CA2810771A1 - Low cut water sampling device - Google Patents
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- CA2810771A1 CA2810771A1 CA2810771A CA2810771A CA2810771A1 CA 2810771 A1 CA2810771 A1 CA 2810771A1 CA 2810771 A CA2810771 A CA 2810771A CA 2810771 A CA2810771 A CA 2810771A CA 2810771 A1 CA2810771 A1 CA 2810771A1
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- 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 74
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 74
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 65
- 238000004891 communication Methods 0.000 claims abstract description 31
- 238000004519 manufacturing process Methods 0.000 claims abstract description 21
- 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
- 230000008901 benefit Effects 0.000 description 4
- 238000013019 agitation Methods 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 238000011161 development Methods 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
- 241000282326 Felis catus Species 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
- 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
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- 238000005859 coupling reaction Methods 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- 238000000921 elemental analysis Methods 0.000 description 1
- 238000005516 engineering process 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
- 239000007788 liquid Substances 0.000 description 1
- 239000000463 material Substances 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
- 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
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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
An apparatus for sampling well production fluids comprises a vessel having an inner chamber. In addition, the apparatus comprises a hydrocarbon fluids outlet conduit in fluid communication with the inner chamber. Further, 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 first portion extending from the vessel and a second portion extending into the inner chamber. The second portion of the well fluids inlet conduit includes a plurality of openings configured to direct the well production fluids radially outward from the well fluids inlet conduit. Still further, the apparatus comprises a sample fluids outlet in fluid communication with the inner chamber.
Description
LOW CUT WATER SAMPLING DEVICE
CROSS-REFERENCE TO RELATED APPLICATIONS
100011 This application claims benefit of U.S. provisional patent application Serial No. 61./384,806 filed September 21, 2010, and entitled "Low Cut Water Sampler," which is hereby incorporated herein by reference in its entirety.
STATEMENT REGARDING FEDERALLY SPONSORED
RESEARCH OR DEVELOPMENT
100021 Not applicable.
BACKGROUND
Field of the Invention 100031 This invention relates generally to the production of hydrocarbons from an earthen formation.- More particularly, the invention relates to a method and system for sampling a low water-cut hydrocarbon stream.
Background of the Technology 100041 In hydrocarbon production operations, water may be produced along with the hydrocarbons. The 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.
In general, 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). However, some wells produce a very low water cat stream of hydrocarbons. Separation of the water and hydrocarbons in such low cut production streams is typically more difficult as compared to high cut production streams.
100051 Sampling and analysis of the water produced from a well serves several purposes. For example, during production, 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. In addition, these treatments may include anticorrosion treatments (corrosion inhibitor added), or treatments to prevent the formation of hydrates or "
deposition of paraffins 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 wells. This information may be used in reservoir development and depletion planning.
100061 One conventional method for sampling water from a produced hydrocarbon stream is to take an isolated direct sample from the pipeline at a single point in time, separate the water, and then analyze the separated water. Thus, with this approach, continuous sampling and analysis of the produced water over time cannot be obtained without repeatedly taking discrete samples from the pipeline. Furthermore, in produced well fluids with low water cut, it is difficult to separate the water and hydrocarbons.
100071 Accordingly, there remains a need in the art for improved systems and methods for sampling water from a produced hydrocarbon stream. Such systems and methods would be particularly well-received if they offered the potential for continuous sampling over time and could be employed with low water cut hydrocarbon streams. =
BRIEF SUMMARY Orl'HE DISCLOSURE
100081 These kind other needs in the art are addressed in one embodiment by an apparatus for sampling well production fluids. in an embodiment, the apparatus comprises a vessel having an inner chamber. in addition, the apparatus comprises a hydrocarbon fluids outlet conduit in fluid communication with the inner chamber. Further, 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 first portion extending from the vessel and a second portion extending into the inner chamber. The second portion of the well fluids inlet conduit includes a plurality of openings configured to direct the well production fluids radially outward from the well fluids inlet conduit. Still further, the apparatus comprises a sample fluids outlet in fluid communication with the inner chamber.
'These and other needs in the art arc addressed in another embodiment by a method of sampling produced well fluids. In an embodiment, the method comprises (a) continuously flowing produced well fluids to a sampling device. The sampling device comprises a vessel having an inner 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. hi addition, the method comprises (b) flowing the produced well fluids through the well fluids inlet conduit into the inner chamber of' the vessel.
Further, the method comprises (c) allowing a sample fluid -in 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. Still further, the method comprises (d) withdrawing a sample of the sample fluid from the vessel through the sample fluids outlet.
100091 These and other needs in the art are addressed in another embodiment by an apparatus for 'sampling well production fluids. In an embodiment, the apparatus comprises a vessel having an inner chamber. In addition, the apparatus comprises a hydrocarbon 'fluids outlet conduit coupled to the vessel. Further, the apparatus comprises a well fluids inlet conduit extending coaxially through the hydrocarbon fluids outlet conduit into the inner chamber. Still further, the apparatus comprises a sample fluids outlet positioned at a lower end of the vessel and in fluid communication with the inner chamber. Moreover, 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.
100101 The foregoing has outlined rather broadly the features and technical advantages of the invention in order that the detailed description of the invention that follows may be better understood. Additional features and advantages of the invention will be described hereinafter that form the subject of the claims of the invention. It should be appreciated by those skilled in the art . that the conception and the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes of the invention. It should also be realized by those skilled in the art that such equivalent constructions do not depart from the spirit and scope of the invention as set forth in the appended claims.
100111 Embodiments described herein comprise a combination of features and advantages intended to address various shortcomings associated with certain prior devices, systems, and methods. The various characteristics described above, as well as other features, will be readily apparent to those skilled in the art upon reading the fbIlowing, detailed description, and by referring to the accompanying drawings.
BRIEF DESCRIPTION OF THE DRAWINGS
100121 For a detailed description of the preferred embodiments of the invention, reference will now be made to the accompanying drawings in which:
100131 Figure 1 is a schematic view of an offshore installation including an embodiment of a low cut water sampler in accordance with the principles described herein;
100141 Figure 2 is a front view of the low cut water sampler of Figure 1;
100151 Figure 3 is a front view of the low cut water sampler of Figure I being supplied produced . well -fluids and before outputting separated hydrocarbon fluids or water;
and 100161 Figure 4 is an enlarged .view of the lower end of the inlet conduit of the low cut water sampler of Figure 1 being supplied produced well fluids and outputting separated hydrocarbon fluid and water.
DETAILED DESCRIPTION orrnE PREFERRED EMBODIMENTS
= 100171 The following discussion is directed to various exemplary embodiments. However, one skilled in the art will understand that the examples disclosed herein have broad application, and that the discussion of any embodiment is meant only to be exemplary of that embodiment, and not intended to suggest that the scope of the disclosure, including the claims, is limited to that embodiment.
100181 Certain terms are used throughout the following description and claims to refer to particular features or components. As one skilled in the art will appreciate, different persons may refer to the same feature or component by different names. This document does not intend to distinguish between components or features that differ in name but not .function. The drawing figures are not necessarily to scale. Certain features and components herein may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in interest of clarity and conciseness.
100101 In the following discussion and in the claims, the terms "including"
and "comprising" are used in an open-ended fashion, and thus should be interpreted to mean "including, but not limited to... ." Also, the term "couple" or "couples" is intended to mean either an indirect or direct connection. Thus, if a first 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. In addition, as used herein, the terms "axial" and "axially"
generally mean along or parallel to a central axis (e.g., central axis of a body or a port), while the terms "radial" and "radially" generally mean perpendicular to the central axis. For instance, an axial distance refers to a distance measured along or parallel to the central axis, and a radial distance means a distance measured perpendicular to the central axis. As used herein, the phrase "low cut" refers to produced well fluids with less than about -10% water composition (by volume), and the phrase "high cut"
refers to produced well fluids with greater than about 10% water composition (by volume).
100201 Referring now Figure 1, an offshore system 10 for producing a completed subterranean wellbore 11 is schematically shown. In this embodiment, 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 manifold 30 to platform 20. In general, riser 40 is a large-diameter pipe that connects manifold 30 to the floating platform 20.
During production operations, well fluids are produced through riser 40 to platform 20, where the produced fluids may be stored, processed, offloaded or combinations thereof. Casing 32 extends from wellhead 31 into subterranean wellbore 11.
100211 System 10 also includes a water sampling device 100 for sampling low cut well fluids produced through riser 40. As will be describe in more detail below, 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. Thus, 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. In this-embodiment, a production sample conduit or flowline 50 supplies produced wellbore fluids from riser 40 to sampling device 100. Samples of the water in the produced well fluids in riser 40 may be obtained continuously with device 100 via flowline 50 to determine the composition of the water therein. Although sampling device 100 is shown disposed on platform 20, device 100 may be disposed at any suitable offshore or onshore location. For examples, 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.
100221 Referring now to Figure 2, water sampling device 100 includes a produced well fluids inlet conduit 110, a separator containment vessel 120, a sample fluid outlet 130, a separated hydrocarbon fluids outlet conduit 140, and a hydrocarbon fluids outlet fitting or coupling 150.
Vessel 120 has an inner chamber 121. In this embodiment, water is sampled and separated from the produced well fluids, and thus, sample fluid outlet 130 may also be referred to as a water outlet.
Inlet conduit 110, water outlet 130, and hydrocarbon outlet conduit 140 are each in fluid communication with inner chamber 121. As will be described in more detail below, produced well fluids, designated with reference numeral 160, enter chamber 121 via inlet conduit 110; separated water samples, designated with reference numeral 161, may be taken from chamber 121 via outlet 130; and hydrocarbon fluids, designated with reference numeral 162 and resulting from the separation of water 161 from well fluids 160, exit chamber 121 via outlet conduit 140 and fitting 150. Flowline 50 previously described is coupled to inlet conduit 110, and thus, supplies produced well fluids to chamber 121 via inlet conduit 110.
100231 In general, separator vessel 120 may be any suitable vessel or container compatible with potentially corrosive well fluids and capable of withstanding relatively high pressures. In particular, vessel 120 is preferably a containment vessel or tank designed and configured to withstand pressures of at least about 285 psi, alternatively about 1,000 psi, alternatively about 5,000 psi, alternatively about 10,000 psi, and alternatively about 20,000 psi.
In this embodiment, vessel 120 is an elongate upright generally cylindrical tank having an upper end 120a and a lower end 120b opposite upper end 120a. Upper end 120a includes a port 122 and lower end 1201) includes a port 123. Conduits 110, 140 extend through port 122 into inner chamber 121, and water outlet 130 is in fluid communication with port 123. Although 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, spherical, etc. In general, 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.
100241 Referring still to Figure 2, as previously described, outlet conduit 140 extends through port 122 and is secured to vessel 120. For instance, conduit 140 may be positioned in port 122 and then welded to vessel 120. In this embodiment, outlet conduit 140 is a tubular having a central axis 145, a first or upper end 140a disposed outside and above vessel 120, and a second or lower end 140b disposed within chamber 121: As will be described in more detail below, hydrocarbon fluids 162 flow from chamber 121 into end 140b, through conduit 140, and out end 140a into fitting 150.
Thus, lower end 140b may also be referred to as an inlet end, and upper end 140a may also be referred to as an outlet end.
100251 Fitting 150 is coupled to upper end 140a of conduit 140. In this embodiment, fitting 150 is a tubular manifold including a main bore or passage 151, a first lateral bore or passage 152 extending from main bore 151, and a second lateral bore or passage 153 extending from main bore 151. Main bore 151 is eoaxially aligned with outlet conduit 140 and has a first or upper end 151a distal conduit 140, and a second or lower end 15Ib in fluid communication with conduit 140. As will be described in more detail below, lower end 151b receives hydrocarbon fluids 162 from chamber 121 via conduit 140, and thus, may also be referred to as hydrocarbon fluids inlet end 151b. Each lateral bore 152, 153 has an inlet end 152a, 153a, respectively, in fluid communication with main bore 151 between ends 151a, b, and an outlet end 152b, 153b, respectively. In this embodiment, outlet end 152b is in fluid communication with a sensor 154. In general, 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.
100261 Referring still to Figure 2, well fluids inlet conduit 110 extends through main bore 151 of fitting 150 and outlet conduit 140 into vessel 120. In this embodiment, inlet conduit 110 is a tubular having a central axis 11,5, a first or inlet end 110a extending from main bore 151 distal vessel 120, and a second or closed end 110b disposed in chamber 121. Conduit 110 is coaxially aligned with main bore 151 of fitting 150 and outlet conduit 140, and thus, central axes 115, 145 arc coincident. Conduit 110 is preferably positioned such that end 1101) is disposed in the upper half of separator chamber 121.
100271 The outer diameter of inlet conduit 110 is less than the inner diameter of main bore 151 and outlet conduit 140, and thus, an annulus 114 is radially positioned between inlet conduit 110 and fitting 150, outlet conduit 140. Annulus 114 extends from end 140b of conduit 140 to upper end 151a amain bore 151. Thus, annulus 114 has a first or upper end 114a coincident with upper end 151a of main bore 151 and a second or lower end 114b coincident with inlet end 140b of conduit 140. Annulus 114 is closed off and sealed at upper end 114a with a cap 116 that extends radially across main bore 151 from inlet conduit 110 to fitting 150. However, lower end 114b of annulus 114 is open to chamber 120. Lateral bores 152, 153 are in fluid communication with annulus 114.
As will be described in more detail below, hydrocarbon fluids 162 flow from chamber 121 into end 114b of annulus 114, through annulus 114, and out end 114a of annulus 114 into lateral bores 152, 151 Thus, lower end 114b may also be referred to as an inlet end.
100281 Relen-ing now to Figures 2 and 4, the portion of inlet conduit 110 extending into chamber 121 includes a plurality of through bores or openings 112 proximal closed end 1101). Openings 112 extend radially through conduit 110 proximal end 110b and allow produced well fluids 160 flowing through conduit 110 to exit inlet conduit 110 in a radial fashion to minimize agitation and mixing of fluids within chamber 121. Accordingly, each opening 112 may be described as an outlet port. As best shown in Figure 4, in this embodiment, openings 112 are arranged in a plurality of axially spaced rows 112a, b, c, d. Openings 112 within each row 112a, b, c, d are circumferentially spaced about conduit 110, and further, openings 112 in each row 112a, h, c, d are circumferentially offset or staggered relative to the openings 112 in the adjacent row(s) 112a, b, c, d. In this embodiment, each row 112a, b, c, d includes two openings 112 spaced 180 apart, with openings 112 in adjacent row s 112a, b, c, d being circumfbrentially staggered 90 apart. However, in other embodiments, each row (e.g., each row 112a, b, c, d) may have more or less openings (e.g., openings 112) and/or the openings in each row may be circumferentially spaced by more or less than 180 . Although openings 112 are shown as circular holes in Figure 4, in general, openings 112 may have any suitable geometry (e.g., oval, rectangular, elliptical, etc.).
100291 Referring again to Figure 2, water outlet 130 is coupled to vessel 120 and extends from port 123. In this embodiment, outlet 130 includes a valve 131 for selectively opening and closing outlet 130. More specifically, 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.
100301 Referring now to Figures 1 and 2, during production operations, produced well fluids 160 are supplied to. inlet conduit 110 via production sample [towline 50. Fluids -160 flow through conduit 110 and radially outward through openings 112 into chamber 121. As previously described, the radial ejection of the produced well fluids 160 from conduit 110 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.
100311 As best shown in Figure 2, without being limited by this or any particular theory, due to the difference in densities and the immiscibility between water 161 and hydrocarbon fluids 162 in produced well .fluids 160, any water 161 in the produced well fluids 160 begins to migrate or settle to the bottom of separator chamber 121 and the hydrocarbon fluids 162 move to the upper portion of chamber 121. En other words, gravity naturally drives the separation of the heavier water 161 from the lighter hydrocarbon fluids l 62.
100321 Moving now to Figure 3, as produced well fluids 160 are supplied to chamber 121 and water 161 separates from hydrocarbon fluids 162, the level of hydrocarbon fluids 162 in chamber 121 begins to rise. When the level of hydrocarbon fluids 162 in chamber 121 is sufficient, the hydrocarbon fluids in the upper portion of chamber 121 exit chamber 121 through annulus 114.
The pressure and/or flow of produced hydrocarbon fluids 160 in conduit 110 into chamber 121 prevents hydrocarbon fluids 162 from backflowing into conduit 110 via openings 112. However, hydrocarbon fluids 162 are free to flow through inlet end 114b and annulus 114 to outlets 152b, 153b. 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 or conduit 50). Cap 116 prevents hydrocarbon fluids 162 from exiting annulus 114 at upper end -114a. Separated water 161 in the lower portion or chamber 121 may be drawn off through outlet 130 for testing by opening valve 131. Initially, and between sampling of water 161 within chamber 121, valve 131 is preferably closed.
100331 In the manner described, embodiments of sampling devices for sampling produced well fluids (e.g., device 100) rely on gravity separation to cost efficiently separate water or other fluids from the produced hydrocarbon fluids for sampling purposes. In contrast to conventional low cut water sampling devices limited to periodic water sampling, embodiments of device 100 allow for continuous sampling of produced well fluids over a Period of time.
Furthermore, embodiments of the apparatus provide a very low cost solution to separating the small percentage of water in low cut produced fluids. In addition, embodiments or the apparatus are capable of withstanding extremely high pressures. Although embodiments disclosed herein (e.g., device 100) have been described. with respect to separating and sampling water from a produced well fluids stream, it is contemplated that other fluids having a higher density than the produced hydrocarbons may also be separated. Further, although embodiments disclosed herein have been shown and described in conjunction with offshore hydrocarbon producing wells, they may also be used to separate and sample fluids from a produced well fluids in a pipeline, on land, etc.
100341 While preferred embodiments have been shown and described, modifications thereof can be made by one skilled in the art without departing from the scope or teachings herein. The embodiments described herein are exemplary only and are not limiting. Many variations and modifications of the systems, apparatus, and processes described herein are possible and are within the scope of the invention. For example, the relative dimensions of various parts, the materials from which the various parts are made, and other parameters can be varied.
Accordingly, the scope of protection is not limited to the embodiments described herein, but is only limited by the claims that follow, the scope of which shall include all equivalents of the subject matter of the claims. Unless expressly stated otherwise, the steps in a method claim may be performed in any order. The recitation of identifiers such as (a), (b), (c) or (I), (2), (3) before steps in a method claim are not intended to and do not specify a particular order to the steps, but rather are used to simply subsequent reference to such steps.
100351 The discussion of a reference is not an admission that it is prior art to the present invention, especially any reference that may have a publication date after the priority date of this application.
The disclosures of all patents, patent applications, and publications cited herein are hereby incorporated herein by reference in their entirety, to the extent that they provide exemplary, procedural, or other details supplementary to those set forth herein.
CROSS-REFERENCE TO RELATED APPLICATIONS
100011 This application claims benefit of U.S. provisional patent application Serial No. 61./384,806 filed September 21, 2010, and entitled "Low Cut Water Sampler," which is hereby incorporated herein by reference in its entirety.
STATEMENT REGARDING FEDERALLY SPONSORED
RESEARCH OR DEVELOPMENT
100021 Not applicable.
BACKGROUND
Field of the Invention 100031 This invention relates generally to the production of hydrocarbons from an earthen formation.- More particularly, the invention relates to a method and system for sampling a low water-cut hydrocarbon stream.
Background of the Technology 100041 In hydrocarbon production operations, water may be produced along with the hydrocarbons. The 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.
In general, 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). However, some wells produce a very low water cat stream of hydrocarbons. Separation of the water and hydrocarbons in such low cut production streams is typically more difficult as compared to high cut production streams.
100051 Sampling and analysis of the water produced from a well serves several purposes. For example, during production, 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. In addition, these treatments may include anticorrosion treatments (corrosion inhibitor added), or treatments to prevent the formation of hydrates or "
deposition of paraffins 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 wells. This information may be used in reservoir development and depletion planning.
100061 One conventional method for sampling water from a produced hydrocarbon stream is to take an isolated direct sample from the pipeline at a single point in time, separate the water, and then analyze the separated water. Thus, with this approach, continuous sampling and analysis of the produced water over time cannot be obtained without repeatedly taking discrete samples from the pipeline. Furthermore, in produced well fluids with low water cut, it is difficult to separate the water and hydrocarbons.
100071 Accordingly, there remains a need in the art for improved systems and methods for sampling water from a produced hydrocarbon stream. Such systems and methods would be particularly well-received if they offered the potential for continuous sampling over time and could be employed with low water cut hydrocarbon streams. =
BRIEF SUMMARY Orl'HE DISCLOSURE
100081 These kind other needs in the art are addressed in one embodiment by an apparatus for sampling well production fluids. in an embodiment, the apparatus comprises a vessel having an inner chamber. in addition, the apparatus comprises a hydrocarbon fluids outlet conduit in fluid communication with the inner chamber. Further, 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 first portion extending from the vessel and a second portion extending into the inner chamber. The second portion of the well fluids inlet conduit includes a plurality of openings configured to direct the well production fluids radially outward from the well fluids inlet conduit. Still further, the apparatus comprises a sample fluids outlet in fluid communication with the inner chamber.
'These and other needs in the art arc addressed in another embodiment by a method of sampling produced well fluids. In an embodiment, the method comprises (a) continuously flowing produced well fluids to a sampling device. The sampling device comprises a vessel having an inner 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. hi addition, the method comprises (b) flowing the produced well fluids through the well fluids inlet conduit into the inner chamber of' the vessel.
Further, the method comprises (c) allowing a sample fluid -in 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. Still further, the method comprises (d) withdrawing a sample of the sample fluid from the vessel through the sample fluids outlet.
100091 These and other needs in the art are addressed in another embodiment by an apparatus for 'sampling well production fluids. In an embodiment, the apparatus comprises a vessel having an inner chamber. In addition, the apparatus comprises a hydrocarbon 'fluids outlet conduit coupled to the vessel. Further, the apparatus comprises a well fluids inlet conduit extending coaxially through the hydrocarbon fluids outlet conduit into the inner chamber. Still further, the apparatus comprises a sample fluids outlet positioned at a lower end of the vessel and in fluid communication with the inner chamber. Moreover, 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.
100101 The foregoing has outlined rather broadly the features and technical advantages of the invention in order that the detailed description of the invention that follows may be better understood. Additional features and advantages of the invention will be described hereinafter that form the subject of the claims of the invention. It should be appreciated by those skilled in the art . that the conception and the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes of the invention. It should also be realized by those skilled in the art that such equivalent constructions do not depart from the spirit and scope of the invention as set forth in the appended claims.
100111 Embodiments described herein comprise a combination of features and advantages intended to address various shortcomings associated with certain prior devices, systems, and methods. The various characteristics described above, as well as other features, will be readily apparent to those skilled in the art upon reading the fbIlowing, detailed description, and by referring to the accompanying drawings.
BRIEF DESCRIPTION OF THE DRAWINGS
100121 For a detailed description of the preferred embodiments of the invention, reference will now be made to the accompanying drawings in which:
100131 Figure 1 is a schematic view of an offshore installation including an embodiment of a low cut water sampler in accordance with the principles described herein;
100141 Figure 2 is a front view of the low cut water sampler of Figure 1;
100151 Figure 3 is a front view of the low cut water sampler of Figure I being supplied produced . well -fluids and before outputting separated hydrocarbon fluids or water;
and 100161 Figure 4 is an enlarged .view of the lower end of the inlet conduit of the low cut water sampler of Figure 1 being supplied produced well fluids and outputting separated hydrocarbon fluid and water.
DETAILED DESCRIPTION orrnE PREFERRED EMBODIMENTS
= 100171 The following discussion is directed to various exemplary embodiments. However, one skilled in the art will understand that the examples disclosed herein have broad application, and that the discussion of any embodiment is meant only to be exemplary of that embodiment, and not intended to suggest that the scope of the disclosure, including the claims, is limited to that embodiment.
100181 Certain terms are used throughout the following description and claims to refer to particular features or components. As one skilled in the art will appreciate, different persons may refer to the same feature or component by different names. This document does not intend to distinguish between components or features that differ in name but not .function. The drawing figures are not necessarily to scale. Certain features and components herein may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in interest of clarity and conciseness.
100101 In the following discussion and in the claims, the terms "including"
and "comprising" are used in an open-ended fashion, and thus should be interpreted to mean "including, but not limited to... ." Also, the term "couple" or "couples" is intended to mean either an indirect or direct connection. Thus, if a first 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. In addition, as used herein, the terms "axial" and "axially"
generally mean along or parallel to a central axis (e.g., central axis of a body or a port), while the terms "radial" and "radially" generally mean perpendicular to the central axis. For instance, an axial distance refers to a distance measured along or parallel to the central axis, and a radial distance means a distance measured perpendicular to the central axis. As used herein, the phrase "low cut" refers to produced well fluids with less than about -10% water composition (by volume), and the phrase "high cut"
refers to produced well fluids with greater than about 10% water composition (by volume).
100201 Referring now Figure 1, an offshore system 10 for producing a completed subterranean wellbore 11 is schematically shown. In this embodiment, 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 manifold 30 to platform 20. In general, riser 40 is a large-diameter pipe that connects manifold 30 to the floating platform 20.
During production operations, well fluids are produced through riser 40 to platform 20, where the produced fluids may be stored, processed, offloaded or combinations thereof. Casing 32 extends from wellhead 31 into subterranean wellbore 11.
100211 System 10 also includes a water sampling device 100 for sampling low cut well fluids produced through riser 40. As will be describe in more detail below, 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. Thus, 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. In this-embodiment, a production sample conduit or flowline 50 supplies produced wellbore fluids from riser 40 to sampling device 100. Samples of the water in the produced well fluids in riser 40 may be obtained continuously with device 100 via flowline 50 to determine the composition of the water therein. Although sampling device 100 is shown disposed on platform 20, device 100 may be disposed at any suitable offshore or onshore location. For examples, 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.
100221 Referring now to Figure 2, water sampling device 100 includes a produced well fluids inlet conduit 110, a separator containment vessel 120, a sample fluid outlet 130, a separated hydrocarbon fluids outlet conduit 140, and a hydrocarbon fluids outlet fitting or coupling 150.
Vessel 120 has an inner chamber 121. In this embodiment, water is sampled and separated from the produced well fluids, and thus, sample fluid outlet 130 may also be referred to as a water outlet.
Inlet conduit 110, water outlet 130, and hydrocarbon outlet conduit 140 are each in fluid communication with inner chamber 121. As will be described in more detail below, produced well fluids, designated with reference numeral 160, enter chamber 121 via inlet conduit 110; separated water samples, designated with reference numeral 161, may be taken from chamber 121 via outlet 130; and hydrocarbon fluids, designated with reference numeral 162 and resulting from the separation of water 161 from well fluids 160, exit chamber 121 via outlet conduit 140 and fitting 150. Flowline 50 previously described is coupled to inlet conduit 110, and thus, supplies produced well fluids to chamber 121 via inlet conduit 110.
100231 In general, separator vessel 120 may be any suitable vessel or container compatible with potentially corrosive well fluids and capable of withstanding relatively high pressures. In particular, vessel 120 is preferably a containment vessel or tank designed and configured to withstand pressures of at least about 285 psi, alternatively about 1,000 psi, alternatively about 5,000 psi, alternatively about 10,000 psi, and alternatively about 20,000 psi.
In this embodiment, vessel 120 is an elongate upright generally cylindrical tank having an upper end 120a and a lower end 120b opposite upper end 120a. Upper end 120a includes a port 122 and lower end 1201) includes a port 123. Conduits 110, 140 extend through port 122 into inner chamber 121, and water outlet 130 is in fluid communication with port 123. Although 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, spherical, etc. In general, 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.
100241 Referring still to Figure 2, as previously described, outlet conduit 140 extends through port 122 and is secured to vessel 120. For instance, conduit 140 may be positioned in port 122 and then welded to vessel 120. In this embodiment, outlet conduit 140 is a tubular having a central axis 145, a first or upper end 140a disposed outside and above vessel 120, and a second or lower end 140b disposed within chamber 121: As will be described in more detail below, hydrocarbon fluids 162 flow from chamber 121 into end 140b, through conduit 140, and out end 140a into fitting 150.
Thus, lower end 140b may also be referred to as an inlet end, and upper end 140a may also be referred to as an outlet end.
100251 Fitting 150 is coupled to upper end 140a of conduit 140. In this embodiment, fitting 150 is a tubular manifold including a main bore or passage 151, a first lateral bore or passage 152 extending from main bore 151, and a second lateral bore or passage 153 extending from main bore 151. Main bore 151 is eoaxially aligned with outlet conduit 140 and has a first or upper end 151a distal conduit 140, and a second or lower end 15Ib in fluid communication with conduit 140. As will be described in more detail below, lower end 151b receives hydrocarbon fluids 162 from chamber 121 via conduit 140, and thus, may also be referred to as hydrocarbon fluids inlet end 151b. Each lateral bore 152, 153 has an inlet end 152a, 153a, respectively, in fluid communication with main bore 151 between ends 151a, b, and an outlet end 152b, 153b, respectively. In this embodiment, outlet end 152b is in fluid communication with a sensor 154. In general, 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.
100261 Referring still to Figure 2, well fluids inlet conduit 110 extends through main bore 151 of fitting 150 and outlet conduit 140 into vessel 120. In this embodiment, inlet conduit 110 is a tubular having a central axis 11,5, a first or inlet end 110a extending from main bore 151 distal vessel 120, and a second or closed end 110b disposed in chamber 121. Conduit 110 is coaxially aligned with main bore 151 of fitting 150 and outlet conduit 140, and thus, central axes 115, 145 arc coincident. Conduit 110 is preferably positioned such that end 1101) is disposed in the upper half of separator chamber 121.
100271 The outer diameter of inlet conduit 110 is less than the inner diameter of main bore 151 and outlet conduit 140, and thus, an annulus 114 is radially positioned between inlet conduit 110 and fitting 150, outlet conduit 140. Annulus 114 extends from end 140b of conduit 140 to upper end 151a amain bore 151. Thus, annulus 114 has a first or upper end 114a coincident with upper end 151a of main bore 151 and a second or lower end 114b coincident with inlet end 140b of conduit 140. Annulus 114 is closed off and sealed at upper end 114a with a cap 116 that extends radially across main bore 151 from inlet conduit 110 to fitting 150. However, lower end 114b of annulus 114 is open to chamber 120. Lateral bores 152, 153 are in fluid communication with annulus 114.
As will be described in more detail below, hydrocarbon fluids 162 flow from chamber 121 into end 114b of annulus 114, through annulus 114, and out end 114a of annulus 114 into lateral bores 152, 151 Thus, lower end 114b may also be referred to as an inlet end.
100281 Relen-ing now to Figures 2 and 4, the portion of inlet conduit 110 extending into chamber 121 includes a plurality of through bores or openings 112 proximal closed end 1101). Openings 112 extend radially through conduit 110 proximal end 110b and allow produced well fluids 160 flowing through conduit 110 to exit inlet conduit 110 in a radial fashion to minimize agitation and mixing of fluids within chamber 121. Accordingly, each opening 112 may be described as an outlet port. As best shown in Figure 4, in this embodiment, openings 112 are arranged in a plurality of axially spaced rows 112a, b, c, d. Openings 112 within each row 112a, b, c, d are circumferentially spaced about conduit 110, and further, openings 112 in each row 112a, h, c, d are circumferentially offset or staggered relative to the openings 112 in the adjacent row(s) 112a, b, c, d. In this embodiment, each row 112a, b, c, d includes two openings 112 spaced 180 apart, with openings 112 in adjacent row s 112a, b, c, d being circumfbrentially staggered 90 apart. However, in other embodiments, each row (e.g., each row 112a, b, c, d) may have more or less openings (e.g., openings 112) and/or the openings in each row may be circumferentially spaced by more or less than 180 . Although openings 112 are shown as circular holes in Figure 4, in general, openings 112 may have any suitable geometry (e.g., oval, rectangular, elliptical, etc.).
100291 Referring again to Figure 2, water outlet 130 is coupled to vessel 120 and extends from port 123. In this embodiment, outlet 130 includes a valve 131 for selectively opening and closing outlet 130. More specifically, 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.
100301 Referring now to Figures 1 and 2, during production operations, produced well fluids 160 are supplied to. inlet conduit 110 via production sample [towline 50. Fluids -160 flow through conduit 110 and radially outward through openings 112 into chamber 121. As previously described, the radial ejection of the produced well fluids 160 from conduit 110 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.
100311 As best shown in Figure 2, without being limited by this or any particular theory, due to the difference in densities and the immiscibility between water 161 and hydrocarbon fluids 162 in produced well .fluids 160, any water 161 in the produced well fluids 160 begins to migrate or settle to the bottom of separator chamber 121 and the hydrocarbon fluids 162 move to the upper portion of chamber 121. En other words, gravity naturally drives the separation of the heavier water 161 from the lighter hydrocarbon fluids l 62.
100321 Moving now to Figure 3, as produced well fluids 160 are supplied to chamber 121 and water 161 separates from hydrocarbon fluids 162, the level of hydrocarbon fluids 162 in chamber 121 begins to rise. When the level of hydrocarbon fluids 162 in chamber 121 is sufficient, the hydrocarbon fluids in the upper portion of chamber 121 exit chamber 121 through annulus 114.
The pressure and/or flow of produced hydrocarbon fluids 160 in conduit 110 into chamber 121 prevents hydrocarbon fluids 162 from backflowing into conduit 110 via openings 112. However, hydrocarbon fluids 162 are free to flow through inlet end 114b and annulus 114 to outlets 152b, 153b. 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 or conduit 50). Cap 116 prevents hydrocarbon fluids 162 from exiting annulus 114 at upper end -114a. Separated water 161 in the lower portion or chamber 121 may be drawn off through outlet 130 for testing by opening valve 131. Initially, and between sampling of water 161 within chamber 121, valve 131 is preferably closed.
100331 In the manner described, embodiments of sampling devices for sampling produced well fluids (e.g., device 100) rely on gravity separation to cost efficiently separate water or other fluids from the produced hydrocarbon fluids for sampling purposes. In contrast to conventional low cut water sampling devices limited to periodic water sampling, embodiments of device 100 allow for continuous sampling of produced well fluids over a Period of time.
Furthermore, embodiments of the apparatus provide a very low cost solution to separating the small percentage of water in low cut produced fluids. In addition, embodiments or the apparatus are capable of withstanding extremely high pressures. Although embodiments disclosed herein (e.g., device 100) have been described. with respect to separating and sampling water from a produced well fluids stream, it is contemplated that other fluids having a higher density than the produced hydrocarbons may also be separated. Further, although embodiments disclosed herein have been shown and described in conjunction with offshore hydrocarbon producing wells, they may also be used to separate and sample fluids from a produced well fluids in a pipeline, on land, etc.
100341 While preferred embodiments have been shown and described, modifications thereof can be made by one skilled in the art without departing from the scope or teachings herein. The embodiments described herein are exemplary only and are not limiting. Many variations and modifications of the systems, apparatus, and processes described herein are possible and are within the scope of the invention. For example, the relative dimensions of various parts, the materials from which the various parts are made, and other parameters can be varied.
Accordingly, the scope of protection is not limited to the embodiments described herein, but is only limited by the claims that follow, the scope of which shall include all equivalents of the subject matter of the claims. Unless expressly stated otherwise, the steps in a method claim may be performed in any order. The recitation of identifiers such as (a), (b), (c) or (I), (2), (3) before steps in a method claim are not intended to and do not specify a particular order to the steps, but rather are used to simply subsequent reference to such steps.
100351 The discussion of a reference is not an admission that it is prior art to the present invention, especially any reference that may have a publication date after the priority date of this application.
The disclosures of all patents, patent applications, and publications cited herein are hereby incorporated herein by reference in their entirety, to the extent that they provide exemplary, procedural, or other details supplementary to those set forth herein.
Claims (22)
1. An apparatus for sampling well production fluids, comprising:
a vessel having an inner chamber;
a hydrocarbon fluids outlet conduit in fluid communication with the inner chamber;
a well fluids inlet conduit coaxially disposed within the hydrocarbon fluids outlet conduit and in fluid communication with the inner chamber, wherein the well fluids inlet conduit has a first portion extending from the vessel and a second portion extending into the inner chamber;
wherein the second portion of the well fluids inlet conduit includes a plurality of openings configured to direct the well production fluids radially outward from the well fluids inlet conduit;
and a sample fluids outlet in fluid communication with the inner chamber.
a vessel having an inner chamber;
a hydrocarbon fluids outlet conduit in fluid communication with the inner chamber;
a well fluids inlet conduit coaxially disposed within the hydrocarbon fluids outlet conduit and in fluid communication with the inner chamber, wherein the well fluids inlet conduit has a first portion extending from the vessel and a second portion extending into the inner chamber;
wherein the second portion of the well fluids inlet conduit includes a plurality of openings configured to direct the well production fluids radially outward from the well fluids inlet conduit;
and a sample fluids outlet in fluid communication with the inner chamber.
2. The apparatus of claim 1, wherein the vessel has an upper end, a lower end, and a first port extending through the lower end of the vessel to the inner chamber;
wherein the sample fluids outlet is in fluid communication with the first port.
wherein the sample fluids outlet is in fluid communication with the first port.
1. The apparatus of claim 2, wherein the vessel has a second port extending through the upper end of the vessel to the inner chamber;
wherein the hydrocarbon fluids outlet conduit and the well fluids inlet conduit extend through the second port.
wherein the hydrocarbon fluids outlet conduit and the well fluids inlet conduit extend through the second port.
4. The apparatus of claim 1, wherein the plurality of openings in the well fluids inlet conduit are arranged in a plurality of axially spaced rows, wherein a plurality of the openings are circumferentially spaced in each row.
5. The apparatus of claim 4, wherein the openings in each row are circumferentially staggered relative to the openings in each axially adjacent row.
6. The apparatus of claim 1, wherein the vessel has a pressure rating of at least about 20,000 psi and the inner chamber has a volume between 1 liter and 4 liters.
7. The apparatus of' claim 1, further comprising a hydrocarbon fluids outlet fitting including a main bore and a first lateral bore extending from the main bore;
wherein the main bore is in fluid communication with the hydrocarbon fluids outlet conduit;
wherein the well fluids inlet conduit extends coaxially through the main bore.
wherein the main bore is in fluid communication with the hydrocarbon fluids outlet conduit;
wherein the well fluids inlet conduit extends coaxially through the main bore.
8. The apparatus of claim 7, wherein an annulus is radially disposed between the well fluids inlet conduit and the hydrocarbon fluids outlet conduit, and radially disposed between the well fluids inlet conduit and the hydrocarbon fluids outlet fitting;
wherein the annulus extends from an inlet end in fluid communication with the inner chamber and a sealed end opposite the inlet end; and wherein the annulus is in fluid communication with the first lateral bore.
wherein the annulus extends from an inlet end in fluid communication with the inner chamber and a sealed end opposite the inlet end; and wherein the annulus is in fluid communication with the first lateral bore.
9. The apparatus 'of claim 8, wherein the first lateral bore has an inlet end in fluid communication with the annulus and a hydrocarbon fluids outlet end opposite the inlet end of the first lateral bore.
10. The apparatus of claim 9, wherein the hydrocarbon fluids outlet fining includes a second lateral bore extending from the main bore;
Wherein the second lateral bore is in fluid communication with the annulus and a sensor.
Wherein the second lateral bore is in fluid communication with the annulus and a sensor.
11. The apparatus of claim 10, wherein the sensor comprises a pressure sensor, a temperature sensors, a flow rate sensor, or a pH sensor.
12. A method of sampling produced well fluids, comprising:
(a) continuously flowing produced well fluids to a sampling device, wherein the sampling device comprises:
a vessel having an inner chamber;
a hydrocarbon fluids outlet conduit in fluid communication with the inner chamber;
a well fluids inlet conduit coaxially disposed within the hydrocarbon fluids outlet conduit and in fluid communication with the inner chamber a sample fluids outlet in fluid communication with the inner chamber (b) flowing the produced well fluids through the well fluids inlet conduit into the inner chamber of the vessel;
(c) allowing a sample fluid in 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 or gravity; and (d) withdrawing a sample or the sample fluid from the vessel through the sample fluids outlet.
(a) continuously flowing produced well fluids to a sampling device, wherein the sampling device comprises:
a vessel having an inner chamber;
a hydrocarbon fluids outlet conduit in fluid communication with the inner chamber;
a well fluids inlet conduit coaxially disposed within the hydrocarbon fluids outlet conduit and in fluid communication with the inner chamber a sample fluids outlet in fluid communication with the inner chamber (b) flowing the produced well fluids through the well fluids inlet conduit into the inner chamber of the vessel;
(c) allowing a sample fluid in 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 or gravity; and (d) withdrawing a sample or the sample fluid from the vessel through the sample fluids outlet.
13. The method of claim 12, wherein the sample fluids outlet includes a valve, and wherein (d) comprises opening the valve to withdraw the sample of the first fluid.
14. The method of claim 12, further comprising:
(e) flowing the one or more hydrocarbon fluids from the inner chamber through an annulus radially positioned between the well fluids inlet conduit and the hydrocarbon fluids outlet conduit.
(e) flowing the one or more hydrocarbon fluids from the inner chamber through an annulus radially positioned between the well fluids inlet conduit and the hydrocarbon fluids outlet conduit.
15. The method of claim 14, wherein (e) further comprises allowing the one of more hydrocarbons to flow out of an upper end of the inner chamber of the vessel.
16. The method of claim 14, wherein the sample fluid is water.
17. The method of claim 14, wherein (b) comprises flowing the produced well fluids radially outward from the well fluids inlet conduit through a plurality of openings in the well fluids inlet conduit, wherein the plurality of openings arc positioned along a portion of the well fluids inlet conduit extending into the inner chamber of the vessel.
18. The method of claim 12, further comprising testing the sample fluid for pH, composition, iesistivity, conductivity, or combinations thereof.
19. An apparatus for sampling well production fluids, comprising:
a vessel having an inner chamber;
a hydrocarbon fluids outlet conduit coupled to the vessel;
a well fluids inlet conduit extending coaxially through the hydrocarbon fluids outlet conduit into the inner chamber;
a sample fluids outlet positioned at a lower end of the vessel and in fluid communication with the inner chamber;
an annulus radially disposed between the hydrocarbon fltiids outlet conduit and the well fluids inlet conduit, wherein the annulus has an inlet end in fluid communication with the inner chamber.
a vessel having an inner chamber;
a hydrocarbon fluids outlet conduit coupled to the vessel;
a well fluids inlet conduit extending coaxially through the hydrocarbon fluids outlet conduit into the inner chamber;
a sample fluids outlet positioned at a lower end of the vessel and in fluid communication with the inner chamber;
an annulus radially disposed between the hydrocarbon fltiids outlet conduit and the well fluids inlet conduit, wherein the annulus has an inlet end in fluid communication with the inner chamber.
20. The apparatus of claim 19, wherein a portion of the well fluids inlet conduit extending into the inner chamber includes a plurality of openings configured to direct the flow of well production fluids radially outward from the well fluids inlet conduit into the inner chamber.
21. The apparatus of claim 19, further comprising a fitting coupled to the hydrocarbon fluids outlet conduit, wherein the fitting includes a first bore;
wherein the well fluids inlet conduit extends coaxially through the first 'bore of the fitting;
wherein the annulus extends into the fitting and is radially disposed between the well fluids inlet conduit and the fitting.
wherein the well fluids inlet conduit extends coaxially through the first 'bore of the fitting;
wherein the annulus extends into the fitting and is radially disposed between the well fluids inlet conduit and the fitting.
22. The apparatus of claim 21, wherein the fitting further comprises a second bore extending from the first bore and a third bore extending from the first bore;
wherein the second bore and the third bore arc each in fluid communication with the annulus.
wherein the second bore and the third bore arc each in fluid communication with the annulus.
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| US61/384,806 | 2010-09-21 | ||
| PCT/US2011/052572 WO2012040339A1 (en) | 2010-09-21 | 2011-09-21 | Low cut water sampling device |
Publications (1)
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|---|---|
| CA2810771A1 true CA2810771A1 (en) | 2012-03-29 |
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| CA2810771A Abandoned CA2810771A1 (en) | 2010-09-21 | 2011-09-21 | Low cut water sampling device |
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| AU (1) | AU2011305492A1 (en) |
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| US20230168235A1 (en) * | 2021-11-19 | 2023-06-01 | United States Geological Survey | Particulate-based cumulative contaminant sampling device |
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| 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 |
| BR112013002736B1 (en) * | 2010-08-05 | 2021-06-08 | Cameron Technologies Limited | water removal method |
-
2011
- 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
- 2011-09-21 US US13/238,726 patent/US20120073806A1/en not_active Abandoned
- 2011-09-21 BR BR112013005928A patent/BR112013005928A2/en not_active Application Discontinuation
- 2011-09-21 AU AU2011305492A patent/AU2011305492A1/en not_active Abandoned
- 2011-09-21 EA EA201370075A patent/EA201370075A1/en unknown
- 2011-09-21 CA CA2810771A patent/CA2810771A1/en not_active Abandoned
Also Published As
| Publication number | Publication date |
|---|---|
| WO2012040339A1 (en) | 2012-03-29 |
| AU2011305492A1 (en) | 2013-03-28 |
| EP2618906A1 (en) | 2013-07-31 |
| EA201370075A1 (en) | 2013-09-30 |
| US20120073806A1 (en) | 2012-03-29 |
| BR112013005928A2 (en) | 2016-05-17 |
| AU2011305492A8 (en) | 2013-04-11 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| FZDE | Discontinued |
Effective date: 20150922 |