CN112412437B - Wellhead return flow measuring method - Google Patents
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- CN112412437B CN112412437B CN202011294341.6A CN202011294341A CN112412437B CN 112412437 B CN112412437 B CN 112412437B CN 202011294341 A CN202011294341 A CN 202011294341A CN 112412437 B CN112412437 B CN 112412437B
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- 238000000034 method Methods 0.000 title claims abstract description 28
- 239000007788 liquid Substances 0.000 claims abstract description 87
- 238000005259 measurement Methods 0.000 claims abstract description 32
- 239000012530 fluid Substances 0.000 claims abstract description 14
- 238000009434 installation Methods 0.000 claims abstract description 13
- 238000000691 measurement method Methods 0.000 claims abstract description 11
- 239000000523 sample Substances 0.000 claims description 85
- 238000002360 preparation method Methods 0.000 claims description 31
- 238000005070 sampling Methods 0.000 claims description 16
- 238000001595 flow curve Methods 0.000 claims description 2
- 238000012544 monitoring process Methods 0.000 abstract description 9
- 238000005553 drilling Methods 0.000 abstract description 8
- 238000012937 correction Methods 0.000 abstract description 3
- 239000003208 petroleum Substances 0.000 abstract description 2
- 238000010586 diagram Methods 0.000 description 4
- 238000004458 analytical method Methods 0.000 description 3
- 230000007774 longterm Effects 0.000 description 2
- 210000002445 nipple Anatomy 0.000 description 2
- 238000012545 processing Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000005540 biological transmission Effects 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000004445 quantitative analysis Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000007790 solid phase Substances 0.000 description 1
- 238000013519 translation Methods 0.000 description 1
Classifications
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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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- 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
- E21B47/10—Locating fluid leaks, intrusions or movements
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Geophysics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
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Abstract
The application relates to the technical field of petroleum engineering drilling, and discloses a wellhead return flow measurement method, which utilizes an online monitoring system to realize measurement of liquid level height and fluid flow velocity in a pipeline, and is also matched with a height automatic correction module, so that the cost is lower, the measurement flow is more accurate, the whole online monitoring system has lower requirement on site installation, the installation is more convenient, and finally, discretization treatment is realized on flow measurement data in the pipeline by an integral method, and the anti-interference capability is further improved.
Description
Technical Field
The application relates to the technical field of petroleum engineering drilling, in particular to a wellhead return flow measuring method.
Background
The return flow of the drilling wellhead is the most direct index of overflow and leakage analysis, so that high-precision monitoring of the flow is realized, and quick detection of the overflow and leakage of the pipeline is facilitated. At present, an 8L03 type outlet flowmeter is commonly used by a well team, and the device adopts contact measurement, so that the problems of poor measurement precision, large fluctuation of measurement data and the like exist, and quantitative analysis cannot be provided for field personnel.
The analysis shows that the problem of large contact measurement error mainly comprises the following reasons:
1. the density, viscosity, wave and liquid level of the incoming drilling fluid have important influence on the swing of the baffle, and the change of the flow cannot be accurately defined, so that the method is a main cause of large error.
2. In the measuring process, the solid phase of the drilling fluid is adhered to the baffle plate, so that the weight of the baffle plate is changed, and further continuous measuring errors are caused.
3. The different mounting positions of the baffles result in different areas of contact with the fluid and also affect the accuracy of the measurement.
A large number of research analyses have been made by researchers with respect to the above problems. For example, in the prior art, publication No.: CN102704874a, publication date: the application discloses a device and a method for detecting the return flow of drilling fluid on the year 2012, month 10 and month 03, which adopts the following technical scheme: the device comprises one or more flow measurement nipple pieces (5) arranged between a shaft drilling fluid return outlet (3) and a vibrating screen (4), wherein the flow measurement nipple pieces (5) comprise rectangular section overflow sections (6) and horn mouth buffer sections positioned at two ends of the rectangular section overflow sections (6), liquid level sensors (1) are arranged at the tops of the rectangular section overflow sections (6), flow velocity sensors (2) are arranged in liquid flow in the rectangular section overflow sections (6), and the liquid level sensors (1) and the flow velocity sensors (2) are respectively electrically connected with calculation and display alarm units (8).
The prior art can realize real-time measurement of wellhead return flow, but has low long-term use reliability because the wellhead return flow is measured in a contact mode, and the wellhead overflow preventing pipe is required to be changed when the device is installed and used, so that the problem of high workload is also solved.
Disclosure of Invention
Aiming at the problems and defects existing in the prior art, the application provides a wellhead return flow measuring method, an on-line monitoring system realizes the measurement of the liquid level height and the fluid flow velocity in a pipeline, and the real liquid level height in the pipeline can be automatically corrected, so that the cost is lower, the measuring flow is more accurate, and finally, the discretization processing is realized by integrating the flow measurement, so that the anti-interference capability is further improved.
In order to achieve the above object, the present application has the following technical scheme:
a wellhead flowback flow measurement method, the method comprising the steps of:
a. centering an empty pipe, horizontally moving a signal generating probe positioned in the middle position of a signal probe device to find the lowest point of a pipeline, wherein the signal probe device is arranged on the outer surface of the pipeline;
b. respectively reading measurement data a and b of two angle sensors on a pipeline and initial measurement value H of other signal generating probes in signal probe device n Two angle sensors are arranged on the outer surface of the pipeline, wherein a represents the included angle between the signal transmitting line of the signal generating probe and the vertical direction, b represents the included angle between the pipeline and the vertical direction, and H n Representing the distance from each signal generating probe to the inner wall of the bottom of the hollow pipe;
c. correcting the true height, and obtaining the vertical distance H from the signal generating probe to the inner wall of the bottom of the pipeline according to the step b True sense ；
H True sense ＝H n X sin (a+b) (formula 1);
d. when in measurement, the time difference between the transmitting signal and the reflecting signal of each signal generating probe is obtained, and the linear distance h between the signal generating probe and the liquid level in the pipeline is calculated n And correcting by using the formula 1 in the step c to obtain each letterVertical distance h from number generating probe to liquid level in pipeline True sense The liquid level height h in the pipeline measured by each signal generating probe is calculated respectively, and the average liquid level height h in the pipeline is converted by using a least square method Liquid and its preparation method ；
e. Calculating the frequency difference between the transmitting signal and the reflecting signal of each signal generating probe to obtain the real-time flow velocity measurement value V of the liquid in the pipeline n And fitting the liquid flow velocity V according to a least square method Liquid and its preparation method ；
f. Dividing 1S into n sampling points according to the average liquid level height h in the pipeline Liquid and its preparation method Average liquid flow velocity V Liquid and its preparation method Calculating the real-time micro-flow Q of a single sampling point, and superposing the real-time micro-flows of n sampling points to obtain the final real-time output flow Q per second; wherein, the real-time micro-flow q of the single sampling point is calculated by the following formula:
order the
If R-h Liquid and its preparation method > 0, then
If R-h Liquid and its preparation method =0, then q=0.5 pi R 2 ×V Liquid and its preparation method ×t；
If R-h Liquid and its preparation method < 0, then
Wherein R is the inner diameter of the pipeline, and t is the single sampling time.
Preferably, in the step a, the signal generating probe located at the middle position horizontally moves and continuously transmits signals, the distance between the signal generating probe and the inner wall of the bottom of the pipeline is calculated through the time difference between the transmitted signals and the reflected signals, and when the maximum distance between the signal generating probe and the inner wall of the bottom of the pipeline is found, the minimum point of the pipeline is the moment.
Preferably, in the step b, the time of the transmitting signal and the reflecting signal of the probe is generated according to each signalThe difference is calculated to obtain the distance H from the signal generating probe to the inner wall of the bottom of the hollow pipe n 。
Preferably, in the step d, the liquid level h in the pipeline measured by the signal generating probe is calculated according to formula 2;
h＝max(H true sense )-h True sense (formula 2).
Preferably, in the step d, according to the liquid level height h in the pipeline measured by each signal generating probe, an arithmetic average value is taken as the average liquid level height h of the liquid in the pipeline Liquid and its preparation method 。
Preferably, in the step e, the real-time flow velocity measurement value V of the liquid measured by each signal generating probe n Taking the arithmetic average value as the measured flow velocity V of the liquid in the pipeline Liquid and its preparation method 。
Preferably, the measuring method further comprises: and after obtaining the real-time flow of the fluid in the pipeline, drawing a flow curve graph according to the real-time flow at each moment.
Preferably, one of the two angle sensors is mounted on both sides of the same mounting plane as the signal probe device.
Preferably, the signal probe device and the one-gauge angle sensor are arranged in the installation shell, the installation shell is connected with the pipeline through the connecting flange, and the connecting flange is provided with a sleeve partially hollowed out.
The application has the beneficial effects that:
(1) The application realizes the measurement of the liquid level height and the fluid flow velocity in the pipeline by utilizing the online monitoring system, and is also matched with the height automatic correction module, so that the cost is lower, the measurement flow is more accurate, the whole online monitoring system has lower requirement on site installation, the installation is more convenient, and finally, the discretization processing of the flow measurement data in the pipeline is realized by an integral method, and the anti-interference capability is further improved.
(2) The application adopts a non-contact method to measure the fluid flow velocity, so the service life of the whole monitoring system is longer, and the long-term use reliability is high.
(3) According to the application, the sleeve arranged on the connecting flange adopts a local hollow structure design, so that the high-temperature drilling fluid steam can be conveniently discharged.
Drawings
The foregoing and the following detailed description of the application will become more apparent when read in conjunction with the following drawings in which:
FIG. 1 is a flow chart of the method of the present application;
FIG. 2 is a schematic diagram of the present application;
FIG. 3 is a schematic diagram of a cross-sectional structure of a pipe according to the present application;
FIG. 4 is a schematic diagram of the height correction of the present application;
FIG. 5 is a diagram illustrating a data discretization process according to the present application.
In the figure:
1. a signal probe device; 2. a number one angle sensor; 3. a second angle sensor; 4. a connecting flange; 5. a sleeve; 11. a signal generating probe.
Detailed Description
The technical solution for achieving the object of the present application is further described below by means of several specific embodiments, and it should be noted that the technical solution claimed by the present application includes, but is not limited to, the following embodiments.
Example 1
The embodiment discloses a wellhead return flow measuring method, which is realized by a wellhead return flow on-line monitoring system, wherein the on-line monitoring system mainly comprises a signal probe device 1, a first-number angle sensor 2, a second-number angle sensor 3, a signal converter and a processor, and the signal probe device 1 further comprises a shell and a signal generating probe 11 arranged in the shell. Referring to fig. 1 of the specification, the method specifically comprises the following steps:
a. centering the empty pipe, horizontally moving a signal generating probe 11 positioned at the middle position of a signal probe device 1 to find the lowest point of the pipeline, wherein the signal probe device 1 is arranged on the outer surface of the pipeline; the empty pipe refers to the condition that no fluid exists in the manifold;
b. device for respectively reading measurement data a and b of two angle sensors on pipeline and signal probe1, the remaining signal generating probes 11 have an initial measurement H n Two angle sensors are arranged on the outer surface of the pipeline, wherein a represents the included angle between the signal emitting line of the signal generating probe 11 and the vertical direction, b represents the included angle between the pipeline and the vertical direction, and H n Representing the distance from each signal generating probe 11 to the inner wall of the bottom of the hollow pipe;
c. correcting the true height, and obtaining the vertical distance H from all the signal generating probes 11 to the inner wall of the bottom of the pipeline according to the step b True sense ；
H True sense ＝H n X sin (a+b) (formula 1);
d. during measurement, the time difference between the transmitted signal and the reflected signal of each signal generating probe 11 is obtained, and the linear distance h between the signal generating probe 11 and the liquid level in the pipeline is calculated n And correcting by using the formula 1 in the step c to obtain the vertical distance h from each signal generating probe 11 to the liquid level in the pipeline True sense The liquid level height h in the pipeline measured by each signal generating probe 11 is calculated respectively, and the average liquid level height h in the pipeline is converted by using a least square method Liquid and its preparation method The method comprises the steps of carrying out a first treatment on the surface of the The average liquid level height h Liquid and its preparation method Refers to the vertical distance from the liquid level to the lowest point of the pipeline;
e. calculating the frequency difference between the transmitted signal and the reflected signal of each signal generating probe 11 to obtain the real-time flow velocity measurement value V of the liquid in the pipeline n And fitting the liquid flow velocity V according to a least square method Liquid and its preparation method ；
f. Dividing 1S into n sampling points according to the average liquid level height h in the pipeline Liquid and its preparation method Average liquid flow velocity V Liquid and its preparation method Calculating the real-time micro-flow Q of a single sampling point, and superposing the real-time micro-flows of n sampling points to obtain the final real-time output flow Q per second; wherein, the real-time micro-flow q of the single sampling point is calculated by the following formula:
order the
If R-h Liquid and its preparation method > 0, then
If R-h Liquid and its preparation method =0, then q=0.5 pi R 2 ×V Liquid and its preparation method ×t；
If R-h Liquid and its preparation method < 0, then
Wherein R is the inner diameter of the pipeline, and t is the single sampling time.
In the present application, the signal emitted from the signal generating probe may be an ultrasonic wave, a radar, or a laser.
In the application, in order to improve the measurement accuracy, a plurality of signal probe devices and matched corresponding angle sensors can be arranged on the outer surface of the pipeline, and the measurement error can be further corrected in a cross comparison mode.
In the application, a plurality of signal generating probes are arranged in a shell of the signal probe device, the signal generating probes positioned at the central position are movable probes, and the rest probes are all fixed probes. When the signal probe device works, the motor in the signal probe device operates and drives the telescopic rod to move, so that the movable probe connected with the telescopic rod is driven to horizontally slide on the translation track.
Example 2
The embodiment discloses a wellhead return flow measurement method, and based on embodiment 1, in the step a, a determination mode of a lowest point of a pipeline specifically includes: the signal generating probe 11 positioned in the middle position horizontally moves and continuously transmits signals, the distance between the signal generating probe 11 and the inner wall of the bottom of the pipeline is calculated through the time difference between the transmitted signals and the reflected signals, and when the maximum distance between the signal generating probe 11 and the inner wall of the bottom of the pipeline is found, the lowest point of the pipeline is found.
Further, in the step b, the distance H from each signal generating probe 11 to the inner wall of the bottom of the hollow pipe is calculated according to the time difference between the transmission signal and the reflection signal of each signal generating probe 11 n 。
Further, in the step d, the liquid level height h in the pipeline measured by the signal generating probe 11 is calculated according to the formula 2;
h＝max(H true sense )-h True sense (formula 2).
Further, in the step d, according to the liquid level height h in the pipeline measured by each signal generating probe 11, the arithmetic average value is taken as the average liquid level height h of the liquid in the pipeline Liquid and its preparation method 。
Further, in the step e, the real-time flow velocity measurement V of the liquid is measured according to each signal generating probe 11 n The arithmetic average value is taken as the measured flow velocity V of the liquid in the pipeline Liquid and its preparation method 。
Further, referring to fig. 5 of the specification, the measuring method further includes drawing a flow chart according to the real-time flow of each moment after obtaining the real-time flow of the fluid in the pipeline. In the figure, S represents the sectional area of the liquid and is obtained by calculating the liquid level height; d represents the distance the liquid flows through during the cycle, obtained by the product of the liquid flow rate and the sampling time.
Further, referring to fig. 2 of the specification, the two angle sensors in the present application are a first angle sensor 2 and a second angle sensor 3, respectively, wherein the first angle sensor 2 and the signal generating probe 11 in the signal probe device 1 are located at two sides of the same installation plane, and the second angle sensor 3 is directly installed on the outer surface of the pipeline through a connecting bolt.
Further, the signal probe device 1 and the first angle sensor 2 are arranged in an installation shell, a connecting flange 4 is arranged at the tail of the installation shell, a connecting flange 4 is also arranged at the corresponding position of a pipeline, the installation shell is connected with the pipeline through the connecting flange 4, and a sleeve 5 with a partially hollowed-out part is arranged on the connecting flange 4.
In the description of the present application, it should be understood that the terms "center," "longitudinal," "lateral," "front," "rear," "left," "right," "vertical," "horizontal," "top," "bottom," "inner," "outer," and the like indicate orientations or positional relationships based on the orientations or positional relationships shown in the drawings, merely to facilitate describing the present application and simplify the description, and do not indicate or imply that the devices or elements being referred to must have a specific orientation, be configured and operated in a specific orientation, and therefore should not be construed as limiting the scope of the present application.
In the description of the present application, it should also be noted that, unless explicitly specified and limited otherwise, the terms "disposed," "mounted," and "connected" are to be construed broadly, and may be, for example, fixedly connected, detachably connected, or integrally connected; can be mechanically or electrically connected; can be directly connected or indirectly connected through an intermediate medium, and can be communication between two elements. The specific meaning of the above terms in the present application will be understood in specific cases by those of ordinary skill in the art.
The foregoing description is only a preferred embodiment of the present application, and is not intended to limit the present application in any way, and any simple modification, equivalent variation, etc. of the above embodiment according to the technical matter of the present application fall within the scope of the present application.
Claims (9)
1. A wellhead return flow measuring method is characterized in that: the method comprises the following steps:
a. the method comprises the steps of centering an empty pipe, horizontally moving a signal generating probe (11) positioned in the middle of a signal probe device (1) to find the lowest point of a pipeline, wherein the signal probe device (1) is arranged on the outer surface of the pipeline;
b. respectively reading the measurement data a and b of two angle sensors on the pipeline and the initial measurement value H of the rest signal generating probes (11) in the signal probe device (1) n Two angle sensors are arranged on the outer surface of the pipeline, wherein a represents the included angle between the signal transmitting line of the signal generating probe (11) and the vertical direction, b represents the included angle between the pipeline and the vertical direction, and H n Representing the distance from each signal generating probe (11) to the inner wall of the bottom of the hollow pipe;
c. correcting the true height, obtaining the vertical distance H from the signal generating probe (11) to the inner wall of the bottom of the pipeline according to the step b True sense ；
H True sense ＝H n X sin (a+b) (formula 1);
d. during measurement, the time difference between the transmitted signal and the reflected signal of each signal generating probe (11) is obtained, and the linear distance h between the signal generating probe and the liquid level in the pipeline is calculated n And correcting by adopting the formula 1 in the step c to obtain the vertical distance h between each signal generating probe (11) and the liquid level in the pipeline True sense The liquid level height h in the pipeline measured by each signal generating probe (11) is calculated respectively, and the average liquid level height h in the pipeline is converted by using a least square method Liquid and its preparation method ；
e. Calculating the frequency difference between the transmitted signal and the reflected signal of each signal generating probe (11) to obtain a real-time flow velocity measurement value V of the liquid in the pipeline n And fitting the liquid flow velocity V according to a least square method Liquid and its preparation method ；
f. Dividing 1S into n sampling points according to the average liquid level height h in the pipeline Liquid and its preparation method Average liquid flow velocity V Liquid and its preparation method Calculating the real-time micro-flow Q of a single sampling point, and superposing the real-time micro-flows of n sampling points to obtain the final real-time output flow Q per second; wherein, the real-time micro-flow q of the single sampling point is calculated by the following formula:
order the
If R-h Liquid and its preparation method > 0, then
If R-h Liquid and its preparation method =0, then q=0.5 pi R 2 ×V Liquid and its preparation method ×t；
If R-h Liquid and its preparation method < 0, then
Wherein R is the inner diameter of the pipeline, and t is the single sampling time.
2. A wellhead flowback flow measurement method according to claim 1, characterized in that: in the step a, the signal generating probe (11) positioned at the middle position horizontally moves and continuously transmits signals, the distance from the signal generating probe (11) to the inner wall of the bottom of the pipeline is calculated through the time difference between the transmitted signals and the reflected signals, and when the maximum distance from the signal generating probe (11) to the inner wall of the bottom of the pipeline is found, the minimum point of the pipeline is obtained.
3. A wellhead flowback flow measurement method according to claim 1, characterized in that: in the step b, the distance H from the signal generating probe (11) to the inner wall of the bottom of the hollow pipe is calculated according to the time difference between the transmitting signal and the reflecting signal of each signal generating probe (11) n 。
4. A wellhead flowback flow measurement method according to claim 1, characterized in that: in the step d, calculating the liquid level height h in the pipeline measured by the signal generating probe (11) according to the formula 2;
h＝max(H true sense )-h True sense (formula 2).
5. A wellhead flowback flow measurement method according to claim 1, characterized in that: in the step d, according to the liquid level height h in the pipeline measured by each signal generating probe (11), taking the arithmetic average value as the average liquid level height h of the liquid in the pipeline Liquid and its preparation method 。
6. A wellhead flowback flow measurement method according to claim 1, characterized in that: in the step e, according to the measured value V of the liquid real-time flow velocity measured by each signal generating probe (11) n Taking the arithmetic average value as the measured flow velocity V of the liquid in the pipeline Liquid and its preparation method 。
7. A wellhead flowback flow measurement method according to claim 1, characterized in that: the measuring method further comprises the following steps: and after obtaining the real-time flow of the fluid in the pipeline, drawing a flow curve graph according to the real-time flow at each moment.
8. A wellhead flowback flow measurement method according to claim 1, characterized in that: of the two angle sensors, one of the two angle sensors and the signal probe device (1) are arranged on two sides of the same installation plane.
9. A wellhead flowback flow measurement method according to claim 1, characterized in that: the signal probe device (1) and one of the angle sensors are arranged in an installation shell, the installation shell is connected with a pipeline through a connecting flange (4), and a sleeve (5) with a partially hollowed-out part is arranged on the connecting flange (4).
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Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| FR2508633A1 (en) * | 1981-06-30 | 1982-12-31 | Schlumberger Prospection | WHEAT EMISSION PROBE FOR MEASURING FLOW IN A WELL, DIAGRAM APPARATUS INCLUDING THE SAME, AND CORRESPONDING METHODS |
| CN1970990A (en) * | 2006-11-29 | 2007-05-30 | 中国石油大学(北京) | Method for measuring return flow in petroleum drilling and device therefor |
| CN102121357A (en) * | 2011-01-13 | 2011-07-13 | 东北石油大学 | Drilling fluid return flow measuring method and measuring device thereof |
| CN103061753A (en) * | 2013-01-18 | 2013-04-24 | 西南石油大学 | Device for measuring downhole flow while drilling and monitoring early overflow |
Family Cites Families (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US6650280B2 (en) * | 2000-12-08 | 2003-11-18 | The United States Of America As Represented By The Administrator Of The National Aeronautics And Space Administration | Measurement system and method |
-
2020
- 2020-11-18 CN CN202011294341.6A patent/CN112412437B/en active Active
Patent Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| FR2508633A1 (en) * | 1981-06-30 | 1982-12-31 | Schlumberger Prospection | WHEAT EMISSION PROBE FOR MEASURING FLOW IN A WELL, DIAGRAM APPARATUS INCLUDING THE SAME, AND CORRESPONDING METHODS |
| CN1970990A (en) * | 2006-11-29 | 2007-05-30 | 中国石油大学(北京) | Method for measuring return flow in petroleum drilling and device therefor |
| CN102121357A (en) * | 2011-01-13 | 2011-07-13 | 东北石油大学 | Drilling fluid return flow measuring method and measuring device thereof |
| CN103061753A (en) * | 2013-01-18 | 2013-04-24 | 西南石油大学 | Device for measuring downhole flow while drilling and monitoring early overflow |
Non-Patent Citations (1)
| Title |
|---|
| 基于电磁流量计的钻井液出口流量监测***;孙合辉;陶青龙;李邓;陈玉新;李洪俊;;科技资讯(第21期);11、15 * |
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