WO2004050567A1 - Procede de traitement des eaux pour la production de petrole lourd - Google Patents

Procede de traitement des eaux pour la production de petrole lourd Download PDF

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Publication number
WO2004050567A1
WO2004050567A1 PCT/US2002/038248 US0238248W WO2004050567A1 WO 2004050567 A1 WO2004050567 A1 WO 2004050567A1 US 0238248 W US0238248 W US 0238248W WO 2004050567 A1 WO2004050567 A1 WO 2004050567A1
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WIPO (PCT)
Prior art keywords
evaporator
set forth
feedwater
stream
steam
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Application number
PCT/US2002/038248
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English (en)
Inventor
William Heins
Original Assignee
Ionics, Incorporated
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Ionics, Incorporated filed Critical Ionics, Incorporated
Priority to CA002448680A priority Critical patent/CA2448680A1/fr
Priority to AU2002360445A priority patent/AU2002360445A1/en
Priority to PCT/US2002/038248 priority patent/WO2004050567A1/fr
Publication of WO2004050567A1 publication Critical patent/WO2004050567A1/fr

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    • CCHEMISTRY; METALLURGY
    • C02TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02FTREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02F1/00Treatment of water, waste water, or sewage
    • C02F1/02Treatment of water, waste water, or sewage by heating
    • C02F1/04Treatment of water, waste water, or sewage by heating by distillation or evaporation
    • C02F1/048Purification of waste water by evaporation
    • CCHEMISTRY; METALLURGY
    • C02TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02FTREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02F2101/00Nature of the contaminant
    • C02F2101/30Organic compounds
    • C02F2101/32Hydrocarbons, e.g. oil
    • CCHEMISTRY; METALLURGY
    • C02TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02FTREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02F2103/00Nature of the water, waste water, sewage or sludge to be treated
    • C02F2103/10Nature of the water, waste water, sewage or sludge to be treated from quarries or from mining activities

Definitions

  • the invention disclosed and claimed herein relates to treatment of water to be used for steam generation in operations which utilize steam to recover oil from geological formations. More specifically, this invention relates to techniques for the preparation of high quality water for steam generators whose steam product is subjected to down-hole use in heavy oil recovery operations.
  • OTSG once-through type steam generators
  • Such steam generators are most commonly provided in a configuration and with process parameters so that steam is generated from a feedwater in a single-pass operation through boiler tubes heated by gas or oil burners.
  • FIG. 1 which depicts the process flow sheet of a typical prior art water treatment system 10
  • such a once through steam generator 12 provides a low quality or wet steam, wherein about eighty percent (80%) quality steam is produced at about 1000 pounds per square inch (psig), or up to as much as 1800 psig.
  • the 80% quality steam 14 (which is 80% vapor, 20% liquid, by weight percent) is injected via steam injection wells 16 to fluidize as indicated by reference arrows 18, along or in combination with other injectants, the heavy oil formation 20, such as oils in tar sands formations. Steam 14 eventually condenses and an oil/water mixture 22 results that migrates through the formation 20 as indicated by reference arrows 24.
  • the oil/water mixture 22 is gathered as indicated by reference arrows 26 by oil/water gathering wells 30 and is pumped to the surface. Then, the sought-after oil is sent to an oil/water separator 32 in which the oil product 34 separated from the water 35 and recovered for sale.
  • the produced water stream 36 after separation from the oil, is further de-oiled in a de-oiling process step 40, normally by addition of a de- oiling polymer 42, which de-oiling process usually results in waste oil/solids sludge 44.
  • the de-oiled produced water stream 46 is then further treated for reuse.
  • the water treatment plant schemes which have heretofore been provided for the produced water stream 46, i.e., downstream of the de-oiling unit 40 and upstream of injection well 16 inlet 48, and the type of boilers which are necessary or desirable as a consequence thereof, is the focus the important improvements described in this disclosure.
  • the water is sent to the "once-through" steam generators 12 for creation of more steam 14 for oil recovery operations.
  • the treated produced water stream 12F is typically required to have less than about 8000 parts per million (“PPM”) of total dissolved solids (“TDS”), and, less frequently, may have up to about 12000 parts per million (as CaCO3 equivalent) of total dissolved solids, as noted in FIG. 6B.
  • PPM parts per million
  • CaCO3 equivalent total dissolved solids
  • the de-oiled recovered water 46 must be treated in a costly water treatment plant sub-system 101 before it can be sent to the steam generators 12.
  • Treatment of water before feed to the once-through steam generators 12 is often initially accomplished by using a warm lime softener 50, which removes hardness, and which removes some silica from the de-oiled produced water feedstream 46.
  • Various softening chemicals 52 are usually necessary, such as lime, flocculating polymer, and perhaps soda ash.
  • the softener clarifier 54 underflow 56 produces a waste sludge 58 which must be further handled and disposed.
  • an "after-filter” 60 is often utilized on the clarate stream 59 from the softener clarifier 54, to prevent carry-over from the softener clarifier 54 of any precipitate or other suspended solids, which substances are thus accumulated in a filtrate waste stream 62.
  • an ion exchange step 64 normally including a hardness removal step such as a weak acid cation (WAC) ion-exchange system that can be utilized to simultaneously remove hardness and the alkalinity associated with the hardness, is utilized.
  • WAC weak acid cation
  • the ion exchange systems 64 require regeneration chemicals 66 as well understood by those of ordinary skill in the art and to which this disclosure is directed. However, regeneration of the ion-exchange system 64 results in the creation of a regeneration waste stream 68.
  • SAGD steam assisted gravity drainage heavy oil recovery process
  • a vapor-liquid separator 72 is required to separate the liquid water from the steam. Then, the liquid blowdown 73 recovered from the separator is typically flashed several times in a series of flash tanks F1 , F2, etc. through FN (where N is a positive integer equal to the number of flash tanks) to successively recover as series of lower pressure steam flows S1 , S2, etc. which may sometimes be utilized for other plant heating purposes. After the last flashing stage FN, a residual hot water final blowdown stream 74 must then be handled, by recycle and/or disposal. The 100% quality steam is then sent down the injection well 16 and injected into the desired formation 20. As depicted in FIG.
  • Another method which has been proposed for generating the required 100% quality steam for use in the steam assisted gravity drainage process involves the use of packaged boilers 80.
  • Various methods are known for producing water of sufficient quality to be utilized as feedwater 80F to a packaged boiler.
  • One method which has been developed for use in heavy oil recovery operations involves de-oiling 40 of the produced water 36, followed by a series of physical-chemical treatment steps. Such treatment steps normally include a series of unit operations as warm lime softening 54, followed by filtration 60 for removal of residual particulates, then an organic trap 84 (normally non-ionic ion exchange resin) for removal of residual organics.
  • the organic trap 84 may require a regenerant chemical supply 85, and, in any case, produces a waste 86, such as a regenerant waste.
  • a pre-coat filter 88 can be used, which has a precoat filtrate waste 89.
  • an ultrafiltration (“UF”) unit 90 can be utilized, which unit produces a reject waste stream 91.
  • effluent from the UF unit 90 or precoat filter 88 can be sent to a reverse osmosis (“RO") system 92, which in addition to the desired permeate 94, produces a reject liquid stream 96 that must be appropriately handled.
  • RO reverse osmosis
  • Permeate 94 from the RO system 92 can be sent to an ion exchange unit 100, typically but not necessarily a mixed bed demineralization unit, which of course requires regeneration chemicals 102 and which consequently produces a regeneration waste 104.
  • the packaged boiler 80 produces a blowdown 110 which must be accommodated for reuse or disposal.
  • a new water treatment process disclosed herein, and various embodiments thereof, can be applied to heavy oil production operations. Such embodiments are particularly advantageous in they minimize the generation of waste products, and are otherwise superior to water treatment processes heretofore used or proposed in the recovery of bitumen from tar sands or other heavy oil recovery operations.
  • Another important objective is to simplify process plant flow sheets, i.e., minimize the number of unit processes required in a water treatment train, which importantly simplifies operations and improves quality control in the manufacture of high purity water for down-hole applications.
  • an improved water treatment process for production of high purity water for down-hole use in heavy oil recovery which: - in one embodiment, eliminates the requirement for separation of the high pressure steam to be utilized downhole from residual hot liquids;
  • FIG. 1 shows a prior art process, namely a generalized process flow diagram for one typical physical-chemical water treatment process in heavy oil recovery operations.
  • FIG. 2 shows a prior art process, namely a generalized process flow diagram for an industry state-of-the-art water treatment process in steam assisted gravity drainage (SAGD) type heavy oil operations.
  • SAGD steam assisted gravity drainage
  • FIG. 3 shows a prior art physical-chemical treatment process scheme, as it might be applied for use in steam assisted gravity drainage (SAGD) type heavy oil recovery operations.
  • SAGD steam assisted gravity drainage
  • FIG. 4 shows one embodiment of the novel water treatment process disclosed and claimed herein, illustrating the use of the process in combination with the use of packaged boilers for steam production, as applied to heavy oil recovery operations.
  • FIG. 4A shows one common variation of well orientation utilized in heavy oil recovery, namely the use of horizontal steam injection wells and of horizontal oil/water gathering wells, such as commonly encountered in a steam assisted gravity drainage heavy oil gathering project.
  • FIG. 5 shows another embodiment of the novel water treatment process disclosed and claimed herein, illustrating the use of the process in combination with the use of once-through steam generators for steam production, as applied to heavy oil recovery operations, which process is characterized by feed of evaporator distillate to once-through steam generators without the necessity of further pretreatment.
  • FIG. 6A shows the typical feedwater quality requirements for steam generators which produce steam in the 1000 pounds per square inch gauge range, or thereabouts, for packaged boiler type installations.
  • FIG. 6B shows the typical feedwater quality requirements for steam generators which produce steam in the 1000 pounds per square inch gauge range, or thereabouts, for once-through type steam generator installations.
  • FIG. 7 illustrates the solubility of silica in water as a function of pH at 25 ° C when such silica species are in equilibrium with amorphous silica, as well as the nature of such soluble silica species (molecule or ion) at various concentration and pH ranges.
  • FIG. 8 diagrammatically illustrates a seeded-slurry scale prevention mechanism useful in the evaporation of waters containing calcium sulfate and silica, as well as the condensation of an evaporated steam distillate at a heat exchange tube, and the downward flow of such condensate by gravity for the collection of such condensate above the bottom tubesheet of an evaporator.
  • This process can substantially reduce capital costs and can minimize ongoing operation and maintenance costs of heavy oil recovery.
  • the elimination of handling of waste sludges and waste streams made possible by the evaporation based water treatment system 120 may be especially important, since it may be difficult to work such waste materials during the extremely cold winter months.
  • the novel process disclosed herein includes an evaporation unit 140 based approach to packaged boiler 80 feedwater 80F pretreatment (i.e., pretreatment of the de-oiled produced water 46 generated following the de-oiling process 40 in line after the oil/water separation process 32) has now been developed as a novel, improved method for produced water treatment in heavy oil production.
  • An oil/water mixture 22 is pumped up through oil gathering wells 30 and this mixture is sent to a series of oil/water separators 32.
  • An oil product 34 is gathered for further conditioning, transport, and sale.
  • the produced water 36 which has been separated from the oil/water mixture 22 is then sent to a produced water de-oiling step 40, which may be accomplished in dissolved air flotation units with the assistance of the addition of a de-oiling polymer 42, or by other appropriate unit processes.
  • the de-oiled produced water 46 is treated and conditioned for feed to a mechanical vapor recompression evaporator unit 140 to concentrate the incoming produced water stream 46.
  • the necessary treatment and conditioning prior to the evaporator unit 140 can usually be efficiently accomplished by addition when necessary and or appropriate of acid 144, such as sulfuric acid or hydrochloric acid, to lower the pH sufficiently so that bound carbonates are converted to free gaseous carbon dioxide, which is removed, along with other non-condensable gases 148 dissolved in the feedwater 46 such as oxygen and nitrogen, in an evaporator feedwater deaerator 150.
  • acid 144 such as sulfuric acid or hydrochloric acid
  • the conditioned feedwater 151 is sent as feed to evaporator 140.
  • Concentrated brine 152 in the evaporator 140 is recirculated via pump 153, so only a small portion of the recirculating concentrated brine is removed on any one pass through the evaporator 140.
  • evaporator 140 the solutes in the feedwater 46 are concentrated via removal of water from the feedwater 46.
  • evaporator 140 is in one embodiment provided in a falling film configuration wherein a thin brine film 154 falls inside of a heat transfer tube 156.
  • a small portion of the water in the thin brine film 154 is extracted in the form of steam 160, via heat given up from heated, compressed steam 162 which is condensing on the outside of heat transfer tubes 156.
  • the water is removed in the form of steam 160, and that steam is compressed through the compressor 164, and the compressed steam 162 is condensed at a heat exchange tube 156 in order to produce yet more steam 160 to continue the evaporation process.
  • condensing steam on the outer wall 168 of heat transfer tubes 156 which those of ordinary skill in the evaporation arts and to which this disclosure is directed may variously refer to as either condensate or distillate 170, is in relatively pure form, low in total dissolved solids.
  • such distillate contains less than 10 parts per million of total dissolved solids of non-volatile components. Since, as depicted in FIGS. 4 and 5, only a single stage of evaporation is provided, such distillate 170 may be considered to have been boiled, or distilled, once, and thus condensed but once.
  • the falling film evaporator 140 design is provided only for purposes of enabling the reader to understand the water treatment process, and is not intended to limit the process to the use of same, as those in the art will recognized that other designs, such as, for example, a forced circulation evaporator, or a rising film evaporator, may be alternately utilized with the accompanying benefits and/or drawbacks as inherent in such alternative evaporator designs.
  • the distillate 170 descends by gravity along tubes 156 and accumulates above bottom tube sheet 172, from where it is collected via condensate line 174.
  • distillate 170 may be sent via line 172 to the earlier discussed deaerator 150 for use in mass transfer, i.e, heating descending liquids in a packed tower to remove non-condensable gases 148 such as carbon dioxide.
  • the bulk of the distillate is removed as a liquid in line 180, and may be sent for further treatment to ultimately produce a feedwater 80F', in the case where packaged boilers 80 are utilized as depicted in FIG. 4.
  • distillate 180 may be sent directly to once-through steam generators as feedwater 12F' (as distinguished by vastly higher quality from feedwater 12F discussed hereinabove with respect to prior art processes) for generation of 80% quality steam 14.
  • the distillate 180 Before feed to the boilers, it may, in some embodiments, be necessary to remove the residual organics and other residual dissolved solids from the distillate 180. For example, as seen in FIG. 4, in some cases, it may be necessary to remove residual ions from the relatively pure distillate 180 produced by the evaporator 140. In most cases the residual dissolved solids in the distillate involve salts other than hardness. In one embodiment, removal of residual dissolved solids can be accomplished by passing the evaporator distillate 180, after heat exchanger 200, through an ion exchange system 202. Such ion-exchange systems may be of mixed bed type and directed to remove the salts of concern in a particular water being treated.
  • regenerant chemicals 204 will ultimately be required, and regeneration results in a regeneration waste206 that must be further treated.
  • the regeneration waste 206 can be sent back to the evaporator feed tank 210 for a further cycle of treatment through the evaporator 140.
  • removal of residual dissolved solids can be accomplished by passing the evaporator distillate 180 through a heat exchanger 200' and then through electrodeionization (EDI) system 220.
  • the EDI reject 222 is also capable of being recycled to evaporator feed tank 210 for a further cycle of treatment through the evaporator 140.
  • evaporator blowdown 230 which contains the concentrated solutes originally present in feedwater 46, along with additional contaminants from chemical additives (such as caustic 232, when utilized to elevate the pH of recirculating brine 152, or regeneration chemicals 204).
  • chemical additives such as caustic 232, when utilized to elevate the pH of recirculating brine 152, or regeneration chemicals 204.
  • the evaporator blowdown 230 can be disposed in an environmentally acceptable manner, which, depending upon locale, might involve injection in deep wells 240, or alternately, evaporation to complete dryness in a zero discharge system 242, such as a crystallizer or drum dryer, to produce dry solids 244 for disposal.
  • the new process method is useful in heavy oil production since it (1 ) eliminates many physical-chemical treatment steps commonly utilized previously in handing produced water, (2) results in lower capital equipment costs, (3) results in lower operating costs for steam generation, (4) eliminates the production of softener sludge, thus eliminating the need for the disposal of the same, (5) eliminates other waste streams, thus minimizing the number of waste streams requiring disposal, (6) minimizes the materiel and labor required for maintenance, and (7) reduces the size of water de-oiling equipment in most operations.
  • the evaporator 140 is designed to produce high quality distillate (typically 2-5 ppm non-volatile TDS) which, after temperature adjustment to acceptable levels in heat exchangers 200 or 200' (typically by cooling to about 45 C, or lower) can be fed directly into polishing equipment (EDI system 220 or ion exchange system 202) for final removal of dissolved solids.
  • polishing equipment EDI system 220 or ion exchange system 202
  • the water product produced by the polish equipment just mentioned is most advantageously used as feedwater for the packaged boiler 80. That is because in the typical once-though steam generator 12 used in oil field operations, it is normally unnecessary to incur the additional expense of final polishing by removal of residual total dissolved solids from the evaporator distillate stream 180. This can be further understood by reference to FIG.
  • the EDI reject stream 222 is recycled to be mixed with the de-oiled produced water 46 in the evaporator feed tank 210 system, for reprocessing through the evaporator 140.
  • the blowdown 230 from the evaporator 140 is often suitable for disposal by deep well 240 injection.
  • the blowdown stream can be further concentrated and/or crystallized using a crystallizing evaporator, or a crystallizer, in order to provide a zero liquid discharge 242 type operation.
  • silica solubility must be accounted for in the design and operation of the evaporator 140, in order to prevent silica scaling of the heat transfer surfaces 260.
  • the solubility characteristics of silica are shown in Figure 6. Since the high pH operation assures increased silica solubility, a concentration factor (i.e, ratio of feed rate 151 to blowdown rate 230) for the evaporator 140 can be selected so that silica solubility is not exceeded.
  • Operation at high pH also allows the use of low cost heat transfer tubes 156 and other brine wetted surfaces such as sump walls 270, thus minimizing the capital cost of the system.
  • the calcium hardness and sulfate concentrations of many produced waters is low (typically 20-50 ppm Ca as CaCO3), in many cases it is also possible to operate the evaporators 140 below the solubility limit of calcium sulfate, with proper attention to feedwater quality and to pre-treatment processes.
  • the mechanical vapor recompression evaporator 140 can also be operated using a calcium sulfate seeded-slurry technique, even at the high pH of operation.
  • That mode of operation can be made possible by the substantial elimination of carbonate alkalinity before the feedwater is introduced into the evaporator 140.
  • the pH can be controlled between about 11 and about 12, while operating the evaporator 140 in the seeded-slurry mode. Operation of the MVR Evaporator in the Seeded-Slurry Mode
  • the evaporator Prior to the initial startup of the MVR evaporator in the seeded-slurry mode, the evaporator, which in such mode is provided in a falling-film, mechanical vapor recompression configuration, the fluid contents of the unit are "seeded" by the addition of calcium sulfate (gypsum).
  • the circulating solids within the brine slurry serve as nucleation sites for subsequent precipitation of calcium sulfate 272, as well as silica 274.
  • Such substances both are precipitated as an entering feedwater is concentrated.
  • the continued concentrating process produces additional quantities of the precipitated species, and thus creates a continuing source of new "seed" material as these particles are broken up by the mechanical agitation, particularly by the action of the recirculation pump 153.
  • calcium sulfate seed crystals 272 are continuously circulated over the wetted surfaces, i.e., the falling film evaporator tubes 156, as well as other wetted surfaces in the evaporator 140.
  • the evaporator can operate in the otherwise scale forming environment.
  • the thermochemical operation within the evaporator 140 with regard to the scale prevention mechanism is depicted in Figure 7. As the water is evaporated from the brine film 154 inside the tubes 156, the remaining brine film becomes super saturated and calcium sulfate and silica start to precipitate.
  • the precipitating material promotes crystal growth in the slurry rather than new nucleation that would deposit on the heat transfer surfaces; the silica crystals attach themselves to the calcium sulfate crystals.
  • This scale prevention mechanism called preferential precipitation, has a proven capability to promote clean heat transfer surfaces 260.
  • the details of one advantageous method for maintaining adequate seed crystals in preferentially precipitation systems is set forth in U.S. Patent No. 4,618,429, issued October 21 , 1986 to Howard R. Herrigel, the disclosure of which is incorporated into this application in full by this reference. It is to be appreciated that the water treatment process described herein for preparing boiler feedwater in heavy oil recovery operations is an appreciable improvement in the state of the art of water treatment for oil recovery operations.
  • the process eliminates numerous of the heretofore encountered waste streams, while processing water in reliable mechanical evaporators, and in one embodiment, in mechanical vapor recompression ("MVR") evaporators .
  • Polishing if necessary, can be accomplished in ion exchange and electrodeionization equipment.
  • the process thus improves on currently used treatment methods by eliminating most treatment or regeneration chemicals, eliminating many waste streams, eliminating some types of equipment. Thus, the complexity associated with a high number of treatment steps involving different unit operations is avoided.
  • the control over waste streams is focused on a the evaporator blowdown, which can be conveniently treated by deep well 240 injection, or in a zero discharge system 242 such as a crystallizer and/or spray dryer, to reduce all remaining liquids to dryness and producing a dry solid 244.
  • a zero discharge system 242 such as a crystallizer and/or spray dryer
  • this waste water treatment process also reduces the chemical handling requirements associated with water treatment operations.

Abstract

L'invention concerne un procédé de traitement par évaporation d'eau produite à partir de la production de pétrole lourd. Cette eau produite à partir d'opérations de récupération de pétrole lourd est tout d'abord traitée par retrait de pétrole et de graisse jusqu'à un niveau souhaité, de préférence environ 20 parties par million, ou moins, dans l'étape de déshuilage (40). Le pH est ensuite ajusté, normalement vers le bas et de l'acide y est ajouté, dans une étape d'addition d'acide (144) afin de libérer au moins une partie de l'alcalinité du carbonate en tant que dioxyde de carbone libre. De l'eau d'alimentation est introduite dans un évaporateur (140) et cette eau d'alimentation est évaporée à un facteur de concentration sélectionné afin de produire: un distillat possédant une petite quantité de solution résiduelle; et une purge d'évaporateur contenant des solides résiduels. Le distillat peut être directement utilisé pour produire de la vapeur dans un générateur de vapeur à passage unique ou peut être poli par une unité d'échange d'ions (22) ou soumis à une électrodionisation avant d'être alimenté dans une chaudière préfabriquée (80). Dans les deux cas, 100 % de la vapeur de qualité est produite pour une utilisation de fond.
PCT/US2002/038248 2002-11-30 2002-11-30 Procede de traitement des eaux pour la production de petrole lourd WO2004050567A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
CA002448680A CA2448680A1 (fr) 2002-11-30 2002-11-30 Methode de traitement de l'eau pour la production de petrole lourd
AU2002360445A AU2002360445A1 (en) 2002-11-30 2002-11-30 Water treatment method for heavy oil production
PCT/US2002/038248 WO2004050567A1 (fr) 2002-11-30 2002-11-30 Procede de traitement des eaux pour la production de petrole lourd

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Application Number Priority Date Filing Date Title
PCT/US2002/038248 WO2004050567A1 (fr) 2002-11-30 2002-11-30 Procede de traitement des eaux pour la production de petrole lourd

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US7770643B2 (en) 2006-10-10 2010-08-10 Halliburton Energy Services, Inc. Hydrocarbon recovery using fluids
US7809538B2 (en) 2006-01-13 2010-10-05 Halliburton Energy Services, Inc. Real time monitoring and control of thermal recovery operations for heavy oil reservoirs
US7832482B2 (en) 2006-10-10 2010-11-16 Halliburton Energy Services, Inc. Producing resources using steam injection
CN102659197A (zh) * 2012-05-18 2012-09-12 江苏中圣高科技产业有限公司 一种回收重油开采采出水作为锅炉给水的水处理工艺
US9133697B2 (en) 2007-07-06 2015-09-15 Halliburton Energy Services, Inc. Producing resources using heated fluid injection
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US10487636B2 (en) 2017-07-27 2019-11-26 Exxonmobil Upstream Research Company Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes
US11002123B2 (en) 2017-08-31 2021-05-11 Exxonmobil Upstream Research Company Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation
US11142681B2 (en) 2017-06-29 2021-10-12 Exxonmobil Upstream Research Company Chasing solvent for enhanced recovery processes
US11261725B2 (en) 2017-10-24 2022-03-01 Exxonmobil Upstream Research Company Systems and methods for estimating and controlling liquid level using periodic shut-ins
US11332386B2 (en) 2018-02-09 2022-05-17 Aquamare, LLC Well wastewater treatment

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CA2455011C (fr) 2004-01-09 2011-04-05 Suncor Energy Inc. Traitement de mousse bitumineuse par injection de vapeur en ligne
CN107140779A (zh) * 2017-07-06 2017-09-08 重集团大连工程技术有限公司 一种核电站蒸发器排污水的零排放处理系统及其处理方法

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Cited By (14)

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Publication number Priority date Publication date Assignee Title
US7809538B2 (en) 2006-01-13 2010-10-05 Halliburton Energy Services, Inc. Real time monitoring and control of thermal recovery operations for heavy oil reservoirs
US7832482B2 (en) 2006-10-10 2010-11-16 Halliburton Energy Services, Inc. Producing resources using steam injection
US7770643B2 (en) 2006-10-10 2010-08-10 Halliburton Energy Services, Inc. Hydrocarbon recovery using fluids
US9133697B2 (en) 2007-07-06 2015-09-15 Halliburton Energy Services, Inc. Producing resources using heated fluid injection
CN102659197A (zh) * 2012-05-18 2012-09-12 江苏中圣高科技产业有限公司 一种回收重油开采采出水作为锅炉给水的水处理工艺
CN102659197B (zh) * 2012-05-18 2014-07-02 江苏中圣高科技产业有限公司 一种回收重油开采采出水作为锅炉给水的水处理工艺
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