+

WO2009085461A1 - Valorisation d'huiles lourdes hydrocarbonées - Google Patents

Valorisation d'huiles lourdes hydrocarbonées Download PDF

Info

Publication number
WO2009085461A1
WO2009085461A1 PCT/US2008/084208 US2008084208W WO2009085461A1 WO 2009085461 A1 WO2009085461 A1 WO 2009085461A1 US 2008084208 W US2008084208 W US 2008084208W WO 2009085461 A1 WO2009085461 A1 WO 2009085461A1
Authority
WO
WIPO (PCT)
Prior art keywords
water
oil
emulsion
process according
heavy
Prior art date
Application number
PCT/US2008/084208
Other languages
English (en)
Inventor
Lin Li
Alberto Montesi
Lee D. Rhyne
Zunqing He
Original Assignee
Chevron U.S.A. Inc.
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 Chevron U.S.A. Inc. filed Critical Chevron U.S.A. Inc.
Publication of WO2009085461A1 publication Critical patent/WO2009085461A1/fr

Links

Classifications

    • 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
    • C10G31/08—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for by treating with water

Definitions

  • the present invention relates to upgrading of heavy hydrocarbons such as whole heavy oil, bitumen, and the like using supercritical water.
  • Oil produced from a significant number of oil reserves around the world is simply too heavy to flow under ambient conditions. This makes it challenging to bring remote, heavy oil resources closer to the markets.
  • One typical example is the Hamaca field in Venezuela.
  • the diluent may be naphtha, or any other stream with a significantly higher API gravity (i.e., much lower density) than the heavy oil.
  • diluted crude oil is sent from the production wellhead via pipeline to an upgrading facility.
  • Two key operations occur at the upgrading facility: (1) the diluent stream is recovered and recycled back to the production wellhead in a separate pipeline, and (2) the heavy oil is upgraded with suitable technology known in the art (coking, hydrocracking, hydrotreating, etc.) to produce higher-value products for market.
  • suitable technology known in the art (coking, hydrocracking, hydrotreating, etc.) to produce higher-value products for market.
  • Some typical characteristics of these higher-value products include: lower sulfur content, lower metals content, lower total acid number (TAN), lower residuum content, higher API gravity, and lower viscosity. Most of these desirable characteristics are achieved by reacting the heavy oil with hydrogen gas at high temperatures and pressures in the presence of a catalyst.
  • Hydrogen-addition processes also have high operating costs, since hydrogen production costs are highly sensitive to natural gas prices. Some remote heavy oil reserves may not even have access to sufficient quantities of low-cost natural gas to support a hydrogen plant.
  • the refineries and/or upgrading facilities that are located closest to the production site may have neither the capacity nor the facilities to accept the heavy oil.
  • Coking is often used at refineries or upgrading facilities. Significant amounts of by-product solid coke are rejected during the coking process, leading to lower liquid hydrocarbon yield. In addition, the liquid products from a coking plant often need further hydrotreating.
  • volume of the product from the coking process is significantly less than the volume of the feed crude oil.
  • a process according to the present invention overcomes these disadvantages by using supercritical water to upgrade a heavy hydrocarbon feedstock into an upgraded hydrocarbon product or syncrude with highly desirable properties (low sulfur content, low metals content, lower density (higher API), lower viscosity, lower residuum content, etc.).
  • the process neither requires external supply of hydrogen nor must it use catalysts. Further, the process in the present invention does not produce an appreciable coke by-product.
  • advantages that may be obtained by the practice of the present invention include a high liquid hydrocarbon yield; no need for externally-supplied hydrogen; no need to provide catalyst; significant increases in API gravity in the upgraded hydrocarbon product; significant viscosity reduction in the upgraded hydrocarbon product; and significant reduction in sulfur, metals, nitrogen, TAN, and MCR (micro-carbon residue) in the upgraded hydrocarbon product.
  • U.S. Patent No 4,840,725 discloses a process for conversion of high boiling liquid organic materials to lower boiling materials using supercritical water in a tubular continuous reactor.
  • the water and hydrocarbon are separately preheated and mixed in a high-pressure feed pump just before being fed to the reactor.
  • U.S. Patent No. 6,887,369 discloses a supercritical water pretreatment process using hydrogen or carbon monoxide preferably carried out in a deep well reactor to hydrotreat and hydrocrack carbonaceous material.
  • the deep well reactor is adapted from underground oil wells, and consists of multiple, concentric tubes.
  • the deep well reactor described in the patent is operated by introducing feed streams in the core tubes and returning reactor effluent in the outer annular section.
  • the present invention relates to a process for upgrading hydrocarbons comprising mixing hydrocarbons with a fluid comprising water in a mixing zone to form an emulsion; heating the emulsion to a temperature above the critical temperature of water; reacting the emulsion in a reaction zone under supercritical water conditions in the absence of externally added hydrogen for a residence time sufficient to allow upgrading reactions to occur; withdrawing a single-phase reaction product from the reaction zone; and separating the reaction product into gas, effluent water, and upgraded hydrocarbon phases.
  • Fig. 1 is a process flow diagram of an embodiment of the present invention.
  • Fig. 2 is a process flow diagram of an embodiment of the present invention.
  • Fig. 3 is a process flow diagram of an embodiment of the present invention.
  • the present process is related to processes described in commonly assigned U.S. Patent Applications 11/555,048; 11/555,130; 11/555,196; and 11/555,211 , all of which were filed on October 31 , 2006 and which are incorporated by reference herein.
  • These patent applications relate to various aspects of heavy oil upgrading technology using supercritical water.
  • the present disclosure also relates to processes using supercritical water to upgrade hydrocarbons and in a way to make fuller use of the potential of supercritical water and minimize by products produced by side reactions by focusing on the solvent oil mixing and contacting. This is accomplished by using the herein disclosed technology to enhance solvent-oil mixing/contacting through formation of emulsion so that the performance of upgrading process can be significantly improved.
  • Water and hydrocarbons, preferably heavy hydrocarbons are the two reactants employed in a process according to the present invention.
  • Any heavy hydrocarbon can be suitably upgraded by a process according to the present invention.
  • the preferred heavy hydrocarbons are heavy crude oil, heavy hydrocarbons extracted from tar sands, commonly called tar sand bitumen, such as Athabasca tar sand bitumen obtained from Canada, heavy petroleum crude oils such as Venezuelan Orinoco heavy oil belt crudes, Boscan heavy oil, heavy hydrocarbon fractions obtained from crude petroleum oils, particularly heavy vacuum gas oils, vacuum residuum as well as petroleum tar, tar sands and coal tar.
  • Other examples of heavy hydrocarbon feedstocks which can be used are oil shale, shale oil, and asphaltenes.
  • Sources of water include but are not limited to drinking water, treated or untreated wastewater, river water, lake water, seawater produced water or the like.
  • a heavy hydrocarbon feed and the fluid comprising water are contacted in a mixing zone to form an emulsion prior to entering the reaction zone.
  • Forming an emulsion allows the present process to utilize the advantage of the high interfacial area of emulsions to improve water-oil contacting.
  • surrounding the heavy hydrocarbon molecules by water molecules during heating and reaction processes avoids over cracking the hydrocarbon feed into light hydrocarbons and polymerizing the hydrocarbon feed into coke.
  • One way to achieve the goal of surrounding the heavy hydrocarbon molecules by water molecules is to form an emulsion, i.e. a kinetically or thermodynamically stable dispersion of an oil phase and an aqueous phase, with or without added surfactant.
  • the high interfacial area of emulsion will provide sufficient contact and mixing of oil with water to achieve a high yield of liquid hydrocarbons.
  • the structure and droplet size of the emulsion can be optimized based on process performance requirement and operation cost.
  • Surfactants or other agents (emulsifiers) may be needed to form a stable emulsion with required structure and droplet size.
  • the emulsion may be either an oil-in-water emulsion or a water-in-oil emulsion.
  • a surfactant or a mix of surfactants may be included in the heavy oil/water feedstock emulsion to increase the stability of the emulsion.
  • Suitable surfactants include both water and oil soluble surfactants.
  • a suitable surfactant or mixtures of surfactants include surfactants having a hydrophilic- lipophilic balance in the range of between about 2 and about 10 and mixtures thereof. When a single surfactant is used, sufficient amounts are used to obtain a stable emulsion. Typically this concentration of single surfactant falls in the range of between about 50 ppm and about 2% of the emulsion. It has been found that when a combination of surfactants is used, the total amount of surfactant added is typically less than the amount used for any single surfactant.
  • Suitable emulsifiers include fatty acid soaps such as calcium dioleate, fatty amides such as the reaction products of oleic acid and diethylamine thiamine, a variety of polymeric emulsifiers containing alcohol or carboxylic acid groups or organophilic clays, and certain organic-silicone-based polymers.
  • Figure 1 shows one embodiment.
  • the water and oil are pumped to a mixer where an oil-in-water emulsion is formed.
  • the emulsion has a ratio of oil to water from 10:1 to 1 :5.
  • the oil-in-water emulsion can be prepared in any convenient way suitable for making a fine dispersion of an aqueous phase in a continuous oil phase, but preferably it is prepared by strong physical agitation of the aqueous and oil components optionally in the presence of a suitable oil-in-water emulsifier.
  • Other ways to form oil-water emulsions include using a micro channel mixer or high shear equipment such as nozzles, etc.
  • surfactants or other agents may be needed to form a stable emulsion with the required structure and droplet size.
  • a pre-heater may be needed to heat the oil to certain temperature to facilitate the emulsion formation.
  • the temperature of heavy oil feed should be kept in the range of about 100° to 200° C to avoid thermal cracking but still high enough to maintain reasonable pressure drop.
  • the oil-in-water emulsion will have lower viscosity than feed oil (heavy oil), and its flow behavior will be more similar to water than feed oil. It is obvious that lower viscosity is advantageous to lower power consumption for pumps.
  • Other advantages of having water as the external, continuous phase will include reduced fouling of the pipes and reactor from the oil phase, and improved heat transfer to the reactor feed.
  • Oil-in-water emulsion is sent to heater to be heated up to temperature required for oil upgrading (higher than supercritical water conditions).
  • Oil-in- water emulsion provide very high interfacial area for water-oil contact, and this is of critical importance to achieve high upgrading performance because the abundance of water molecules surrounding the hydrocarbon molecules will significantly suppress condensation reactions and therefore reduce formation of coke and solid product.
  • Figure 2 shows another embodiment.
  • a second water stream is added to the process so that water to oil ratio for emulsion formation and for the upgrading process can be adjusted independently to optimize the performance.
  • the temperature of second water stream can also be adjusted to achieve optimized performance.
  • the viscosity of oil-in-water emulsion would be much lower than feed oil, which makes the mixing of those two streams much easier.
  • Figure 3 shows yet another embodiment.
  • Water-in-oil emulsion which also has the advantage of high water-oil interfacial area, was formed at the mixer. Then the emulsion will meet with and heated up by a water stream with temperature higher then critical point. Since the water has a lower boiling point than feed oil, water inside the oil shell will quickly evaporate to break up the oil shell and therefore achieve very good water-oil mixing.
  • reaction conditions After the reactants have been mixed to form an emulsion, they are passed into a reaction zone in which they are allowed to react under temperature and pressure conditions of supercritical water, i.e. supercritical water conditions, in the absence of externally added hydrogen, for a residence time sufficient to allow upgrading reactions to occur.
  • the reaction is preferably allowed to occur in the absence of externally added catalysts or promoters, although the use of such catalysts and promoters is permissible in accordance with the present invention.
  • Hydrogen as used herein in the phrase, "in the absence of externally added hydrogen” means hydrogen gas. This phrase is not intended to exclude all sources of hydrogen that are available as reactants. Other molecules such as saturated hydrocarbons may act as a hydrogen source during the reaction by donating hydrogen to other unsaturated hydrocarbons. In addition, H 2 may be formed in-situ during the reaction through steam reforming of hydrocarbons and water-gas-shift reaction.
  • the reaction zone preferably comprises a reactor, which is equipped with a means for collecting the reaction products (syncrude, water, and gases), and a bottom section where any metals or solids (the “dreg stream”) may accumulate.
  • Supercritical water conditions include a temperature from 374 0 C (the critical temperature of water) to 1000 0 C, preferably from 374 0 C to 60O 0 C and most preferably from 374°C to 400 0 C, a pressure from 3,205 (the critical pressure of water) to 10,000 psia, preferably from 3,205 psia to 7,200 psia and most preferably from 3,205 to 4,000 psia, an oil/water volume ratio from 1:0.1 to 1 :10, preferably from 1 : 0.5 to 1 :3 and most preferably about 1 :1 to 1 :2.
  • the reactants are allowed to react under these conditions for a sufficient time to allow upgrading reactions to occur.
  • the residence time will be selected to allow the upgrading reactions to occur selectively and to the fullest extent without having undesirable side reactions of coking or residue formation.
  • Reactor residence times may be from 1 minute to 6 hours, preferably from 8 minutes to 2 hours and most preferably from 10 to 40 minutes.
  • a single phase reaction product is withdrawn from the reaction zone, cooled, and separated into gas, effluent water, and upgraded hydrocarbon phases.
  • This separation is preferably done by cooling the stream and using one or more two-phase separators, three- phase separators, or other gas-oil-water separation device known in the art.
  • any method of separation can be used in accordance with the invention.
  • the emulsion has been broken as a result of the very high temperature reaction.
  • composition of gaseous product obtained by treatment of the heavy hydrocarbons in accordance with the process of the present invention will depend on feed properties and typically comprises light hydrocarbons, water vapor, acid gas (CO 2 and H 2 S), methane and hydrogen.
  • the effluent water may be used, reused or discarded. It may be recycled to e.g. the feed water tank, the feed water treatment system or to the reaction zone.
  • the upgraded hydrocarbon product which is sometimes referred to as "syncrude” herein may be upgraded further or processed into other hydrocarbon products using methods that are known in the hydrocarbon processing art.
  • the process of the present invention may be carried out as a continuous or semi-continuous process or a batch process.
  • the continuous process the entire system operates with a feed stream of oil and a separate feed stream of water and reaches a steady state; whereby all the flow rates, temperatures, pressures, and composition of the inlet, outlet, and recycle streams do not vary appreciably with time.
  • the major chemical/upgrading reactions are believed to be:
  • the exact pathway may depend on the reactor operating conditions (temperature, pressure, O/W volume ratio), reactor design (mode of contact/mixing, sequence of heating), and the hydrocarbon feedstock.
  • the experiment was performed using a continuous system.
  • the heated crude was mixed with water in the micromixer to form a water-oil emulsion, which was injected into a stream of supercritical water at temperature of 400° C.
  • the total water to oil ratio (volume at room temperature) was 3:1.
  • the oil-supercritical water mixture was then injected into a reactor at temperature of 400° C and pressure of 3400 psig.
  • the upgraded product which formed a homogeneous phase with supercritical water, was withdrawn from the top of the reactor and send to high pressure separator which was operated at the same pressure but lower temperature to achieve oil-water separation.
  • the dreg stream was removed from reactor bottom.
  • the diluted heavy crude oil properties were measured before reacting it with the supercritical water process as referred to in Example 1.
  • the properties of the crude were as follows: 12.8 API gravity at 60/60; 1329 CST viscosity @40°C; 13.04 wt% MCRT; 3.54 wt% sulfur; 0.56 wt% nitrogen; 3.05 mg KOH/gm acid number; 1.41 wt% water; 371 ppm Vanadium; and 86 ppm Nickel.
  • the diluted heavy crude oil after the super critical water treatment was converted into a syncrude with the following properties: 23.4 API gravity at 60/60; 9.8 CST viscosity @40°C; 1.9 wt% MCRT; 2.7 wt% sulfur; 2.41 mg KOH/gm acid number; 88% Vanadium reduction; and 93% Nickel reduction.
  • the liquid product (syncrude) from this reference run has the following properties: 22 API gravity at 60/60; 14.7 CST viscosity @40°C; 1.99 wt% MCRT; 2.74 wt% sulfur; 3.0 mg KOH/gm acid number; 86% Vanadium reduction; and 91% Nickel reduction. Overall the product quality is comparable with those obtained in Example 1. However, in order to achieve upgraded product with such quality, much longer residence time was needed. As a result, the liquid productivity for this was 9.2 Ib/ft3.h.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

La présente invention concerne un procédé utilisant une émulsion eau supercritique/huile pour valoriser une charge lourde hydrocarbonée en un produit hydrocarboné valorisé ou brut de synthèse ayant des propriétés fortement souhaitées (faible teneur en soufre, faible teneur en métaux, faible densité (degré API supérieur), faible viscosité, faible teneur en résidus, etc.). Le procédé ne nécessite ni alimentation externe en hydrogène ni utilisation de catalyseurs externes.
PCT/US2008/084208 2007-12-28 2008-11-20 Valorisation d'huiles lourdes hydrocarbonées WO2009085461A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US11/966,708 US20090166261A1 (en) 2007-12-28 2007-12-28 Upgrading heavy hydrocarbon oils
US11/966,708 2007-12-28

Publications (1)

Publication Number Publication Date
WO2009085461A1 true WO2009085461A1 (fr) 2009-07-09

Family

ID=40796817

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2008/084208 WO2009085461A1 (fr) 2007-12-28 2008-11-20 Valorisation d'huiles lourdes hydrocarbonées

Country Status (2)

Country Link
US (1) US20090166261A1 (fr)
WO (1) WO2009085461A1 (fr)

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2009073442A3 (fr) * 2007-11-28 2009-11-05 Saudi Arabian Oil Company Processus de réduction d'acidité de pétrole brut
WO2009085700A3 (fr) * 2007-12-20 2009-12-10 Chevron U.S.A. Inc. Procédé intégré pour la valorisation sur champ d'hydrocarbures
EP2961816A4 (fr) * 2013-02-28 2016-11-02 Aduro Energy Inc Système et procédé pour la commande et l'optimisation de la valorisation hydrothermique de pétrole brut lourd et de bitume
US9644455B2 (en) 2013-02-28 2017-05-09 Aduro Energy Inc. System and method for controlling and optimizing the hydrothermal upgrading of heavy crude oil and bitumen
US10900327B2 (en) 2013-02-28 2021-01-26 Aduro Energy, Inc. System and method for hydrothermal upgrading of fatty acid feedstock
US11414606B1 (en) 2018-11-08 2022-08-16 Aduro Energy, Inc. System and method for producing hydrothermal renewable diesel and saturated fatty acids

Families Citing this family (25)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20110003901A1 (en) * 2008-12-30 2011-01-06 Chevron U.S.A. Inc. Ft water treating and recovery
US8197670B2 (en) * 2010-02-23 2012-06-12 Chevron U.S.A. Inc. Process for upgrading hydrocarbons and device for use therein
US8444843B2 (en) 2010-04-15 2013-05-21 Saudi Arabian Oil Company Electrocatalytic dissociation of water for hydrodesulfurization of hydrocarbon feedstock
US9382485B2 (en) * 2010-09-14 2016-07-05 Saudi Arabian Oil Company Petroleum upgrading process
JP5943455B2 (ja) * 2011-08-19 2016-07-05 国立研究開発法人海洋研究開発機構 乳化物の製造方法
CN103320160B (zh) * 2012-03-22 2016-01-13 中国石油化工股份有限公司 一种含酸原油的加工方法
CN103789024B (zh) * 2012-11-03 2017-05-17 中国石油化工股份有限公司 一种高酸原油临氢水热裂解的方法
CN103788999B (zh) * 2012-11-03 2016-08-17 中国石油化工股份有限公司 一种高酸原油的预处理方法
US9024096B2 (en) * 2012-12-11 2015-05-05 Lummus Technology Inc. Conversion of triacylglycerides-containing oils
US9914885B2 (en) 2013-03-05 2018-03-13 Saudi Arabian Oil Company Process to upgrade and desulfurize crude oil by supercritical water
PL3097165T3 (pl) 2014-01-20 2022-11-07 Applied Research Associates, Inc. Wysokowydajny sposób obniżania temperatury płynięcia
SG11201607310WA (en) * 2014-03-05 2016-10-28 Chugoku Electric Power Gasification system
US9505678B2 (en) 2014-05-12 2016-11-29 Saudi Arabian Oil Company Process to produce aromatics from crude oil
SI3250660T1 (sl) * 2015-01-28 2023-12-29 Applied Research Associates, Inc., Postopek hidrotermalnega čiščenja
CA2941568A1 (fr) 2015-08-31 2017-02-28 University Of New Brunswick Procede de valorisation de liquides d'hydrocarbure lourd
US9926497B2 (en) 2015-10-16 2018-03-27 Saudi Arabian Oil Company Method to remove metals from petroleum
US10066172B2 (en) * 2015-12-15 2018-09-04 Saudi Arabian Oil Company Supercritical water upgrading process to produce paraffinic stream from heavy oil
KR102403974B1 (ko) * 2016-07-08 2022-05-30 어플라이드 리서치 어소시에이츠 인코포레이티드 초임계 수 분리 방법
US10106748B2 (en) 2017-01-03 2018-10-23 Saudi Arabian Oil Company Method to remove sulfur and metals from petroleum
US10703999B2 (en) 2017-03-14 2020-07-07 Saudi Arabian Oil Company Integrated supercritical water and steam cracking process
US10526552B1 (en) 2018-10-12 2020-01-07 Saudi Arabian Oil Company Upgrading of heavy oil for steam cracking process
US11162035B2 (en) 2020-01-28 2021-11-02 Saudi Arabian Oil Company Catalytic upgrading of heavy oil with supercritical water
US11286429B2 (en) 2020-06-25 2022-03-29 Saudi Arabian Oil Company Process for heavy oil upgrading utilizing hydrogen and water
US11781075B2 (en) 2020-08-11 2023-10-10 Applied Research Associates, Inc. Hydrothermal purification process
CN115577628B (zh) * 2022-10-11 2025-04-25 西南石油大学 一种基于神经网络的油水乳状液黏度预测方法

Citations (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5316659A (en) * 1993-04-02 1994-05-31 Exxon Research & Engineering Co. Upgrading of bitumen asphaltenes by hot water treatment

Family Cites Families (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
ZA753184B (en) * 1974-05-31 1976-04-28 Standard Oil Co Process for recovering upgraded hydrocarbon products
US3989618A (en) * 1974-05-31 1976-11-02 Standard Oil Company (Indiana) Process for upgrading a hydrocarbon fraction
US3948755A (en) * 1974-05-31 1976-04-06 Standard Oil Company Process for recovering and upgrading hydrocarbons from oil shale and tar sands
US4005005A (en) * 1974-05-31 1977-01-25 Standard Oil Company (Indiana) Process for recovering and upgrading hydrocarbons from tar sands
US3948754A (en) * 1974-05-31 1976-04-06 Standard Oil Company Process for recovering and upgrading hydrocarbons from oil shale and tar sands
US3960706A (en) * 1974-05-31 1976-06-01 Standard Oil Company Process for upgrading a hydrocarbon fraction
US3983027A (en) * 1974-07-01 1976-09-28 Standard Oil Company (Indiana) Process for recovering upgraded products from coal
US3988238A (en) * 1974-07-01 1976-10-26 Standard Oil Company (Indiana) Process for recovering upgraded products from coal
IT1107051B (it) * 1983-02-28 1985-11-18 Car Bench Spa Banco per la riparazione di scoddhe di autoveicoli provvisto di supporti unificati per dime dotati di tre gradi di liberta' di movimento
US4557820A (en) * 1984-05-24 1985-12-10 The Standard Oil Company Conversion of high boiling organic materials to low boiling materials
US4594141A (en) * 1984-12-18 1986-06-10 The Standard Oil Company Conversion of high boiling organic materials to low boiling materials
US4840725A (en) * 1987-06-19 1989-06-20 The Standard Oil Company Conversion of high boiling liquid organic materials to lower boiling materials
US5096567A (en) * 1989-10-16 1992-03-17 The Standard Oil Company Heavy oil upgrading under dense fluid phase conditions utilizing emulsified feed stocks
CA2143404C (fr) * 1994-03-09 1999-05-04 Michael Siskin Methode pour eliminer les heteroatomes en milieu reducteur, dans de l'eau sous des conditions supercritiques
FR2727634A1 (fr) * 1994-12-06 1996-06-07 Electrolyse L Procede en milieu reducteur de transformation chimique de structures chimiques complexes dans un fluide supercritique
WO2003025098A2 (fr) * 2001-09-17 2003-03-27 Southwest Research Institute Processus de pretraitement pour huile lourde et materiaux charbonneux
CA2526965C (fr) * 2003-05-16 2011-10-11 Velocys Inc. Procede pour former une emulsion par la technique de traitement en microcanal

Patent Citations (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5316659A (en) * 1993-04-02 1994-05-31 Exxon Research & Engineering Co. Upgrading of bitumen asphaltenes by hot water treatment

Cited By (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2009073442A3 (fr) * 2007-11-28 2009-11-05 Saudi Arabian Oil Company Processus de réduction d'acidité de pétrole brut
US9295957B2 (en) 2007-11-28 2016-03-29 Saudi Arabian Oil Company Process to reduce acidity of crude oil
US9656230B2 (en) 2007-11-28 2017-05-23 Saudi Arabian Oil Company Process for upgrading heavy and highly waxy crude oil without supply of hydrogen
US10010839B2 (en) 2007-11-28 2018-07-03 Saudi Arabian Oil Company Process to upgrade highly waxy crude oil by hot pressurized water
WO2009085700A3 (fr) * 2007-12-20 2009-12-10 Chevron U.S.A. Inc. Procédé intégré pour la valorisation sur champ d'hydrocarbures
EP2961816A4 (fr) * 2013-02-28 2016-11-02 Aduro Energy Inc Système et procédé pour la commande et l'optimisation de la valorisation hydrothermique de pétrole brut lourd et de bitume
US9644455B2 (en) 2013-02-28 2017-05-09 Aduro Energy Inc. System and method for controlling and optimizing the hydrothermal upgrading of heavy crude oil and bitumen
US9783742B2 (en) 2013-02-28 2017-10-10 Aduro Energy, Inc. System and method for controlling and optimizing the hydrothermal upgrading of heavy crude oil and bitumen
US10323492B2 (en) 2013-02-28 2019-06-18 Aduro Energy, Inc. System and method for controlling and optimizing the hydrothermal upgrading of heavy crude oil and bitumen
US10900327B2 (en) 2013-02-28 2021-01-26 Aduro Energy, Inc. System and method for hydrothermal upgrading of fatty acid feedstock
US11414606B1 (en) 2018-11-08 2022-08-16 Aduro Energy, Inc. System and method for producing hydrothermal renewable diesel and saturated fatty acids

Also Published As

Publication number Publication date
US20090166261A1 (en) 2009-07-02

Similar Documents

Publication Publication Date Title
US20090166261A1 (en) Upgrading heavy hydrocarbon oils
US20080099377A1 (en) Process for upgrading heavy hydrocarbon oils
US7740065B2 (en) Process to upgrade whole crude oil by hot pressurized water and recovery fluid
JP6080758B2 (ja) 石油流からの硫黄化合物の除去
US20080099374A1 (en) Reactor and process for upgrading heavy hydrocarbon oils
US20080099376A1 (en) Upgrading heavy hydrocarbon oils
US20080099378A1 (en) Process and reactor for upgrading heavy hydrocarbon oils
KR102150269B1 (ko) 중유로부터 파라핀 스트림을 생산하기 위한 초임계수 경질화 공정
US20090166262A1 (en) Simultaneous metal, sulfur and nitrogen removal using supercritical water
US9145523B2 (en) Upgrading of hydrocarbons by hydrothermal process
WO2009085700A2 (fr) Procédé intégré pour la valorisation sur champ d'hydrocarbures
CA2790617C (fr) Procede pour la valorisation d'hydrocarbures et dispositif destine a etre utilise dans celui-ci
US20210122985A1 (en) Upgrading and extraction of heavy oil by supercritical water

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 08868095

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 08868095

Country of ref document: EP

Kind code of ref document: A1

点击 这是indexloc提供的php浏览器服务，不要输入任何密码和下载