CN114876452A - Logging equipment calibration method and logging equipment calibration system - Google Patents
Logging equipment calibration method and logging equipment calibration system Download PDFInfo
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- CN114876452A CN114876452A CN202210520411.8A CN202210520411A CN114876452A CN 114876452 A CN114876452 A CN 114876452A CN 202210520411 A CN202210520411 A CN 202210520411A CN 114876452 A CN114876452 A CN 114876452A
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- 238000000034 method Methods 0.000 title claims abstract description 24
- 239000007788 liquid Substances 0.000 claims abstract description 158
- 238000012360 testing method Methods 0.000 claims abstract description 128
- 239000000523 sample Substances 0.000 claims abstract description 22
- 238000012795 verification Methods 0.000 claims abstract description 14
- 238000001514 detection method Methods 0.000 claims description 23
- 239000012530 fluid Substances 0.000 claims description 12
- 230000015572 biosynthetic process Effects 0.000 claims description 6
- 238000002347 injection Methods 0.000 claims description 5
- 239000007924 injection Substances 0.000 claims description 5
- 239000003129 oil well Substances 0.000 claims description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 5
- 238000007599 discharging Methods 0.000 claims description 4
- 239000011435 rock Substances 0.000 claims description 4
- 238000007789 sealing Methods 0.000 claims description 4
- 238000006243 chemical reaction Methods 0.000 claims description 3
- 238000010586 diagram Methods 0.000 description 4
- 238000011156 evaluation Methods 0.000 description 4
- 239000003921 oil Substances 0.000 description 4
- 238000004088 simulation Methods 0.000 description 3
- 238000011161 development Methods 0.000 description 2
- 230000000149 penetrating effect Effects 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000001802 infusion Methods 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 210000001503 joint Anatomy 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/005—Testing the nature of borehole walls or the formation by using drilling mud or cutting data
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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Abstract
The invention discloses a logging equipment checking method and a logging equipment checking system, wherein the logging equipment checking method comprises the following steps of: s1, placing the core to be tested in a test box body; s2, filling liquid into the test chamber; s3, inflating and pressurizing the test box body to a preset pressure to enable liquid in the box body to penetrate through the core to be tested and be discharged out of the test box body; s4, collecting the discharged liquid, and calculating to obtain the fluidity of the core to be measured; s5, placing the logging equipment at a liquid discharge port of the test box, repeating the steps S2-S3, and obtaining the fluidity of the core to be detected, which is detected on the logging equipment; s6, comparing the fluidity of the core to be tested obtained in the step S5 with the fluidity of the core to be tested obtained in the step S4; and S7, adjusting the correlation coefficient of the probe of the logging device according to the comparison result until the fluidity of the core to be measured by the logging device is consistent with the fluidity of the core to be measured in the step S4. The invention can realize data reliability verification and error value adjustment of the fluidity parameter acquired by the logging equipment.
Description
Technical Field
The invention relates to the technical field of logging equipment calibration, in particular to a logging equipment calibration method and a logging equipment calibration system.
Background
In the oil and gas exploration process, two parameters of formation pressure and mobility are important for reservoir evaluation, and in most of the existing cases, the two parameters are obtained by logging in an underground open hole section by using logging equipment. The setting areas and pumping modes of the logging equipment of different manufacturers are often different, so that the data read by different logging equipment in the same well and the same test point are often different, especially in a tight stratum, the mobility values read by different types of logging equipment may differ by several times to tens of times, which brings great trouble to reservoir evaluation, and therefore, a method and a system for verifying the logging equipment on the ground are necessary to be designed to solve the technical problem that the pressure and mobility parameters acquired by the logging equipment cannot be verified in data reliability.
In the prior art, some stratum pressure simulation systems exist, stratum and stratum pressures of rock cores with different lithologies are simulated indoors, ground tests and simulation tests in the development process of logging equipment are achieved, and accuracy and reliability of stratum pressure parameters obtained by the logging equipment can be verified.
However, the existing technology has technical defects and shortcomings of parameter checking unicity, and by using the existing formation pressure simulation system, data accuracy and reliability can only be checked on formation pressure parameters measured by logging equipment, so that the technical problem of data reliability checking on core mobility parameters cannot be solved.
Disclosure of Invention
The invention aims to provide a logging device calibration method and a logging device calibration system, so as to realize calibration of fluidity parameters obtained by logging devices.
The technical scheme adopted by the invention for solving the technical problems is as follows: a logging equipment calibration method is provided, and comprises the following steps:
s1, placing the core testing module with the core to be tested in a testing box body, and butting the core testing module on a liquid outlet of the testing box body;
s2, filling liquid into a liquid filling port of the test box body until the test box body is filled with the liquid;
s3, inflating and pressurizing the inflation inlet of the test box body to a preset pressure, driving liquid in the test box body to enter the core test module, penetrate through the core to be tested and be discharged from the liquid discharge port;
s4, collecting liquid seeped out from the liquid outlet, and calculating to obtain the fluidity of the core to be measured by combining the liquid seepage speed and the preset pressure;
s5, placing the logging equipment at a liquid discharge port of the test box, repeating the steps S2-S3, starting the logging equipment, and obtaining the fluidity of the core to be detected, which is obtained by the detection of the logging equipment;
s6, comparing the fluidity of the core to be tested obtained in the step S5 with the fluidity of the core to be tested obtained in the step S4;
and S7, adjusting the correlation coefficient of the logging equipment probe according to the comparison result until the mobility of the core to be detected, which is obtained by the detection of the logging equipment, is consistent with the mobility of the core to be detected, which is obtained in the step S4.
Preferably, step S4 includes the steps of:
s4.1, collecting liquid seeped out from the liquid outlet;
s4.2, recording the seepage time and the seepage amount of the collected liquid;
s4.3, calculating according to the following formula (I) to obtain the fluidity lambda of the core to be measured 1 ：
In the formula (I), lambda 1 The fluidity of the core to be detected is obtained; p1 is the predetermined pressure in MPa in step S3; 0.001 is a water column pressure conversion coefficient; h is the distance from the gas charging port to the core to be tested in the step S3 to the liquid dischargeThe vertical distance of one end in the outgoing direction is m; 0.101 is standard atmospheric pressure in MPa; t is the exudation time of the liquid in step S4.2, in units of S; s is the area of the cross section of the rock core to be measured and the unit is cm 2 (ii) a V is the amount of liquid exuded in step S4.2, in cm 3 (ii) a And L is the length of the core to be measured and is in cm.
Preferably, in step S1, a surface of the test box body is provided with a curved surface corresponding to an inner surface of an oil well, and the core testing module is positioned on an inner side of the curved surface in the test box body; the liquid discharge port is formed in the cambered surface;
and in the step S4.1, a drainage device is arranged outside the liquid outlet.
Preferably, in step S5, the logging device detects the obtained mobility λ of the core to be tested 2 Obtained by the following formula (II):
in the formula (II), λ 2 Detecting the obtained core fluidity to be detected for the logging equipment; c is the correlation coefficient of the probe used by the logging equipment at present; q is the volume of its pumped liquid read from the logging device in cm 3 (ii) a μ is the formation fluid viscosity, 1 under experimental conditions; Δ P is the pressure difference read from the logging tool as it draws fluid in MPa.
Preferably, in step S7, adjusting the logging device includes adjusting a probe correlation coefficient used by the logging device; step S7 includes the following steps:
s7.1, calculating and obtaining a target probe correlation coefficient C according to the following formula (III) o ：
In the formula (III), λ 1 Calculating the fluidity of the core to be measured obtained in the step S4.3; c is the correlation coefficient of the probe in the step 5；λ 2 Detecting the obtained core fluidity to be detected by the logging equipment in the step 5;
s7.2, adjusting the probe correlation coefficient of the logging equipment to be a target probe correlation coefficient C o ；
S7.3, repeating the steps S5-S6 for one or more times until lambda 2 ＝λ 1 。
Preferably, in step S2, the liquid filling unit is connected to the liquid filling port of the test tank;
the liquid filling unit comprises a liquid filling pump, a first connecting pipeline connected between the liquid filling pump and the liquid filling port, and a first pressure detection module connected to the first connecting pipeline; after the liquid injection pump is started, liquid is pumped into the liquid injection port through the first connecting pipeline until the test box body is filled with the liquid.
Preferably, in step S3, an inflation unit is connected to the inflation port of the test box;
the inflation unit comprises a gas compressor, a second connecting pipeline connected between the gas compressor and the inflation inlet, a gas storage tank, a second pressure detection module and a pressure regulation module;
the gas storage tank is arranged on the second connecting pipeline and stores the pressurized gas generated by the gas compressor and conveys the pressurized gas into the test box body through the second connecting pipeline; and the pressurized gas reaches a preset pressure through the cooperation of the second pressure detection module and the pressure regulation module.
The invention also provides a logging equipment calibration system; a logging tool verification method for use with any of the above; the well logging equipment calibration system comprises a closed test box body, a core test module for placing a core to be tested, a liquid filling unit and an air filling unit;
the test box body is respectively provided with a liquid charging port, a gas charging port and a liquid discharging port; the core testing module is arranged in the testing box body and is relatively communicated with the liquid outlet;
the liquid filling unit is connected with the liquid filling port and is used for filling liquid into the test box body;
the inflation unit is connected with the inflation inlet and used for inflating and pressurizing the test box body, driving liquid in the test box body to enter the core test module, and permeating the core to be tested to seep out from the liquid outlet.
Preferably, one surface of the test box body is provided with an arc surface corresponding to the inner surface of the oil well; the liquid discharge port is arranged on the cambered surface.
Preferably, the core testing module comprises a cylinder for placing a core to be tested, at least one sealing element and at least one supporting element;
the opposite two ends of the cylinder are open and are communicated with the test box body and the liquid outlet;
the supporting piece is arranged in one end of the cylinder body close to the liquid outlet and supports the core to be measured in the cylinder body;
the sealing element is arranged in the opposite other end of the cylinder body and seals a gap between the inner surface of the cylinder body and the core to be measured.
The invention has the beneficial effects that: the method is used for verifying the logging equipment on the ground, can carry out data reliability verification and error value adjustment on the mobility parameters acquired by the logging equipment, and provides objective and accurate evaluation data for oil field reservoir evaluation in the oil field exploration and development process.
Drawings
The invention will be further described with reference to the accompanying drawings and examples, in which:
FIG. 1 is a schematic diagram of a logging tool calibration system according to an embodiment of the present invention;
FIG. 2 is a schematic diagram of a combination of a test box and a core test module in a logging device calibration system according to an embodiment of the invention;
FIG. 3 is a front view of a test box configuration in a logging tool verification system in accordance with an embodiment of the present invention;
fig. 4 is an exploded schematic view of a core testing module in a logging device calibration system according to an embodiment of the present disclosure;
FIG. 5 is a block diagram of a core testing module of the logging device calibration system according to an embodiment of the present disclosure;
FIG. 6 is a schematic diagram of the operational status of logging devices in a logging device verification system according to an embodiment of the present invention.
Detailed Description
For a more clear understanding of the technical features, objects and effects of the present invention, embodiments of the present invention will now be described in detail with reference to the accompanying drawings.
As shown in fig. 1 to 3, a logging device calibration system according to an embodiment of the present invention includes a sealed test box 1, a core testing module 4 for placing a core 21 to be tested, a liquid filling unit 3, a pressure compensation unit 2 for increasing pressure to the test box 1, and a fluid discharge unit 14.
The core test module 4 is arranged inside the test box body 1. The pressure compensation unit 2, the liquid filling unit 3 and the fluid discharge unit 14 are respectively connected to the test tank 1. The liquid filling unit 3 is used for filling liquid such as water into the test box 1, so that the test box 1 is filled with the liquid. The pressure compensation unit 2 is used for filling gas into the test box body 1, increasing the internal pressure of the test box body 1, and enabling liquid to enter the core test module 4 and to be discharged out of the core test module 4 after penetrating through the core 21 to be tested. The fluid discharge unit 14 is used for discharging the fluid in the test tank 1.
Specifically, as shown in fig. 2 to 3, an arc surface 25 is provided on one surface of the test box 1, and the arc surface 25 is arranged corresponding to the inner surface of the oil well, so as to simulate the oil seepage surface of the oil well where the core is located in actual operation. The core testing module 4 is arranged on the inner side of the testing box body 1 and positioned on the cambered surface 25 of the testing box body, the cambered surface 25 is further provided with a liquid outlet 28, and the core testing module 4 is in butt joint with the liquid outlet 28, so that the liquid outlet 28 is communicated with the core testing module 4 relatively and is used for discharging liquid seeped from the core testing module 4.
For better collection of the liquid discharged from the liquid outlet 28, a drainage device can be arranged outside the liquid outlet 28 to avoid the liquid of the test box 1 from being shunted along the cambered surface 25. The drainage device may be a cylinder or the like disposed along the outer periphery of the liquid discharge port 28.
Corresponding to the connection between the liquid filling unit 3 and the pressure compensation unit 2, a liquid filling port 16 for accessing liquid and an inflation port 15 for accessing gas are arranged on the test box body 1, the liquid filling port 16 is connected with the liquid filling unit 3, and the inflation port 15 is connected with the pressure compensation unit 2.
As shown in FIGS. 2-3, the test chamber 1 further may include a chamber body 34 and a cover 26. One side of the box body 34 is opened to form an open side, and the cover body 26 can be opened, closed and sealed on the open side of the box body 34, so that the test box body 1 forms an openable and closable box body structure, and the openable and closable arrangement is convenient for taking and placing the core test module 4, cleaning the interior of the box body 34 and the like.
Alternatively, the cover 26 may be integrally provided separately from the case 34, and the cover 26 may be fastened to the case 34 by the latch 27 after the cover 26 is fitted to the open side of the case 34. Alternatively, the cover 26 may be hinged to the case 34 on one side so that the cover 26 can be rotated relative to the case 34 to open and close, and the opposite side of the cover 26 is detachably fastened to the case 34 by the latch 27. Alternatively, the cover 26 may be connected to the case 34 by interference fit, snap fit, or the like.
As shown in fig. 3-5, the core testing module 4 may include a barrel 23, at least one seal 20, and at least one support 22. The cylinder 23 is used for placing a core 21 to be tested, and opposite ends of the cylinder are open and are communicated with the test box body 1 and the liquid outlet 28. The liquid in the test box 1 can enter the core 21 to be tested from one open end of the cylinder 23 under the condition of pressure difference, and is discharged from the other opposite open end of the cylinder 23 and the liquid discharge port 28 in sequence after permeating through the core 21 to be tested.
The supporting piece 22 is arranged in one end of the cylinder 23 close to the liquid outlet 28, and supports the core 21 to be measured in the cylinder 23, so that the core 21 to be measured is prevented from falling off the cylinder 23. The sealing element 20 is arranged at the other end of the cylinder 23, seals a gap between the inner surface of the cylinder 23 and the core 21 to be tested, and prevents liquid in the test box 1 from passing through the gap between the cylinder 23 and the core 21 to be tested, so that subsequent calibration results are influenced.
Specifically, the cylinder 23 may be a steel cylinder, which may be, but is not limited to, a circular cylinder. In order to support and position the core 21 to be measured and not affect the discharge of the liquid after penetrating through the core 21 to be measured, the support member 22 includes at least one filter net, and the shape of the filter net can be set corresponding to the shape of the inner circumference of the cylinder 23. A protruding positioning step 24 is arranged in the cylinder 23, the support piece 22 is arranged on the positioning step 24, and the support piece 22 is limited in the cylinder 23 through the positioning step 24.
The positioning step 24 is a flange formed to extend horizontally from the inner surface of the lower end portion of the cylinder 23 toward the center of the cylinder. Alternatively, the positioning step 24 may be an annular flange or a plurality of spaced-apart block-shaped flanges, which may be used to support and position the core 21 to be measured. The supporting piece 22 is located between the core 21 to be measured and the positioning step 24, so that the core 21 to be measured can be prevented from being separated from the cylinder 23, and meanwhile, the interaction force generated when the core 21 to be measured is in direct contact with the positioning step 24 can be buffered.
In the present embodiment, as shown in fig. 1, the liquid charging unit 3 includes a liquid charging pump 10, a first connection line 32 connected between the liquid charging pump 10 and the liquid charging port 16, a first pressure detection module 12 provided on the first connection line 32, and a first on-off valve 11 provided on the first connection line 32.
Specifically, the first pressure detection module 12 may be a hydraulic gauge. The first switching valve 11 may be a ball valve. The infusion pump 10 can continuously infuse the test chamber 1 with liquid. Alternatively, the liquid injected into the test tank 1 by the liquid injection pump 10 may be water, slurry, crude oil, or the like. Specifically, the liquid enters the first connecting line 32, and the first switching valve 11 is connected after the liquid charge pump 10, which controls the liquid input into the first connecting line 32. A first pressure detection module 12 is arranged after the first on-off valve 11 for detecting the pressure of the liquid in the first connection line 32. The end of the first connecting pipeline 32 is provided with a hydraulic quick connector 29 which can be connected with a liquid filling port 16 reserved on the test box body 1, so that the liquid pumped into the first connecting pipeline 32 by the liquid filling pump 10 is transmitted into the test box body 1.
In this embodiment, as shown in fig. 1, the pressure compensation unit 2 includes a pressure input source, a second connection pipe 31 connected between the pressure input source and the test box 1, and a pressure adjustment system disposed on the second connection pipe 31. The pressure regulation system comprises a second on-off valve 7, a balancing valve 8 and a second pressure detection module 9.
Specifically, the second pressure detection module 9 may be a high-precision electronic display pressure gauge, the precision of which is required to be three decimal places, so as to ensure that the pressure of the pressurized gas input into the test box 1 is accurately controlled;
the pressure input sources include a gas compressor 5 and a gas tank 6. Gas compressor 5 squeezes compressed gas into gas holder 6, second ooff valve 7 is the control switch of gaseous input, the gaseous pressure size in the adjustable second connecting line 31 of balanced valve 8, the gaseous pressure size is read out through the figure that shows in the second pressure detection module 9 in the second connecting line 31, the end of second connecting line 31 is equipped with quick-operation joint 30, can be connected with the inflation inlet 15 of reserving on the experimental box 1, thereby transmit the compressed gas that gas compressor 5 produced to in the experimental box 1 through second connecting line 31.
In this embodiment, as shown in fig. 1, the fluid discharge unit 14 includes a third connection line 33, and a third on/off valve 13 connected to the third connection line 33, and liquid and gas in the test chamber body 1 can be discharged from the test chamber body 1 through the third connection line 33 from the fluid discharge port 17.
The method for verifying the logging equipment is used for verifying the logging equipment and can be realized by adopting the logging equipment verifying system. Referring to fig. 1-6, the verification method may include the steps of:
s1, placing the core testing module 4 with the core 21 to be tested in the test box 1, and butting the core testing module 4 on the liquid outlet 28 of the test box 1;
s2, filling liquid into the liquid filling port 16 of the test box body 1 until the test box body 1 is filled with the liquid;
specifically, the test chamber 1 can be filled with the filling liquid from the open side of the test chamber 1, and then the cover 26 is closed and locked, the test chamber 1 is connected to the liquid filling unit 3, the first switch valve 11 is opened, and when the pressure value of the first pressure detecting module 12 begins to rise, it indicates that the test chamber 1 is filled with the filling liquid.
S3, inflating and pressurizing the inflation inlet 15 of the test box body 1 to a preset pressure, driving the liquid in the test box body 1 to enter the core test module 4, penetrate through the core 21 to be tested and be discharged from the liquid discharge port 28;
the predetermined pressure affects the seepage velocity of the liquid discharged from the liquid discharge port 28, and the specific value of the predetermined pressure is affected by various factors, including the property, particularly fluidity, of the liquid selected for the test, the property, particularly permeability, of the core 21 to be tested selected for the test, the atmospheric pressure of the local environment in which the test is performed, the accuracy of the selected second pressure detection module 9, and the like. In specific implementation, the predetermined pressure is required to satisfy the condition that the liquid in the test box 1 seeps through the core 21 to be tested and is discharged out of the test box 1, and can be read by the second pressure detection module 9.
S4, collecting liquid seeped out from the liquid outlet 28, and calculating to obtain the fluidity of the core 21 to be measured by combining the liquid seepage speed and the preset pressure;
step S4 includes the following steps:
s4.1, collecting liquid seeped out from the liquid outlet;
s4.2, recording the seepage time and the seepage amount of the collected liquid;
calculating according to the following formula (I) to obtain the fluidity lambda of the core to be measured 1 ：
In the formula (I), lambda 1 The fluidity of the core 21 to be measured; p1 is the predetermined pressure in MPa in step S3; 0.001 is a water column pressure conversion coefficient; h is the vertical distance from the inflation inlet 15 to one end, away from the liquid discharge direction, of the core 21 to be tested in the step S3, and the unit is m; 0.101 is standard atmospheric pressure in MPa; t is the exudation time of the liquid in step S4.2, in units of S; s is the area of the cross section of the rock core 21 to be measured and the unit is cm 2 (ii) a V is the amount of liquid exuded in step S4.2, in cm 3 (ii) a And L is the length of the core 21 to be measured and has a unit of cm.
In the step S4.1, a drainage device is arranged outside the liquid discharge port 28, and through the arrangement of the drainage device, the liquid discharged from the liquid discharge port 28 is better collected, so that the liquid is prevented from being shunted along the arc surface 25, and the recording of the seepage time and the seepage amount of the collected liquid is prevented from being influenced. The drainage device may be a cylinder or the like disposed along the outer periphery of the liquid discharge port 28.
S5, as shown in FIG. 6, the logging device 18 is placed at the liquid discharge port 28 of the test box body 1, the steps S2-S3 are repeated, the test probe 19 of the logging device is aligned to the liquid discharge port 28, the logging device 18 is started to perform suction measurement, and the fluidity of the core 21 to be tested, which is obtained through detection on the logging device 18, is obtained;
preferably, the logging device 18 detects the obtained fluidity λ of the core 21 to be tested 2 Obtained by the following formula (II):
in the formula (II), λ 2 Obtaining the mobility of a core to be detected 21 for the detection of logging equipment; c is the probe correlation coefficient used by the logging device 18; q is the volume of its pumped liquid read from the logging device in cm 3 (ii) a μ is the formation fluid viscosity, 1 under experimental conditions; Δ P is the pressure difference read from the logging tool at which it draws fluid in MPa.
S6, comparing the fluidity of the core 21 to be tested obtained in the step S5 with the fluidity of the core 21 to be tested obtained in the step S4;
and S7, adjusting the logging equipment 18 according to the comparison result (such as the difference) until the mobility of the core 21 to be detected, which is obtained by the detection of the logging equipment 18, is consistent with the mobility of the core 21 to be detected, which is obtained in the step S4.
Preferably, in step S7, adjusting the logging device includes adjusting a probe correlation coefficient of the logging device; step S7 includes the following steps:
s7.1, calculating and obtaining a target probe correlation coefficient C according to the following formula (III) o ：
In the formula (III), λ 1 Calculating the fluidity of the core 21 to be measured obtained in the step S4.3; c is the probe correlation coefficient in the step 5; lambda [ alpha ] 2 The mobility of the core to be detected 21 obtained by the detection of the logging equipment in the step 5 is measured;
s7.2, adjusting the correlation coefficient of the logging equipment probe to be a target probe correlation coefficient C o ；
S7.3, repeating the steps S5-S6 for one or more times until lambda 2 ＝λ 1 。
To improve the verification accuracy, steps S2-S7 may be repeated one more time or more while gradually increasing or decreasing the predetermined pressure to improve the accuracy of the verification result.
The above description is only an embodiment of the present invention, and not intended to limit the scope of the present invention, and all modifications of equivalent structures and equivalent processes performed by the present invention and the contents of the attached drawings, or directly or indirectly applied to other related technical fields, are included in the scope of the present invention.
Claims (10)
1. A method of logging device calibration, comprising the steps of:
s1, placing the core testing module with the core to be tested in a testing box body, and butting the core testing module on a liquid outlet of the testing box body;
s2, filling liquid into a liquid filling port of the test box body until the test box body is filled with the liquid;
s3, inflating and pressurizing the inflation inlet of the test box body to a preset pressure, driving liquid in the test box body to enter the core test module, penetrate through the core to be tested and seep out of the liquid outlet;
s4, collecting liquid seeped out from the liquid outlet, and calculating to obtain the fluidity of the core to be measured by combining the liquid seepage speed and the preset pressure;
s5, placing the logging equipment at a liquid discharge port of the test box, repeating the steps S2-S3, starting the logging equipment, and obtaining the fluidity of the core to be detected, which is obtained by the detection of the logging equipment;
s6, comparing the fluidity of the core to be tested obtained in the step S5 with the fluidity of the core to be tested obtained in the step S4;
and S7, adjusting the correlation coefficient of the logging equipment probe according to the comparison result until the mobility of the core to be detected, which is obtained by the detection of the logging equipment, is consistent with the mobility of the core to be detected, which is obtained in the step S4.
2. The logging apparatus verification method of claim 1, wherein step S4 comprises the steps of:
s4.1, collecting liquid seeped out from the liquid outlet;
s4.2, recording the seepage time and the seepage amount of the collected liquid;
s4.3, calculating according to the following formula (I) to obtain the fluidity lambda of the core to be measured 1 ：
In the formula (I), lambda 1 The fluidity of the core to be detected is obtained; p1 is the predetermined pressure in MPa in step S3; 0.001 is a water column pressure conversion coefficient; h is the vertical distance from the inflation inlet in the step S3 to one end, far away from the liquid discharge direction, of the core to be tested, and the unit is m; 0.101 is standard atmospheric pressure in MPa; t is the exudation time of the liquid in step S4.2, in units of S; s is the area of the cross section of the rock core to be measured and the unit is cm 2 (ii) a V is the amount of liquid exuded in step S4.2, in cm 3 (ii) a And L is the length of the core to be measured and is in cm.
3. The logging device calibration method according to claim 2, wherein in step S1, one surface of the test box is provided with a curved surface corresponding to an inner surface of the oil well, and the core test module is positioned inside the test box on an inner side of the curved surface; the liquid discharge port is formed in the cambered surface;
and in the step S4.1, a drainage device is arranged outside the liquid outlet.
4. The method for verifying the logging equipment as claimed in claim 2, wherein in step S5, the logging equipment detects the obtained fluidity λ of the core to be tested 2 Obtained by the following formula (II):
in the formula (II), λ 2 Obtaining the fluidity of the core to be detected for the detection of logging equipment; c is the correlation coefficient of the probe used by the logging equipment at present; q is the volume of its pumped liquid read from the logging device in cm 3 (ii) a μ is the formation fluid viscosity, 1 under experimental conditions; Δ P is the pressure difference read from the logging tool as it draws fluid in MPa.
5. The logging tool verification method of claim 2, wherein in step S7, adjusting the logging tool comprises adjusting a probe correlation coefficient of the logging tool; step S7 includes the following steps:
s7.1, calculating and obtaining a target probe correlation coefficient C according to the following formula (III) o ：
In the formula (III), λ 1 Calculating the fluidity of the core to be measured obtained in the step S4.3; c is the probe correlation coefficient in the step 5; lambda [ alpha ] 2 Detecting the obtained core fluidity to be detected by the logging equipment in the step 5;
s7.2, adjusting the probe correlation coefficient of the logging equipment to be a target probe correlation coefficient C o ；
S7.3, repeating the steps S5-S6 for one or more times until lambda 2 ＝λ 1 。
6. The logging apparatus verification method according to any one of claims 1 to 5, wherein in step S2, a liquid filling unit is connected to the liquid filling port of the test tank;
the liquid filling unit comprises a liquid filling pump, a first connecting pipeline connected between the liquid filling pump and the liquid filling port, and a first pressure detection module connected to the first connecting pipeline; after the liquid injection pump is started, liquid is pumped into the liquid injection port through the first connecting pipeline until the test box body is filled with the liquid.
7. A logging device verification method according to any of claims 1-5, wherein in step S3, a gas filling unit is connected to the gas filling port of the test box;
the inflation unit comprises a gas compressor, a second connecting pipeline connected between the gas compressor and the inflation inlet, a gas storage tank, a second pressure detection module and a pressure regulation module;
the gas storage tank is arranged on the second connecting pipeline and stores the pressurized gas generated by the gas compressor and conveys the pressurized gas into the test box body through the second connecting pipeline; and the pressurized gas is enabled to reach the preset pressure through the cooperation of the second pressure detection module and the pressure regulation module.
8. A logging device verification system, for use in a logging device verification method according to any of claims 1-5; the well logging equipment calibration system comprises a closed test box body, a core test module for placing a core to be tested, a liquid filling unit and an air filling unit;
the test box body is respectively provided with a liquid charging port, a gas charging port and a liquid discharging port; the core testing module is arranged in the testing box body and is relatively communicated with the liquid outlet;
the liquid filling unit is connected with the liquid filling port and is used for filling liquid into the test box body;
the inflation unit is connected with the inflation inlet and used for inflating and pressurizing the test box body, driving liquid in the test box body to enter the core test module, and permeating the core to be tested to seep out from the liquid outlet.
9. The logging device calibration system of claim 8 wherein a surface of the test housing is provided with a contour corresponding to an inner surface of the well; the liquid discharge port is arranged on the cambered surface.
10. The logging equipment calibration system as recited in claim 8, wherein the core testing module comprises a barrel for placing a core to be tested, at least one seal and at least one support;
the opposite two ends of the cylinder are open and are communicated with the test box body and the liquid outlet;
the supporting piece is arranged in one end of the cylinder body close to the liquid outlet and supports the core to be measured in the cylinder body;
the sealing element is arranged in the opposite other end of the cylinder body and seals a gap between the inner surface of the cylinder body and the core to be measured.
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| CN202210520411.8A CN114876452A (en) | 2022-05-13 | 2022-05-13 | Logging equipment calibration method and logging equipment calibration system |
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