System and method for evaluating contamination of formation fluid samples with filtrate using refraction index

FIELD: chemistry.

SUBSTANCE: described are versions of a method and apparatus for conducting such evaluation when determining the final degree of purity or final degree of contamination of fluid during sampling thereof. The described apparatus and method involve measuring the refraction index of the fluid over a certain period of time, curve fitting using refraction index measurement results or data values derived therefrom and calculating the final refraction index or final data value based on the fitted curve in order to calculate the final degree of contamination or purity of the fluid.

EFFECT: high information content and reliability of evaluation.

25 cl, 6 dwg

 

The present invention relates to a device and method of assessment of the state of formation fluids using a refractive index in the selection of such a formation fluid.

In the process of drilling oil and gas wells in the wellbore circulating drilling fluid (also referred to as "washing liquid"). Usually used drilling fluids, water or hydrocarbon based. After drilling and prior to its completion for the purpose of extracting hydrocarbons from strata of rocks often take samples of borehole fluid with different levels of depths in the borehole to determine characteristics of the fluid and to establish the whereabouts and contents or quantity of hydrocarbons in the reservoir fluid, status, headers, etc. In some cases it is also desirable to take samples of the formations or zones that contain predominantly stratiform mineralized water, i.e. water samples.

Most of the wells drilled at the conditions of positive differential pressure, i.e. due to the weight of the drilling fluid pressure in the wellbore during drilling exceeds the formation pressure. Depending on the physical properties of the reservoir, in which the drilling, such as porosity, permeability and other rock properties, drilling fluid penetrates to different depths of the reservoir. As a result, pronicheva the Oia drilling fluid (also referred to as the breakthrough of the mud) is pollution relic or untouched fluid in the reservoir. In this regard, to obtain a sample of the downhole fluid place the device at the desired depth and taken away or pump out the fluid from the reservoir into the wellbore until it is determined that selected fluid essentially does not contain the mud. For pumping fluid and sampling of formation fluids to the desired depth in the wellbore are usually installed downhole tool called "probowalismy layers". Initially, the fluid that is withdrawn from the reservoir, often heavily polluted by the leachate of the drilling fluid used to drill the wellbore. To obtain pure enough (usually with a degree of pollution of <10%) samples of reservoir fluids during a certain period of time, usually 30 to 90 minutes usually pumped from the reservoir into the wellbore, and then collect samples into the sample chamber for laboratory analysis. To control the degree of contamination of sampled fluid often use optical sensors. To calculate the time that may be required to obtain a relatively pure sample of the downhole fluid, and subsequent calculation of purity and pollution, if the fluid pumped over a relatively long period of time, apply measurements of optical absorption. In wells carry out the measurement of the refractive index, but they are not used for R the account of the purity or contamination of saline formation water. The results of measurements of the refractive index can be much less sensitive to the passage present in the reservoir fluid particles of sand or other substances, which are able to scatter light in the analyzed fluid than the results of spectral measurements of optical absorption.

In this regard, there is a need for a device and method using the measurement results of the refractive index to determine one or more characteristics (parameters) of the mineralized formation water taken from the reservoir penetration of the drilling fluid is water-based, to determine the degree of purity or pollution of the mineralized formation water in the selection process of formation fluids and to calculate at a given point in time, how much time you may need to clear in order to make selection of the sample. In some situations, for example, if too deep a penetration zone or permanent unwanted fluid from the adjacent layers during pumping of fluid obtaining a pure sample can be impossible even with continued pumping for a relatively long time. In such cases it is desirable for a relatively short time to determine that it may be impossible for a reasonable time to take the samples from specific conventions is in the wellbore.

In the present invention proposes a method of evaluating characteristics of saline water in the fluid produced from the reservoir, into which penetrates the drilling fluid is water-based, the implementation of which:

calculate the refractive index of mineralized water in the fluid produced from the reservoir, using well log data;

select the fluid from the reservoir;

carry out a series of measurements of the refractive index of the fluid for a certain period of time in the selection process of formation fluid from the formation; and

assess the characteristics of saline water in the fluid produced from the reservoir, using the calculated refractive index and the refractive index measured in the selection process of formation fluids.

Logging data can be some of the data, including the resistivity of the rock, the porosity of the rock and neutron cross-section.

In another embodiment proposes a method of evaluating characteristics of saline water in the fluid produced from the reservoir, into which penetrates the drilling fluid is water-based, the implementation of which:

calculate the refractive index of mineralized water in the fluid produced from the reservoir, the results of downhole measurements,

select the fluid from the reservoir;

carry out a series of measurements of the coefficient of the pre is omline fluid for a certain period of time in the selection process fluid;

make the selection (fitting on corresponding points of the curve to the measured values of the refractive index; and

assess the characteristics of saline water in the fluid produced from the formation, on the basis of the calculated refractive index and selected curve.

Private options exercise additionally calculate the final value of the coefficient from measurements of the refractive index and on the basis of the calculated refractive index at time t and the chosen curve, additionally evaluate the refractive index at a later time t+Δt.

Characteristics of saline water in the fluid produced from a formation, corresponds to one of the including: the refractive index of mineralized water in the fluid produced from the reservoir, and the resistivity corresponding to the measurements of refractive index.

In one of the private options additionally complete selection of fluid, if the difference between the calculated refractive index and the final value of the coefficient from measurements of the refractive index exceeds the selected value.

When calculating the refractive index calculate the refractive index corresponding to the selected temperature and pressure.

The following variant of the method the evaluation of the characteristics of the fluid, where:

select the fluid from the reservoir;

measure the refractive index of the fluid in the selection process of formation fluids with the aim of obtaining values of the refractive index over a certain period of time in the selection process fluid;

get the value of the specific resistance of the fluid corresponding to the obtained values of the refractive index;

make the selection curve for the obtained values of resistivity;

based on the selected curve, calculate the final value of resistivity; and

evaluate the characteristic of the fluid using the current values of the resistivity and the estimated final value of resistivity.

Characteristic of the fluid may be one of the characteristics, including contamination of the fluid, the purity of the fluid, the content of hydrocarbons in the fluid, the relative content of contamination of the fluid, the relative amount of oil in the fluid, the relative gas content in the fluid and the relative water content in the fluid.

In one of the private options additionally evaluate the components of the fluid and reproduce a visual image of these components in the form of halftone pictorial image or a color visual image. Selection curve implement one of the methods, including odbor asymptotic curve, selection neasepticheskoe curve selection curve using the least squares method.

The present invention also proposes a device for evaluating the performance of mineralized water in the fluid drawn from the reservoir, containing:

a sampler for sampling formation fluid;

Refractometer for measuring the refractive index of the fluid in the selection process of formation fluids;

a storage device for storing the calculated values of the refractive index of mineralized water in the fluid drawn from the reservoir, which is determined using well log data; and

the processor is capable of determining characteristics of saline water in the fluid drawn from the reservoir, based on the calculated values of the refractive index of saline water and the measurement results of the refractive index, implemented in the selection process fluid from the reservoir.

In private versions of the device includes a chamber for collecting fluid and a pump for pumping fluid into the chamber.

Mentioned characteristic is one involving the contamination of saline water in the fluid drawn from the reservoir and clean saline water taken from the reservoir.

In another embodiment, a device for evaluating the performance of mineralized water in the fluid, the floor is chemom from the reservoir, which penetrates the drilling fluid is water-based, containing:

a sampler for sampling fluid from the reservoir;

Refractometer for the implementation of the multiple dimensions of the refractive index of the fluid in the selection process fluid from the reservoir;

a storage device for storing the calculated values of refractive index defined on the basis of well log data; and

the processor is capable of selecting a curve to the values of a series of measurements of the refractive index performed over a certain period of time in the selection process fluid, and to determine the characteristics of saline water in the fluid produced from the formation, on the basis of the calculated refractive index and selected curve.

The processor may be configured to calculate the final value of the coefficient from measurements of the refractive index.

The processor is configured to, based on the calculated refractive index at time t and the chosen curve, calculate the degree of pollution or purity of saline water in the fluid drawn from the reservoir, at a later time t+Δt.

The above data values match one of the values, including the value of many measurements of the refractive index and the value of the specific resistance that meet the following this set of measured values of the refractive index.

In one of the private options, the processor can instruct the selection of the sample fluid from the reservoir when the selected data value indicates that the mineralized water in the fluid drawn from the reservoir, has a reasonable degree of purity, or mineralized water in the fluid drawn from the reservoir, has a reasonable degree of contamination.

In addition, the processor capable of processing the results of measurements of the refractive index in one of the locations, including a location in the wellbore, the position on the surface and a position partially in the bore and partially on the surface.

The device may include a pump for pumping fluid from the reservoir into the chamber or the wellbore.

The device may also contain a means of transportation, which is the cable or pipe system for delivery of the sampler and the Refractometer into the wellbore.

In addition, the device may further comprise a chamber for collecting fluid from a reservoir and a pump for pumping fluid into the chamber under a pressure in excess of hydrostatic pressure, or chamber for collecting fluid from the reservoir and associated gas chamber to increase the pressure of the fluid in the chamber.

To facilitate the understanding described in the present invention device and method the following detailed description of embodiments with SS is the LCA to the attached drawings, on which the same elements are denoted by the same positions and have:

figure 1 shows a view in vertical section of the system wireline according to one of embodiments of the present invention,

figure 2 - block diagram of probovatel layers applicable to the system shown in figure 1 according to one of embodiments of the present invention,

figure 3 - optical Refractometer applicable is shown in figure 2, the downhole tool for determining the refractive index of the samples downhole fluid

figure 4 is a diagram illustrating an example of measurement of the refractive index, carried out for a certain period of time during which the composition of the fluid drawn from the reservoir varies from mud filtrate water-based mostly on stratiform mineralized water,

figure 5 is a diagram illustrating an example of measurement of the refractive index, carried out for a certain period of time during which the composition of the fluid drawn from the reservoir varies from mud filtrate hydrocarbon based mainly on the produced oil, and

figure 6 is a diagram illustrating an example of resistivity, calculated on the basis of the refractive index.

Figure 1 shows the block-the Hema system wireline according to one of embodiments of the present invention. Shows well 101 drilled in the reservoir 102. In the well 101, drilled in the reservoir 102 is logging device 103 on the reinforced cable 115. From the device 103 depart optional gripper 112 and 114 to stabilize the device 103. The device has two expanding packer 104 and 106, are able to divide the annular space of the wellbore 101 on the upper annular space 130, sealed intermediate the annular space 132 and the lower annular space 134. Machine selectively retractable Shoe 140. Gripping device 112, the packers 104 and 106 and the sliding Shoe 140, which is used for sampling fluid, which is described further below when considering figure 2.

Telemetry used in cable embodiment, includes a downhole device 116 two-way communication, United with the ground device 118 two-way communication with one or more conductors 120, passing inside of the reinforced cable 115. Ground device 118 two-way communication is placed in the ground controller 150, which has a processor, memory, and output device, generally indicated by the position 152. To supply armored cable 115 in the wellbore 101 use the standard cable pulley 122. The device 103 has a downhole controller 160 with a processor and a memory 162 to control Obrosova the receiving layer as described in the invention methods. The downhole device 103 has a variety of sensors, including optical sensor module 170 and optional containers 128 samples. The optical sensor module 170 is used to measure the refractive index of the fluid drawn from the reservoir over time in selected locations and at variable depths in the borehole 101. The device 103 also has other sensors (generally indicated by the position 125), such as a pressure sensor, temperature sensor, flow meter, etc.

Figure 2 shows a block diagram of part of probovatel 103 layers used in the borehole for sampling formation fluid and measurement in place of the refractive index. Selectively retractable gripping elements 112 are in contact with the wall 204 of the well and record the tubular element 206 of the device 103. Packers 104 and 106 forward and come into contact with the wall 204 of the well. Advanced packers divide the annular space of wells in three areas - the upper annular space 130, the intermediate annular space 132 and the lower annular space 134. A sealed annular space (or sealed region) 132 adjacent to the reservoir 218. On the tubular element 206 has a sliding sealing Shoe 140, which may be selectively advance and enter the sealed area 132. Through the Shoe 140 LM passes the Kai line 222, serving as a channel for communication between reservoir fluid 208 and the sensors, such as optical sensor module 170, and having an aperture 220, tightly pressed to the wall 204. In addition, there are sensors 125 to determine the pressure, temperature and flow velocity of the sample of the formation fluid. Packers 104 and 106 tightly pressed to the wall 204 and form a seal between the wall 204 and a sliding Shoe 140. As a result of reduced pressure in the sealed region 132 to the occurrence of the Shoe 140 in contact with the wall is initiated by the flow of formation fluid in the sealed region 132. When extended Shoe 140 is in contact with the wall, the fluid 208 from the reservoir enters the device through the opening 220. When installing sliding Shoe 140 gives him a certain orientation. To determine the orientation of the sliding Shoe 140 may use a sensor such as an accelerometer. After that, the sliding Shoe 140 may be installed in the desired direction.

To control the selection of the formation fluid 208 is used downhole controller 160. The controller 160 is connected to the control unit volume of drilling fluid in the borehole, such as the pump 226. The pump 226 may be a screw pump or any applicable pump, capable of pumping wireline fluid 208 from the reservoir 218. For measuring the rate of flow of the fluorescence is IDA provides a flow meter. Liquid line 222 between the optical touch module 170 and the pump 226 is valve 230 for controlling the flow of fluid entering the pump 226. The volume below the level of the return stroke of the piston pump 226 is test volume 205, which includes a liquid line 222.

To determine the refractive index of reservoir fluid in the test volume 205 using the optical sensor module 170. You can use any appropriate optical module or system, can be used to determine the refractive index. According to one feature of the optical sensor module is designed for measuring the refractive index using the intensity of the reflection at the interface of open and fluid. By comparing the intensity of the reflection at the air-filled sensor and reduced-intensity reflection, when the sensor is any other fluid, and using the known reflection coefficients of the window (usually sapphire window) and air calculate the refractive index. According to one feature of the Refractometer optical sensor module 170 may be designed for measurement in place of the refractive index of any desired fluid, including oil, gas and stratiform mineralized water. The Refractometer can have a wide range, such as from n=1.0 to n=1,75, and consider what Ino high resolution, such as 0,00025 or higher. This Refractometer provides a relatively wide range of refractive indices and has a relatively high resolution. This Refractometer provides a measurement of the refractive index applicable for monitoring purification of samples containing primarily of mud filtrate to mainly clean or relic formation fluid described in the invention. For the purposes of the present description can be used by any applicable Refractometer, including, without limitation, refractometers, described in the patent US 6683681 B2 and in the application publication US 2004/0007665 A1, the assignee of which is the assignee of the present application, the contents of which are by reference incorporated into the present application.

The optical sensor module 170 is connected to the controller 160 and provides feedback to the control system with feedback. It is used to adjust parameters, such as finding cleaning samples. Purification of the samples means the transition from contaminated leachate formation fluid to relic or almost clear Plast fluid during pumping of fluid at selected depths in the wellbore. The downhole controller 160 may have a processor such as a microprocessor for processing measured values from the cylinder is enta refraction. As machine-readable media for storing data, computer programs and algorithms associated with the application described in the invention device, and to perform various functions and methods associated with such a device, this may be a storage device, such as a mass storage device.

In the cleaning process selected fluid line 219 is produced in the upper annular space 130. Line 219 is connected to the pump 226 pipeline

227. with selectable internal valve 232. If desired sampling fluid, the fluid may be directed to an optional tanks or containers 228 sample using internal valves 232, a and 233b, and not by filing a fluid line 219. The fluid in the tank 228. extracted from the well for analysis.

According to one feature of the results is carried out in the well data can be transmitted to the surface for use or further processing. The controller 160 sends the processed data to the system 116 bilateral data 116, located in the wellbore. System 116 data transmits the data signal ground controller 150 includes a CPU 151, and a storage device for storing computer programs, algorithms and data applicable is described in izopet the NII device and methods. For the purposes of the present description is applicable to any data transmission system. The signals received at the surface, handles the CPU 151 associated with the ground controller 150, which converts the data and moves it to the appropriate output device and(or) storage device 152. Ground the controller 150 can also be used to transmit downhole device 103 initiating the test commands.

Figure 3 shows a diagram of node 305 Refractometer applicable in the optical touch module 170. The source 310 of the light comprising an incandescent lamp and a collimating lens, emits a collimated beam of light. A collimated beam of light may fall mainly perpendicular to the outer surface of the first sapphire window 303. After interaction with the fluid, the light exits through the second sapphire window 302. According to one of the configurations sapphire window 303 and 302 may be located generally perpendicular to the collimated light beam and separated by a gap or channel 304, which between them flows the investigated layer fluid. In one embodiment, the implementation of the node 305 Refractometer rejects of the incident collimated beam of light from the light source 310 and focuses it on the border of section 307 of the first sapphire window 303 and the fluid in the channel 304. A beam splitter 317 divides the reflected beam of light between refracto what EPR 316, 318 and 320 and the spectrometer 621 weak reflectivity. Part of the collimated light beam, which is not rejected for use in the Refractometer or spectrometer weak reflectivity goes on, and it is used in other sensors.

Figure 3 shows two optical transmitting terminal 300, 301 (which may be a relay lenses, glass or sapphire rods), also called the left rod 300 and the right rod 301, which can be used to direct light. In one configuration, the longitudinal axes of both the optical transmitting rods lie in a plane perpendicular to the plane as resistant to pressure plates forming the first sapphire window 303 and the second sapphire window 302 and channel 304. In addition, both the optical transmitting terminal 300, 301 can be located next to each other (and to touch each other where they converge on the surface 303), and may be in contact with the first sapphire wafer 303. For maximum amplification of the light signal can be applied to high-temperature gel for matching the refractive indices, which eliminates the gap between the transmitting terminals 300, 301 and the first sapphire wafer 303. If the gap is filled only with air, the results of measuring the ratio rotten the value does not change, because it is on the same order of magnitude reduces the measurement results of the light intensity as the unknown sample and the control sample. This system can be used to determine the refractive index of a sample of formation fluid in the channel 304 (figure 2). Details of the measurement methods and analysis to determine the refractive index is given in the patent US 6683681 B2 and published applications US 2004/0007665 A1.

Figure 4 shows a diagram 400 illustrating an example of on-site measurements of refractive index performed over the selected time period during pumping formation fluid. In the particular example illustrated in figure 4, mud is mud water based, and relict fluid is saline produced water. On the y-axis 402 deferred refractive index, and on the x-axis 404 represents time. During the period prior to pumping at the moment 406 (after about 4200 seconds) refractive index, measured by Refractometer, similar to that shown and described with reference to figure 3, has a very stable and constant value indicated by the position 408. With the beginning of the suction refractive index selected fluid changes, and after a short time starts to grow from the moment indicated by the arrow 410. what about the least pumping fluid relative content of the filtrate (mud) in fluid begins to decrease, and the relative content of relict fluid begins to increase. In other words, as pumping formation fluid is the process of cleaning fluid, which increases the degree of purity of the samples with the removal of filtrate from the zone of penetration of the formation. Thus, the relative content of the relic of the fluid or the degree of purity "fp" begins to increase, and the degree of pollution "fc" begins to decline. In the particular example illustrated in figure 4, mud is mud water based, and relict fluid is saline produced water. Since the refractive index of the drilling fluid is water-based is lower than the refractive index of the mineralized formation water, the refractive index of sampled fluid increases over time. This is because the density (refractive index) of the drilling fluid is water-based is less than the density of the mineralized formation water. As shown in figure 4, the refractive index increases rapidly until the arrow 414, and then increase begins to decrease on the cone, i.e. it starts relatively slowly increase over time. In the particular example illustrated in figure 4, it is shown that the refractive index increases on the expiration of about 6500 seconds. Typically, when a long time pumping (which may be 24 hours, and so on) is achieved dynamic equilibrium in which the sample of well fluid pumped from the reservoir, is treated with the same speed with which it is contaminated again under the influence of the neighboring areas, such as areas above and below the zone from which a sample is taken. Thus, the results of downhole measurements, such as measurements of refractive index, often predominantly cease to change, but the degree of purity of the sample still does not reach 100%. Dynamic equilibrium depends on various factors such as the ratio of horizontal and vertical permeability. From the point of view of the present description, the degree of purity obtainable, after a very long period of time, referred to as the final degree of purity "ftp", which is usually less than 100%. Appropriate final degree of pollution (1-ftp) is designated as "ftc." Thus, preferably by control measurements to calculate what time it may be necessary to achieve final purity or appropriate final degree of contamination. In addition, in the selection process of formation fluids, it is desirable to carry out the calculation of the actual degree of purification, i.e. the degree of contamination or cleanliness really is time. If the amount of leachate reaching the final purity exceeds the selected threshold (e.g., more than 5% or 10%), perhaps it is undesirable to perform the selection of the sample at the selected location in the wellbore and may be more desirable to complete the selection process fluid and move the device to another location in the wellbore.

As shown in figure 4, line 450 indicated the estimated or calculated value of the refractive index relict saline formation water. By comparing the calculated refractive index relict saline formation water and the measured refractive index of contaminated mixture determine relative abundance of relict saline formation water in the mixture extracted fluids. By comparing the results of both refractive indices can be calculated degree of pollution or purity. According to one feature of the estimated value of the refractive index relict saline formation water can be calculated based on previous data and knowledge of rock properties of the reservoir from which the selected fluid. The refractive index of the mud filtrate can be determined directly. Alternatively, it can be calculated from other the property, such as the resistivity in the case of drilling fluids, water-based. Ongoing comparison may include differencing and using ratios of the selected measurement value or values.

According to one feature in the selection of the sample of water from the well, drilled using the drilling fluid is water-based, to calculate the specific resistance relict saline formation water, and on the basis of the refractive index relict saline formation water can be used in the logs. For example, the resistivity of the mineralized formation water can be calculated using typical rock properties in the region of the wellbore, such as the Archie parameters "a" and "m" indicator specific resistance (F=a/Porosity ^ m), as well as charts logging resistance using probes with a large radius of research and porosity according to neutron logging in the saturated zone. Similar charts neutron logging can be used to calculate the mineralization mineralized formation water. For a zone with a 100% water saturation neutron cross section data logging is Standard deviation _ Chart=RMS otklonyayuscyeyesya produced water * Porosity + Signicade the ranks otclonenieami * (1 - The porosity). The effect of dissolved salt on the section of the mineralized formation water can be defined mineralization mineralized formation water by calculating the values of RMS otklonyayuscyeyesya produced water in terms of typical neutron cross section for the formation and porosity according to the charts neutron logging. Then, on the basis of resistivity, pressure, and temperature of the saline formation water, you can calculate the refractive index of the mineralized formation water. The relationship between resistivity, pressure, temperature and refractive index are discussed in the patent US 7027928. By directly measuring the refractive index of the mud filtrate water, or if its resistivity is known, by calculating its refractive index, specify both endpoints for evaluation on the basis of the degree of pollution in percent. Thus, define a known refractive index as pure mud filtrate on a water basis (one endpoint)and net mineralized formation water (the other endpoint). The degree of contamination can be calculated according to the results of linear interpolation between the two endpoints of pure fluids.

<> In the selection of the sample of oil from wells drilled using a drilling fluid hydrocarbon-based, to calculate the refractive index reservoir oil you can use prior information about the fluid obtained in this region. As with the direct measurement of the refractive index of the mud filtrate hydrocarbon-based known to both endpoints, it is possible to determine the degree of pollution according to the results of linear interpolation between the end points of pure fluids.

As shown in figure 4, at any point in the selection process fluid of known refractive index of the fluid. By comparing the current value of the refractive index and the calculated values of line 450 can determine the degree of pollution or purity. If the difference between the calculated value line 450 and the ultimate value of the data in figure 4 (described in more detail hereinafter) exceeds the specified value, it may be impracticable to obtain a relatively pure sample, even if the fluid pumped from the reservoir in a long time. In this case, the device may be moved to another location in the wellbore to obtain pure samples. Described in the invention system, the device and methods can be designed to provide both qualitative and quantitative the x indicators of current and final degrees of purity and pollution using a series of measurements of refractive index, carried out for a selected period of time. According to one feature of the present invention have the indicator or carry out the calculation in real time of the segment elapsed time pumping before Plast fluid reaches a certain degree of purity, on the basis of changes of the refractive index. For example, the difference between the refractive index of the mineralized formation water with high salinity and a refractive index almost fresh mud water based is approximately 0,030. Thus, the proposed in the present invention, the system allows real-time to calculate the relative content of polluted or clean fluid based on the current refractive index and the estimated final refractive index or calculation of the refractive index relict saline formation water.

According to another particularly proposed in the present invention, the system calculates the final purity or contamination by appropriate curve fit to the data of the refractive index obtained for a selected period of time. For the purposes of the present invention can be used by any applicable method or algorithm of fitting curves. Some examples of construction methods (functions the NCI/selection) curves, which can be used in the present invention, is described next. Curve that can be fitted to the data shown in figure 4, marked by a solid line 420.

Figure 5 shows a diagram illustrating an example of on-site measurements of refractive index, carried out for a selected period of time during pumping formation fluid, used drilling mud is mud hydrocarbon-based, and relict fluid is formation oil. On the y-axis 502 deferred refractive index (rounded with an accuracy of up to 0.001), and on the x-axis 504 deferred pumped volume of fluid. In the illustrated figure 5 example uses the pumped volume, not time, as in figure 4. In some cases, the pumped volume of fluid may be a more viable option, for example, when the speed of the pumping fluid is predominantly unstable over time pumping. At the beginning of pumping with zero volume 506 results of measurement of refractive index by Refractometer, similar to that shown and described with reference to figure 3, are somewhat unstable, as indicated by the position 515. Such results can be obtained due to random changes in the composition initially pumped fluid. With the increase of pumped about the EMA refractive index of the fluid begins to fall, as shown, the initial part of the data, generally indicated by arrow 506, and then begins to rise more gradually, as the data being displayed, generally indicated by arrow 508. In any particular case, the pumping rate of change of the refractive index depends on the degree of purification. In the particular example illustrated in figure 5, as a continuation of the pumping volume of the arrow 510 (4000-5000 CC), the refractive index begins to grow relatively slowly. In the particular example illustrated in figure 5, the dynamic equilibrium or final degree of purity can be achieved after pumping much larger volume, which, as shown, exceeds 14,000 cubic cm

In the example illustrated in figure 5, the refractive index decreases as the pumping fluid, since the refractive index of the drilling fluid hydrocarbon-based greater than the refractive index of the reservoir oil. Proposed in the present invention, the system allows you to fit an appropriate curve to the data and provides the calculation of the refractive index in the final purity and current purity (or contamination) of sampled fluid. When known, the refractive index of the filtrate and formation fluid, it is possible to determine the degree of purity, or zag is annenia in percent according to the results of linear interpolation between the two endpoints. As shown in figure 4, according to one of the features proposed in the present invention the system provides a calculation of the refractive index in the final purity or the current level of contamination by appropriate curve fit to the data of the refractive index obtained for a selected period of time. Before the implementation of the fit of the curve to calculate the final values system usually discards atypical (high and low) results (peaks data), such as indicated by the position 412 (figure 4) and position 515 (figure 5).

The resistivity of formation fluids associated with the refractive index of the fluid and, therefore, can be calculated based on the refractive index and is used to calculate the final values. Figure 6 shows a diagram 600 illustrating an example of resistivity, calculated on the basis of the refractive index, measured during the cleaning. When the mud is fresh drilling fluid is water-based, and relict fluid is a saline formation water, the refractive index increases in the cleaning process. This is because the density of the mineralized formation water exceeds the density of the drilling fluid is water-based. However, since the specific resistance, good discharge performance is e mineralized formation water is less than the resistivity of fresh drilling fluid is water-based, it will decrease during the cleaning process. Figure 6 illustrates an example in which the resistivity calculated or estimated on the basis of the refractive index decreases in the cleaning process. On the y-axis 602 deferred calculated resistivity, and on the x-axis 604 represents time. The calculated resistivity is shown since the start of pumping, which in this particular case corresponds to 8000 seconds, and up to the moment of 10000 seconds. For the period prior to the commencement of pumping, and perform other tasks using a downhole tool, such as instrument setup, etc. Values of resistivity with time is shown by arrow 608. As noted above, the data of the refractive index or the data of resistivity, calculated on the basis of the refractive index, can be used to calculate the final purity or contamination by appropriate fitting curve to the data. To calculate the specific resistance on the basis of the refractive index shown in the example illustrated by diagram 600 may be used any known dependence. Because such relationships are known, they are not described in the present invention. The dependencies are stored in memory in the well or on the surface and used to calculate the sensible resistance based on the measured values of the refractive index.

To fit the curve can be used by the processor downhole tool or ground-based processor, or an appropriate combination. According to one feature of the measurement data, such as shown in figure 4 and 5, or calculated data, such as shown in Fig.6, can be transferred to ground-based processor, which is programmed using command adjusts the curve to a specific number of data points and extrapolate the curve to determine the final grade or final degree of contamination and the current levels of purity or pollution. According to another particularly in downhole memory available to the downhole processor may be stored programs, while the downhole processor performs the curve fitting and through the telemetry system sends the results to the surface. As noted above, to fit the curve to the measurement results of the refractive index or the calculated resistivity can be used by any applicable method of curve fitting. Examples of some methods of curve fitting are listed below.

In one of the embodiments proposed in the invention method and device are fitting the measurement data to neasepticheskoe curve. One example neasepticheskoe curve is a curve, which is in charge of the AET fit to the data over a typical or selected time pumping, such as from 30 minutes to two hours, with subsequent extrapolation of the results to the magnitude of the multiple time pumping, but with the approach of plus or minus infinity to infinity, such as the approximation in the form of a power series.

According to one feature of the present invention provide adjustment continuously differentiable neasepticheskoe curve to the original data. Adjustment may be made to the current elapsed time or to the pumped volume of fluid. The method used in the present invention, includes, without limitation, for example, fit neasepticheskoe curve to the points of the input data, such as A(t)=c1+c2t1/2+c3t1/3+C4tl/4. Program by calculating analytically calculates the first derivative as dA/dt=(C2/2)t-1/2+(C3/3)t-2/3+(c4/4)t-3/4. In relation to this method and0means "end" refractive index, i.e. the index of refraction at any very long time (for example, 24 hours), which greatly exceeds the normal duration of pumping. Over time decreases as (a0-A)and t(dA/dt), where a represents the refractive index at time t. If we assume that both quantities decrease at the same rate, they are proportional to each other, what about the features (A 0-A)=mt(dA/dt), where "m" is a constant. According to one feature of the proposed method fills in the various calculated values And0until you find a design value And0providing acceptable or best linear fit using the least squares method y=(a-a0and x=[t(dA/dt)]. The best match is given by the formula y=MX+b, in which the intersection point b is the closest to zero, which, as has been established, provides a higher precision than finding the maximum "R2for linear approximation of the two is directly proportional variables. For the implementation of the fit curve in the present invention selects a point of the input data in the selected time t (which may be the latest point in time t), in which the actual data intersect (or very close) to the line of maximum compliance. To predict the refractive index at a slightly later time t+Δt using the formula Δ=(a0-A)/[1+m(1+t/Δt)], which is obtained by replacing dA/dt on Δ/Δt, replacing t by t+Δt and replacement for a+Δ in the formula (A0-A)=mt (dA/dt). Then recursively apply this formula Δ to predict the refractive index at time t+Δt, then use the newly calculated refractive index for which ycycline refractive index at a slightly later time t+2Δt, and so forth for all time points in the future. Thereby carry out the prediction of A(t).

If the slope m of the adjustment is positive, it means that was selected unwanted segment of the source data with a curvature up or down in the direction of plus or minus infinity. In this case, choose a new point of data input at a certain time t and continue the process of curve fitting as described above. For data whose values increase and equalize over time, the final degree of purity in any future time t given by the formula A(t)/A0. For data, the values are reduced and equalized over time, the final degree of purity in any future time t given by the formula [As-A(t)]/[As-A0], where Asmeans the initial refractive index from the left edge (the earliest point in time) of the selected data window.

Thus, according to one feature of the present invention, a method of calculating the features of interest or a parameter, such as current, future or final degree of purity or pollution of the mineralized formation water in the reservoir fluid pumped or pumped at the selected location in the wellbore in the selection process fluid. According to one feature of the method to evaluate the characteristics of mineralized is authorized formation water in the fluid, received from the reservoir, into which penetrates the drilling fluid is water-based. In the process calculate the refractive index of the relic mineralized formation water measurements in wells; select fluid from the reservoir; repeatedly measure the refractive index of the fluid in the selection process of the formation fluid; and comparing the calculated refractive index with a refractive index measured in the selection process of formation fluids, to assess the characteristics of the mineralized formation water. The interesting characteristic or property may be the degree of contamination of a sample of well fluid or the degree of purity of the mineralized formation water in the sample of the downhole fluid, or the relative content of pure or relict saline formation water or the relative content of contaminated produced water in the sample of the downhole fluid.

According to another particular method to evaluate the characteristics of the mineralized formation water in the fluid produced from the reservoir, into which penetrates the drilling fluid is water-based, they expect refractive index relict saline produced water based on the log data, such as charts logging resistance or other charts electric logs; select the fluid from the reservoir; repeatedly measure the refractive index of the fluid in the selection process fluid; perform curve fitting to the data values that correspond to the set of measured values of the refractive index; and assess the characteristics of the mineralized formation water, based on the calculated refractive index and fitted curve. When implementing the method may additionally calculate the final value of the data and(or) assess the degree of contamination or the degree of purity of the mineralized formation water in the future time, based on the calculated refractive index and fitted curve. Data values that fit curve may be the actual measured values of the refractive index or the value of the specific resistance, derived from the measured values of the refractive index. According to one feature of the selection of the fluid is completed when the difference between the calculated refractive index and the final value is greater than the selected value. According to another particular collect sample of formation fluid, when it is established that the mineralized formation water has an acceptable level of purity. According to another particular calculate the estimated coefficient of refraction relict saline formation water, which is adequate to the selected temperature and pressure.

According to other features of the method of estimation of characteristics of the fluid in the selection process of formation fluids, the implementation of which: selected fluid from the formation; measuring the refractive index of the fluid in the selection process of formation fluids with the aim of obtaining multiple values of the refractive index; receiving a lot of resistivity corresponding to multiple values of the refractive index; carry out fitting a curve through a set of values of resistivity; based on the fitted curve, calculate the final value of resistivity; and evaluate the characteristic of the fluid using the current values of the resistivity and the estimated final value. Characteristic of the fluid may be the final value of contamination of the fluid; the final value of clean fluid; the final value of the content of hydrocarbons in the fluid; the relative contamination of the fluid; the relative amount of oil in the fluid; the relative gas content in the fluid; or the relative water content in the fluid. Can be used with any method of calculating the components of the fluid and reproducing a visual image of the estimated components, which may be a halftone pictorial image or color Nagle's is a great image in addition, each such image may be two-dimensional or three-dimensional image.

According to other features of the proposed device for evaluating the characteristics of the mineralized formation water in the fluid drawn from the reservoir, which can be: a sampler for sampling formation fluid; a Refractometer for measuring the refractive index of the fluid in the selection process of formation fluid; a storage device that stores the estimated value of the refractive index relict saline formation water in the reservoir, which is determined using the log data; a processor that calculates a characteristic of the mineralized formation water based on the calculated values of the refractive index relict saline formation water and the measurement of refractive index, implemented in the selection process of formation fluids. To collect a sample of the downhole fluid may be used in the sampling chamber. For pumping formation fluid into the sample chamber under hydrostatic pressure can be used pump. To increase the pressure of the fluid in the sample chamber can be used compressed gas in the chamber. According to other features, the processor may perform curve fitting to the data values that correspond to mnozhestvennosti measurements of refractive index, to calculate the characteristics of the mineralized formation water in the selected fluid based on the calculated refractive index relict saline formation water and fitted curve. The processor may also calculate the final value of the data and to calculate the degree of contamination or the degree of purity of the mineralized formation water in the selected fluid at a future point in time based on the calculated refractive index relict saline formation water and fitted curve. The data values used to fit the curve may be the data values that correspond to the set of measured values of the refractive index, or resistivity, corresponding to the set of measurement results of the refractive index. According to other features, the processor may be designed to serve the team selection of a sample of formation fluid when the selected data value indicates that the degree of purity of the mineralized formation water or the degree of contamination of saline formation water is acceptable.

According to other features of the proposed machine-readable medium with a built-in a computer program that may contain: a set of commands fit curve to the data corresponding to the set of values, measure the refractive index of the fluid, obtained in the selection process of formation fluids; the set of commands calculate the final values of the refractive index on the basis of the fitted curve; and a set of commands for the evaluation of the characteristics of the mineralized formation water in the fluid based on the fitted curve and the calculated values relict saline formation water, calculated using log data. The computer program may further comprise a set of commands fit curve to the data values for a selected period of time and extrapolation of the fitted curve to the value of multiple selected time, with the approach of plus or minus infinity to infinity.

Machine-readable media may be a ROM, RAM, ROM, CD-ROM, DVD, flash memory, or any other known or not currently known machine-readable medium, in which a computer, such as processor downhole controller 418 and / or the processor ground controller 412 performs proposed in the present invention methods.

In the above description, for the purpose of illustration and explanation given private embodiments of the present invention. However, specialists in the art will understand that the described embodiments of can be made many an is of stovini and changes. It is implied that all such modifications and improvements should be considered as included in the description.

1. The method of evaluating characteristics of saline water in the fluid produced from the reservoir, into which penetrates the drilling fluid is water-based, the implementation of which:
calculate the refractive index of mineralized water in flude obtained from a formation, using well log data;
select the fluid from the reservoir;
carry out a series of measurements of the refractive index of the fluid for a certain period of time in the selection process of formation fluid from the formation; and
assess the characteristics of saline water in the fluid produced from the reservoir, using the calculated refractive index and the refractive index measured in the selection process of formation fluids.

2. The method according to claim 1, wherein the logging data are some of the data, including the resistivity of the rock, the porosity of the rock and neutron cross-section.

3. The method of evaluating characteristics of saline water in the fluid produced from the reservoir, into which penetrates the drilling fluid is water-based, the implementation of which:
calculate the refractive index of mineralized water in flude received from the reservoir, the results of downhole measurements, select the fluid from the reservoir;
Khujand is are a series of measurements of the refractive index of the fluid for a certain period of time in the selection process fluid;
make the selection curve to the measured values of the refractive index; and
assess the characteristics of saline water in the fluid produced from the formation, on the basis of the calculated refractive index and selected curve.

4. The method according to claim 3, which further calculate the final value of the coefficient from measurements of the refractive index.

5. The method according to claim 4, in which on the basis of the calculated refractive index at time t and the chosen curve, additionally evaluate the refractive index at a later time t+Δt.

6. The method according to claim 1, in which the characteristic of saline water in the fluid produced from a formation, corresponds to one of the include:
the refractive index of mineralized water in flude received from the reservoir, and the resistivity corresponding to the measurements of refractive index.

7. The method according to claim 4, which further complete the selection of the fluid, if the difference between the calculated refractive index and the final value of the coefficient from measurements of the refractive index exceeds the selected value.

8. The method according to claim 3, in which the calculation of the refractive index calculated refractive index corresponding to the selected temperature and pressure.

9. Method of assessment ha is acteristic fluid, where:
select the fluid from the reservoir;
measure the refractive index of the fluid in the selection process of formation fluids with the aim of obtaining values of the refractive index over a certain period of time in the selection process fluid;
get the value of the specific resistance of the fluid corresponding to the obtained values of the refractive index;
make the selection curve for the obtained values of resistivity;
based on the selected curve, calculate the final value of resistivity; and
evaluate the characteristic of the fluid using the current values of the resistivity and the estimated final value of resistivity.

10. The method according to claim 9, in which the characteristic of the fluid is one of the characteristics, including contamination of the fluid, the purity of the fluid, the content of hydrocarbons in the fluid, the relative content of contamination of the fluid, the relative amount of oil in the fluid, the relative gas content in the fluid and the relative water content in the fluid.

11. The method according to claim 9, which further evaluate the components of the fluid and reproduce a visual image of these components in the form of halftone pictorial image or a color visual image.

12. The method according to claim 9, in which the selection curve implement Aut one way, includes matching asymptotic curve, selection neasepticheskoe curve selection curve using the least squares method.

13. The device for evaluating the performance of mineralized water in the fluid samples from a formation, comprising:
a sampler for sampling formation fluid;
Refractometer for measuring the refractive index of the fluid in the selection process of formation fluids;
a storage device for storing the calculated values of the refractive index of mineralized water in flute taken from the reservoir, which is determined using well log data; and
the processor is capable of determining characteristics of saline water in flute taken from the reservoir, based on the calculated values of the refractive index of saline water and the measurement results of the refractive index, implemented in the selection process fluid from the reservoir.

14. The device according to item 13, containing a chamber for collecting fluid and a pump for pumping fluid into the chamber.

15. The device according to item 13, in which the said characteristic is one involving the contamination of saline water in flute taken from the reservoir and clean saline water taken from the reservoir.

16. The device for evaluating the performance of mineralized water in the fluid produced from the reservoir, in which p is aniket the drilling fluid is water-based, contains:
a sampler for sampling fluid from the reservoir;
Refractometer for the implementation of the multiple dimensions of the refractive index of the fluid in the selection process fluid from the reservoir;
a storage device for storing the calculated values of refractive index defined on the basis of well log data; and
the processor is capable of selecting a curve to the values of a series of measurements of the refractive index performed over a certain period of time in the selection process fluid, and to determine the characteristics of saline water in the fluid produced from the formation, on the basis of the calculated refractive index and selected curve.

17. The device according to clause 16, in which the processor is configured to calculate the final value of the coefficient from measurements of the refractive index.

18. The device according to clause 16, in which the processor is configured to, based on the calculated refractive index at time t and the chosen curve, calculate the degree of pollution or purity of saline water in the fluid drawn from the reservoir, at a later time t+Δt.

19. The device according to clause 16, in which the data values match one of the values, including the value of many measurements of the refractive index and the value of the specific resistance, according to dtweedie to this set of measured values of the refractive index.

20. The device according to item 16, containing a pump for pumping fluid from the reservoir into the chamber or the wellbore.

21. The device according to clause 16, in which the processor is able to give command to the selection of the sample fluid from the reservoir when the selected data value indicates that the mineralized water in the fluid drawn from the reservoir, has a reasonable degree of purity, or mineralized water in the fluid drawn from the reservoir, has a reasonable degree of contamination.

22. The device according to item 16, containing the means of transportation, which is the cable or pipe system for delivery of the sampler and the Refractometer into the wellbore.

23. The device according to clause 16, in which the processor is capable of processing the results of measurements of the refractive index in one of the locations, including a location in the wellbore, the position on the surface and a position partially in the bore and partially on the surface.

24. The device according to item 16, further containing chamber for collecting fluid from a reservoir and a pump for pumping fluid into the chamber under a pressure in excess of hydrostatic pressure.

25. The device according to item 16, further containing chamber for collecting fluid from the reservoir and associated gas chamber to increase the pressure of the fluid in the chamber.



 

Same patents:

FIELD: machine building.

SUBSTANCE: procedure is based in usage of concentrator of micro-impurities in aerosol containing sprayer of examined oil, heating chamber, cooling chamber, channel for drainage of condensed fluid, and channel for exhaust of concentrated aerosol connected to source of spectre excitation. Also, aerosol of examined motor oil is generated by means of a jet-centrifugal sprayer. It is ignited with a high-voltage torch discharge directing it into a plasma-chemical reactor axially to axis of plasma flow for successive aerosol particles after-burning. Further, upon passing through the cooling chamber and filter produced solid, liquid and gaseous products are examined by methods of spectral analysis.

EFFECT: complete collection of wear products.

1 dwg

FIELD: agriculture.

SUBSTANCE: emulsion is diluted with water at least in five stages, at that reducing the concentration of surface-active agent in two times after each dilution. The interfacial tension is determined. Creation of the curve of surface tension at the liquid-liquid interface of the surface-active agent concentration is carried out. Emulsion is held at each stage to its full coagulation. The repeated definition of interfacial tension and the definition of the desired amount of surface-active agent on the shift of the isotherm on the horizontal axis is conducted.

EFFECT: invention enables to optimise the content of surface-active agent in formulations of herbicidal preparations.

9 ex, 3 tbl

FIELD: oil and gas industry.

SUBSTANCE: method involves sampling and preparation of sample with thermostatting at temperature of 50-70°C with simultaneous extrusion of sulphurated hydrogen and light mercaptans with inert gas or air to in-series located absorbing solutions; at that, as absorbing solution for determining sulphurated hydrogen, there used is sodium carbonate solution, and as absorbing solution for determining light mercaptans there used is sodium hydrate solution, quantitative estimation of sulphurated hydrogen and light mercaptans by method of iodimetric titration. At that, before mixture of vapours of light hydrocarbons with sulphurated hydrogen and light mercaptans, which is extruded from the sample with air or inert gas, enters in-series located absorbing solutions, it is cooled to the temperature of more than 15°C to 20°C.

EFFECT: improving accuracy and reliability, and speeding-up the analysis.

5 ex, 3 tbl, 1 dwg

FIELD: chemistry.

SUBSTANCE: method of determining colloidal stability of grease is realised from the amount of oil squeezed from the grease, where a cup full of grease with a piston and fitted with an oiled filter together with a set of dry filters is subjected to thermal stabilisation and subsequently held under a load, after which the amount of oil squeezed from the grease into the dry filters is determined. Before thermal stabilisation, a medium boundary is created between the analysed grease and the dry filters by separating them from each other in order to prevent penetration of oil into the dry filters before loading. The amount of oil squeezed from the grease is determined from the displacement of the piston during loading. The invention also discloses a device for realising the said method.

EFFECT: more reliable determination.

4 cl, 1 dwg

FIELD: chemistry.

SUBSTANCE: in the method which involves centrifuging a prepared oil solution and subsequent suspension of the obtained residue, deposition takes place in a thin annular layer of the oil solution which rotates together with a rotor. Centrifugation is done once and decantation of the centrifuge effluent is done automatically when the centrifugal rotor stops. In the device which has a housing, an electric motor with a vertical shaft, the rotor is made in form of a reservoir with a removable cover, in which there are two cavities for putting the analysed oil solution, depositing impurities and decantation of the centrifuge effluent. The rotor also has a removable cylindrical insert made from metal foil for collecting residues which undergoes control weighing. The rotor is driven by the shaft of the electric motor through an overrunning centrifugal clutch which automatically connects them in startup and centrifugation mode and also disconnects when the electric drive is switched off, thereby providing smooth free run-out of the rotor with the filtered centrifuge effluent.

EFFECT: increased accuracy, simplification and faster determination.

3 cl, 1 dwg

FIELD: physics; measurement.

SUBSTANCE: invention relates to measuring techniques. Control of oil decomposition is done based on varying the test parametre of working oil relative that of clean oil. The test parametre is calculated using fluorescence intensity of oil, simultaneously measured in three spectral ranges and two operating spectral ranges are used, in which intensity values are greater than in the third. The device has a case in which there is an optical window, and a receiving-transmitting unit, in which are fitted an optical emitter and receiver with a measuring photodetector. The measuring photodetector is a colour sensor, which allows for simultaneous measurement of fluorescence intensity of oil in three spectral ranges.

EFFECT: increased sensitivity and reliability of control.

5 cl, 6 dwg

FIELD: chemistry.

SUBSTANCE: invention relates to analytical chemistry, namely, to method of preparing samples for detecting elements and their isotopes in hydrocarbon, mineral and synthetic, in particular, vacuum oils, oil products and fuels and lubricants. Method of preparing samples for detecting content of uranium isotopes in oils by method of weight-spectrometry with inductively-connected plasma includes selection of oil samples and their decomposition with concentrated acid at high temperatures and pressure. Sample decomposition is carried out till full transparency according to multi-step programme in microwave oven by means of nitric acid in amount not less than 5 cm3 per each sample with weight from 0.4 g to 0.6 g. High frequency radiation power is maximum, pressure within autoclave being within the range from 500 to 1200 kPa, with exposure time on sample from 5 to 15 min at each decomposition stage.

EFFECT: ensuring full decomposition of hydrocarbon oils samples to state of transparency, reduction of sample decomposition time and lowering limits of detecting uranium isotopes in hydrocarbon oils samples.

1 dwg, 1 ex, 3 tbl

FIELD: measuring technique.

SUBSTANCE: device comprises valving device mounted between the horizontal first pipeline and second pipeline. The second pipeline whose sections are arranged above the first pipeline is provided with measuring section that is used as a measuring chamber. The first radioactive isotope means is used for measuring the mass of a portion of gas-containing liquid supplied to the chamber and has first unit of radiation source and first unit for detecting radiation arranged at the top and the bottom end of the measuring section, respectively. The axis of the measuring section is vertical or is inclined to the longitudinal axis of the first pipeline. The second radioactive isotope means is used for determining the presence of gas-containing liquid in the measuring section and has second unit of the radiation source, second unit of radiation detecting that are arranged in the top part of the measuring section from two diametrically opposite sides.

EFFECT: simplified design and reduced time of measuring.

2 dwg

FIELD: analytical methods in petroleum industry.

SUBSTANCE: invention relates to analytical checking of crude oil, petroleum derivatives, and gas condensate quality. 2 to 5g sample is thermostatically controlled at 50-70°C, while simultaneously hydrogen sulfide and light mercaptans are for 2-5 min displaced by inert gas or air into in series arranged absorption solutions, namely sodium carbonate solution for determining hydrogen sulfide and sodium hydroxide solution for determining light mercaptans. After complete withdrawal of hydrogen sulfide and light mercaptans, their quantitative content is determined by means of iodometric titration method.

EFFECT: extended range of analyzed products, increased determination accuracy, shortened analytical procedure, and enabled carrying out analyses not only in stationary laboratory without deviation from standardized procedures.

1 dwg, 1 tbl

FIELD: investigating or analyzing materials.

SUBSTANCE: method comprises measuring density of fuels at a temperature of 20°C or measuring the density of fuels in the temperature range from mines 10°C to plus 30°C in g/cm3 with further determining of the kinematic viscosity from the formulae proposed.

EFFECT: enhanced reliability.

2 dwg, 3 tbl

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes measuring in given sequence of appropriate parameters with following calculation of determined characteristics on basis of certain relation. Device for determining characteristics for sublimation of liquid oil products contains sublimation retort with dimensions, allowing to place 5-15 ml of analyzed probe therein, device for heating retort in its lower portion with constant and adjusted heating intensiveness, two inertia-less temperature sensors providing for continuous measurement of true value of temperature of sample in steam couple, device for continuous pressure measurement in stem phase of sample during sublimation, which includes pressure sensor as well as capillary and receiving and signals processing sensors, sent by temperature sensors and pressure sensor.

EFFECT: simplified construction, higher speed of operation.

2 cl, 4 ex, 10 tbl, 5 dwg

FIELD: oil and gas extractive industry.

SUBSTANCE: method for detecting amount of organic acids in oil flows, includes: a) eradiation of sample of said oil flow by infrared radiation; b) determining spectrum of infrared absorption, while given eradiation is performed only in ranges of spectrum with frequencies from 1000 to 1350 sm-1, from 1550 to 2200 sm-1, from 2400 to 2770 sm-1 and from 3420 to 4800 sm-1; and c) finding relation between all said frequencies of said spectrum of infrared absorption, determined at stage b), and content of organic acids in said oil flow with use of linear multidimensional regression analysis. Also provided are method for optimizing mixing of two and more product oil flows, containing organic acids with different total acid value levels and method for optimization of agents admixture, which neutralize organic acids, to product oil flow.

EFFECT: higher efficiency.

3 cl, 4 tbl, 14 dwg

FIELD: investigating or analyzing materials.

SUBSTANCE: method comprises measuring density of fuels at a temperature of 20°C or measuring the density of fuels in the temperature range from mines 10°C to plus 30°C in g/cm3 with further determining of the kinematic viscosity from the formulae proposed.

EFFECT: enhanced reliability.

2 dwg, 3 tbl

FIELD: analytical methods in petroleum industry.

SUBSTANCE: invention relates to analytical checking of crude oil, petroleum derivatives, and gas condensate quality. 2 to 5g sample is thermostatically controlled at 50-70°C, while simultaneously hydrogen sulfide and light mercaptans are for 2-5 min displaced by inert gas or air into in series arranged absorption solutions, namely sodium carbonate solution for determining hydrogen sulfide and sodium hydroxide solution for determining light mercaptans. After complete withdrawal of hydrogen sulfide and light mercaptans, their quantitative content is determined by means of iodometric titration method.

EFFECT: extended range of analyzed products, increased determination accuracy, shortened analytical procedure, and enabled carrying out analyses not only in stationary laboratory without deviation from standardized procedures.

1 dwg, 1 tbl

FIELD: measuring technique.

SUBSTANCE: device comprises valving device mounted between the horizontal first pipeline and second pipeline. The second pipeline whose sections are arranged above the first pipeline is provided with measuring section that is used as a measuring chamber. The first radioactive isotope means is used for measuring the mass of a portion of gas-containing liquid supplied to the chamber and has first unit of radiation source and first unit for detecting radiation arranged at the top and the bottom end of the measuring section, respectively. The axis of the measuring section is vertical or is inclined to the longitudinal axis of the first pipeline. The second radioactive isotope means is used for determining the presence of gas-containing liquid in the measuring section and has second unit of the radiation source, second unit of radiation detecting that are arranged in the top part of the measuring section from two diametrically opposite sides.

EFFECT: simplified design and reduced time of measuring.

2 dwg

FIELD: chemistry.

SUBSTANCE: invention relates to analytical chemistry, namely, to method of preparing samples for detecting elements and their isotopes in hydrocarbon, mineral and synthetic, in particular, vacuum oils, oil products and fuels and lubricants. Method of preparing samples for detecting content of uranium isotopes in oils by method of weight-spectrometry with inductively-connected plasma includes selection of oil samples and their decomposition with concentrated acid at high temperatures and pressure. Sample decomposition is carried out till full transparency according to multi-step programme in microwave oven by means of nitric acid in amount not less than 5 cm3 per each sample with weight from 0.4 g to 0.6 g. High frequency radiation power is maximum, pressure within autoclave being within the range from 500 to 1200 kPa, with exposure time on sample from 5 to 15 min at each decomposition stage.

EFFECT: ensuring full decomposition of hydrocarbon oils samples to state of transparency, reduction of sample decomposition time and lowering limits of detecting uranium isotopes in hydrocarbon oils samples.

1 dwg, 1 ex, 3 tbl

FIELD: physics; measurement.

SUBSTANCE: invention relates to measuring techniques. Control of oil decomposition is done based on varying the test parametre of working oil relative that of clean oil. The test parametre is calculated using fluorescence intensity of oil, simultaneously measured in three spectral ranges and two operating spectral ranges are used, in which intensity values are greater than in the third. The device has a case in which there is an optical window, and a receiving-transmitting unit, in which are fitted an optical emitter and receiver with a measuring photodetector. The measuring photodetector is a colour sensor, which allows for simultaneous measurement of fluorescence intensity of oil in three spectral ranges.

EFFECT: increased sensitivity and reliability of control.

5 cl, 6 dwg

FIELD: chemistry.

SUBSTANCE: in the method which involves centrifuging a prepared oil solution and subsequent suspension of the obtained residue, deposition takes place in a thin annular layer of the oil solution which rotates together with a rotor. Centrifugation is done once and decantation of the centrifuge effluent is done automatically when the centrifugal rotor stops. In the device which has a housing, an electric motor with a vertical shaft, the rotor is made in form of a reservoir with a removable cover, in which there are two cavities for putting the analysed oil solution, depositing impurities and decantation of the centrifuge effluent. The rotor also has a removable cylindrical insert made from metal foil for collecting residues which undergoes control weighing. The rotor is driven by the shaft of the electric motor through an overrunning centrifugal clutch which automatically connects them in startup and centrifugation mode and also disconnects when the electric drive is switched off, thereby providing smooth free run-out of the rotor with the filtered centrifuge effluent.

EFFECT: increased accuracy, simplification and faster determination.

3 cl, 1 dwg

FIELD: chemistry.

SUBSTANCE: method of determining colloidal stability of grease is realised from the amount of oil squeezed from the grease, where a cup full of grease with a piston and fitted with an oiled filter together with a set of dry filters is subjected to thermal stabilisation and subsequently held under a load, after which the amount of oil squeezed from the grease into the dry filters is determined. Before thermal stabilisation, a medium boundary is created between the analysed grease and the dry filters by separating them from each other in order to prevent penetration of oil into the dry filters before loading. The amount of oil squeezed from the grease is determined from the displacement of the piston during loading. The invention also discloses a device for realising the said method.

EFFECT: more reliable determination.

4 cl, 1 dwg

FIELD: oil and gas industry.

SUBSTANCE: method involves sampling and preparation of sample with thermostatting at temperature of 50-70°C with simultaneous extrusion of sulphurated hydrogen and light mercaptans with inert gas or air to in-series located absorbing solutions; at that, as absorbing solution for determining sulphurated hydrogen, there used is sodium carbonate solution, and as absorbing solution for determining light mercaptans there used is sodium hydrate solution, quantitative estimation of sulphurated hydrogen and light mercaptans by method of iodimetric titration. At that, before mixture of vapours of light hydrocarbons with sulphurated hydrogen and light mercaptans, which is extruded from the sample with air or inert gas, enters in-series located absorbing solutions, it is cooled to the temperature of more than 15°C to 20°C.

EFFECT: improving accuracy and reliability, and speeding-up the analysis.

5 ex, 3 tbl, 1 dwg

Up!