Adaptive method of measuring the flow rate of a group of oil wells

 

(57) Abstract:

The invention relates to the field of monitoring the development of petroleum fields and can be used when measuring the performance of oil wells. The objective of the invention is to ensure the reliability of control over the selection of products by a group of wells with a minimum measurement time of each well. The method includes alternately, each well measure the quantity of fluid passing through the meter for a fixed minimum duration of a single measurement cycle, which we define for each well, getting average performance and the determination of the daily performance of the well. The average productivity of wells is determined from the optimum number of measurement cycles N=10. For any expected daily production of oil wells set the total measurement time Tand= 2.4 hours. The minimum duration of a single measurement cycle of each well satises t 2.5 minutes 1 C.p. f-crystals.

The invention relates to a method of measuring the flow rate of oil wells and can be used in information-measure concentration the EPA 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.

The known method [2] measuring the productivity of wells by measuring the average consumption values for appropriately chosen time, in order to increase measurement accuracy 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 finish to achieve the 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 (IU number of measurements averaged measured value and its standard deviation (x1). The resulting valueicompared with the specified value average standard deviation of the result of the arithmetic meany. Wheny1measurement of the well is terminated and the signal on connection the next hole. Wheny<1increasing the measurement time and again calculates the arithmetic mean of the measured value and its mathematical expectation2. Next, after a rather complicated procedure, calculates the difference between the mean square deviations, produced a new criterion (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 values and3and only ifx-n12, where n is the total number of intervals tnthe measure, included in a specified duration of measurement equal to tn= t + ntngiven 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 izmerenii. 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.

The closest technical solution, that is the prototype, adopted by the known method [3] 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 reference 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, choose the desired time the La produce the reference volume (weight) of the liquid during the measurement time, 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.

Thus, the goal of the proposed method is to provide a well-known way of measuring the flow rate of oil wells more high consumer properties, namely: minimize time measurement of oil wells while maintaining the efficiency and reliability of the monitoring group of wells, i.e. practicing a certain part of the productive formation of the Deposit.

As shown by experiments and field tests on the implementation of known and proposed methods of measurement goal (the desired effect) is achieved by the adaptive method of measuring the flow rate of a group of oil wells, which in turn at each well measure the amount of fluid passing through the meter for a fixed minimum duration t Edineti and the determination of the daily performance of the well, the average productivity of wells is determined from the optimal number of cycles of dimension N=10, while for any expected daily production of oil wells set the total measurement time Tand= 2.4 hours. The total time of measurement of the specific flow rate of the well is determined by the formula Tand= Nt, where N is the number of unit of measurement cycles for one specific well; t - time of a single measurement cycle of production of the well.

An additional distinction of the proposed adaptive method of measuring the flow rate of a group of oil wells is that the minimum duration of a single measurement cycle of each well satises t 2.5 minutes

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, the industrial Prim is what let the initial data namely, the method is carried out at the mine, containing 8 wells, and operational (current) development plan (or project) set the rate of liquid extraction for each of them in number 10, 15, 30, 20, 50, 25, 10 and 80 m3a day or otherwise, 7; 10; 21; 14; 35; 17,5; 7 and 56 liters per minute, respectively. Operators of oil production well-known technical means of capacity control wells set (approximately) the above values of flow rates, the value of which requires further adjusted according to the requirements of the development; and then, of course, need a quick and reliable control over the operation of each well. For this purpose establish (set) the minimum required time of a single measurement cycle for each well set specific dimensional volume of the flow meter. Does the meter flow rate cycle, the filling-emptying" measuring capacity with maximum dimensional volume of this tank uses for wells with the highest flow rate, and the minimum for marginal wells. It should be noted that (in modern computer based) this method is fairly simple, just need edeleny step height capacity meter flow rate, representing well-known, so-called group measuring unit (GMS).

In our case, we can take that to the first and seventh wells (10 m3/day) the controller uses the sensor level, defining and limiting the measuring volume flow meter (GMS) in the amount of 0.017 m3and for the last, tenth, wells (80 m3/day) will be involved level sensors, defining and limiting the measuring volume flow meter in size 0,140 m3. It follows that, in magnitude of a measured volume meter for each well, have the ability to set and specify the minimum duration of a single cycle of measurement of its performance, and to accurately determine (calculate) the value of its daily production rate set (set by the program controller) operation of averaging the measured performance results of the 10 individual cycles. The total time of measurement of the flow rate of the entire group of wells is 4 hours (even taking into account technological wasting time switching).

Thus, the set of essential features (including distinctive) declare adaptive way of measuring the flow rate of the group n is etenia" and 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 and.with. No. 446640, CL E 21 In 47/10, 1972.

2. The USSR and.with. No. 751977, CL E 21 In 47/10, 1976.

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

1. Adaptive method of measuring the flow rate of a group of oil wells, which in turn at each well measure the amount of fluid passing through the meter for a fixed minimum duration t of a single measurement cycle, which we define for each well, getting average performance and the determination of the daily performance of the well, characterized in that the average productivity of wells is determined from the optimal number of cycles of dimension N=10, while for any expected daily production of oil wells set the total measurement time Tand= 2,4 PM

2. The method according to p. 1, characterized in that the minimum duration of a single measurement cycle of each well satises t 2.5 minutes

 

Same patents:

The invention relates to a method of determining the location and zone settings disorders (MN) integrity of concrete dams, as well as the contact zones of dams with rock bases and coastal adjacency

The invention relates to oil production and can be used for the operational records of flow rates of production of oil and gas condensate wells in systems sealed collection

The invention relates to oil production and can be used for the operational records of flow rates of production of oil and gas condensate wells in systems sealed collection

The invention relates to the operation of wells and can be used to measure and control the number of components in the production wells

The invention relates to the operation of wells and can be used in the measurement and control of flow rate

The invention relates to oil and gas industry and can be used for quality control of construction of wells, methods of stimulation and other activities associated with oil and gas production

The invention relates to the oil and gas industry, namely to control the development of oil and gas fields, in particular to methods for assessing the integrity of the production casing of the injection wells equipped with tubing
The invention relates to the oil industry and can be used in the development of fields with long lifetime and determination of the working thickness of the layers over the entire lifetime

The invention relates to the oil and gas industry, in particular to methods for estimation of leakages in the production string, equipped with tubing (tubing)

The invention relates to systems of control and accounting for oil extraction

FIELD: oil and gas extractive industry.

SUBSTANCE: device has body with ports in lower and upper ends, main sensitive elements in form of turbines and packing elements, placed in pairs at body ends, side port made in body between main sensitive elements and converter, connected to surface equipment. In side pipe, mounted inside the body between main sensitive elements, additional sensitive element is placed in form of turbine and thermal sensor. Lower end of side pipe is connected to side port. Diameter of turbine of additional sensitive element is less than diameter of turbines of main sensitive elements. Converter is a control block mounted above body including sleeves locator and electronic microprocessor device.

EFFECT: higher precision.

1 dwg

FIELD: oil and gas production.

SUBSTANCE: invention relates to gas-liquid systems coming from oil production wells. Mixture is separated into liquid and gas in separator. Liquid is periodically accumulated in separator container and then displaced with gas. During this operation, differential pressure for liquid reaching its lower and upper recorded levels and time required for filling recorded volumes are measured as well as absolute pressure and temperature of gas in container. Liquid flow value expressed in weight is calculated using special mathematical dependence. At oil field, liquid and gas enter separator from preliminary gas intake installation or from the first separation step.

EFFECT: increased accuracy of measurement due to avoided gas density registration and excluded necessity of using strictly cylindrically-shaped measuring container.

1 dwg

FIELD: oil extractive industry.

SUBSTANCE: mixture is separated on liquid and gas in separator. Liquid is periodically collected and forced away by gas while measuring absolute pressure and gas temperature in separator tank near upper and lower fixed liquid levels, and times of forcing away of fixed liquid volume. Additionally measured are absolute pressure and temperature in moment when liquid reaches intermediate fixed level. Then liquid is forced from intermediate fixed level to lower fixed level separator is switched off from well, and mass loss of gas is calculated from provided relation. Device for realization of method consists of separator with feeding pipe, in which a three-drive valve is mounted, and draining pipe, which through said valve is connected to liquid outlet channel and to gas outlet channel. Separator is provided with sensors of temperature and pressure and sensors of upper, intermediate and lower levels, mounted in such a manner, that they separate fixed volumes between each other in separator tank, in case of equality of which calculations are simplified.

EFFECT: higher precision.

2 cl, 1 dwg

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes measuring volume and denseness of fresh oil in reservoir in case of even or balanced temperature and pressure. Combined sample of fresh oil is taken from pipeline during its draining and denseness of oil and bed water and ballast content is determined. Then mass of drained oil is determined with consideration of measured parameters. Prior to draining, fresh oil from reservoir is exposed until partial separation of bed water, and its denseness is measured. During draining of fresh oil, its denseness,, volumetric share of water therein, pressure and temperature are determined. Drained oil mass and percentage of ballast is determined from given mathematical expressions. Denseness of exposed bed water is measured on basis of sample, taken after exposure of fresh oil in reservoir. Denseness of exposed bed water is measured in its flow during draining from reservoir after exposure and before draining fresh oil. Volume of fresh oil in reservoir is measured continuously by its level and data from graduating table for reservoir. Draining of combined sample of fresh oil from pipeline during its draining is performed manually or automatically in case of constant kinetic condition. After exposure of fresh oil in reservoir point samples of fresh oil are taken, additional combined sample is made thereof and denseness of fresh oil, oil and bed water and ballast percentage is determined from it, and these parameters are used when evaluating precision of determining parameters of drained oil. Measurements of denseness, volumetric water share, pressure and temperature during draining of fresh oil in flow are performed periodically with averaging of current values of measured parameters for time interval, equal to period of change of parameters of fresh oil in reservoir. Mass of bed water MW is determined from given formula.

EFFECT: higher precision.

8 cl, 1 dwg

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes separating gas from liquid in the mixture. Liquid is periodically accumulated in calibrated gas separator tank with concurrent by-way of gas into collector and accumulated liquid is pushed out by gas with open pipeline used for draining gas into collector. During pushing away accumulated liquid by gas differential pressure between lower and upper pipeline points is additionally measured. Liquid flow in gas-liquid mixtures is calculated as total of flow of liquid filling calibrating tank, and flow of liquid, carried away by gas from separator, determined from given relation. Method is realized by device, which contains calibrating tank with inlet branch pipe for feeding gas-liquid mixture therein, pipeline for draining gas and pipeline for draining liquid, connected to collector through three-drive valve. Also, following are mounted in separator: level relay-sensor limiting calibrating volume, absolute temperature sensor, absolute pressure sensor and differential pressure sensor between lower and upper separator points. Between lower and upper pipeline points a sensor for measuring differential pressure is mounted. At entrance of pipeline dispersant is mounted for evening gas and liquid speeds.

EFFECT: higher precision.

2 cl, 1 dwg

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

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

FIELD: gas industry.

SUBSTANCE: device has two level comparators, two pulse generators, first, second and third active band filters, first and second piezoceramic detectors of flow pressure pulses. Output of first detector is connected to input of synchronizing low frequency amplifier, output of which is connected to input of first filter, output of which is connected to first input of scaling amplifier, output of which is connected to ADC input, output of which is connected to first input of microprocessor controller, output of which is connected to second input of scaling amplifier. Additionally provided are passive two-mode filter, switchboard and fourth filter. Output of second piezoceramic detector is connected to input of two-mode passive filter, output of which is connected to input of fourth filter, output of which is connected to inputs of third and fourth filters, outputs of which are connected to inputs of first and second level comparators, outputs of which are connected to inputs of first and second pulse generators, outputs of which are connected to first and second switchboard inputs, output of which is connected to second input of controller, second output of which is connected to third input of switchboard.

EFFECT: higher efficiency and precision.

2 dwg

FIELD: gas industry.

SUBSTANCE: device has two piezoceramic detectors of flow pressure pulses, output of first of which is connected to input of synchronizing low frequency amplifier. Output of synchronizing amplifier is connected to input of first active band filter, output of which is connected to first input of scaling amplifier, output of which is connected to input of ADC. ADC output is connected to first input of microprocessor controller. First output of controller is connected to second input of scaling amplifier. Device also has level comparator, pulse generator, second and third active band filters, while controller is made with product parameters recorders. Additionally provided are two-mode filter, switchboard and fourth active band filter. Output of second piezoceramic detector is connected to input of two-mode passive filter, output of which is connected to input of second active band filter. Output of second filter is connected to inputs of, respectively, third and fourth filters, outputs of which are connected to first and second inputs of switchboard, connected to level comparator input. Output of the latter is connected to input of pulse generator, output of which is connected to second input of controller. Second output of controller is connected to third input of switchboard.

EFFECT: higher precision.

2 dwg

FIELD: oil and gas industry.

SUBSTANCE: device has container for marked liquid lowered on geophysical cable with depressurization assemblies and driving assemblies and measuring sensors, more than one. Measuring sensors are positioned above and below researched bed range no less than one on each side. As marked liquid, ferromagnetic liquid is used, and as measuring sensors - magnetic field measuring devices.

EFFECT: lower costs, simplified construction, higher precision.

1 dwg

Up!