EP1618284A2 - Device for analysing at least one gas contained in a liquid, particularly bore fluid - Google Patents
Device for analysing at least one gas contained in a liquid, particularly bore fluidInfo
- Publication number
- EP1618284A2 EP1618284A2 EP04742533A EP04742533A EP1618284A2 EP 1618284 A2 EP1618284 A2 EP 1618284A2 EP 04742533 A EP04742533 A EP 04742533A EP 04742533 A EP04742533 A EP 04742533A EP 1618284 A2 EP1618284 A2 EP 1618284A2
- Authority
- EP
- European Patent Office
- Prior art keywords
- face
- liquid
- conduit
- drilling
- installation
- Prior art date
- Legal status (The legal status 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 status listed.)
- Granted
Links
- 239000007788 liquid Substances 0.000 title claims abstract description 45
- 239000012530 fluid Substances 0.000 title claims description 14
- 239000012528 membrane Substances 0.000 claims abstract description 60
- 238000004458 analytical method Methods 0.000 claims abstract description 27
- 238000005553 drilling Methods 0.000 claims description 55
- 238000009434 installation Methods 0.000 claims description 23
- 239000011248 coating agent Substances 0.000 claims description 11
- 238000000576 coating method Methods 0.000 claims description 11
- 238000005070 sampling Methods 0.000 claims description 11
- 238000001914 filtration Methods 0.000 claims description 9
- 238000011144 upstream manufacturing Methods 0.000 claims description 7
- HBMJWWWQQXIZIP-UHFFFAOYSA-N silicon carbide Chemical compound [Si+]#[C-] HBMJWWWQQXIZIP-UHFFFAOYSA-N 0.000 claims description 5
- 229910010271 silicon carbide Inorganic materials 0.000 claims description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 5
- 230000002209 hydrophobic effect Effects 0.000 claims description 4
- 229920002313 fluoropolymer Polymers 0.000 claims description 3
- 238000009736 wetting Methods 0.000 claims description 3
- 230000001105 regulatory effect Effects 0.000 claims description 2
- 239000010802 sludge Substances 0.000 abstract description 5
- 239000003129 oil well Substances 0.000 abstract description 2
- 239000007789 gas Substances 0.000 description 47
- 239000012159 carrier gas Substances 0.000 description 7
- 238000002347 injection Methods 0.000 description 7
- 239000007924 injection Substances 0.000 description 7
- 239000011148 porous material Substances 0.000 description 6
- 238000001514 detection method Methods 0.000 description 5
- 238000000605 extraction Methods 0.000 description 5
- 239000011435 rock Substances 0.000 description 5
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 4
- 230000006866 deterioration Effects 0.000 description 3
- 238000002955 isolation Methods 0.000 description 3
- 210000000056 organ Anatomy 0.000 description 3
- 238000011002 quantification Methods 0.000 description 3
- 239000007787 solid Substances 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- 238000005299 abrasion Methods 0.000 description 2
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 description 2
- 229910002092 carbon dioxide Inorganic materials 0.000 description 2
- 239000001569 carbon dioxide Substances 0.000 description 2
- 150000001875 compounds Chemical class 0.000 description 2
- 230000006870 function Effects 0.000 description 2
- 238000010438 heat treatment Methods 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 239000011368 organic material Substances 0.000 description 2
- 230000035515 penetration Effects 0.000 description 2
- 230000035939 shock Effects 0.000 description 2
- -1 steam Substances 0.000 description 2
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 1
- 229920000914 Metallic fiber Polymers 0.000 description 1
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000004422 calculation algorithm Methods 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 239000000919 ceramic Substances 0.000 description 1
- 230000001186 cumulative effect Effects 0.000 description 1
- 238000005520 cutting process Methods 0.000 description 1
- 238000007872 degassing Methods 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 238000010790 dilution Methods 0.000 description 1
- 239000012895 dilution Substances 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000002360 explosive Substances 0.000 description 1
- 239000004811 fluoropolymer Substances 0.000 description 1
- 238000005755 formation reaction Methods 0.000 description 1
- ZZUFCTLCJUWOSV-UHFFFAOYSA-N furosemide Chemical compound C1=C(Cl)C(S(=O)(=O)N)=CC(C(O)=O)=C1NCC1=CC=CO1 ZZUFCTLCJUWOSV-UHFFFAOYSA-N 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 239000002808 molecular sieve Substances 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 239000003921 oil Substances 0.000 description 1
- 229920001343 polytetrafluoroethylene Polymers 0.000 description 1
- 239000004810 polytetrafluoroethylene Substances 0.000 description 1
- 239000000741 silica gel Substances 0.000 description 1
- 229910002027 silica gel Inorganic materials 0.000 description 1
- URGAHOPLAPQHLN-UHFFFAOYSA-N sodium aluminosilicate Chemical compound [Na+].[Al+3].[O-][Si]([O-])=O.[O-][Si]([O-])=O URGAHOPLAPQHLN-UHFFFAOYSA-N 0.000 description 1
- 229910001220 stainless steel Inorganic materials 0.000 description 1
- 239000010935 stainless steel Substances 0.000 description 1
- 239000000126 substance Substances 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
- E21B49/005—Testing the nature of borehole walls or the formation by using drilling mud or cutting data
Definitions
- the present invention relates to a device for analyzing at least one gas contained in a liquid, in particular a drilling fluid, circulating in a conduit of a fluid extraction installation in a basement, this device being of the type comprising : - means for analyzing the or each gas;
- means for withdrawing at least a fraction of the or each gas comprising at least one porous membrane member, this member comprising a support and having a first face in contact with the liquid circulating in the conduit and a second face which opens into conduct linked to the means of analysis.
- This analysis carried out continuously, comprises two main phases.
- the first phase consists in extracting the gases conveyed by the mud (for example hydrocarbon compounds, carbon dioxide, hydrogen sulphide).
- the second phase consists in qualifying and quantifying the gases extracted.
- devices of the aforementioned type have been directly installed in the drilling pipe, upstream of the drilling head. well, as described in US Patent 5,469,917. These devices include a capillary tubular membrane. However, the sludge circulating around the membrane is loaded with pieces of rock.
- the membrane is wound on a threaded rod.
- the protection of the membrane is then ensured by the thread of the support for pieces of rock having a size greater than the distance which separates two consecutive threads from the threaded rod.
- the main object of the invention is therefore to have a device for analyzing the gases contained in a liquid containing debris of various sizes, in particular a drilling fluid, installed directly in a conduit of a fluid extraction installation. in a basement, without significant constraints on the membrane, in particular as regards the nature and geometry of the membrane.
- the invention relates to a device of the aforementioned type, characterized in that said first face has a hardness greater than 1400 Vickers (kgf / mm 2 ), in particular between 1400 and 1900 Vickers (kgf / mm 2 ).
- the porous membrane member comprises a coating which covers the support along said first face
- the coating is based on silicon carbide; - Said first face is also hydrophobic and oleophobic;
- the wetting angle of the water on said first face is greater than 120 °
- said first face comprises fluoropolymers incorporated by grafting
- the first face of the membrane member in contact with the liquid is substantially planar
- This device further comprises means for regulating the pressure in the pipe at the level of the second face of the membrane member;
- the installation also relates to an installation for extracting fluids in the basement of the type comprising a duct connecting at least one point of the basement to the surface, and a discharge pipe connected to the duct at the level of the surface, characterized in that it further comprises at least one device according to the characteristics described above, and in that the sampling means of said device are mounted on a tubular element constituted by the conduit or the discharge conduit.
- the first face of the membrane member in contact with the liquid is arranged substantially parallel to the elongation axis of the tubular element
- the tubular element comprises a bypass and said sampling means are placed in said bypass; and - The sampling means of said device are placed in said conduit upstream of said conduit;
- filtration means downstream of the discharge pipe and it comprises two devices as defined above, the respective sampling means of the two devices being placed respectively upstream and downstream of the filtration means.
- FIG. 1 shows schematically in vertical section a drilling installation provided with an analysis device according to the invention
- FIG. 2 shows schematically the main elements of the analysis device according to the invention
- FIG. 3 schematically shows a detail of a variant of the installation shown in Figure 1;
- FIG. 4 shows schematically in vertical section an installation comprising two analysis devices according to the invention.
- FIG. 5 shows schematically in vertical section a detail of a variant of the device shown in Figure 2.
- a device according to the invention is used, for example, in an installation for drilling an oil production well.
- this installation 11 comprises a drilling pipe 13 in a cavity drilled by a rotary drilling tool 15, a surface installation 17, and an analysis device 19 according to the invention mounted on the drilling pipe.
- drilling 13 is disposed in the cavity drilled in the basement 21 by the rotary drilling tool 15.
- This duct 13 comprises at the surface a well head 23 provided with a discharge pipe 25.
- the drilling tool 15 comprises a drilling head 27, a drilling string 29, and a head 31 for injecting liquid.
- the drilling head 27 comprises means 33 for drilling the rocks of the basement 21. It is mounted on the lower part of the drilling string 29 and is positioned in the bottom of the drilling pipe 13.
- the lining 29 comprises a set of hollow drilling tubes. These tubes delimit an internal space 35 making it possible to bring a liquid from the surface 37 to the drilling head 27.
- the liquid injection head 31 is screwed onto the upper part of the lining 29.
- the surface installation 17 comprises means 41 for supporting and driving in rotation the drilling tool 15, means 43 for injecting the drilling liquid and a vibrating screen 45.
- the injection means 43 are hydraulically connected to the injection head 31 to introduce and circulate a liquid in the internal space 35 of the drill string 29.
- the vibrating screen 45 collects the liquid loaded with drilling residues which leaves the evacuation pipe 25 and separates the liquid from the solid drilling residues.
- the analysis device 19 comprises a sampling head 51 of at least a fraction of the or each gas and analysis means 53 of the or each gas.
- the sampling head 51 comprises a porous membrane member 55 of which a first flat face 57 is in contact with the liquid flowing in the conduit 13 and a second face 59 opens into a conduit 61 connected to the means of analysis 53.
- the porous membrane member 55 comprises a membrane support 63 and a coating 65 which covers the support 63 on the side of the liquid along the first face 57.
- This first face 57 is arranged in the conduit 13 parallel to the elongation axis of the conduit 13, that is to say parallel to the flow of the liquid flow.
- this first face 57 is arranged along a wall of the duct 13 or slightly set back from this wall.
- tools can be inserted or removed from the drilling pipe 13, minimizing the risk of deterioration of the membrane member 55 by mechanical contact or shock.
- the circulation of the liquid parallel to the first face 57 limits the abrasion forces applied to the coating 65.
- the membrane support 63 is made from a porous material, for example a ceramic.
- the membrane support 63 is in the form of a disc. In the example illustrated in the drawings, the diameter of this support is substantially equal to 50 mm and its thickness is less than 10 mm.
- Examples of materials that can be used to make the membrane support 63 are sintered stainless steel, metallic fibers, or alumina.
- the pore size of the membrane support 63 is between 0.01 ⁇ m and 5 ⁇ m depending on the desired application. Preferably, the pore diameter is chosen between 0.02 ⁇ m and 3 ⁇ m.
- the coating 65 which constitutes the first face 57 of the membrane member 55 comprises a thin layer based on silicon carbide deposited on the support 63.
- the thickness of this layer is between 0.5 ⁇ m and 2 ⁇ m. This thin layer covers the surface of the support between the pores.
- the membrane member 55 is permeable to all of the gases present in the mud.
- the hardness of the first face 57 of the member 55 is greater than 1400 Vickers (kgf / mm2). In the example described in the Figures, this hardness is between 1400 and 1900 Vickers (kgf / mm2).
- the coating 65 is modified by grafting fluorinated polymer chains having a strong hydrophobic and oleophobic character. Preferably, this grafting is carried out on the basis of a perfluoroalkylethoxysilane.
- This modification of the coating 65 makes it possible to make the first face 57 of the membrane member 55 hydrophobic and oleophobic. Consequently, the wetting angle of the water on the first face 57 of the membrane member 55 is greater than 120 ° and substantially equal to 130 °.
- the membrane member 55 is thus impermeable to the liquid circulating in the conduit, which contributes to limiting the clogging of the pores of the support by solid residues originating from this liquid.
- the pipe 61 connecting the porous membrane member 55 and the analysis means 53 comprises a chamber 71 for receiving the gases, a pressure controller 73 in the chamber, means 75 for conveying the gases extracted from the reception chamber 71 to 'to the analysis means 53 and means 77 for filtering the extracted gases.
- the receiving chamber 71 covers the second face 59 of the membrane member, opposite the first face 57. It comprises a bell, provided with an inlet orifice 79 and an outlet orifice 81 connected respectively to the means conveyor 75 and pressure controller 73.
- the chamber pressure controller 73 comprises elements 83 for measuring the differential pressure between the liquid in the conduit and the gas in the chamber in connection with a pressure regulator 85 mounted on the conduit downstream of the chamber.
- This regulator 85 is controlled so that, when the device according to the invention is used for the analysis of the gases contained in the sludge, the pressure difference between the liquid circulating in the conduit 13 and the gas present in the receiving chamber 17 is substantially zero. This substantially zero pressure difference prevents the penetration of the liquid circulating in the conduit 13 into the membrane member 55.
- the means for conveying the extracted gases comprise means 87 for introducing a carrier gas into the receiving chamber 71 through the inlet orifice 79.
- the carrier gas is, for example, nitrogen or air.
- a mass flow regulator 89 fixes the flow of carrier gas entering the chamber 71 and consequently in the analysis means 53. Consequently, the dilution of the extracted gases is constant as a function of time.
- a volume flow meter 91 is mounted on the pipe 61 downstream of the filtration means 77 to measure the gas flow resulting from the carrier gas and the extracted gases.
- the filtration means 77 are arranged on the pipe downstream from the pressure regulator 85. These filtration means 77 notably eliminate the water vapor present in the extracted gases. They consist for example of a desiccator based on silica gel filter cartridges, a molecular sieve or a coalescer filter.
- the analysis means 53 include instrumentation 93 allowing the detection and quantification of one or more extracted gases and a computer 95 for determining the gas concentration in the liquid flowing in the conduit 13.
- the instrumentation includes, for example, infrared detection devices for the quantification of carbon dioxide, FID chromatographs (flame ionization detector) for the detection of hydrocarbons or TCD (thermal conductivity detector), depending on the gases. to analyze.
- FID chromatographs flame ionization detector
- TCD thermo conductivity detector
- the analysis means also comprise a sensor 97 for measuring the temperature of the liquid flowing in the duct 13.
- the computer 95 includes a memory 99 containing calibration charts and a processor 101 for implementing a calculation.
- the calibration charts are established according to the temperature, the flow and the characteristics of the mud. They contain data which relate the concentration of one or more gases in the mud to the concentration of gases extracted from this mud through the membrane organ, as measured using instrumentation.
- the calculation algorithm determines the actual quantities of gas in the mud from the measurements made by the instrumentation 93, the temperature measured in the conduit 13 by the sensor 97 and data contained in the memory 99.
- the concentration of the gases in the mud is determined individually or cumulatively.
- the drilling tool 15 is rotated by the surface installation 41.
- a drilling liquid is introduced into the interior space 35 of the drilling string 29 by the injection means 43. This liquid descends to the drilling head 27, and passes into the drilling conduit 13 through the drilling head 27. This liquid cools and lubricates the drilling means 33. Then, the liquid collects the solid cuttings resulting from the drilling and rises by the annular space defined between the drill string 29 and the walls of the drilling conduit 13. The flow of this liquid is substantially parallel to these walls.
- the liquid therefore circulates continuously along the first face 57 of the membrane member 55.
- a fraction of the gas present in the liquid is extracted through the membrane member 55 and enters the extraction chamber 71.
- the controller 73 of pressure in the chamber 71 is activated so that the differential pressure between the chamber 71 and the drilling pipe 13 is substantially zero. Thus, the penetration of the liquid into the membrane member 55 is avoided.
- the extracted gases are then entrained by the carrier gas from the extraction chamber 71 through the outlet orifice 81, the pressure regulator 85 and the filtration means 77, to the analysis means 53.
- the extracted gases are then analyzed by the instrumentation 63 and the computer 95 determines the actual concentration of the gas or gases analyzed in the drilling mud as a function of time.
- the sampling head 51 is installed in a bypass 111 of the drilling pipe 13.
- Isolation means such as an inlet valve 113 and an outlet valve 115 are provided at the ends of this branch 111, on either side of the head 51 to isolate this branch and easily disassemble the sampling head 51. In this configuration, the risk of deterioration of the membrane member 55 by mechanical contact or shock during the introduction and circulation of tools in the drilling pipe 13 is minimized.
- a recirculation pipe 121 is provided for conveying the liquid extracted from the vibrating screen 45 to the means 43 for injecting the liquid into the interior space 35 of the drill string 29.
- the measuring head 51 of the first device 19 is disposed on the discharge pipe 25 in the upstream part of this pipe, that is to say at the level of the well head 23.
- the measuring head 51 A of the second device 19A is arranged on the injection pipe 123 between the injection means 43 and the injection head 31. It is thus possible to quantify the difference between the gaseous content of the liquid leaving the drilling pipe 13 and the gaseous content of the liquid reinjected after degassing on the filter screen 45.
- the sampling head 51 comprises two porous membrane members 55, 55A.
- Each porous membrane member 55, 55A is associated with a receiving chamber 71, 71 A of the extracted gases each comprising an inlet orifice 79, 79A and an outlet orifice 81, 81 A.
- the inlet orifice of the first chamber is connected to the conveying means 75.
- the outlet orifice 81 of the first chamber is connected to the inlet orifice 79A of the second chamber 71 A by the line 61.
- the carrier gas is brought into the first chamber 71 via the inlet port 79 of this first chamber 71.
- This gas brings the gases extracted in the first chamber 71 to the second chamber 71A through the outlet port 81, the pipe 61 and the inlet orifice 79A of the second chamber 71A.
- the second chamber 71A therefore receives a mixture containing the gases extracted in the first chamber 71 and the carrier gas.
- This mixture then receives the gas extracted in the second chamber 71A, which enriches it with gas from the drilling pipe 13 and facilitates the detection of the gases extracted by the analysis means 53.
- the support 63 of the porous membrane member has a face which has a hardness greater than 1400 Kgf / mm 2 , in particular between 1400 and 1900 Kgf / mm 2 , without a coating based on silicon carbide being is necessary.
- the membrane organ of this type can be made of ⁇ alumina.
- the membrane support is made from an organic material such as for example polytetrafluoroethylene and comprises a coating of silicon carbide.
- heating means are installed on the drilling pipe upstream of the device according to the invention relative to the direction of circulation of the drilling fluid to facilitate the extraction of dissolved or free gases.
- the device and the heating means are arranged in a bypass in which the mud circulates freely or assisted.
- a device is obtained for the precise and continuous analysis of the gases contained in an abrasive liquid circulating in a drilling installation in a basement.
- Membrane members of various types and geometries can be used in this device, depending on the characteristics of the drilling fluid and the configuration of the wellbore.
- this device can be manufactured from membranes of simple geometries and readily available as flat discoid membranes.
- This device is not selective and allows the analysis of individual or cumulative concentrations of a plurality of dissolved or free gases in the drilling fluid.
- This device also has the advantage of minimizing the risk of deterioration of the device during the introduction and circulation of objects in the drilling pipe.
- This device also makes it possible to greatly limit the clogging of the membranes and the resulting yield losses.
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)
- Separation Using Semi-Permeable Membranes (AREA)
- Earth Drilling (AREA)
Abstract
Description
Claims
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
FR0305131A FR2854197B1 (en) | 2003-04-25 | 2003-04-25 | DEVICE FOR ANALYZING AT LEAST ONE GAS CONTAINED IN A LIQUID, IN PARTICULAR A DRILLING FLUID. |
PCT/FR2004/000953 WO2004097175A2 (en) | 2003-04-25 | 2004-04-16 | Device for analysing at least one gas contained in a liquid, particularly bore fluid |
Publications (2)
Publication Number | Publication Date |
---|---|
EP1618284A2 true EP1618284A2 (en) | 2006-01-25 |
EP1618284B1 EP1618284B1 (en) | 2007-08-15 |
Family
ID=33104418
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP04742533A Expired - Lifetime EP1618284B1 (en) | 2003-04-25 | 2004-04-16 | Device for analysing at least one gas contained in a liquid, particularly bore fluid |
Country Status (9)
Country | Link |
---|---|
US (1) | US7748266B2 (en) |
EP (1) | EP1618284B1 (en) |
AR (1) | AR044089A1 (en) |
AT (1) | ATE370312T1 (en) |
CA (1) | CA2523380C (en) |
DE (1) | DE602004008255D1 (en) |
ES (1) | ES2291897T3 (en) |
FR (1) | FR2854197B1 (en) |
WO (1) | WO2004097175A2 (en) |
Families Citing this family (24)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
FR2885165B1 (en) * | 2005-04-27 | 2008-12-05 | Geoservices | DEVICE FOR EXTRACTING AT LEAST ONE GAS CONTAINED IN A DRILLING MUD, ANALYZING ASSEMBLY AND METHOD FOR EXTRACTING THE SAME |
GB2445745B (en) * | 2007-01-17 | 2009-12-09 | Schlumberger Holdings | System and method for analysis of well fluid samples |
US20100050761A1 (en) * | 2008-08-26 | 2010-03-04 | SchlumbergerTechnology Corporation | Detecting gas compounds for downhole fluid analysis |
US8904859B2 (en) | 2008-08-26 | 2014-12-09 | Schlumberger Technology Corporation | Detecting gas compounds for downhole fluid analysis |
GB201001833D0 (en) | 2010-02-04 | 2010-03-24 | Statoil Asa | Method |
RU2544342C2 (en) * | 2010-01-13 | 2015-03-20 | Сантос Лтд | Measurement of gas content in non-traditional container rocks |
EP2444802A1 (en) * | 2010-10-22 | 2012-04-25 | Geoservices Equipements | Device for analyzing at least one hydrocarbon contained in a drilling fluid and associated method. |
US20130319104A1 (en) * | 2011-02-17 | 2013-12-05 | Neil Patrick Schexnaider | Methods and systems of collecting and analyzing drilling fluids in conjunction with drilling operations |
BR102014011707B1 (en) * | 2013-05-17 | 2021-06-15 | Schlumberger Technology B.V. | MEASUREMENT DEVICE, WELL BOTTOM TOOL, AND METHOD |
CA2921151C (en) * | 2013-09-25 | 2019-02-19 | Halliburton Energy Services, Inc. | Real time measurement of mud logging gas analysis |
US20150107349A1 (en) * | 2013-10-17 | 2015-04-23 | Schlumberger Technology Corporation | Mud logging depth and composition measurements |
US10844712B2 (en) * | 2014-08-11 | 2020-11-24 | Schlumberger Technology Corporation | Devices and methods for measuring analyte concentration |
CA2992175A1 (en) | 2015-08-27 | 2017-03-02 | Halliburton Energy Services, Inc. | Sample degasser dilution control system |
US9546891B1 (en) * | 2016-02-18 | 2017-01-17 | Ian Padden | Flow measuring system having a housing with a flow measurement device and a deflector plate attached over a hole in a riser |
TWI577966B (en) * | 2016-04-11 | 2017-04-11 | 財團法人國家實驗研究院 | Composite hydrological monitoring system |
US20190277729A1 (en) * | 2016-10-31 | 2019-09-12 | Abu Dhabi National Oil Company | Methods and systems for sampling and/or analyzing fluid, such as production fluid from an oil and gas well |
GB2589500B (en) * | 2018-06-12 | 2022-10-26 | Baker Hughes Holdings Llc | Gas ratio volumetrics for reservoir navigation |
US10704347B2 (en) * | 2018-06-25 | 2020-07-07 | Schlumberger Technology Corporation | Method and apparatus for analyzing gas from drilling fluids |
US11255191B2 (en) * | 2020-05-20 | 2022-02-22 | Halliburton Energy Services, Inc. | Methods to characterize wellbore fluid composition and provide optimal additive dosing using MEMS technology |
US11255189B2 (en) | 2020-05-20 | 2022-02-22 | Halliburton Energy Services, Inc. | Methods to characterize subterranean fluid composition and adjust operating conditions using MEMS technology |
US11060400B1 (en) | 2020-05-20 | 2021-07-13 | Halliburton Energy Services, Inc. | Methods to activate downhole tools |
US11530610B1 (en) | 2021-05-26 | 2022-12-20 | Halliburton Energy Services, Inc. | Drilling system with fluid analysis system |
CN116054530A (en) | 2021-10-28 | 2023-05-02 | 力智电子股份有限公司 | Control circuit of power supply conversion device and control method thereof |
US20230175393A1 (en) * | 2021-12-08 | 2023-06-08 | Halliburton Energy Services, Inc. | Estimating composition of drilling fluid in a wellbore using direct and indirect measurements |
Family Cites Families (9)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3673864A (en) * | 1970-12-14 | 1972-07-04 | Schlumberger Technology Corp | Methods and apparatus for detecting the entry of formation gases into a well bore |
US3731530A (en) * | 1972-03-20 | 1973-05-08 | Schlumberger Technology Corp | Apparatus for determining the gas content of drilling muds |
US5351532A (en) * | 1992-10-08 | 1994-10-04 | Paradigm Technologies | Methods and apparatus for making chemical concentration measurements in a sub-surface exploration probe |
CA2236615C (en) * | 1998-04-30 | 2006-12-12 | Konstandinos S. Zamfes | Differential total-gas determination while drilling |
GB2363809B (en) * | 2000-06-21 | 2003-04-02 | Schlumberger Holdings | Chemical sensor for wellbore applications |
US7318343B2 (en) * | 2002-06-28 | 2008-01-15 | Shell Oil Company | System for detecting gas in a wellbore during drilling |
EA012141B1 (en) * | 2003-11-21 | 2009-08-28 | Бейкер Хьюз Инкорпорейтед | Method and apparatus downhole fluid analysis using molecularly imprinted polymers |
CN1946920A (en) * | 2004-03-17 | 2007-04-11 | 贝克休斯公司 | Method and apparatus for downhole fluid analysis for reservoir fluid characterization |
US7240546B2 (en) * | 2004-08-12 | 2007-07-10 | Difoggio Rocco | Method and apparatus for downhole detection of CO2 and H2S using resonators coated with CO2 and H2S sorbents |
-
2003
- 2003-04-25 FR FR0305131A patent/FR2854197B1/en not_active Expired - Fee Related
-
2004
- 2004-04-16 EP EP04742533A patent/EP1618284B1/en not_active Expired - Lifetime
- 2004-04-16 DE DE602004008255T patent/DE602004008255D1/en not_active Expired - Lifetime
- 2004-04-16 WO PCT/FR2004/000953 patent/WO2004097175A2/en active IP Right Grant
- 2004-04-16 ES ES04742533T patent/ES2291897T3/en not_active Expired - Lifetime
- 2004-04-16 CA CA002523380A patent/CA2523380C/en not_active Expired - Fee Related
- 2004-04-16 AT AT04742533T patent/ATE370312T1/en active
- 2004-04-16 US US10/554,201 patent/US7748266B2/en not_active Expired - Fee Related
- 2004-04-23 AR ARP040101405A patent/AR044089A1/en unknown
Non-Patent Citations (1)
Title |
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See references of WO2004097175A2 * |
Also Published As
Publication number | Publication date |
---|---|
WO2004097175A2 (en) | 2004-11-11 |
US7748266B2 (en) | 2010-07-06 |
FR2854197A1 (en) | 2004-10-29 |
WO2004097175A3 (en) | 2005-02-17 |
FR2854197B1 (en) | 2005-07-22 |
EP1618284B1 (en) | 2007-08-15 |
AR044089A1 (en) | 2005-08-24 |
DE602004008255D1 (en) | 2007-09-27 |
CA2523380C (en) | 2009-10-06 |
US20090293605A1 (en) | 2009-12-03 |
ATE370312T1 (en) | 2007-09-15 |
CA2523380A1 (en) | 2004-11-11 |
ES2291897T3 (en) | 2008-03-01 |
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