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WO1997008424A1 - Systeme d'outil de fond de puits - Google Patents

Systeme d'outil de fond de puits Download PDF

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Publication number
WO1997008424A1
WO1997008424A1 PCT/GB1996/002075 GB9602075W WO9708424A1 WO 1997008424 A1 WO1997008424 A1 WO 1997008424A1 GB 9602075 W GB9602075 W GB 9602075W WO 9708424 A1 WO9708424 A1 WO 9708424A1
Authority
WO
WIPO (PCT)
Prior art keywords
downhole tool
downhole
tool system
pressure
tubing
Prior art date
Application number
PCT/GB1996/002075
Other languages
English (en)
Inventor
John Howard Curley
Original Assignee
Win Cubed Limited
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 Win Cubed Limited filed Critical Win Cubed Limited
Priority to AU68290/96A priority Critical patent/AU6829096A/en
Priority to GB9707804A priority patent/GB2317905A/en
Publication of WO1997008424A1 publication Critical patent/WO1997008424A1/fr

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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
    • 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
    • E21B49/088—Well testing, e.g. testing for reservoir productivity or formation parameters combined with sampling
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/20—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables
    • E21B17/206—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables with conductors, e.g. electrical, optical
    • 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
    • E21B47/002—Survey of boreholes or wells by visual inspection
    • 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
    • E21B49/08—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

Definitions

  • This invention relates to the evaluation of reservoir properties and well intervention in oil and gas wells.
  • DST drill stem test
  • WFS Wireline Fluid Samplers
  • DST equipment is lowered into the borehole to flow a well (producing fluid from the reservoir, usually to surface) , and it is run on drillpipe or tubing. These tools are operated to flow, shut-in or circulate the well either by mechanical manipulation of the drillpipe or by annulus pressure (the pressure in the annulus between the liner and the drillpipe) .
  • the typical DST is a short-term flow test which can last a few hours to a few days. It usually includes fluid sampling and measurement of the recovery of reservoir pressure after the flow period, since this can provide important reservoir information.
  • Coiled tubing has been used increasingly for this purpose for many years. It is a service provided by many companies including Halliburton, Nowsco and Schlumberger Dowell. Coiled tubing is typically manufactured from stainless steel. It can be seam-welded into lengths of 1,000m or more. It can be butt- welded to create longer lengths. It was originally available in small sizes of about 25.4mm diameter, but larger sizes, which can be about 60.3mm diameter or larger, are now available. It is flexible enough to be wound onto a large reel which typically contains lengths of over 3000m. The coiled tubing can be manoeuvred into or out of the well by means of an injector.
  • the coiled tubing can be gripped by contoured blocks which are carried on 2 sets of chains. It can be connected to the wellhead through a stuffing box and blow out preventer.
  • the stuffing box allows the coiled tubing to be run into or out of the hole while under pressure.
  • coiled tubing Its small diameter enables the coiled tubing to be run inside a well completion tubing string (typically in the range 60.3 - 177.8 mm diameter, although smaller and larger tubings exist) .
  • Uses include, for example, nitrogen lifting a well (to initiate flow to surface) and for placing or injecting acids or other chemicals into the formation.
  • Coiled tubing drilling is another type of well intervention. Using downhole turbine motors driven by the pumping of drilling fluids, solids or cement which have settled where they are not wanted can be drilled out.
  • WFS Wireless Fidel Formation Dynamics tester
  • RCI Western Atlas Reservoir Characterisation Instrument
  • WFS tools are, however, limited in several ways. They cannot be used for injection of treatment fluids from surface. Also, the volume of hydrocarbon which can be pumped from the formation using a WFS is limited to at most a few barrels because there is a risk of creating a "kick".
  • a "kick" is an influx of reservoir fluids into the wellbore, which, if not controlled, can quickly rise to surface and create a high pressure surge. If not controlled, this surge can blow mud out of the hole which, if unchecked, can cause a blowout. Hydrocarbons must be pumped to cleanup before taking a sample, otherwise the sample will be contaminated.
  • a WFS can only pump fluids into the annulus (the annular space between the borehole wall and the WFS tool or its wireline cable) . Such fluids are free to rise to surface, creating the risk of a kick.
  • WFS samples often suffer from contamination from drilling mud which can reduce the quality of the samples and introduce errors in phase behaviour predictions. This can be especially problematic when pseudo oil-based muds are used for drilling. These may contain some components which also occur in crude oils and so can lead to confusion. There are techniques, using equation of state simulation, to compensate for the impact of this contamination. However, it is advantageous to reduce the amount of contamination in the samples in the first place.
  • the latest coiled tubing applications include advanced drilling applications such as sidetracking to drill new wells - especially horizontal and multi-lateral wells. Other uses are to cut it and use it as a quicker and cheaper completion than small-sized conventional tubing.
  • a completion is typically run to achieve permanent production from a well. It is typically a string of tubing, a packer which anchors and seals against the liner and various tubular sections with machined internal profiles to receive matching profiled plugs.
  • Coiled tubing can also aid running electrical wireline logs in difficult conditions, such as high angle or horizontal wells.
  • the downhole tools and electrical wireline cable can be pushed to the bottom of the well using the weight and stiffness of the coiled tubing. In more extreme situations, calling for even more weight and stiffness, drillpipe must be used, although this is a slower operation.
  • Coiled tubing can also have electrical wireline cable pumped through it to run its entire length. This helps to obtain a pressure seal (compared with running the electrical wireline cable outside the coiled tubing) when running downhole tools under pressure in a producing well. It can be used, for example, to run wireline production logs in high angle wells. These use temperature probes, gradiomanometers to measure fluid density changes and turbine spinners to measure flowrate. Current uses of coiled tubing are therefore diverse. However, they do not exploit the capability to flow or pump hydrocarbons up the coiled tubing. Nor do they combine such flow with downhole electrical instrumentation and control.
  • the present invention is described here in broad concept. It is a downhole tool system and method which allows the previously separate operational capabilities and uses of DSTs, wireline, and coiled tubing to be combined to advantage. It is a downhole tool system which enables high quality sampling and many other forms of well evaluation and intervention.
  • the downhole tool system uses coiled tubing, or a similar continuous reel of tubing, to run the downhole tool into a well.
  • the downhole tool is run into the well and its packer or probe can be set and unset to seal against the borehole wall as often as required, using internal hydraulic power generated via the electrical power from surface.
  • the method can be used to run the downhole tool into an "open hole” (before casing or liner has been run) or after completion, when a tubing string has been run and set to produce from the well.
  • the method can be used advantageously in multi-lateral boreholes (multiple high deviation wellbores branching from one vertical wellbore) .
  • the present invention provides a device which may be used in a sampling method in which the downhole sampling tool is run into the borehole on electrical coiled tubing (coiled tubing containing a wireline cable within it, running its entire length) or similar continuous reel of tubing which provides for electrical connection for power, control and data telemetry.
  • the downhole tool of the invention could also be run on drill pipe or tubing in a similar way.
  • a connector with a pressure-tight seal is required, so that the downhole tool of the invention may pump safely into the coiled tubing or fluids may be pumped safely from surface down the coiled tubing and through the downhole tool.
  • the connector In the case where the downhole tool is connected to electrical coiled tubing with an internal wireline, the connector must provide a pressure-tight means for the wireline cable to exit through the flow tube to establish electrical contact with the tool electronics. In such a case, and unlike a WFS, which can only vent fluids to the side, the flow tube will pass from the top, down the tool, either internally or externally.
  • Electrical termination at surface may be by a pressure- tight brush pickup in the coiled tubing reel.
  • the electrical cable is used to transmit power and control signals to the downhole device and provides the means for data telemetry from the tool during operation.
  • the method can be used to run the downhole tool either in "open hole” (before casing or liner has been run) or after completion, when a string of tubing has been permanently set in place to produce from the well.
  • the downhole tool may be of modular design, allowing the use of either a probe, single packer or straddle packer module, running internally carried sample bottles which are certified for air transport, running large sample containers, providing a pump module and providing various downhole sensors.
  • a small diameter "slim hole” version of the downhole tool is required.
  • the current invention can provide real-time surface readout of pressure, temperature and differentiation of fluid phases from each other such as through means of light absorption and by in-situ measurement of saturation pressure by de-pressurisation and re-pressurisation of a sample.
  • the tool can be run in conjunction with downhole cameras, steering and traction devices to find and enter multiple boreholes.
  • a considerable advantage of the present invention is that it allows quicker evaluation than with a conventional DST. Being continuous, it is intrinsically quicker and safer to run into and pull out of the hole. Unlike DSTs, it does not require mechanical manipulation of the coiled tubing or the application of annulus pressure to operate, which often requires a liner to be run.
  • the downhole tool can receive fluids pumped from surface.
  • the present invention can pump or flow more fluids at higher rates from the reservoir than a WFS to increase the chances of gathering high quality samples.
  • the present invention reduces the amount of contamination in samples by enabling much increased volumes of fluid to be pumped or flowed before sampling takes place, thus enabling more complete cleanup to representative reservoir fluids.
  • the pump and internal tubing within the tool are larger than in WFS tools. This enables the larger cleanup volumes to be pumped at higher rates than in WFS tools, so that larger volumes can be handled reasonably quickly.
  • Evaluation or treatment of multiple zones is possible in one run in the hole and is relatively quick to perform, whereas usually this would require multiple runs with DST tools.
  • Small zones can be precisely targeted if necessary, which can enable investigation of changes in reservoir or fluid properties over small distances or reduce injection treatment volumes.
  • evaluation or treatment of each borehole in a multi-lateral well is possible in one run in the hole which again can save time.
  • Figure 1 is a schematic side view of an electrical coiled tubing reel and injector assembly.
  • Figure 2 is a schematic side view of the downhole tool suspended in the well.
  • Figure 3 is a schematic cross section of one type of electrical coiled tubing containing an electrical wireline cable.
  • Figure 1 shows the electrical coiled tubing reel (1) , injector assembly (2) and stuffing box (3) mounted over the wellhead with the electrical coiled tubing (4) run into the borehole.
  • Figure 2 shows the downhole tool suspended in the well in open hole on the electrical coiled tubing (4) .
  • Figure 3 shows a cross section of the electrical coiled tubing (4) containing the electrical wireline (14) .
  • the downhole tool is connected to the coiled tubing via the connector (5) .
  • the downhole tool can be positioned using a gamma ray or other depth reference (6) next to a zone of interest.
  • the tool is set in position using hydraulic power to press the probe (12) packer or packers (13) into the borehole wall.
  • the tool is run in drilling mud or kill-weight fluid.
  • a failsafe valve in the pump module (7) closes in the downhole tool to isolate the coiled tubing from the annulus. Retraction of the probe (12) is delayed by means of a hydraulic reservoir (10) to allow recovery from brief power outages without unsetting the tool.
  • the pump module (7) is used to pump fluid from the formation into the coiled tubing (4) . By opening a valve, it can also pump into the annulus. A "cushion" of less dense fluid inside the coiled tubing is not necessary to control drawdown (pressure drop ) on the formation, as it is in a DST, which can save time.
  • drawdown pressure drop
  • the well may be able to flow naturally into the coiled tubing (4), in which case the pump can be by-passed by opening a by-pass valve.
  • the contamination of the flowstream can be measured using downhole sensors (11) and monitored in real time via telemetry to surface. Flow can be sustained for as long as necessary to obtain high quality samples with real time indication of the fluid sample quality.
  • samples can be captured using the tools internal multi-sample bottles (9) or large sample chamber (8) .
  • the internal sample bottles (9) can be approved for air transport so that transfer into another vessel approved for transport is not required at surface, which can be detrimental to sample quality. If required, a pressure build up with downhole shut-in can be carried out. The tool can then be unset and moved on to a new zone of interest.
  • a slim hole version of the downhole tool can be set at specific depths with a gamma ray or casing collar locator.
  • a packer or straddle packer module (13) is used to isolate the perforated zone of interest in order to inject or displace fluids, or to flow and take fully instrumented downhole samples from specific intervals.
  • downhole measurement and real time surface monitoring via telemetry enable confirmation that all the right fluids have been injected into the right place.
  • the monitoring permits investigation of the fluids flowing before committing to a sample. If necessary, flow can be sustained from a specific interval until it stabilises (measuring for example a water-oil ratio or gas-oil ratio) or until it reaches surface. If the interval being tested dies due to unloading heavy, contaminated fluid, it can be pumped using the pump module to attempt to clean the zone up. The tool can then be unset and moved on to a new zone of bread .
  • the device can be run in conventional, multi-lateral and other non-conventional or extended reach development wells.
  • the tool can be set at several places in a horizontal section to flow up the coiled tubing in order to evaluate the well productivity.
  • the well can be flowed up the tubing and the tool can monitor pressure , temperature and fluid type at locations along the horizontal section.
  • each wellbore can be entered and specific zones can be evaluated separately before they are completed.
  • Fluid need not be brought to the surface. It can be reinjected into the test zone after the test, either from surface or with the pump module.
  • the volume of fluid flowed can be measured via the number of pump strokes, which have a known volume. Hence the fluid level in the coiled tubing can be calculated at any time to avoid flowing to surface, if this is not required.
  • the downhole valve system within the tool and the valves in the choke manifold can act as a double barrier to shut in between the reservoir and the surface. It is also possible to sever the coiled tubing upstream of the tubing reel using the shear rams in the coiled tubing BOP (Blow Out Preventer) or the shear rams in the drilling BOP.
  • BOP Blow Out Preventer
  • the risks and possible consequences that could arise from operations with the improved downhole tool require a detailed safety review which takes into account the prevailing well control system on a rig.
  • the pipework, choke manifold, heater, separator, gauge/storage tanks and flares are all of reduced size.
  • flowrates will be less than for a typical DST since the coiled tubing internal diameter will generally be less than that of a typical DST tubing.
  • the contents of the coiled tubing can be reverse circulated out (rather than just re- injected) after each sampling job.
  • the greater offtake will also create a reservoir pressure disturbance which reaches further away from the wellbore. This is more valuable for reservoir characterisation using pressure transient analysis interpretation based on the pressure drawdown and pressure buildup cycle.
  • the volume of offtake is essentially limited only by the time allocated for the task and the pump rate.
  • the downhole tool system can be run in oil or gas wells on land, offshore on fixed installations such as platforms or jackup rigs and on floating vessels such as drillships or semi ⁇ submersible rigs.
  • a floating situation will require a heave compensation system and a subsea injector or other means to achieve a pressure seal around the coiled tubing within the rigs BOP (blow out preventer) which is set on the seabed.
  • BOP blow out preventer
  • such means can provide the method to achieve pressure connection with the annulus and enable use of the standard rig kill and choke lines to the BOP for this purpose.
  • a subsea coiled tubing BOP will also be needed to enable an emergency disconnection by severing the coiled tubing. This will cause the valve downhole to shut, isolating the coiled tubing, and surface, from reservoir pressure.
  • the present invention also provides a method for the evaluation of a well.
  • the downhole tool of the present invention may be used alone or in combination with known downhole tools and/or methods of well evaluation.
  • the improved downhole tool and method enhance the gathering of dynamic reservoir data.
  • Dynamic reservoir data are acquired while reservoir pressures are changing and reservoir fluids may be flowing as a consequence.
  • Examples of dynamic reservoir data are pressure and temperature drawdown and buildup as a consequence of fluid offtake and shut-in.
  • Another example is the taking of fluid samples which requires the offtake of fluids from the reservoir.
  • Static reservoir data by comparison include porosity, permeability, water saturation; also pressures and temperatures measured when no fluids are flowing or when pressure differentials (which may or may not cause measurable fluid movement) have dissipated.
  • the improved downhole tool is best placed at the centre of the dynamic data acquisition planning.
  • the nearest equivalent tools in use today, the WFS tools are not typically used in this way.
  • the approach of the present invention can lead to large departures from the usual sequence of events in conventional data acquisition. Examples might include running the tool before penetrating the whole reservoir or running the tool days before conventional open hole logs are run.
  • Drilling mud cools the drill bit, lubricates the drillstring in the wellbore and transports the rock cuttings to surface in suspension.
  • a mud which is optimal from a drilling or environmental viewpoint may not be suitable from a contamination of representative fluid samples viewpoint.
  • Open hole logs which gather static reservoir data, are almost invariably run before a WFS.
  • the improved downhole tool of the present invention may be run before or after open hole logs.
  • the chosen sequence of data acquisition will reflect the well objectives and the data acquisition objectives. There are occasions where the need for dynamic data is more urgent than the need for static data, so the improved downhole tool of the present invention can be run first.
  • the present invention can strongly influence real-time decisions on a well.
  • Resistivity, porosity and gamma ray data are all examples of measurements made with open hole logs. Several logs are needed and they require interpreting to indicate for example, the shale-corrected porosity and the water saturation. Traditionally these data, possibly combined with WFS data, are used to make a decision on whether or not to run a DST on a well.
  • the improved downhole tool provides more direct measurements and therefore makes such welltesting decisions simpler - to prove that reservoir fluids will flow, to sample them, to capture them in sample bottles and to allow surface inspection of samples.
  • the improved downhole tool may provide all the dynamic well evaluation which is needed. Or, it may indicate the remaining areas of uncertainty and help focus on specific aspects to evaluate further. It can thus help design a DST or other test which is optimised to gather this data.
  • the improved downhole tool might indicate that representative fluid properties differ somewhat from one productive horizon to the next. This might be a case where prolonged testing and sampling was consequently planned on the same well to establish whether or not there really were fluid property differences.
  • the improved fluid sampler can be used to provide evidence of pressure depletion due to fluid offtake.
  • the fluid offtake can be from the subject well or in the form of an interference test by fluids being produced from another well.
  • the improved downhole tool data would indicate whether a DST, or indeed a longer extended welltest might be required on the same well to investigate further the possibility of depletion.
  • the information obtained from the improved fluid sampler might indicate unexpectedly low productivity from a tested zone. This might indicate the merit of a maximum rate DST across the whole productive interval to confirm or refute the possibility of poor productivity. It might also give early warning to plan for a stimulation treatment. These are not always possible immediately after a disappointing DST due to significant planning, equipment and material lead times.
  • the method for best use of the improved downhole tool will produce different outcomes each time depending on the reservoir geology, well objectives, drilling programme, fluid properties, reservoir pressure and temperature. The method requires consistent thinking ahead about the well evaluation and the best way to achieve, or even improve on the stated objectives. It is much more flexible than just following a fixed programme and more powerful than just reacting to events.
  • the improved downhole tool system of the present invention provides good quality data quickly.
  • the improved downhole tool and method provide a means to optimise the gathering of dynamic reservoir data. This may avoid the need to re-enter a well or avoid the need to drill another well to address unanswered questions.
  • the tool and method can be applied in an exploration, appraisal or development well.

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  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Physics & Mathematics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geophysics (AREA)
  • Mechanical Engineering (AREA)
  • Chemical & Material Sciences (AREA)
  • Analytical Chemistry (AREA)
  • Electric Cable Installation (AREA)
  • Connector Housings Or Holding Contact Members (AREA)
  • Earth Drilling (AREA)

Abstract

La présente invention concerne un système d'outil de fond de puits qui se compose d'un outil de fond de puits mis en communication fluidique, via un connecteur étanche (5), avec un dévidoir à alimentation axiale pour tube de production (1), pour tige de forage ou pour tube classique, de façon à assurer l'écoulement des fluides entre la formation, l'outil et la surface, l'outil de fond de puits étant en communication électrique avec la surface (4).
PCT/GB1996/002075 1995-08-22 1996-08-22 Systeme d'outil de fond de puits WO1997008424A1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
AU68290/96A AU6829096A (en) 1995-08-22 1996-08-22 Downhole tool system
GB9707804A GB2317905A (en) 1995-08-22 1996-08-22 Downhole tool system

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GBGB9517149.2A GB9517149D0 (en) 1995-08-22 1995-08-22 Improved downhole tool system
GB9517149.2 1995-08-22

Publications (1)

Publication Number Publication Date
WO1997008424A1 true WO1997008424A1 (fr) 1997-03-06

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PCT/GB1996/002075 WO1997008424A1 (fr) 1995-08-22 1996-08-22 Systeme d'outil de fond de puits

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AU (1) AU6829096A (fr)
GB (2) GB9517149D0 (fr)
WO (1) WO1997008424A1 (fr)

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2001027432A3 (fr) * 1999-10-09 2001-10-04 Schlumberger Ltd Procedes et appareil pour realiser des mesures sur des fluides produits par des formations souterraines
WO2002057595A1 (fr) * 2001-01-18 2002-07-25 Shell Internationale Research Maatschappij B.V. Mesure de la temperature statique d'une formation in situ
WO2002070864A1 (fr) * 2001-01-18 2002-09-12 Shell Internationale Research Maatschappij B.V. Determination de la mobilite effective in situ et de la permeabilite effective d'une formation
US6659180B2 (en) 2000-08-11 2003-12-09 Exxonmobil Upstream Research Deepwater intervention system
US6789937B2 (en) * 2001-11-30 2004-09-14 Schlumberger Technology Corporation Method of predicting formation temperature
US6871532B2 (en) * 2001-10-12 2005-03-29 Schlumberger Technology Corporation Method and apparatus for pore pressure monitoring
AU781820B2 (en) * 1999-12-03 2005-06-16 Baker Hughes Incorporated Fluid cut control device
US8424596B2 (en) 2009-11-03 2013-04-23 Robert Douglas Bebb High efficiency fluid pumping apparatus and method

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US4535843A (en) * 1982-05-21 1985-08-20 Standard Oil Company (Indiana) Method and apparatus for obtaining selected samples of formation fluids
US4936139A (en) * 1988-09-23 1990-06-26 Schlumberger Technology Corporation Down hole method for determination of formation properties
US4938060A (en) * 1988-12-30 1990-07-03 Otis Engineering Corp. Downhole inspection system
US5180014A (en) * 1991-02-14 1993-01-19 Otis Engineering Corporation System for deploying submersible pump using reeled tubing
US5291947A (en) * 1992-06-08 1994-03-08 Atlantic Richfield Company Tubing conveyed wellbore straddle packer system
US5337838A (en) * 1990-09-19 1994-08-16 Sorensen Kurt I Method and an apparatus for taking and analyzing level determined samples of pore gas/liquid from a subterranean formation
US5351533A (en) * 1993-06-29 1994-10-04 Halliburton Company Coiled tubing system used for the evaluation of stimulation candidate wells
US5377755A (en) * 1992-11-16 1995-01-03 Western Atlas International, Inc. Method and apparatus for acquiring and processing subsurface samples of connate fluid

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4535843A (en) * 1982-05-21 1985-08-20 Standard Oil Company (Indiana) Method and apparatus for obtaining selected samples of formation fluids
US4936139A (en) * 1988-09-23 1990-06-26 Schlumberger Technology Corporation Down hole method for determination of formation properties
US4938060A (en) * 1988-12-30 1990-07-03 Otis Engineering Corp. Downhole inspection system
US5337838A (en) * 1990-09-19 1994-08-16 Sorensen Kurt I Method and an apparatus for taking and analyzing level determined samples of pore gas/liquid from a subterranean formation
US5180014A (en) * 1991-02-14 1993-01-19 Otis Engineering Corporation System for deploying submersible pump using reeled tubing
US5291947A (en) * 1992-06-08 1994-03-08 Atlantic Richfield Company Tubing conveyed wellbore straddle packer system
US5377755A (en) * 1992-11-16 1995-01-03 Western Atlas International, Inc. Method and apparatus for acquiring and processing subsurface samples of connate fluid
US5351533A (en) * 1993-06-29 1994-10-04 Halliburton Company Coiled tubing system used for the evaluation of stimulation candidate wells

Cited By (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2001027432A3 (fr) * 1999-10-09 2001-10-04 Schlumberger Ltd Procedes et appareil pour realiser des mesures sur des fluides produits par des formations souterraines
AU781820B2 (en) * 1999-12-03 2005-06-16 Baker Hughes Incorporated Fluid cut control device
US6659180B2 (en) 2000-08-11 2003-12-09 Exxonmobil Upstream Research Deepwater intervention system
WO2002057595A1 (fr) * 2001-01-18 2002-07-25 Shell Internationale Research Maatschappij B.V. Mesure de la temperature statique d'une formation in situ
WO2002070864A1 (fr) * 2001-01-18 2002-09-12 Shell Internationale Research Maatschappij B.V. Determination de la mobilite effective in situ et de la permeabilite effective d'une formation
US6786086B2 (en) 2001-01-18 2004-09-07 Shell Oil Company Determining the in situ effective mobility and the effective permeabilty of a formation
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GB2317905A (en) 1998-04-08
GB9707804D0 (en) 1997-06-04
AU6829096A (en) 1997-03-19
GB9517149D0 (en) 1995-10-25

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