Oil production well liquid production profile and dipole sound wave integrated test system

Abstract

The invention relates to the technical field of oil and gas well oil testing and production testing, in particular to an oil producing well liquid producing profile and dipole sound wave integrated testing system which comprises the following steps that firstly, testing pipe columns are installed together, the test tubular column comprises a multi-core cable, and a coiled tubing, an array probe output profile logging instrument, a centralizer, a headstall and a dipole acoustic logging instrument which are sequentially connected together from top to bottom, and the lower end of the multi-core cable penetrates through the coiled tubing and then is connected with the array probe output profile logging instrument and the dipole acoustic logging instrument; step 2, cleaning the shaft; according to the invention, the integrated monitoring of the liquid production profile and the dipole sound wave of the oil production well is realized, the tripping-in times of the coiled tubing are reduced, the problems of long construction period and high cost of respectively monitoring the liquid production profile of the oil well and detecting the dipole sound wave are solved, the two testing technologies are complementary, a reference is provided for evaluating the reservoir and fracturing effect and optimizing the fracturing scheme, and the working efficiency is improved. And the accuracy of reservoir dessert understanding and fracturing effect evaluation is improved.

Description

Technical Field

[0001] The invention relates to the technical field of oil and gas well oil testing and production testing, and is an integrated testing system for the production fluid profile of an oil producing well and dipole acoustic waves. Background Art

[0002] With the continuous deepening of domestic oil and gas exploration and development, the oil and gas reserves in low-permeability reservoirs account for more than two-thirds of the proven reserves. Low-permeability reservoirs generally have complex lithology and strong heterogeneity. After perforation, there is no natural production capacity. It is often necessary to transform the reservoir through fracturing technology to increase the connectivity and drainage area of ​​the reservoir, effectively expand the seepage channel, and increase production capacity. The quality of the fracturing results is directly related to the final oil and gas production effect. At the same time, due to the strong heterogeneity of the reservoir, the production capacity after staged fracturing is very different. It is urgent to understand the fracturing and seam formation under different fracturing processes and construction parameters, as well as the production capacity effects of each segment and cluster after fracturing, to provide an important basis for verifying the classification of sweet spot reservoirs and optimizing fracturing transformation plans.

[0003] The journal article titled Research on Interpretation Methods of Fluid Imaging Logging Data for Horizontal Wells in Offshore Oil Fields disclosed that by using a fluid scanning imaging FSI logging instrument that combines multiple micro-rotors and sensors, the stratified flow velocity and stratified phase retention rate of the wellbore can be measured, thereby realizing the monitoring of the multiphase flow production profile of the horizontal well.

[0004] The patent document with application number 201910644976.5 and titled "A method and device for evaluating the effect of hydraulic fracturing of formations" discloses: the method is to perform array acoustic logging within a depth interval, construct dipole acoustic logging data in different directions, filter and normalize the dipole acoustic logging data in different directions, calculate the energy envelope of scattered waves before and after fracturing, and use the difference in shear wave velocity and scattered wave energy of dipole acoustic logging before and after fracturing to jointly evaluate the fracturing effect around the wellbore. The advantage of this method is that it can evaluate the fracturing effect along the wellbore direction, and can also achieve the evaluation of the fracturing effect within a radial range of tens of meters around the wellbore.

[0005] The article titled Research on Evaluation Methods of Fracturing Effects in Low Permeability Reservoirs Based on Dipole Acoustic Logging Data disclosed that by comparing formation anisotropy before and after fracturing, the vertical extension height of the fractures and the complexity of fracture development can be accurately identified.

[0006] Dipole acoustic logging and production fluid profile monitoring are two testing methods that can evaluate reservoirs and fracturing effects from different angles. The two processes have their own advantages. Among them, for oil well production fluid profile testing, array multi-probe testing has obvious advantages over distributed fiber optic monitoring technology. Considering the testing cost, some oil wells are tested with array multi-probe testing, and some oil wells are tested with dipole acoustic logging. If the two testing processes are monitored at the same time, multiple trips are required, the testing cycle is long, and the cost is high. At present, the advantages of the two testing and evaluation processes have not been effectively complementary. There is an urgent need for an integrated testing system for oil well production fluid profiles and dipole acoustic waves to reduce the total testing cycle and cost of downhole production fluid profiles and dipole acoustic wave monitoring, comprehensively evaluate reservoirs and fracturing effects from different angles, and achieve accurate evaluation of reservoirs and fracturing effects. Summary of the invention

[0007] The present invention provides an integrated testing system for oil well production fluid profile and dipole acoustic wave, which overcomes the deficiencies of the above-mentioned prior art and can effectively solve the problems of long construction period and high cost in the prior art of separately monitoring oil well production fluid profile and detecting dipole acoustic wave.

[0008] The technical solution of the present invention is achieved by the following measures: an integrated testing system for oil well production fluid profile and dipole acoustic wave, comprising the following steps: Step 1, installing a test string together, wherein the test string includes a multi-core cable and a coiled tubing, an array probe production profile logging instrument, a centralizer, a bridle, and a dipole acoustic logging instrument that are sequentially connected from top to bottom, wherein the lower end of the multi-core cable passes through the coiled tubing and is respectively connected to the array probe production profile logging instrument and the dipole acoustic logging instrument; Step 2: Clean the wellbore, lower the test string into the well to a certain depth, and then test whether the dipole acoustic logging instrument is normal. If normal, continue to lower the test string; if not, take out the test string and check it; Step 3: lower the lower end of the test string to the bottom of the artificial well, pull up the test string at a uniform speed, and pull out the test string after the dipole sonic logging instrument monitors the formation anisotropy for the first time; Step 4: Fracturing the oil well in stages, draining the well after fracturing to test production; Step 5: Repeat step 2; Step 6: Lower the test string to the bottom of the artificial well again, perform dipole acoustic logging in the well-shut state, and pull up the test string at a uniform speed. The dipole acoustic logging instrument monitors the formation anisotropy for the second time. After the perforation and fracturing section monitoring is completed, the test string is lowered to the bottom of the artificial well again. Step 7: Start production. After the production and oil and water content are stable, pull up the test string at a uniform speed. The array probe production profile logging instrument monitors in real time and determines whether the array probe production profile logging instrument is working properly. After the perforation and fracturing section measurement is completed, lower the test string to the bottom of the artificial well. According to the working condition of the array probe production profile logging instrument last time, determine the lifting speed this time. Pull up the test string at a uniform speed, monitor the working condition of the array probe production profile logging instrument in real time, and after recording qualified production profile data, pull out the test string; Step eight, based on the first monitoring of formation anisotropy by the dipole sonic logging instrument and the second monitoring of formation anisotropy by the dipole sonic logging instrument, each perforation cluster is evaluated, and the evaluation results are used as auxiliary data to obtain the interpretation results of the fluid production profile.

[0009] The following are further optimizations and / or improvements to the above technical solutions: In the above step 1, the multi-core cable is a 7-core cable, 3 cable cores of the multi-core cable are connected to the array probe production profile logging instrument, and 2 cable cores are connected to the dipole acoustic wave logging instrument; the array probe production profile logging instrument is equipped with a turbine speed probe, a density probe and a water holding probe.

[0010] The above-mentioned step seven is to start the well production, and after the production and oil and water are stable, pull up the test string at a uniform speed, monitor the working conditions of the turbine speed probe, density probe and water holding probe of the array probe production profile logging instrument in real time through the array probe production profile logging instrument, and collect the production liquid profile data, the production liquid profile data includes turbine speed, fluid density and water holding rate, after the perforation and fracturing section measurement is completed, lower the test string to the bottom of the artificial well, determine the lifting speed this time according to the working conditions of the turbine speed probe, density probe and water holding probe last time, pull up the test string at a uniform speed, monitor the working conditions of the turbine speed probe, density probe and water holding probe of the array probe production profile logging instrument in real time again through the array probe production profile logging instrument, collect the production liquid profile data, and after recording the qualified production liquid profile data, pull out the test string.

[0011] In the above step eight, the fracturing initiation, fracture height and degree of development of the hydraulic fracturing network of each perforation cluster are evaluated based on the first monitoring of formation anisotropy by the dipole sonic logging instrument and the second monitoring of formation anisotropy by the dipole sonic logging instrument.

[0012] In the above step 2, after the test string is lowered into the well for 500 meters, the dipole sonic logging instrument is tested to see whether it is normal.

[0013] The speed of lifting the test pipe string in the above step 6 is the same as the speed of uniformly lifting the test pipe string in step 3.

[0014] The present invention realizes the integrated monitoring of the production profile of oil wells and dipole acoustic waves, reduces the number of times the coiled tubing is lowered, and solves the problem of long construction period and high cost for separate monitoring of the production profile of oil wells and detection of dipole acoustic waves. The two testing technologies complement each other, provide a reference for reservoir and fracturing effect evaluation and optimization of fracturing schemes, and improve the accuracy of reservoir sweet spot recognition and fracturing effect evaluation. BRIEF DESCRIPTION OF THE DRAWINGS

[0015] Attached Figure 1 It is a schematic diagram of the front cross-sectional structure of the first embodiment.

[0016] The codes in the attached drawings are: 1 is a coiled tubing, 2 is an array probe production profile logging tool, 3 is a centralizer, 4 is a bridle, 5 is a dipole sonic logging tool, and 6 is a multi-core cable. DETAILED DESCRIPTION

[0017] The present invention is not limited by the following embodiments, and specific implementation methods can be determined based on the technical solution of the present invention and actual conditions.

[0018] In the present invention, for the convenience of description, the relative position relationship of each component is described according to the attached Figure 1 The positional relationships such as front, back, top, bottom, left, and right are described according to the layout directions of the drawings in the specification.

[0019] The present invention will be further described below in conjunction with embodiments and drawings: Embodiment 1: As shown in the attached Figure 1 As shown, the integrated test system for oil well production fluid profile and dipole acoustic wave includes the following steps: Step 1: Install the test string together, the test string includes a multi-core cable 6 and a coiled tubing 1, an array probe production profile logging instrument 2, a centralizer 3, a bridle 4 and a dipole acoustic logging instrument 5 which are sequentially connected from top to bottom, and the lower end of the multi-core cable 6 passes through the coiled tubing and is respectively connected to the array probe production profile logging instrument 2 and the dipole acoustic logging instrument 5; Step 2: Clean the wellbore, lower the test string into the well to a certain depth, and then test whether the dipole acoustic logging instrument 5 is normal. If normal, continue to lower the test string; if not, take out the test string and check it; Step 3: lower the lower end of the test string to the bottom of the artificial well, and pull up the test string at a uniform speed. After the dipole sonic logging instrument 5 monitors the formation anisotropy for the first time, pull out the test string; Step 4: Fracturing the oil well in stages, draining the well after fracturing to test production; Step 5: Repeat step 2; Step 6: Lower the test string to the bottom of the artificial well again, perform dipole acoustic logging in the well-shut state, and pull up the test string at a uniform speed. The dipole acoustic logging instrument 5 monitors the formation anisotropy for the second time. After the perforation and fracturing section monitoring is completed, the test string is lowered to the bottom of the artificial well again; Step 7: Start production, and after the production and oil and water are stable, pull up the test string at a uniform speed, and the array probe production profile logging instrument 2 monitors in real time and determines whether the array probe production profile logging instrument 2 is working normally. After the perforation and fracturing section measurement is completed, lower the test string to the bottom of the artificial well, and determine the lifting speed this time according to the last working condition of the array probe production profile logging instrument 2. Pull up the test string at a uniform speed, monitor the working condition of the array probe production profile logging instrument 2 in real time, and after recording qualified production liquid profile data, pull out the test string; Step eight, based on the first monitoring of formation anisotropy by the dipole acoustic logging instrument 5 and the second monitoring of formation anisotropy by the dipole acoustic logging instrument 5, each perforation cluster is evaluated, and the evaluation results are used as auxiliary data to obtain the interpretation results of the liquid production profile.

[0020] The present invention realizes the integrated monitoring of the production profile of oil wells and dipole acoustic waves, reduces the number of trips of coiled tubing, solves the problem of long construction period and high cost for separate monitoring of the production profile of oil wells and dipole acoustic wave detection, makes the two testing technologies complementary, provides a reference for reservoir and fracturing effect evaluation and fracturing scheme optimization, and improves the accuracy of reservoir sweet spot recognition and fracturing effect evaluation.

[0021] The above-mentioned oil well production fluid profile and dipole acoustic wave integrated test system can be further optimized and / or improved according to actual needs: Embodiment 2: As an optimization of the above embodiment, in step 1, the multi-core cable 6 is a 7-core cable, 3 cable cores of the multi-core cable 6 are connected to the array probe production profile logging instrument 2, and 2 cable cores are connected to the dipole acoustic logging instrument 5; the array probe production profile logging instrument 2 is provided with a turbine speed probe, a density probe and a water holding probe. The remaining 2 cores of the multi-core cable 6 are reserved. In this way, multiple parameters of the horizontal well can be measured.

[0022] Embodiment 3: As an optimization of the above embodiment, step 7 is to start production, and after the production and oil and water are stable, the test string is lifted at a uniform speed, and the array probe production profile logging instrument 2 is used to determine in real time whether the turbine speed probe, density probe and water holding probe of the array probe production profile logging instrument 2 are working properly and collect the production liquid profile data, which includes the turbine speed, fluid density and water holding rate. After the perforation and fracturing section measurement is completed, the test string is lowered to the bottom of the artificial well, and the lifting speed is determined according to the working conditions of the turbine speed probe, density probe and water holding probe last time, and the test string is lifted at a uniform speed, and the array probe production profile logging instrument 2 is used again to determine in real time whether the turbine speed probe, density probe and water holding probe of the array probe production profile logging instrument 2 are working properly and collect the production liquid profile data. After the qualified production liquid profile data is recorded, the test string is lifted. In this way, the turbine speed, fluid density and water holding rate can be displayed in real time by the ground equipment, which is convenient for the ground equipment to analyze the data and the characteristics of the horizontal well fracturing section in real time.

[0023] Embodiment 4: As an optimization of the above embodiment, in step 8, the fracturing situation, fracture height and development degree of the hydraulic fracture network of each perforation cluster are evaluated based on the first monitoring of the formation anisotropy by the dipole acoustic logging instrument 5 and the second monitoring of the formation anisotropy by the dipole acoustic logging instrument 5. This can reflect the reservoir physical properties and hydraulic fracture characteristics of the horizontal well.

[0024] Embodiment 5: As an optimization of the above embodiment, as shown in the attached Figure 1 As shown, in step 2, after the test string is lowered into the well for 500 meters, the dipole acoustic logging instrument 5 is tested to see if it is normal. In this way, the fault of the dipole acoustic logging instrument 5 can be discovered in time to avoid the occurrence of faults during the test process.

[0025] Embodiment 6: As an optimization of the above embodiment, the speed of lifting the test string in step 6 is the same as the speed of uniformly lifting the test string in step 3. This can ensure that the base of the data collected by the dipole acoustic logging instrument 5 for the second monitoring of formation anisotropy is consistent with that of the data collected by the dipole acoustic logging instrument 5 for the first monitoring of formation anisotropy, which is convenient for comparison of subsequent data information and can also improve test efficiency.

[0026] The specific process of the oil well production fluid profile and dipole acoustic wave integrated testing system of the present invention is as follows: The first step is to assemble a 2-inch 6500-meter-long coiled tubing 1 with a multi-core cable 6, and the lower part of the coiled tubing 1 is connected in sequence to the array probe production profile logging instrument 2, the centralizer 3, the bridle 4 and the dipole acoustic logging instrument 5, and the multi-core cable 6 is connected to the dipole acoustic logging instrument 5, and then powered on for testing to ensure that the dipole acoustic logging instrument 5 works normally; Step 2: Horizontal well H6023, with a vertical depth of 4,200 meters and a horizontal section length of 1,500 meters, clean the wellbore before fracturing, and lower the test string into the well. After 500 meters into the well, test the dipole sonic logging instrument 5 to work normally and then continue to lower the test string; The third step is to lower the test string to the bottom of the artificial well at 5700 meters, and then pull up the test string at a uniform speed of 6 meters per minute. The dipole sonic logging instrument 5 monitors the formation anisotropy for the first time. After the horizontal section monitoring is completed, the test string is pulled out. The fourth step is to perform 30-stage fracturing on the horizontal well H6023, and then drain the fluid for trial production after fracturing; Step 5: Drill the fracturing bridge plug in the wellbore, clean the sand and debris in the horizontal well H6023 and shut in the well, connect the No. 1, 2, and 3 cable cores of the multi-core cable 6 to the array probe output profile logging instrument 2, connect the No. 4 and 5 cable cores of the multi-core cable 6 to the dipole acoustic logging instrument 5, and keep the remaining No. 6 and 7 cable cores of the multi-core cable 6 for backup. When the test string is 500 meters into the well, test the array probe output profile logging instrument 2 and the dipole acoustic logging instrument 5 and continue to run them in normally; Step 6: Lower the test string to 5700 meters below the bottom of the artificial well again, perform dipole acoustic logging in the well-shut state, and pull up the test string at a uniform speed of 6 meters per minute. The dipole acoustic logging instrument 5 monitors the formation anisotropy for the second time. After the perforation and fracturing section monitoring is completed, the test string is lowered to 5700 meters below the bottom of the artificial well again. The seventh step is to start production. After the production and oil and water are stable, the test string is lifted at a uniform speed of 10 meters per minute to conduct a production profile test. When the test string is lifted to the 15th stage of fracturing, the real-time data of the ground equipment shows that the turbine speed is abnormally low, and the density probe and the water holding probe are working normally. When the test string is lifted to the 17th stage of fracturing, the turbine speed is normal. There may be foreign matter stuck in the turbine in the early stage. After the horizontal section measurement is completed, the test string is lowered to the toe of the horizontal well, and the test string is lifted at a uniform speed of 15 meters per minute. The turbine speed probe, density probe and water holding probe of the array probe production profile logging instrument 2 are working normally. After recording the qualified production profile data, the ground equipment and the multi-core cable 6 are disconnected and the test string is lifted out; Step 8: Analyze the anisotropy of the formation before and after fracturing based on dipole acoustic logging data; At fracturing levels 7, 12, 14, and 24, the formation anisotropy before and after fracturing is basically the same (the formation anisotropy of the first monitoring is basically the same as the formation anisotropy of the second monitoring), and the evaluation fracture is not opened; At levels 1, 3, 10, 20, 27, and 28, the formation anisotropy before and after fracturing is greatly different (the formation anisotropy during the first monitoring and the formation anisotropy during the second monitoring are greatly different), and the fracture network is well developed; According to the monitoring data of the liquid production profile, the 1st, 3rd, 10th, 20th, 27th and 28th levels are the main contribution sections of liquid production, corresponding to the development sections of the hydraulic fracture network, and also corresponding to the sweet spots of logging and well logging evaluation, reflecting the characteristics that the better the reservoir physical properties, the more developed the hydraulic fractures, and the better the production capacity; The contribution rate of the 12th level of the production profile interpretation is moderate, but the fractures are not developed in the dipole acoustic interpretation, and the physical properties and oil content of this section are poor according to the logging and well logging evaluation. Combined with the dipole acoustic test and logging data, it is believed that there may be errors in the interpretation of the 12th level production profile, and a secondary analysis and interpretation should be conducted; Through the test of this well, it is believed that the classification of reservoir sweet spots by logging and well logging data is accurate. When drilling new wells in the next step, the evaluation criteria of sweet spots should be followed when drilling in geological guidance. When designing a fracturing scheme, the concept of creating complex fractures should be used to arrange the fractures, while optimizing the spacing between fracturing sections and increasing the density of the fracture network in the horizontal section.

[0027] The above technical features constitute the embodiments of the present invention, which have strong adaptability and implementation effect. Non-essential technical features can be added or reduced according to actual needs to meet the requirements of different situations.

Claims

1. An integrated test system for oil well production fluid profile and dipole acoustic wave, characterized in that The steps include: Step 1, installing a test string together, wherein the test string includes a multi-core cable and a coiled tubing, an array probe production profile logging instrument, a centralizer, a bridle, and a dipole acoustic logging instrument that are sequentially connected from top to bottom, wherein the lower end of the multi-core cable passes through the coiled tubing and is respectively connected to the array probe production profile logging instrument and the dipole acoustic logging instrument; Step 2: Clean the wellbore, lower the test string into the well to a certain depth, and then test whether the dipole acoustic logging instrument is normal. If normal, continue to lower the test string; if not, take out the test string and check it; Step 3: lower the lower end of the test string to the bottom of the artificial well, pull up the test string at a uniform speed, and pull out the test string after the dipole sonic logging instrument monitors the formation anisotropy for the first time; Step 4: Fracturing the oil well in stages, draining the well after fracturing to test production; Step 5: Repeat step 2; Step 6: Lower the test string to the bottom of the artificial well again, perform dipole acoustic logging in the well-shut state, and pull up the test string at a uniform speed. The dipole acoustic logging instrument monitors the formation anisotropy for the second time. After the perforation and fracturing section monitoring is completed, the test string is lowered to the bottom of the artificial well again. Step 7: Start production. After the production and oil and water content are stable, pull up the test string at a uniform speed. The array probe production profile logging instrument monitors in real time and determines whether the array probe production profile logging instrument is working properly. After the perforation and fracturing section measurement is completed, lower the test string to the bottom of the artificial well. According to the working condition of the array probe production profile logging instrument last time, determine the lifting speed this time. Pull up the test string at a uniform speed, monitor the working condition of the array probe production profile logging instrument in real time, and after recording qualified production profile data, pull out the test string; Step eight, based on the first monitoring of formation anisotropy by the dipole sonic logging instrument and the second monitoring of formation anisotropy by the dipole sonic logging instrument, each perforation cluster is evaluated, and the evaluation results are used as auxiliary data to obtain the interpretation results of the fluid production profile.

2. The oil well production fluid profile and dipole acoustic wave integrated testing system according to claim 1, characterized in that In step one, the multi-core cable is a 7-core cable, 3 cable cores of the multi-core cable are connected to the array probe production profile logging instrument, and 2 cable cores are connected to the dipole acoustic wave logging instrument; the array probe production profile logging instrument is equipped with a turbine speed probe, a density probe and a water holding probe.

3. The oil well production fluid profile and dipole acoustic wave integrated testing system according to claim 2, characterized in that Step seven is to start production at the well. After the production and oil and water content are stable, the test string is pulled up at a uniform speed. The working conditions of the turbine speed probe, density probe and water holding probe of the array probe production profile logging instrument are monitored in real time through the array probe production profile logging instrument, and the production liquid profile data are collected. The production liquid profile data include turbine speed, fluid density and water holding rate. After the perforation and fracturing section measurement is completed, the test string is lowered to the bottom of the artificial well. The lifting speed this time is determined according to the working conditions of the turbine speed probe, density probe and water holding probe last time. The test string is pulled up at a uniform speed, and the working conditions of the turbine speed probe, density probe and water holding probe of the array probe production profile logging instrument are monitored in real time again through the array probe production profile logging instrument, and the production liquid profile data are collected. After the qualified production liquid profile data is recorded, the test string is pulled up.

4. The oil well production fluid profile and dipole acoustic wave integrated testing system according to claim 3, characterized in that In step eight, the fracturing initiation, fracture height and development degree of the hydraulic fracturing network of each perforation cluster are evaluated based on the first monitoring of formation anisotropy by the dipole sonic logging instrument and the second monitoring of formation anisotropy by the dipole sonic logging instrument.

5. The oil well production fluid profile and dipole acoustic wave integrated testing system according to claim 1, 2, 3 or 4, characterized in that In step 2, the test string is lowered into the well for 500 meters to test whether the dipole sonic logging instrument is normal.

6. The oil well production fluid profile and dipole acoustic wave integrated testing system according to claim 1, 2, 3 or 4, characterized in that The speed of lifting the test pipe string in step 6 is the same as the speed of uniformly lifting the test pipe string in step 3.

7. The oil well production fluid profile and dipole acoustic wave integrated testing system according to claim 5, characterized in that The speed of lifting the test pipe string in step 6 is the same as the speed of uniformly lifting the test pipe string in step 3.

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