WO1999045236A1 - Procede et appareil pour tester une formation - Google Patents

Procede et appareil pour tester une formation Download PDF

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Publication number
WO1999045236A1
WO1999045236A1 PCT/US1999/004596 US9904596W WO9945236A1 WO 1999045236 A1 WO1999045236 A1 WO 1999045236A1 US 9904596 W US9904596 W US 9904596W WO 9945236 A1 WO9945236 A1 WO 9945236A1
Authority
WO
WIPO (PCT)
Prior art keywords
formation
well bore
drill string
fluid
test
Prior art date
Application number
PCT/US1999/004596
Other languages
English (en)
Inventor
Per Erik Berger
Nils Reimers
Don Thorton Macune
Original Assignee
Baker Hughes Incorporated
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
Priority claimed from US09/088,208 external-priority patent/US6047239A/en
Application filed by Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Priority to DE69928780T priority Critical patent/DE69928780T2/de
Priority to AU28892/99A priority patent/AU2889299A/en
Priority to EP99909756A priority patent/EP1064452B1/fr
Publication of WO1999045236A1 publication Critical patent/WO1999045236A1/fr
Priority to NO20004426A priority patent/NO320901B1/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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/124—Units with longitudinally-spaced plugs for isolating the intermediate space
    • E21B33/1243—Units with longitudinally-spaced plugs for isolating the intermediate space with inflatable sleeves
    • 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
    • E21B49/008—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 by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor
    • 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
    • E21B49/02—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 by mechanically taking samples of the soil
    • E21B49/06—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 by mechanically taking samples of the soil using side-wall drilling tools pressing or scrapers
    • 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
    • E21B49/10—Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
    • 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
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/22—Fuzzy logic, artificial intelligence, neural networks or the like

Definitions

  • this invention relates to a method and apparatus for isolating a downhole reservoir, and testing the reservoir formation and
  • hydrocarbon reserves numerous subterranean reservoirs and formations will be encountered.
  • information about the formations such as whether
  • the reservoirs contain hydrocarbons, logging devices have been incorporated into drill
  • MWD drilling systems
  • the MWD systems can generate data which includes
  • a common telemetry method is the mud-pulsed system, an example of
  • One type of post-drilling test involves producing fluid from the reservoir
  • This sequence may be repeated several times at several different reservoirs
  • a wireline is often used to lower the test tool into the well
  • the test tool sometimes utilizes packers for isolating the reservoir. Numerous
  • test assembly or alternatively, provide for data transmission from the test assembly.
  • Some of those designs include signaling from the surface of the Earth with pressure pulses,
  • a wire line can be lowered
  • the amount of time and money required for retrieving the 3 drill string and running a second test rig into the hole is significant. Further, if the hole
  • the density of the drilling fluid is
  • the formation pressure as the drill bit penetrates the formation is the formation pressure as the drill bit penetrates the formation.
  • mud may be maintained at too high or too low a density for maximum efficiency
  • bore hole has been drilled into the reservoir, without removal of the drill string.
  • a formation testing method and a test apparatus are disclosed.
  • the test apparatus is mounted on a work string for use in a well bore filled with fluid. It can be
  • the work string may be one capable of going
  • the work string must be
  • the work string can contain a Measurement While Drilling system and a drill
  • the formation test apparatus may include at least one
  • expandable packer or other extendible structure that can expand or extend to contact the wall of the well bore; means for moving fluid, such as a pump, for taking in
  • test apparatus will also contain control means, for controlling the various valves or pumps which are
  • the tool must have a communication system
  • the method involves drilling or re-entering a bore hole and selecting an
  • extendible element such as a packer or test probe, is set against the wall of the bore
  • the drill string can continue rotating and advancing while the sleeve is held stationary during performance of the test
  • the well bore fluid primarily drilling mud, may then be withdrawn from the
  • intermediate annulus stabilizes may then be measured, it will correspond to the formation pressure Pressure
  • Pressure can also be applied to fracture the formation, or to
  • Additional extendible elements may also be
  • a piston or other test probe can be extended from the test apparatus to contact the bore hole wall in a sealing relationship, or some other
  • expandable element can be extended to create a zone from which essentially pristine
  • formation fluid can be withdrawn This could also be accomplished by extending a
  • the test tool to contact the bore hole wall, thereby exposing a sample port to the formation fluid Regardless of the apparatus used, the goal is to establish a zone of
  • extendible elastomeric element can retract within a recession in the tool, or it can
  • a sleeve or some other type of cover may be protected by a sleeve or some other type of cover.
  • apparatus can contain a resistivity sensor for measuring the resistivity of the well bore
  • test chambers within the test apparatus.
  • test chambers can be maintained at atmospheric pressure while the work string is being
  • a test chamber can be selectively placed in fluid communication with the test port. Since the
  • formation fluid will be at much higher pressure than atmospheric, the formation fluid
  • test chamber will flow into the test chamber.
  • test chambers can be used to measure the test chamber.
  • apparatus has contained therein a drilling fluid return flow passageway for allowing
  • At least one pump which can be a Venturi pump or any other suitable type of pump, for preventing overpressurization in an intermediate annulus.
  • the drilling fluid pump To prevent overpressurization, the drilling fluid is pumped down the
  • the device may also include a circulation valve, for opening and closing the
  • a shunt valve can be located in the work string and
  • valves can be used in operating the test apparatus as a down hole blow ⁇
  • the method includes the steps of setting the expandable packers, and then positioning the circulating valve in the closed position.
  • the packers are set at a position that is above the influx zone so that the influx zone is
  • resistivity sensors with the MWD system to allow for real time data transmission of
  • the packers can be set multiple times, so that testing of several zones is
  • the high pressure is contained within the lower part of the well bore, significantly reducing risk of being exposed to these pressures at surface. Also, by
  • FIG. 1 is a partial section view of the apparatus of the present invention as it
  • Figure 2 is a perspective view of one embodiment of the present invention
  • Figure 3 is a section view of the embodiment of the present invention shown in
  • Figure 4 is a section view of the embodiment shown in Figure 3, with the
  • Figure 5 is a section view of the embodiment shown in Figure 3, illustrating the flow path of drilling fluid
  • Figure 6 is a section view of a circulation valve and a shunt valve which can be
  • Figure 7 is a section view of another embodiment of the present invention, showing the use of a centrifugal pump to drain the intermediate annulus;
  • FIG. 8 is a schematic of the control system and the communication system
  • Figure 9 is a partial section view of the apparatus of the present invention.
  • Figure 10 is a section view of the apparatus of the present invention, showing
  • Figure 11 is a perspective view of the apparatus of the present invention.
  • Figure 12 is a section view of the embodiment shown in Figure 11.
  • the drilling rig 2 has a work string 6, which in the embodiment shown is a drill string.
  • tubing as well as coiled tubing or other small diameter work string such as snubbing
  • Figure 1 depicts the drilling rig 2 positioned on a drill ship S with a riser extending from the drilling ship S to the sea floor F.
  • the work string 6 can have a downhole drill motor 10.
  • the sensors 14 sense down hole characteristics of the well bore, the bit, and the reservoir, with such sensors being well known in the art.
  • the bottom hole assembly
  • one or more subterranean are described in greater detail hereinafter. As can be seen, one or more subterranean
  • reservoirs 18 are intersected by the well bore 4.
  • Figure 2 shows one embodiment of the formation test apparatus 16 in a
  • Stabilizer ribs 20 are also shown between the packers 24, 26,
  • one embodiment of the formation test apparatus 16 is
  • test apparatus 16 contains an upper
  • the packers 24, 26 can be expandable by any means known in
  • Inflatable packer means are well known in the art, with inflation being
  • covers for the expandable packer elements may also be included to shield the packer
  • a high pressure drilling fluid passageway 27 is formed between the longitudinal
  • passageway 28 conducts fluid from a first port of the control valve 30 to the packers 12
  • the inflation fluid passageway 28 branches off into a first branch 28 A that is connected to the inflatable packer 26 and a second branch 28B that is connected to the
  • a second port of the control valve 30 is connected to a drive
  • a third port of the control valve 30 is connected to a low pressure passageway 31, which leads to one of the return flow passageways 36.
  • the low pressure passageway 31 could lead to a Venturi pump 38 or to a centrifugal
  • control elements to be discussed are operable by a downhole electronic control system 100 seen in Fig. 8, which will be discussed in greater detail hereinafter.
  • control valve 30 can be selectively positioned to pressurize the cylinder 35 or the packers 24, 26 with high pressure drilling fluid
  • control valve 30 can lock the extended element in place. It
  • control valve 30 can be selectively positioned to place the
  • pressure passageway 31 can be connected to a suction means, such as a pump, to draw
  • an accurate volume within the intermediate annulus 33 may be calculated, which is useful in pressure testing techniques.
  • the test apparatus 16 also contains at least one fluid sensor system 46 for
  • the sensor system 46 can
  • a resistivity sensor for determining the resistivity of the fluid.
  • a dielectric for determining the resistivity of the fluid.
  • a pressure sensor for sensing the fluid pressure may be included.
  • Other types of sensors which can be
  • element can be provided on the outer face 47 of the piston 45 to ensure that the sample
  • a pump inlet passageway 40B connects the
  • the pump 53 can be a centrifugal
  • wheel 55 can be driven by flow through a bypass passageway 84 between the longitudinal bore 7 and the return flow passageway 36. .
  • the pump 53 can
  • a pump outlet passageway 40C is connected 14 between the outlet of the pump 53 and the sensor system 46.
  • passageway 40D is connected between the sensor 46 and the return flow passageway 36.
  • the passageway 40D has therein a valve 48 for opening and closing the
  • passageway 40D As seen in Figure 4, there can be a sample collection passageway 40E which
  • the passageway 40E leads to the adjustable choke means 74 and to the sample chamber 56, for collecting a sample.
  • 40E has therein a chamber inlet valve 58 for opening and closing the entry into the
  • the sample chamber 56 can have a movable baffle 72 for
  • An outlet passage from the sample chamber 56 is also provided, with a chamber outlet valve 62 therein, which can be a manual valve.
  • a sample expulsion valve 60 which can be a manual valve.
  • valves 60 and 62 are connected to external ports (not shown) on the
  • valves 62 and 60 allow for the removal of the sample fluid once the work
  • sample chamber 56 can be made wireline retrievable, by means well known in the art
  • a Venturi pump 38 is used to prevent overpressurization of the intermediate annulus 33.
  • the drill string 6 contains several drilling fluid return flow passageways 36 for
  • a Venturi pump 38 is provided
  • Venturi pump 38 could be connected to the low
  • FIG. 2 Several return flow passageways can be provided, as shown in Fig. 2.
  • One return flow passageway 36 is used to operate the Venturi pump 38.
  • Fig. 3 Several return flow passageways can be provided, as shown in Fig. 2.
  • the return flow passageway 36 has a generally constant internal diameter
  • This low pressure zone communicates with the intermediate annulus 33 16 through the draw down passageway 41, preventing any overpressurization of the intermediate annulus 33.
  • the return flow passageway 36 also contains an inlet valve 39 and an outlet
  • valve 80 for opening and closing the return flow passageway 36, so that the upper
  • annulus 32 can be isolated from the lower annulus 34.
  • the bypass passageway 84
  • valve 92 located in the shunt passageway 94, for allowing flow from the inner bore 7 of the work string 6 to the upper annulus 32.
  • the remainder of the formation tester is
  • the circulation valve 90 and the shunt valve 92 are operatively associated with
  • FIG. 7 illustrates an alternative means of performing the functions performed
  • the centrifugal pump 53 can have its inlet connected to the
  • valve 57 and a sample inlet valve 59 are provided in the pump inlet passageway to the
  • the pump inlet passageway is also
  • pump 53 or another similar pump, to withdraw fluid from the intermediate annulus 33 17 through valve 57, to withdraw a sample of formation fluid directly from the formation through valve 59, or to pump down the cylinder 35 or the packers 24, 26.
  • Figure 7 also shows a means of applying fluid pressure to the formation, either
  • applying this fluid pressure may be either to fracture the formation, or to perform a
  • pump inlet valve 120 can be rotated clockwise a quarter turn by the control system 100
  • the pump outlet valve 122 can be positioned as shown to align the pump outlet with the return flow
  • pump outlet valve 122 can be rotated clockwise a quarter turn by the control system
  • inlet valve 120 aligned to connect the pump inlet with the return flow passageway 36 and the pump outlet valve 122 aligned to connect the pump outlet with the low
  • the pump 53 can be operated to draw fluid from the return
  • Pressurization of the formation can be through the extendible piston 45, with the
  • sample inlet valve 59 open and the draw down valve 57 shut.
  • pressurization of the formation can be through the annulus 33, with the sample inlet
  • valve 59 shut and the draw down valve 57 open.
  • the invention includes use of a control system 100 for
  • the control system 100 is capable of processing the sensor information
  • transmission energy could be used such as mud pulse, acoustical, optical, or electro ⁇
  • the communications interface 104 can be powered by a downhole electrical
  • the power source 106 also powers the flow line sensor system 46,
  • microprocessor/controller 102 controls the various valves and pumps.
  • Communication with the surface of the Earth can be effected via the work string 6 in the form of pressure pulses or other means, as is well known in the art.
  • the surface computer 110 for interpretation and display.
  • Command signals may be sent down the fluid column by the communications
  • controller 102 will then signal the appropriate valves and pumps for operation as
  • the down hole microprocessor/controller 102 can also contain a pre-
  • down hole data such as pressure, resistivity, flow rate, viscosity, density, spectral
  • microprocessor/controller would automatically send command signals via the control
  • One set of packers can be used to have two or more sets of extendible packers, with associated test apparatus 16 therebetween.
  • One set of packers can be used to have two or more sets of extendible packers, with associated test apparatus 16 therebetween.
  • One set of packers can be used to have two or more sets of extendible packers, with associated test apparatus 16 therebetween.
  • One set of packers can be used to have two or more sets of extendible packers, with associated test apparatus 16 therebetween.
  • the apparatus can then be used to pump formation fluid from the first formation into
  • This function can be performed either from one annulus 33 at the first formation to another annulus 33 at the second formation, using the extended
  • the pump 53 can be operated to pump formation fluid
  • return flow passageway 36 can extend through the work string 6 to the second set of test apparatus 16 at the second formation.
  • the second sample inlet valve 59 can
  • test apparatus 16 In the second set of test apparatus 16, the pump inlet and
  • outlet valves 120, 122 can be rotated clockwise a quarter turn to allow the second
  • Variations of this process can be used to pump formation fluid from one or more
  • a formation coring device 124 can be extended into the formation by equipment identical to the equipment described
  • the coring device 124 can be rotated by a turbine
  • the outlet of the turbine 126 can be via an outlet passageway 130 and a turbine
  • control valve 132 which is controlled by the control system 100.
  • the coring device 124 is extended and rotated to obtain a pristine core
  • the core sample can then be withdrawn into the work string
  • the apparatus of the present invention can be modified
  • 216 can be located on the side of the test tool opposite the test port, for the purpose of
  • Upper stabilizers 220 and lower stabilizers 222 can be
  • Figure 12 is a longitudinal section view of the embodiment of the test apparatus
  • non-rotating sleeve 200 and the work string is sealed by upper rotating seals 202 and
  • a plurality of other rotating seals 206, 208, 210, 212, 214 21 can be used to seal fluid passageways which lead from the inner bore 7 of the work
  • the non-rotating sleeve 200 is shorter than the recess into which
  • a spring 223 is provided between the
  • One or more extendible stabilizer blades or ribs 216 can be provided on the
  • non-rotating sleeve 200 on the side opposite the test piston 45 or the test port rib 20.
  • a remotely operated rib extension valve 218 can be provided in a passageway 219
  • extendible rib 216 is located. Opening of the rib extension valve 218 introduces
  • extendible rib 216 extendible rib 216.
  • a spring or other biasing element known in the art not limited to, a spring or other biasing element known in the art (not shown).
  • the formation tester 16 is positioned adjacent a selected formation
  • valves 39 and 80 are
  • control valve 30 is positioned to align the high pressure passageway 27 with the inflation fluid
  • passageways 28A, 28B, and drilling fluid is allowed to flow into the packers 24, 26
  • extension of the packers 24, 26 can be used to stop
  • the sleeve 200 is essentially
  • another expandable element such as the piston 45 can be extended to 23 contact the wall of the well bore, by appropriate positioning of the control valve 30.
  • the extendible rib 216 alone can be used to hold the non- rotating sleeve 200 stationary.
  • the upper packer element 24 can be wider than the lower packer 26, thereby
  • the lower packer 26 will set first. This can prevent
  • the Venturi pump 38 can then be used to prevent overpressurization in the
  • valve 41 in the embodiment shown in Fig. 3, or by opening the valves 82, 57, and 48 in the embodiment shown in Fig. 7.
  • the resistivity and the dielectric constant of the fluid being drained can be constantly monitored by the sensor
  • the data so measured can be processed down hole and transmitted up-hole
  • the operator may choose to continue circulation in order to
  • sample chamber 56 The sample chamber may be empty or filled with some 24 compressible fluid. If the sample chamber 56 is empty and at atmospheric conditions,
  • choke 74 is included for regulating the flow into the chamber 56. The purpose of the
  • adjustable choke 74 is to control the change in pressure across the packers when the sample chamber is opened. If the choke 74 were not present, the packer seal might be
  • valve 58 Another purpose of the choke 74 would be to control the process of flowing
  • valve 58 can again be closed
  • multiple pressure build-up tests can be performed by repeatedly pumping down the intermediate annulus 33, or by repeatedly filling additional sample chambers.
  • Formation permeability may be calculated by later analyzing the pressure versus time
  • the data may be analyzed
  • the sample chamber 56 could be used in
  • the packers 24, 26 can be deflated and withdrawn, thereby returning
  • test apparatus 16 to a standby mode. If used, the piston 45 can be withdrawn.
  • packers 24, 26 can be deflated by positioning the control valve 30 to align the low
  • the piston 45 can be 25 withdrawn by positioning the control valve 30 to align the low pressure passageway 31 with the cylinder passageway 29.
  • the Venturi pump 38 or the centrifugal pump 53 can be used.
  • the sample chamber 56 can be separated from the work
  • a source of compressed air is attached to the expulsion valve 60.
  • baffle 72 toward the outlet valve 62, forcing the sample out of the sample chamber 56.
  • the sample chamber may be cleaned by refilling with water or solvent through the outlet valve 62, and cycling the baffle 72 with compressed air via the expulsion valve
  • the fluid can then be analyzed for hydrocarbon number distribution, bubble point
  • a sensor package can be associated with
  • the sample may be discharged downhole.
  • the packers 24, 26 are set so that an upper 32, a lower 34, and an
  • embodiments of extendible elements may also be used to determine formation pressure.
  • the method further includes the steps of adjusting the density of the drilling
  • the operator would continue drilling to a second subterranean horizon, and at
  • drilling of the bore hole may resume at the correct overbalance weight.
  • valves 39 and 48 may be monitored by opening valves 39 and 48 and closing valves 57, 59, 30, 82, and
  • the pressure in the upper annulus may be monitored while circulating directly to
  • internal diameter 7 of the drill string may be monitored during normal drilling by
  • the by-pass valve 82 with all other valves closed. Finally, the by-pass passageway 84 would allow the operator to circulate heavier density fluid in order to control the kick.
  • the inflatable packers 24, 26 are set at a position that is 27 above the influx zone so that the influx zone is isolated.
  • the heavier drilling fluid is

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  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Chemical & Material Sciences (AREA)
  • Analytical Chemistry (AREA)
  • Soil Sciences (AREA)
  • Earth Drilling (AREA)
  • Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
  • Sampling And Sample Adjustment (AREA)
  • Automatic Analysis And Handling Materials Therefor (AREA)

Abstract

L'invention concerne un procédé et un appareil permettant d'obtenir des échantillons d'une formation vierge ou de fluide d'une formation, à l'aide d'une colonne de production conçue pour effectuer d'autres travaux de fond, par exemple des sondages, des travaux de reconditionnement, ou des opérations de rentrée. Un élément extensible s'étend contre la paroi de ladite formation de manière à prélever un échantillon d'une formation vierge ou de fluide. Pendant que l'échantillonneur est en attente, cet élément extensible est rétracté à l'intérieur de la colonne de production, tout en restant protégé par une autre structure de toute détérioration que cet élément pourrait subir lors du fonctionnement de ladite colonne de production. L'appareil de cette invention est utilisé pour détecter ou échantillonner les conditions de fond tout en utilisant une colonne de production, les mesures ou prélèvements d'échantillons effectués pouvant ensuite servir à modifier les propriétés du fluide de travail sans que l'on ait à retirer ladite colonne de production du trou de sonde. Lorsque l'élément extensible se présente sous la forme d'un packer, l'appareil de cette invention peut être utilisé pour empêcher les secousses d'atteindre la surface, pour modifier la densité de la boue de forage, et pour continuer à faire fonctionner la colonne de production. Cet appareil de contrôle peut par ailleurs être monté sur un manchon coulissant non rotatif de cette colonne.
PCT/US1999/004596 1998-03-06 1999-03-03 Procede et appareil pour tester une formation WO1999045236A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
DE69928780T DE69928780T2 (de) 1998-03-06 1999-03-03 Verfahren und vorrichtung zum formationstesten
AU28892/99A AU2889299A (en) 1998-03-06 1999-03-03 Formation testing apparatus and method
EP99909756A EP1064452B1 (fr) 1998-03-06 1999-03-03 Procede et appareil pour tester une formation
NO20004426A NO320901B1 (no) 1998-03-06 2000-09-05 Fremgangsmate og apparat for formasjonsutproving med fluidoverforing mellom to formasjonssoner

Applications Claiming Priority (6)

Application Number Priority Date Filing Date Title
US7714498P 1998-03-06 1998-03-06
US60/077,144 1998-03-06
US09/088,208 1998-06-01
US09/088,208 US6047239A (en) 1995-03-31 1998-06-01 Formation testing apparatus and method
US22686599A 1999-01-07 1999-01-07
US09/226,865 1999-01-07

Publications (1)

Publication Number Publication Date
WO1999045236A1 true WO1999045236A1 (fr) 1999-09-10

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Application Number Title Priority Date Filing Date
PCT/US1999/004596 WO1999045236A1 (fr) 1998-03-06 1999-03-03 Procede et appareil pour tester une formation

Country Status (5)

Country Link
EP (1) EP1064452B1 (fr)
AU (1) AU2889299A (fr)
DE (1) DE69928780T2 (fr)
NO (1) NO320901B1 (fr)
WO (1) WO1999045236A1 (fr)

Cited By (15)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1096104A1 (fr) * 1999-10-26 2001-05-02 Halliburton Energy Services, Inc. Dispositif et procédé d'essai et de forage de puits
WO2001051768A2 (fr) * 2000-01-14 2001-07-19 Shell Internationale Research Maatschappij B.V. Systeme de diagraphie en cours de forage
US6581455B1 (en) * 1995-03-31 2003-06-24 Baker Hughes Incorporated Modified formation testing apparatus with borehole grippers and method of formation testing
US7134493B2 (en) 2001-03-09 2006-11-14 Shell Oil Company Logging system for use in a wellbore
AU2003279008B2 (en) * 2002-10-04 2007-04-19 Halliburton Energy Services, Inc. Well control using pressure while drilling measurements
US7207216B2 (en) 2000-11-01 2007-04-24 Baker Hughes Incorporated Hydraulic and mechanical noise isolation for improved formation testing
GB2453052A (en) * 2007-09-20 2009-03-25 Schlumberger Holdings Methods and apparatus for characterizing downhole fluids, and circulation pumps for use in such methods and apparatus
US8479810B2 (en) 2007-06-26 2013-07-09 Paul David Metcalfe Downhole apparatus
CN103306658A (zh) * 2013-07-01 2013-09-18 中国石油化工股份有限公司 逐级坐封多级分段压裂管柱及其使用方法
US9353606B2 (en) 2010-11-16 2016-05-31 Darcy Technologies Limited Downhole method and apparatus
CN107355195A (zh) * 2017-04-28 2017-11-17 北京捷威思特科技有限公司 地层测试取样双封隔器
CN109915130A (zh) * 2017-12-07 2019-06-21 中国石油天然气股份有限公司 一种试油装置及方法
EP3565953A4 (fr) * 2017-01-05 2020-08-05 General Electric Company Système et procédé de détection d'hydrocarbures dans une formation rocheuse souterraine
FR3102505A1 (fr) * 2019-10-24 2021-04-30 Burgeap Dispositif pour prélever du liquide dans un piézomètre
CN113686374A (zh) * 2021-09-03 2021-11-23 贝兹维仪器(苏州)有限公司 一种模拟钻井高频震动旋转的传感器测试装置

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US10570724B2 (en) 2016-09-23 2020-02-25 General Electric Company Sensing sub-assembly for use with a drilling assembly

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EP1096104A1 (fr) * 1999-10-26 2001-05-02 Halliburton Energy Services, Inc. Dispositif et procédé d'essai et de forage de puits
US6343650B1 (en) 1999-10-26 2002-02-05 Halliburton Energy Services, Inc. Test, drill and pull system and method of testing and drilling a well
WO2001051768A2 (fr) * 2000-01-14 2001-07-19 Shell Internationale Research Maatschappij B.V. Systeme de diagraphie en cours de forage
WO2001051768A3 (fr) * 2000-01-14 2002-07-04 Shell Int Research Systeme de diagraphie en cours de forage
US7207216B2 (en) 2000-11-01 2007-04-24 Baker Hughes Incorporated Hydraulic and mechanical noise isolation for improved formation testing
US7134493B2 (en) 2001-03-09 2006-11-14 Shell Oil Company Logging system for use in a wellbore
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US8555985B2 (en) 2007-06-26 2013-10-15 Paul David Metcalfe Permeability modification
US8479810B2 (en) 2007-06-26 2013-07-09 Paul David Metcalfe Downhole apparatus
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GB2453052B (en) * 2007-09-20 2010-03-17 Schlumberger Holdings Methods and apparatus for characterizing downhole fluids, and circulation pumps for use in such methods and apparatus
GB2453052A (en) * 2007-09-20 2009-03-25 Schlumberger Holdings Methods and apparatus for characterizing downhole fluids, and circulation pumps for use in such methods and apparatus
US9353606B2 (en) 2010-11-16 2016-05-31 Darcy Technologies Limited Downhole method and apparatus
US10337297B2 (en) 2010-11-16 2019-07-02 Halliburton Manufacturing And Services Limited Downhole method and apparatus
CN103306658A (zh) * 2013-07-01 2013-09-18 中国石油化工股份有限公司 逐级坐封多级分段压裂管柱及其使用方法
CN103306658B (zh) * 2013-07-01 2016-01-20 中国石油化工股份有限公司 逐级坐封多级分段压裂管柱及其使用方法
EP3565953A4 (fr) * 2017-01-05 2020-08-05 General Electric Company Système et procédé de détection d'hydrocarbures dans une formation rocheuse souterraine
CN107355195A (zh) * 2017-04-28 2017-11-17 北京捷威思特科技有限公司 地层测试取样双封隔器
CN109915130A (zh) * 2017-12-07 2019-06-21 中国石油天然气股份有限公司 一种试油装置及方法
FR3102505A1 (fr) * 2019-10-24 2021-04-30 Burgeap Dispositif pour prélever du liquide dans un piézomètre
CN113686374A (zh) * 2021-09-03 2021-11-23 贝兹维仪器(苏州)有限公司 一种模拟钻井高频震动旋转的传感器测试装置
CN113686374B (zh) * 2021-09-03 2023-11-17 贝兹维仪器(苏州)有限公司 一种模拟钻井高频震动旋转的传感器测试装置

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NO320901B1 (no) 2006-02-13
DE69928780D1 (de) 2006-01-12
EP1064452B1 (fr) 2005-12-07
AU2889299A (en) 1999-09-20
NO20004426L (no) 2000-11-01
NO20004426D0 (no) 2000-09-05
EP1064452A1 (fr) 2001-01-03

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