Method for recording oil flow

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

 

The invention relates to oil production and refining industries, and in particular, to a method of accounting for oil with the definition phase and component structures at its production from the well or during vacations and transportation to the consumer.

A known method for determining volume fraction and the physical parameters of the oil in the reservoir fluid wells, characterized by the fact that when liquid extraction exercise influence on the flow of sampled reservoir fluid by passing it through a nozzle in a measuring Cup, simultaneously measuring the pressure drop across the nozzle, the flow rate and receive an information signal on fluid flow, summarize the signals received at different pressure drops of oil and water jet and then determine the volume fraction of oil in the reservoir fluid and the kinematic viscosity of oil and water (see EN 2096608, E 21 IN 47/00, 1997).

The disadvantage of this method is the low accuracy of determination of the quantitative composition of the components in crude oil.

There is also known a method of accounting for oil, including the measurement of volume and density of crude oil in the tank at the same or reduced to one temperature and pressure, the selection of a joint sample of crude oil from the pipeline when it is pumping and determining the density of oil and water and the contents of the ballast, and determination of the mass of katanoi oil taking into account the measured parameters, and selection of point samples in the tank to improve the reliability indicators of oil (see oil and Oil products, Methods of measurement of mass, GOST 26976-86).

The disadvantage of this method is that the method is not specified levels selection of point samples in the presence of reservoir bottom of reservoir water, which reduces the measurement accuracy due to discrepancies in the reservoir accounting for oil-water flows.

Task patentable method is to increase the accuracy of determining the mass of oil and formation water and the percentage of ballast.

This task is achieved in that in the method of accounting for oil, including the measurement of volume and density of crude oil in the tank at the same or reduced to one temperature and pressure, the selection of a joint sample of crude oil from the pipeline when it is pumping and determining the density of oil and water and the contents of the ballast, and mass determination of drained oil taking into account the measured parameters, before pumping of crude oil from the reservoir produce it sucks to partial separation of produced water and the determination of the density of the reservoir water, when pumping crude oil is measured in flux density, volume fraction of water in it, the pressure and temperature, the mass M drained of oil and the percentage of ballast SW set the Ute of the following expressions:

where GSV1 - volume of crude oil before pumping, m3;

GSV2 - volume of crude oil after pumping, m3;

W is the volume fraction of water, %;

DB- the density of the formation water, kg/m3;

D20the density of crude oil at 20C in vacuum, kg/m3;

Wmn- mass fraction of mechanical impurities, %.

This task is achieved by the fact that the determination of the density of distilled water reservoir carried out in the sample taken after sludge crude oil tank.

And the fact that the determination of the density of distilled water reservoir is carried out in its flow when pumping from the tank after settling and before the pumping of crude oil.

And the fact that the volume of crude oil in the reservoir continuously determine the level and calibration data table on the tank.

And the fact that the selection of bulk samples of crude oil from the pipeline when the pumping is performed manually or automatically when the isokinetic condition.

And also the fact that after sludge crude oil tank take spot samples of crude oil, create additional pooled sample and determine the density of crude oil, oil and formation water and the contents of the ballast and use these parameters when assessing the accuracy of definition of indicators of the quality control Department is Channa oil.

And that dimension when pumping crude oil in the flow of its density, volume fraction of water, pressure and temperature are carried out periodically by averaging the current values of measured parameters over a time interval equal to the period measurement parameters of crude oil in the tank.

And the fact that a lot of produced water MBdetermined by the formula:

The invention is illustrated by the drawing, which shows a process diagram of the information-measuring system (IMS)that implements a patented method.

The method is as follows.

IMS uses the data about the quantity and quality of crude oil, located in the cylindrical vertical tank and fill pipe during pumping.

Oil-water stream (crude oil) from the pipeline through the valve 1 is supplied and stored in a vertical tank. After accumulation of fluid and partial separation of produced water before being pumped through the sampling device 2 and the ball valve 3 is selected in probsably 27 sample brine.

Pumping is pumping unit 26. When pumping crude oil through a remotely controlled valve 4 and 25 flows into the bypass line. In the bypass line crude oil after the valve 20 passes the sensor density measuring device 19, and the gap test is bornoe device 18, primary measuring transducer volume fraction of water in oil 17 and the valve output manifold, in which the measured pressure and temperature, respectively using the sensors 22 and 23.

Part of the fluid flow, the selected slot sampling device 18 enters the line quality, in which, using a remotely operated valve 16, the readings of the flow indicator 15 create conditions isokinetic. In line quality liquid after the indicator 15 passes successively through the sensor density measuring device 14, the impeller 13 and 7, the check valve 6 and the ball valve 5 to the input of the pump. In line quality there are two types of sampling: manual and automatic, using the hardware of probabilitv STANDARD BOSNA. After dispersant 13 through the ball valve 12 is manually selected sample in the sampler 11. After disperser 7, using a locking device 8 in the sampler 10 according to the program control unit 9, is automatically selected during the period of pumping the combined sample is used to determine in the laboratory of physical and chemical indicators of oil.

Upon delivery of oil from the tank must be closed and sealed gate valves on all lines except the line in which it is pumping fluid.

Using the sampling device 2 is set to be given the pipeline of the tank, through the ball valve 3 before being pumped selected sample to determine the density of formation waters in the chemistry lab.

Before pumping test closed if the valve 4, 24, and 25. Then open the valves 20 and 21, ball valves 5 and 16. Open the valve with remote control 4 and 25. Fill sensors densitometer 19 and PIP-VSN 17, and line quality reservoir waters. Record the density of the formation water. To open the first valve 4, and then the valve 25 and are pumping fluid from the reservoir.

At carrying out of acceptance of transactions, the pumped mass party of liquid (crude oil) is defined as the difference between the mass of liquid in the tank at the start and end of pumping. When this mass of product at the beginning and end of pumping are calculated from the measured and calculated values of the volume and density of the liquid at the beginning and at the end of pumping.

Determination of the mass of fluid in the reservoir runs after the tank was in a state of sludge, and after a time of sludge regulated process, taking into account the presence of demulsifier and durability oil-water emulsion.

After a time the sludge from the tank selected spot samples of crude oil and perform laboratory analysis of the combined samples for the determination of density about the s, oil and brine content of the ballast (water, salts and solids).

The volume of liquid in the tank is determined continuously (automatically) at the level of the fluid and calibration data table on the tank, made and approved in the prescribed manner and entered into the database. The level measurement section the gas-liquid perform sensor Dur radar level gauge VM R company to the Crown, which is mounted on top of the tank.

Measuring the average temperature is in the tank multipoint thermometer DTT, and pumped flow temperature sensor 23. Point thermometers should be evenly distributed over the height of the tank. Based on the data of the temperature sensor automatic adjustment of the volume of liquid in the tank by its average temperature.

The density measurement of the fluid flow to be pumped out of the tank, is carried out by the densitometer 7826 company Solartron. If the range of change of velocity of fluid flow does not match the passport data of the densitometer 7826, the instantaneous density of the pumped liquid can be obtained by using a densitometer 7835 from the same company, placed in the node.

In the process of emptying the tank of the pipeline are selected in the site quality of the joint fluid sample and perform laboratory of the Academy of Sciences is Liz for determining the density of a liquid (crude oil), oil and brine water content of salts and solids. Then carry out a manual entry of results of laboratory analysis: density at 20C and the percentage of ballast.

The conversion of the measured values of fluid density to a standard temperature of 20C carry out on the table GOST 3900. next, the resulting table is the density equals the density of D20in vacuum, which is achieved by increasing a density of 1.1 kg/m3

Mass M drained of oil and the percentage of ballast SW is determined from the following expressions:

where GSV1 - volume of crude oil before pumping, m3;

GSV2 - volume of crude oil after pumping, m3;

W is the volume fraction of water, %;

DB- the density of the formation water, kg/m3;

D20the density of crude oil at 20C in vacuum, kg/m3;

Wmn- mass fraction of mechanical impurities, %.

For all parameters measured directly in IMS and in the laboratory on selected combined samples, do comparisons of these parameters and the comparison result is considered positive if the condition is met:

|PAR-PARlab|≤ΔPAR+ΔPARlabwhere

PAR and PARlab- one or another physical parameter of crude oil or produced water is, measured directly in IMS or and lab combined sample, selected in the pipeline or tank.

ΔPAR ΔPARlab- absolute error of direct measurements and laboratory analysis, respectively.

IMS automatically carries out the processing of the measurement results to calculate the mass by the formula above.

To obtain data on the net weight of the oil in the pumped fluid they use established after the centrifugal pump full flow primary measuring transducer volume fraction of water W in oil PIP-VSN and density sensor 7826 company Solartron.

Also in the pipeline is installed sensors pressure and temperature of the firm Fisher Rosemount. These tools are used to determine the current density values Di, volume fraction Wi of water in the oil, the temperature Ti and pressure Pi pumped from the reservoir fluid. IMS averages the current values of measured parameters over a time interval equal to the period of the survey of the parameters of the liquid in the tank, for example 2-3 seconds,

Therefore, every 2-3 seconds to get data on the gross weight of the fluid Mi, the average density Di and the average values of the volume fraction of water Wi, using which you can determine the amount of water Qi during the measured interval. Summing the values Qi during pumping, get the amount of PLA the postal water in the shipped product.

The weight of the reservoir water MIndetermined by the formula:

Control precision measurements of the mass of oil produced IMS comparison with the results obtained when measuring liquid parameters for samples taken from the tank.

1. The method of accounting for oil, including the measurement of volume and density of crude oil in the tank at the same or reduced to one temperature and pressure, the selection of a joint sample of crude oil from the pipeline when it is pumping and determining the density of oil and water and the content of the ballast mass determination of drained oil taking into account the measured parameters, characterized in that before the pumping of crude oil from the reservoir produce it sucks to partial separation of produced water and the determination of the density of the reservoir water, when pumping crude oil is measured in flux density, volume fraction of water in it, the pressure and temperature at this mass M drained of oil and the percentage of ballast SW is determined from the following expressions:

where GSV1 - volume of crude oil before pumping, m3;

GSV2 - volume of crude oil after pumping, m3;

W is the volume fraction of water, %;

DB- the density of the formation water, KGM, 3;

D20the density of crude oil at 20C in vacuum, kg/m3;

Wmn- mass fraction of mechanical impurities, %.

2. The method according to claim 1, characterized in that the determination of the density of distilled water reservoir carried out in the sample taken after sludge crude oil tank.

3. The method according to claim 1, characterized in that the determination of the density of distilled water reservoir is carried out in its flow when pumping from the tank after settling and before the pumping of crude oil.

4. The method according to claim 1, characterized in that the amount of crude oil in the reservoir continuously measure the level and calibration data table on the tank.

5. The method according to claim 1, characterized in that the selection of a joint sample of crude oil from the pipeline when the pumping is performed manually or automatically when the isokinetic condition.

6. The method according to claim 1, characterized in that after sludge crude oil tank take spot samples of crude oil, create additional pooled sample and determine the density of crude oil, oil and formation water and the contents of the ballast and use these parameters when assessing the accuracy of the definitions of the indicators pumped out of oil.

7. The method according to claim 1, characterized in that the measurement when pumping crude oil in the flow of its density, volume fraction of water, pressure and temperature, the wasp is estlat periodically averaged current values of measured parameters over the time interval equal to the period measurement parameters of crude oil in the tank.

8. The method according to claim 1, characterized in that the weight of the reservoir water MIndetermined by the formula:



 

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