EP2772610B1 - Procédé pour déterminer le profil des influx de fluides dans des gisements à formations multiples - Google Patents

Procédé pour déterminer le profil des influx de fluides dans des gisements à formations multiples Download PDF

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Publication number
EP2772610B1
EP2772610B1 EP12844033.6A EP12844033A EP2772610B1 EP 2772610 B1 EP2772610 B1 EP 2772610B1 EP 12844033 A EP12844033 A EP 12844033A EP 2772610 B1 EP2772610 B1 EP 2772610B1
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Prior art keywords
wellbore
temperature
production
fluid
zone
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Not-in-force
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EP12844033.6A
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German (de)
English (en)
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EP2772610A1 (fr
EP2772610A4 (fr
Inventor
Bertrand Theuveny
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Services Petroliers Schlumberger SA
Prad Research and Development Ltd
Schlumberger Technology BV
Schlumberger Holdings Ltd
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Services Petroliers Schlumberger SA
Prad Research and Development Ltd
Schlumberger Technology BV
Schlumberger Holdings Ltd
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Publication of EP2772610A4 publication Critical patent/EP2772610A4/fr
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    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/14—Obtaining from a multiple-zone well
    • 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
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
    • 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
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/103—Locating fluid leaks, intrusions or movements using thermal measurements
    • 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
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
    • E21B49/087—Well testing, e.g. testing for reservoir productivity or formation parameters
    • E21B49/0875—Well testing, e.g. testing for reservoir productivity or formation parameters determining specific fluid parameters

Definitions

  • the disclosure relates to the field of geophysical studies of oil and gas wells, in particular to determining the inflow profile of fluids inflowing into the wellbore from multi-zone reservoirs.
  • the method for determining profile of fluid inflow from a multi-zone reservoir provides the possibility to determine the inflow profile at an initial stage of production, just after perforating a well, and in enhancing the accuracy of inflow profile determination due to the possibility of determining inflow profile by transient temperature data.
  • the method comprises measuring temperature in a wellbore during a wellbore-return-to-thermal-equilibrium time after drilling and then perforating the wellbore. Temperature of fluids inflowing into the wellbore from pay zones is determined at an initial stage of production and a specific flow rate for each pay zone is determined by rate of change of the measured temperatures.
  • temperature of the fluids is determined with the use of sensors installed on a tubing string, above each perforated interval.
  • the wellbore return-to-thermal-equilibrium time usually lasts for 5-10 days.
  • Temperature of the fluids inflowing into the wellbore from pay zones at the initial state of production is preferably measured within 3-5 hours from start of production.
  • Figure 1 shows a scheme with three perforated intervals and three temperature sensors
  • Figures 2a and 2b show results of calculation of inflow profiles for two versions of formation permeabilities
  • Figure 3 shows temperatures of fluids inflowing into the wellbore and temperatures of the corresponding sensors for the case illustrated in Figure 2a
  • Figure 4 shows temperatures of the fluids inflowing into the wellbore and temperatures of the corresponding sensors for the case illustrated in Figure 2b
  • Figure 5 shows time derivatives of fluid temperature and temperature of sensor 1 for the case illustrated in Figure 2a
  • Figure 6 shows time derivatives of fluid temperature and temperature of sensor 1 for the case illustrated in Figure 2b
  • Figure 8 shows the same ratios for Figure 6 ;
  • Figure 9 shows correlation between the time derivative T in and specific flow rate q.
  • the method may be used with a tubing-conveyed perforation. It is based on the fact that a near-wellbore space, as a result of drilling, usually has a lower temperature than temperature of surrounding rocks.
  • temperature of a reservoir in a near-borehole zone is significantly (by 10-20 K and more) lower than an original temperature of the surrounding reservoir at a depth under consideration.
  • a relatively long period of wellbore-retuming-to-thermal-equilibrium follows during which other working operations in the well are carried out, including installation of a testing string with perforator guns.
  • temperature measurements in the wellbore are conducted.
  • an initial stage of production follows - cleanup of the near-borehole zone of the reservoir.
  • temperature of the fluids inflowing into the wellbore is measured.
  • radial profile of temperature in the reservoir prior to start of the cleanup is determined with the use of some general relationship that follows from the equation of conductive heat transfer (1).
  • ⁇ T ⁇ t a ⁇ ⁇ 2 T ⁇ r 2 + 1 r ⁇ ⁇ T ⁇ r
  • " a " is a heat diffusivity of the reservoir.
  • Formulas (4), (5) give an approximate radial temperature profile near the wellbore prior to start of production.
  • a numerical simulation demonstrates that after 50 hours of borehole-return-to-thermal-equilibrium time, these formulas are adequate for r ⁇ 0.5 ⁇ 0.7 m (with accuracy of 1 ⁇ 5 %) for an arbitrary possible initial (before closure) temperature profile.
  • Formulas (4), (5) do not take into consideration the influence of heat emission in course of perforation and radial non-uniformity of thermal properties of the wellbore and the reservoir, that is why after comparison with results of numerical simulation, introduction of some correction coefficient might be necessary.
  • q [m 3 /m/s] is a specific flow rate
  • ⁇ f c f is a volumetric heat capacity of the fluid
  • ⁇ m c m is a volumetric heat capacity of the rock matrix
  • ⁇ is a porosity of the reservoir.
  • Equation (6) does not account for conductive heat transfer, the Joule-Thomson effect and the adiabatic effect.
  • All parameters in this formula can be approximately estimated (" a " and ⁇ ) or measured.
  • the value of ⁇ s is measured with the use of temperature sensors after installing the tubing string before the perforation.
  • the value of ⁇ 1 is measured above the first perforation interval at the initial stage of production.
  • the parameter ⁇ (11) is one and the same for all zones; the parameters ⁇ i are different because they depend on the temperature of the reservoir T ⁇ ,i recorded in the wellbore before start of production.
  • the numeric model of the producing wellbore should calculate transient temperatures of the flow at each depth of placement of the sensor with consideration of heat losses into the surrounding reservoir, the calorimetric law for the fluids being mixed in the wellbore, and the thermal influence of the wellbore which is understood here as the influence of the fluid initially filling the wellbore.
  • the flow rate is determined with the use of the procedure of model fitting that minimizes differences between the recorded and calculated temperatures of the sensors.
  • T 1 * ⁇ Q 1 + T in , 2 ⁇ Q 2 Q 1 + Q 2 T 2 *
  • T 1 * are T 2 * are temperatures of the fluid below and above the perforated zone.
  • T 2 * are temperatures of the fluid below and above the perforated zone.
  • Relative flow rates for perforated zones 3 and 4 can be calculated using the dimensionless values y 2 , y 3 and so on, which were determined previously for the perforated zones located down the wellbore.
  • Geothermal gradient equals 0.02 K/m.
  • the temperature of the undisturbed reservoir at the depth of sensor 1 (274 m) is 65.5°C that at the depth of sensor 3 (230 m) is 64.6°C.
  • Figure 1 shows the scheme of a well with three perforated intervals (#1: 280-290 m, #2: 260-270 m, #3: 240-250 m) and three temperature sensors: T 1 at the depth of 274 m, T 2 at the depth of 254 m and T 3 at the depth of 230 m.
  • the reservoir/wellbore temperature is the same in both cases under consideration.
  • Figures 3 and 4 show temperatures of the produced fluids (thin curves) and temperatures of the corresponding sensors (bold curves).
  • the difference between T in ,1 and T 1 remains practically constant after ⁇ 1 hr of production.
  • Time derivatives of fluid temperature and temperature of sensor #1 are presented in Figures 5 and 6 .
  • the difference between dT in ,1 / dt and ⁇ 1 amounts to about 6-8%, that confirming our assumption made in the analysis presented above.
  • Relative errors (related to the total flow rate) are 0.3%, 1%, and 1.3%.
  • Equation 8 For the third perforated zone, Equation 8 gives f 32 ⁇ 0.96, while from Equation (22) we find two roots:
  • the most reliable inversion of temperature measured among perforated intervals immediately after perforating can be made with the use of a specialized numerical model and fitting the transient temperature data with consideration of absolute values of temperature as well as time derivatives of temperature.

Landscapes

  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics (AREA)
  • Investigating Or Analyzing Materials Using Thermal Means (AREA)
  • Measuring Temperature Or Quantity Of Heat (AREA)
  • Measuring Volume Flow (AREA)

Claims (7)

  1. Procédé pour déterminer le profil d'un flux de fluides, provenant des réservoirs répartis sur de multiples zones, entrant à l'intérieur d'un puits de forage, comprenant :
    - la mesure de la température dans le puits de forage pendant un temps de retour à l'équilibre thermique du puits de forage après forage ;
    caractérisé en ce que le procédé comprend en outre les étapes de :
    - perçage du puits de forage ;
    - détermination de la température des fluides entrant à l'intérieur du puits de forage depuis chaque zone de production au niveau d'une phase initiale de production ; et
    - détermination d'un débit spécifique pour chaque zone de production au moyen de la vitesse de variation des températures mesurées.
  2. Procédé selon la revendication 1, dans lequel la température des fluides entrant à l'intérieur du puits de forage depuis les zones de production est déterminée par mesure directe de la température des fluides entrant à l'intérieur du puits de forage depuis chaque zone de production, et dans lequel un débit spécifique de chaque zone de production est déterminé au moyen de la formule : Q i = 4 π χ ⋅ a ⋅ h i ⋅ T in , i • T • s − 1 ,
    Figure imgb0053
     dans laquelle :
    Qi est un débit de la i-ème zone de production ;
    Ṫs est une vitesse de rétablissement de température dans le puits de forage avant perçage ;
    Ṫin,i est une vitesse de variation de température du fluide entrant à l'intérieur du puits de forage depuis la i-ème zone de production au niveau de la phase initiale de production ;
    hi est une épaisseur de la i-ème zone de production ;
    a est une diffusivité thermique du réservoir, χ = c f ⋅ ρ f ρ r ⋅ c r ,
    Figure imgb0054
    ρfcf est une capacité thermique volumique du fluide ;
    ρrcr = φ · ρfcf + (1 - φ) · ρmcm est une capacité thermique volumique de la roche saturée par le fluide ;
    ρmcm est une capacité thermique volumique d'une matrice rocheuse ;
    φ est une porosité du réservoir.
  3. Procédé selon la revendication 1, dans lequel le temps de retour à l'équilibre thermique du puits de forage est de 5-10 jours.
  4. Procédé selon la revendication 1, dans lequel la température des fluides entrant à l'intérieur du puits de forage depuis chaque zone de production au niveau de la phase initiale de production est mesurée dans 3-5 heures après le début de la production.
  5. Procédé selon la revendication 1, dans lequel la température des fluides est déterminée par des capteurs installés sur une colonne de tubage qui est utilisée pour le perçage, au-dessus de chaque intervalle percé, un débit spécifique d'une zone de production plus basse étant déterminé au moyen de la formule : Q 1 = 4 π χ ⋅ a ⋅ h 1 ⋅ T • 1 T • s − 1 ,
    Figure imgb0055
     dans laquelle :
    Ql est un débit de la zone plus basse ;
    Ṫs est une vitesse de rétablissement de température dans le puits de forage avant perçage ;
    Ṫ1 est une vitesse de variation de température du fluide entrant à l'intérieur du puits de forage depuis la zone de production au niveau de la phase initiale de production, telle que mesurée au-dessus de l'intervalle percé plus bas ;
    hl est une épaisseur de la zone de production plus basse ;
    a est une diffusivité thermique du réservoir, χ = c f ⋅ ρ f ρ r ⋅ c r ,
    Figure imgb0056
    ρfcf est une capacité thermique volumique du fluide ;
    ρrcr = φ · ρfcf + (1 - φ) · ρmcm est une capacité thermique volumique de la roche saturée par le fluide ;
    ρmcm est une capacité thermique volumique de la matrice rocheuse ;
    φ est une porosité du réservoir, et
    dans lequel des débits spécifiques de zones de production situées au-dessus sont déterminés au moyen de températures mesurées par les capteurs installés sur la colonne de tubage, en utilisant les débits déterminées pour les zones de production situées au-dessous.
  6. Procédé selon la revendication 5, dans lequel le temps de retour à l'équilibre thermique du puits de forage est de 5-10 jours.
  7. Procédé selon la revendication 5, dans lequel la température des fluides entrant à l'intérieur du puits de forage depuis chaque zone de production au niveau de la phase initiale de production est mesurée dans 3-5 heures après le début de la production.
EP12844033.6A 2011-10-26 2012-10-25 Procédé pour déterminer le profil des influx de fluides dans des gisements à formations multiples Not-in-force EP2772610B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
RU2011143218/03A RU2474687C1 (ru) 2011-10-26 2011-10-26 Способ определения профиля притока флюидов многопластовых залежей
PCT/RU2012/000872 WO2013062446A1 (fr) 2011-10-26 2012-10-25 Procédé pour déterminer le profil des influx de fluides dans des gisements à formations multiples

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EP2772610A1 EP2772610A1 (fr) 2014-09-03
EP2772610A4 EP2772610A4 (fr) 2016-01-27
EP2772610B1 true EP2772610B1 (fr) 2017-07-26

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EP (1) EP2772610B1 (fr)
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WO (1) WO2013062446A1 (fr)

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BR102014011707B1 (pt) 2013-05-17 2021-06-15 Schlumberger Technology B.V. Dispositivo de medição, ferramenta para fundo de poço, e método
RU2531499C1 (ru) * 2013-08-23 2014-10-20 Шлюмберже Текнолоджи Б.В. Способ определения профиля притока флюидов многопластовых залежей в скважине
RU2645692C1 (ru) * 2016-12-21 2018-02-27 Шлюмберже Текнолоджи Б.В. Способ определения профиля притока флюида в многопластовой скважине
RU2651832C2 (ru) * 2017-02-20 2018-04-24 Юрий Васильевич Коноплёв Способ и установка для контроля дебита нефтяных скважин

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SU905443A1 (ru) * 1980-03-28 1982-02-15 Производственный Геофизический Трест Газовой Промышленности "Союзгазгеофизика" Способ определени профил притока флюида
SU1079827A1 (ru) * 1982-02-08 1984-03-15 Ташкентский Ордена Дружбы Народов Политехнический Институт Им.А.Р.Бируни Способ определени интервалов притока пластового флюида в скважине
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GB9916022D0 (en) * 1999-07-09 1999-09-08 Sensor Highway Ltd Method and apparatus for determining flow rates
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AU2004309118B2 (en) * 2003-12-24 2008-06-12 Shell Internationale Research Maatschappij B.V. Method of determining a fluid inflow profile of wellbore
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BR112012016256A2 (pt) * 2009-12-31 2016-05-17 Prad Res & Dev Ltd métiodo para determinação de um perfil de influxo e parâmetros de uma área em torno do poço em um poço de múltipla zonas

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Publication number Publication date
RU2474687C1 (ru) 2013-02-10
EP2772610A1 (fr) 2014-09-03
WO2013062446A1 (fr) 2013-05-02
EP2772610A4 (fr) 2016-01-27
US20140288836A1 (en) 2014-09-25

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