WO2015163781A1 - Procédé pour surveiller les paramètres d'un puits de forage de pétrole et de gaz en activité - Google Patents

Procédé pour surveiller les paramètres d'un puits de forage de pétrole et de gaz en activité Download PDF

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Publication number
WO2015163781A1
WO2015163781A1 PCT/RU2014/000300 RU2014000300W WO2015163781A1 WO 2015163781 A1 WO2015163781 A1 WO 2015163781A1 RU 2014000300 W RU2014000300 W RU 2014000300W WO 2015163781 A1 WO2015163781 A1 WO 2015163781A1
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well
frequency
profile
fluid
placement
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PCT/RU2014/000300
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English (en)
Russian (ru)
Inventor
Константин Викторович ТОРОПЕЦКИЙ
Виктор Николаевич ЕРЕМИН
Александр Николаевич ЧЕРЕМИСИН
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УЛЬЯНОВ, Владимир Николаевич
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Priority to PCT/RU2014/000300 priority Critical patent/WO2015163781A1/fr
Priority to EA201501084A priority patent/EA201501084A1/ru
Publication of WO2015163781A1 publication Critical patent/WO2015163781A1/fr

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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • E21B47/07—Temperature

Definitions

  • the invention relates to the field of oil production, in particular, to geophysical studies of oil and gas wells, and can be used to determine in real time the profile of the inflow for producers and the injectivity profile for injection wells, as well as to assess the technical condition of the production string wells, namely, for detecting annular flows, above and below the perforation interval.
  • Geophysical studies of wells including the construction of inflow profiles for operating and inflow profiles for injection wells, the determination of casing flows, as a rule, are carried out by means of a whole range of measures, including shutting down the well, extracting the assembly and then lowering the geophysical instrument and stretching it along the studied well intervals.
  • a preliminary study of the bottom of the well is required, and after its shutdown, the creation of an artificial flow.
  • artificially induced inflow does not exactly reproduce the situation of a working well.
  • such well surveys are a time-consuming process, associated with long well downtime, the risk of losing productive parameters of the well, as well as with dangerous " production processes.
  • a known method of researching productive intervals in wells with electric centrifugal pumps including the descent of a deep geophysical instrument to the bottom and its extension along productive intervals with simultaneous measurement parameters, and in order to increase the efficiency of research by providing the possibility of removing the device from the well, before the descent of the well pump into the zone of productive intervals, a flow guide apparatus is installed, and pulling the device and carried inside struenapravlyayuschego apparatus.
  • the advantage of this method is the ability to study the well without stopping directly during operation and without removing the layout. Moreover, this method allows you to measure the distributed parameters in the well table, thereby constructing a flow chart and assessing the technical condition of the casing string.
  • the disadvantages of this method include the need for a hoisting operation with a downhole tool, as well as the need for a special layout design. Moreover, this arrangement design limits the diameter of the borehole pump and the pressure developed by it, which makes it impossible to use in a number of wells with abnormally low reservoir pressure. In addition, the introduction of a geophysical cable through a lubricator at the wellhead entails certain risks of depressurization of the well.
  • a known acoustic method for identifying the location of annular fluid flows (see patent RU2462592, class E21 B47 / 10, E21 B47 / 14, 2012), including the descent and rise in the well of the receiver of acoustic signals.
  • This records on the rise curves of changes in the intensity of the noise signal taken from the output of the receiver, followed by signal processing in the secondary equipment.
  • the rise of the downhole receiver of noise signals is carried out at a constant known speed.
  • the receiver is performed with a sharply directed directional characteristic to the orthogonal axis of the well. Processing of the output signal is carried out by extracting from the registered noise signal the characteristics of the receiver passage relative to the location of the annular fluid flow for a given speed.
  • the advantage of this method is the reliable identification and localization of annular cross-flow areas on the casing, since the well is stopped, and the flow of fluid in the leakage region is reliably recorded by the acoustic method.
  • the disadvantages of this method include the necessity of shutting down the well and removing the layout for research. Also, this method does not allow determining the inflow profile.
  • a known method of controlling the depth parameters during the operation of the well including the descent into the well of a chain of geophysical measuring modules, sequentially interconnected by means of pipe sections, the upper of which is connected - is single through the transitional perforated chamber to the bottom of the riser for the production of the well, and the number of modules is equal to p-1, where n is the number of productive strata of the well.
  • the entire structure is driven by a winch through a lubricator at the wellhead.
  • the advantage of this method is the ability to measure distributed geological and technological parameters in the intervals of perforation of productive strata of a well directly during operation and without stopping it.
  • the disadvantages of this method include the need to introduce a movable geophysical cable through the lubricator at the mouth, which is associated with the risks of depressurization.
  • GIS geophysical well research
  • the advantage of this method is the ability to measure the distributed geological and technological parameters of the well without the need to extend the measuring device along the studied interval. In addition, for the period of the study does not require shutting down the well and removing the layout. This greatly simplifies and speeds up well exploration, and allows real-time construction of thermograms and a noise profile.
  • the optical fiber does not require power supply and is insensitive to various kinds of interference, since it does not contain electrical circuits.
  • the disadvantages of this method include the need to use an expensive multimode optical fiber, which must be extended over the entire length of the well from the wellhead to the sump, including both the observation interval and low-informative sections.
  • the low spatial resolution and “point to point” measurement accuracy cast doubt on the value of this method as a tool for determining the inflow profile from a thermogram.
  • the use of optical fiber is impossible due to the design features of well layout, such as mechanized wells with a submersible pump.
  • the advantage of this method is the ability to measure local geological and technical characteristics of the well in the field of placement of well logging tools in real time using a cable line to transmit data to the surface. These measurements make it possible to solve a number of geological and technological problems, such as selecting the optimal operating mode of the downhole equipment and determining the filtration characteristics of the formation and the bottomhole zone of the well (CCD) using hydrodynamic research (well test), in particular, such as the pressure recovery curve (HP) .
  • the disadvantage of this method is the measurement of physical parameters only at fixed points in the well, which does not allow determining the inflow profile or assessing the technical condition of the casing and annulus.
  • the objective of the present invention is to remedy this drawback, namely, expanding the functionality of the proposed method by real-time monitoring of well parameters, which allows, in addition to selecting the optimal operating mode of the well equipment and determining the filtration characteristics of the formation and CCD, to build an inflow profile and / or component composition in the perforation interval for producing wells; to build injectivity profiles in the perforation interval for injection wells; identify areas of casing leakage and / or annular flows outside the perforation interval; identify areas of narrowing of the cross section due to solid deposits.
  • the indicated problem in a method for monitoring the parameters of an operating oil and gas well including measuring its physical characteristics using geophysical instruments lowered into the well and calculating the geological and technological parameters of the well from them, is solved by the fact that they are produced in real time at locally selected points and / or along selected sections of the well from measuring the physical characteristics of the well, while the physical temperature of the well selects the temperature of the fluid and / or flow rate and / or pressure of the fluid and / or acoustic noise characteristics of the well and / or the composition of the fluid.
  • the inventive method allows, in addition to selecting the optimal operating mode of the well equipment and determining the filtration characteristics of the formation and CCD, without additionally stopping the existing well, and / or extracting the layout and / or carrying out hoisting operations, it is decided tasks for:
  • the frequency of placement of temperature sensors can be increased compared to areas outside the perforation interval.
  • thermodynamic model of the well which includes the thermophysical properties of the fluid and the section rocks of the well (geological model data). This allows one to interpret the temperature distribution in terms of the inflow or absorption in a unit interval.
  • thermo-profile is supplemented with measurements of the component composition (specific moisture content and / or specific gas content) at least at one point upstream, it will become possible to recognize the nature of the change in the inflow profile and even localize the area of water and / or gas breakthrough. .
  • thermodynamic model The absence of information on the thermophysical properties of section rocks in the geological model of the section casts doubt on the accuracy of the thermodynamic model and interpretation of thermograms.
  • a detailed knowledge of the inflow or injection profile is required, because A priori information about the well section is not enough to build a thermodynamic model.
  • the inflow profile is measured using a chain of sequentially connected flowmeters with a sampling frequency of at least once a day, while the frequency of placement of flowmeters varies depending on the well section, and in the interval of perforation, the frequency of placement of flowmeters can be increased compared to areas outside the perforation interval.
  • the specific moisture content profile and / or specific gas content profile are additionally measured using a chain of sequentially connected moisture meters and / or densitometers with a sampling frequency of at least once a day, while the frequency of placement moisture meters and / or densitometers varies depending on the well site, and in the perforation interval, the frequency of The formation of moisture meters and / or densitometers can be increased compared to areas outside the perforation interval.
  • the composition of the inflow is required to be known not as detailed as the inflow profile, therefore, the frequency of placement of component sensors (moisture content and gas content) can be reduced in comparison with the frequency of placement of debitometers.
  • the acoustic noise profile is measured using a chain of series-connected acoustic sensors with a sampling frequency of at least once a day, while the frequency of placement of acoustic sensors (hydrophones) varies depending on the area wells, and in the perforation interval, the frequency of the placement of hydrophones can be reduced compared to areas outside the perforation interval.
  • a certain frequency band should be selected to distinguish useful noise from the noise from the flow along the borehole (usually low frequencies - up to 1 kHz) or flow in the pore matrix (usually high frequencies above 10 kHz).
  • Downhole pressure knowledge is necessary to optimize well operation and downhole equipment.
  • the rates of fluid withdrawal from the reservoir are determined by depression, i.e. the difference between the reservoir and bottomhole pressures, and the ratio of the selected phases will be different due to the different phase permeability of the reservoir with respect to gas and liquid.
  • depression i.e. the difference between the reservoir and bottomhole pressures
  • the ratio of the selected phases will be different due to the different phase permeability of the reservoir with respect to gas and liquid.
  • the drop and increase in pressure corresponds to the areas of fluid inflow or absorption, which, in combination with measuring the temperature profile, allows more reliably localizing areas of parasitic inflow due to leaking casing string.
  • the implementation of the proposed method depends on the necessary and sufficient set of primary data and on the assigned monitoring tasks, which means that it can be optimally selected for each specific well, taking into account the following factors:
  • the claimed method of monitoring an existing oil and gas well due to the possibility of selecting the most informative set of primary measured data (fluid temperature, fluid flow rate, fluid pressure, acoustic noise characteristics of the well and component composition of the fluid), taking into account the characteristics of a particular well, a wide range of geological, technological and field tasks (to determine the profile, composition of the inflow, the injectivity profile, evaluate the technical condition of the casing string, including to localize and evaluate the extent of leakage and annular circulation, as well as determine the filtration properties of the formation and select the optimal well operation mode), which has no analogues among the well-known methods of geophysical research of wells, which means that it meets the criterion of “inventive step”.
  • FIG. 1 is a diagram of a device for a mechanized oil and gas well, representing the implementation of one of the variants of the proposed method, in particular, with measuring the distribution of fluid temperature in the perforation interval, acoustic noise outside the perforation interval and local fluid pressure over the perforation interval, including: wellbore 1 , wellhead equipment 2, casing 3, into which an assembly consisting of a tubing (H T) 4 immersed in a centrifugal pump (ESP) tubing is immersed 5 driven by a submersible electric motor (PED) with hydroprotection 6, the power of which is provided via cable 7, at the lower end of which is placed a submersible telemetry system (TMS) 8 unit, connected to the cable of the ⁇ 7 for power and data transmission to the surface ; in turn, the unit of transfer electronics 9 is connected to the TMS block 8, to which the chain of temperature sensors 10 and the chain of acoustic sensors 1 1 are connected, and a block for measuring pressure, flow rate and component composition of fluid 12 is
  • FIG. 2 shows the result of measuring the distribution of fluid temperature along the wellbore using the implementation of FIG. 1.
  • the temperature distribution in the well is measured after a long stop, i.e. the geotherm 17, and compare it with the temperature distribution after the inflow 18 is called.
  • the deviation of the temperature profile 18 from the geotherm 17 is caused by the inflow in the interval 19, which causes local heating of the fluid due to throttling of the fluid as it passes through the porous medium.
  • FIG. 3 shows the result of measuring the distribution of fluid temperature along the wellbore using the implementation of FIG. 1.
  • the temperature profile 20 is measured and then interpreted based on the solution of the inverse heat transfer problem 2, the reference profile of the inflow 21 measured as a result of pulling the mechanical flow meter along the studied interval is in good agreement with the profile inflow 21 ', calculated according to the temperature profile 20, with the exception of areas of small fluid flows, where the thermometry gives an underestimation of the flow rate.
  • FIG. 4 shows the result of measuring the fluid temperature distribution along the wellbore using the implementation of FIG. 1.
  • the temperature distribution in the well is measured after a long stop, i.e. geotherm 22, and its comparison with the temperature distribution after calling the inflow at consecutive moments of time after 30 minutes (23) and 6 hours (24), and as a result of the inflow behind the column in the interval 25, thermal profiles 23 and 24 cause anomalies 23a and 24a and, as a result of the inflow into the column in the interval 26, on the thermoprofiles 23 and 24, anomalies 236 and 246 arise.
  • the region of annular circulation is localized, namely, the inflow interval behind the column 25 .
  • FIG. 5 shows the result of measuring the acoustic distribution along the wellbore using the implementation of FIG. 1.
  • the integral noise profile is measured along the wellbore 27, on which the leakage region of the fluid 28, which is accompanied by increased acoustic emission relative to the background, is clearly positioned.
  • FIG. 6 shows the result of measuring the local fluid pressure over the perforation interval using the implementation of FIG. 1.
  • a measurement of the time base of the pressure increase after stopping the well, i.e. pressure recovery curve (VD) 29, and its subsequent analysis, including the selection of a section with a bilinear flow regime 30 (1/4 slope), a section with a linear flow regime 3 1 (1/2 slope) and a pseudo-radial regime current 32.
  • VD pressure recovery curve
  • FIG. 7 is a diagram of a fountain gas condensate well device representing another embodiment of the inventive method, in particular, measuring the distribution of component composition and flow rate in the perforation interval, as well as the pressure distribution in the entire deposited interval, including wellbore 33, wellhead equipment 34, casing 35, into which the arrangement is composed of a tubing 36 ending in funnel 37, packer 38 isolates the casing space at the lower end of of the garden string 35, a suspension 39 of the casing 40 is placed, at the upper end of the casing 40 there is a transmission electronics unit and a wireless telemetry communication unit 41, below which there is a chain of thermoconductive flow meters 42 and sensors of component composition 43 located in the perforation interval, also a chain of pressure sensors 44 located throughout the interval of the casing liner, the casing liner 40 intersects the reservoir 45 in the perforation interval 46, as well as the aquifer ast 47.
  • FIG. 8 is a drawing explaining the result of direct measurements of the profile and composition of the gas condensate well inflow obtained using the implementation shown in FIG. 7.
  • the figure includes the measured distribution of flow rate 48 and fluid composition — condensate-gas factor (GHF), recalculated as the rate of condensate 49, and GHF in turn was determined by measuring the density of fluid 50 along the perforation interval.
  • GHF condensate-gas factor
  • FIG. 9 is a drawing explaining the result of measuring the pressure profile along the casing liner obtained using the implementation of FIG. 7.
  • the figure includes the measured distribution of hydrostatic pressure in a stopped well 5 1 and its comparison with the pressure distribution in dynamics 52, after the inflow is called. On the pressure profile 52, a portion 52a is identified corresponding to a narrowing of the cross section due to the precipitation of gas hydrates.
  • Example 1 Determination of the profile of the inflow, the technical condition of the casing string and the filtration properties of the formation.
  • the distribution of temperature and integral acoustic noise is measured in the wellbore, and the flow rate, component composition and pressure are measured local at a point above the temperature measurement interval.
  • the fluid inflow from the formation is accompanied by a number of thermodynamic processes, therefore, the deviation of the temperature from the stationary value can be a very sensitive indicator of the presence of inflow, and with a thermodynamic model of the well, we can calculate the inflow in a single interval, thus constructing the inflow profile in the perforation interval.
  • the appearance of anomalies in the temperature distribution outside the perforation interval means inflow into the column through the casing stain area, or inflow into the annulus due to the violation of the integrity of the cement stone. It is important to note that in the claimed method, the construction of the inflow profile is carried out in real time, and one can observe the life of the well without any intervention that would introduce a systematic error both at the time of measurement and from one measurement to another .
  • the spatial resolution is determined by the frequency of placement of thermal sensors, and can be made arbitrarily small.
  • C 0 is the heat capacity of the main phase
  • M is the mass of the main phase
  • T 0 is the temperature of the main phase
  • Am is the mass of the additional phase
  • C g is the heat capacity of the additional phase
  • T x is the temperature of the additional phase.
  • thermodynamic model is calculated on the basis of measurements of the total flow rate and component composition of the fluid at a point upstream.
  • the fluid pressure and component composition at the same point make it possible to estimate the pressure and, consequently, the composition of the fluid downstream, and to correct the thermodynamic model of fluid inflow from the formation in the perforation interval.
  • the technical condition of the casing outside the perforation interval is monitored by measuring the distribution of integral acoustic noise in a limited frequency band of 1 - 5 kHz.
  • the outflow of fluid in the area of casing leakage and / or annular circulation is accompanied by increased acoustic emission in the indicated frequency band, and is an addition to the thermal profile.
  • the filtration properties of the formation are determined through the relationship between the production rate of the well and the depression, which is the difference between the bottomhole and formation pressure.
  • the bottomhole pressure during the tests is regulated by the rate of fluid selection by setting certain operating modes of pumping or shut-off and control equipment.
  • a knowledge of the inflow profile is necessary for analyzing the efficiency of the delivery intervals and the localization of intervals with increased returns of water and / or gas, as well as determining the areas of casing leakage and / or annular circulation, which, of course, forms the basis for planning repair and insulation works.
  • the bottomhole pressure and knowledge of the filtration properties are necessary to set the optimal conditions for the removal of fluid from the reservoir and to establish the most optimal operating mode of pumping equipment.
  • FIG. 1 shows a producing mechanized oil and gas well equipped with a deep pump.
  • the immersion telemetry unit 8 there is a transmission electronics unit 9 and an integrated geophysical device 12 that measures the flow, pressure and component composition of the well fluid at the reception of the deep pump 5.
  • a chain of geophysical instruments connected in series to measure temperature 10 and integral acoustic noise 1 1.
  • the frequency of placement of temperature sensors in the perforation interval is increased compared to areas outside the perforation interval, and the integrated acoustic noise sensors there no.
  • the temperature profile in static is measured - geotherm 17, and the acoustic noise profile in the absence of any flow is a “zero” level.
  • the well is put into operation by calling the inflow with a deep pump 5, which takes out the fluid, which causes a decrease in the dynamic level in the annulus and a drop in bottomhole pressure, which in turn causes a depression on the formation and the outflow of fluid.
  • the transmission electronics unit interrogates the complex geophysical instrument 12, as well as both chains of geophysical instruments 10 and 1 1, at a certain interval and transmits data to the surface, where this information is analyzed according to the laid down well models.
  • FIG. Figure 2 shows the use of a temperature profile to indicate flow.
  • the current temperature distribution 18 is compared with the previously measured geotherm 17.
  • the position of this anomaly induces an inflow interval of 19, and after applying the inherent thermodynamic model, the magnitude of this anomaly can be converted into the inflow value.
  • An inflow in the perforation interval is a sign of a normally working well, however, the appearance of a temperature anomaly outside the perforation interval is detracts from a parasitic tributary, i.e. casing leakage and / or annular circulation leakage section.
  • FIG. 3 shows a detailed temperature distribution in the perforation interval.
  • the temperature profile 20 is interpreted using the thermodynamic model of the well in terms of inflow into a unit interval, i.e. inflow profile 2 is being built.
  • thermograms 23 and 24 show the position of the annular circulation region and make it possible to estimate the value of the parasitic flow after interpretation using the thermodynamic model.
  • the frequency of placement of temperature sensors is increased compared to areas outside the perforation interval, since the inflow profile usually needs to be known with a higher spatial resolution than to locate areas of casing leakage and / or annular circulation.
  • FIG. 5 shows the distribution of integral acoustic noise 27 outside the perforation interval.
  • the appearance of a section of increased acoustic emission 28 in the frequency range 1–5 kHz indicates the flow of fluid through the casing leakage region.
  • FIG. Figure 6 shows the HPC after stopping a well with a hydraulic fracture 29 and typical sections, including a section with a bilinear flow regime 30 (inclination 1/4), a section with a linear flow regime 31 (inclination 1/2) and a section with a pseudo-radial flow regime 32.
  • the hydrodynamic model on the basis of the obtained HPC gives the following information: the conductivity of the crack is determined from the section with bilinear flow mode 30, the crack length is determined from the section with linear flow mode 31, and the pseudo-radial flow is determined from the section with pseudo-radial flow mode 32 ny skin factor. (See Karnakhov ML, Pyankova EM, MODERN METHODS OF HYDRODYNAMIC RESEARCHES OF WELLS. Handbook of a well research engineer. Infra-Engineering Publishing House, 2010).
  • Example 2 Determination of the profile and composition of the inflow, as well as sections of narrowing the cross section due to solid deposits.
  • the distribution of flow rate and component composition (specific fluid content) as well as the pressure distribution are measured in the wellbore.
  • FIG. 7 shows a producing flowing gas condensate well.
  • a transmission electronics unit 37 equipped with a wireless telemetry communication unit for transmitting data to the surface.
  • a chain of thermoconductive flow meters 38 and a chain of sensors of component composition 39 under the block of transmission electronics 37 is a chain of thermoconductive flow meters 38 and a chain of sensors of component composition 39, in this case, acoustic densitometers that allow you to determine GF, as well as a chain of pressure sensors 40.
  • f is the friction coefficient
  • p is the average fluid density
  • V is the average fluid flow rate in the wellbore
  • d is the cross-sectional area.
  • the friction coefficient f is calculated from the Blasius equation:
  • the component composition of the gas condensate mixture — KGF a b in the stream is determined by measuring the density of p mix from the relation:
  • Pi p g are the thermobaric values of the density of the liquid and gas.
  • FIG. Figure 8 shows the inflow profile 41 with the GF 42 profile superimposed on it, obtained by direct measurements using a chain of thermo-inductive flow meters 38 in combination with a chain of density sensors 39 located in the perforation interval.
  • FIG. 9 shows a pressure profile 45, in which sections 45a and 456 are marked, corresponding to a narrowing of the cross section due to precipitation of gas hydrates, and also 45b, corresponding to a parasitic inflow into the column, i.e. casing liner leakage area.
  • the chain of acoustic noise and temperature sensors was assembled from the combined geophysical instruments TSh-M (A -2000) manufactured by NPF Geofizika, sequentially connected by a three-core load-bearing geophysical cable. This device allows you to measure the intensity of acoustic noise in the wellbore in four spectral bands, of which only HF (2 - 5 kHz) was used, as well as the temperature of the borehole fluid in the range 0-100 ° C with a resolution of 0.005 ° C and accuracy to ⁇ 1 ° C.
  • a chain of sensors was connected by a geophysical cable to the complex geophysical instrument SAKMAR-5D-42-ETsN produced by NPF Geofizika.
  • This instrument allows measuring the temperature of a well fluid in the range of 0 - 120 ° C with a resolution of 0.003 ° C and accuracy of ⁇ 0.85 ° C, the pressure of the well fluid in the range of 0 - 40 MPa with a resolution of 0.02% VPI and accuracy of ⁇ 0.2% VPI , downhole fluid flow rate in the range of .5-100 m 3 / h with an accuracy of ⁇ 4%, specific moisture content of the downhole fluid in the range 0-100% with an accuracy of ⁇ 5%.
  • the SAKMAR-5D-42-ETSN integrated geophysical instrument was suspended on a load-bearing geophysical cable under the ESC, connecting as an affiliated device to the high-precision submersible telemetry block of the EEC BP-103M4 manufactured by Izhevsk Radio Plant.
  • This TMS unit allows measuring the pressure of the well fluid in the range 0–40 MPa with a resolution of 0.002% VPI and accuracy of ⁇ 0.02%, the temperature of the well fluid in the range 0–150 ° C with a resolution of 0.001 ° C and accuracy of ⁇ 0.3 ° C.

Abstract

L'invention concerne le domaine de l'exploration géophysique de puits de forage pétroliers ou gaziers et notamment un procédé pour surveiller les paramètres d'un puits de forage de pétrole et de gaz en activité et peut s'utiliser pour déterminer en temps réel le profil d'excitation pour les puits d'extraction et le profil d'injectivité pour les puits d'injection, et pour évaluer l'état technique d'une colonne d'exploitation d'un puits, à savoir pour détecter les fuites de liquide derrière un tubage de forage en amont et en aval de l'intervalle de perforation. Le procédé pour surveiller les paramètres d'un puits de forage de pétrole et de gaz en activité est mis en œuvre en temps réel dans des points choisis localement et/ou le long de zones choisies d'un puits de mesure des propriétés physiques du puits. En tant que caractéristique du puits de forage on choisit une température du fluide et/ou un débit de fluide et/ou une pression de fluide et/ou une caractéristique du bruit acoustique du puits et/ou la composition du fluide en termes de composants. Le résultat technique de l'invention consiste en une efficacité plus élevée et en même temps en une réduction de dépenses et de risques lors de l'exploration de puits de forage de gaz et de pétrole existants, qu'il s'agisse de puits d'extraction ou de puits d'injection.
PCT/RU2014/000300 2014-04-24 2014-04-24 Procédé pour surveiller les paramètres d'un puits de forage de pétrole et de gaz en activité WO2015163781A1 (fr)

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EA201501084A EA201501084A1 (ru) 2014-04-24 2014-04-24 Способ мониторинга параметров действующей нефтегазовой скважины

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Cited By (1)

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Publication number Priority date Publication date Assignee Title
CN111827970A (zh) * 2020-08-06 2020-10-27 中国石油天然气集团有限公司 一种复合型持水率流量传感器

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