismic geological reflecting layer of the ground two-dimensional or three-dimensional seismic data;
(5) processing seismic data of a Zero Offset vertical seismic profile (Zero Offset VSP) in a well, and calculating a stratum absorption attenuation parameter Q by using a continuous spectral ratio slope method, an energy spectrum centroid frequency shift method, a peak frequency method or an attenuation travel time chromatography method according to the attenuation characteristic of the amplitude of a descending direct wave from the well head to the well bottom:
for example, the absorption attenuation Q factor of the stratum is solved by using the absorption attenuation rule of the zero offset VSP data, and the energy attenuation generated by the earth absorption attenuation is compensated.
Assuming that the amplitude spectrum of the seismic signal decays exponentially over time, one of the calculations to find the quality factor Q is given as follows:
wherein: a is1(f) -an amplitude spectrum within a reference time window; a is2(f) -amplitude spectra within a sliding time window;
is obtained by the formula:
wherein f represents the frequency of the signal, and tau represents the direct wave travel time difference between two data (two-stage detectors);
(6) and establishing a well control velocity field for the two-dimensional or three-dimensional seismic data acquired on the ground according to a true amplitude recovery factor (Tar factor) extracted from the vertical seismic section data in the well, and performing amplitude recovery processing based on the velocity field.
The calculation formula of the true amplitude recovery factor is as follows:
when a wave impedance interface exists, the seismic wave energy also undergoes transmission loss, i.e. part of the energy is reflected back, so the total amplitude attenuation can be expressed by the following formula:
A＝A0ta
after logarithm taking:
lnA＝alnt+lnA0
here, the inverse number of α is a Tar (true amplitude recovery) factor, and a value of the Tar factor can be obtained by a linear fitting formula y ═ kx + b.
Tar＝-k
The Tar factor:
wherein: COEF (t) denotes the true amplitude recovery factor, v0Is the velocity initial value or water layer velocity, v is the root mean square velocity, t is the sampling point time (ms);
(7) performing deconvolution processing on ground acquired two-dimensional or three-dimensional seismic data according to deconvolution parameters extracted from vertical seismic profile data in a well;
(8) performing velocity, anisotropic two-dimensional or three-dimensional parameter joint modeling of each well flooding parameter constraint based on Vertical Seismic Profile (VSP) data extraction in a well;
(9) performing resolution-improving processing on well control ground two-dimensional or three-dimensional seismic data by using various well flooding parameters extracted from vertical seismic profile data in a well;
(10) performing anisotropic migration processing on two-dimensional or three-dimensional seismic data acquired on the ground according to the anisotropy parameters eta, delta and epsilon of the underground stratum accurately calculated and extracted in the step (3);
the calculation formula of the anisotropic parameter is as follows:
the non-hyperbolic approximate time distance formula under any anisotropic strength is expressed as follows:
wherein: eta is an anisotropic parameter for prestack time bias, t is a two-way travel, x is offset distance of shot-geophone points, and VnmoFor NMO speed, t0When the double-pass is zero-offset,
called the non-elliptical anisotropy coefficient or non-ellipticity, epsilon, delta are the anisotropy parameters used for prestack depth migration. And can derive:
v is obtained by Taylor seriesnmo≈α0(1+δ)。
Wherein: alpha is alpha0Satisfactory results can be obtained using this equation for the P-wave velocity, with kinetic correction or pre-stack time migration.
Therefore, whether the accurate non-elliptical anisotropy coefficient eta can be obtained is a key and precondition for processing the anisotropic seismic data.
Through VSP data, accurate eta values can be obtained through scanning and used for non-hyperbolic correction and pre-stack time migration imaging. First, scan V using the above formulanmoBecause of t0Can be obtained by zero well source spacing VSP, x is known for offset. A set of eta is given, for each depth point, a theoretical t value at different offset distances under each eta is calculated, the theoretical t is compared with the first arrival time observed by the actual 3D-VSP, and when the error is minimum, the eta is givenThe value is obtained.
For the prestack depth migration of VTI (vertical Transverse Isotropy) media, Thomsen anisotropy coefficients epsilon and delta are needed, and the accuracy of the epsilon and delta calculation is related to the precision of prestack depth migration imaging.
The exact values of ε and δ are obtained by a Thomsen method of anisotropy coefficient scanning, similar to the η value scanning. The accurate delta value is obtained by means of time difference scanning. Using the formula:
vqP(θ)＝α0(1+δsin2θcos2θ+εsin4θ)
vqPand (3) obtaining an accurate epsilon value in a time difference scanning mode for the anisotropic velocity and theta for the phase angle. After epsilon and delta are obtained, an accurate VTI model can be established for prestack depth migration imaging.
(11) Performing Q compensation or Q migration processing on pre-stack gather data on the two-dimensional or three-dimensional seismic data acquired on the ground according to the stratum absorption attenuation parameter Q extracted in the step (5);
(12) comparing the interval velocity of longitudinal wave and transverse wave of each stratum obtained from zero-offset VSP data with the interval velocity of longitudinal wave and transverse wave of each stratum measured by an acoustic logging instrument, wherein the corresponding difference of the longitudinal wave and transverse wave velocities is caused by the difference between VSP data frequency (low frequency) and acoustic logging data frequency (high frequency), so that the frequency dispersion effect of the longitudinal wave and transverse wave velocities of each stratum in the well can be calculated, and the method can be used as a tool for describing reservoir rock and fluid characteristics.
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 (1)
1. The method for acquiring and processing the logging VSP composite data based on the optical fiber sensing is characterized in that a logging VSP composite data acquisition system based on the optical fiber sensing is adopted, and the logging VSP composite data acquisition system based on the optical fiber sensing comprises the following steps: the system comprises a ground artificial seismic source, a distributed optical fiber sensing armored photoelectric composite cable arranged in a full well section well, a logging instrument, a logging truck near a ground wellhead and a distributed optical fiber sensing modulation and demodulation instrument arranged in the logging truck, wherein the head end of the distributed optical fiber sensing armored photoelectric composite cable is connected with the logging truck near the ground wellhead, the tail end of the distributed optical fiber sensing armored photoelectric composite cable is connected with the logging instrument, and the logging truck near the ground wellhead, the distributed optical fiber sensing armored photoelectric composite cable and the logging instrument are used for collecting vertical seismic profile data and logging data in the same well in one-time;
the method comprises the following steps:
(1) connecting a distributed optical fiber sensing armored photoelectric composite cable on a logging truck with a logging instrument going down a well near a well head, and connecting various optical fibers at the head end of the distributed optical fiber sensing armored photoelectric composite cable with various optical fiber modulation and demodulation instruments in the logging truck; the high-temperature-resistant and hydrogen-loss-resistant single-mode optical fiber with the tail end provided with the delusters is connected with the signal input end of the distributed optical fiber sound wave sensing modulation and demodulation instrument, and the two high-temperature-resistant and hydrogen-loss-resistant multimode with the tail ends welded into a U shape are connected with the double-end signal input end of the distributed optical fiber temperature sensing modulation and demodulation instrument;
(2) laying a ground artificial seismic source at each position of the ground artificial seismic source for acquiring vertical seismic section data in the well; meanwhile, establishing a connection with a distributed optical fiber acoustic wave sensing modulation and demodulation instrument in the logging truck in a wired or wireless mode, and triggering the distributed optical fiber acoustic wave sensing modulation and demodulation instrument by using an excitation signal of a ground artificial seismic source to synchronously trigger and start the distributed optical fiber acoustic wave sensing modulation and demodulation instrument to start data acquisition when the ground artificial seismic source is excited;
(3) slowly lowering a logging instrument to the bottom of the well through a pulley on a derrick above the well mouth or on a crane through a distributed optical fiber sensing armored photoelectric composite cable;
(4) the logging instrument is put down to the bottom of the well and stops for a moment, after the logging instrument is stable and static, ground artificial seismic sources which are distributed on the ground in advance are rapidly and sequentially excited immediately, an excitation signal of each ground artificial seismic source is synchronously transmitted to an external trigger signal input end of a distributed optical fiber acoustic wave sensing modulation and demodulation instrument in a logging truck in a wired or wireless mode, and the distributed optical fiber acoustic wave sensing modulation and demodulation instrument is triggered and started to synchronously acquire zero offset or non-zero offset or Walkerround vertical seismic section namely VSP data in a whole well section which is excited by the ground artificial seismic sources; the method comprises the steps that a distributed optical fiber temperature sensing modulation and demodulation instrument in a logging truck is started while vertical seismic section data are collected, and real-time temperature distribution data and temperature gradient data of a whole well section are collected synchronously; meanwhile, starting a distributed optical fiber pressure sensing modulation and demodulation instrument in the logging truck, and synchronously acquiring real-time pressure distribution data of the whole well section;
(5) after the vertical seismic profile data acquisition is finished, the logging truck immediately starts to slowly lift up the logging instrument, and open hole cable logging data of the whole well section or a pre-designed well section or production logging data in a cased well or an oil pipe are acquired; after the acquisition of the logging data is finished, the logging instrument is lifted out of a wellhead, the logging truck is moved to the next well site to be logged, and the steps (1) to (5) are repeated to sequentially acquire vertical seismic profile data and conventional logging data of the lower well;
(6) respectively calculating and solving accurate average longitudinal wave and transverse wave velocity values of an underground medium and longitudinal wave and transverse wave layer velocity values of each stratum according to the initial arrival travel time of longitudinal waves and transverse waves of zero-deviation vertical seismic section data collected in a well and the distance from a ground artificial seismic source point near a well head to each detection point on an underground distributed optical fiber sensing armored photoelectric composite cable;
(7) according to the initial travel time of longitudinal waves and transverse waves of non-zero-deviation vertical seismic profile data or Walkeround VSP data acquired in a well and the distance from a non-zero-deviation ground artificial vibration source point or a Walkeround VSP ground artificial vibration source point to each detection point on the underground distributed optical fiber sensing armored photoelectric composite cable, calculating and solving accurate average longitudinal wave and transverse wave speed values of an underground medium in different directions and longitudinal wave and transverse wave layer speed values of each stratum in different directions respectively;
(8) by utilizing multi-azimuth non-zero offset VSP data or Walkeround VSP data in the well, according to the step (7), obtaining accurate average longitudinal wave and transverse wave speed values of the underground medium in different azimuths and longitudinal wave and transverse wave interval speed values of each stratum in different azimuths, and respectively calculating the anisotropic parameters of the longitudinal wave and transverse wave speeds of the underground stratum;
(9) removing multiples in the ground two-dimensional or three-dimensional seismic data according to the depth position of a reflecting layer of the vertical seismic section data in the well, and calibrating each seismic geological reflecting layer of the ground two-dimensional or three-dimensional seismic data;
(10) processing seismic data of a zero-deviation vertical seismic section in a well, and calculating a stratum absorption attenuation parameter Q by using a continuous spectrum ratio slope method, an energy spectrum centroid frequency shift method, a peak frequency method or an attenuation travel-time chromatography method according to the attenuation characteristic of the amplitude of a downlink direct wave from the well head to the well bottom;
(11) establishing a well control velocity field for two-dimensional or three-dimensional seismic data acquired on the ground according to a true amplitude recovery factor extracted from vertical seismic profile data in a well, and performing amplitude recovery processing based on the velocity field; the calculation formula of the true amplitude recovery factor is as follows:
where COEF (t) represents the true amplitude recovery factor, v0Is the initial velocity or water layer velocity, v is the root mean square velocity, t is the sampling point time;
(12) performing deconvolution processing on ground acquired two-dimensional or three-dimensional seismic data according to deconvolution parameters extracted from vertical seismic profile data in a well;
(13) performing velocity and anisotropic two-dimensional or three-dimensional parameter combined modeling of each well flooding parameter constraint extracted based on vertical seismic profile data in a well;
(14) performing resolution-improving processing on well control ground two-dimensional or three-dimensional seismic data by using various well flooding parameters extracted from vertical seismic profile data in a well;
(15) performing anisotropic migration processing on the two-dimensional or three-dimensional seismic data acquired on the ground according to the anisotropic parameters of the underground stratum accurately calculated and extracted in the step (8);
(16) performing Q compensation or Q migration processing on pre-stack gather data on the two-dimensional or three-dimensional seismic data acquired on the ground according to the stratum absorption attenuation parameter Q extracted in the step (10);
(17) comparing the layer velocity of longitudinal waves and transverse waves of each stratum obtained from zero-offset VSP data with the layer velocity of the longitudinal waves and transverse waves of each stratum measured by an acoustic logging instrument, wherein the corresponding difference of the longitudinal wave velocity and the transverse wave velocity is caused by the difference of the VSP data frequency and the acoustic logging data frequency, and thus, the frequency dispersion effect of the longitudinal wave velocity and the transverse wave velocity of each stratum in the well can be calculated.
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