WO1996012088A1 - Well fluid sampling tool and well fluid sampling method - Google Patents
Well fluid sampling tool and well fluid sampling method Download PDFInfo
- Publication number
- WO1996012088A1 WO1996012088A1 PCT/GB1995/002435 GB9502435W WO9612088A1 WO 1996012088 A1 WO1996012088 A1 WO 1996012088A1 GB 9502435 W GB9502435 W GB 9502435W WO 9612088 A1 WO9612088 A1 WO 9612088A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- sample
- well fluid
- sampling tool
- temperature
- tool
- Prior art date
Links
- 239000012530 fluid Substances 0.000 title claims abstract description 91
- 238000005070 sampling Methods 0.000 title claims abstract description 71
- 238000000034 method Methods 0.000 title claims abstract description 20
- 150000001875 compounds Chemical class 0.000 claims abstract description 6
- 238000001556 precipitation Methods 0.000 claims abstract description 4
- 238000003860 storage Methods 0.000 claims abstract description 4
- 239000000463 material Substances 0.000 claims description 14
- 238000012423 maintenance Methods 0.000 claims description 12
- 238000009413 insulation Methods 0.000 claims description 9
- 238000010438 heat treatment Methods 0.000 claims description 5
- 239000011248 coating agent Substances 0.000 claims description 4
- 238000000576 coating method Methods 0.000 claims description 4
- 230000020169 heat generation Effects 0.000 claims description 4
- 238000007789 sealing Methods 0.000 claims description 3
- 230000003466 anti-cipated effect Effects 0.000 claims description 2
- 230000005855 radiation Effects 0.000 claims description 2
- 230000009467 reduction Effects 0.000 abstract description 2
- 239000012071 phase Substances 0.000 description 18
- 239000002131 composite material Substances 0.000 description 8
- 239000007788 liquid Substances 0.000 description 6
- 239000010720 hydraulic oil Substances 0.000 description 5
- 239000003921 oil Substances 0.000 description 5
- 239000004215 Carbon black (E152) Substances 0.000 description 3
- 238000004458 analytical method Methods 0.000 description 3
- 230000008859 change Effects 0.000 description 3
- 229930195733 hydrocarbon Natural products 0.000 description 3
- 150000002430 hydrocarbons Chemical class 0.000 description 3
- 239000011810 insulating material Substances 0.000 description 3
- 230000006798 recombination Effects 0.000 description 3
- 238000005215 recombination Methods 0.000 description 3
- 238000001816 cooling Methods 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- 238000012546 transfer Methods 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 1
- 239000004964 aerogel Substances 0.000 description 1
- 238000000429 assembly Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000000919 ceramic Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 239000012141 concentrate Substances 0.000 description 1
- 230000008602 contraction Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000001747 exhibiting effect Effects 0.000 description 1
- 239000011888 foil Substances 0.000 description 1
- 230000000977 initiatory effect Effects 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 238000004321 preservation Methods 0.000 description 1
- 230000037452 priming Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
- 230000035899 viability Effects 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
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
- E21B49/081—Obtaining fluid samples or testing fluids, in boreholes or wells with down-hole means for trapping a fluid sample
- E21B49/082—Wire-line fluid samplers
Definitions
- This invention related to a well fluid sampling tool and to a well fluid sampling method.
- Reservoir fluids liquids (such as water or oil) and as) are found in geological reservoirs wherein they are contained at a high pressure (relative to ambient atmospheric pressure) , and usually also at an elevated temperature (relative to ambient atmospheric temperature). At such pressures, the gas is dissolved in the liquid such that the reservoir fluid initially exists as a single-phase fluid, but the reservoir fluid will release dissolved gas to form a two-phase fluid with separate gas and liquid components if the reservoir fluid has its initial pressure sufficiently reduced towards ambient atmospheric pressure. Also, the initial relatively high temperature of the reservoir fluid results in volumetric contraction of a given mass of fluid as it cools towards ambient atmospheric temperature if withdrawn from the well.
- a well fluid test is usually performed. This test usually involves flowing the well fluid to surface, mutually separating the oil and gas in a separator, separately measuring the oil and gas flow rates, and then flaring the products (or transporting the products elsewhere for use or safe disposal).
- BHS Bottom Hole Sampling
- SRS Surface Recombination Sampling
- a typical BHS tool is run into the well to trap a sample of reservoir fluid at the required depth by controlled opening of an internal chamber to admit reservoir fluid, followed by sealing of the sample- holding chamber after admission of a predetermined volume of fluid.
- the tool is then retrieved from the well and the sample is transferred from the tool to a sample bottle for shipment to the analytical laboratory.
- the sample pressure As the tool in retrieved from the well, its temperature drops and the fluid sample shrinks causing the sample pressure to drop. This pressure drop occurs because the sample-holding chamber within the typical BHS tool has a fixed volume after the sample is trapped and because the sample temperature is uncontrolled. Usually the sample pressure falls below the Bubble Point Pressure, allowing gas to break out of solution.
- the temperature change which the sample experiences and the resultant pressure change may also cause the precipitation of compounds previously dissolved in the well fluid, some of which cannot be re-dissolved by re- pressurisation.
- the absence of these compounds in the re-formed aliquot renders certain analyses meaningless.
- a well fluid sampling tool comprising a sample chamber; operative means for the tool operative to admit a well fluid sample to said sample chamber; and temperature maintenance means for maintaining the temperature of a well-fluid sample held within said sample chamber, the temperature maintenance means acting to counteract changes in temperature of the sample.
- the temperature maintainteance means acts to maintain said well fluid sample in single-phase form.
- the temperature maintenance means is formed as a storage heater.
- Said temperature maintenance means may comprise heat retention means which preferably comprises thermal insulation means disposed to minimise heat loss from a well-fluid sample at an elevated temperature relative to ambient temperature and held within the sample chamber.
- Said thermal insulation means preferably comprises a heat insulating jacket at least partially surrounding the sample chamber, the jacket being formed of a material or materials having a low thermal conductivity and preferably also exhibiting low thermal radiation characteristics.
- the jacket preferably also has a high specific heat capacity.
- Said thermal insulation means may additionally or alternatively comprise an evacuated jacket at least partially surrounding the sample chamber.
- the evacuated jacket may comprise at least part of the heat insulating jacket.
- Said temperature maintenance means may additionally or alternatively comprise heat generation means for generating heat in or adjacent the sample chamber.
- the heat generation means preferably comprises electrically energised electric heater means conveniently in the form of a dissipative resistor disposed on and/or in the sample chamber.
- the resistor may be in the form of an elongate tape wound around the sample chamber.
- the resistor may be in the form of a resistive coating.
- Electrical energy for energisation of the electric heater means may come from batteries or any other suitable source of electrical energy comprised within the sampling tool; additionally or alternatively, the electrical energy may come from an out-of-tool source, e.g. a wellhead generator, and be conveyed to the sampling tool by means of an electric cable.
- a well fluid sampling method comprising the steps of providing a well fluid sampling tool comprising a sample chamber, lowering said tool down a well to a location where well fluid is to be sampled, admitting a sample of well fluid into said sample chamber and then sealing said sample chamber, and maintaining the temperature of the well fluid sample held within the sample chamber while raising the tool and the sample up the well, in a manner tending to counteract changes in temperature of the well fluid sample.
- the sampled well fluid is maintained in single-phase form.
- said well fluid sampling tool is preferably a well fluid sampling tool according to the first aspect of the present invention.
- the method may comprise the step of holding the tool adjacent the sampling location, or in another region of elevated temperature, for a period at least sufficient to elevate the temperature of the sample chamber towards the anticipated temperature of the sample to be taken.
- the method may comprise the alternative or additional step of pre-heating the sample chamber prior to lowering the sampling tool down the well.
- Figure 1 diagrammatically illustrated the order ⁇ f assembly of Figures 2A - 4G to form composite figures
- Figures 2A - 2G (assembled as indicated in Figure 1 to form a composite Figure 2) illustrate a longitudinal section of a well fluid sampling tool in accordance with the invention, the tool being in a pre- sampling configuration
- Figures 3A - 3G (assembled as indicated in Figure 1 to form a composite Figure 3) illustrate the tool of Figure 2 in its sampling configuration, i.e. in the process of sampling a surrounding well fluid;
- Figures 4A - 4G (assembled as indicated in Figure 1 to form a composite Figure 4) illustrate the tool of Figure 2 in its post-sampling configuration.
- a well-fluid sampling tool 10 comprises an elongate linear assembly (within a multi-component casing) of a clock 12, a clock-actuated trigger assembly 14, an air chamber 16, a trigger-actuated valve 18, a sample inlet valve 20, a sampling piston 22, a sample chamber 24, and a wireline connector 26 at the top of the tool 10.
- a clock-actuated trigger assembly 14 an air chamber 16
- a trigger-actuated valve 18 a sample inlet valve 20
- sampling piston 22 a sampling piston 22
- sample chamber 24 a sample chamber 24
- wireline connector 26 at the top of the tool 10.
- the sample chamber 24 comprises an inner tube 30 of a material having properties suitable for use as a sample chamber, i.e. mechanical strength and durability, and resistance to chemical attack by well fluids.
- the material of the inner tube 30 is also selected to have a high specific heat capacity.
- the sample chamber 24 further comprises an outer tube 32 of a thermally insulating material also having a high specific heat capacity, as well as adequate mechanical properties and corrosion resistance.
- the material of the outer tube 32 may be a suitable ceramic or be formed of steel having a thermally insulating coating.
- the annulus 34 between the inner and outer tubes 30, 32 may be evacuated such that the vacuum around the sample chamber 24 further improves thermal insulation of the sample chamber 24.
- the annulus 34 may be filled with an aerogel as an additional insulating material.
- the exterior of the inner tube 30 is wound with an electrical resistance heater 36 in the form of a tape or foil or may be coated with a resistive coating.
- the heater 36 is connected (by means not shown) to a control circuit and battery pack (not shown) mounted inside a battery chamber 38 forming part of the sampling tool 10 between the upper end of the sampling chamber 24 (the right-hand end of the sample chamber 24 as viewed in Figures 2, 3 & 4) and the wireline connector 26.
- Electric power for the heater 36 may additionally or alternatively be supplied from an external generator or electric mains (not shown), conveniently though an electric cable (not shown) paralleling (or serving in place of) the wireline (not shown) coupled to the wireline connector 26 (which is suitably adapted to the transfer of electric power as well as mechanical lifting forces).
- the tool 10 is prepared for sampling operation by setting the internal components to the positions shown in Figure 2 (in particular, setting the sampling piston 22 to the lower (left) end of the sample chamber 24), evacuating the annulus 34 through a re-closable valve 40, setting (but not yet initiating operation of) the clock 12 to respond after a predetermined time delay, and pressurising the upper (right) end of the sample chamber 24 above the piston 22 with hydraulic oil.
- the hydraulic oil is injected through a priming valve 42 until the upper end of the sample chamber 24 is filled with oil at a pressure greater than the fluid pressure at the location where the sample is eventually to be taken.
- the pre-pressurisation holds the piston 22 against the bottom of the sample chamber 24 against upward force on the piston 22 produced by the pressure of well fluids entering the initially open sample inlet valve 20, until the piston 22 is released for sample taking by opening the valve 18 within the trigger assembly 14 to depressurise the hydraulic pre-filling by draining it into the air chamber 16.
- the sample chamber 24 is pre-heated by energising the heater element 36, using either the batteries (previously charged and installed in the battery chamber 38) or an external power supply, such as a wellhead generator or mains power.
- the inner tube 30, together with the heater element 36 and suitable further thermal insulation, may be combined as a form of storage heater which may be detachable from the rest of the tool 10 for convenience in pre-heating and other purposes (e.g. sample handling and sample chamber cleaning) .
- the prepared tool 10 is connected to a wireline (not shown) by means of the connector 26 and lowered down the well to the location at which a well fluid sample is to be taken. If the tool 10, and the sample chamber 24 in particular, are not yet at or near the ambient temperature at the sampling location, the tool 10 is suspended at the sampling location until temperature equilibrium is approached or reached. (although beneficial in ways which are detailed below, the thermal insulation of the sample chamber 24, and the high specific heat capacity of the sample chamber materials make the sample chamber slow to warm up to downhole ambient temperature; pre-heating reduces this delay) .
- the clock 12 reaches the end of the pre-set delay period and actuates the trigger assembly 14 to open the valve 18 as shown in composite Fig 4, allowing hydraulic oil to drain from the upper (right) end of the sample chamber 24 into the air chamber 16.
- This allows the sampling piston 22 to move up (rightwards along) the sample chamber 24 under the pressure of well fluid entering the lower (left) end of the sample chamber 24 through the sample inlet valve 20.
- the rate at which hydraulic oil flows into the air chamber 16 is metered to control the rate at which well fluid enters the sample chamber 24 to level low enough to avoid a pressure drop across the valve 20 that would otherwise cause dissolved materials to come out of solution in the liquid component of the well fluid.
- the sampling tool is pulled back up the well to the surface, with the hot, high-pressure well fluid sample sealed inside the sample chamber 24.
- the initial temperature of the well-fluid sample i.e. the temperature of the well fluid at the time of sampling, is substantially maintained by the storege heater arrangement and by the structure of the sample chamber 24, i.e. by the thermal isolation provided by the use of thermally insulating material for the outer tube 32, together with the evacuation of the annulus 34 between the outer and inner tubes 32 & 30, and also by the high specific heat capacities of the materials selected to form the tubes 30 and 32.
- sample temperature should commence to fall significantly, such a temperature fall would be detected by the control circuit (in the chamber 38) through a sample temperature sensing means (not illustrated) , for example a thermistor or thermocouple in thermal contact with the sample.
- a sample temperature sensing means for example a thermistor or thermocouple in thermal contact with the sample.
- the control circuit would connect the batteries (also in the chamber 38) to the heater 36 so as to heat up the underlying inner tube 30 and thereby maintain the sample against untoward cooling.
- the highly desirable effect of maintaining the temperature of the sampled well fluid at or near initial as-sampled temperature is the preservation of the initial volume of the sampled well fluid without the volumetric shrinkage otherwise induced by temperature reduction, and consequently the maintenance of the well-fluid sample at or sufficiently near its initial pressure as to obviate loss of the initial single-phase condition of the sample otherwise induced by shrinkage.
- the initial single-phase condition of the well fluid sample was maintained by externally pressurising the sample chamber from an in-tool pressure source as soon as the sample was taken; in the present invention the initial single-phase condition of the well-fluid sample is maintained by maintaining the temperature of the sample sufficiently to prevent cooling of the sample to the point at which there would be significant loss of single-phase condition, and without resort to internal pressurisation of the sample chamber.
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Sampling And Sample Adjustment (AREA)
Abstract
Description
Claims
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
AU36170/95A AU3617095A (en) | 1994-10-14 | 1995-10-16 | Well fluid sampling tool and well fluid sampling method |
US08/817,377 US5901788A (en) | 1995-10-16 | 1995-10-16 | Well fluid sampling tool and well fluid sampling method |
GB9707608A GB2309473B (en) | 1994-10-14 | 1995-10-16 | Well fluid sampling tool and well fluid sampling method |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
GB9420727A GB9420727D0 (en) | 1994-10-14 | 1994-10-14 | Thermal sampling device |
GB9420727.1 | 1994-10-14 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO1996012088A1 true WO1996012088A1 (en) | 1996-04-25 |
Family
ID=10762838
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/GB1995/002435 WO1996012088A1 (en) | 1994-10-14 | 1995-10-16 | Well fluid sampling tool and well fluid sampling method |
Country Status (3)
Country | Link |
---|---|
AU (1) | AU3617095A (en) |
GB (2) | GB9420727D0 (en) |
WO (1) | WO1996012088A1 (en) |
Cited By (12)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO1998039552A1 (en) * | 1997-03-03 | 1998-09-11 | Csm Associates Limited | Samplers for high-temperature fluids |
WO2000034624A2 (en) | 1998-12-09 | 2000-06-15 | Expro North Sea Limited | Apparatus and method for well fluid sampling |
GB2350139A (en) * | 1999-05-18 | 2000-11-22 | Halliburton Energy Serv Inc | Verification of monophasic samples by temperature measurement |
EP0999348A3 (en) * | 1998-11-02 | 2000-11-29 | Halliburton Energy Services, Inc. | Fluid sample chamber with non-reactive lining |
EP0903464A3 (en) * | 1997-09-23 | 2000-12-06 | Halliburton Energy Services, Inc. | Well fluid sampling apparatus |
WO2001063093A1 (en) * | 2000-02-25 | 2001-08-30 | Baker Hughes Incorporated | Apparatus and method for controlling well fluid sample pressure |
WO2002057595A1 (en) * | 2001-01-18 | 2002-07-25 | Shell Internationale Research Maatschappij B.V. | Measuring the in situ static formation temperature |
US6439307B1 (en) | 1999-02-25 | 2002-08-27 | Baker Hughes Incorporated | Apparatus and method for controlling well fluid sample pressure |
WO2002070864A1 (en) * | 2001-01-18 | 2002-09-12 | Shell Internationale Research Maatschappij B.V. | Determining the in situ effective mobility and the effective permeability of a formation |
EP1427912A2 (en) * | 2001-09-19 | 2004-06-16 | Baker Hughes Incorporated | Dual piston single phase sampling mechanism and procedure |
GB2405652A (en) * | 2003-08-04 | 2005-03-09 | Pathfinder Energy Services Inc | Apparatus for obtaining high quality formation fluid samples |
US6871532B2 (en) * | 2001-10-12 | 2005-03-29 | Schlumberger Technology Corporation | Method and apparatus for pore pressure monitoring |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB0025302D0 (en) * | 2000-10-14 | 2000-11-29 | Sps Afos Group Ltd | Downhole fluid sampler |
Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP0148696A1 (en) * | 1983-12-22 | 1985-07-17 | Societe De Prospection Electrique Schlumberger | Apparatus and method for taking a sample representative of the fluid in a well bore |
US4766955A (en) * | 1987-04-10 | 1988-08-30 | Atlantic Richfield Company | Wellbore fluid sampling apparatus |
EP0515495A1 (en) * | 1990-02-15 | 1992-12-02 | Oilphase Sampling Services Limited | Well fluid sampling tool and well fluid sampling method |
Family Cites Families (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5549162A (en) * | 1995-07-05 | 1996-08-27 | Western Atlas International, Inc. | Electric wireline formation testing tool having temperature stabilized sample tank |
-
1994
- 1994-10-14 GB GB9420727A patent/GB9420727D0/en active Pending
-
1995
- 1995-10-16 AU AU36170/95A patent/AU3617095A/en not_active Abandoned
- 1995-10-16 WO PCT/GB1995/002435 patent/WO1996012088A1/en active Application Filing
- 1995-10-16 GB GB9707608A patent/GB2309473B/en not_active Expired - Lifetime
Patent Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP0148696A1 (en) * | 1983-12-22 | 1985-07-17 | Societe De Prospection Electrique Schlumberger | Apparatus and method for taking a sample representative of the fluid in a well bore |
US4766955A (en) * | 1987-04-10 | 1988-08-30 | Atlantic Richfield Company | Wellbore fluid sampling apparatus |
EP0515495A1 (en) * | 1990-02-15 | 1992-12-02 | Oilphase Sampling Services Limited | Well fluid sampling tool and well fluid sampling method |
Cited By (23)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO1998039552A1 (en) * | 1997-03-03 | 1998-09-11 | Csm Associates Limited | Samplers for high-temperature fluids |
EP0903464A3 (en) * | 1997-09-23 | 2000-12-06 | Halliburton Energy Services, Inc. | Well fluid sampling apparatus |
EP0999348A3 (en) * | 1998-11-02 | 2000-11-29 | Halliburton Energy Services, Inc. | Fluid sample chamber with non-reactive lining |
US6702017B1 (en) | 1998-12-09 | 2004-03-09 | Expro North Sea Limited | Apparatus and method for well fluid sampling |
WO2000034624A2 (en) | 1998-12-09 | 2000-06-15 | Expro North Sea Limited | Apparatus and method for well fluid sampling |
WO2000034624A3 (en) * | 1998-12-09 | 2000-08-17 | Expro North Sea Ltd | Apparatus and method for well fluid sampling |
AU771730B2 (en) * | 1998-12-09 | 2004-04-01 | Expro North Sea Limited | Improvements in or relating to well fluid sampling |
US6439307B1 (en) | 1999-02-25 | 2002-08-27 | Baker Hughes Incorporated | Apparatus and method for controlling well fluid sample pressure |
GB2350139A (en) * | 1999-05-18 | 2000-11-22 | Halliburton Energy Serv Inc | Verification of monophasic samples by temperature measurement |
US6216782B1 (en) | 1999-05-18 | 2001-04-17 | Halliburton Energy Services, Inc. | Apparatus and method for verification of monophasic samples |
GB2350139B (en) * | 1999-05-18 | 2003-07-16 | Halliburton Energy Serv Inc | Method for verification of monophasic samples |
WO2001063093A1 (en) * | 2000-02-25 | 2001-08-30 | Baker Hughes Incorporated | Apparatus and method for controlling well fluid sample pressure |
WO2002070864A1 (en) * | 2001-01-18 | 2002-09-12 | Shell Internationale Research Maatschappij B.V. | Determining the in situ effective mobility and the effective permeability of a formation |
WO2002057595A1 (en) * | 2001-01-18 | 2002-07-25 | Shell Internationale Research Maatschappij B.V. | Measuring the in situ static formation temperature |
US6786086B2 (en) | 2001-01-18 | 2004-09-07 | Shell Oil Company | Determining the in situ effective mobility and the effective permeabilty of a formation |
AU2002250839B2 (en) * | 2001-01-18 | 2006-02-23 | Shell Internationale Research Maatschappij B.V. | Determining the in situ effective mobility and the effective permeability of a formation |
EP1427912A2 (en) * | 2001-09-19 | 2004-06-16 | Baker Hughes Incorporated | Dual piston single phase sampling mechanism and procedure |
EP1427912A4 (en) * | 2001-09-19 | 2005-11-02 | Baker Hughes Inc | Dual piston single phase sampling mechanism and procedure |
US7246664B2 (en) | 2001-09-19 | 2007-07-24 | Baker Hughes Incorporated | Dual piston, single phase sampling mechanism and procedure |
US7621325B2 (en) | 2001-09-19 | 2009-11-24 | Baker Hughes Incorporated | Dual piston, single phase sampling mechanism and procedure |
US6871532B2 (en) * | 2001-10-12 | 2005-03-29 | Schlumberger Technology Corporation | Method and apparatus for pore pressure monitoring |
GB2405652A (en) * | 2003-08-04 | 2005-03-09 | Pathfinder Energy Services Inc | Apparatus for obtaining high quality formation fluid samples |
GB2405652B (en) * | 2003-08-04 | 2007-05-30 | Pathfinder Energy Services Inc | Apparatus for obtaining high quality formation fluid samples |
Also Published As
Publication number | Publication date |
---|---|
GB2309473A8 (en) | 1997-09-05 |
AU3617095A (en) | 1996-05-06 |
GB2309473A (en) | 1997-07-30 |
GB9420727D0 (en) | 1994-11-30 |
GB9707608D0 (en) | 1997-06-04 |
GB2309473B (en) | 1998-05-27 |
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