US20110068046A1 - Mercury removal from water - Google Patents
Mercury removal from water Download PDFInfo
- Publication number
- US20110068046A1 US20110068046A1 US12/879,724 US87972410A US2011068046A1 US 20110068046 A1 US20110068046 A1 US 20110068046A1 US 87972410 A US87972410 A US 87972410A US 2011068046 A1 US2011068046 A1 US 2011068046A1
- Authority
- US
- United States
- Prior art keywords
- stream
- mercury
- gas stream
- aqueous
- treated gas
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- QSHDDOUJBYECFT-UHFFFAOYSA-N mercury Chemical compound [Hg] QSHDDOUJBYECFT-UHFFFAOYSA-N 0.000 title claims abstract description 127
- 229910052753 mercury Inorganic materials 0.000 title claims abstract description 110
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 51
- 238000000034 method Methods 0.000 claims abstract description 31
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 24
- 229930195733 hydrocarbon Natural products 0.000 claims description 57
- 150000002430 hydrocarbons Chemical class 0.000 claims description 57
- 239000004215 Carbon black (E152) Substances 0.000 claims description 55
- 239000007788 liquid Substances 0.000 claims description 41
- 239000003638 chemical reducing agent Substances 0.000 claims description 17
- 238000001914 filtration Methods 0.000 claims description 12
- 238000004519 manufacturing process Methods 0.000 claims description 12
- 150000001875 compounds Chemical class 0.000 claims description 8
- 229910021626 Tin(II) chloride Inorganic materials 0.000 claims description 5
- 239000002245 particle Substances 0.000 claims description 5
- TXUICONDJPYNPY-UHFFFAOYSA-N (1,10,13-trimethyl-3-oxo-4,5,6,7,8,9,11,12,14,15,16,17-dodecahydrocyclopenta[a]phenanthren-17-yl) heptanoate Chemical compound C1CC2CC(=O)C=C(C)C2(C)C2C1C1CCC(OC(=O)CCCCCC)C1(C)CC2 TXUICONDJPYNPY-UHFFFAOYSA-N 0.000 claims description 4
- OAKJQQAXSVQMHS-UHFFFAOYSA-N Hydrazine Chemical compound NN OAKJQQAXSVQMHS-UHFFFAOYSA-N 0.000 claims description 4
- 239000000203 mixture Substances 0.000 claims description 4
- 235000011150 stannous chloride Nutrition 0.000 claims description 4
- 239000001119 stannous chloride Substances 0.000 claims description 4
- 239000012279 sodium borohydride Substances 0.000 claims description 2
- 229910000033 sodium borohydride Inorganic materials 0.000 claims description 2
- 239000002594 sorbent Substances 0.000 claims description 2
- 239000003345 natural gas Substances 0.000 abstract description 9
- 238000012545 processing Methods 0.000 abstract description 4
- 239000007789 gas Substances 0.000 description 81
- 238000000926 separation method Methods 0.000 description 5
- 239000000654 additive Substances 0.000 description 4
- 230000000996 additive effect Effects 0.000 description 4
- 150000002484 inorganic compounds Chemical class 0.000 description 4
- 229910010272 inorganic material Inorganic materials 0.000 description 4
- 239000000463 material Substances 0.000 description 4
- 238000012856 packing Methods 0.000 description 4
- 238000013459 approach Methods 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 238000001816 cooling Methods 0.000 description 2
- 230000007613 environmental effect Effects 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 229960002523 mercuric chloride Drugs 0.000 description 2
- LWJROJCJINYWOX-UHFFFAOYSA-L mercury dichloride Chemical compound Cl[Hg]Cl LWJROJCJINYWOX-UHFFFAOYSA-L 0.000 description 2
- 229910000474 mercury oxide Inorganic materials 0.000 description 2
- UKWHYYKOEPRTIC-UHFFFAOYSA-N mercury(ii) oxide Chemical compound [Hg]=O UKWHYYKOEPRTIC-UHFFFAOYSA-N 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- XLYOFNOQVPJJNP-PWCQTSIFSA-N Tritiated water Chemical compound [3H]O[3H] XLYOFNOQVPJJNP-PWCQTSIFSA-N 0.000 description 1
- 239000002250 absorbent Substances 0.000 description 1
- 230000002745 absorbent Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000000919 ceramic Substances 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000007717 exclusion Effects 0.000 description 1
- 239000000446 fuel Substances 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 239000012071 phase Substances 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 230000006798 recombination Effects 0.000 description 1
- 238000005215 recombination Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 239000011343 solid material Substances 0.000 description 1
- AXZWODMDQAVCJE-UHFFFAOYSA-L tin(II) chloride (anhydrous) Chemical compound [Cl-].[Cl-].[Sn+2] AXZWODMDQAVCJE-UHFFFAOYSA-L 0.000 description 1
- 238000011144 upstream manufacturing Methods 0.000 description 1
- 239000012808 vapor phase Substances 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
Images
Classifications
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G33/00—Dewatering or demulsification of hydrocarbon oils
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F1/00—Treatment of water, waste water, or sewage
- C02F1/70—Treatment of water, waste water, or sewage by reduction
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G31/00—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for
-
- 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
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2257/00—Components to be removed
- B01D2257/60—Heavy metals or heavy metal compounds
- B01D2257/602—Mercury or mercury compounds
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F1/00—Treatment of water, waste water, or sewage
- C02F1/001—Processes for the treatment of water whereby the filtration technique is of importance
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F2101/00—Nature of the contaminant
- C02F2101/10—Inorganic compounds
- C02F2101/20—Heavy metals or heavy metal compounds
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F2103/00—Nature of the water, waste water, sewage or sludge to be treated
- C02F2103/18—Nature of the water, waste water, sewage or sludge to be treated from the purification of gaseous effluents
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F2103/00—Nature of the water, waste water, sewage or sludge to be treated
- C02F2103/34—Nature of the water, waste water, sewage or sludge to be treated from industrial activities not provided for in groups C02F2103/12 - C02F2103/32
- C02F2103/36—Nature of the water, waste water, sewage or sludge to be treated from industrial activities not provided for in groups C02F2103/12 - C02F2103/32 from the manufacture of organic compounds
- C02F2103/365—Nature of the water, waste water, sewage or sludge to be treated from industrial activities not provided for in groups C02F2103/12 - C02F2103/32 from the manufacture of organic compounds from petrochemical industry (e.g. refineries)
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/10—Feedstock materials
- C10G2300/1025—Natural gas
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/20—Characteristics of the feedstock or the products
- C10G2300/201—Impurities
- C10G2300/205—Metal content
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/80—Additives
- C10G2300/805—Water
Definitions
- Embodiments of the invention relate to methods and systems for removing mercury from water.
- Recovered fluids from wells drilled into hydrocarbon reservoirs often include water. Separators remove the water from oil and gas products also produced. However, the water from some reservoirs contains mercury. The mercury in the water presents environmental and safety concerns and may prevent ability to discharge the water without first being treated.
- a process of removing mercury from water includes separating crude production into a gaseous hydrocarbon stream, a liquid hydrocarbon stream and an aqueous stream. Water forms a majority of the aqueous stream. Removing mercury from a contaminated gas stream including the gaseous hydrocarbon stream provides a treated gas stream. Further, contacting the treated gas stream with the aqueous stream transfers mercury from the aqueous stream to the treated gas stream such that mercury removal from the aqueous stream is independent from the liquid hydrocarbon stream.
- a method of removing mercury from water includes adding a reducing agent to an aqueous stream such that mercury-containing compounds in the aqueous stream are converted to form elemental mercury.
- the method further includes transferring the elemental mercury from the aqueous stream to a methane-containing gas stream. The transferring occurs upon contacting the gas stream with the aqueous stream combined with the reducing agent.
- the method includes removing the elemental mercury from the gas stream.
- a process of removing mercury from water includes separating crude production into a gaseous hydrocarbon stream, a liquid hydrocarbon stream and an aqueous stream. Water forms a majority of the aqueous stream. Transferring mercury from the liquid hydrocarbon stream to a first portion of a treated gas stream occurs by contacting the first portion of the treated gas stream with the liquid hydrocarbon stream. Furthermore, transferring mercury from the aqueous stream to a second portion of the treated gas stream by contacting the second portion of the treated gas stream with the aqueous stream is independent of the first portion of the treated gas stream being contacted with the liquid hydrocarbon stream. The treated gas stream forms by removing mercury from the gaseous hydrocarbon stream mixed with the first and second portions of the treated gas stream recycled after the contacting with the liquid hydrocarbon and aqueous streams.
- FIG. 1 is a schematic of a production system for mercury removal from water, according to one embodiment of the invention.
- FIG. 2 is a schematic of a production system having elements shown in FIG. 1 with a subunit for removing mercury from a hydrocarbon liquid stream, according to one embodiment of the invention.
- FIG. 3 is a schematic of a production system having elements shown in FIG. 1 with a subunit for initial removal of mercury from a hydrocarbon and water mixture, according to one embodiment of the invention.
- FIG. 4 is a graph showing mercury concentration in water before and after being contacted with a stream of hydrocarbon gas, according to one embodiment of the invention.
- Embodiments of the invention relate to removal of mercury from water.
- the removal relies on transferring mercury from an aqueous stream to a natural gas stream upon contacting the aqueous stream with the natural gas stream.
- Processing of the natural gas stream after used to strip the mercury from the aqueous stream removes the mercury from the natural gas stream.
- the water comes from crude production and is thus recovered from reservoirs along with hydrocarbons that may be liquid and gaseous.
- Mercury concentrations in the water that is produced often prevent outputting the water as waste due to environmental issues and regulations.
- the removal of the mercury from the water thereby enables discharge of the water separated from the hydrocarbons.
- “mercury” refers to mercury within or from compounds, such as mercuric chloride, mercury oxide and combinations thereof, containing mercury and at least one other element and/or elemental mercury. Location for removing the mercury depends on application and can be performed onsite at offshore platforms with limited space and facilities.
- FIG. 1 illustrates a system in which crude production removed from a well defines an input stream 100 introduced into a separator 102 for separation into a hydrocarbon gas stream 104 , a hydrocarbon liquid “HC(L)” stream 108 , and an aqueous stream 106 that are each individually removed from the separator 102 .
- Water forms a majority of the aqueous stream 106 .
- Mercury-containing gas including in part at least a portion of the hydrocarbon gas stream 104 , feeds into a mercury removal unit (MRU) 118 for removal of mercury from the mercury-containing gas, thereby forming a treated gas stream 122 output from the MRU 118 .
- the treated gas stream 122 includes hydrocarbon gas “HC(G),” such as methane, and may provide a supply for natural gas usable in part for sales or as fuel.
- Part of the treated gas stream 122 forms a recycle gas stream 120 , which is introduced into a water-gas contactor 112 for contact with at least a portion of the aqueous stream 106 that also enters the water-gas contactor 112 .
- a water-gas contactor 112 for contact with at least a portion of the aqueous stream 106 that also enters the water-gas contactor 112 .
- the mercury contained in the aqueous stream 106 transfers to the recycle gas stream 120 , thereby forming a water-passed gas stream 116 output from the water-gas contactor 112 and a treated water “H2O” stream 114 output from the water-gas contactor 112 .
- the water-passed gas stream 116 hence includes hydrocarbon gas and mercury “HC(G)+HG.”
- the water-passed gas stream 116 mixes with the hydrocarbon gas stream 104 and provides a portion of the mercury-containing gas that feeds into the MRU 118 .
- an optional chemical additive stream 110 mixes with the aqueous stream 106 to introduce a reducing agent into the aqueous stream 106 upstream from passing of the recycle gas stream 120 in contact with the aqueous stream 106 .
- the reducing agent breaks molecular bonds between mercury atoms and other elements in mercury-containing compounds.
- the reducing agent may be provided as a liquid and includes any substance that forms a compound with such released non-mercury elements to prevent recombination with elemental mercury. Examples of the reducing agent include stannous chloride (SnCl 2 ; “SNCL2”), sodium borohydride, and hydrazine. Amount of the reducing agent introduced via the additive stream depends on concentration of mercury in the aqueous stream 106 and may be sufficient to establish an excess mole ratio of the reducing agent relative to the mercury.
- the reducing agent supplied through the additive stream 110 may facilitate effectiveness of sparging within the water-gas contactor 112 since mercury removal ability via the sparging is higher for elemental mercury relative to when not in elemental form.
- Reducing inorganic compounds, such as mercury oxide or mercuric chloride, in the aqueous stream 106 tends to promote the mercury removal.
- the elemental mercury may convert into mixed element compounds due to cooling of the aqueous stream 106 and temperature influence on solubility of the elemental mercury.
- the aqueous stream 106 may cool upon coming out of the well making introduction of the additive stream 110 desirable to reduce the inorganic compounds to the elemental mercury.
- the treated water stream 114 passes through an optional filtration system 124 to remove suspended particulates from the treated water stream 114 .
- the filtration system 124 operates based on size exclusion to trap or retain particles above a certain size, such as about 0.2 micron or about 0.4 micron.
- the cooling that is inevitable after the input stream 100 comes out of the well promotes adherence of the mercury to the particulates.
- Generation of a filtered water stream 126 flowing out of the filtration system 124 thus results in further mercury removal .since residual mercury still within the treated water stream 114 is associated with the particulates.
- the water-gas contactor 112 includes multiple (e.g., 2, 4, 6 or more) theoretical stages of separation between vapor and liquid phases. Either trays or packing material of the water-gas contactor 112 may form the theoretical stages by being in a flow path of fluids described herein passing through the water-gas contactor 112 .
- the packing material making up an internal part of the water-gas contactor 112 may include random oriented objects or a shaped structure and may be made of metallic, ceramic, plastic or other solid material.
- amount of the packing material utilized depends on a desired number of the stages provided by the packing material.
- the MRU 118 defines a fixed bed including any mercury sorbent material capable of removing mercury from gases.
- the treated gas stream 122 includes less than about 20 weight percent (wt. %) of the mercury within the mercury-containing gas, less than about 10 wt. % of the mercury within the mercury-containing gas, or less than about 1 wt. % of the mercury within the mercury-containing gas.
- the treated water stream 114 or the filtered water stream 126 may contain less than about 50 wt. %, 10 wt. %, or 1 wt. % of the mercury contained in the aqueous stream 106 .
- the aqueous stream 106 for some embodiments contains at least about 5 parts-per-billion (ppb), 100 ppb or 500 ppb mercury.
- the recycle gas stream 120 contacts the aqueous stream 106 at ambient temperature, such as about 21° C., or from about 0° C. to about 300° C.; a pressure in the range of from about 0.1 Bars to about 15 Bars, from about 0.5 Bars to about 10 Bars, or from about 1 Bar to about 5 Bars; and a gas to liquid ratio in the range of from about 50 to about 300 standard cubic feet of gas/barrel of liquid (SCF/bbl) or from about 100 to about 200 SCF/bbl.
- ambient temperature such as about 21° C., or from about 0° C. to about 300° C.
- a pressure in the range of from about 0.1 Bars to about 15 Bars, from about 0.5 Bars to about 10 Bars, or from about 1 Bar to about 5 Bars
- a gas to liquid ratio in the range of from about 50 to about 300 standard cubic feet of gas/barrel of liquid (SCF/bbl) or from about 100 to about 200 SCF/bbl.
- FIG. 2 illustrates a schematic of a production system that includes a subunit for removing mercury from the hydrocarbon liquid stream 108 .
- the system incorporates an oil-gas contactor 200 of the subunit with elements already described herein with respect to FIG. 1 and identified by common reference numbers.
- a first portion 220 of the treated gas stream 122 enters the water-gas contactor 112 to generate the treated water stream 114 .
- a second portion 221 of the treated gas stream 122 flows into the oil-gas contactor 200 and is introduced into the hydrocarbon liquid stream 108 also input into the oil-gas contactor 200 .
- Such contacting transfers mercury from the hydrocarbon liquid stream 108 to the second portion 221 of the treated gas stream 122 and occurs subsequent to separation of the hydrocarbon liquid stream 108 from the aqueous stream 106 .
- Resulting effluent from the oil-gas contactor 200 includes hydrocarbon liquids forming a treated oil stream 208 and hydrocarbon gases contaminated with mercury forming an oil-passed gas stream 216 .
- the oil-passed gas stream 216 also passes through the mercury removal unit 118 and is thereby regenerated to make up part of the treated gas stream 122 .
- FIG. 3 shows a schematic of a production system with an exemplary alternative configuration such that a subunit provides initial removal of mercury from a hydrocarbon and water liquid mixture.
- U.S. patent application Ser. No. 12/538,606 which is herein incorporated by reference in its entirety, further describes such exemplary techniques depicted by the subunits in FIGS. 2 and 3 for liquid hydrocarbon processing to remove mercury.
- the water-gas contactor 112 generates the treated water stream 114 utilizing a first portion 320 of the treated gas stream 122 .
- the system further incorporates an emulsion-gas contactor 300 of the subunit.
- the separator 102 may only provide separation for two phases leaving water in the hydrocarbon liquid stream 108 that feeds into the emulsion-gas contactor 300 .
- a second portion 321 of the treated gas stream 122 flows into the emulsion-gas contactor 300 where introduced into the hydrocarbon liquid stream 108 .
- Such contacting transfers mercury from the hydrocarbon liquid stream 108 to the second portion 321 of the treated gas stream 122 and occurs prior to separation of the aqueous stream 106 out of the hydrocarbon liquid stream 108 .
- Three individual resulting effluents from the oil-gas contactor 200 include hydrocarbon liquids forming a treated oil stream 308 , hydrocarbon gases contaminated with mercury forming an emulsion-passed gas stream 316 , and the aqueous stream 106 , which then feeds to the water-gas contactor 112 for further water treatment as set forth herein.
- the emulsion-passed gas stream 316 passes through the mercury removal unit 118 and is thereby regenerated to make up part of the treated gas stream 122 .
- the oil-gas contactor 200 and the emulsion-gas contactor 300 enable reducing mercury concentration in the hydrocarbon liquid stream 108 independent of utilizing the water-gas contactor 112 to remove the mercury from the aqueous stream 106 .
- Thresholds for mercury concentrations in the hydrocarbon liquids depend on economics and marketability to refineries. However, mercury concentration in the water may need to meet separate set requirements necessitating individual treatment of the aqueous stream 106 .
- independent processing of the aqueous stream 106 to remove mercury makes possible optional addition of the reducing agent, optional use of the filtration system 124 , and conducting treatment without having to ensure certain temperatures of the aqueous stream 106 during the contacting to remove the mercury.
- FIG. 4 depicts a graph showing mercury concentration in water before and after being contacted with a stream of hydrocarbon gas.
- the water Prior to being sparged with the gas, the water contained 489 micrograms per liter ( ⁇ g/l) of total mercury and 1.4 82 g/l of dissolved mercury.
- the water after being sparged with the gas for 20 minutes contained no dissolved mercury and had only 10 ⁇ g/l of the total mercury remaining. Since the 10 ⁇ g/l of the total mercury remaining was associated with suspended particles greater than 0.45 microns in size, filtering provided an option for removing residual mercury from the water following the sparging. Results thus demonstrated effectiveness of such techniques for removing mercury from actual produced water.
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Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
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US12/879,724 US20110068046A1 (en) | 2009-09-18 | 2010-09-10 | Mercury removal from water |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US24387909P | 2009-09-18 | 2009-09-18 | |
US12/879,724 US20110068046A1 (en) | 2009-09-18 | 2010-09-10 | Mercury removal from water |
Publications (1)
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US20110068046A1 true US20110068046A1 (en) | 2011-03-24 |
Family
ID=43755715
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US12/879,724 Abandoned US20110068046A1 (en) | 2009-09-18 | 2010-09-10 | Mercury removal from water |
Country Status (6)
Country | Link |
---|---|
US (1) | US20110068046A1 (fr) |
EP (1) | EP2478123A4 (fr) |
CN (1) | CN102498223A (fr) |
AU (1) | AU2010295857B2 (fr) |
CA (1) | CA2774488A1 (fr) |
WO (1) | WO2011034791A1 (fr) |
Cited By (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP2508243A1 (fr) * | 2011-04-06 | 2012-10-10 | Shell Internationale Research Maatschappij B.V. | Procédé et appareil pour éliminer du mercure d'un flux de puits d'hydrocarbures |
US20130306310A1 (en) * | 2012-05-16 | 2013-11-21 | Darrell Lynn Gallup | Pipeline reaction for removing heavy metals from produced fluids |
US9296956B2 (en) | 2010-10-28 | 2016-03-29 | Chevron U.S.A. Inc. | Method for reducing mercaptans in hydrocarbons |
US10514371B2 (en) | 2017-11-01 | 2019-12-24 | Savannah River Nuclear Solutions, Llc | Reactive diffusive gradient in thin-film sampler and mercury speciation by use of same |
US11319225B2 (en) | 2018-10-24 | 2022-05-03 | Savannah River Nuclear Solutions, Llc | Modular system and method for mercury speciation in a fluid sample |
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CN103476710B (zh) * | 2011-02-01 | 2016-12-28 | 澳大利亚生物精炼私人有限公司 | 磷酸纤维素粉末产品及其制造方法以及从含水溶液中去除污染物的应用 |
CN102874956B (zh) * | 2012-11-02 | 2013-09-04 | 永兴鑫裕环保镍业有限公司 | 一种含汞工业废水处理工艺 |
US9023196B2 (en) * | 2013-03-14 | 2015-05-05 | Chevron U.S.A. Inc. | Process, method, and system for removing heavy metals from fluids |
WO2017066453A1 (fr) | 2015-10-13 | 2017-04-20 | Regents Of The University Of Minnesota | Nanomatériaux à base de sélénium et leurs procédés de fabrication et d'utilisation |
CN108687114B (zh) * | 2018-05-16 | 2021-05-11 | 扬州杰嘉工业固废处置有限公司 | 一种含汞试剂废物稳定及固化处置工艺 |
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KR20140019434A (ko) * | 2011-04-06 | 2014-02-14 | 쉘 인터내셔날 리써취 마트샤피지 비.브이. | 탄화수소 웰 스트림으로부터의 폐수로부터 수은을 제거하는 방법 및 장치 |
AU2012238593B2 (en) * | 2011-04-06 | 2015-12-03 | Shell Internationale Research Maatschappij B.V. | Method and apparatus for removing mercury from waste water from hydrocarbon well stream |
KR101978529B1 (ko) * | 2011-04-06 | 2019-05-14 | 쉘 인터내셔날 리써취 마트샤피지 비.브이. | 탄화수소 웰 스트림으로부터의 폐수로부터 수은을 제거하는 방법 및 장치 |
US20130306310A1 (en) * | 2012-05-16 | 2013-11-21 | Darrell Lynn Gallup | Pipeline reaction for removing heavy metals from produced fluids |
US10514371B2 (en) | 2017-11-01 | 2019-12-24 | Savannah River Nuclear Solutions, Llc | Reactive diffusive gradient in thin-film sampler and mercury speciation by use of same |
US11319225B2 (en) | 2018-10-24 | 2022-05-03 | Savannah River Nuclear Solutions, Llc | Modular system and method for mercury speciation in a fluid sample |
Also Published As
Publication number | Publication date |
---|---|
CN102498223A (zh) | 2012-06-13 |
CA2774488A1 (fr) | 2011-03-24 |
AU2010295857B2 (en) | 2014-04-17 |
EP2478123A4 (fr) | 2014-06-11 |
EP2478123A1 (fr) | 2012-07-25 |
WO2011034791A1 (fr) | 2011-03-24 |
AU2010295857A1 (en) | 2012-03-08 |
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