WO2008055162A2 - Procédé pour valoriser des hydrocarbures liquides lourds - Google Patents

Procédé pour valoriser des hydrocarbures liquides lourds Download PDF

Info

Publication number
WO2008055162A2
WO2008055162A2 PCT/US2007/083014 US2007083014W WO2008055162A2 WO 2008055162 A2 WO2008055162 A2 WO 2008055162A2 US 2007083014 W US2007083014 W US 2007083014W WO 2008055162 A2 WO2008055162 A2 WO 2008055162A2
Authority
WO
WIPO (PCT)
Prior art keywords
water
temperature
process according
oil
psia
Prior art date
Application number
PCT/US2007/083014
Other languages
English (en)
Other versions
WO2008055162A3 (fr
Inventor
Zunqing He
Lin Li
Lixiong Li
Daniel Chinn
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.
Priority to CA002666673A priority Critical patent/CA2666673A1/fr
Priority to EA200970438A priority patent/EA200970438A1/ru
Publication of WO2008055162A2 publication Critical patent/WO2008055162A2/fr
Publication of WO2008055162A3 publication Critical patent/WO2008055162A3/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
    • 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
    • C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
    • C10G1/04—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
    • C10G1/047—Hot water or cold water extraction processes

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.
  • TAN total acid number
  • 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. These hydrogen-addition processes also generally require expensive catalysts and resource intensive catalyst handling techniques, including catalyst regeneration.
  • 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. Further, the 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. 5,914,031 discloses a three zone reactor design so that the reactant activity, reactant solubility and phase separation of products can be optimized separately by controlling temperature and pressure. However, all the examples given in the patent were obtained using batch operation.
  • 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 is based on experimental findings that the heating sequence of the reactants, oil and water, is of fundamental importance to achieve enhanced upgrading performance meaning that byproducts such as solid residue and light hydrocarbon gases are reduced or eliminated. Reducing solid formation not only improves the liquid oil yield but also allows the process to operate more efficiently. It is well understood that solids in the system will pose significant challenges for reactor and process design. Direct heating of oil feed may lead to over heating which in turn leads to more solid residue formation, lower desired product yield and lower product quality.
  • the present invention relates to a process for upgrading hydrocarbons, preferably heavy hydrocarbons comprising: mixing the hydrocarbons with a fluid comprising water that has been heated to a temperature higher than its critical temperature in a mixing zone to form a mixture; passing the mixture to a reaction zone; reacting the mixture in the 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 another embodiment of the present invention.
  • Fig. 3 is a graph showing the required Tscw as a function of water-to-oil ratio.
  • Fig. 4 is a process flow diagram of another embodiment of the present invention.
  • 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. Mixing
  • the heavy hydrocarbon feed and a fluid comprising water that has been heated to a temperature higher than its critical temperature are contacted in a mixing zone prior to entering the reaction zone.
  • mixing may be accomplished in many ways and is preferably accomplished by a technique that does not employ mechanical moving parts. Such means of mixing may include, but are not limited to, use of static mixers, spray nozzles, sonic or ultrasonic agitation.
  • the oil and water should be heated and mixed so that the combined stream will reach supercritical water conditions in the reaction zone.
  • One key aspect of this invention is to design the heating sequence so that the temperature and pressure of the hydrocarbons and water will reach reaction conditions in a controlled manner. This will avoid excessive local heating of oil, which will lead to solid formation and lower quality product.
  • the oil should only be heated up with sufficient water present and around the hydrocarbon molecules. This requirement can be met by mixing oil with water before heating up.
  • FIG. 2 is a process flow diagram of one embodiment of the present invention.
  • water is heated to a temperature higher than critical conditions, and then mixed with oil.
  • the temperature of heavy oil feed should be kept in the range of about 100 0 C to 200°C to avoid thermal cracking but still high enough to maintain a reasonable pressure drop.
  • the water stream temperature should be high enough to make sure that after mixing with oil, the temperature of the oil-water mixture is still higher than the water supercritical temperature.
  • the oil is actually heated by water. An abundance of water molecules surrounding the hydrocarbon molecules will significantly suppress condensation reactions and therefore reduce formation of coke and solid product.
  • the required temperature of the supercritical water stream, T S ⁇ w can be estimated based on reaction temperature, TR, and water to oil ratio.
  • FIG 4 shows another embodiment of a process according to the invention.
  • Water is heated up to supercritical conditions by Heater 1 , then the supercritical water mixed with heavy oil feed in the mixer.
  • the temperature of heavy oil feed should be kept in the range of about 100 0 C to 200 0 C to avoid thermal cracking but still high enough to maintain reasonable pressure drop.
  • the temperature of the water-oil mixture would be lower than critical temperature of water; therefore Heater 2 is needed to raise the temperature of the mixture stream to above the critical temperature of water.
  • the heavy oil is first partially heated up by water, then the water-oil mixture is heated to supercritical conditions by the second heater (Heater 2).
  • reaction conditions After the reactants have been mixed, 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 section, preferably at the bottom, 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 600 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 20 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.
  • 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 ⁇ 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 either as a continuous or semi-continuous process or a batch process or as a continuous process.
  • the entire system operates with a feed stream of oil and a separate feed stream of supercritical 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.
  • a number of upgrading reactions are occurring simultaneously at the supercritical water conditions used in the present process.
  • the major chemical/upgrading reactions are believed to be:
  • the exact pathway may depend on the reactor operating conditions (temperature, pressure, 0/W volume ratio), reactor design (mode of contact/mixing, sequence of heating), and the hydrocarbon feedstock.
  • Figure 1 shows a process flow diagram for a laboratory unit for practicing some embodiments of the invention.
  • Oil and supercritical water are contacted in a mixer prior to entering the reactor.
  • the reactor is equipped with an inner tube for collecting the products (syncrude, excess water, and gas), and a bottom section where any metals or solids comprising a "dreg stream" of indeterminate properties or composition may accumulate.
  • the shell-side of the reactor is kept isothermal during the reaction with a clamshell furnace and temperature controller.
  • Preferred reactor residence times are 20-40 minutes, with preferred oil/water volume ratios on the order of 1 :3.
  • Preferred temperatures are around 374°- 400 0 C, with the pressure at 3,200-4,000 psig.
  • the reactor product stream leaves as a single phase, and is cooled and separated into gas, syncrude, and effluent water.
  • the effluent water is recycled back to the reactor. Sulfur from the original feedstock accumulates in the dreg stream for the most part, with lesser amounts primarily in the form of H2S found in the gas phase and water phase.
  • Elimination of the dreg stream means that a greater degree of hydrocarbon is recovered as syncrude, but it also means that metals and sulfur will accumulate elsewhere, such as in the water and gas streams.
  • a Hamaca crude oil was diluted with a diluent hydrocarbon at a ratio of 5:1 (20 vol% of diluent).
  • the diluted Hamaca crude oil properties were measured before reacting it with the supercritical water process as referred to in Example 1 and Fig. 2.
  • the properties of the crude were as follows: 12.8 API gravity at 60/60; 1329 CST viscosity @40°C; 7.66 wt% C/H ratio; 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 Hamaca crude oil after the super critical water treatment was converted into a syncrude with the following properties: 24.1 API gravity at 60/60; 5.75 CST viscosity @40°C; 7.40 wt% C/H ratio; 2.25 wt% MCRT; 2.83 wt% sulfur; 0.28 wt% nitrogen; 1.54 mg KOH/gm acid number; 0.96 wt% water; 24 ppm Vanadium; and 3 ppm Nickel.
  • Substantial reductions in metals and residues were observed, with simultaneous increase in the API gravity and a significant decrease in the viscosity of the original crude oil feedstock. There were modest reductions in the Total Acid number, sulfur concentration, and nitrogen concentration which could be improved with further optimization of the reaction conditions.
  • the product syncrude had the following properties: 14.0 API gravity at 60/60; 188 CST viscosity @40°C; 8.7 wt% MCRT; 3.11 wt% sulfur; 267 ppm Vanadium; and 59 ppm Nickel. This comparison demonstrates the importance of the heating sequence of the present invention.
  • the starting feedstock of diluted Hamaca crude at 30 grams produced a syncrude product of 22.73 grams.
  • the dreg stream that was formed accounted for 5.5 grams.
  • the overall recovery with the dreg stream was 96.7 percent.
  • sulfur accounted for 31% of the total sulfur with the remaining sulfur in the oil product, water phase, and gas phase.
  • the metals content of the dreg stream accounted for 82% of the total metals with the remaining metals in the oil product.
  • Undiluted Boscan crude oil properties were measured before reacting it with the supercritical water process of the present invention.
  • the properties of the crude were as follows: 9 API gravity at 60/60; 1 ,140 CST viscosity @40°C; 8.0 wt% C/H ratio; 16 wt% MCRT; 5.8 wt% Sulfur; and 1 ,280 ppm Vanadium;.
  • the undiluted Boscan crude oil after the super critical water treatment was converted into a syncrude with the following properties: 22 API gravity at 60/60; 9 CST viscosity @40°C; 7.6 wt% C/H ratio; 2.5 wt% MCRT; 4.6% sulfur; and 130 ppm Vanadium.
  • a simulated distillation analysis of the original crude oil vs. the syncrude products from different experimental runs shows that the syncrude prepared in accordance with the present invention clearly has superior properties than the original crude.
  • the syncrudes contain a higher fraction of lower-boiling fractions. 51% of the diluted Hamaca crude boils across a range of temperatures of less than 1000 0 F 1 while employing a process according to the present invention using supercritical water depending on process configurations, between 79 to 94% of the syncrude boils across a range of temperatures of less than 1000 0 F.

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)
  • Life Sciences & Earth Sciences (AREA)
  • Wood Science & Technology (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

L'invention concerne un procédé qui utilise de l'eau supercritique pour valoriser une charge d'hydrocarbures lourds de façon à obtenir un produit hydrocarboné valorisé ou un pétrole brut de synthèse présentant des propriétés hautement recherchées (faible teneur en soufre, faible teneur en métaux, densité réduite (densité API accrue), viscosité réduite, teneur réduite en résidus, etc.). Ce procédé ne nécessite pas d'alimentation externe en hydrogène ni d'alimentation externe en catalyseurs. L'invention concerne également des procédés améliorés de mélange des réactifs.
PCT/US2007/083014 2006-10-31 2007-10-30 Procédé pour valoriser des hydrocarbures liquides lourds WO2008055162A2 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
CA002666673A CA2666673A1 (fr) 2006-10-31 2007-10-30 Procede pour valoriser des hydrocarbures liquides lourds
EA200970438A EA200970438A1 (ru) 2006-10-31 2007-10-30 Способ повышения качества тяжелых углеводородных нефтей

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US11/555,130 US20080099377A1 (en) 2006-10-31 2006-10-31 Process for upgrading heavy hydrocarbon oils
US11/555,130 2006-10-31

Publications (2)

Publication Number Publication Date
WO2008055162A2 true WO2008055162A2 (fr) 2008-05-08
WO2008055162A3 WO2008055162A3 (fr) 2008-07-10

Family

ID=39328837

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2007/083014 WO2008055162A2 (fr) 2006-10-31 2007-10-30 Procédé pour valoriser des hydrocarbures liquides lourds

Country Status (5)

Country Link
US (1) US20080099377A1 (fr)
CN (1) CN101553553A (fr)
CA (1) CA2666673A1 (fr)
EA (1) EA200970438A1 (fr)
WO (1) WO2008055162A2 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2009085700A2 (fr) * 2007-12-20 2009-07-09 Chevron U.S.A. Inc. Procédé intégré pour la valorisation sur champ d'hydrocarbures

Families Citing this family (39)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7947165B2 (en) * 2005-09-14 2011-05-24 Yeda Research And Development Co.Ltd Method for extracting and upgrading of heavy and semi-heavy oils and bitumens
US7943036B2 (en) 2009-07-21 2011-05-17 Chevron U.S.A. Inc. Systems and methods for producing a crude product
US7842181B2 (en) * 2006-12-06 2010-11-30 Saudi Arabian Oil Company Composition and process for the removal of sulfur from middle distillate fuels
BRPI0819687A2 (pt) 2007-11-28 2018-09-11 Aramco Services Co processo para beneficiamento de óleo bruto altamente ceroso e pesado sem fornecimento de hidrogênio
US8142646B2 (en) 2007-11-30 2012-03-27 Saudi Arabian Oil Company Process to produce low sulfur catalytically cracked gasoline without saturation of olefinic compounds
US20090145808A1 (en) * 2007-11-30 2009-06-11 Saudi Arabian Oil Company Catalyst to attain low sulfur diesel
WO2009105749A2 (fr) * 2008-02-21 2009-08-27 Saudi Arabian Oil Company Catalyseur pour parvenir à une essence à faible teneur en soufre
US8236169B2 (en) * 2009-07-21 2012-08-07 Chevron U.S.A. Inc Systems and methods for producing a crude product
US7931797B2 (en) 2009-07-21 2011-04-26 Chevron U.S.A. Inc. Systems and methods for producing a crude product
CN101942338B (zh) * 2009-07-09 2013-11-20 中国石油化工股份有限公司 重油改质的组合工艺方法
US8759242B2 (en) 2009-07-21 2014-06-24 Chevron U.S.A. Inc. Hydroprocessing catalysts and methods for making thereof
US9068132B2 (en) 2009-07-21 2015-06-30 Chevron U.S.A. Inc. Hydroprocessing catalysts and methods for making thereof
US8927448B2 (en) 2009-07-21 2015-01-06 Chevron U.S.A. Inc. Hydroprocessing catalysts and methods for making thereof
CN102041018B (zh) * 2009-10-16 2014-03-05 中国石油化工股份有限公司 一种煤和油共炼的处理方法
CN102041053B (zh) * 2009-10-21 2013-07-24 中国石油化工股份有限公司 一种煤焦油的处理方法
US8394260B2 (en) * 2009-12-21 2013-03-12 Saudi Arabian Oil Company Petroleum upgrading process
US9005432B2 (en) 2010-06-29 2015-04-14 Saudi Arabian Oil Company Removal of sulfur compounds from petroleum stream
CN102311797A (zh) * 2010-07-07 2012-01-11 中国石油化工股份有限公司 一种重油改质的组合工艺方法
US9039889B2 (en) 2010-09-14 2015-05-26 Saudi Arabian Oil Company Upgrading of hydrocarbons by hydrothermal process
US9382485B2 (en) 2010-09-14 2016-07-05 Saudi Arabian Oil Company Petroleum upgrading process
JP6097224B2 (ja) 2010-12-30 2017-03-15 シェブロン ユー．エス．エー． インコーポレイテッド 水素化処理触媒を作製するための方法
US8535518B2 (en) 2011-01-19 2013-09-17 Saudi Arabian Oil Company Petroleum upgrading and desulfurizing process
WO2013052603A2 (fr) * 2011-10-04 2013-04-11 Chevron U.S.A. Inc. Système et procédé permettant de produire du pétrole brut synthétique à partir de fluides produits en mer et contenant un fort pourcentage de co2
US9162208B2 (en) 2011-10-04 2015-10-20 Chevron U.S.A. Inc. Process and system for producing synthetic crude oil from offshore produced fluids containing high CO2 content
US9321037B2 (en) 2012-12-14 2016-04-26 Chevron U.S.A., Inc. Hydroprocessing co-catalyst compositions and methods of introduction thereof into hydroprocessing units
US9687823B2 (en) 2012-12-14 2017-06-27 Chevron U.S.A. Inc. Hydroprocessing co-catalyst compositions and methods of introduction thereof into hydroprocessing units
US9914885B2 (en) * 2013-03-05 2018-03-13 Saudi Arabian Oil Company Process to upgrade and desulfurize crude oil by supercritical water
US10144874B2 (en) 2013-03-15 2018-12-04 Terrapower, Llc Method and system for performing thermochemical conversion of a carbonaceous feedstock to a reaction product
US9567530B2 (en) * 2014-11-26 2017-02-14 Saudi Arabian Oil Company Process for heavy oil upgrading in a double-wall reactor
CA2941568A1 (fr) 2015-08-31 2017-02-28 University Of New Brunswick Procede de valorisation de liquides d'hydrocarbure lourd
CN105952424B (zh) * 2016-05-31 2018-08-14 西安交通大学 一种超临界水驱油模拟装置及方法
CN106350101B (zh) * 2016-09-19 2018-01-23 华东理工大学 基于亚/超临界水中重芳烃自组装效应的重质油预处理的方法及应用
US10752847B2 (en) 2017-03-08 2020-08-25 Saudi Arabian Oil Company Integrated hydrothermal process to upgrade heavy oil
US10703999B2 (en) 2017-03-14 2020-07-07 Saudi Arabian Oil Company Integrated supercritical water and steam cracking process
CN110461810B (zh) 2017-03-24 2022-05-13 泰拉能源公司 用于通过转化成甲酸来再循环热解尾气的方法和系统
CN106987265B (zh) * 2017-04-10 2019-06-21 华东理工大学 基于超临界水的重质油减黏的处理方法
US10787610B2 (en) 2017-04-11 2020-09-29 Terrapower, Llc Flexible pyrolysis system and method
US11021659B2 (en) 2018-02-26 2021-06-01 Saudi Arabia Oil Company Additives for supercritical water process to upgrade heavy oil
US10526552B1 (en) 2018-10-12 2020-01-07 Saudi Arabian Oil Company Upgrading of heavy oil for steam cracking process

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4818370A (en) * 1986-07-23 1989-04-04 Cities Service Oil And Gas Corporation Process for converting heavy crudes, tars, and bitumens to lighter products in the presence of brine at supercritical conditions
US4840725A (en) * 1987-06-19 1989-06-20 The Standard Oil Company Conversion of high boiling liquid organic materials to lower boiling materials
US6887369B2 (en) * 2001-09-17 2005-05-03 Southwest Research Institute Pretreatment processes for heavy oil and carbonaceous materials
US20050167333A1 (en) * 2004-01-30 2005-08-04 Mccall Thomas F. Supercritical Hydrocarbon Conversion Process

Family Cites Families (21)

* 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
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
US3989618A (en) * 1974-05-31 1976-11-02 Standard Oil Company (Indiana) Process for upgrading a hydrocarbon fraction
US3960706A (en) * 1974-05-31 1976-06-01 Standard Oil Company Process for upgrading a hydrocarbon fraction
US3988238A (en) * 1974-07-01 1976-10-26 Standard Oil Company (Indiana) Process for recovering upgraded products from coal
US3983027A (en) * 1974-07-01 1976-09-28 Standard Oil Company (Indiana) Process for recovering upgraded products from coal
US3948754A (en) * 1974-05-31 1976-04-06 Standard Oil Company Process for recovering and upgrading hydrocarbons from oil shale and tar sands
US4559127A (en) * 1984-05-24 1985-12-17 The Standard Oil Company Conversion of high boiling organic materials to low boiling materials
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
US4994149A (en) * 1986-03-06 1991-02-19 Delta Projects Inc. Diluent substitution apparatus
US5252224A (en) * 1991-06-28 1993-10-12 Modell Development Corporation Supercritical water oxidation process of organics with inorganics
US5384051A (en) * 1993-02-05 1995-01-24 Mcginness; Thomas G. Supercritical oxidation reactor
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
US5560823A (en) * 1994-12-21 1996-10-01 Abitibi-Price, Inc. Reversible flow supercritical reactor and method for operating same
US5567698A (en) * 1995-02-15 1996-10-22 Bristol-Myers Squibb Company Pyridinium thiomethyl substituted chepholosporin derivatives
JP3366820B2 (ja) * 1997-02-19 2003-01-14 株式会社日立製作所 酸化処理方法とその装置及び反応容器
US20040035749A1 (en) * 2001-10-24 2004-02-26 Khan Motasimur Rashid Flow properties of heavy crude petroleum
JP3724438B2 (ja) * 2002-03-08 2005-12-07 株式会社日立製作所 超臨界水による重質油の処理方法と処理装置及び重質油処理装置を備えた発電システム

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4818370A (en) * 1986-07-23 1989-04-04 Cities Service Oil And Gas Corporation Process for converting heavy crudes, tars, and bitumens to lighter products in the presence of brine at supercritical conditions
US4840725A (en) * 1987-06-19 1989-06-20 The Standard Oil Company Conversion of high boiling liquid organic materials to lower boiling materials
US6887369B2 (en) * 2001-09-17 2005-05-03 Southwest Research Institute Pretreatment processes for heavy oil and carbonaceous materials
US20050167333A1 (en) * 2004-01-30 2005-08-04 Mccall Thomas F. Supercritical Hydrocarbon Conversion Process

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2009085700A2 (fr) * 2007-12-20 2009-07-09 Chevron U.S.A. Inc. Procédé intégré pour la valorisation sur champ d'hydrocarbures
WO2009085700A3 (fr) * 2007-12-20 2009-12-10 Chevron U.S.A. Inc. Procédé intégré pour la valorisation sur champ d'hydrocarbures

Also Published As

Publication number Publication date
WO2008055162A3 (fr) 2008-07-10
CN101553553A (zh) 2009-10-07
CA2666673A1 (fr) 2008-05-08
US20080099377A1 (en) 2008-05-01
EA200970438A1 (ru) 2009-10-30

Similar Documents

Publication Publication Date Title
US20080099377A1 (en) Process for upgrading heavy hydrocarbon oils
US20080099376A1 (en) Upgrading heavy hydrocarbon oils
US20080099374A1 (en) Reactor and process for upgrading heavy hydrocarbon oils
US20080099378A1 (en) Process and reactor for upgrading heavy hydrocarbon oils
US20090166262A1 (en) Simultaneous metal, sulfur and nitrogen removal using supercritical water
US20090166261A1 (en) Upgrading heavy hydrocarbon oils
JP6080758B2 (ja) 石油流からの硫黄化合物の除去
US20090159498A1 (en) Intergrated process for in-field upgrading of hydrocarbons
US9951283B2 (en) Petroleum upgrading and desulfurizing process
JP5269089B2 (ja) 熱加圧水によって高ワックス質原油をアップグレードする方法
US5322617A (en) Upgrading oil emulsions with carbon monoxide or synthesis gas
CA2790617C (fr) Procede pour la valorisation d'hydrocarbures et dispositif destine a etre utilise dans celui-ci
US11286434B2 (en) Conversion process using supercritical water
JP2021514022A (ja) 重質油をアップグレードする超臨界水プロセスのための添加剤

Legal Events

Date Code Title Description
WWE Wipo information: entry into national phase

Ref document number: 200780040312.3

Country of ref document: CN

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

Ref document number: 07863664

Country of ref document: EP

Kind code of ref document: A2

ENP Entry into the national phase

Ref document number: 2666673

Country of ref document: CA

NENP Non-entry into the national phase

Ref country code: DE

WWE Wipo information: entry into national phase

Ref document number: 200970438

Country of ref document: EA

122 Ep: pct application non-entry in european phase

Ref document number: 07863664

Country of ref document: EP

Kind code of ref document: A2