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WO1983000743A1 - Procede et dispositif de mesure de l'injection ou de la production de profils d'ecoulement pour des fluides visqueux - Google Patents

Procede et dispositif de mesure de l'injection ou de la production de profils d'ecoulement pour des fluides visqueux Download PDF

Info

Publication number
WO1983000743A1
WO1983000743A1 PCT/US1981/001160 US8101160W WO8300743A1 WO 1983000743 A1 WO1983000743 A1 WO 1983000743A1 US 8101160 W US8101160 W US 8101160W WO 8300743 A1 WO8300743 A1 WO 8300743A1
Authority
WO
WIPO (PCT)
Prior art keywords
tracer
fluid
wellbore
tool
newtonian
Prior art date
Application number
PCT/US1981/001160
Other languages
English (en)
Inventor
Production Research Company Exxon
Original Assignee
Bragg, James, R.
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 Bragg, James, R. filed Critical Bragg, James, R.
Priority to EP19810902518 priority Critical patent/EP0088749A4/fr
Priority to GB08300963A priority patent/GB2116706A/en
Priority to PCT/US1981/001160 priority patent/WO1983000743A1/fr
Priority to DE813152941T priority patent/DE3152941T1/de
Publication of WO1983000743A1 publication Critical patent/WO1983000743A1/fr
Priority to NO831467A priority patent/NO831467L/no

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
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/11—Locating fluid leaks, intrusions or movements using tracers; using radioactivity
    • E21B47/111—Locating fluid leaks, intrusions or movements using tracers; using radioactivity using radioactivity
    • 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
    • E21B47/11—Locating fluid leaks, intrusions or movements using tracers; using radioactivity

Definitions

  • This invention relates to a method and apparatus for obtaining information from a borehole.
  • this invention relates to a method and apparatus for measuring the fluid flow profile in a wellbore penetrating a petroleum reservoir.
  • Crucial information for proper planning of enhanced oil recovery operations includes the vertical conformity of the producing formations as well as their horizontal permeability and uniformity. This information is often obtained by an evaluation of the direction and speed of formation fluid flow by a borehole in the field. By obtaining such information at a sufficient number of boreholes throughout a field, a mapping of the total flow throughout a reservoir may be constructed to help plan the injection of chemicals or water in the enhanced oil recovery process.
  • an injection well is cased and the casing perforated at the levels of those zones into which fluid is to be injected. As fluid is pumped down the injection well, varying proportions of the fluid pass through the perforations into the different zones. The patterns of fluid flow into the various zones, including the proportion of fluid passing into each zone, are affected by the permeabilities of the various zones.
  • spinner surveys which utilize a spinner rotor in the logging tool to detect flow can be used when the fluid flow rate is high.
  • An example of a spinner flow meter is the Schlumberger Production Combination Tool, described in the publication "Schlumberger Engineered Production Services” published by Schlumberger Well Services of Houston, Texas.
  • spinner survey tools currently available are often ineffective at the low flow rates normally encountered in wells containing viscous fluids. For example, in many wells the maximum injection rate per foot of reservoir interval flooded with viscous fluids is 5 barrels per day.
  • the maximum flow rate in casing above the zone, prior to any fluid entering the reservoir is 100 barrels per day.
  • the logging tool To accurately detect fluid loss to the reservoir zone, the logging tool must be able to detect a difference in flow rate of 5 barrels per day over a vertical distance within the wellbore of 1 foot. This is equivalent to a change in fluid velocity of approximately 0.16 ft/min if the hole diameter is 5 inches and tool outer diameter is 1.5 inches.
  • Conventional spinner surveys are simply not sensitive enough to detect such low flow rates.
  • a logging tool commonly used to measure fluid flow profiles in low flow rate wells is the radioactive tracer flow logging tool.
  • This is a very old and well known device.
  • U.S. 2,453,456 to R. G. Piety on November 9, 1948 describes one of the earlier such radioactive tracer flow logging tools.
  • two or more radioactive detectors are commonly suspended in a wellbore in a fixed, spaced relationship.
  • a sample of radioactive material (often Iodine 131) is injected into the flowing wellbore fluid at a fixed point above the uppermost detector, and the arrival time of the radioactive sample at each of the detectors in the string is recorded. If a large amount of tracer is flowing into the reservoir, differences will be detected in radioactivity level between the two detectors. Conversely, if little tracer is flowing into the reservoir, there will be little difference in radioactivity level between the two detectors. From this information, the flow rate of the radioactive sample between detectors can be calculated to generate an injection profile.
  • a current exacple of a radioactive tracer flow logging tool is the Nuclear Flolog (TM) or Tracerlog (TM) offered by Dresser Atlas.
  • TM Nuclear Flolog
  • TM Tracerlog
  • the Dresser Atlas tool is briefly described in a brochure entitled “Production Services” published in January, 1981 (reference number 9307) by Dresser Atlas, Dresser Industries, Inc.
  • an improved method and apparatus for conducting radioactive flow logging in non-Newtonian fluids comprises reducing the tracer injection velocity, compared to that required for Newtonian fluids, so that the tracer material is optimally positioned in substantially the center of the annular region of flowing non- Newtonian fluid between the tool and the wellbore casing. This may be accomplished by increasing the size of the tracer ejection ports, or by increasing the number of injection ports, or both.
  • the invention is based on the fact that the velocity distribution profile for non-Newtonian fluids is significantly different than the profile for Newtonian fluids.
  • FIGURE 1 schematically illustrates a radioactive flow logging tool positioned adjacent to a perforated casing interval.
  • FIGURE 2 is a schematic representation of the fluid rheology on the velocity profile in a logging tool/casing annulus.
  • the present invention is an improved method and apparatus for generating an injection profile for non-Newtonian fluids flowing in a wellbore.
  • the invention resides in a reduction of the ejection velocity of a radioactive tracer just sufficiently to place the tracer in substantially the center of the annular space containing flowing viscous wellbore fluids.
  • FIGURE 1 a radioactive tracer flow logging tool 11 is schematically illustrated. The particular logging tool 11 is shown being used to measure injection profiles over an open hole completion interval, although obviously this is not a limiting factor.
  • the tool 11 is shown suspended in a cased wellbore 12 through packer 13 from the surface by means of a wireline 14, and extends into an open hole completion in a reservoir 20 having a permeable wall 15.
  • the tool 11 comprises two gamma detectors 16 and 17 in a vertically spaced relationship and radioactive ejector assembly 18 having ejector ports 19.
  • Ejector assembly 18 contains a suitable radioactive dye, such as Iodine 131, which may be ejected by means of a suitable pump from the tool via ports 19.
  • the general operation of the detectors and the ejector assembly is known, for example the Dresser Atlas Flolog (TM) and will not be further described.
  • the present invention may also be applied to other logging tools having one or more radioactive tracer ejectors and having either one or two or more radiation detectors. Moreover, the present invention may be applied whether or not the tool is stationary, or moved up or down, to detect fluid flow following tracer injection (eg., the so-called "logging up” technique).
  • the tool may be centralized or decentralized. However, if decentralized, the radioactive tracer ejector must be directed toward the center of the wellbore. Conventionally, it has always been desired to eject the radioactive tracer at a maximum possible velocity in order to obtain increased dispersion. However, when ejecting tracer into a viscous non-Newtonian fluid, it has now been discovered that this gives completely undesirable results.
  • the tracer material enters the viscous fluid as a discrete "blob" that is propelled into the annulus without dispersing into the flowing wellbore fluids and onto the casing wall where the fluid velocity is significantly lower (near zero) than the average fluid velocity in the annulus.
  • the ejected tracer material remains undispersed, even though it passes through an annular region of high, velocity ordinarily sufficient to cause dispersion for Newtonian fluids. Ejection of tracers into the wellbore under these conditions causes the flow rate in the flowing non-Newtonian fluid, as measured by relative movement past two detectors, to be much too low.
  • the present invention is for use in non-Newtonian fluids and requires that the tracer material be ejected at a low velocity compared to the ejection velocity into Newtonian fluids, such as brines.
  • the ejector 18 is so constructed and arranged as to result in a tracer ejection velocity which is just sufficient to place tracer material substantially in the center of the annular region between the tool 11 and the open hole wall 15.
  • the ejection velocity will preferably be at least 25% less than the ejection velocity into a Newtonian fluid flowing at the same rate as said given rate.
  • a Newtonian fluid is one whose viscosity does not vary with shear rate, while a non-Newtonian fluid varies with shear. Most enhanced oil recovery solutions exhibit non-Newtonian behavior.
  • the ejector assembly 18 may specifically be adapted to achieve the required velocity by: (1) increasing the size of the ejector ports 19, to preferably at least 25% greater cross- sectional area than conventionally used for Newtonian fluids; (2) increasing the number of ejector ports 19, preferably using twice as many ports as for Newtonian fluids; and/or (3) reducing the distance between the ejector assembly 18 and the first gamma detector 16, preferably reducing such distance to at least less than one-half (1/2) of the conventional distance.
  • Fluid flow rates of 100, 200, and 300 barrels per day of the viscous biopolymer solution were maintained in the pipe during the tests. It was visually observed that, regardless of the flow rate, ejected material was not dispersed in the flowing fluid, and in most cases the ejected tracer moved as a discrete volume (or "blob") through the annular region of high velocity to the wall of the pipe where it flowed at a significantly lower velocity (near zero) than the average fluid velocity.
  • FIG. 2 A better understanding of the present invention may be obtained by referring to Figure 2.
  • the tool 11 is schematically illustrated in the center of a wellbore.
  • the velocity distribution of a Newtonian brine is illustrated as compared to a pseudo plastic xanthamonas biopolymer solution (a non-Newtonian fluid).
  • a biopolymer solution such as is the one previously described having a viscosity of 30 centipoise, would exhibit the non- Newtonian velocity distribution.
  • R t is the tool radius
  • R mv is the radius of the tool to the center of the annular space between the wellbore and the tool (or to the point of maximum velocity)
  • R c is the radius of the wellbore (the subscript c standing for casing, although the invention does not require a cased wellbore)
  • V z stands for the velocity distribution in the axial direction.
  • the velocity distribution for a non- Newtonian fluid is substantially different than that for a Newtonian fluid.
  • the distribution indicates the critical importance of properly ejecting the tracer material at a velocity which places the material at about R mv .
  • the test suggested that in order to accurately measure a flow profile for flowing viscous fluids, the tracer ejection velocity must be adjusted so that the tracer will move closer to point "B" in Figure 2. Point “A” and point “C” have too low a velocity to carry the tracer material past the detectors. Moreover, and significantly, simply causing the ejected tracer material to pass through R mv (or point "B") will not achieve the benefits of the present invention.
  • Velocity profiles for Newtonian or non-Newtonian can be calculated from theory. Different components of the fluid velocity can be experimentally measured if the tracer is placed at different radial distances from the wellbore centerline. By adjusting the tracer ejection to place the tracer at specific radial distances, specific velocity components can be measured. Of special interest is the maximum fluid velocity at point "B" of Figure 2, which can be correlated with the average fluid velocity for any fluid reology. Appropriate fluid flow theory is found in A. G. Fredrickson and R. B. Bird, "Non-Newtonian Flow in Annuli", Industrial and Engineering Chemistry, volume 50, number 3, March 1958 (pages 347-352).
  • the tracer ejection velocity In order to accurately measure the flow rate for viscous fluids, the tracer ejection velocity must be reduced just sufficiently so that the tracer material moves preferably to the center of the tool/casing annulus. While too high a velocity will place the tracer at the casing wall, which is a low velocity region; too low a velocity will place the tracer just next to the tool, another low velocity region.
  • it was experimentally determined that satisfactory velocities could be achieved by using three 0.032 inch diameter ejector ports, instead of one 0.025 inch port. The distance from the uppermost detector to the ejector ports was 14 inches, rather than 4.5 feet. Thus, placement of the tracer as desired can be achieved by a number of means.
  • the volume of tracer ejected for a given number of ejection ports of fixed diameter can be varied, or the number of ports or the diameter of the ports can be varied for a fixed volume of tracer ejected.
  • Multiple ports having different diameters can be used to place shots at different radial distances from the wellbore centerline, thus allowing simultaneous measurement of different velocity components.
  • the ejector ports may be placed closer to the uppermost detector in order to more accurately and quickly detect the tracer velocity at low flow rates.
  • the amount of fluid flowing from the wellbore into a given vertical interval of reservoir is measured by the following steps: (1) placing the tool 11 at a stationary position at a known depth; (2) ejecting a volume of radioactive tracer (usually radioactive iodine, iodine 131, dissolved in water) at a low rate just sufficient to place the tracer in substantially the center of the annular region between the tool 11 and the wall 15; (3) monitoring the radiation intensity moving past the two detectors 16 and 17 placed a known distance apart; (4) using the computer travel time of tracer between detectors to determine fluid velocity; (5) from the measured fluid velocity and known dimensions of of the wellbore and logging tool, computing the fluid flow rate; (6) repeating steps (1) to (5) at various depths over which fluid flow into the formation is being measured; (7) by determining differences in fluid flow rates at various depths determining the amount of fluid entering the formation over various depth intervals.
  • radioactive tracer usually radioactive iodine, iodine 131, dissolved in water

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  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Geophysics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Measuring Volume Flow (AREA)

Abstract

Procédé et dispositif (11) de carottage par traceur radioactif pour déterminer les profils d'écoulement pour des fluides non-Newtoniens s'écoulant dans un forage de puits (12). Le traceur radioactif est éjecté à une vitesse inférieure à la vitesse des fluides Newtoniens. La vitesse d'éjection est tout juste suffisante pour placer le traceur sensiblement dans le centre de la région annulaire entre l'outil (11) et le forage de puits (12).
PCT/US1981/001160 1981-08-27 1981-08-27 Procede et dispositif de mesure de l'injection ou de la production de profils d'ecoulement pour des fluides visqueux WO1983000743A1 (fr)

Priority Applications (5)

Application Number Priority Date Filing Date Title
EP19810902518 EP0088749A4 (fr) 1981-08-27 1981-08-27 Procede et dispositif de mesure de l'injection ou de la production de profils d'ecoulement pour des fluides visqueux.
GB08300963A GB2116706A (en) 1981-08-27 1981-08-27 Method and apparatus for measuring injection or production flow profiles for viscous fluids
PCT/US1981/001160 WO1983000743A1 (fr) 1981-08-27 1981-08-27 Procede et dispositif de mesure de l'injection ou de la production de profils d'ecoulement pour des fluides visqueux
DE813152941T DE3152941T1 (de) 1981-08-27 1981-08-27 Verfahren und vorrichtung zum messen von injektions- oder foerderstroemungsprofilen fuer viskose fluide
NO831467A NO831467L (no) 1981-08-27 1983-04-26 Fremgangsmaate og apparat for maaling av injeksjon eller produksjons-stroemningsprofiler for viskoese fluider

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US1981/001160 WO1983000743A1 (fr) 1981-08-27 1981-08-27 Procede et dispositif de mesure de l'injection ou de la production de profils d'ecoulement pour des fluides visqueux

Publications (1)

Publication Number Publication Date
WO1983000743A1 true WO1983000743A1 (fr) 1983-03-03

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PCT/US1981/001160 WO1983000743A1 (fr) 1981-08-27 1981-08-27 Procede et dispositif de mesure de l'injection ou de la production de profils d'ecoulement pour des fluides visqueux

Country Status (5)

Country Link
EP (1) EP0088749A4 (fr)
DE (1) DE3152941T1 (fr)
GB (1) GB2116706A (fr)
NO (1) NO831467L (fr)
WO (1) WO1983000743A1 (fr)

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4861986A (en) * 1988-03-07 1989-08-29 Halliburton Logging Services, Inc. Tracer injection method
CN113047826A (zh) * 2021-04-13 2021-06-29 西南石油大学 一种智能可释放示踪剂产液剖面测试实验装置及方法
US11326440B2 (en) 2019-09-18 2022-05-10 Exxonmobil Upstream Research Company Instrumented couplings

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2232241B (en) * 1989-05-27 1993-06-02 Schlumberger Ltd Method for determining dynamic flow characteristics of multiphase flows
CN112878917B (zh) * 2021-01-19 2021-11-09 中国石油大学(北京) 自适应切削齿及pdc钻头

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2453456A (en) * 1945-03-07 1948-11-09 Phillips Petroleum Co Instrument for measuring water flow in wells
US3395277A (en) * 1964-05-21 1968-07-30 Cardinal Surveys Company Borehole fluid flow measuring device using radioactive tracer means
US3406284A (en) * 1964-08-19 1968-10-15 Cardinal Surveys Company Method of determining direction and velocities of fluid flow into a well by means ofradioactive tracer introduction into the well
US4071756A (en) * 1976-05-10 1978-01-31 Continental Oil Company Determination of residual oil in a subterranean formation
US4166216A (en) * 1977-09-23 1979-08-28 Schlumberger Technology Corporation Methods and apparatus for determining dynamic flow characteristics of production fluids in a well bore
US4166215A (en) * 1977-09-23 1979-08-28 Schlumberger Technology Corporation Methods and apparatus for determining dynamic flow characteristics of production fluids in a well bore

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2453456A (en) * 1945-03-07 1948-11-09 Phillips Petroleum Co Instrument for measuring water flow in wells
US3395277A (en) * 1964-05-21 1968-07-30 Cardinal Surveys Company Borehole fluid flow measuring device using radioactive tracer means
US3406284A (en) * 1964-08-19 1968-10-15 Cardinal Surveys Company Method of determining direction and velocities of fluid flow into a well by means ofradioactive tracer introduction into the well
US4071756A (en) * 1976-05-10 1978-01-31 Continental Oil Company Determination of residual oil in a subterranean formation
US4166216A (en) * 1977-09-23 1979-08-28 Schlumberger Technology Corporation Methods and apparatus for determining dynamic flow characteristics of production fluids in a well bore
US4166215A (en) * 1977-09-23 1979-08-28 Schlumberger Technology Corporation Methods and apparatus for determining dynamic flow characteristics of production fluids in a well bore

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4861986A (en) * 1988-03-07 1989-08-29 Halliburton Logging Services, Inc. Tracer injection method
US11326440B2 (en) 2019-09-18 2022-05-10 Exxonmobil Upstream Research Company Instrumented couplings
CN113047826A (zh) * 2021-04-13 2021-06-29 西南石油大学 一种智能可释放示踪剂产液剖面测试实验装置及方法

Also Published As

Publication number Publication date
GB2116706A (en) 1983-09-28
GB8300963D0 (en) 1983-02-16
EP0088749A4 (fr) 1985-07-30
NO831467L (no) 1983-04-26
EP0088749A1 (fr) 1983-09-21
DE3152941T1 (de) 1983-09-08

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