WO2012040358A1 - Valorisation d'hydrocarbures in situ avec un fluide généré pour fournir de la vapeur et de l'hydrogène - Google Patents

Valorisation d'hydrocarbures in situ avec un fluide généré pour fournir de la vapeur et de l'hydrogène Download PDF

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Publication number
WO2012040358A1
WO2012040358A1 PCT/US2011/052601 US2011052601W WO2012040358A1 WO 2012040358 A1 WO2012040358 A1 WO 2012040358A1 US 2011052601 W US2011052601 W US 2011052601W WO 2012040358 A1 WO2012040358 A1 WO 2012040358A1
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WO
WIPO (PCT)
Prior art keywords
hydrocarbons
hydrogen
steam
formation
injection stream
Prior art date
Application number
PCT/US2011/052601
Other languages
English (en)
Inventor
Scott Macadam
James P. Seaba
Wayne Reid Dreher, Jr.
Joe D. Allison
Original Assignee
Conocophillips Company
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 Conocophillips Company filed Critical Conocophillips Company
Priority to CA2812589A priority Critical patent/CA2812589A1/fr
Publication of WO2012040358A1 publication Critical patent/WO2012040358A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/30—Specific pattern of wells, e.g. optimising the spacing of wells
    • E21B43/305—Specific pattern of wells, e.g. optimising the spacing of wells comprising at least one inclined or horizontal well
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
    • E21B43/2406—Steam assisted gravity drainage [SAGD]

Definitions

  • Embodiments of the invention relate to methods and systems for delivering hydrogen and steam to a subsurface reservoir for upgrading of hydrocarbons in situ.
  • SAGD steam assisted gravity drainage
  • Viscosity reduction obtained during production by heating the oil with the steam is based on temperature of the oil and therefore temporary. Subsequent transport of the oil through a pipeline, for example, thus relies on diluting the oil with less viscous hydrocarbons.
  • blending the oil creates problems due to added costs, potential to cause fouling and optimization issues at refineries utilizing such blends as feedstock.
  • In situ upgrading of the oil offers permanent viscosity reduction to facilitate transportation thereof and improves refinery demand for the oil.
  • Extent of the in situ upgrading in past approaches depends on various factors including presence of a hydrogen donor within the formation for reacting with the oil to yield products that are upgraded.
  • cost of generating hydrogen at a surface facility, difficulty in transporting hydrogen or expense of compounds that function as the hydrogen donor make prior techniques to supply the hydrogen donor where wanted in the formation undesirable.
  • a method of in situ upgrading hydrocarbons includes generating a hydrogen and steam containing injection stream by vaporization of water contacted with flow from combustion of a gaseous hydrocarbon fuel with an oxidant and at an oxygen:fuel equivalence ratio less than 1. The method further includes introducing the injection stream into a formation to contact, heat and hydroprocess hydrocarbons in the formation. In addition, the method includes recovering to surface the hydrocarbons that have been upgraded.
  • a system for in situ upgrading hydrocarbons includes a hydrogen and steam generator having an output of an injection stream produced by vaporization of water contacted with flow from combustion of a gaseous hydrocarbon fuel with an oxidant and at an oxygen: fuel equivalence ratio less than 1.
  • An injector conveys the injection stream into a formation to contact, heat and hydroprocess hydrocarbons in the formation.
  • a recovery assembly produces to surface the hydrocarbons that are upgraded.
  • a method of in situ upgrading hydrocarbons includes injecting hydrogen and steam into a first wellbore of a steam assisted gravity drainage well pair. Operation of a direct steam generator under fuel-rich conditions generates the steam and hydrogen. The method also includes recovering upgraded hydrocarbons to surface through a second wellbore of the steam assisted gravity drainage well pair.
  • Figure 1 is a schematic of a production system in which cogeneration of steam and hydrogen enables steam assisted recovery of in situ upgraded hydrocarbons, according to one embodiment of the invention.
  • Figure 2 is a schematic of a production system illustrating cogeneration of steam and hydrogen combined with a wellbore heater and optional catalyst for use in steam assisted recovery of in situ upgraded hydrocarbons, according to one embodiment of the invention.
  • Figure 3 is a graph of modeled results for hydrogen and carbon monoxide levels in product gas from a direct steam generator versus oxygen to fuel equivalence ratio for combustion in the direct steam generator, according to one embodiment of the invention.
  • Embodiments of the invention relate to recovery of in situ upgraded hydrocarbons by injecting steam and hydrogen into a reservoir containing the hydrocarbons.
  • a mixture output generated as water is vaporized by direct contact with flow from fuel-rich combustion provides the steam and hydrogen.
  • the steam heats the hydrocarbons facilitating flow of the hydrocarbons and reaction of the hydrogen with the hydrocarbons to enable hydroprocessing prior to recovery of the hydrocarbons to surface.
  • Figure 1 illustrates a production system with a fuel-rich direct steam generator
  • the fluid stream includes steam and hydrogen (H 2 ) produced by the generator 100.
  • H 2 hydrogen
  • heat transfer from the steam makes petroleum products mobile enough to enable or facilitate both upgrading by reaction of the petroleum products with the hydrogen and recovery of the petroleum products with, for example, a production well 102.
  • the injection and production wells 101, 102 traverse through an earth formation 103 containing the petroleum products, such as heavy oil or bitumen, heated by the fluid stream.
  • the injection well 101 includes a horizontal borehole portion that is disposed above (e.g., 0 to 6 meters above) and parallel to a horizontal borehole portion of the production well 102. While shown in an exemplary steam assisted gravity drainage (SAGD) well pair orientation, some embodiments utilize other configurations of the injection well 101 and the production well 102, which may be combined with the injection well 101 or arranged crosswise relative to the injection well 101, for example. Further, upgrading processes described herein may rely on other production techniques, such as use of the fluid stream from the generator 100 as a drive fluid or cyclic injecting and producing during alternating periods of time.
  • SAGD steam assisted gravity drainage
  • the generator 100 includes a fuel input 104, an oxidant input 106 and a water input 108 that are coupled to respective sources of fuel, oxidant and water and are all in fluid communication with a flow path through the generator 100.
  • the generator 100 differs from indirect- fired boilers since transfer of heat produced from combustion occurs by direct contact of the water with combustion gasses. This direct contact avoids thermal inefficiency due to heat transfer resistance across boiler tubes.
  • Tubing 112 conveys the fluid stream from the generator 100 to the injection well 101 by coupling an output from the flow path through the generator 100 with the injection well 101.
  • Examples of the oxidant include air, oxygen enriched air and oxygen (i.e., oxy combustion with greater than 95% pure 0 2 or greater than 99% pure 0 2 ), which may be separated from air.
  • Sources for the fuel include natural gas or other hydrocarbon gas mixtures that may contain at least 90% methane.
  • at least some of the hydrogen in the fluid stream comes from operation of the generator 100 with the fuel introduced in excess of a supply rate that achieves complete combustion given amount of oxygen supplied to the generator 100.
  • Such fuel-rich operating conditions of the generator 100 thus provide combustion at an oxygen:fuel equivalence ratio less than 1.
  • the oxidantfuel equivalence ratio as used herein refers to a ratio of actual oxidantfuel ratio to a stoichiometric oxidantfuel ratio.
  • a stoichiometric mixture contains just enough of the oxygen for complete burning of the fuel such that all the oxygen is consumed in reaction without the oxygen passing through in combustion products.
  • the generator 100 produces the hydrogen at a pressure and temperature suitable for reservoir injection conditions. Producing the hydrogen mixed with the steam within the fluid stream from the generator 100 therefore avoids alternative surface storage of hydrogen or separate hydrogen production and injection equipment. This cogeneration of the hydrogen and the steam together within the generator 100 also enables injection of the hydrogen while limiting safety issues associated with handling of the hydrogen. Compared to in situ combustion for generation of the hydrogen, the hydrogen being part of the fluid stream from the generator 100 further enables delivery of the hydrogen through the conduit 112 and the injection well 101 to locations where desired in the formation 103.
  • the steam upon exiting the injection well 101 and passing into the formation 103 condenses and contacts the petroleum products to create a mixture of condensate from the steam and the petroleum products.
  • the mixture migrates through the formation 103 due to gravity drainage and is gathered at the production well 102 through which the mixture is recovered to surface.
  • a separation process may divide the mixture into components for recycling of recovered water back to the generator 100.
  • exemplary reactions for the hydroprocessing include desulfurization, olefin and aromatic saturation and hydrocracking. With respect to the saturation of olefins, unsaturated bonds accept the hydrogen becoming capped to prevent undesired polymerization of the petroleum products. At least a few of the reactions may proceed to some extent even below an injection temperature that the fluid stream produced by the generator 100 enters the formation 103.
  • Figure 2 shows a device 200 for cogeneration of steam and hydrogen, an injector
  • a wellbore heater 250 and optional catalyst 252 facilitate in situ upgrading of hydrocarbons by hydroprocessing reactions. Disposing the heater 250 and the catalyst 252 along the producer 202 places the catalyst 252 in a flow path of the hydrocarbons from the formation 103 to the surface. The heater 250 also thereby increases temperature of the hydrocarbons in contact with the catalyst 252 to a reaction temperature sufficient to achieve the hydroprocessing reactions.
  • the hydrogen required for the reactions comes from the hydrogen that is introduced through the injector 201.
  • Proximity of the producer 202 and the injector 201 allows for mixing of the hydrogen with surrounding fluids at hydroprocessing zones where the temperature is increased by the heater 250 to promote the reactions.
  • Flow of production fluids including the hydrocarbons and water further mix with the hydrogen and help in transporting the hydrogen toward the hydroprocessing zones.
  • the heater 250 achieves subsurface heating of the hydrocarbons to the reaction temperature above 300° C or above 400° C.
  • the heater 250 supplements the heating of the hydrocarbons achieved by the fluid stream that is produced by the generator 200 since the reaction temperature may be above an injection temperature that the fluid stream enters the formation 103.
  • the heater 250 provides a non- steam based source of heat using various other techniques for heating of the hydrocarbons.
  • Examples of the heater 250 include an induction heating tool, a radio frequency or microwave heating device or a resistive heating element.
  • the heater 250 utilizing an exemplary induction heating method includes a coiled conductive metal through which current is passed to create heat by inducing hysteresis losses in a metal liner of the producer 202. In this example of the heater 250, current also passes into the reservoir surrounding the producer 202 for additional heating of the hydroprocessing zones.
  • Several approaches enable disposing of the catalyst 252 subsurface for the in situ upgrading. For example, passing the catalyst 252 through the producer 202 to where desired may be done as part of a water-in-oil emulsion or to create a packed bed. In some embodiments, solid particles forming the catalyst 252 provide packing in an annulus of the producer 202.
  • the catalyst 252 defines a hydroprocessing catalyst.
  • Suitable compounds for the catalyst 252 include metal sulfides (e.g., MoS 2 , WS 2 , CoMoS and NiMoS), metal carbides (MoC and WC) or other refractory type metal compounds such as metal phosphides and metal borides.
  • metal sulfides e.g., MoS 2 , WS 2 , CoMoS and NiMoS
  • metal carbides MoC and WC
  • other refractory type metal compounds such as metal phosphides and metal borides.
  • a water-gas shift reaction produces additional hydrogen to supplement hydrogen production within generators described herein.
  • the water-gas shift reaction yields carbon dioxide and the hydrogen by conversion of water vapor and carbon monoxide also output in fluid streams from the generators.
  • the water-gas shift reaction occurs once the carbon monoxide is injected into a hydrocarbon reservoir.
  • the catalyst 252 as shown in Figure 2 may thus define a water-gas shift catalyst in a flow path of the carbon monoxide mixed with the steam.
  • composition of the catalyst 252 promotes both the hydroprocessing and water-gas shift reactions or may include compounds that are mixed together or disposed in separate locations and define the hydroprocessing catalyst that is different from the water-gas shift catalyst.
  • Exemplary catalysts 252 specific for the water-gas shift reaction include copper/zinc/aluminum (Cr/Zn/Al) and iron/chromium/copper (Fe/Cr/Cu).
  • the upgrading of the hydrocarbons yields products with permanent viscosity reduction. This viscosity reduction helps to at least limit amount of diluting required for transport of the products. In addition, the upgrading facilitates further processing of the products at refineries.
  • Figure 3 illustrates a plot of modeled results for hydrogen and carbon monoxide levels in product gas from a direct steam generator versus oxygen to fuel equivalence ratio for combustion in the direct steam generator.
  • First line 301 with triangular data points represents the hydrogen levels.
  • the generator produces over 19 volume percent hydrogen on a dry basis at an oxygen:fuel equivalence ratio of 0.9.
  • conventional operation with an oxygen:fuel equivalence ratio greater than 1 yields less than 1 volume percent hydrogen on a dry basis. While the oxygen:fuel equivalence ratio of 0.9 is a minimum depicted, the generator may operate at lower values of the oxygen:fuel equivalence ratio and hence may produce even higher concentrations of the hydrogen than indicated by the plot.
  • the steam produced per unit of the fuel burned decreases as the oxygen:fuel equivalence ratio drops.
  • the oxygen:fuel equivalence ratio of 0.9 provides about 86-88% of the steam per unit of the fuel burned relative to operating at stochiometric conditions (i.e., the oxygen:fuel equivalence ratio equals 1). Selection of the oxygen:fuel equivalence ratio thus depends on an economic balance between steam production rate and hydrogen production rate.
  • Second line 302 with square data points represents the carbon monoxide levels.
  • the carbon monoxide level increases with the hydrogen level as the oxygen:fuel equivalence ratio decreases. Therefore, increase in the carbon monoxide available for the water-gas shift reaction to make additional hydrogen occurs in a synergistic relation with raising of the hydrogen output based on the oxygen:fuel equivalence ratio.
  • the generator produces over 12 volume percent carbon monoxide on a dry basis at the oxygen:fuel equivalence ratio of 0.9. In contrast, conventional operation with the oxygen:fuel equivalence ratio greater than 1 yields less than 1 volume percent carbon monoxide on a dry basis.
  • fluid streams produced by generators described herein contains at least 5 volume percent hydrogen on a dry basis, at least 10 volume percent hydrogen on a dry basis or at least 15 volume percent hydrogen on a dry basis. Operation with the oxygen:fuel equivalence ratio less than 0.98, less than 0.95, less than 0.92 or less than 0.9 may provide desired amounts of the hydrogen within the fluid streams. While limited by reduction in the steam production, ability to approach full hydrocarbon upgrading relies on utilizing concentrations of the hydrogen as high as possible.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Hydrogen, Water And Hydrids (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

L'invention concerne des procédés et un appareil pour récupérer in situ des hydrocarbures valorisés par injection de vapeur et d'hydrogène dans un réservoir contenant des hydrocarbures. Une sortie de mélange généré par vaporisation d'eau par contact direct avec un écoulement de la combustion riche en carburant fournit la vapeur et l'hydrogène. La vapeur chauffe les hydrocarbures en facilitant l'écoulement des hydrocarbures et la réaction de l'hydrogène avec les hydrocarbures pour permettre un hydrotraitement avant la récupération des hydrocarbures à la surface.
PCT/US2011/052601 2010-09-24 2011-09-21 Valorisation d'hydrocarbures in situ avec un fluide généré pour fournir de la vapeur et de l'hydrogène WO2012040358A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
CA2812589A CA2812589A1 (fr) 2010-09-24 2011-09-21 Valorisation d'hydrocarbures in situ avec un fluide genere pour fournir de la vapeur et de l'hydrogene

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US38636110P 2010-09-24 2010-09-24
US61/386,361 2010-09-24

Publications (1)

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WO2012040358A1 true WO2012040358A1 (fr) 2012-03-29

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US (1) US20120073810A1 (fr)
CA (1) CA2812589A1 (fr)
WO (1) WO2012040358A1 (fr)

Cited By (1)

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EP3957704A1 (fr) 2020-08-21 2022-02-23 Vito NV Procédé d'hydrotraitement d'un composé organique et catalyseurs correspondants

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WO2012149025A1 (fr) * 2011-04-25 2012-11-01 Conocophillips Company Reconfiguration catalytique à fréquence radio in situ
US10161233B2 (en) 2012-07-13 2018-12-25 Harris Corporation Method of upgrading and recovering a hydrocarbon resource for pipeline transport and related system
US9057237B2 (en) 2012-07-13 2015-06-16 Harris Corporation Method for recovering a hydrocarbon resource from a subterranean formation including additional upgrading at the wellhead and related apparatus
US9200506B2 (en) 2012-07-13 2015-12-01 Harris Corporation Apparatus for transporting and upgrading a hydrocarbon resource through a pipeline and related methods
US9044731B2 (en) 2012-07-13 2015-06-02 Harris Corporation Radio frequency hydrocarbon resource upgrading apparatus including parallel paths and related methods
WO2015095926A1 (fr) * 2013-12-23 2015-07-02 Shale Energy Limited Procédé, système et appareil pour le traitement in situ d'une formation de schistes bitumineux
CA2847881C (fr) 2014-03-28 2018-01-02 Suncor Energy Inc. Production de vapeur distante et separation d'eau et d'hydrocarbure dans les exploitations de drainage par gravite assistees a la vapeur
US11156072B2 (en) 2016-08-25 2021-10-26 Conocophillips Company Well configuration for coinjection
CA2976575A1 (fr) 2016-08-25 2018-02-25 Conocophillips Company Configuration de puits en vue de la coinjection
CA2943314C (fr) 2016-09-28 2023-10-03 Suncor Energy Inc. Production d'hydrocarbure par generation de vapeur en contact direct
CN106640007A (zh) * 2016-12-30 2017-05-10 中国海洋石油总公司 多源多元热流体发生系统及方法
CN106640008A (zh) * 2016-12-30 2017-05-10 中国海洋石油总公司 超临界多源多元热流体注采系统及注采方法
JP7217745B2 (ja) * 2017-06-15 2023-02-03 レベンテック インコーポレイテッド 地下地熱貯留層から水素を生産する方法
CN112196505A (zh) * 2020-09-04 2021-01-08 中国石油工程建设有限公司 一种油藏原位转化制氢系统及其制氢工艺
CN113773827B (zh) * 2021-08-31 2022-11-04 广汉市福客科技有限公司 一种自发泡延缓型固体泡沫排水剂及其制备方法
CN115490206A (zh) * 2022-08-10 2022-12-20 西南石油大学 一种利用井下电加热实现近井地带原位制氢方法

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US2734578A (en) * 1956-02-14 Walter
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US20090065206A1 (en) * 2007-09-06 2009-03-12 Thane Geoffrey Russell Wellbore fluid treatment tubular and method
US20090194282A1 (en) * 2007-10-19 2009-08-06 Gary Lee Beer In situ oxidation of subsurface formations

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP3957704A1 (fr) 2020-08-21 2022-02-23 Vito NV Procédé d'hydrotraitement d'un composé organique et catalyseurs correspondants
WO2022038285A1 (fr) 2020-08-21 2022-02-24 Vito Nv Procédé d'hydrotraitement d'un composé organique et catalyseurs associés

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Publication number Publication date
CA2812589A1 (fr) 2012-03-29
US20120073810A1 (en) 2012-03-29

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