Method for measuring debit of oil wells group

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes measuring average value of flow during adequately picked time for each well of group with successive - according to given program - connection of wells to measuring device and following recalculation of debit to day productiveness. At the same time the most dynamic well of group is selected on basis of one of most unstable parameters. Numeric value of relative quadratic error δ3 of average flow value m(q) is set and recorded in memory of computer, for example, industrial controller. Period of scanning for this well is determined. With same period remaining wells of the group are scanned. Scanning period for each I of them is corrected by comparison of current - actual - relative average quadratic error δmi of average flow value q1 with previously set δ3 from conditions δ≥δ3(1+K); δmi≤δ3(1-K), where K - coefficient for limiting changing range δmi, defining necessity of correction of scanning period for I well towards decrease or increase. If switching moments for measurements of two or more wells from group coincide, order of their scanning is set in accordance to decrease of productiveness of these wells.

EFFECT: higher efficiency.

2 cl, 1 ex

 

The invention relates to a method of measuring the flow rate of oil wells and can be used in information-measuring systems of production, transport, oil, gas and water.

The known method [1] measuring the productivity of wells by measuring the average consumption values for adequately selected time during a fixed time interval, namely at the stage adaptation of determining the magnitude of the relative changes in the productivity of wells and give the necessary measurement time. At the stage of measurement determine the volume of liquid passed through the meter during the time specified on the adaptation stage. However, it follows that the amount of data received for a certain pre-adaptation time may be insufficient to predict the required duration of the measurement, and the value obtained performance values may be inaccurate.

Also known method [2] measurement of the flow rate of the wells, which consists in measuring the quantity of fluid passed through the meter during a fixed time interval with conversion to daily performance, the optimal measurement time chosen by a flexible program based on the comparison of the travel time of a fixed quantity of liquid in the control phase measurement with settings this is Onen time and in the stage of the main measuring the flow rate is determined by counting meter the volume of fluid over a period of time determined at the stage of control.

Measurement in this method is carried out in three stages. At the first stage control measure the time of passage of a fixed amount (weight) of liquid through the meter. In the second step compares the results of the test measurements with the results of previous measurements of the production rate of this well and with a reference time setting. Based on this comparison, select the required measurement time for a given constant error averaging and volume control. In the third stage using the meter to produce the reference volume (weight) of the liquid at the time of measurement defined in the second phase, and calculate the daily performance of the well.

This method, first, the relatively complicated to implement, and secondly, when it is used for automated group units type “Satellite” spent considerable time on the measurement of the output of one well, the more the total time of measurement of the flow rate of a group of wells.

The closest technical solution, i.e. the prototype as a way [3] measuring the productivity of wells by measuring the average consumption values for appropriately chosen time, in order to improve the accuracy measure is by setting the control time in the measurement process, determine the average consumption values and their mean-square deviation of discretely increasing time intervals, comparing each subsequent value with the previous and complete measurement of the achievement difference between two adjacent mean square deviation set point.

In this way, the optimal time measurement of the flow rate of each well from a group of wells come with iterations (method of successive approximations, starting a measurement with a known flow rate of least time. According to the results of several measurements are averaged measured value and its standard deviation (and σ1). The resulting value σicompared with the specified value average standard deviation of the result of the arithmetic mean σy. When σyσ1measurement of the well is terminated and the signal on connection the next hole. When σy1increasing the measurement time and again calculates the arithmetic mean of the measured valueand its mathematical expectation σ2. Next, after a rather complicated procedure, calculates the difference between the mean square of the deviations produced new Cree is ERI (not given here), and the system again has two outcomes: either the measurement ends, or is added to increase the measurement time. With increasing measurement time determined new valuesand σ3and only ifwhere n is the total number of intervals Δ tnthe measure, included in a specified duration of measurement equal to tn=Δ t+nΔ tnissued the obtained value of xn.

The difficulty with this method of measurement is obvious, and the selected criteria will be effective if a sufficiently large number of measurements at each step of iterations. When a significant number of wells connected to alternately measure the flow rate of the i-th well, this method leads to unreasonably long time measurement of the flow rate of a group of wells. And when you consider that to get a true xiwill require a number of measurements to determine the daily production rate of each well, the application of this method is hardly justified.

Using as a criterion the numerical values of average standard deviation of σ () average consumption is unjustified, because σ () unstable and on the procedure for finding the optimal measurement time will be imposed more the positive uncertainty, due to unforeseen change σ ().

In addition, the search for the optimal measurement time should be linked to the period of the survey well.

Thus, the goal of the proposed method is to provide a well-known way of measuring the flow rate of a group of oil wells more high consumer properties by giving adaptability when selecting the sampling period of each well from a group of wells.

The required technical result in the claimed method, according to the prototype method, consisting in the measurement of average consumption values for adequately selected time for each specific well with alternate according to a given program by connecting the wells to the meter, the subsequent recalculation of the flow rate in productivity is achieved by choosing one of the most unstable flow parameters the dynamic borehole from the group, set and recorded in the memory of the computer, for example, an industrial controller, the numerical value of the relative root mean square error δ3average flow rate m(q), define the polling interval of this well, the poll with the same period the rest of the wells group, adjust the polling period for each i-th of them by comparing the current relative root mean square error ´ mithe average value of the flow qiwith the previous δ3terms and conditions:

δmiδ3(1+K); δmiδ3(1-K)

where K - coefficient restrictions of range δmigoverning the necessity of adjusting the sampling period of the i-th well in the direction of increase or decrease.

An additional difference of the proposed method of measuring the flow rate of a group of oil wells is that the coincidence of the shift points on the measurement of the flow rate of the two or more wells from a group, the order of their survey set in descending order of performance of these wells.

Note that from well-known sources of information (including patent) is not identified ways identical to the offer, and/or methods with a set of essential features (including distinctive), equivalent to the essential features of the proposed technical solutions and showing the same new properties that allow you to achieve the desired technical result in implementation. This suggests that the proposed technical solution is new, not obvious, industrially applicable and meets the “criteria” of the invention.

Here is an example of a specific implementation of the method.

There are 8 wells with the following numerical values of the s their average daily expenditure:

15, 30, 40, 25, 20, 60, 70 and 75 m3a day.

One of the parameters characterizing the dynamics of the wells, for example, the pressure (or flow)defined the dynamic well with known industrial sound level meters or spectrum analyzers, sensors which can be installed on the mouth of the wells (directly in the stream or on the body of the pipe). Defines the polling interval for this well in one of known methods, for example, according to the average number of intersections of the flow line zero level, which is functionally connected with the period of the survey a random function or the correlation interval [4]. Let the sampling period t0=2 hours

Set the relative root mean square error δ3the medium flow through the borehole

where σ (mq) - the mean square error of the mean flow mq; σq- the standard deviation of the process (flow).

The numerical value of the relative error is more stable (normalized)than σ (mq)because it takes into account the standard deviation of consumption.

With sampling period t0=2 h polled, all wells after 24 hours, each well will be called 10 times. As the set of samples at each well is determined by the current value of δmi determined by the formula

If the numerical value of δmiwill be given more δ3that guarantees the desired accuracy of the average daily flow rate, recalculated t0in the direction of decrease and Vice versa (in accordance with the terms δmiδ3(1+K); δmiδ3(1-K)). In practice, the K-factor set equal to 0.1, i.e. the inequality works with sensitivity better than 10% from the specified error.

Let the transmitter meter well performance (controller) logged value δ3=5%. Then the inequality given numerical values To look like this:

δmi5,5; δmi4,5.

Let after days obtained the following values of the current (actual) for each well relative root mean square error δmi:

4,0; 5,0; 6,0; 6,0; 2,5; 3,0; 4,5; 4,0.

Therefore, the period of the survey wells with spending 40 and 25 m3per day should be reduced to Δ t, i.e. increased sampling frequency, and the flow measurement first connects well with a flow rate of 40 m3/day.

The sample wells with a flow rate of 70 m3per day should be increased at the time Δ t, which is set in the ideal setpoint in the controller (computer). All operations makes the controller of the automated installation.

Thus, the set of essential features (including distinctive) the proposed method of measuring flow rate of a group of oil wells produce the required technical result meets the criteria of “invention” and is subject to the protection of the security document (patent) of the Russian Federation in accordance with the request of the applicant.

Sources of information

1. The USSR, A.S. No. 446640, CL E 21 In 47/10, 1972.

2. The USSR, A.S. No. 751977, CL E 21 In 47/10, 1976.

3. The USSR, A.S. No. 439598, CL E 21 In 47/10, 1971, the prototype.

4. Romanenko A.F., G. A. Sergeev Questions applied analysis of random processes. - M.: Soviet radio, 1968. - 256 S.

1. A method of measuring the flow rate of a group of oil wells by measuring the average consumption values for adequately selected time for each specific well groups with alternate according to a given program by connecting the wells to the meter, the subsequent recalculation of the flow rate in the daily performance, wherein choosing one of the most unstable flow parameters the dynamic borehole from the group, set and recorded in the memory of the computer, for example, an industrial controller, the numerical value of the relative root mean square error δ3average flow rate m(q), determine the period of the survey this is quaini, poll with the same period the rest of the wells group, adjust the polling period for each i-th of them by comparing the current relative root mean square error δmithe average value of the flow qiwith the previous δ3terms and conditions

δmi≥δ3(1+K); δmiδ3(1-K)

where K - coefficient restrictions of range δmigoverning the necessity of adjusting the sampling period of the i-th well in the direction of increase or decrease.

2. A method of measuring the flow rate of a group of oil wells under item 1, characterized in that the coincidence of the shift points on the measurement of the flow rate of the two or more wells from a group, the order of their survey set in descending order of performance of these wells.



 

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