WO2012040339A1 - Low cut water sampling device - Google Patents
Low cut water sampling device Download PDFInfo
- Publication number
- WO2012040339A1 WO2012040339A1 PCT/US2011/052572 US2011052572W WO2012040339A1 WO 2012040339 A1 WO2012040339 A1 WO 2012040339A1 US 2011052572 W US2011052572 W US 2011052572W WO 2012040339 A1 WO2012040339 A1 WO 2012040339A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- fluids
- inner chamber
- conduit
- vessel
- well
- Prior art date
Links
- 238000005070 sampling Methods 0.000 title claims abstract description 33
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims description 63
- 239000012530 fluid Substances 0.000 claims abstract description 206
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 73
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 73
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 64
- 238000004891 communication Methods 0.000 claims abstract description 30
- 230000006854 communication Effects 0.000 claims abstract description 30
- 238000004519 manufacturing process Methods 0.000 claims abstract description 20
- 238000000034 method Methods 0.000 claims description 19
- 230000005484 gravity Effects 0.000 claims description 4
- 239000000203 mixture Substances 0.000 claims description 4
- 238000012360 testing method Methods 0.000 claims description 2
- 238000011282 treatment Methods 0.000 description 7
- 238000000926 separation method Methods 0.000 description 6
- 238000004458 analytical method Methods 0.000 description 4
- 102100026933 Myelin-associated neurite-outgrowth inhibitor Human genes 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 3
- 238000013019 agitation Methods 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 230000018109 developmental process Effects 0.000 description 2
- 239000007789 gas Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 230000000737 periodic effect Effects 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-M Bicarbonate Chemical compound OC([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-M 0.000 description 1
- 235000008733 Citrus aurantifolia Nutrition 0.000 description 1
- 235000011941 Tilia x europaea Nutrition 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- -1 and thus Substances 0.000 description 1
- 238000013459 approach Methods 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000002844 continuous effect Effects 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 230000008878 coupling Effects 0.000 description 1
- 238000010168 coupling process Methods 0.000 description 1
- 238000005859 coupling reaction Methods 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- 238000000921 elemental analysis Methods 0.000 description 1
- 238000007667 floating Methods 0.000 description 1
- 150000004677 hydrates Chemical class 0.000 description 1
- 239000003112 inhibitor Substances 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 239000004571 lime Substances 0.000 description 1
- 230000000670 limiting effect Effects 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000000051 modifying effect Effects 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000003921 oil Substances 0.000 description 1
- 238000013439 planning Methods 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 239000000725 suspension 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
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
- E21B49/086—Withdrawing samples at the surface
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
-
- 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
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N1/00—Sampling; Preparing specimens for investigation
- G01N1/02—Devices for withdrawing samples
- G01N1/10—Devices for withdrawing samples in the liquid or fluent state
- G01N1/20—Devices for withdrawing samples in the liquid or fluent state for flowing or falling materials
- G01N1/2035—Devices for withdrawing samples in the liquid or fluent state for flowing or falling materials by deviating part of a fluid stream, e.g. by drawing-off or tapping
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N1/00—Sampling; Preparing specimens for investigation
- G01N1/28—Preparing specimens for investigation including physical details of (bio-)chemical methods covered elsewhere, e.g. G01N33/50, C12Q
- G01N1/40—Concentrating samples
- G01N1/4077—Concentrating samples by other techniques involving separation of suspended solids
- G01N2001/4083—Concentrating samples by other techniques involving separation of suspended solids sedimentation
Definitions
- This invention relates generally to the produclion of hydrocarbons from an earthen formation. - More particularly, the invention relates to a method and system for sampling a low water-cut hydrocarbon stream.
- water may be produced along with the hydrocarbons.
- Hi e water is typically intermixed with, or in suspension with crude oil, gas, or other hydrocarbon fluids, but does not form a solution with the hydrocarbon fluids.
- the percentage of water mixed with hydrocarbons produced from hydrocarbon producing wells, also referred to as the "water cut,” is greater than 10% (by volume).
- some wells produce a very low water cut stream of hydrocarbons. Separation of the water and hydrocarbons in such low cut production streams is typically more dilTicult as compared to high cut production streams.
- Sampling and analysis of the water produced from a well serves several purposes.
- the well may be treated with certain compounds to improve production or to prevent certain adverse conditions.
- Such treatments may include injection of water containing surfactants or polymers.
- these treatments may include anticorrosion treatments (corrosion inhibitor added), or treatments to prevent the formation of hydrates or deposition of paraffi ns or salts.
- These treatments facilitate transport of the fluid to the surface and/or prevent oil deposits.
- the relative volumes of the physical and/or chemical characteristics of these treatments in water or other fluids can vary considerably as a function of time.
- One way to monitor and adjust such treatments is to sample and analyze the produced water to determine the quantities and characteristics of the additives in the water.
- the water characteristics analyzed and evaluated typically include without limitation, resistivity, density, pH, conductivity, bicarbonate alkalinity, and quantitative elemental analysis. Water samples can also be used to analyze the source of the fluids produced for multi-zonal completion wel ls. This in formation may be used in reservoir development and depletion plann ing.
- the apparatus comprises a vessel having an inner chamber.
- the apparatus comprises a hydrocarbon fluids outlet conduit in fluid communication with the inner chamber.
- the apparatus comprises a well fluids inlet conduit coaxially disposed within the hydrocarbon fluids outlet conduit and in fluid communication with the inner chamber.
- the well fluids inlet conduit has a fi rst portion extending from the vessel and a second portion extending into the inner chamber.
- the second portion of the well fluids in let conduit includes a plurality of openings con fi gured to direct the well production fluids radially outward from the well fluids inlet conduit.
- the apparatus compri ses a sample fluids outlet in fluid commun ication with the inner chamber.
- the method comprises (a) continuously flowing produced well fluids lo a sampling device.
- the sampling device compri ses a vessel having an inn er chamber, a hydrocarbon fluids outlet conduit in fluid communication with the inner chamber, and a well fluids inlet conduit coaxially disposed within the hydrocarbon fluids outlet conduit and in fluid communication with the inner chamber.
- the method comprises (b) flowing the produced well fluids through the well fluids inlet conduit into the inner chamber of the vessel.
- the method comprises (c) allowing a sample fluid i n the produced well fluids to separate from one or more hydrocarbon fluids in the produced well fluids to a lower portion of the inner chamber under the force of gravity.
- the method comprises (d) withdrawing a sample of the sample fluid from the vessel through the sample fluids outlet.
- the apparatus comprises a vessel having an inner chamber.
- the apparatus compri ses a hydrocarbon fluids outlet conduit coupled to the vessel.
- the apparatus comprises a well fluids inlet conduit extending coaxially through the hydrocarbon fluids outlet conduit into the i nner chamber.
- the apparatus comprises a sample fluids outlet positioned at a lower end of the vessel and in fluid communication with the inner chamber.
- the apparatus comprises an annulus radially disposed between the hydrocarbon fluids outlet conduit and the well fluids inlet conduit. The annulus has an inlet end in fluid communication with the inner chamber.
- Embodiments descri bed herein compri se a combination of features and advantages intended to address vari ous shortcomi ngs associated with certain pri or devices, systems, and methods.
- the various characteristics described above, as wel l as other features, will be readily apparent to those ski lled in the art upon reading the following detailed descri ption, and by referring lo the accompanyi ng drawings.
- Figure 1 is a schematic view of an offshore installat ion including an embodiment of a low cut water sampler in accordance with the pri nciples described herein;
- Figure 2 is a front view of the low cut water sampler of Figure 1 ;
- Figure 3 is a front view of the low cut water sampler of Figure 1 being supplied produced well fluids and before oulputting separated hydrocarbon fluids or water;
- Figure 4 is an enlarged view of the lower end of (he inlet conduit of the low cut water sampler of Figure I being supplied produced wel l fluids and oulputting separated hydrocarbon fluid and water.
- the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to... .”
- the term “couple” or “couples” is intended to mean cither an indirect or direct connection.
- i f a fi rst device couples to a second device, that connection may be through a direct connection, or through an indirect connection via other devices, components, and connections.
- axial and axially generally mean along or parallel to a central axis (e.g., central axis of a body or a port), whi le the terms “radial” and “radially” generally mean perpendicular to the central axis.
- an axial distance refers to a distance measured along or parallel to the central axis
- a radi al distance means a distance measured perpendicular to the central axis.
- low cut refers to produced well fluids with less than about 10% water composition (by volume)
- high cut refers to produced well fluids with greater than about 10% water composition (by volume).
- system 10 for producing a completed subterranean wellbore 1 1 is schematically shown.
- system 10 includes an offshore platform 20 at the sea surface 12, a subsea production manifold 30 mounted to a wellhead 31 at the sea floor 13, and a production riser 40 extending from mani fold 30 to platform 20.
- riser 40 is a large-di ameter pipe that connects mani fold 30 to the floating platform 20.
- Casing 32 extends from wellhead 3 1 into subterranean wellbore 1 1 .
- System 10 also includes a water sampling device 100 for sampling low cut well fluids produced through riser 40.
- device 100 receives samples of produced well fluids from riser 40, separates the water from the produced well fluids, outputs the separated water for subsequent analysis, and outputs the balance of the produced well fluids (following separation of the water).
- the produced well fluids flowing through riser 40 typically comprise hydrocarbon fluids (e.g. liquid hydrocarbons such as crude oil and/or hydrocarbon gases such as natural gas) and water.
- hydrocarbon fluids e.g. liquid hydrocarbons such as crude oil and/or hydrocarbon gases such as natural gas
- the balance or remainder of the produced well fluids after separation of the water in device 100 is predominantly hydrocarbon fluids, it being understood that such fluids may include small quantities of water, solids (e.g., sand), or other fluids.
- a production sample conduit or flowline 50 supplies produced wellbore fluids from ri ser 40 to sampling device 100. Samples of the water in the produced well fluids i n riser 40 may be obtained continuously with device 100 via flowline 50 to determi ne the composition of the water therein .
- sampling device 100 is shown disposed on platform 20, device 100 may be disposed at any suitable offshore or onshore location.
- sample flowline 50 may extend from platform 20 to a different offshore or onshore location for sampling with device 100 and subsequent analysis of the separated water.
- water sampling device 100 includes a produced well fluids inlet conduit 1 10, a separator containment vessel 120, a sample fluid outlet 130, a separated hydrocarbon fluids outlet conduit 140, and a hydrocarbon fluids outlet fi tting or coupling 150.
- Vessel 120 has an inner chamber 12 1 .
- sample fluid outlet 130 may also be referred to as a water outlet.
- Inlet conduit 1 10, water outlel 130, and hydrocarbon outlet condui t 140 are each in fluid communication with inner chamber 12 1.
- produced well fluids designated with reference numeral 160
- separated water samples designated with reference numeral 161
- hydrocarbon fluids designated with reference numeral 162 and resulting from the separation of water 161 from well fluids 160, exit chamber 12 1 via outlet conduit 140 and fi tting 1 50.
- Flowline 50 previously descri bed is coupled to inlet conduit 1 10, and thus, supplies produced well fluids to chamber 12 1 via inlet conduit 1 10.
- separator vessel 120 may be any suitable vessel or container compatible with potentially corrosive well fluids and capable of withstanding relatively high pressures.
- vessel 120 is preferably a containment vessel or tank designed and con fi gured to wi thstand pressures of at least about 285 psi, alternatively about 1 ,000 psi, alternati vely about 5,000 psi, alternatively about 10,000 psi, and alternatively about 20,000 psi.
- vessel 120 is an elongate upright generally cylindrical tan k having an upper end 120a and a lower end 120b opposite upper end 120a.
- Upper end 120a includes a port 122 and lower end 120b includes a port 123.
- Conduits 1 10, 140 extend through port 122 into inner chamber 121 , and water outlet 1 0 is in fluid commun ication with port 123.
- vessel 120 is a cylindrical upright vessel in this embodiment, in other embodiments the separator vessel (e.g., vessel 120) may have other suitable geometries such as rectangular, spheri cal, etc.
- vessel 120 and inner chamber 121 may have any suitable volume. However, for embodiments described herein, vessel 120 is preferably sized such that chamber 121 has a volume between 1 liter and 4 liters.
- outlet conduit 140 extends through port 122 and is secured to vessel 120.
- conduit 140 may be positioned in port 122 and then welded to vessel 120.
- outlet conduit 140 is a tubular having a central axis 1 45, a fi rst or upper end 140a disposed outside and above vessel 120, and a second or lower end 1 40b disposed within chamber 121 .
- hydrocarbon fluids 162 flow from chamber 121 into end 140b, through conduit 140, and out end 140a into fi tting 150.
- lower end 140b may also be referred to as an inlet end
- upper end 140a may also be referred to as an outlet end.
- Fi tting 150 is a tubular mani fold including a main bore or passage 15 1 , a fi rst lateral bore or passage 1 52 extending from main bore 15 1 , and a second lateral bore or passage 153 extendin g from main bore 151.
- Main bore 1 51 is coaxially aligned with outlet conduit 140 and has a fi rst or upper end 151 a distal conduit 140, and a second or lower end 15 1 b in fluid communication with conduit 140.
- lower end 151 b receives hydrocarbon fluids 162 from chamber 12 1 via conduit 140, and thus, may also be refen ed to as hyilrocarbon fluids inlet end 1 51 b.
- Each lateral bore 152, 153 has an inlet end 1 52a, 153a, respectively, in fluid communication with main bore 1 51 between ends 1 51 a, b, and an outlet end 152b, 153b, respectively.
- outlet end 152b is in fluid communication with a sensor 154.
- sensor 154 may comprise any suitable type of sensor or gauge for monitoring one or more parameters of the fluids in chamber 122 such as pressure, temperature, flow rate, etc.
- inlet conduit 1 10 extends through main bore 151 of fi tting 150 and outlet conduit 140 into vessel 120.
- inlet conduit 1 10 is a tubular having a central axis 1 1 5, a fi rst or inlet end 1 10a extending from main bore 151 distal vessel 120, and a second or closed end 1 10b disposed in chamber 12 1.
- Conduit 1 10 is coaxially aligned with main bore 1 51 of fitting 1 50 and outlet conduit 140, and thus, central axes 1 15, 145 arc coincident.
- Conduit 1 10 is preferably positioned such that end 1 10b is disposed in the upper half of separator chamber 12 1.
- annulus 1 14 is radially positioned between inlet conduit 110 and fi tting 150, outlet conduit 1 40. Annulus 1 14 extends from end 140b of conduit 140 to upper end 151 a of main bore 151 .
- annulus 1 14 has a first or upper end 1 14a coincident with upper end 151 a of main bore 15 1 and a second or lower end 1 14b coinciden t with inlet end 140b of conduit 140.
- Annulus 1 14 is closed off and sealed at upper end 1 1 4a with a cap 1 16 that extends radially across main bore 151 from inlet conduit 1 10 lo fi tting 1 50.
- lower end 1 14b of annulus 1 14 is open lo chamber 120. Lateral bores 152, 153 are in fluid communication with annulus 1 14. As will be described in more detail below, hydrocarbon fluids 162 (low from chamber 12 1 into end 1 14b of ann ulus 1 14, through annulus 1 14, and out end 1 14a of annulus 1 14 into lateral bores 152, 153. Thus, lower end 1 14b may also be referred to as an inlet end.
- the portion of inlet conduit 1 10 extending into chamber 121 includes a plurality of through bores or open ings 1 12 proximal closed end 1 10b. Openings 1 12 extend radially through conduit 1 10 proximal end 1 10b and allow produced well fluids 160 flowing through conduit 1 10 to exit inlet conduit 1 10 in a radial fashion to minimize agitation and mixing of fluids within chamber 12 1. Accordingly, each opening 1 12 may be described as an outlet port. As best shown in Figure 4, in this embodiment, openings 1 12 arc arranged in a plurality of axially spaced rows 1 12a, b, c, d.
- Openings 1 12 within each row 1 12a, b, c, l are circumferentially spaced about conduit 1 10, and further, openings 1 12 in each row 1 12a, b, c, d are circumferentially offset or staggered relative to the openings 1 12 in the adjacent row(s) 1 12a, b, c, d.
- each row 1 12a, b, c, d includes two openings 1 12 spaced 180° apart, with openings 1 12 in adjacent row s 1 12 a, b, c, d being circumferentially staggered 90° apart.
- each row may have more or less openings (e.g., openings 1 12) and/or the openings in each row may be circumferentially spaced by more or less than 180°.
- openings 1 12 are shown as circular holes in Figure 4, in general, openings 1 12 may have any suitable geometry (e.g., oval, rectangular, elliptical, etc.).
- water outlet 130 is coupled to vessel 120 and extends from port 123.
- outlet 130 includes a valve 1 1 for selectively opening and closing outlet 130. More speci fi cally, valve 131 has a closed position restricting and/or preventing fluid flow through outlet 130, and an open position allowing fluid flow through outlet 130.
- produced well fluids 160 are supplied to inlet conduit 1 10 via production sample flowline 50. Fluids 1 60 flow through conduit 1 10 and radially outward through open ings 1 12 into chamber 12 1. As previously described, the radial ejection of the produced well fluids 160 from conduit 1 10 offers the potential to reduce and or prevent mixing and agitation of the separated water 161 and hydrocarbon fluids 162 within separator chamber 121 . As desired, produced well fluids 160 may be provided to vessel 120 continuously or on a periodic basis.
- any water 161 in the produced well fluids 160 begins to migrate or settle to the bottom of separator chamber 12 1 and the hydrocarbon fluids 162 move to the upper portion of chamber 121 . fn other words, gravity naturally drives the separation of the heavier water 161 from the lighter hydrocarbon fluids 162.
- Outlet 152b supplies hydrocarbon fluids 162 to sensor 154.
- Outlet 153b may be connected to a flowline or conduit that may direct the separated hydrocarbon fluids to any desired location (e.g., back into the produced well fluids downstream of conduit 50).
- Cap 1 16 prevents hydrocarbon fluids 162 from exiting annulus 1 1 4 at upper end 1 14a.
- Separated water 161 in the lower portion of chamber 121 may be drawn off through outlet 130 for testing by opening valve 131 . Initially, and between sampling of water 161 within chamber 12 1, valve 131 is preferably closed.
- sampling devices for sampling produced well fluids e.g., device 100
- device 100 In the manner descri bed, embodiments of sampling devices for sampling produced well fluids (e.g., device 100) rely on gravity separation to cost effi ciently separate water or other fluids from the produced hydrocarbon fluids for sampling purposes.
- embodiments of device 100 allow for continuous sampling of produced well fluids over a period of lime.
- embodiments of the apparatus provide a very low cost solution to separating the small percentage of water in low cut produced fluids.
- embodiments of the apparatus are capable of withstanding extremely high pressures.
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- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Geochemistry & Mineralogy (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Analytical Chemistry (AREA)
- Health & Medical Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Hydrology & Water Resources (AREA)
- Biochemistry (AREA)
- General Health & Medical Sciences (AREA)
- General Physics & Mathematics (AREA)
- Immunology (AREA)
- Pathology (AREA)
- Sampling And Sample Adjustment (AREA)
Abstract
Description
Claims
Priority Applications (5)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CA2810771A CA2810771A1 (en) | 2010-09-21 | 2011-09-21 | Low cut water sampling device |
EP11767855.7A EP2618906A1 (en) | 2010-09-21 | 2011-09-21 | Low cut water sampling device |
EA201370075A EA201370075A1 (en) | 2010-09-21 | 2011-09-21 | THE DEVICE FOR THE SAMPLING OF SAMPLES, PRODUCED FROM THE WELLS OF THE CURRENT MEDIUMS AND IMPLEMENTED BY THE METHOD OF THE FENCE |
AU2011305492A AU2011305492A1 (en) | 2010-09-21 | 2011-09-21 | Low cut water sampling device |
BR112013005928A BR112013005928A2 (en) | 2010-09-21 | 2011-09-21 | "method and equipment for sampling well production fluids". |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US38480610P | 2010-09-21 | 2010-09-21 | |
US61/384,806 | 2010-09-21 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2012040339A1 true WO2012040339A1 (en) | 2012-03-29 |
Family
ID=44786095
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2011/052572 WO2012040339A1 (en) | 2010-09-21 | 2011-09-21 | Low cut water sampling device |
Country Status (7)
Country | Link |
---|---|
US (1) | US20120073806A1 (en) |
EP (1) | EP2618906A1 (en) |
AU (1) | AU2011305492A1 (en) |
BR (1) | BR112013005928A2 (en) |
CA (1) | CA2810771A1 (en) |
EA (1) | EA201370075A1 (en) |
WO (1) | WO2012040339A1 (en) |
Families Citing this family (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
NO340557B1 (en) * | 2015-05-18 | 2017-05-15 | Typhonix As | Choke valve separator |
US10481049B2 (en) * | 2017-11-28 | 2019-11-19 | Air Liquide Canada, Inc. | Cryogenic liquid sampler |
US10473561B2 (en) * | 2017-11-28 | 2019-11-12 | Air Liquide Canada, Inc. | Method of sampling a cryogenic liquid |
US20230168235A1 (en) * | 2021-11-19 | 2023-06-01 | United States Geological Survey | Particulate-based cumulative contaminant sampling device |
Citations (2)
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WO2002001044A1 (en) * | 2000-06-22 | 2002-01-03 | Den Norske Stats Oljeselskap A.S | Inclined separator for separating well fluids |
US6444001B1 (en) * | 2000-03-14 | 2002-09-03 | Glenn E. Sheffield | Separator and separator system |
Family Cites Families (20)
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US3499531A (en) * | 1969-06-25 | 1970-03-10 | Ind Service Co Inc | Cyclonic separation devices |
DE3070156D1 (en) * | 1979-08-09 | 1985-03-28 | British Petroleum Co Plc | Separator for oil, gas and water |
US4323122A (en) * | 1980-06-02 | 1982-04-06 | Knopik Dwayne L | Process for recovering organic liquids from underground areas |
US4476928A (en) * | 1982-07-23 | 1984-10-16 | Dimar Holding Corporation | Method and apparatus for solvent generation and recovery of hydrocarbons |
US5254292A (en) * | 1989-02-02 | 1993-10-19 | Institut Francais Du Petrole | Device for regulating and reducing the fluctuations in a polyphasic flow, and its use |
US5002657A (en) * | 1990-05-04 | 1991-03-26 | Botts John B | Separator for oil well production fluids |
US5232475A (en) * | 1992-08-24 | 1993-08-03 | Ohio University | Slug flow eliminator and separator |
US6730236B2 (en) * | 2001-11-08 | 2004-05-04 | Chevron U.S.A. Inc. | Method for separating liquids in a separation system having a flow coalescing apparatus and separation apparatus |
CA2396682C (en) * | 2002-08-02 | 2006-09-19 | Northland Energy Corporation | Method and apparatus for separating and measuring solids from multi-phase well fluids |
US7510597B2 (en) * | 2004-03-19 | 2009-03-31 | Shell Oil Company | Method and separator for cyclonic separation of a fluid mixture |
EP1593418A1 (en) * | 2004-05-06 | 2005-11-09 | Services Petroliers Schlumberger | A gravity separator for a multi-phase effluent |
EP1783101A1 (en) * | 2005-11-03 | 2007-05-09 | M-I Epcon As | Method and plant for purifying water |
GB0519119D0 (en) * | 2005-09-20 | 2005-10-26 | Colquhoun Ross | Apparatus and method |
EP1779911A1 (en) * | 2005-10-28 | 2007-05-02 | M-I Epcon As | A separator tank |
US8168071B2 (en) * | 2005-11-09 | 2012-05-01 | Suncor Energy Inc. | Process and apparatus for treating a heavy hydrocarbon feedstock |
US7569097B2 (en) * | 2006-05-26 | 2009-08-04 | Curtiss-Wright Electro-Mechanical Corporation | Subsea multiphase pumping systems |
GB0811307D0 (en) * | 2008-06-20 | 2008-07-30 | Ross Lamond Colquhoun | Test apparatus |
US8127867B1 (en) * | 2008-09-30 | 2012-03-06 | Bronco Oilfield Services, Inc. | Method and system for surface filtering of solids from return fluids in well operations |
EP2263767A1 (en) * | 2009-06-17 | 2010-12-22 | M-I Epcon As | A separator tank for separating oil and gas from water |
GB2495656B (en) * | 2010-08-05 | 2017-05-24 | Cameron Int Corp | Petroleum desalting utilizing voltage modulation |
-
2011
- 2011-09-21 US US13/238,726 patent/US20120073806A1/en not_active Abandoned
- 2011-09-21 CA CA2810771A patent/CA2810771A1/en not_active Abandoned
- 2011-09-21 EA EA201370075A patent/EA201370075A1/en unknown
- 2011-09-21 AU AU2011305492A patent/AU2011305492A1/en not_active Abandoned
- 2011-09-21 BR BR112013005928A patent/BR112013005928A2/en not_active Application Discontinuation
- 2011-09-21 WO PCT/US2011/052572 patent/WO2012040339A1/en active Application Filing
- 2011-09-21 EP EP11767855.7A patent/EP2618906A1/en not_active Withdrawn
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6444001B1 (en) * | 2000-03-14 | 2002-09-03 | Glenn E. Sheffield | Separator and separator system |
WO2002001044A1 (en) * | 2000-06-22 | 2002-01-03 | Den Norske Stats Oljeselskap A.S | Inclined separator for separating well fluids |
Also Published As
Publication number | Publication date |
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BR112013005928A2 (en) | 2016-05-17 |
AU2011305492A8 (en) | 2013-04-11 |
US20120073806A1 (en) | 2012-03-29 |
EP2618906A1 (en) | 2013-07-31 |
CA2810771A1 (en) | 2012-03-29 |
EA201370075A1 (en) | 2013-09-30 |
AU2011305492A1 (en) | 2013-03-28 |
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