On - line regime composition distribution
FIELD: oil-and-gas production.
SUBSTANCE: invention related to oil-and-gas production and meant multiphase fluid for oil and gas composition analysis. Method executed in on - line regime. From the sources flow transported as a mixed flow via single pipeline. In and after the pipeline execute composition measurements, at least on of the mixed flow phases. It is analysed with device, which uses mixed flow fluid probes, the measurement results sent to computing device, which calculates flow form every source with help of separation algorithm that uses measured mixed flow, analysed composition of at least one phase, associated with every source.
EFFECT: distribution of backward flow to well or reservoir reliability increase in oil and/or gas production systems.
24 cl, 4 dwg
The technical field
The invention relates to systems of oil and/or gas. In particular, the invention relates to the identification of how much each source, such as a single borehole or a productive area, contributes to the total flux of the source.
Source in the system of oil and/or gas may be, for example, borehole, area production area tank or reservoir. The flow from each source is usually a multiphase flow comprising the composition of components related to oil and gas, brine, metals, water and so on. Flow can be defined as mass flow or volume flow. Usually, the lines from a variety of sources using any tools connected to a single pipeline. In the case of oil and gas from offshore fields it can be a riser, which brings the total flow to the operating equipment on the sea surface. An example of such operational equipment serve as a production platform, a mining ship or shore mining equipment. This means that streams from different sources are mixed before they enter the operating equipment. Therefore, the breakdown of the flows for each source is the main task.
Prior t the transport shows that the direct measurement of the expenditure flows in multiphase flows is possible with the use of measuring multiphase flows. As already mentioned, the streams from multiple sources are often mixed in the same stack, so to measure the direct costs of each source, for example, requires a multiphase flow meter associated with each of them.
There is prior art in the field of analysis of oil and gas compositions for multiphase fluid. U.S. patent 5166747 describes a device for analyzing the composition of fluids in the wellbore. The device distinguishes between formation fluids and drilling mud. The device uses absorption spectral information to determine fluid composition.
European patent 859236 discloses a method for selecting at least one component of the crude oil flowing through the pipeline, and then through the separator. The method includes the step of analyzing the sample of crude oil before it goes into the pipeline, to obtain analytical results before the crude oil from which was taken the sample will enter the separator.
In International publication WO 9414060 described composition analyzer for determining the composition and flow of multicomponent multiphase fluid containing gas. The analyzer sod is RIT the pipeline to receive the stream of multi-component and multiphase fluid. The section of the pipe is heated. The analyzer includes means for measuring temperature, pressure and flow rate of the fluid at the point directly above and downstream of the heated section of the pipeline. The measurement results are sent to the programmable logic of a computing device that is programmed to use the equations of thermodynamics and condition of the gas to calculate the fluid composition and expenditure flows compositions of fluids.
One way costs are allocated to the source is the application of computer simulation to determine the cost of threads, which gives the closest possible approximation to the measured flow parameters such as pressure and temperature. Such parameters can be obtained for each source or pipeline conveying fluid from a source. The remaining problem is that the success of this method depends on the availability of the results of the pre-made measurements, and how reliable are the models and computer simulation. The problem is that these measurements are often not available due to high cost. Another problem is that if such measuring equipment is available, but has failed, the repair may have a high value is ü, it is located under the surface of the sea or even in the descending well. Even if such equipment is repaired or replaced, there remains the problem of estimation or calculation of the flow from the sources, while the measurement results are not available.
It is known that fluids produced from different sources usually have slightly different compositions. The mixture of certain oil, gas and water is an example of a fluid. Fluids obtained from different sources of production consist mainly of the same components, but usually, their concentrations vary slightly from one source to another. Publication "description of the Deposit Big Burgan: using Geochemistry and identification of oil"; "Characterizing the Greater Burgan Field: Use of Geochemistry and Oil Fingerprinting"; SPE 37803, published by the Society of Petroleum Engineers, Inc. in 1997, describes that the identification of the characteristics of the oil are determined to develop tanks and are used to identify wells with mixed production due to mechanical problems of the wellbore.
Another problem is that the increased demand for improved reliability and stability of the flow distribution is implemented in existing facilities where possible operational flow measurements from separate sources. For example, there is a need to continue in the execution flow distribution, at that time, as such measurements online are not available due to equipment failure or connection.
The above problems as well as other problems are solved by the present invention, is described below.
The aim of the invention is the provision of a method of distributing flow back to many sources in the system of oil and/or gas, which is independent from operational measurements carried out in or close to the sources.
The aim of the invention is the provision of a method in which the mixed flow from the at least one phase is measured online at or after the pipeline that transports the mixed flow from the at least one phase. Additionally, the method includes that the composition of the registered components of the fluid, at least one phase of the mixed flow is analyzed online using the analysis device, which can be any of the devices that are implicitly or explicitly determine the concentration of components of the fluid. The method also includes the fact that the measured flow rate of the mixed flow and analyzed the composition is made available computing device. The computing device calculates the flow from each source using the allocation algorithm. The algorithm races the determining uses the measured mixed stream and analyzed the composition. Additionally, the method includes that the allocation algorithm uses the composition of at least one phase associated with each of the involved sources. In the method, the composition of at least one phase of each source is set to perform online measurements, operational analysis, and rapid calculation. The composition of at least one phase associated with each of the involved sources, can be installed using the technology of the prior art based on, for example, testing a single well.
The word "online" means that measurement, analysis and calculations are performed during normal production in the system of production and, moreover, that the measure, as well as sample fluid for analysis, are carried out online from the mixed stream. The test fluid used in the analysis online, taken at any point in the production system, where the flows from all sources are in the same mixture, for example at the end of the riser. At least one phase may be a gas phase, an oil phase or an aqueous phase, or any combination of the mentioned phases.
Important and particularly useful characteristic of the invention is that it makes it possible for online distribution flows back to the source, where it is enough only is one of the online analysis of the composition of, at least one phase of the mixed flow and only one dimension of the stream.
An important advantage of the invention is that it provides flow distribution without installing equipment for measurement of flow parameters such as flow rate, temperature or pressure at or near the source. Thus, the invention reduces the cost of the system oil. Such equipment may be installed, in spite of the cost, but in this case the invention provides that the distribution of flows is performed, even if the connection to such equipment is not available or the connection with the surface broken.
Another advantage of the invention is that a method for the rapid distribution based on the use of data obtained from equipment that is less expensive to maintain and repair compared to the equipment needed for the methods of the prior art. The invention is particularly useful in the system of oil and/or gas from offshore fields, because the invention allows that all measurements online intended for flow distribution, are above sea level or close to it. This means that, compared with the methods of distribution of the prior art, which are dependent on the equipment for carrying out of Areni, beneath the water, at the wellhead or in the borehole, the invention discloses that the equipment required for operational measurements, can be installed on the surface, which in turn provides less expensive maintenance and faster repair.
Another advantage of the invention is that if the dimension of the mixed stream is not available and the only available measurement is the online analysis of the composition of at least one phase of the mixed flow, the invention still allows the distribution of relative flows back to the source.
Another objective of the invention is the provision of a system for distributing flow back to many sources in the system of oil and/or gas. The system includes a measuring device which iteratively measures the flow rate of the mixed flow of the at least one phase, while the measurements are performed at or after the pipeline. The system further comprises an analyzing device that repeatedly analyzes the composition of at least one phase of the mixed flow. The device serves samples of fluid from the mixed stream. The system further comprises a computing device in which the flow from each source is repeatedly calculated by using the mention is on allocation algorithm.
Another objective of the invention is the provision of a computer program, comprising means software code that is downloaded to the CPU of a computing device. The computer program can perform any of the steps described above.
Another aim of the invention is the provision of a computer program product, stored on computer readable media containing means software code that is downloaded to the CPU mentioned computing device. A computer program product capable of performing any of the steps described above.
Brief description of drawings
The present invention will be described in more detail in connection with the attached schematic drawings.
Figure 1 shows a General view of the system of oil and/or gas. The system of oil and/or gas in the example is a system of production from offshore fields.
Figure 2 shows the fundamental General view of many multiphase flows, mixed into a single stream.
Figure 3 shows a General view of the method in accordance with the invention.
Figure 4 schematically shows a system in accordance with the invention.
Detailed description of the invention
Figure 1 shows a General view of the system 1 oil and/or gas. Figure 1 shows an example system oil and/or gas from the offshore location is of an unforgettable. System for the extraction of oil and/or gas contains many sources. Figure 1 shows a production system containing stream, such as multiphase flow, from a variety of sources, designated as 2 and 3. A common thread of the threads of the sources is mixed in the means of transportation, such as pipeline 4. One of the types of pipeline in the case of production from offshore fields is the riser. Sources 2 and 3 may, for example, be wells, productive zones, reservoir zones or reservoirs. The invention relates to the execution flow distribution online back to many sources in the system of oil and/or gas. The system of production from offshore fields may contain surface (side) of the separator 5. The location of the device 8 measurement of flow and analyzer 7, operating in the online mode, is symbolic and is not limited to the location after the separator 5, or a specific outlet of the separator.
Figure 2 shows a schematic General view of the sources, flows, and compositions in the system of production. Mixed flow mT20 is a mixture of stream m1, ...,mk22b-24b from each source 22a-24a. The mixed stream is a stream of at least one phase of each of the sources. Therefore, the mixed stream may be a subset of the total flow in drobopro the de 4. Sources may be sources 2 and 3, shown in figure 1. The flow from each source by means of the invention is, for example, as mass flow or volume flow. The invention makes possible the distribution of online using the appropriate device for establishing the composition of the CTmixed flow 20. The distribution is based on the measurement at any point in the production system, where the flows from all of the involved sources are a mixture. This point for measurement can be, for example, at the end of the riser, separator or at the outlet of the separator. This online analyzer symbolically shown as 7 in figure 1. Can be used on any other device or method of measurement, which explicitly or implicitly determine the composition of the registered components of the fluid. Analyzed the concentration of the registered components of the fluid, such as hydrocarbon composition of the oil phase or the concentration of salts in the aqueous phase or any combination of phases. Again it should be noted that in this context, the fluid may contain one or several phases. If you are considering one or multiple fluid phases, it can be defined as another fluid. The analyzing device may be a chromatograph, a device that uses near-infrared spectrum, a mass spectrometer and the device, using fluorescence in the ultraviolet region of the spectrum.
In the system of oil and/or gas from each source 22a-24a usually has its own distinctive signatures concentrations. Each source contributes to the mixed stream, which may not be associated with any other sources. The method based on the invention for distribution online, uses this signature together with the following algorithms. Is it possible to influence these signatures or concentration, for example, by introducing a fluid, such as methanol or transporting gas at the points where the streams have not yet mixed. It makes discernment composition flows between the sources is quite simple. The method based on the invention includes that at least part of the fluid coming from each source is installed and associated with each source 22a-24a. Under the structure usually refers to a hydrocarbon compound and/or composition of the inorganic components. Examples of measurements and analytical methods to establish a composition for one source were discussed in the section on prior art. Establishing a composition may include the use of measuring equipment, which temporarily or permanently placed in the well, the wellhead or in sebastain. Establishing fluid composition from the source may also include that of the source is taken to be the set of samples. Another possibility is the establishment of a composition directly from the mixed stream, which can be performed with a known flow of each involved well in some moments of time and the composition of the mixed flow measured in these same moments of time. Another possibility is to control the composition with other measured parameters of the fluid and the model fluid. Any of the above or other methods known prior art can be used to establish the composition of at least one phase flow from each affected source. As a result, each source gets its own vector of composition c1, ...,ckthat contains the relative magnitude of each component associated with this source. Again it should be noted that the fluid may consist of any set of phases of phases that contain the flow. Phase, for example, may be oil phase, gas phase or aqueous phase stream. Vectors compositions generally linearly independent. It is preferable to assume that the vectors compositions are constant for a given period of time.
Figure 3 shows a General view of the method in accordance with the invention.
JV the property includes multiple measurement 30 flow mixed flow out, at least one phase. The term "repeatedly" means that the measurement stage and other stages of the method are performed repeatedly usually after a fixed interval of time. An example of such a suitable interval is 1 hour. "Repeatedly" means that other steps of the method are performed before the phase measurement will be repeated. Must not interfere with that in an alternative embodiment, measurement of the mixed flow can be performed continuously during phase measurements. Flow mixed flow mT20 of at least one phase, for example, aqueous phase, oil phase, gas phase or combination is measured online. In other words, the mixed flow refers to the amount of the expenditure flows from each affected source 22a-24a, source1, ..., sourcek. If the measurement of the flow rate is unavailable, the method based on the invention, is not able to spread the cost flows in absolute numbers, but he is able to distribute the sources relative expenditure flows. In the case of the variant implementation in the system of production from offshore fields can be measured mixed flow in the riser. An alternative implementation in the system of production from offshore fields may include the fact that the mixed flow corresponds to the gas f is ze and is measured at the outlet surface (side) of the separator 5.
The method in accordance with the claimed invention additionally includes the fact that the composition of cT25 flow mixed flow 20 of at least one phase repeatedly analyzed 31 online. The sample of fluid is taken at any point in the production system, where the flows from all sources involved are in the same mixture, for example, at the end of the riser. At least one phase of the analyzed online, corresponds to at least one phase, a pre-associated with each of the involved sources 22a-24a. Additionally, similarly, at least one phase is analyzed, as measured by the mixed flow at the measurement stage. The analysis can be performed several times, each time is the analysis phase. As well as the measurement stage, the analysis stage is performed repeatedly. The composition typically contains hydrocarbons and/or inorganic composition. Components in the analysis phase can be a subset of the components of at least one phase, such as the heaviest components in the oil phase or the light components in the gas phase. It is preferable to use equipment that is tested in the analysis of the composition, such as described above, the analyzing device 7. The online analysis and the above offline analysis-setting composition associated with each East is cinecom, can be done very well using the same analysis device.
The method in accordance with the invention additionally includes that to the measured flow and analyzed composition is accessed 32, and they are made available computing device 9. Examples of such a computer is a workstation, personal computer (PC), programmable logic controller (PLC), portable computer, the system process control analyzer, measuring device or a specialized device. To perform calculations in the most effective way calculations and algorithms can be implemented on any number of devices. It is preferred that the measurement and/or analysis results automatically sent to the device or device using a communication means, for example, with industrial communication networks Fieldbus.
The method in accordance with the invention additionally includes the fact that the computing device calculates the flow from each source using the allocation algorithm at the stage 33 of the calculation. As well as the phase measurement and analysis phase, the phase calculation is performed repeatedly. The basic principles of the calculation method described below. In the future there will be different is I between the consideration of the mixed stream from one or more of its phases or mixed flow of all phases.
As mentioned, Figure 2 shows a General view of the involved vectors used in the phase calculation method based on the invention. Figure 2 shows the compositions
c1, ...,ckand cT.
As shown previously, c1, ...,ckusually installed offline. c1, ...,ckare structures associated with each of the individual sources, source1, ..., sourcek. cTis a vector of composition or concentration of the mixed stream. The structure in the embodiment of the invention is analyzed multiple times during production online. The above and subsequent descriptions of the composition measurements are symbolic and should be considered as an example and should not limit the scope of the invention. May be, for example, that one or many components are measured, and relationships with other compositions are calculated from these measurements.
The flow rate may be, for example, measured and expressed as mass flow or volume flow. Consumption 20 mixed flow in one or more of its phases, mTas mentioned earlier, must be measured, while the corresponding expenditure flows of the above-mentioned one or more phases from each source 22b-24b, m1, ...,mkare the unknown costs of threads that must be calculated using the lgorithm distribution. If the flow rate of the mixed flow of all phases is not measured and, on the contrary, the flow rate for one or multiple phases measured, the flow rate for one or multiple phases corresponding to each source is calculated in the calculation step.
Below is a schematic General view of the matrices used at the stage 33 of the calculation, which distributes the flow to multiple sources 22a-24a. The matrix C is the matrix in which the vector compositions c1, ...,ckare columns.
Let m determines the vector of expenditure streams from separate sources
The Superscript T means the transpose of the vector. Due to mass conservation expenditure flows and compositions satisfy the following matrix equation
Let w be a vector consisting of the corresponding expenditure flows from each source
W=[w1, ...,wk]Twhere wi=mi/mT, i=1, ...,k.
Matrix equation for conservation of mass of each component then reads
Before solving this system of equations is useful to exclude equations, which do not provide significant information about the real source of expenditure flows, or otherwise pre-treat the system of equations. The purpose is this kind of preprocessing is to minimize the effects of measurement errors. Pre-processing may, for example, to draw statistical and mathematical methods, experience-based decisions, or decisions based on product performance, providing calculations. Examples of suitable statistical and mathematical methods are multidimensional analysis (MMA) and linear analysis. A final set of equations can be solved in different ways. In one embodiment, the implementation uses the method of least squares.
Ready the matrix C is not degenerate, that is satisfied if its columns are linearly independent, the unknown vector w is calculated. When the vector w is defined, mass fraction or volume fraction (which is significant), derived from each source is known and if the flow rate of 20 mixed flow, mTmeasured, private expenditure flows [ml, ...,mk] calculated directly from the definition of wi.
Implementation of the algorithm can be implemented in a computer programming language such as C++ or similar. If at least part of the algorithm must be executed in the PLC or in the industrial controller, a suitable programming language for the implementation is a programming language based on standard IEC 6-1131, or programming language, which is at least partially what about the compliant IEC 6-1131.
The result of the calculation, which is the expenditure flows, distributed back to each source, temporarily stored in a memory of the computing device 9. The result of the calculation can be presented on a computer screen users, such as operators of the manufacturing process or manufacturing engineers. The costs of threads distributed back to each source, usually stored on computer readable media. Such computer readable media may be a hard disk, which is located near the system oil and/or gas or removed from said system, for example, on the shore in the event of a system of production from offshore fields.
The steps of the above method can be performed in a different sequence from the sequence in which they are described.
The system 40 based on the invention shown in Figure 4. The system includes the previously mentioned measuring device 8. The measuring device measures the flow rate of the mixed flow of the at least one phase. The measuring device may be a flow meter. It may also be a multiphase flow meter. Measurements are made at or after the pipeline. Measurements can be made before, at or after the existing surface (side) of the separator. The measuring device can measure the mixed flow from one to the basics, such as the gas phase.
The system 40 in accordance with the invention further comprises the previously mentioned analyzing device 7, which analyzes the composition of at least one phase of the mixed flow 4. In the analyzing device 7 serves samples of the mixed fluid flow. Samples are taken at or after the pipeline transporting the mixed flow. The sample fluid can be taken manually, automatically, or can be obtained by directing a jet of mixed flow in the analyzing device.
The system 40 in accordance with the invention further comprises the previously mentioned computing device 9. Computing device repeatedly calculates the flow 22b-24b ml, ...,mkfrom each source 22a-24a using the previously mentioned algorithm of the distribution.
The computer program 10 in accordance with the invention is able to perform any of the stages in accordance with the previously described manner. The computer program is loaded into the CPU already mentioned computing device 9.
The computer program product 10 in accordance with the invention stored on a computer readable medium and includes means software code that is downloaded to the CPU mentioned computing device 9. Computer software is able to perform any of the stage is in accordance with the previously described method.
Note that the above-described embodiments of the invention are merely examples and should not limit the scope of the invention.
1. The method of flow distribution back to many sources (22A, 23a, 24A) in the system (1) oil and/or gas, in which the composition of at least one phase of each of the sources (22A, 23a, 24A) is known and associated with each source, and the flow from the sources is transported in the form of the mixed stream (20) one pipeline (4), the said method is performed online and consists of the following stages, which are:
measure the mixed stream, at least one phase, these measurements are made at or after the pipeline (4),
analyze the structure of (25), at least one phase of the mixed stream (20) using a device (7), which uses a sample of fluid from the mixed stream (20), which is taken at or after the pipeline (4),
get access to data for the mentioned measured mixed stream (20) and referred to the analyzed composition and make them available to the computing device (9),
I hope in the specified computing device (9) stream (22A, 23a, 24A) from each source (22b, 23b, 24b) using a distributed algorithm that uses the measured mixed stream (20), referred analyzed with the Tav (25) and the above-mentioned composition, at least one phase associated with each source,
or if the phase measurement missing values of the mixed flow, the calculation step calculates the relative flow from each source instead of absolute flow.
2. The method according to claim 1 in which the said device (7) in the analysis phase uses technology that is explicitly or implicitly determines the concentration of the registered components of the fluid.
3. The method according to claim 1 or 2, in which the flow from each source is calculated as mass flow or volume flow.
4. The method according to claim 3, in which the composition of at least one phase are vector formulations with1, ...,ckassociated with the source1, ..., sourcekvector composition withtthe mixed stream is a vector compositions, at least one of the registered component of the fluid and the matrix composition is a matrix in which the vector composition of c1, ...,ckare the columns in this matrix symbolically represented as
5. The method according to claim 4, in which the measured mixed stream is mtcalculated flow from at least one phase from each source1, ..., sourcekis m1, ...,mkand m determines the flux vector from a separate source is of IKI,
which is symbolically represented as
6. The method according to claim 5, in which the expenditure flows and compositions satisfy the matrix equation
7. The method according to claim 6, in which the relative costs of the flows from each source are collected in the vector
w=[w1, ...,wk]Tin which wi=mi/mT, i=1, ...,k and Cw=CT,
and where each of the costs of individual streams of m1, ...,mkbased on the definition of wi.
8. The method according to claim 7, in which at the stage of calculation to solve the above system of equations.
9. The method according to claim 1, in which the system oil and/or gas is an oil and/or gas from offshore fields, the pipeline is a riser, the device used in the analysis phase, is located on the surface, and the springs are located under water.
10. The method according to claim 1, wherein the device (7) in the analysis phase is a gas chromatograph, a device that uses near-infrared region of the spectrum, a mass spectrometer, or a device using fluorescence in the ultraviolet region of the spectrum.
11. The method according to claim 2, in which the components of the analysis phase are a subset of the components of at least one phase.
12. The method according to claim 11, in which one of the components was prior is about injection in the source.
13. The system (40) to flow back to many sources (22A, 23a, 24A) in the system (1) oil and/or gas, in which the composition of at least one phase of each source is known and associated with each source, and mixed flow (20) of the sources is transported as a mixed flow in a single pipe (4), the above system has a capability of functioning online and contains:
the measuring device (8), which measures the mixed flow (20) of the at least one phase, the measurements to be performed at or after the pipeline (4),
the analyzing device (7), which analyzes the composition of at least one phase, the said device (7), which serves samples of the mixed fluid flow (20), which is taken at or after the pipeline (4),
computing device (9), in which the flow (22b, 23b, 24b) of each source (22A, 23a, 24A) is calculated using the distributed algorithm that uses the measured mixed stream (20), referred analyzed composition (25) and the above-mentioned composition of at least one phase associated with each source,
or if the measurement results by the measuring device, the computing device calculates the relative flow from each source together is the absolute stream.
14. The system of item 13, in which the analyzing device (7) uses any measurement technology, which explicitly or implicitly determines the concentration of the registered components of the fluid.
15. The system of item 13 or 14, in which the flow from each source is calculated as mass flow or volume flow.
16. The system of item 13, in which the composition of at least one phase are vector composition with1, ...,ckassociated with the source1, ..., sourcekas the vector composition withtthe mixed stream is a vector compositions, at least one of the registered component of the fluid and the matrix is the matrix in which the vector composition with1, ...,ckare the columns in this matrix is represented as
17. The system of item 13, in which the measured mixed stream is mtand hope flow from at least one phase from each source1, ..., sourcekis m1, ...,mkand m determines the flux vector from separate sources, which is symbolically represented as
18. System 17, in which the expenditure flows and compositions satisfy the matrix equation
19. System p, which costs from sidelnyk flows from each source are
w=[wi, ...,wk]in which wi=mi/mT, i=1, ...,k and Cw=CT,
and where each of the costs of individual streams of m1, ...,mkbased on the definition of wi.
20. The system according to claim 19, in which the step of calculating to solve the above system of equations.
21. The system of item 13, in which the system oil and/or gas is an oil and/or gas from offshore fields, the pipeline is a riser, the device used in the analysis phase, is located on the surface, and the springs are located under water.
22. The system of item 13, in which the analyzing device (7) is a gas chromatograph, a device that uses near-infrared region of the spectrum, a mass spectrometer or a device using fluorescence in the ultraviolet region of the spectrum.
23. Computer-readable media (10)containing a computer software product, comprising a means software code that is downloaded to the CPU of a computing device (9), when this computer program product is used to carry out the method according to one of claims 1 to 12.
24. The method of flow distribution back to many sources (22A, 23a, 24A) in the system (1) oil and/or gas, according to the specified method using the system according to one of p-22 for distribution of the population flow (22b,
23b, 24b) for many sources (22A, 23a, 24A) in the system (1) oil and/or gas.
09.05.2003 according to claims 1-24.
FIELD: physics, measurements.
SUBSTANCE: invention is related to facilities for odorisation of natural gases and may be used in gas, oil and other industries. The result is provided due to the fact that working, consumption tanks are used, as well as reservoir for storage of odorant, which are connected between other by pipelines, odorant is supplied into working reservoir from reservoir for its storage by means of creation of pressure difference between reservoir for its storage and working reservoir, afterwards, odorant is pumped from working reservoir into consumption reservoir, from which odorant is dosed into gas line, proportionally to gas consumption. Besides odorant is pumped from working reservoir into consumption reservoir by excess pressure from high pressure gas line, and in consumption reservoir pressure is created, which is equal to pressure in low pressure gas line, level of odorant in consumption reservoir is maintained as permanent with the help of float valve, and in working reservoir odorant level is controlled by detectors of upper and lower levels, process of working reservoir filling with odorant and its pumping into consumption reservoir is done by signals from level detectors with the help of electric valves, and batching is done from system of commercial accounting of gas consumption.
EFFECT: higher accuracy of batching.
FIELD: automation and management of technological processes.
SUBSTANCE: in the process of management of gasoline mixing station, characteristics of quality of mixture components and product at input and output of mixing collector are measured in each regulation cycle, values of time delays of mixture components with mixing collector and duration of mixing of components in mixing collector are determined, and forming of controlling influences is synchronized with moments of querying of product and mixture component quality analyzers at output and input of mixing collector with consideration of technological delays of mixture components in pipelines and in mixing collector. Adjustment of flow of mixture components is performed by realization of iteration procedure, which minimizes the number of measuring operations.
EFFECT: increased quality of product, increased productivity of mixing station and improved economical characteristics of the compounding process.
7 cl, 2 dwg
FIELD: engineering of means for automation of oil transportation process along different pipelines with different quality of oil and joining oil flows with control over quality parameters of oil mixture.
SUBSTANCE: in the method for controlling oil compounding process, flow values for transported oil flows are measured and also flow of mixed oil flow, content in transported flows and in mixed oil flow of sulfur and/or water is determined, relations of aforementioned contents in each of transported flows are determined and in mixed flow and relations of losses of each of transported flows and mixed flow and these relations are compared to given values, if all relations of flows correspond to given values and in case of deviation of relation of aforementioned contents for at least one transported flow oil flow is adjusted for appropriate flow, process for determining sulfur and/or water content in each of transported flows is performed by measuring density of oil in appropriate flow with consideration of correlation dependency between density and content of aperture component. System for controlling oil compounding process having , mounted in each oil pipe for transporting oil, flow meter, oil density meter and means for adjusting oil flow, mounted in oil pipe for mixed flow, oil flow meter, sulfur and/or water content meter, and also calculating device for coefficients of relation of oil flows in each transported flow and in mixed flow and/or device for calculating coefficients of relation of water contents in oil for each transported flow and in mixed flow, inputs of first of aforementioned calculating devices are connected to flow meters, and outputs of each one of aforementioned calculating devices are connected to appropriate inputs of comparison block, outputs of which are connected to means for adjusting oil flow, is provided with device for calculating sulfur content and/or device for calculating water content in oil, made with possible calculating of content of appropriate component with consideration of correlation dependency between oil density and content of aforementioned component, inputs of each of calculating devices are connected to oil density meters of transported flows, and outputs are connected to appropriate inputs of appropriate device for calculating relation coefficients.
EFFECT: increased efficiency.
2 cl, 1 dwg, 3 tbl
FIELD: engineering of automation systems.
SUBSTANCE: method for compounding oil includes continuous measurements of sulfur content in mixed oil flow and source flow of sulfurous oil and adjusting feeding thereto of highly sulfurous oil for providing required sulfur content in mixed oil flow. Adjustment is performed by evening out oscillations of sulfur content in mixed flow, for which purpose reservoir or reservoir park is used, connected to flow of highly sulfurous oil, in case when sulfur content in mixed flow drops below acceptable levels, a portion of highly sulfurous oil is fed thereto, enough to provide for required sulfur content in mixed flow, in case when sulfur content in mixed flow exceeds required value, feeding of highly sulfurous oil from reservoir or reservoir park to mixing point is halted, when reservoir or reservoir park is overflowed, flow of highly sulfurous oil is sent to mixing point with flow value equal to flow value of highly sulfurous oil entering aforementioned reservoir or reservoir park.
EFFECT: maintained stability and evenness of mixing.
2 cl, 3 dwg, 3 tbl
FIELD: petroleum processing and petrochemistry.
SUBSTANCE: process comprises heating additives, pumping and mixing them with oil components. Oil components and additives are mixed by synchronously feeding them into collecting channel provided with static mixer. Synchronization is provided by frequency changers, employed in automated control system, to control speed of rotation of pump motors. Oil components are controlled by means of Coriolis-type flowmeters.
EFFECT: reduced oil preparation time, reduced power and expensive materials consumption, and increased component dispensing accuracy.
3 cl, 1 dwg
FIELD: automation of processes for transporting oil with different quality parameters through different pipelines.
SUBSTANCE: systems may include at least two oil pipelines designed for transporting oil flows and oil pipeline designed for mixed oil flow. System includes shutters mounted in oil conduits and designed for controlling respective oil flows, devices for measuring density, flow rate, content of sulfur or chlorides and water content. Said devices are connected with units for calculating parameters and determining relation of said parameters in each flow relative to mixed flow. System also includes microprocessor designed for comparing measured and calculated parameters with preset ones and for generating signals for regulating shutter position in respective flows according to comparison results.
EFFECT: possibility for controlling oil compounding process according to several quality parameters.
FIELD: systems for controlling or regulating non-electric variables.
SUBSTANCE: odorizer comprises main and calibrating tanks filled with odorant, batching device made of electromagnetic pulser provided with the check valve and bellows batcher, flow rate meter, and computing unit. The electromagnetic pulser has housing, core, coil, and spring. The bellows batcher is made of nonmagnetic housing which receives a sleeve connected with the electromagnetic pulser through the check valve. The pipe passes through the bottom of the sleeve. The cap is mounted above the top end of the pipe. The cap is connected with the control device. The double-arm lever is mounted in the bottom part of the housing. One arm of the lever mounted under the bottom end of the pipe is provided with cup having opening in the bottom. The other arm of the lever is provided with a permanent magnet which interacts with the magnetoelectric lead mounted outside of the housing of the bellows batcher and connected with the electromagnetic pulser through the computing unit. The batcher also has valves, batch divider, port, and reserve passage for supplying odorant.
EFFECT: simplified design.
FIELD: operative manufacture planning.
SUBSTANCE: method is based on use of computer system, including an optimizer, tables for selection of goal function, block for determination of optimization method. Database for recording inputted information and received results is used as well as block for importing data concerning initial state of reservoir fleet and mixing task. Graphic user interface is used to indicate and alter current data during creation of timetable, parameters for optimizer adjustment and indication of textual and graphical system reports. Block for controlling trustworthiness of initial data for forming the best timetable, block for generation of optimization task matrix and block for interpretation of results of optimization task solution are used. Data concerning amount of components, admixtures and product oils in all mixing reservoirs at the moment of beginning of timetable creation, concerning planned tasks for readiness of product oils at certain time moment in accordance to shipment graph, concerning mixing receipts and certification time for each oil, concerning mixing time and readjustment of mixing reservoir during transfer from one oil type to another, concerning speed of feeding of each component and admixture from appropriate reservoirs, concerning configuration of area of mixing and amount of mixing reservoirs are all transferred to computer system from data import block. After check of physical possibility, linear programming matrix is generated for use by optimizer, which automatically selects an optimization method for determination of the best timetable, which is interpreted in form of series of mixing of given product oils, beginning and ending time for each mixing, transfer of each component and admixture from appropriate reservoirs for mixing of each oil, beginning and ending time for feeding of prepared oil directly after mixing and certification into appropriate product reservoir, time of switching feeding of component after filling of one component reservoir to another by results interpretation block.
EFFECT: higher efficiency.
FIELD: measurement equipment.
SUBSTANCE: measurement electronic device (20) of flow metre includes interface (201) for receiving frequency characteristic of flow material and data processing system (203) which receives from interface (201) the frequency characteristic containing the signals of the first and the second sensors, and breaks it into frequency component of gas and frequency component of fluid. Data processing system (203) determines total density as to frequency characteristic, gas density as to frequency gas component, volume content of gas as to frequency characteristic and one or more from frequency gas component and frequency component of fluid, and mass fraction as to volume content of gas multiplied by ratio of gas density divided by total density. Besides data processing system (203) is intended for determining instantaneous frequency and instantaneous phase difference by means of which mass flow rate is determined.
EFFECT: invention improves measurement accuracy of mass fraction of components and mass of abruptly changing two-phase medium flows with air bubbles involved.
36 cl, 20 dwg
SUBSTANCE: invention is intended for measuring multicomponent mixture stream coming out of well. Fluid stream consisting of the first component (oil) and the second component (water) is directed into the first pipeline (108) where it is divided into two streams using gravity. Using the second pipeline (110) connected with the first pipeline water is continuously sampled from the liquid flowing in the pipeline (108), and sample density is measured in the second pipeline using Coriolis flowmetre (116).
EFFECT: increasing measurement accuracy while reducing labor consumption.
19 cl, 4 dwg
SUBSTANCE: metre electronics (20) of coriolis flow metre, through which multiphase material flows, includes an interface (201) for receiving first and second sensor signals (210 and 211). Data processing system (203), which is part of the metre electronics (20), can receive first sensor signal (210) and second sensor signal (211), generate the first ninety degree phase shift (213) from the first sensor signal (210) and generate a second ninety degree phase shift (214) from the second sensor signal (211), calculate frequency (221) using one of first ninety degree phase shift (213) or second ninety degree phase shift (214), calculate phase difference (220) using one or more of first ninety degree phase shift (213) and second ninety degree phase shift (214), and calculate one or more mass flow (223), density (224) or volume flow (225) of the multiphase flow. Data processing system (203) also generates instantaneous flow density to determine one or more liquid content (1427) or gas content (1428).
EFFECT: increased accuracy of measurement.
39 cl, 27 dwg
SUBSTANCE: electronic measuring device (20) has an interface (201) for receiving the first sensor signal and the second sensor signal from a flow metre and a data processing system (203), linked to interface (201). Data processing system (203) can receive the first and second sensor signals from interface (201), shift the phase of the first and second sensor signals by 90 degrees, calculate the frequency characteristic using the 90 degree phase shift of the first or second sensor signal, determine instantaneous density of the gas stream using the frequency characteristic, compare the instantaneous density of the stream with at least one preset density of gas or preset density of liquid and detect liquid phase based on the said comparison, and based on the instantaneous density of the stream. In the embodiment, instantaneous density is further compared with excitation transfer coefficient.
EFFECT: increased accuracy of measuring liquid fraction in a gas stream.
28 cl, 17 dwg
FIELD: measurement equipment.
SUBSTANCE: invention is intended for measurement of two-phase or multi-phase mixture with the help of Coriolis metre of mass flow/density and/or viscosity. Measurement device comprises metering converter of vibration type and electronic equipment electrically connected to it. Metering converter comprises at least one measurement tube installed in pipeline line. Electronic equipment supplies excitation current to system of metering tube oscillations exciter, and system of detector produced at least one signal for measurement of metering tube oscillations. To obtain value that represents physical measured value, electronic equipment estimates, based on excitation current and at least one signal of oscillations measurement, Coriolis coefficient of communication between the first internal mode of free oscillations of metering tube, specified at current moment by excitation system, and the second internal mode of free oscillations of metering tube. In the second internal mode metering tube has its own shape, which corresponds to mode of oscillation caused by forces of Coriolis induced in flowing mix. Due to change in concentration of at least one of mix components Coriolis coefficient of communication varies in time.
EFFECT: invention increases accuracy of heterogeneous medium measurements.
20 cl, 14 dwg
FIELD: physics, measurement.
SUBSTANCE: measurement electronic device (20) comprises interface (201) for reception of frequency characteristic of flow material and system (203) for processing of data related to interface (201). System (203) for data processing is intended for reception of frequency characteristic from interface (201), breakdown of frequency characteristic at least into frequency component of gas and frequency characteristic of fluid and detection of volume content of gas by frequency characteristic and one or more components from frequency characteristic of gas and frequency component of fluid.
EFFECT: invention provides for higher accuracy of measurements in double-phase flow due to fast detection of frequency by received signals of Coriolis flow metre detectors.
34 cl, 20 dwg
FIELD: physics, measurements.
SUBSTANCE: electronic metre (20) includes interface (201) for reception of oscillating response of flowing substance that comprises at least the first signal of detector and the second signal of detector, and system (203) of processing that communicates to interface (201). System (203) of processing is intended for reception of oscillating response from interface (201), generation of ninety-degree phase shift from the first signal of detector and generation of at least one parametre of flow with application of at least the first signal of detector and ninety-degree phase shift, comparison of at least one flow parametres with at least one set of parametres that define abnormality, detection of shift in oscillating response, if at least one flow parametre is within the limits of set of parametres that determine abnormality, and indication of abnormality mode (for instance, air bubbles, two-phase or multi-phase flow) as a result of detection.
EFFECT: provision of possibility to detect any abnormalities in flowing substance in online mode due to application of fast frequency and phase difference determination by signals of detectors.
45 cl, 20 dwg
SUBSTANCE: invention is intended for determination of velocity in mix of gaseous and liquid components, mostly steam flowing in steam pipeline of small diametre and mixed with liquid phase in the form of water drops of different size. In process of measurement two collimated light beams spaced in direction of flow at previously specified distance are sent via polyphase liquid medium by means of pipe transparent sections from illuminating device (light diode, junction laser). Scattered, deflected and weakened light is detected with the help of two photo detectors connected to two collimated beams for creation of two signals. Cross-relation function is calculated between two signals to determine time delay between signals; and average velocity of polyphase liquid medium is calculated as ratio of previously determined distance to time delay. In version of realisation pair of flat light beams are sent through liquid medium.
EFFECT: increased accuracy of measurement of average and local velocity of steam medium, possibility to define steam quality.
19 cl, 19 dwg
FIELD: physics, measuring.
SUBSTANCE: invention can be used in the petroleum industry for measuring of oil-water-gas intermixtures. The method includes following stages: perform electromagnetic measuring of losses and a phase in two directions of a pipe. On the basis of these measuring determine degree of formation of a ring stream. On the basis of effects of two previous stages, including updating depending on degree of formation of a ring stream, calculate an inductivity of the specified intermixture; measure density of an intermixture and correct the found value depending on degree of formation of a ring stream. Obtain values of temperature and pressure; determine velocity of the fluid and gas and on the basis of known values of densities and inductivities of builders of a fluid intermixture and with use of the effects gained at the previous stages, calculate volume and mass rates of flux of the intermixture components. The method is realised by a rate-of-flow indicator containing one transmitting antenna and two accepting antennas, located in the same traversal section of tubular section, and one transmitting antenna and two accepting antennas spatially parted in a dilatational direction of tubular section, and also density gauge on the basis of uptake of γ-radiation or pressure drop measuring in the Venturi tube.
EFFECT: increase of measuring accuracy in the conditions of a ring stream and in case of major concentration of gas in the middle of a pipe, without prestress intermixing, with use simple actually nonintrusive constructions.
21 cl, 17 dwg
FIELD: physics; measurement.
SUBSTANCE: present invention pertains to measurement technology, and specifically to measurement of flow characteristics of liquid and/or gaseous media, and can be used for controlling streams with varying flow rate, particularly when designing control of oil and gas deposits by measuring production capacity of each well in a group. Flow meters are fitted in pipes carrying the product of the well and connected to a recording device. Signals from the flow meters are recorded. The flow meters used have accuracy of not more than 18% and sensors for measuring density of the well product can also be fitted. The density sensors are fitted if the signal from the low accuracy flow meter deviates by a value exceeding a preset value.
EFFECT: lower cost price of the system for monitoring operation parameters of a well field with increased efficiency and information content of measurements at the same time.
7 cl, 4 dwg, 1 ex
SUBSTANCE: invention refers to methods of drilled operating wells investigation and can be used for reveal of hydrocarbon-bearing formations directly on completion of their drilling by gamma-ray logging (GR) during well rearrangement. This is achieved by activating tracing fluid with low-active radon in such a view that radon specific activity in tracing fluid would be of 0.37-1.0 MBq/m3. With such radon concentrations, licensing of such works is not required according to radiation safety standards "НРБ-99", i.e. they are environmentally safe. At the end of penetration after drill column has been lifted the GR is performed and hydrocarbon-bearing formations are selected according to values of gamma ray intensity exceeding 50 mcR/h. The method features the simplicity of technical execution, use of standard equipment, environmental safety, high sensitivity and reliability.
EFFECT: increase in reliability of hydrocarbon-bearing formation reveal from GR which is performed during well drilling.