WO2021162570A1 - Procédé pour déterminer la composition en composants d'un mélange de gaz et de liquide - Google Patents

Procédé pour déterminer la composition en composants d'un mélange de gaz et de liquide Download PDF

Info

Publication number
WO2021162570A1
WO2021162570A1 PCT/RU2019/000897 RU2019000897W WO2021162570A1 WO 2021162570 A1 WO2021162570 A1 WO 2021162570A1 RU 2019000897 W RU2019000897 W RU 2019000897W WO 2021162570 A1 WO2021162570 A1 WO 2021162570A1
Authority
WO
WIPO (PCT)
Prior art keywords
fluid
component
gas
wellbore
zone
Prior art date
Application number
PCT/RU2019/000897
Other languages
English (en)
Russian (ru)
Inventor
Константин Васильевич РЫМАРЕНКО
Марат Тохтарович НУХАЕВ
Александр Владимирович ГОЛУБЦОВ
Original Assignee
Общество с ограниченной ответственностью Научно-Производственное Объединение "МФ Технологии"
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Общество с ограниченной ответственностью Научно-Производственное Объединение "МФ Технологии" filed Critical Общество с ограниченной ответственностью Научно-Производственное Объединение "МФ Технологии"
Publication of WO2021162570A1 publication Critical patent/WO2021162570A1/fr

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
    • G01V1/44—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
    • G01V1/48—Processing data

Definitions

  • the invention relates to the field of oil production, in particular to the field of monitoring the component composition of oil and gas fluid entering the well at the inflow section and can be used to diagnose the operation of an oil producing well.
  • the method should determine the component composition of the fluid in the well inflow section with sufficient accuracy for practical use.
  • the method should determine the three-component composition of the fluid in real time.
  • the method must determine along the entire length of the inflow section the location of the unwanted fluid components (gas, water).
  • the method must be able to continuously monitor the inflow section.
  • the known method makes it possible to assess the nature of the product entering the production pipe, allows continuous monitoring for a long period of time, and also makes it possible to conduct research in horizontal sections of wells.
  • the known method makes it possible to determine the compositional composition of the fluid entering the inflow section, but only by two components (oil, water), since the studies are carried out by quantitative assessment of the reagent dissolved in the fluid, and the reagent does not dissolve in the gaseous medium.
  • the specified operating mode of the well does not allow organizing its continuous exploration in real time.
  • the known method makes it possible to detect liquid flows behind the casing and penetrating into the casing, based on the spectrum of noise generated by the movement of the fluid in the area of the acoustic noise receiver.
  • the known method is difficult to apply in horizontal sections of wells, without the use of additional equipment (devices for pulling flexible cables in horizontal sections of wells), since the probe is lowered on a suspension from a logging cable.
  • the known method can detect fluid flows in the wellbore or outside it, but it does not seem possible to estimate the component composition of the fluid, and it is also impossible to detect the presence of a gaseous medium in the circumferential space.
  • the known method does not allow continuous monitoring, since the measuring probe at one time makes measurements in one section of the wellbore, which does not exceed the dimensions (length) of the probe, and to measure the next section, the measuring probe must be moved.
  • the closest in technical essence to the claimed method is the method taken as a prototype for determining the averaged geophysical parameters in an unstuffed well (see patent application RU2012139483, MKI: ⁇ 21 ⁇ 27/14, G01V 1/44, 2014).
  • the method includes placing a probe in the wellbore and moving along it a probe emitting acoustic waves, according to the propagation velocity of which in the medium under investigation, the averaged geophysical parameters of the medium under study are judged, while the movement along the wellbore is carried out intermittently, and waves in the investigated medium are carried out at the moments of stopping the sounding means.
  • the known method makes it possible to evaluate the surrounding medium by assessing the density of the medium, based on the propagation velocity of sound waves emitted by the source and received by the probe sensor, which makes it possible to detect the gas factor with confidence.
  • the known method has a number of significant disadvantages.
  • the known method evaluates the adjacent medium by measuring the density of the medium, based on the propagation velocity of sound waves emitted by the source and received by the probe sensor, this method allows only the gas-oil ratio to be detected with confidence, and in the case of a multicomponent fluid, the density which can be caused by many factors, such as the content of gas and liquid factors in it in different proportions, therefore, the same picture of the permeability and propagation velocity of sound waves can be given by different combinations of these factors, which makes them impossible differentiation with sufficient accuracy of the present components of the fluid factor.
  • the known method does not allow real-time surveys in the well, since surveys are performed discretely and pointwise, and only at the location of radiation sources and receiving an acoustic signal, fixed on an acoustic probe, the length of which determines the length of the measured zone.
  • the shorter the probe the more accurate the localization of the measurements in the borehole and the longer the time required to survey the borehole.
  • the known method is able to simultaneously conduct research in an area not exceeding the length of the probe (about 1.5 m), which does not allow assessing the inflow profile throughout the entire inflow area.
  • the known method does not allow for continuous monitoring of the well, since the measuring probe at a given time makes measurements only in one section of the wellbore.
  • the constant presence of a probe on a flexible suspension in the wellbore is undesirable from the point of view of operation. wells, as it interferes with routine maintenance (cleaning the wellbore, using other probing tools, etc.).
  • the known method is difficult to apply in horizontal sections of wells, without the use of additional equipment (devices for pulling flexible cables in horizontal sections of wells), since the probe is lowered on a suspension from a flexible cable.
  • the technical result of the proposed technical solution is the elimination of these disadvantages, namely the creation of a new method for determining the component composition of the fluid entering the wellbore at the inflow section, which allows real-time continuous monitoring of the operating well along the entire length of all inflow sections, not only for vertical, but also for horizontal wells, and without running additional equipment into the well.
  • the specified technical result in the method for determining the composition of the gas-liquid mixture entering the wellbore at the inflow section, including the placement in the wellbore in the inflow section of the source and receiver of the acoustic signal, is achieved by the fact that in the inflow section in the holes between a zone of increased fluid pressure and a zone of reduced fluid pressure, stationary N hydroacoustic and / or gas-jet emitters and L hydrophones are placed, while the fluid component entering the zone of reduced pressure through the perforation holes is judged by the frequency of the hydrophone signal, and the comparative value of the presence of this component is determined by the amplitude of the received signal, normalized relative to a previously captured reference signal for a given component in a simulated environment.
  • hydrodynamic emitter as an acoustic emitter, for heavily watered wells, in order to localize the zones of water inflow in the inflow sections.
  • Figure 1 shows a drawing explaining the essence of the claimed method, where: 1 - tubing; 2 - annular space; 3a ... 3p - packers; 4- well liner; 5 - oil-permeable layer; 6a - 66 perforations with acoustic vibrations emitters installed in them; 7a-7b - acoustic vibration receivers fixed on tubing; 8 - data cable; 9 Vintage - 96 - inflow sections.
  • FIG. 2 shows a figure explaining the algorithm for comparing the obtained signal values with the reference ones, where: 10 - reference signal from the oil; 11 - signal at the frequency of the oil component, obtained during measurements in the well; 12 - signal from salt water; 13 - signal at the frequency of the water component obtained during measurements in the borehole; 14 - signal from methane; 15 - signal at the frequency of the gas component obtained during measurements in the borehole.
  • FIG. 3 shows a figure explaining the essence of the claimed method, where: 16 - downhole space; 17 - well completion device; 18 réelle - 186 section of the inflow; 19–196 sources of acoustic vibrations; 20a-20b acoustic vibration receivers; 21 - data cable; 22 bottomhole zone.
  • the tubing section with perforation along the pipe surface was selected, into which the fluid enters from the high-pressure zone (annulus) (2) (see Fig. 1).
  • FIG. 1 horizontal fragment of an oil well using the proposed method will function as follows.
  • Oil fluid in the inflow section (9a - 96), bounded by packers (Za, 36), from the bottomhole zone (5) under the influence of the pressure difference in the bottomhole zone (5) and tubing (1) passes through the liner (4 ) into the annulus (2), from where, through the perforations equipped with acoustic oscillators (6a, 66) it penetrates the tubing (1) while causing the radiation of acoustic oscillations by sources of acoustic oscillations.
  • Acoustic vibrations are recorded by acoustic vibration receivers (7a - 76) fixed on the tubing and are transmitted, for further processing, via an information cable (8).
  • the received signal is processed according to the figure in FIG. 2.
  • the comparison is carried out according to the magnitude of the signal amplitude, the differentiation of the signal source is carried out according to the frequency of the generated signal.
  • the signal amplitude is compared in the frequency band characteristic for each component of the medium.
  • FIG. 2a the reference signal from oil (10) and the recorded signal from the oil fluid (11), in the frequency range typical for oil, with amplitudes A1 and A2, respectively. Similar actions are performed for each frequency range, characteristic for each component of the fluid, for water ⁇ and ⁇ 4, and also ⁇ 5 and ⁇ 6 for gas, respectively.
  • the current state of the fluid can be represented in real time.
  • Variant 2 As the low-pressure zone of the inflow section (18a, 186), the downhole space (16) with perforation along the surface of the pipe (17) was selected, into which fluid flows from the high-pressure zone (bottom-hole zone) (22) (see Fig. H). Under the influence of the pressure difference in the near-wellbore zone (22) and downhole space (16), the fluid passes through the perforations equipped with acoustic oscillation emitters (19a, 196) and penetrates into the downhole space (16), while causing the emission of acoustic signals by sources of acoustic oscillations. Acoustic vibrations are recorded by acoustic vibration receivers (20a - 206) fixed to the tubing and are transmitted for further processing via an information cable (21). The processing of the received signal is carried out similarly to that shown in FIG. 2 and described in example 1.
  • GOST 982-80 For emu transformer oil (GOST 982-80) was used to control the oil component of the fluid; to emulate the water component, salt water was used (at a concentration of 5 mg / l, which corresponds to the salinity of the formation water of the Kanchurinskoye field - Bashkortostan); methane was used as a gas component (as the predominant associated petroleum gas). The mixture was used with different proportions of the components.
  • the hydrodynamic emitter generated oscillations in the range of 12 Hz (+/- 1 Hz) when using salt water as a 100% solution.
  • the hydrodynamic emitter generated oscillations in the range of 43 Hz (+/- 2 Hz) when using transformer oil as a 100% solution.
  • the gas jet radiator generated oscillations in the range of 238 Hz (+/- 10 Hz).
  • the claimed method has confirmed the possibility of assessing the component composition of the oil fluid by direct transformation of acoustic vibrations generated by the fluid entering through the tubing perforation holes into acoustic vibrations received by hydrophones.

Landscapes

  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geophysics (AREA)
  • Remote Sensing (AREA)
  • Acoustics & Sound (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • General Physics & Mathematics (AREA)
  • Fluid Mechanics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics And Detection Of Objects (AREA)

Abstract

L'invention se rapporte au domaine de l'extraction pétrolière, notamment au domaine du contrôle de la composition en composants d'un liquide à base de gaz et de pétrole pénétrant dans un puits dans la zone affluente, et peut être utilisée afin de diagnostiquer le fonctionnement d'un puits d'extraction de pétrole. L'invention concerne un procédé pour déterminer la composition en composants d'un mélange de gaz et de liquide entrant dans le l'âme du puits dans une zone d'affluent, qui consiste à placer une source et un récepteur de signal acoustique dans le l'âme du puits dans la zone de l'affluent. L'invention est caractérisée en ce que, dans la zone de l'affluent dans les ouvertures entre la zone de fluide à haute pression et la zone de fluide à basse pression sont disposés de manière stationnaire N émetteurs hydro-acoustiques et/ou à flux de gaz et L hydrophones; on évalue la composition du fluide ayant pénétré dans la zone de basse pression via l'ouverture de perforation en se basant sur la fréquence du signal de l'hydrophone, et la valeur comparative de la présence d'un composant donné est déterminée en fonction de l'amplitude du signal reçu et normalisé par rapport à un signal de référence préalablement échantillonné pour le composant donné dans un système de modèle.
PCT/RU2019/000897 2020-02-13 2020-02-13 Procédé pour déterminer la composition en composants d'un mélange de gaz et de liquide WO2021162570A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
RU2019139202 2020-02-13
RU2019139202 2020-02-13

Publications (1)

Publication Number Publication Date
WO2021162570A1 true WO2021162570A1 (fr) 2021-08-19

Family

ID=77295203

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/RU2019/000897 WO2021162570A1 (fr) 2020-02-13 2020-02-13 Procédé pour déterminer la composition en composants d'un mélange de gaz et de liquide

Country Status (1)

Country Link
WO (1) WO2021162570A1 (fr)

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6205087B1 (en) * 1996-01-31 2001-03-20 Schlumberger Technology Corporation Sonic data logging system
RU2197647C1 (ru) * 2001-10-31 2003-01-27 Петроальянс Сервисис Компани Лимитед Скважинная насосная установка для испытания и исследования пластов
RU2499283C1 (ru) * 2012-04-23 2013-11-20 ТиДжиТи Ойл энд Гэс Сервисиз ФЗЕ Способ и устройство для скважинной спектральной шумометрии
RU2526096C2 (ru) * 2012-04-20 2014-08-20 Эстония, Акционерное общество ЛэндРесурсес Способ сейсмоакустических исследований в процессе добычи нефти

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6205087B1 (en) * 1996-01-31 2001-03-20 Schlumberger Technology Corporation Sonic data logging system
RU2197647C1 (ru) * 2001-10-31 2003-01-27 Петроальянс Сервисис Компани Лимитед Скважинная насосная установка для испытания и исследования пластов
RU2526096C2 (ru) * 2012-04-20 2014-08-20 Эстония, Акционерное общество ЛэндРесурсес Способ сейсмоакустических исследований в процессе добычи нефти
RU2499283C1 (ru) * 2012-04-23 2013-11-20 ТиДжиТи Ойл энд Гэс Сервисиз ФЗЕ Способ и устройство для скважинной спектральной шумометрии

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
KOSKOV ET AL.: "Kompleksnaya otsenka sostoyaniya i raboty neftyanykh skvazhin promyslovo-geofizicheskimi metodami", PERM, IZDATELSTVO PGTU, 2010, pages 101 - 105, ISBN: 978-5-398-00427-4 *

Similar Documents

Publication Publication Date Title
US20220282611A1 (en) Method for fracturing activity and intensity monitoring and pressure wave resonance analysis
US11125909B2 (en) Enhanced seismic surveying
US11762115B2 (en) Fracture wave depth, borehole bottom condition, and conductivity estimation method
US7516015B2 (en) System and method for detection of near-wellbore alteration using acoustic data
US10126448B2 (en) Formation measurements using downhole noise sources
US4046220A (en) Method for distinguishing between single-phase gas and single-phase liquid leaks in well casings
US20090166030A1 (en) Method to monitor reservoir fracture development and its geometry
US10344582B2 (en) Evaluation of downhole installation
CA3065588C (fr) Methode et systeme de surveillance d`operations post-stimulation au moyen d`un reseau de capteurs sans fil acoustiques
US10662761B2 (en) Evaluation of cased hole perforations in under-pressured gas sand reservoirs with stoneley wave logging
US11566517B2 (en) Quantifying cement bonding quality of cased-hole wells using a quality index based on frequency spectra
AU2017374025A1 (en) Evaluation of physical properties of a material behind a casing utilizing guided acoustic waves
US11174724B2 (en) Downhole tool for detecting pipe leaks
RU2707311C1 (ru) Способ оценки профиля фазовой проницаемости в нефтяных и газовых эксплуатационных скважинах
US3588800A (en) Method of determining characteristics of earth formations
RU2344285C1 (ru) Способ обнаружения газонасыщенных пластов в скважинах
WO2021162570A1 (fr) Procédé pour déterminer la composition en composants d'un mélange de gaz et de liquide
GB2572811A (en) Evaluation of a formation outside of a pipe and evaluation of formation creep outside of a pipe
CN108756867B (zh) 基于声波测井曲线和电阻率测井曲线进行压裂选层的方法
US20210088476A1 (en) Autonomous inflow control device for live flow monitoring
EA009033B1 (ru) Способ и система для оценки поведения давления порового флюида в подземной формации
RU2728121C1 (ru) Способ определения характеристик фильтрационного потока в околоскважинной зоне пласта
RU2728123C1 (ru) Способ определения работающих интервалов глубин нефтяных и газовых пластов
in’t Panhuis Fundamentals of Distributed Acoustic Sensing for Inflow Profiling
Shuck et al. Noise Characteristics of Oil Wells and Reservoirs

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 19958749

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 19958749

Country of ref document: EP

Kind code of ref document: A1