CN114993391B - Horizontal well array turbine flowmeter and measuring method - Google Patents
Horizontal well array turbine flowmeter and measuring method Download PDFInfo
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- G—PHYSICS
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- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
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- E21B47/00—Survey of boreholes or wells
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Abstract
The invention discloses a horizontal well array turbine flowmeter and a measuring method, wherein the horizontal well array turbine flowmeter comprises: the device comprises a cable head, a middle shaft main body, a voltage regulating system, a data transmission system, a signal conversion system, a control system, 1 telescopic center turbine rotor, 8 double-layer layout array arms, 8 identical array turbine rotors, a telescopic center shaft and a conical head. Aiming at the difficult problems of complex speed profile caused by the special well structure of the horizontal well and uneven distribution of fluid media, the layout structure of the double-layer array type turbine distribution and centering turbine rotor is adopted, the principle is reliable, the operation is convenient, the method is suitable for monitoring fluid speed profile information of the oil-gas-water single-phase, two-phase and multi-phase fluid flow conditions of the horizontal well with different structures, and further the fluid speed distribution characteristics of the horizontal well can be accurately reflected. According to the measuring method, the turbine rotating speed of the local point at the mapping position is calculated based on Gaussian radial basis function interpolation, then the apparent fluid speed is calculated quantitatively, and the fluid flow of the well bore can be calculated accurately.
Description
Technical Field
The invention relates to the technical field of horizontal well array turbine flowmeters, in particular to a horizontal well array turbine flowmeter and a measuring method.
Background
The horizontal well is used as an emerging high-efficiency oilfield development technology and is increasingly used for unconventional oil and gas reservoir development, different from a conventional vertical well structure, the horizontal well is fluctuant, a horizontal well section shows various combination forms such as upward inclination, downward inclination, horizontal and the like, the complicated well structure enables the oil and gas-water multiphase fluid medium distribution in the horizontal well to be obviously different from that of a conventional vertical well in the development process, the characteristics of layering or irregular disturbance flow in the gas-oil-water state are often shown, the fluid medium distribution and the speed profile are extremely irregular, and the errors of a full-well flowmeter and a continuous flowmeter in the conventional vertical well production profile logging method are extremely large in the multiphase fluid speed monitoring of the horizontal well.
Currently, the multi-phase fluid speed monitoring of the horizontal well adopts an array type flow probe layout structure, and is represented by a flow scanning imager FSI of Schlumberger company and a MAPS array flowmeter of Sondex company. The FSI of Schlumberger company adopts 5 miniature turbine rotors with the same size and axially vertically and centrally distributed to realize speed monitoring, and has better application effect on the laminar flow characteristics of multiphase fluid media; the SAT of Sondex adopts 6 turbine rotors with the same size which are annularly and uniformly distributed to realize fluid speed measurement, and has better application effect on annular fluid medium distribution. And in the measuring process, different measuring speeds are adopted for multiple up-measuring and down-measuring, and then a turbine rotating speed and measuring speed intersection method is combined to obtain the apparent fluid speed at each probe position of the corresponding horizontal shaft, and finally, a weighting method is adopted to calculate and obtain the multiphase fluid apparent speed of the horizontal shaft.
However, in the actual horizontal well logging process, the relative position of the probe space of the same depth point array in the lifting and lowering processes of the instrument can be changed due to the rotation of the instrument, so that a great error exists in calculating the apparent fluid speed by aiming at the multi-measurement intersection method of the monitoring information of the same probe in the actual data processing process, and the calculation accuracy of the multiphase fluid flow of the horizontal well is further affected; the actual single annular distribution and the axial vertical centering distribution can also cause inaccurate limitation of monitoring data due to rotation of the instrument.
In order to overcome the limitation that the multi-factor influence of the horizontal well multiphase fluid speed monitoring process and the data processing is greatly influenced by the rotation of the instrument, it is necessary to design a new horizontal well array flow monitoring instrument, establish a method for accurately calculating the apparent fluid speed corresponding to the monitoring data, realize the accurate quantitative calculation of the horizontal well multiphase fluid flow, and further provide accurate and reliable technical support parameters for the dynamic quantitative evaluation of the production of each production layer of the complex oil and gas reservoir horizontal well development and the optimization adjustment of the development scheme of the next stage.
Disclosure of Invention
The invention aims to provide a horizontal well array turbine flowmeter and a measuring method, wherein the flowmeter can be used for accurately monitoring the flow rate of oil-gas-water multiphase fluid of a non-conventional oil-gas reservoir horizontal well development shaft, and can solve the problem that in the prior art, the rotation of the flowmeter is caused by the single annular distribution and the axial vertical centering distribution of a probe, so that monitoring data is inaccurate.
In order to achieve the above purpose, the technical scheme adopted by the invention is as follows:
In a first aspect, the present invention provides a method comprising: the device comprises a cable head, a center shaft main body, a voltage regulating system, a data transmission system, a signal conversion system, a control system, 1 telescopic center turbine rotor, 8 double-layer layout array arms, 8 identical array turbine rotors, a telescopic center shaft and a conical head;
The cable head is connected with the upper end of the center shaft main body and is used for being connected with a logging cable; the inside of the middle shaft main body is sequentially provided with: the voltage regulating system, the data transmission system, the signal conversion system and the control system are sequentially connected; the control system is used for controlling the extension and retraction of the telescopic central shaft and the extension and retraction of the array arms; the signal conversion system is used for converting a turbine rotor rotation frequency signal into a current signal for transmission; the data transmission system realizes stable output of signal data; the voltage regulating system is used for regulating the ground voltage to the voltage intensity required by the flowmeter;
The lower end of the middle shaft main body is connected with one end of the 8 double-layer layout array arms near the edge, and the center of the middle shaft main body is connected with one end of the telescopic center shaft; the middle position of the telescopic central shaft is provided with 1 telescopic central turbine rotor;
the 8 array turbine rotors are correspondingly installed at the middle positions of the 8 double-layer layout array arms respectively;
the other ends of the 8 double-layer layout array arms are fixedly connected with the conical head.
Further, the middle shaft main body is of a coaxial structure made of a cylindrical steel material with a preset outer diameter.
Further, the 8 double-layer layout array arms are composed of an inner layer and an outer layer, and each layer is composed of 4 spring arms which are uniformly distributed in a ring shape; in the 8 double-layer layout arrays, the included angle formed by every two adjacent array arms and the telescopic central shaft is 45 degrees.
Further, the ratio of the blade diameter of the telescoping center turbine rotor to the blade diameter of the array turbine rotor is 3:1.
Further, the telescopic center turbine rotor is connected with a flexible spring surrounding the telescopic center shaft up and down respectively.
In a second aspect, an embodiment of the present invention further provides a measurement method of a horizontal well array turbine flowmeter, using the horizontal well array turbine flowmeter according to any one of the above embodiments as a measurement instrument, where the measurement method includes:
1) Debugging and instrument well descending:
detecting whether the instrument works normally, if so, ensuring that 8 double-layer layout array arms of the instrument are in a fully folded state, and adopting an oil pipe transmission mode to perform well descending, wherein a ground system is kept to supply power to the instrument in the well descending process;
2) Positioning and monitoring:
Determining a monitoring target interval by combining the well structure of the target well and perforation interval information, stopping the well when the instrument is lowered to about 200m from the top of the uppermost perforation interval, opening a control system at the moment, ensuring that a spring arm and a rotor are in a fully opened state, and defining the lowering time measuring speed of the instrument to be positive;
The method comprises the steps of performing downward measurement at the speed V l1 while monitoring and recording instrument output signals, wherein the output signals of a telescopic central turbine rotor are RPS 01, the output signals of 8 array rotors are RPS11、RPS21、RPS31、RPS41、RPS51、RPS61、RPS71、RPS81, respectively, stopping the downward measurement when the instrument is lowered to a position below a lowest perforation section or the bottom of a well cannot be further lowered to the well, and the top position of a target interval is measured at the same speed-V l1, wherein the output signals of the central rotor are RPS 02, and the output signals of 8 array rotors are RPS12、RPS22、RPS32、RPS42、RPS52、RPS62、RPS72、RPS82, respectively and are lifted to the top position of the target interval, so that one-time test operation is completed;
3) Repeated measurements are performed several times:
Increasing the instrument well descending speed to V l2, and repeating the step 2) to measure the position below the lowest perforation section or stopping the well descending when the well bottom cannot be further descended; then, the top position of the target layer section is measured at the same speed-V l2, and output signals of the telescopic central turbine rotor and the array turbine rotor in all lifting and lowering processes are recorded; increasing the instrument well-down speed to V l3＝Vl1+2ΔV、Vl4＝Vl1 +3DeltaV, repeating the steps until all operations are completed, and recording 8 groups of instrument speeds and corresponding rotor response signals at the same time;
4) Completing testing and instrument well lifting:
And (3) operating a ground control system to retract the array arms, stopping power supply, lifting the instrument to the ground, and completing the test.
Further, in step 3), the process of calculating the total flow of the fluid in the horizontal well by using the 8 sets of instrument speeds and the corresponding rotor response signals obtained by recording is as follows:
Step 1: based on the structure of the horizontal well array turbine flowmeter, the opening degree of the annular array turbine rotor probe can be freely adjusted, so that the distance between the outer layer 4 annular array probes and the center of the shaft is expressed as,
rc＝kc·R (1)
The inner layer 4 annular array probes are shown as being spaced from the center of the wellbore,
rm＝km·R (2)
Wherein k c represents the opening degree of the outer layer 4 array probes;
k m represents the opening degree of the middle 4 array probes;
r c represents positions of center points of the sections of the wellbores, which are away from the numbers 1,2, 3 and 4 of the outer layer 4 array probes;
r m represents the positions of the center points of the sections of the wellbores, which are separated by the numbers 5, 6, 7 and 8 of the inner layer 4 array probes;
R represents the distance from the center when the outer layer 4 annular array probes are fully opened, and is equal to the radius of the section of the shaft;
Step 2: when the number 1 array rotor probe is positioned at the top of a horizontal shaft in the 8 measuring processes or any one of the number 1,2,3 and 4 probes rotates the top of the section of the shaft in a certain measuring process, the clockwise rotation angle of the number 1 probe relative to the highest position of the section of the shaft is theta j = 0.5 n pi, n = 0,1,2 and 3 …, at the moment, the rotor probes exist at all position points when the 8 array rotor probes do not rotate relative to an instrument, the central rotor is always positioned at the central position of the section of the shaft in the measuring process, the fluid apparent velocity V ai' at each probe position is directly obtained by adopting a method of comparing the rotational speeds of an upper turbine with a lower turbine and is expressed as,
V′ai＝-bi/Ki (5)
Where V' ai is the calculated apparent fluid velocity at the ith rotor; RPS ij is the response value of the ith rotor in the jth measurement, and the same position in the intersection calculation process is calculated according to the actual probe value; v lj is the instrument speed at the j-th pass of the measurement; i is rotor number=0, 1,2 … …; j is measurement sequence number j=1, 2 … … 8; n is the number of effective measuring points, and 8 times of measurement are effective and equal to 8; k i is a rotor constant obtained by fitting the ith rotor and is related with the property of the rotor; b i is the intercept on the rotor speed axis at the time of the ith rotor engagement;
when the rotor response has positive rotation and reverse rotation characteristics, fitting calculation is carried out on the positive rotation rotor response and the reverse rotation rotor response by adopting a formula (3) and a formula (4), the RPS response value in the positive rotation process is positive, the RPS response value in the reverse rotation process is negative, the apparent fluid velocity of each rotor obtained in the positive rotation process is,
V′ai Positive direction ＝-bi Positive direction /Ki Positive direction (6)
The fluid velocity at each rotor determined during the reversal process is,
V′ai Reverse-rotation ＝-bi Reverse-rotation /Ki Reverse-rotation (7)
The apparent fluid velocity of each rotor at this point is indicated as,
When the rotor is rotated all the way forward or all the way backward,
Vai＝|V′ai|+|Vai Zero (zero) | (9)
Wherein V' ai Positive direction is the calculated apparent fluid velocity when the ith rotor rotates positively; v' ai Reverse-rotation is the calculated apparent fluid velocity at which the ith rotor is reversed; b i Positive direction is the intercept on the rotor rotating speed shaft obtained by fitting when the ith rotor rotates positively; b i Reverse-rotation is the intercept on the rotor rotating speed shaft obtained by fitting when the ith rotor is reversed; k i Positive direction is a rotor constant obtained by fitting when the ith rotor rotates positively; k i Reverse-rotation is a rotor constant obtained by fitting when the ith rotor is reversed; v ai Zero (zero) is the i-th rotor apparent fluid velocity calculated by the instrument in the zero flow interval; based on the turbine rotor distribution structure of the array turbine flowmeter, the section of the shaft is divided into 9 areas, namely a rotor distribution area No. 0, a rotor distribution area No. 5, 6, 7 and 8 and a rotor distribution area No. 1, 2, 3 and 4 from inside to outside, the distances between the outer boundaries of the sub areas and the center of the section of the shaft are R·rT/(rT+2rt)、R·(rT+rt)/(rT+2rt)、R·rT/(rT+2rt); respectively, the corresponding areas of the rotor probe control areas are shown as,
The fluid velocity in the horizontal bore is indicated as,
Wherein A 0～A8 is the area represented by 9 areas after the section of the shaft is cut; a is the integral sectional area of the shaft; v a is horizontal wellbore fluid velocity; r is the radius of the section of the horizontal shaft; r t is the radius of the number 1-8 array rotor blade; r T is rotor blade radius number 0;
Step 3: by combining the distribution characteristics of fluid media in the horizontal shaft and the distribution characteristics of the velocity profile, the space coordinates of the double-layer annular array rotor probe in the horizontal shaft can be calculated as follows by taking the position of the probe No. 0 as the origin of coordinates assuming that the clockwise rotation angle of the probe No. 1 relative to the highest position of the section of the shaft is theta j in each logging process,
Probe 0: (0,0)
Probe 1: (k c·R·sinθj,kc·R·cosθj)
Probe 2: (k c·R·sin(θj+0.5π),kc·R·cos(θj +0.5pi)
Probe 3: (k c·R·sin(θj+π),kc·R·cos(θj +pi)
Probe 4: (k c·R·sin(θj+1.5π),kc·R·cos(θj +1.5pi)
Probe 5:
probe 6:
probe 7:
Probe 8:
Wherein, theta j is the angle of clockwise rotation of the No.1 probe relative to the highest position of the section of the shaft; because the instrument rotates randomly in the logging process, 9 rotor responses are interpolated by adopting a Gaussian radial basis function method aiming at each measurement data, the weight occupied by each probe of each point to be estimated is calculated by utilizing a Gaussian function, and the descending control coefficients in the horizontal direction and the vertical direction are introduced, so that the value of the point to be estimated is calculated accurately according to the coordinates of the known probes and the corresponding values, the corresponding Gaussian weight calculation method is as shown in the formula,
Wherein, (X i,Yi) is the coordinate value of the probe i; (x, y) is the point coordinate value to be estimated; m and n are decreasing control coefficients in the horizontal and vertical directions of the section of the shaft, and according to the calculated weight, the response value of each position point to be calculated can be calculated according to the measured value of each probe;
The logging prediction response value of each point of the cross section of the shaft is obtained through a Gaussian radial basis function interpolation matrix, and the response value of the corresponding position is calculated to satisfy the following conditions:
wherein RPS k is the response value of the position to be inserted; RPS i is the logging response value of the ith probe; d ik is the weight coefficient of the distance from the ith probe position to the kth point; c i a predetermined coefficient to be increased for ensuring compatibility;
Dividing the section of the shaft according to m multiplied by m grids by combining the relation between the radius of the array rotor blade and the radius of the section of the shaft, wherein each grid can completely contain the array blade, and then m is satisfied,
Wherein [ (formula) is rounding operation;
The interpolation operation obtains the topmost position of the probe and the mapping position of the residual probe, namely the rotor response value at the corresponding position when the instrument does not rotate, the apparent fluid velocity RPS xy 'at the corresponding local position is obtained by combining the formulas (3) to (5), the local fluid velocity V axy' at each position is obtained by further combining the formulas (8) and (9), the fluid velocity in the horizontal shaft is expressed as,
Wherein A xy is the area of each grid area after the grids are segmented according to m rows and m columns; v axy is apparent fluid velocity for the corresponding grid region;
The total flow of wellbore multiphase fluid is expressed as,
Q＝Va·PC＝0.25×24×60×πR2Va (18)
Wherein PC is the horizontal well bore tubing constant; q is the total flow of the multiphase flow of the horizontal well bore.
Compared with the prior art, the invention has the following beneficial effects:
(1) The horizontal well array turbine flowmeter adopts a combined structure of the central rotor and the surrounding inner and outer layers of staggered annular array rotors, so that the full coverage of the section of a horizontal shaft can be realized as much as possible, the influence caused by uneven distribution of fluid media is effectively overcome, the monitored fluid speed information is more comprehensive, and the accuracy is higher;
(2) The invention adopts the differential design of the sizes of the central rotor and the peripheral array rotor blades, can effectively overcome the limitation of weakening the central flow in the existing horizontal well array flow monitoring technology, and reflects the speed profile information of the horizontal shaft as truly as possible;
(3) The method and the device correct the starting speed according to the forward rotation and reverse rotation conditions in the measuring process of the rotor flowmeter, and effectively improve the calculation precision of the rotor apparent fluid speed;
(4) According to the invention, aiming at the monitoring data when the array turbine flowmeter rotates randomly in the process of loading and unloading the well, firstly, a Gaussian radial basis interpolation method is adopted to obtain all grid area array rotor response values, and then, a local position apparent fluid speed is calculated according to the grid area, so that the influence of the direct intersection method on the apparent fluid speed due to the rotation of the instrument in the data processing process of the conventional horizontal well array flowmeter is effectively overcome, and the calculated wellbore apparent fluid speed has higher precision.
In general, the invention realizes the full coverage measurement of the wellbore fluid velocity profile in the flow process of the unconventional oil and gas reservoir horizontal wellbore oil, gas and water multiphase fluid, and accurately calculates the total flow of the wellbore multiphase fluid based on monitoring data, thereby laying a foundation for dynamic evaluation of each production zone in the unconventional oil and gas reservoir development horizontal well production.
Drawings
Fig. 1 is a schematic structural diagram of a horizontal well array turbine flowmeter according to an embodiment of the present invention.
FIG. 2 is a schematic cross-sectional view of a wellbore profile with an array turbine rotor fully deployed during a flowmeter of the present invention.
FIG. 3 is a schematic cross-sectional view of a wellbore during a flowmeter of the present invention in which the array turbine rotor is fully deployed and the instrument is rotated.
FIG. 4 is a grid-like cut-off schematic view of a well bore distribution section after the array turbine rotor is fully opened and the instrument is rotated during the flow meter logging process according to the present invention.
Detailed Description
The invention is further described in connection with the following detailed description, in order to make the technical means, the creation characteristics, the achievement of the purpose and the effect of the invention easy to understand.
In the description of the present invention, it should be noted that the directions or positional relationships indicated by the terms "upper", "lower", "inner", "outer", "front", "rear", "both ends", "one end", "the other end", etc. are based on the directions or positional relationships shown in the drawings, are merely for convenience of describing the present invention and simplifying the description, and do not indicate or imply that the devices or elements referred to must have a specific direction, be configured and operated in the specific direction, and thus should not be construed as limiting the present invention. Furthermore, the terms "first," "second," and the like, are used for descriptive purposes only and are not to be construed as indicating or implying relative importance.
In the description of the present invention, it should be noted that, unless explicitly specified and limited otherwise, the terms "mounted," "provided," "connected," and the like are to be construed broadly, and may be fixedly connected, detachably connected, or integrally connected, for example; 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 invention will be understood in specific cases by those of ordinary skill in the art.
Referring to fig. 1, the horizontal well array turbine flowmeter provided by the invention mainly comprises a cable head 01, a center shaft main body 02, a voltage regulating system 03, a data transmission system 04, a signal conversion system 05, a control system 06, 1 telescopic center turbine rotor 07, 8 double-layer layout array arms 08, 8 identical high-sensitivity micro turbine rotors 09 with the numbers of 1-8, a telescopic center shaft 10 and a conical head 11.
The middle shaft main body 02 is made of cylindrical steel materials with the outer diameter of 43mm, for example, and is of a coaxial structure, so that the underground high-temperature high-pressure environment can be effectively adapted; the voltage regulating system 03, the data transmission system 04, the signal conversion system 05 and the control system 06 are arranged in parallel in the steel shell cavity of the middle shaft main body 02 and are connected in sequence. The size of the outer diameter is positively correlated with the inner diameter of the horizontal well and is smaller than the inner diameter size of the horizontal well.
The upper portion of axis main part 02 is connected with cable head 01, can realize the direct connection with logging cable, realizes the connection with ground power supply system and signal acquisition system, namely: ground power supply and traction are realized.
The voltage regulating system 03 realizes voltage intensity conversion and supplies power to all turbine rotors; the control system 06 realizes the control of the extension and the retraction of the array arms and the opening and the closing of the rotor blades and controls the extension and the retraction of the telescopic central shaft; the signal conversion system 05 converts a rotation pulse signal of the turbine rotor into a current signal and outputs the current signal to the ground acquisition system. The data transmission system realizes stable output of signal data.
The middle of the lower part of the middle shaft main body 02 is connected with a relatively thin telescopic center shaft 10, the diameter of which can be a rigid material with the diameter of 5mm, and the telescopic center shaft can freely stretch. As shown in fig. 2,8 double-layer layout array arms 08 arranged in an externally staggered 2-layer manner are connected with the upper middle shaft main body 02, the double-layer layout array arms 08 are steel spring arms, the annular included angle between each layer of spring arms is fixed by 0.5 pi, and the spring arms are fully opened and exert a centralizing effect; the included angle formed by every two adjacent array arms and the central shaft is 45 degrees; the middle positions of the 8 staggered array arms are provided with the identical 8 high-sensitivity miniature turbine rotors 09, wherein the numbers 1-4 are the outer-layer turbine rotors and the numbers 5-8 are the inner-layer turbine rotors, so that the speed monitoring of the shaft section position array is realized. A high-sensitivity telescopic central turbine rotor 07 is mounted on the central rotor shaft, the number of the telescopic central turbine rotor is 0, the radius of the central rotor blade is larger than the diameter of the outer 8 array rotors, and the ratio of the diameter of the blades of the turbine rotor 07 to the diameter of the micro array turbine rotor 09 is 3:1. The upper part and the lower part of the central rotor are respectively provided with a spring which surrounds the central shaft, and the central rotor is pushed to open and close along with the extension and the retraction of the array arms, so that the functions of assisting the central turbine rotor to stretch and push to fix are achieved. The telescopic central shaft 10 and the lower part of the double-layer layout array arm 08 are connected with the conical head 11, acting to secure the array arm and the central shaft.
When the downhole logging is started, the array arm is controlled to be opened, as shown in fig. 3, at the moment, the 8 micro turbine rotor blades are opened, and the central rotor is pushed to be opened to the same cross section with the 8 micro rotors under the action of the spring; when the instrument is in the well or the logging construction is completed, the array arm is controlled to be folded, at the moment, the 8 micro turbine blades are contracted, the central rotor is also automatically contracted along with the folding of the array arm, and the whole instrument is in a regular cylindrical structure, so that the safe well lifting and well descending of the instrument are realized. The lower part of the central rotor shaft is connected with a conical fixing device, so that the safe fixing of the central turbine shaft and 8 array arms is realized.
Aiming at the difficult problem of complex speed profile caused by uneven distribution of special well structures and fluid media of the horizontal well, the double-layer array turbine distribution and central turbine rotor layout structure is adopted, the instrument principle is reliable, the operation is convenient, and the instrument is suitable for monitoring fluid speed profile information of oil-gas-water single-phase, two-phase and multi-phase fluid flow conditions of the horizontal well with different structures, so that the fluid speed distribution characteristics of the horizontal well can be accurately reflected.
Based on the same inventive concept, the embodiment of the invention also provides a measuring method of the horizontal well array turbine flowmeter, wherein the horizontal well array turbine flowmeter is used as a measuring instrument for measuring, and the measuring method comprises the following steps:
1) Debugging and instrument descending. The ground is connected with the instrument system, the power-on checking system works normally, the operation control system checks whether the array arm opens and closes normally, if so, the instrument array arm is ensured to be in a complete closing state, the instrument is driven into the well in an oil pipe transmission mode, and the ground system is kept to supply power to the instrument in the well driving process.
2) Positioning and monitoring. And determining the depth of the monitored target interval by combining the well structure of the target well and the perforating interval information, stopping descending when the instrument descends to about 200m from the top of the uppermost perforating interval, opening a control valve at the moment, ensuring that a spring arm and a rotor are in a fully opened state, performing descending measurement at the speed V l1 (the time measurement speed of the instrument is positive), simultaneously monitoring and recording output signals of the instrument, wherein the output signals of a central rotor are RPS 01, the output signals of 8 array rotors are RPS11、RPS21、RPS31、RPS41、RPS51、RPS61、RPS71、RPS81, respectively, stopping descending measurement when the instrument descends to the position below the lowest perforating interval or the bottom of the well cannot descend further, and at the moment, measuring the top of the target interval at the same speed-V l1, wherein the output signals of the central rotor are RPS 02, and the output signals of 8 array rotors are RPS12、RPS22、RPS32、RPS42、RPS52、RPS62、RPS72、RPS82, respectively and upwards lifted to the top of the target interval.
3) The measurement was repeated a plurality of times. Increasing the instrument well descending speed to V l2, and repeating the step 2) to measure the position below the lowest perforation section or stopping the well descending when the well bottom cannot be further descended; then, the top position of the target layer section is measured at the same speed-V l2, and output signals of the central rotor and the array rotor in all lifting and lowering processes are recorded; increasing tool running speed to V l3＝Vl1+2ΔV、Vl4 =
And V l1 +3DeltaV, repeating the steps until all the operations are completed, and recording to obtain 8 groups of instrument speeds and corresponding rotor response signals.
4) And (5) completing testing and instrument well lifting. And (3) operating a ground control system to retract the instrument arm, stopping power supply, lifting the instrument to the ground, and completing the test.
Further, in the step 3), the method for calculating the total flow of the fluid under the horizontal well by using the monitoring data of the turbine flowmeter of the horizontal well array comprises the following steps 1-4, referring to fig. 2-4:
Step 1: based on the horizontal well array turbine flowmeter structure, the opening degree of the annular array turbine rotor probe can be freely adjusted, so that the distance between the outer 4 annular array probes and the center of the shaft is expressed as,
rc＝kc·R (1)
The inner layer 4 annular array probes are shown as being spaced from the center of the wellbore,
rm＝km·R (2)
Wherein k c is the opening degree of the outer layer 4 array probes, and the fraction;
k m —the opening degree of the inner layer 4 array probes, the decimal;
r c -the positions of the center points of the sections of the wellbores, which are 1,2, 3 and 4, of the outer layer 4 array probes are m (m);
r m -the positions of center points of the sections of the wellbores, which are the positions of the center points of the sections of the wellbores, are the positions of the inner layer 4 array probes with the numbers of 5,6,7 and 8, and m;
and R is the distance from the center when the outer layer 4 annular array probes are fully opened, and is equal to the radius of the section of the shaft, and m.
Step 2: when the No.1 turbine rotor probe is positioned at the top of a horizontal shaft in 8 measuring processes or any one of the No.1, 2,3 and 4 probes rotates the top of the section of the shaft in a certain measuring process, the clockwise rotation angle of the No.1 probe relative to the highest position of the section of the shaft is theta j =0.5.npi (n=0, 1,2,3 and …), at the moment, the rotor probes exist at all position points when the 8 array rotor probes do not rotate relative to an instrument, the central rotor is always positioned at the central position of the section of the shaft in the measuring process, the fluid apparent velocity V ai' at each probe position is directly obtained by the method of measuring the turbine rotational speed vs. cable speed up and down,
V′ai＝-bi/Ki (5)
Wherein V' ai is the calculated apparent fluid velocity at the ith rotor, meters per minute (m/min); RPS ij is the response value of the ith rotor in the jth measurement, and the same position in the intersection calculation process is calculated according to the actual probe value, and the rotation/second (rad/s); v lj is the instrument speed in the j-th pass, meters per minute (m/min); i is rotor number=0, 1,2 … …; j is measurement sequence number j=1, 2 … … 8; n is the number of effective measuring points, and 8 times of measurement are effective and equal to 8; k i is a rotor constant obtained by fitting the ith rotor and is related with the property of the rotor; b i is the intercept on the rotor speed axis at the time of the ith rotor engagement.
When the rotor response has positive rotation and reverse rotation characteristics, fitting calculation is carried out on the positive rotation rotor response and the reverse rotation rotor response by adopting a formula (3) and a formula (4), the RPS response value in the positive rotation process is positive, the RPS response value in the reverse rotation process is negative, the apparent fluid velocity of each rotor obtained in the positive rotation process is,
V′ai Positive direction ＝-bi Positive direction /Ki Positive direction (6)
The fluid velocity at each rotor determined during the reversal process is,
V′ai Reverse-rotation ＝-bi Reverse-rotation /Ki Reverse-rotation (7)
The apparent fluid velocity of each rotor at this point is indicated as,
When the rotor is rotated all the way forward or all the way backward,
Vai＝|V′ai|+|Vai Zero (zero) | (9)
Wherein V' ai Positive direction is the calculated apparent fluid velocity in the forward rotation of the ith rotor, meter/min; v' ai Reverse-rotation is the calculated apparent fluid velocity at the time of inversion of the ith rotor, meters per minute (m/min); b i Positive direction is the intercept on the rotor rotating speed shaft obtained by fitting when the ith rotor rotates positively; b i Reverse-rotation is the intercept on the rotor rotating speed shaft obtained by fitting when the ith rotor is reversed; k i Positive direction is a rotor constant obtained by fitting when the ith rotor rotates positively; k i Reverse-rotation is a rotor constant obtained by fitting when the ith rotor is reversed; v ai Zero (zero) is the calculated fluid velocity in meters per minute (m/min) of the ith rotor at zero flow interval for the instrument. Based on the turbine rotor distribution structure of the array turbine flowmeter, the section of the shaft is divided into 9 areas, as shown in fig. 4, the areas are respectively a rotor distribution area No. 0, a rotor distribution area No. 5, 6, 7 and 8, and a rotor distribution area No. 1,2, 3 and 4 from inside to outside, the distances between the outer boundaries of the sub areas and the center of the section of the shaft are R·rT/(rT+2rt)、R·(rT+rt)/(rT+2rt)、R·rT/(rT+2rt). respectively, the corresponding areas of the rotor probe control areas are shown as,
The fluid velocity in the horizontal bore is indicated as,
Wherein A 0～A8 is the area represented by 9 areas after the section of the shaft is cut, and the square meter (m 2); a is the integral sectional area of the shaft; v a is horizontal wellbore fluid velocity, meters per minute (m/min); r is the radius of the section of the horizontal shaft and meters (m); r t is the radius of the rotor blade of the array 1-8, m; r T is the rotor blade radius number 0, meters (m).
Step 3: when the array turbine flowmeter rotates randomly in the logging process, most of actual logging construction is occupied under the condition, the spatial positions corresponding to the other rotors measured each time are changed except for the rotor with the center number 0, and at the moment, if the fluid velocity of the local position of the array rotor is obtained by directly adopting the methods of the formula (3) and the formula (4), the error of the obtained fluid velocity of the array rotor is extremely large. At this time, by combining the distribution characteristics of fluid media in the horizontal shaft and the distribution characteristics of the velocity profile, assuming that the clockwise rotation angle of the No. 1 probe relative to the highest position of the shaft section in each logging process is theta j, the space coordinates of the double-layer annular array rotor probe in the horizontal shaft can be obtained by taking the position of the No. 0 probe as the origin of coordinates,
Probe 0: (0,0)
Probe 1: (k c·R·sinθj,kc·R·cosθj)
Probe 2: (k c·R·sin(θj+0.5π),kc·R·cos(θj +0.5pi)
Probe 3: (k c·R·sin(θj+π),kc·R·cos(θj +pi)
Probe 4: (k c·R·sin(θj+1.5π),kc·R·cos(θj +1.5pi)
Probe 5:
probe 6:
probe 7:
Probe 8:
wherein, θ j is the angle (rad) of clockwise rotation of the No. 1 probe relative to the highest position of the section of the shaft.
Because the instrument rotates randomly in the logging process, 9 rotor responses are interpolated by adopting a Gaussian radial basis function method aiming at each measurement data, the weight occupied by each probe of each point to be estimated is calculated by utilizing a Gaussian function, and the descending control coefficients in the horizontal direction and the vertical direction are introduced, so that the value of the point to be estimated is calculated accurately according to the coordinates of the known probes and the corresponding values, the corresponding Gaussian weight calculation method is as shown in the formula,
Wherein, (X i,Yi) is the coordinate value of the probe i; (x, y) is the point coordinate value to be estimated; m and n are decreasing control coefficients in the horizontal and vertical directions of the section of the shaft, the larger m is, the slower the attenuation in the horizontal direction is, the larger n is, the slower the attenuation in the vertical direction is, m and n are related to the radius of the shaft, generally, the value of m is 1/2 of the diameter, the value of n is 1/6 of the diameter, and the response value of each position point to be solved can be obtained according to the actual measurement value of each probe according to the required weight.
The logging prediction response value of each point of the cross section of the shaft is obtained through a Gaussian radial basis function interpolation matrix, and the response value of the corresponding position is calculated to satisfy the following conditions:
Wherein RPS k is the response value of the position to be inserted; RPS i is the logging response value of the ith probe; d ik is the weight coefficient of the distance from the ith probe position to the kth point; the coefficient to be determined increased by C i to ensure compatibility is not limited by the grid system, and the coefficients corresponding to different detection values are different.
Dividing the section of the shaft according to m multiplied by m grids by combining the relation between the radius of the array rotor blade and the radius of the section of the shaft, wherein each grid can completely contain the array blade, and then m is satisfied,
In the formula, [ ] is a rounding operation.
The interpolation operation obtains the topmost position of the probe and the mapping position of the residual probe, namely the rotor response value at the corresponding position when the instrument does not rotate, the apparent fluid velocity RPS xy 'at the corresponding local position is obtained by combining the formulas (3) to (5), the local fluid velocity V axy' at each position is obtained by further combining the formulas (8) and (9), the fluid velocity in the horizontal shaft is expressed as,
Wherein A xy is the area of each grid area after the grids are cut according to m rows and m columns, and m 2;Vaxy is the apparent fluid velocity of the corresponding grid area, m/min.
The total flow of wellbore multiphase fluid is expressed as,
Q＝Va·PC＝0.25×24×60×πR2Va (18)
Wherein PC is the horizontal well bore tubing constant; q is the total flow of multiphase flow of the horizontal shaft, square/day (m 3/d).
The measuring method of the horizontal well array turbine flowmeter provided by the embodiment of the invention can realize dynamic and efficient monitoring and accurate quantitative evaluation of horizontal well production in the unconventional oil and gas reservoir development process. The array turbine flowmeter comprises a central shaft main body, a voltage regulating system, a data transmission system, a signal conversion system, a control system, a central turbine rotor, 8 double-layer layout array arms, 8 high-sensitivity micro turbine rotors in double-layer distribution and a centralizer. The instrument fully considers the distribution of the fluid medium of the horizontal shaft, the distribution of the velocity profile, the rotation of the instrument, the contribution difference of the probe and the influence of the fluid property in the well logging process, and the established method for quantitatively calculating the apparent fluid velocity after calculating the turbine rotating speed of the local turbine at the mapping position based on Gaussian radial basis function interpolation can accurately calculate the fluid flow of the shaft, thereby providing technical support for the accurate quantitative evaluation of the dynamic state of each production zone of the horizontal well for unconventional oil and gas reservoir development and the optimization and adjustment of the development scheme of the next stage.
It will be apparent to those skilled in the art that various modifications and variations can be made to the present invention without departing from the spirit or scope of the invention. Thus, it is intended that the present invention also include such modifications and alterations insofar as they come within the scope of the appended claims or the equivalents thereof.
Claims (7)
1. A horizontal well array turbine flowmeter, comprising: the device comprises a cable head, a center shaft main body, a voltage regulating system, a data transmission system, a signal conversion system, a control system, 1 telescopic center turbine rotor, 8 double-layer layout array arms, 8 identical array turbine rotors, a telescopic center shaft and a conical head;
The cable head is connected with the upper end of the center shaft main body and is used for being connected with a logging cable; the inside of the middle shaft main body is sequentially provided with: the voltage regulating system, the data transmission system, the signal conversion system and the control system are sequentially connected; the control system is used for controlling the extension and retraction of the telescopic central shaft and the extension and retraction of the array arms; the signal conversion system is used for converting a turbine rotor rotation frequency signal into a current signal for transmission; the data transmission system realizes stable output of signal data; the voltage regulating system is used for regulating the ground voltage to the voltage intensity required by the flowmeter;
The lower end of the middle shaft main body is connected with one end of the 8 double-layer layout array arms near the edge, and the center of the middle shaft main body is connected with one end of the telescopic center shaft; the middle position of the telescopic central shaft is provided with 1 telescopic central turbine rotor;
the 8 array turbine rotors are correspondingly installed at the middle positions of the 8 double-layer layout array arms respectively;
the other ends of the 8 double-layer layout array arms are fixedly connected with the conical head.
2. The horizontal well array turbine flowmeter of claim 1, wherein said bottom bracket body is of a coaxial construction of cylindrical steel material of a predetermined outer diameter.
3. The horizontal well array turbine flowmeter of claim 1, wherein said 8 double-layered layout array arms are comprised of an inner layer and an outer layer, each layer being comprised of 4 spring arms arranged uniformly in a ring shape; in the 8 double-layer layout arrays, the included angle formed by every two adjacent array arms and the telescopic central shaft is 45 degrees.
4. The horizontal well array turbine flow meter of claim 1, wherein the ratio of the vane diameter of said telescoping center turbine rotor to the vane diameter of said array turbine rotor is 3:1.
5. The horizontal well array turbine flowmeter of claim 1, wherein said telescoping center turbine rotor is connected up and down with a flexible spring surrounding said telescoping center shaft, respectively.
6. A measurement method of a horizontal well array turbine flowmeter, characterized in that the measurement is performed using the horizontal well array turbine flowmeter according to any one of claims 1 to 5 as a measurement instrument, the measurement method comprising:
1) Debugging and instrument well descending:
detecting whether the instrument works normally, if so, ensuring that 8 double-layer layout array arms of the instrument are in a fully folded state, and adopting an oil pipe transmission mode to perform well descending, wherein a ground system is kept to supply power to the instrument in the well descending process;
2) Positioning and monitoring:
Determining a monitoring target interval by combining the well structure of the target well and perforation interval information, stopping the well when the instrument is lowered to about 200m from the top of the uppermost perforation interval, opening a control system at the moment, ensuring that a spring arm and a rotor are in a fully opened state, and defining the lowering time measuring speed of the instrument to be positive;
The method comprises the steps of performing downward measurement at the speed V l1 while monitoring and recording instrument output signals, wherein the output signals of a telescopic central turbine rotor are RPS 01, the output signals of 8 array rotors are RPS11、RPS21、RPS31、RPS41、RPS51、RPS61、RPS71、RPS81, respectively, stopping the downward measurement when the instrument is lowered to a position below a lowest perforation section or the bottom of a well cannot be further lowered to the well, and the top position of a target interval is measured at the same speed-V l1, wherein the output signals of the central rotor are RPS 02, and the output signals of 8 array rotors are RPS12、RPS22、RPS32、RPS42、RPS52、RPS62、RPS72、RPS82, respectively and are lifted to the top position of the target interval, so that one-time test operation is completed;
3) Repeated measurements are performed several times:
Increasing the instrument well descending speed to V l2, and repeating the step 2) to measure the position below the lowest perforation section or stopping the well descending when the well bottom cannot be further descended; then, the top position of the target layer section is measured at the same speed-V l2, and output signals of the telescopic central turbine rotor and the array turbine rotor in all lifting and lowering processes are recorded; increasing the instrument well-down speed to V l3＝Vl1+2ΔV、Vl4＝Vl1 +3DeltaV, repeating the steps until all operations are completed, and recording 8 groups of instrument speeds and corresponding rotor response signals at the same time;
4) Completing testing and instrument well lifting:
And (3) operating a ground control system to retract the array arms, stopping power supply, lifting the instrument to the ground, and completing the test.
7. The method of claim 6, wherein the step of calculating the total flow rate of the fluid in the horizontal well by using the 8 sets of instrument speeds and the corresponding rotor response signals obtained by recording is as follows:
Step 1: based on the structure of the horizontal well array turbine flowmeter, the opening degree of the annular array turbine rotor probe can be freely adjusted, so that the distance between the outer layer 4 annular array probes and the center of the shaft is expressed as,
rc＝kc·R (1)
The inner layer 4 annular array probes are shown as being spaced from the center of the wellbore,
rm＝km·R (2)
Wherein k c represents the opening degree of the outer layer 4 array probes;
K m represents the opening degree of the inner layer 4 array probes;
r c represents positions of center points of the sections of the wellbores, which are away from the numbers 1,2, 3 and 4 of the outer layer 4 array probes;
r m represents the positions of the center points of the sections of the wellbores, which are separated by the numbers 5, 6, 7 and 8 of the inner layer 4 array probes;
R represents the distance from the center when the outer layer 4 annular array probes are fully opened, and is equal to the radius of the section of the shaft;
Step 2: when the number 1 array rotor probe is positioned at the top of a horizontal shaft in the 8 measuring processes or any one of the number 1,2,3 and 4 probes rotates the top of the section of the shaft in a certain measuring process, the clockwise rotation angle of the number 1 probe relative to the highest position of the section of the shaft is theta j = 0.5 n pi, n = 0,1,2 and 3 …, at the moment, the rotor probes exist at all position points when the 8 array rotor probes do not rotate relative to an instrument, the central rotor is always positioned at the central position of the section of the shaft in the measuring process, the fluid apparent velocity V ai' at each probe position is directly obtained by adopting a method of comparing the rotational speeds of an upper turbine with a lower turbine and is expressed as,
V'ai＝-bi/Ki (5)
Where V' ai is the calculated apparent fluid velocity at the ith rotor; RPS ij is the response value of the ith rotor in the jth measurement, and the same position in the intersection calculation process is calculated according to the actual probe value; v lj is the instrument speed at the j-th pass of the measurement; i is rotor number=0, 1,2 … …; j is measurement sequence number j=1, 2 … … 8; n is the number of effective measuring points, and 8 times of measurement are effective and equal to 8; k i is a rotor constant obtained by fitting the ith rotor and is related with the property of the rotor; b i is the intercept on the rotor speed axis at the time of the ith rotor engagement;
when the rotor response has positive rotation and reverse rotation characteristics, fitting calculation is carried out on the positive rotation rotor response and the reverse rotation rotor response by adopting a formula (3) and a formula (4), the RPS response value in the positive rotation process is positive, the RPS response value in the reverse rotation process is negative, the apparent fluid velocity of each rotor obtained in the positive rotation process is,
V'ai Positive direction ＝-bi Positive direction /Ki Positive direction (6)
The fluid velocity at each rotor determined during the reversal process is,
V'ai Reverse-rotation ＝-bi Reverse-rotation /Ki Reverse-rotation (7)
The apparent fluid velocity of each rotor at this point is indicated as,
When the rotor is rotated all the way forward or all the way backward,
Vai＝|V'ai|+|Vai Zero (zero) | (9)
Wherein V' ai Positive direction is the calculated apparent fluid velocity when the ith rotor rotates positively; v' ai Reverse-rotation is the calculated apparent fluid velocity at which the ith rotor is reversed; b i Positive direction is the intercept on the rotor rotating speed shaft obtained by fitting when the ith rotor rotates positively; b i Reverse-rotation is the intercept on the rotor rotating speed shaft obtained by fitting when the ith rotor is reversed; k i Positive direction is a rotor constant obtained by fitting when the ith rotor rotates positively; k i Reverse-rotation is a rotor constant obtained by fitting when the ith rotor is reversed; v ai Zero (zero) is the i-th rotor apparent fluid velocity calculated by the instrument in the zero flow interval; based on the turbine rotor distribution structure of the array turbine flowmeter, the section of the shaft is divided into 9 areas, namely a rotor distribution area No. 0, a rotor distribution area No. 5, 6, 7 and 8 and a rotor distribution area No. 1, 2, 3 and 4 from inside to outside, the distances between the outer boundaries of the sub areas and the center of the section of the shaft are R·rT/(rT+2rt)、R·(rT+rt)/(rT+2rt)、R·rT/(rT+2rt); respectively, the corresponding areas of the rotor probe control areas are shown as,
The fluid velocity in the horizontal bore is indicated as,
Wherein A 0～A8 is the area represented by 9 areas after the section of the shaft is cut; a is the integral sectional area of the shaft; v a is horizontal wellbore fluid velocity; r is the radius of the section of the horizontal shaft; r t is the radius of the number 1-8 array rotor blade; r T is rotor blade radius number 0;
Step 3: by combining the distribution characteristics of fluid media in the horizontal shaft and the distribution characteristics of the velocity profile, the space coordinates of the double-layer annular array rotor probe in the horizontal shaft can be calculated as follows by taking the position of the probe No. 0 as the origin of coordinates assuming that the clockwise rotation angle of the probe No. 1 relative to the highest position of the section of the shaft is theta j in each logging process,
Probe 0: (0,0)
Probe 1: (k c·R·sinθj,kc·R·cosθj)
Probe 2: (k c·R·sin(θj+0.5π),kc·R·cos(θj +0.5pi)
Probe 3: (k c·R·sin(θj+π),kc·R·cos(θj +pi)
Probe 4: (k c·R·sin(θj+1.5π),kc·R·cos(θj +1.5pi)
Probe 5:
probe 6:
probe 7:
Probe 8:
Wherein, theta j is the angle of clockwise rotation of the No.1 probe relative to the highest position of the section of the shaft; because the instrument rotates randomly in the logging process, 9 rotor responses are interpolated by adopting a Gaussian radial basis function method aiming at each measurement data, the weight occupied by each probe of each point to be estimated is calculated by utilizing a Gaussian function, and the descending control coefficients in the horizontal direction and the vertical direction are introduced, so that the value of the point to be estimated is calculated accurately according to the coordinates of the known probes and the corresponding values, the corresponding Gaussian weight calculation method is as shown in the formula,
Wherein, (X i,Yi) is the coordinate value of the probe i; (x, y) is the point coordinate value to be estimated; m and n are decreasing control coefficients in the horizontal and vertical directions of the section of the shaft, and according to the calculated weight, the response value of each position point to be calculated can be calculated according to the measured value of each probe;
The logging prediction response value of each point of the cross section of the shaft is obtained through a Gaussian radial basis function interpolation matrix, and the response value of the corresponding position is calculated to satisfy the following conditions:
wherein RPS k is the response value of the position to be inserted; RPS i is the logging response value of the ith probe; d ik is the weight coefficient of the distance from the ith probe position to the kth point; c i a predetermined coefficient to be increased for ensuring compatibility;
Dividing the section of the shaft according to m multiplied by m grids by combining the relation between the radius of the array rotor blade and the radius of the section of the shaft, wherein each grid can completely contain the array blade, and then m is satisfied,
Wherein [ (formula) is rounding operation;
The interpolation operation obtains the topmost position of the probe and the mapping position of the residual probe, namely the rotor response value at the corresponding position when the instrument does not rotate, the apparent fluid velocity RPS xy 'at the corresponding local position is obtained by combining the formulas (3) to (5), the local fluid velocity V axy' at each position is obtained by further combining the formulas (8) and (9), the fluid velocity in the horizontal shaft is expressed as,
Wherein A xy is the area of each grid area after the grids are segmented according to m rows and m columns; v axy is apparent fluid velocity for the corresponding grid region;
The total flow of wellbore multiphase fluid is expressed as,
Q＝Va·PC＝0.25×24×60×πR2Va (18)
Wherein PC is the horizontal well bore tubing constant; q is the total flow of the multiphase flow of the horizontal well bore.
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