Method and device for measuring oil well production rate

FIELD: oil industry.

SUBSTANCE: device comprises multiple-pass well shifting connected with bullet and terminal controller connected with the turbine flow meter and well shifting. The method comprises measuring time interval before the first pulse corresponding to the measuring cycle of the turbine flow meter and determining time interval required for synchronization of the beginning of fluid accumulation in the bullet and the end of measurements from the measuring time obtained.

EFFECT: enhanced accuracy of measurements.

2 cl, 4 dwg

 

The invention relates to the field of development and exploitation of oil fields, in particular for measuring the flow rate of oil production wells.

During the development and operation of oil fields for measuring the flow rate used automated group metering stations now type "Satellite" [1]. Measurement of flow rate of oil wells is carried out by intermittent transmission fluid that has accumulated in the separator, through the turbine meter. The dwell time of the fluid and the number of pulsed fluid passes through the meter during the measurement depends on the flow rate of the measured well. Cyclic measurement method provides for the transmission of fluid flow through the meter in a narrow range of flow rates that allows for measurement of flow rate in a wide range.

Known technical solutions closest to the technical nature of the claimed object, which serves as the base object is a method of measuring the flow rate of oil wells using now type "Sputnik AM-40" [2]. In the fields of RF installed thousands of these measuring units. Retool the oil industry with new modern similar devices, such as AHP type GM-40, almost impossible, because the cost now is hundreds of thousands of rubles is th (300-600 rubles). In the known method [2] measurement of the flow rate of oil production wells based on the accumulation of fluid in the Bullitt. The mode of accumulation of fluid in the Bullitt necessary to ensure a constant flow rate of fluid through the meter TOP-1-50, measurement error which is 2.5% is achieved when the fluid flow through the meter in the range from 1.6·10-3to 8.3·10-3m3/S. In real terms, to the Bullitt switch wells of a multi-way (PSM) connect up to 14 wells, flow rates which must be monitored daily.

The disadvantages of the known method [2] are as follows:

- hard time measuring the flow rate of all wells connected to the AHP;

- the impossibility of measuring the flow rate of all wells connected to the AHP for the day with the required accuracy.

Standard method with fixed time measurement of the rate offered by the manufacturer, is a sequential automatic connection of the wells to the Bullitt using PSM. The measurement time for all wells is the same and is 2 hours. In real terms, to the AHP connects up to ten wells, among which are as low debit wells (2-10 m3/day)and high yield (more than 20 m3/day). Rigid fixation time for all wells does not allow the effect is positive for the day to measure the flow rates of all wells, connected to the AHP, with the accuracy not worse than 6%.

Chart measuring the flow rate using the AHP as recommended by the manufacturer, is shown in figure 1. In the diagram Q is the amount of liquid in Bullitt, t - time processes, including recurring time intervals, where (τ1c) the time of accumulation of fluid in the bullet, (, τ2- the expiration time of a fluid from a bullet through the turbine meter TOP-1-50, which is typically less than 10 seconds, TW- hard-coded measurement time, followed by an interval of PSM switching to another well of not more than 20 seconds. From the diagram presented in figure 1, it follows that when measuring flow rate using the AHP influence on the measurement accuracy have three independent and unsynchronized between a periodic process:

1) accumulation and drain the fluid τ=τ21where the time of discharge is much less than the duration of accumulation;

2) the emergence of pulses n1n2, ..., evidence of passing through TOR-1-50 another hundred liters;

3) the beginning and end of the measurement TW.

Due to the random nature of the switching on and off a hard-coded time measurement of the flow rate of the TWpossible unpredictable absolute error of measurement from -100 to +100 liters, dependent on the STI from coincidence or not n 1from the beginning, and n1with the end of period TW. So that measurement error was not worse than 6% taking into account the error THOR-1-50 of 2.5%, it is necessary that through the turbine unit has passed not less than 2.5 cubic metres of liquid that requires a two-hour cycle, TWthe flow rate of 30 m3/day. Accordingly, for a flow rate of 10 m3/night cycle measurement becomes equal to 6 hours, but for 2 m3/day increased to 30 hours. Naturally, for 8-10 low yield wells connected to the AHP, the measurement should be within 10-12 days.

Known technical solutions closest to the technical nature of the claimed object, which serves as the base object is the device now type "Sputnik AM-40". Figure 2 shows a functional diagram of the AHP. From the switch to the wells of a multi-way (PSM) 1 oil-water fluid from the test wells served in bullet 2. Water-oil fluid from the other wells connected to PSM and enters the highway 3 exit now. Accumulation of fluid in the bullet is in the closed gas valve 4, is administered by the regulator of the gas valve 5. The minimum liquid level in Bullitt, in which the gas valve begins to cover the gas conduit 6, corresponds to 150 litres of oil-water mixture. Full closure of the valve 4 will astupaet when additional supply in the bullet 15 liters of fluid. The entire process of filling the bullet is at a pressure of 1 MPa. Further filling occurs with increasing pressure P1to pressure in excess of output R20.05-0.12 MPa. This excess pressure responsive differential pressure gauge 7. The flow regulator 8 opens and closes the line with turbine meter TOP-1-50 9. From the measuring line 10 water-oil fluid is delivered to the output of the AHP. Pulses n1showing passing through TOR-1-50 another hundred liters, proceed to count the amount of fluid 11. The time measurement of the flow rate of all wells in the same way and is set by the operator 12. After a testing time TWone well PSM automatically connects to the bullet next well.

The disadvantages of the known devices [2] as follows:

- rigid fixation time measurement of the flow rate of all wells connected to the AHP;

- the impossibility of measuring the flow rate of all wells connected to the AHP, during the day with the required accuracy.

The objective of the invention is to reduce the time of measurement of the flow rate of all wells connected to the AHP, while increasing the accuracy of measurement.

The task is achieved by the fact that in the measurement of flow rate using a flexible measuring mode, excluding the uncertainty of the beginning and the end is of dimension for each well the length of time of measurement, which determines the accuracy of the measurement. In the present method, in contrast to the known start time of the measurement is chosen randomly and all three periodic process associated with the measurement of flow rate (accumulation and discharge of the liquid; the emergence of pulses n1n2, ...; the beginning and end of the measurement TW), logically linked to temporary relationships.

A comparison of the proposed technical solutions with prototype has allowed to establish their compliance with the criterion of "novelty". The study of other known technical solutions in this field of technology features that distinguish the claimed invention from the prototype, were not identified and therefore they provide the claimed technical solution according to the criterion of "significant differences".

An example of the method.

Measurement of flow rate of oil wells, according to the claimed method, as follows. Figure 3 shows a diagram of the work now in the flexible mode measurements using a programmable processor device of the terminal controller (T-controller). In the programme of work T controller includes the following operations:

1) measuring and storing the time intervals n, between Stolichnoye pulses TOR-1-50;

2) edit the drilling and analysis of time to first n 1pulse;

3) determining the number n stolarova pulses on the selected criterion measurement mode;

4) integration duration n stolarova intervals and the quantity of liquid QW(n)passing through TOR-1-50 during n intervals;

5) the extrapolation of the integration on the day;

6) the accumulation of measurement results and their transfer in a distributed computer network.

After switching PSM on the test well T-controller starts counting the time until the first pulse of n1sensor TOP-1-50. Depending on the values of the time of arrival of the pulse n1and these are the cases: n1=1.2 hours for a flow rate of 2 m3/day; n1=15 minutes - 10 m3/day; n1=7.2 minutes for 20 m3/day etc., T-controller sets the number n required stolarova measurement cycles counter TOP-1-50. For example, if the count n1is 15 minutes, the controller sets the measurement of small flow rates from 2 to 10 m3/day, taking n=2. If the measured time of n1less than 7 minutes, the controller translates the AHP on the measurement for the case where the flow rate of 20 m3/day and more. When this is set to n=6. As a result, for all cases as marginal mode and vysokostebelnyh wells measurement error not worse than 2.5%, i.e. it is determined by the error in the ora TOR-1-50.

The inventive method of measurement allows you to measure the rate of ten production wells connected to the AHP for the day even if the flow rate is 2 m3/day. Usually the proportion of high and low yield wells connected to the AHP is 1/1. Therefore, testing of all wells fits in 24 hours. Therefore, testing of ten wells connected to the AHP type "Sputnik AM-40", one day becomes real.

To implement the described method of measuring the flow rate of oil wells a device, the concept of which is shown in figure 4.

From PSM 1 liquid from the test wells served in bullet 2. Water-oil fluid from the other wells connected to PSM and enters the highway 3 exit now. Accumulation of fluid in the bullet is in the closed gas valve 4, is administered by the regulator of the gas valve 5. The flow regulator 6 opens and closes the line to the gauge TOP-1-50 7. From TOP-1-50 signal is fed to the T-controller 8 associated with PSM. Measuring pipe 9 also delivers the water-oil fluid at the exit now.

The device operates as follows. Water-oil fluid from PSM 1 from test wells served in bullet 2, in which there is accumulation of fluid. the minimum liquid level or conditionally zero in bullet 2 corresponds to 150 litres. After closing the trunk with a measuring device TOR-1-50 7 is closing the gas valve 4. The accumulation of fluid in the Bullitt occurs with increasing pressure P1in Bullitt. If the pressure P1until pressure exceeds the outlet pressure P20.05-0.12 MPa, flow controller 6 opens the measuring pipe 9, and water-oil fluid flows through the turbine meter TOP-1-50 7. When it flows through the meter the first portion of the liquid component of about 40 liters. The pressure in the bullet decreases, and the flow regulator closes the measuring line.

Simultaneously with the switching of the PSM on the test well T-controller 8 starts the countdown to the nearest pulse n1coming from TOR 1-50. When working evenly upstream pump there is a directly proportional relation between the time n and the flow rate Q. the T-controller measures the time interval n1, analyzes and sets the number n of measured intervals stolarova of pulses necessary to measure the flow rate with the above measurement accuracy of 2.5%. The selected measurement mode flow test wells T-controller uses for PSM.

Switching time PSM is such that the liquid residue is always merge from a bullet to the set of conditionally zero is level 150 litres and the cycle of accumulation of fluid in the bullet for another well always starts with conditionally zero level 150 litres.

Using the proposed method and device for measuring the flow rate of oil wells that use a flexible measuring mode, excluding the uncertainty of the beginning and end of the measurement sets for each test well the duration of the measurement, which determines the accuracy of the measurement, measure the flow rates of producing wells connected to the AHP, one day while increasing the accuracy of the measurements.

Sources of information

1. Isakovich RA, Popadic VE Control and automation of oil and gas: a Textbook for colleges. - M.: Nedra, 1985. - 351 S.

2. Oilfield equipment: a Handbook/edited Ehink. - M.: Nedra, 1990. - 559 S.

1. A method of measuring the flow rate of oil wells, including automatic connection of the wells to the bullet for the accumulation of water-oil fluid and the end of the bullet through the turbine meter with installed flow, characterized in that for each well after the start of measurement determines the interval n1time of occurrence of the first pulse corresponding to the measuring cycle turbine meter, and based on the analysis of interval n1set the length of time dimension as n measured intervals n1when the number n is chosen depending on the required precision is the measurement of so, to the accumulation of fluid in Bullitt and the end of the process the measurements were synchronized.

2. Device for measuring the flow rate of oil production wells containing the switch wells of a multi-way, coupled with Bullitt, the flow regulator and turbine meter, characterized in that additionally introduced directly connected to the turbine meter and switch wells terminal controller is configured to select the optimal measurement time for each well on the measured time interval of the parish nearest impulse turbine meter.



 

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