Method for periodic operation of oil well with submersible pump set with controllable electric drive

FIELD: oil and gas industry.

SUBSTANCE: according to the method fluid pumping from the well is alternated with fluid accumulation in the well at switched off pump set and average delivery in time is controlled for the purpose of matching with the well flow rate by changing speed rate of the pump shaft. Pump capacity in pumping process is controlled by a submersible flow rate meter placed at the pump output. Pumping out will be performed till the pump reaches the preset minimum pressure at suction and accumulation will be performed till the pump reaches the preset maximum pressure. Pressure value is controlled by means of a submersible pressure sensor. Frequency of the pump shaft rotation during pumping period is changed on the basis of readings of the submersible flow rate meter so that maximum value of efficiency factor is reached for the pump during pumping period. Time of accumulation is limited by regulations on motionless fluid in surface equipment in winter time by permitted decrease of oil temperature in the submersible electric motor and permitted frequency of stops and starts of the latter. Maximum pressure value for the cemented stratum is selected on condition of maximum oil production and for the stratum destructed intensely in extraction process on conditions of minimum discharge of mechanic impurities.

EFFECT: increased production and maintained reliability for submersible equipment due to its operation in the mode of maximum efficiency factor.

 

The invention relates to mechanized production fluids from oil wells and can be used to optimize the technology of well operation, the flow rate of which is less than the minimum permissible supply electrical submersible pump (ESP).

The known method of periodic operation of installing wells with electric submersible pump (ESP) with non-adjustable electric drive [Bogdanov A. A. Submersible centrifugal pumps for oil production. - M.: Nedra, 1968. P. 225], according to which the pumping fluid from wells alternating with accumulation of fluid in the well off the installation.

The disadvantage of this method is the lack of criteria for selecting periods of pumping and fluid accumulation, which leads to the work of the ESP out of range and loss of oil produced compared to continuous operation.

The known method of periodic operation of marginal producing wells ESP with adjustable electric drive, consisting in the alternation of pumping fluid from the well and fluid accumulation in the well ESP when running on low speed, to prevent draining of fluid from the pump-compressor pipes (tubing) [RF Patent №2119578, CL E21B 43/00, publ. 27.09.1998].

The disadvantages of this method are: never operate the pump out of range and poor conditions in the OHL�the frame of the motor during accumulation of fluid in the well. This leads to a high specific energy consumption, overheating, electrical insulation and premature failure, reducing the turnaround time of equipment operation.

The closest analogue, taken as a prototype of the invention is a method of periodic operation of an oil well submersible centrifugal pump unit with adjustable actuator, according to which the pumping fluid alternate with accumulation of fluid in the well off when you install and adjust the average integral time supply installation to be consistent with the well production [RF Patent №2293176, CL E21B 43/00, publ. 10.02.2007]. With the change of the ratio of the duration of pumping fluid from the well and the duration of accumulation of fluid in the well. In the process of pumping fluid from a well, the pump speed variable, it picked such that pump efficiency over the entire range of regulation was not less than 0.9 of the maximum value of the efficiency (use the readings of the pressure sensors and the flow meter installed at the wellhead). The duration of pumping-accumulation is chosen so that the decrease in yield compared to continuous operation was not more than 5%.

The main disadvantage of this method is the use of sensors at the wellhead for about�for determining the operation mode of ESP. Currently, there are no exact methods for such calculations are generally used approximate empirical methods, the actual mode of operation of ESP is estimated with large errors, thus failing to achieve the stated values of the efficiency of the installation.

The object of the invention is an operational mode intermittent operation even under varying parameters of the well, allowing to increase production and also to maintain the reliability of submersible equipment at the expense of its operation at maximum efficiency.

To achieve this goal we propose a method for the periodic operation of the well ESP with adjustable actuator, wherein pumping fluid from wells alternating with accumulation of fluid in the borehole when the installation, changing the speed of the shaft to regulate the average in time supply installation for the purpose of its harmonization with the flow rate of the well, characterized in that the pump in the pumping process using control located at the output of submersible flow meter, pumping before reaching the pump intake specified minimum pressure, and the accumulation - up to the maximum pressure, the control pressure value is carried out using a submersible pressure transducer, the shaft speed of the pump during the period�and pumping change based on the testimony of submersible flow meter so to ensure maximum efficiency of the pump during pumping, the accumulation time limit in the rules of the finding of fluid without movement of the rebar in the ground in the cold season, the allowable temperature drop of the oil in the submersible motor and the permissible frequency of stops and starts last.

The value of the maximum pressure selected from the conditions of maximum production, if the cemented layer, or at least the removal of mechanical impurities, if the formation is heavily destroyed in the mining process.

The method is implemented as follows.

In submersible pump installation place the pressure sensor at the pump intake, and at the output - submersible flow meter that is connected to the ground control stations for the transmission of actual data.

A reference value for the start of the periodic mode of operation of wells with ESP is the minimum pressure at the pump intake Pminallowed value which is governed by the terms of oil and is determined by the minimum allowable height of the liquid column in the well.

The second parameter is the maximum pressure at the pump intake Pmax. Due to the fact that the dependence of the average well yield (q) of the difference Pmax-Pminmonotonous, without extremes - the smaller the difference, the higher the depression on the layer and left during� the well yield, then Pmaxmay not be an optimization parameter in this algorithm is selected and operating conditions subject to the following requirements:

- the accumulation time (tNACfluid in the well when the pump is switched off, during which the inlet pressure to the pump is changed from Pminto Pmaxmust not be greater than the maximum time during which the liquid can exist without movement rebar in the ground in the cold season (as determined by the regulations of the oil company);

for time tNACthe temperature of the oil in the pad should not be lowered so that when the launch pad was the release of oil from hydronamic;

- the smaller the difference of Pminand Pmaxthe more often there will be stops and starts of the pad, which reduces the reliability in the case, ESP if not equipped with soft starters.

The cycle starts with pumping fluid from wells with ESP enabled at the operating frequency (e.g. 50 Hz). Submersible pressure sensor performs measurements of the pressure at the pump intake. Pumping continues until the Pminthen turn off the ESP.

When the installation of the well begins to fill with liquid, the process of accumulation. In the process of accumulation by submerged sensor measured pressure at the pump intake and is controlled by the time�I accumulation. Once maximum pressure is reached at the reception or the maximum permissible period of accumulation begins pumping fluid.

The frequency of rotation of the pump shaft (f(t) is selected so that at any time t the current value of the flow Q(t), measured submersible flow meter that was optimal, i.e., the pump would work at maximum efficiency. The value of f(t) is calculated according to the formula of the similarity theory for centrifugal pumps:

where the reference frequency f0selects the operating frequency of the pump (typically 50 Hz), Qopt(f0- the flow corresponding to the maximum efficiency at reference frequency f0(when the pump is in fluid of the same viscosity as that of the borehole fluid).

If the reservoir rock is poorly cemented, and oil production is accompanied by the removal of mechanical impurities, the selection criterion of Pmaxwill not the maximum production and the minimum of the removal of mechanical impurities, which is known to be achieved in the context of quasistationarity production when the average well production rate q constant:

The condition q=const is provided by the variation of tNAC(i.e., Pmax) since tOTCuniquely specified conditions pumping - the pump operates at supply corresponding to the maximum efficiency.

Thus there is a periodic mode cost of ownership�and wells alternating periods of pumping fluid from a well with pumping plant and the accumulation of fluid when the pump is switched off, such that on the testimony of a submersible pressure sensors at the inlet to the pump is the optimal timing of accumulation of fluid in the borehole, providing for the extraction from the reservoir at maximum depression (if the cemented layer) and with minimal removal of mechanical impurities (if the formation is heavily destroyed in the mining process), and using a submersible flow sensor is instantaneous adjustment of frequency of rotation of the pump shaft, providing operation of the pumping unit in the optimum efficiency at any point of time during the pumping period.

Method periodic operation of an oil well submersible pump unit with adjustable electric drive, wherein pumping fluid from wells alternating with accumulation of fluid in the well off when you install and adjust the average time the flow of installation to align with the flow rate of the well by changing the rotational speed of the pump shaft, characterized in that the pump in the pumping process using control located at the output of submersible flow meter, pumping before reaching the pump intake specified minimum pressure, and the accumulation - up to achieve max�pressure, in this case, the control pressure value is carried out using a submersible pressure transducer, the shaft speed of the pump during the pumping period is changed based on the testimony of submersible flow meter in such a way as to ensure maximum efficiency of the pump during pumping, the accumulation time limit in the rules of the finding of fluid without movement of the rebar in the ground in the cold season, the allowable temperature drop of the oil in the submersible motor and the permissible frequency of stops and starts last, the value of maximum pressure for the cemented layer is selected from the conditions of maximum production, and reservoir, rapidly disintegrating in the process of production, - the minimum of the removal of mechanical impurities.



 

Same patents:

FIELD: measurement equipment.

SUBSTANCE: invention relates to the field of instruments moving in shafts of wells, drilled via underground beds of mountain rocks. A well measurement instrument comprising a jacket made as capable of displacement inside the well shaft, at least one sensor made as capable of measurement of the well shaft parameter, a controller installed in the jacket comprising at least one of the following: a data saving device and an operation control device, at least for one sensor, and the first port of optic connection installed in the first opening in the jacket, besides, the first port of optic connection includes a light source controlled with the help of electricity, besides, the first hole in the jacket tightly closed by the port plug having an optically transparent window, besides, the port plug is made as capable of resisting the inlet of fluid medium of the well inside the jacket, and the second port of optic connection installed in the second opening in the jacket, besides, the second port of optic connection includes a photodetector, besides, the second opening in the jacket is tightly closed with the port plug, having an optically transparent window, besides, the port plug is made as capable of resisting inlet of fluid medium of the well inside the jacket.

EFFECT: transmission of data on working condition of an instrument and/or data saved in the instrument, and/or transmission of control signals and working instructions to such instruments during location of instruments on earth surface.

13 cl, 5 dwg

FIELD: oil and gas industry.

SUBSTANCE: invention relates to oil and gas industry, namely to method of tightness testing of the cased injection well. Methods includes: determination of actual pressure difference on the packer ΔCp_a=Pwh1-Pfr-Cwh2+Cfr2-Perr1-Perr2, where Pwh1 and Pwh2 are measured wellhed pressure on injection to top and bottom reservoirs, respectively, Cfr1 and Pfr2 are pressure losses for friction during water movement via short and long strings. respectively, Perr1 and Perr2 are absolute errors of measurements by technical pressure gauge in short and long strings, respectively, atm. At that criterion of the tightness estimation is the pre-specified critical pressure difference ΔCd_cr. System tightness is estimated by comparison of the actual pressure difference on packer ΔCp_a and pre-specified critical pressure difference at |ΔCp_a|>|ΔCd_cr| the system is tight. Method of the tightness testing of the injection well contains stages at which: pressure change is registered in well blocked by the packer, by wellhead pressure measuring at input to tubing string in top and bottom reservoirs, respectively. Data analysis is performed, and tightness is determined. At that preliminary current water flowrate via pipeline is measured Q. Tightness is estimated if the following condition is met: ΔCw_cΔCw_a(QcQa)2, where ΔCw_c and Qc are measured current wellhead pressure difference and current water flowrate, respectively; ΔPw_a and Qa are actual measured current wellhead pressure difference and current water flowrate, respectively. If the condition is met the well is tight.

EFFECT: decreased number of tightness tests in wells operated under process of simultaneous-separate injection.

16 cl, 2 tbl, 2 dwg

FIELD: mining.

SUBSTANCE: electronic probe is offered which contains a metal power supply compartment 1 and a plastic housing 2 conjugate to it where a measurement unit 3, and also a signal processing unit 4 designed as a microcontroller unit, and a magnetic antenna 5, which are filled with a moisture resistant compound. The measurement unit 3 comprises a tilt sensor 6 of longitudinal axis with reference to the horizon, a roll sensor 7 and a pulse stabiliser 8. The plastic housing 2 is made of multilayered fibreglass the inner layers of which are made of vitreous fibres with longitudinal and orthogonal orientation in the housing structure, and external layers are made of vitreous fibres with diagonal orientation. The magnetic antenna 5 and the measurement unit 3 have multilayered high-adhesive moisture resistant coating 11, and the microcontroller unit 4 - the coating 12 of varnish with low adhesive ability to the moisture resistant coating of the measurement unit 3 and the magnetic antenna 5, and they are filled during assembly with the moisture resistant compound 13.

EFFECT: improvement of the probe reliability due to strengthening of the housing and reliable sealing of the main electronic units.

3 cl, 3 dwg

FIELD: oil and gas industry.

SUBSTANCE: stopped well is chosen; its flushing is performed, and with that, temperature at the circulation system outlet is recorded. With that, pumping of hot liquid (heat carrier) is performed through annular space, with that, at its inlet the liquid temperature varies as per a periodic law and is recorded, and heat conductivity coefficient λ"п" and coefficients of heat transfer through tubing strings k1 and casing string k2 are calculated as per mathematical formulas.

EFFECT: improving measurement accuracy of an average integral value of heat conductivity of mine rocks as to a well log and determining coefficients of heat transfer through the tubing strings and through the casing string, length of the circulation system of the well.

FIELD: measurement equipment.

SUBSTANCE: invention relates to well measurement devices, used to measure electromagnetic properties of a well shaft. A well measurement instrument is proposed, which includes at least one non-flat antenna configured to transmit and/or receive electromagnetic radiation. At the same time the non-flat antenna includes at least one non-flat loop of an antenna wire turned around the instrument body. Besides, in one version of realisation the non-flat antenna may be considered double-planar, including the first and second sections of semi-elliptical shape, forming the first and second crossing geometric planes. In the other version of realisation axial separation between the non-flat loop of the antenna wire and the central line of the antenna passing along the circumference changes substantially in a sinusoid manner relative to the azimuthal angle along the circumference of the instrument. The sample non-flat antenna according to the invention may be preferably made as capable of receiving and transmitting radiation substantially of purely x-, y- and z-mode.

EFFECT: provision of directional action of an antenna with the possibility to receive signals from different sides.

15 cl, 13 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: invention relates to production of hydrocarbon raw materials from the productive formation drilled by a well and relates, in particular, to non-radioactive indicators and methods of their use for tracking of movement of treating liquid and formation fluids. The method of the treating liquid movement tracking in the productive formation drilled by a well comprising: preparation of the treating liquid containing multiple indicator additives representing drops of high-viscosity liquid with the diameter no more than 1000 nanometres; pumping the treating liquid with multiple indicator additives into the borehole and productive formation; determination of position and distribution of the treating liquid by registration of changes in the physical properties of the formation caused by inflow of the treating liquid with multiple indicator additives.

EFFECT: improvement of accuracy of determination of position and distribution of the treating liquid by registration of changes in the physical properties of the formation caused by inflow of the treating liquid with multiple indicator additives.

18 cl

FIELD: oil and gas industry.

SUBSTANCE: method provides for use of the production wells. One or several wells are equipped with pump unit with possibility of discharge change. For each production well the deposit or deposits used for production are known. At wellhead of each production well the produced crude oil and oil gas are measured, as well as crude oil watercut is determined. The product wells product is delivered to the gathering header of the wells cluster. The cluster contains one or more injection wells. For each injection well the deposit or deposits used for injection are known. Injectability of the injected water and required injection pressure are determined. Compatibility of the injected water and produced water is studied. Injection is performed upon compatibility of the injected and produced waters. Coordinates of all production and injection wells of the cluster using the same deposits are determined. For each production well time of the produced product lifting is determined from suction of the pump unit to wellhead at maximum discharge. Volume of produced crude oil and oil gas is measured with interval not exceeding half of measured time of fluid lifting for the given well. At wellhead of each well the injected water pressure and its volume are measured. Injected water volume and wellhead pressure are measured with interval not exceeding half of measured time of water supply to the wellhead of each injection well before parker. For each injection well the curve of injected water pressure and volume vs. time is plotted. For each production well using the plotted volume of produced crude oil and oil gas vs. time the relationship with the injected water volume and wellhead pressure is determined, as well as distances to each injection well ensuring injection to the same deposit. For the production wells equipped with pump units with possibility of discharge change such relationships are determined at different discharge. The wells cluster is controlled based on the obtained relationships for all production wells. At that the treated water supply system for injection is made with possibility to change water volume and wellhead pressure for one or more injection wells.

EFFECT: increased efficiency of clusters well control.

2 cl, 1 dwg

FIELD: measurement equipment.

SUBSTANCE: invention relates to monitoring and inspection of quality or level of cementation in a well. The method is proposed to determine type of material in a cavity between an inner metal wall and an outer metal wall, where the following sequence of actions is realised. at first at the inner side of the inner metal wall they install an instrument, which comprises a pulse generator and a signal recorder; then by means of the pulse generator they generate electromagnetic pulses of low duration, which cause mechanical vibrations in walls; data characterising reflections of these mechanical vibrations from the cavity created between the specified walls is recorded by means of the signal recorder; recorded data is analysed to determine type of material in the cavity. Also the device is proposed for realisation of this method.

EFFECT: increased accuracy and information value of measurements, which will make it possible for an operator to predict functional service life of a well and guarantee integrity of its structure.

16 cl, 6 dwg

FIELD: measurement equipment.

SUBSTANCE: invention relates to drilling equipment, namely, to devices of sensor switching, which measure drilling parameters directly in process of drilling within a telemetering system. The device comprises a body and contact elements, is located inside a drilling pipe and made in the form of a jet element, including a supply balloon with compressed gas, a jet unit of command signal generation, jet triggers with a count input, jet units of inverters, jet logical elements "AND" and "OR" and a jet unit of output signal generation, besides, the output of the jet unit of command signal generation is connected with the input of jet triggers, outputs of which are connected with inputs of the jet unit of inverters, and outputs of inverters are connected with inputs of jet logical elements "AND" connected to outlets of bottomhole sensors, outputs of elements "AND" are connected with inputs of the logical element "OR", the output of which is connected to the input of the jet unit of output signal generation.

EFFECT: increased reliability of bottomhole sensor switching within a telemetering system.

1 dwg

FIELD: physics, geophysics.

SUBSTANCE: invention relates to nuclear geophysics and is used for estimation of cement stone density of buried gas storages in their operation without lifting of oil-well tubing. Claimed method comprises measurement of current magnitudes A as Ca/Si ratio in wells by devices of wide-band spectrometric neutron gamma-logging, selection of Amin and Amax of Ca/Si) ratio, and determination of double difference parameter from measurement results (DDP(Ca/Si)) by formula DDP(Ca/Si)=AAminAmaxAit. Spectrometer calibration is performed by static method based on interrelations between double difference parameter (DDP(Ca/Si)) and magnitudes of density boundaries of normal cement stone selected from the condition: maximum magnitude 1 of DDPCa/Si corresponds to density of cement stone - 1.95 g/cm3 - upper boundary of normal cement stone density, mean magnitude of 0.57 DDPCa/Si corresponds to current density of cement stone - 1.65 g/cm3 - lower boundary of cement stone density. Density of gamma-radiation (γsngl) is calculated by the formula: γsngl=1.25+0.7 DDPCa/Si.

EFFECT: higher accuracy of data.

3 dwg

FIELD: physics.

SUBSTANCE: methods and systems for gathering, deriving and displaying the azimuthal brittleness index of a borehole are disclosed. Certain embodiments include various methods for calculating and displaying borehole measurements in real-time for geosteering and drilling operations. One embodiment of the disclosed method for calculating and displaying azimuthal brittleness includes a step of taking measurements of compressional and shear wave velocities as a function of position and orientation from inside the borehole. These velocity measurements are taken by an azimuthal acoustic device. Azimuthal brittleness is then derived based on the compressional and shear wave velocities.

EFFECT: high reliability of data of planning geological survey operations.

19 cl, 6 dwg

FIELD: oil and gas industry.

SUBSTANCE: method includes cyclic forced gas pumping from the annulus and pressure decreasing in it. Periodically the well flow header is partially closed. Pressure upstream the shutdown element of the header is increased to ensure the produced fluid supply to the expansion chamber of the tank with resilient element and to accumulate mechanical energy in the expansion chamber. Then full opening of the header shutdown element is performed. Pressure upstream the shutdown element is decreased, and fluid is displaced from the expansion chamber to the header due to the accumulated mechanical energy. Each cyclic volume increasing of part of the tank above the expansion chamber ensures annulus gas suction in it, and this volume decreasing ensures gas displacement to the header.

EFFECT: possibility of gas pumping from the annulus in tubing string of the well for different methods of mechanised oil production.

1 dwg

FIELD: oil and gas industry.

SUBSTANCE: group of inventions is related to oil production industry, in particular, to secondary and tertiary methods of enhanced oil recovery for beds with low oil saturation that envisage use of equipment for production of gaseous nitrogen with high pressure and temperature. Nitrogen compressor plant comprises a multistage piston-type compressor with a power drive unit made as diesel engine, and gas-separating unit. Output of the compressor intermediate stage is coupled to input of gas-separating unit. Output of gas-separating unit is coupled to input of the compressor stage, which follows the intermediate stage. At that nitrogen compressor plant includes heat exchanger, which working medium input is coupled to the compressor output. Input of the compressor heat exchanger is coupled to exhaust output of diesel engine. Gas-separating unit is made as a hollow-fibre membrane unit. Output of the heat exchanger working medium is coupled to input of additional heater. At that output of the additional heater serves as output of the station.

EFFECT: development of more effective means for oil extraction from low-permeable collectors complicated by high paraffin content.

8 cl, 4 dwg

FIELD: oil and gas industry.

SUBSTANCE: device comprises a pipe string run in to the well, a packer with a flow shutoff mounted in it. The packer is made as a hollow body with the upper row of openings placed above the sealing element in the packer. Inside the hollow body there is a pipe concentric to its axis and fixed rigidly to the pipe string from top and to the piston from bellow. The pipe with piston may be moved axially in regard to the hollow case of the flow shutoff. In the hollow body below the sealing element of the packer there is the lower row of openings. The piston is made hollow and plugged from below. Opposite the upper and lower rows of openings in the hollow body the piston is equipped with inner cylindrical sample capture and a row of feedthrough openings. In the hollow body above the upper row of radial openings there is a cam slot in the form of longitudinal groove and three transversal grooves. The transversal grooves are made from the upper, medium and lower parts of the lower part of the longitudinal grove. In cam slot of the hollow body there is a guide pin installed so that it may be moved axially and transversally. It is fixed rigidly in the piston above its upper inner circular sample capture. When the guide pin is placed in the transversal groove made of the medium part of the longitudinal groove, the device is designed to connect inner space of the pipe through a row of feedthrough openings of the piston, inner cylindrical sample capture, the upper and lower rows of openings with over-packer and below-packer space of the well. When the guide pin is placed in the transversal groove made of the upper part of the longitudinal groove, the device is designed to connect inner space of the pipe through a row of feedthrough openings of the piston, inner cylindrical sample capture, the upper row of openings with over-packer space of the well. The lower row of openings in the hollow body is sealed in tight-proof way by the piston. When the guide pin is placed in the transversal groove made of the lower part of the longitudinal groove, the device is designed to connect inner space of the pipe through a row of feedthrough openings of the piston, inner cylindrical sample capture, the lower row of openings with below-packer space of the well. At that the upper row of openings in the hollow body is sealed in tight-proof way by the piston.

EFFECT: simplified design of the device, improved reliability of its operation and expanded functionality.

3 dwg

FIELD: oil and gas industry.

SUBSTANCE: invention is related to oil and gas producing industry and can be used for annular gas bypassing to the flow string in wells operated by sucker-rod pump units. Task of the invention is to perfect design of the downhole device for annular gas bypassing in order to improve operational efficiency of the well sucker-rod pumping equipment notwithstanding temperature conditions of the well operation and pressure of annular gas. The device is placed in the well annular space over the well fluid level in the flow string collar. The device comprises a return valve and a radial hydraulic channel. In the collar lower part there is a radial hydraulic channel interconnected to the well annular space at the one side through the return valve and to the flow string cavity at the other side through a jet device. At that axes of the radial hydraulic channel and the jet device are crossed in the nozzle area of the latter. Besides the device comprises a flow string with a whipstock for gas-fluid flow in it. The whipstock is made as a bushing capable to be fixed in the flow string collar. Length of the whipstock for gas-fluid flow is less than distance between receipt and discharge of the jet device. Axes of the radial hydraulic channel and the jet device are perpendicular. Fixation of the whipstock for gas-liquid flow in the flow string collar may be implemented by equipping the flow string collar with an inner groove and the whipstock for gas-liquid flow with a ring holder.

EFFECT: usage of device allows reducing pressure of annular gas notwithstanding temperature and pressure conditions thus increasing life between overhauls for the sucker-rod pumping equipment; besides, this device allows reducing pump-setting depth for the sucker-rod pump due to increase of fluid level over the pump thus reducing consumption of the flow string and pump rods and increasing life between overhauls for the units.

3 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: according to the method the hydraulic fracturing of formation is performed. After hydraulic fracturing of the formation in the well the proppant underflash is left. From above in addition from the coarse fraction proppant the bridge with a rated length is created. This length is selected in view of the condition of providing of counter-pressure on the proppant in the hydraulic fracturing crack sufficient for holding of proppant in a hydraulic fracturing crack at decrease of liquid level in the well down to the well bottomhole level. The package of downhole pumping equipment includes the antisand filter. During the well operation the antisand filter is placed directly over the proppant bridge. The liquid is sampled. The liquid level during liquid sampling - operation is maintained at the level of the deep-well pump.

EFFECT: increase in oil production.

1 ex

FIELD: oil and gas industry.

SUBSTANCE: as per the method, continuous lowering of a flexible pipe is performed into an internal cavity of tubing string to the well bottom. Gas is supplied to the well annular space. At the same time, gas is supplied to the space between the flexible pipe and the tubing string directly from the pipeline of the same well. Killing liquid is removed to day surface via the flexible pipe. Gas is supplied when the flexible pipe achieves killing liquid level. The flexible pipe is lowered at the specified speed from killing liquid level to the well bottom. Flexible pipe lowering speed and minimum required gas consumption providing killing liquid removal to day surface is determined as per an analytical expression.

EFFECT: improving efficiency of removal of killing liquid from a gas well due to continuous removal of liquid, reduction of gas consumption and power consumption.

1 ex, 1 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: set of invention can be used, primarily, at development of remote oil deposits under extreme climatic conditions. Proposed process comprises recovery of associated oil has (AOG) at locations of oil separation via multistage low-temperature separation of AOG to stripped gas (SG) and dry gas condensate of AOG. This process involves separate delivery of DSG and AOG gas condensate via pipeline to the points of their accumulation, treatment and application. Note here that they are delivered via pipes to mid stations of their accumulation, treatment and partial application. These stations are located at distances not exceeding several tens of kilometres from oil fields. SG is liquefied at mid stations to produce liquefied natural gas for supply to local consumers. AOG gas condensate is subjected to deeper drying and cleaning of sulphur and other harmful impurities. LNG and dry AOG gas condensate produced at mid stations are accumulated in separate storage tanks. These products are carried by, mainly, regional line aircraft fuel carriers to regional refineries. Said refineries produce automotive propane-butane fuel and aircraft condensed fuel for local consumers as well as stock for consumers of petrochemical products as wide fraction of light hydrocarbons. The latter are delivered to other regions by, for example, medium-range tanker aircraft.

EFFECT: higher efficiency owing to almost full recovery and application of associate oil gas.

2 cl, 3 dwg

FIELD: oil and gas industry.

SUBSTANCE: according to the method a geologic structure is identified within the area of a deposit. Potential reservoir beds are identified in the section of rocks above the deposit, the direction of their highs - uprising and three-axis orientation of systems of subvertical fracturing is identified. Development and inspection wells are constructed with opening of the reservoir beds above the deposit height. Pressure and temperature survey is performed in the development wells and the composition of formation fluids is identified for all the wells. According to the results of the survey data depressurisation of the deposit is recorded. The inspection wells are constructed close to the wells intended for monitoring of sealing at the borehole annulus and the deposit in the direction of the subvertical fractures and uprising of the potential reservoir beds above the deposit. A change in pressure and temperature is identified for depth intervals of the reservoir beds on the real time basis.

EFFECT: reduced time for the detection of potential cross-flows of hydrocarbons to the above reservoir beds in result of the pressure failure in its cover and the borehole annulus of the wells in order to take measures on its elimination and prevention of potential blowouts to the surface.

1 dwg, 1 ex

FIELD: oil and gas industry.

SUBSTANCE: invention suggests hydraulic pump smart device for oil production and acquisition and storage of data from the well bottom that comprises jet pump unit, the lower isolation valve and unit with electronic instruments, which form a united and integrated unit actuated by operating fluid injected to the well from the ground oil lifting, closure of the well bottom, recovery of pressure in the formation and lifting of the device to the surface. The invention also discloses the method for oil production, receipt and recording of data from the well bottom using the above device.

EFFECT: performance of one complex function consisting in lifting of fluid and recording of data from the well bottom by means of temporary closure of the well.

17 cl, 11 dwg

FIELD: oil extractive industry.

SUBSTANCE: method includes lowering a tail piece into well with temperature, electric conductivity and pressure sensors placed on tail piece along its length. Pressure sensors are used in amount no less than three and placed at fixed distances from each other. After that, continuously during whole duration of well operation between maintenance procedures, temperature, conductivity of well fluid, absolute value of face pressure and difference of pressures along depth of well in area of productive bed are recorded. Different combinations of pairs of pressure sensors are used for determining special and average values of well fluid density. When absolute pit-face pressure is lower then saturation pressure for well fluid by gas and/or when average values of density deviate from well fluid preset limits and/or when its conductivity deviates from preset limits, adjustment of well operation mode is performed.

EFFECT: higher efficiency, higher safety.

2 cl

Up!