Well temperature measurement device
FIELD: oil and gas industry.
SUBSTANCE: device includes a mechanical oscillating system with constant magnets fixed on it and a converter of mechanical oscillations to electrical ones. A mechanical oscillating system is made in the form of a cylindrical bimetallic spiral, one end of which is rigidly fixed, and the other one is free, and the converter of mechanical oscillations to electrical ones is made in the form of a system of interacting electromagnetic fields of constant magnets rigidly fixed on a cylindrical bimetallic spiral and coils of a drive and pickup of oscillations providing for transverse oscillations of the cylindrical bimetallic spiral.
EFFECT: enhancing reliability of a device and improving its design.
The invention relates to the oil and gas industry, namely, devices for measuring the temperature of the drilling fluid in the drilling process.
A device for temperature measurement in wells.with. The USSR №1298365, 1987), contains a source of energy, temperature Converter, made in the form located in the housing of the jet generator, consisting of inkjet element, comprising a power nozzle, inlet and outlet nozzles placed in the recess panel and interconnected switching channels. A disadvantage of this device is the difficulty in implementing a power source and increased the time of data acquisition in connection with the use of subsonic frequency range.
The closest in technical essence is a device for measuring the temperature in the wells.with. The USSR №279520, 1971), which contains a mechanical oscillatory system with fixed permanent magnet, a Converter of mechanical vibrations into electrical and filled with mercury bulb. Mechanical oscillatory system is executed in the form of a hollow balance attached to the tube associated with the bulb, and the cavity of the balance sheet, tube and bulb are connected with each other. The ripple is made as follows. In the drive system and volume served a short current pulse Magnetic field, generated in the coil by this pulse interacts with the field of a permanent magnet, and the balance begins to oscillate. Eat oscillations is made by the same coil. A disadvantage of this device is the low frequency of the mechanical oscillatory system, which reduces the amount of information received from the device temperature measurement, i.e. not fully use the bandwidth of a wired communication channel.
The technical objective is to create a reliable and accurate device for monitoring the temperature in the borehole during drilling.
The technical result is increased reliability of the device and improving its design. It is achieved that the device containing a mechanical oscillatory system with fixed permanent magnets and a Converter of mechanical vibrations into electrical, mechanical oscillatory system is executed in the form of a cylindrical bimetallic spiral, one end of which is rigidly fixed, and the second is free, and Converter of mechanical vibrations into electrical executed in the form of a system of interacting electromagnetic fields of permanent magnets fixed on the cylindrical bimetallic spirals and coils of the drive and pickup fluctuations, providing transverse vibrations of a cylindrical bimetal is political spiral.
In Fig.1 shows a device for measuring the temperature in the well.
The device is located in the drill pipe, casing, rigidly attached to the bottom of the borehole by means of ribs. It contains a mechanical oscillatory system 1 made in the form of a cylindrical bimetallic spiral, one end of which is rigidly fixed, and the second is free. Inside the case there is a coil of the actuator 2, two permanent magnet 3, the coil removal rate fluctuations 4 associated with the communication line 5.
The device operates as follows.
In the drive system 2 is fed a short current pulse. The magnetic field created in the coil of the actuator 2 this pulse interacts with the field of the permanent magnet 3, and a bimetallic cylindrical spiral 1 begins to oscillate. Changing the temperature of the washing liquid causes a change in the oscillation frequency of the cylindrical bimetallic spiral 1. Eat oscillations produced by the coil of the pickup 4.
It is established that there is a relationship between the frequency of the forced oscillations of a cylindrical bimetallic spiral and temperature in the well. A dependency graph, obtained experimentally, is shown in Fig.2. Thus, changing the frequency of the current is transmitted through the communication line at the wellhead and registered devices. This information is used to carry out the control process is com wiring hole.
The pulse frequency of the cylindrical bimetallic spiral is defined by the equation:
where f0the oscillation frequency, Hz;
E - the modulus of elasticity of the material of the bimetallic cylindrical helix;
γ is the density of the material of the bimetallic cylindrical helix;
e and L is the thickness and length of the bimetallic cylindrical spiral.
The device parameters are in good agreement with the parameters of the wired communication channel bottom and the mouth of the well.
The device allows to increase the accuracy of measuring the temperature of the drilling fluid in the borehole during the drilling process and increases the reliability of the structure.
Device for measuring temperature in a borehole containing a mechanical oscillatory system with fixed permanent magnets and a Converter of mechanical vibrations into electrical, characterized in that the mechanical oscillatory system is executed in the form of a cylindrical bimetallic spiral, one end of which is rigidly fixed, and the second is free, and Converter of mechanical vibrations into electrical executed in the form of a system of interacting electromagnet the agricultural fields of permanent magnets, rigidly mounted on the cylindrical bimetallic spirals and coils of the drive and pickup fluctuations, providing transverse vibrations of a cylindrical bimetallic spiral.
FIELD: oil and gas industry.
SUBSTANCE: invention is related to the area of wells completion and testing in oil industry and intended for calculation of parameters for the well bottomhole and bottomhole area. The method where in process of string movement in the well pressure is measured by two sensors, at that one sensor is installed over the packer while the second one is installed below the packer. According to results of pressure measurement fluid density is determined and then flowing bottomhole pressure is determined on the basis of fluid density, gravity constant, preset rate of drilling string motion, cross-sectional area of the drilling string, formation pressure, and productivity index of the well.
EFFECT: potential determination of parameters for the well bottomhole and bottomhole area during round-trip operations with further calculation of liquid influx/reflux at the bottomhole and calculation of skin factor, permeability or thickness of the reservoir.
13 cl, 5 dwg
FIELD: oil-and-gas industry.
SUBSTANCE: evaluation of fluid inflow fraction from every productive zone of multi-zone productive well comprises determination of pressure at wellhead. Integrated indicator curve (IPR1) is obtained to describe the relationship between pressure and fluid yield from first productive zone and integrated indicator curve (IPR2) is obtained to describe the relationship between pressure and fluid yield from second productive zone. Value for integrated indicator curve at the point of mixing (IPRm) is obtained with the help of IPR1 and IPR2. Initial fluid inflow fraction from first productive zone at mixing points and initial fluid inflow fraction from second productive zone are defined. First total curve of outflow (TPR1) is obtained describing the relationship between fluid pressure and yield, fluid flowing from mixing point to wellhead. First portion of fluid inflow from first productive zone (Q11) and first portion of fluid inflow from second productive zone (Q21) are defined at mixing point with the help of IPRm and TPR1. Machine-readable carrier accessible for processor comprise program including instructions for above listed jobs.
EFFECT: more efficient evaluation of the portion of influx from productive seam.
20 cl, 5 dwg
FIELD: measurement equipment.
SUBSTANCE: system (100) of sensors for measurement of a technological parameter of a fluid medium in a well location, comprising a resonator (110) of a parameter, which is located in a well (106), having resonance frequency that varies depending on the technological parameter of the fluid medium and which in response generates a resonant acoustic signal on the resonance frequency that indicates the technological parameter. Besides, the system comprises an acoustic sensor (118), arranged in the location near above the surface, spaced from the parameter resonator, a measurement circuit (102), connected with the acoustic sensor, and an acoustic source connected with a pipe in the location near above the surface and spaced from the parameter resonator placed in the well. At the same time the acoustic sensor is made as capable of receiving the resonant acoustic signal, transmitted from the parameter resonator, the measurement circuit is arranged as capable of formation of an output signal of the technological parameter, corresponding to the technological parameter of the fluid medium, in response to the received resonant acoustic signal, and the acoustic source is arranged as capable of transmission of the acoustic signal into the well.
EFFECT: provision of measurement of well fluid medium properties in real-time mode both in process of drilling and in process of well operation.
20 cl, 6 dwg
FIELD: oil and gas industry.
SUBSTANCE: the method is realized in two stages. At the first stage to the lower horizontal producer a flow string is run in to the beginning of a slotted filter. A heat insulated filter is set in the upper horizontal injector above the slotted filter. In the upper horizontal injector temperature tests are made in the interval from the well head up to the packer. Steam is injected to the lower horizontal producer and temperature tests are made simultaneously in the upper horizontal injector. Upon completion of steam injection to the lower well the final temperature test is made in the upper well. At the second stage fresh water is injected to the upper horizontal injector and a heat insulated flow string is run in with a thermal packer and shank. The packer is set before the slotted filter and control temperature test is made in tubular annulus in the interval from the well head up to the packer. Steam is injected to the upper horizontal injector though the heat insulated flow string, through the packer and shank to the beginning of the slotted filter. At that, periodically, upon commencement of injection, temperature tests are made in tubular annulus in the interval from the well head up to the packer. Upon completion of steam injection the final temperature test is performed in the upper horizontal injector. When required, tests in the lower producer and operational procedures for the wells are interchanged.
EFFECT: improving authenticity of the obtained results during identification of intervals with cross flows behind the casing for wells operated in deposits of viscous and superviscous oil.
SUBSTANCE: proposed device comprises housing to accommodate the set of pressure and temperature gages, moisture metre and flow metre, electronics unit connected by logging cable, on one side, with surface control station and. On opposite side, with said gages, coupling unit with cable joint head and centring skid. Instrumentation module is secured at said housing by leverage, said module including inclination metre and extra gages, at least, moisture metre and flow metre connected with electronics unit. This module can reciprocate along the gravity vector between casing pipe and housing. It is located at casing pipe profile lower part by centring skid and coupling unit. It is equipped with housing turn drive and instrumentation module to turn them from gravity vector set by inclination metre via electronic unit.
EFFECT: registration borehole fluid interface boundaries and flow rate of every separate phase in conditionally horizontal wells.
4 cl, 3 dwg
FIELD: oil and gas industry.
SUBSTANCE: bubble-point pressure determination method includes measurement of bottomhole pressure at different oil production rates and registration of bottomhole pressure change curves upon returning the well to production in linear and nonlinear oil influx modes above or below bubble point pressure. At that wellhead pressure change curves and dynamic level changes in annular space are recorded additionally. By measurement results average density is calculated at each moment of time for the mixture column at annular space and the curve of average density changes in time at annular space is plotted. The free gas release is fixed when a gas separator releases it to the annular space. The value of bubble point pressure is determined by comparison of the mixture density change curve with pressure changes at pump suction at a certain period of time.
EFFECT: improvement of accuracy measurement of bubble point pressure.
1 tbl, 1 ex, 3 dwg
FIELD: oil and gas industry.
SUBSTANCE: invention is related to a method of well production optimisation. Intervals are selected in a deviated offshoot and drill-stem testing and borehole treatment is deployed. Then each interval is isolated in order to perform the required testing. The obtained testing data are evaluated in order to define respective recovery measures, which are implemented later by means of the drill-stem testing and borehole treatment.
EFFECT: provision of testing and treatment for the plenty of intervals in a horizontal hole during one running to the borehole.
11 cl, 6 dwg
FIELD: oil and gas industry.
SUBSTANCE: method lies in measurement of the maximum dynamic head depth for the known well-killing fluid with homogeneous density when bringing the well on to stable production after killing according to the following formula Pbthp=ρkf.·g·(Hperf-HDHmax), where ρkf - density of the well-killing fluid, kg/m3; g - acceleration of free fall, m/s2; Hperf - height of the upper perforated openings, m; HDHmax - maximum dynamic head depth in the well when bringing the well on to stable production after killing, m.
EFFECT: reducing downtime during well surveys, improving accuracy and reliability while determining the bottomhole pressure and simplifying of the bottomhole pressure measurement when bringing the well on to stable production after killing.
FIELD: oil and gas industry.
SUBSTANCE: monitoring method of inter-well parameters, at which by means of a laser radiation source there formed with the specified duration and frequency is a light pulse entering a fibre-optic cable where dissipation radiation is evolved through the cable length. Dissipation radiation entering a processing unit is converted to an electric signal and amplified. Then, a useful signal supplied to the input of the second controller is separated from it, where frequency of displacement of the useful signal relative to generation frequency of the laser radiation source is determined, and then, as per its value there calculated is a current value of pressure change parameter; the obtained data is compared to the those specified in the first controller, at deviation of which an oil recovery process is automatically controlled in compliance with the change of inflow, which is determined by continuous measurement of the well pressure change; electric motor shaft rotation frequency is controlled; when pressure change parameter value is lower than the specified value, the electric motor shaft rotation frequency is increased, and when the pressure change parameter value is higher than the specified value, then the electric motor shaft rotation frequency is decreased.
EFFECT: optimisation, automation and enhanced efficiency of an oil recovery process.
16 cl, 3 dwg
FIELD: oil and gas industry.
SUBSTANCE: well production rate is changed and temperature is measured during certain time period for fluid flowing to the well from each layer; temperature variation value ΔTP is measured for initial stage and steady-state value A of temperature-time logarithmic derivative is calculated for each layer. Specific yield value q for each layer is determined against the specified mathematical expression. Yield Q for each layer of the well is determined and influx profile is defined as totality of yields Q for all layers.
EFFECT: improving accuracy of well parameters determination.
FIELD: well boring, particularly for measuring pressure in well during drilling thereof.
SUBSTANCE: device has body with central flushing orifice and grooves. Arranged in the grooves are electrical circuits and positive pressure transducers isolated by pressure-resistant shell. The first pressure transducer is connected with central flushing orifice in tube, another one - with annular tube space. The device is provided with power source and two differential amplifiers with outputs connected to summing unit inputs. Supply diagonal units are linked correspondingly with power source inputs. The first units of measuring diagonals of the first and the second pressure transducers are connected correspondingly with inverting and non-inverting inputs of the first differential amplifier. The second units of measuring diagonals of the first and the second pressure transducers are linked correspondingly to inverting and non-inverting inputs of the second differential amplifier. The first and the second pressure transducers may be arranged in the body at 0°-45° and 153°-180° angles to vertical device axis correspondingly or may be inversely arranged. The body may be formed of titanic alloy.
EFFECT: increased measuring reliability.
4 cl, 2 dwg
FIELD: survey of boreholes or wells, particularly in borehole geophysical instrument requiring additional thermal stabilization.
SUBSTANCE: mounting with members to be thermostated is arranged inside heat absorbing device. Heat absorbing device is made as a set of heat absorbers, each of which is made as hollow heat-conductive cylinder filled with heat absorbing material. Heat insulator is formed as cylindrical heat-protective shell with outer and inner ring-shaped ribs and adapted for receiving heat absorbers. Heat-conductive mounting have heat absorbing plugs connected to ends thereof. Each heat-absorbing plug is made as hollow heat-conductive cylinder filled with heat absorbing material. Surfaces of heat-protective case, heat-protective cylindrical shell, heat absorbers and heat absorbing plugs facing thermostating members are covered with heat absorbing coating. Surfaces thereof facing borehole are covered with heat-reflecting coating.
EFFECT: increased duration of working thermostating cycle and simplified structure of thermostat.
6 cl, 2 dwg
FIELD: survey of boreholes or wells, particularly for tracing pressure distribution along well bore and for diagnosing various situations in well bore.
SUBSTANCE: method involves temporarily blocking part or full fluid flow by quick-acting valve gate along with continuously recording pressure in point spaced a small distance from the valve gate in upstream direction; determining friction losses with the use of Darcy-Weisbach equation; plotting diagram depicting pressure as a function of distance on the base of above time diagram and on the base of acoustic speed in real fluid with the use of the following relation: ΔL=0.5aΔt, which correlates time Δt with distance ΔL. To estimate acoustic speed in fluid one may use correlations which determine relation between hydraulic impact value, fluid pressure, fluid velocity and acoustic speed in the fluid and which are known from Joukowski formula. Acoustic speed also may be estimated on the base of time determination between pressure change peaks depicted on time diagram and caused by equipment, flow sectional area and other parts located along well bore, discharge line and pipeline in predetermined points. Acoustic speed may be determined on the base of changes in time diagrams in at least two different points along pipeline and by comparison of above time diagrams. Combined well temperature and pressure diagram may also be obtained, wherein above temperature distribution along well bore depth is measured with the use of optical fiber. Above method may be used to determine and localize influx points in well bore, discharge line and pipeline or to determine and localize losses from well. Method may also be used to determine and localize collapse of discharge lines or presence of deposits, namely hydrates, solid hydrocarbons, pyrobitumen or sand. Above method may be used to determine effective diameters of well bore, discharge line or pipeline in different sections thereof, or to determine which gas lift valves are in working state and to localize and determine working characteristic values of pipeline equipment utilized for oil and/or gas production.
EFFECT: increased efficiency of well survey.
12 cl, 11 dwg, 2 ex