WO2002018746A1 - Procede et systeme destines a injecter un gaz dans un reservoir - Google Patents

Procede et systeme destines a injecter un gaz dans un reservoir Download PDF

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Publication number
WO2002018746A1
WO2002018746A1 PCT/IB2001/001560 IB0101560W WO0218746A1 WO 2002018746 A1 WO2002018746 A1 WO 2002018746A1 IB 0101560 W IB0101560 W IB 0101560W WO 0218746 A1 WO0218746 A1 WO 0218746A1
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WO
WIPO (PCT)
Prior art keywords
gas
reservoir
water
hydrate
oil
Prior art date
Application number
PCT/IB2001/001560
Other languages
English (en)
Inventor
Svein Arne Morud
Bjorn Øyvind BRINGEDAL
Lars NØKLEBERG
Original Assignee
Abb Research Ltd.
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 Abb Research Ltd. filed Critical Abb Research Ltd.
Priority to AU2001284323A priority Critical patent/AU2001284323A1/en
Publication of WO2002018746A1 publication Critical patent/WO2002018746A1/fr

Links

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
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/40—Separation associated with re-injection of separated materials
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/36—Underwater separating arrangements

Definitions

  • the present invention relates to a method and a system for injecting a gas into a reservoir.
  • reservoir should be regarded as any natural reservoir ex ⁇ isting in nature, in particular any underground reservoir. Oil reservoirs as well as water reservoirs in the earth are included. Particularly included are reservoirs from which a natural resource is extracted and which, as a result of such extraction, are subjected to an unwanted pressure decrease.
  • Oil production includes extracting oil from a reservoir, normally via one or more wells.
  • the latter is traditionally either flared, stored and/or transported for further use, or re-injected into the reservoir.
  • Gas flaring is not allowed in many regions and will probably be forbidden in most regions in the near future for environmental reasons.
  • Transportation and/or storage of the gas will require the use of a compressor and a storage vessel and/or a pipeline for the transportation thereof.
  • a compressor and a storage vessel and/or a pipeline for the transportation thereof.
  • off-shore plants or plants where the amount of extracted gas is low such arrangements will suffer from low cost efficiency.
  • Re-injection of the gas will in many cases be the most appropriate way of handling the extracted gas.
  • Re-injected gas will also have the positive effect of contributing to the preservation of the pres- sure in the reservoir, something that is positive for the extraction of oil therefrom.
  • traditional re-injection of the gas will require the use of a compressor and a separate injection well. The cost of such equipment is often much higher than the value of the gas, and can be an economical barrier to the development of marginal oil fields.
  • One object of the invention is to suggest a method by means of which a gas can be injected into a reservoir in a cost-ef&cient and reliable way, well competitive with methods according to prior art.
  • the object of the invention is obtained by means of the initially de- fined method, which is characterised in that it comprises the step of producing a gas hydrate from said gas and injecting the gas hydrate into the reservoir.
  • a gas hydrate can be injected into the reservoir using only a liquid pump and without the need of a gas compressor.
  • hydrate as used in this context, comprises special inclu- sion compounds having a crystalline structure known as clathrate.
  • gas molecules are physically entrapped or engaged in an expanded water lattice network comprising hydrogen-bonded water molecules.
  • the gas molecules preferably light hydro-carbon gas molecules and other associated gases physically react with water at elevated pressures and low temperatures to form ice-like compounds.
  • the hydrate particles shall be of such character that they melt and release the gas and water when the temperature is sufficiently increased. Thereby preservation or even an increase of the pressure in the reservoir into which the gas/gas hydrate is injected can be obtained.
  • the gas hydrate is produced by mixing the gas and water.
  • Water has the advantage of having suitable physical properties for hydrate generation, being environmentally harmless and also, at least in connection to off-shore plants, being readily available.
  • the gas comprises natural gas that has been extracted together with and separated from oil from an oil reservoir.
  • the reservoir into which the hydrate is injected is the same as said oil reservoir there is not only a question of injecting gas, but of re-injecting it into the reservoir.
  • the invention includes re-injection of the gas hydrate into the same reservoir as the one from which the gas was originally extracted.
  • the water used should comprise sea water. Such water already has the advantage of having a fairly low temperature and being readily available. However, cooled produced water could also be used instead of or as a complement to cold sea water.
  • the water temperature should be below approximately 10 °C, preferably below 5 °C.
  • the water/ gas ratio is chosen such that a liquid slurry consisting of water and gas hydrate is produced and that said slurry is injected into the oil reservoir.
  • the preferred maximum amount of gas is approximately 13 wt %, the water amount then being approximately 87 wt %. This is the upper limit. If natural gas hydrates are produced at high pressure and low temperature, the upper limit might be reached. Creating hydrates near the hydrate formation curve, the amount of gas in the hydrates will be considerably lower than this limit.
  • excess water and/ or surface ac- five chemicals may be added to the hydrate slurry. Also any thermo active agent may be added to the slurry.
  • the hydrates can be produced from approximately 10 bar and higher depending on the temperature and gas mixture. Salty water will raise the hydrate curve and make it more difficult to create natural gas hydrates. When the hydrates are produced they are relatively stable also at atmospheric pressure, and they are meta-stable for negative temperatures, T ⁇ 0 °C.
  • the hydrate can be produced, for example by injecting the gas into a water-filled system, or by injecting gas and water simultaneously in any suitable system or device.
  • the gas and water can be mixed in a venturi tube (jet pump), which can allow a lower operating pressure in a first stage separator (e.g. three phase separator for separating oil, gas and water).
  • a first stage separator e.g. three phase separator for separating oil, gas and water.
  • Other possible solutions of how to actually produce the hydrate are those mentioned in for example the international patent application WO 93/01153, Gudmundsson.
  • the object of the invention is also obtained by means of the initially defined system, characterised in that it comprises a device for producing from said gas a gas hydrate, which is to be injected into the reservoir.
  • the system preferably comprises means for conducting the characteristic steps of the inventive method.
  • the device preferably comprises a vessel with inlets for the gas and the medium with which it will form the hydrate, for example water. It should also
  • the gas hydrate producing device is adapted to mix the gas with water in order to produce the gas hydrate, preferably in such a way that easily pumpable hydrate slurry is obtained.
  • the system comprises means, preferably a pump or the like, for delivering sea water to the hydrate producing device.
  • the gas comprises natural gas extracted together with oil from said reservoir, and the system comprises a separator for separating the gas from the oil.
  • the gas will be re-injected into the same reservoir as it was extracted from.
  • the invention also covers the case in which the gas is injected into any other or neigh- bouring reservoir.
  • the system preferably comprises means for adding warm water, preferably production water or top side process water to the gas hydrate that is to be injected into the reservoir.
  • Production water is water that has been extracted together with oil from an oil reservoir and then separated from the oil. Such water will have the effect of improving the injectivity of the slurry by melting the hydrates, making it easier to re-inject the slurry without blockage or clogging in the re-injection well.
  • the warm water and the hydrate slurry need not necessarily be in direct contact with each other.
  • the warm water, such as production water can be conducted in annular tube or pipe ar- ranged directly outside the pipe for conducting the hydrate to the reservoir and thereby heating the outer peripheral regions of the hydrate.
  • the warm water can be conducted in the inner tube and the slurry in the annular tube.
  • any hot medium may be used for the purpose of heating the hydrate slurry just before the latter is injected into the reservoir. Accordingly, a medium of significantly higher temperature than the hydrate slurry is brought into a heat exchanging relationship with said slurry before injection of the latter into the reservoir.
  • the gas hydrate production device is operating at a sub-sea level according to one embodiment.
  • the figure shows a first embodiment of the system according to the invention. Also shown or indicated are parts of an oil extraction plant, the system being a part of that plant.
  • the plant comprises a plurality of wells 1 forming a so called production tree and by means of which oil is extracted from a reservoir or cavity (not shown). Gas, water and other particulate material such as sand is normally also extracted as a bi-product to the oil.
  • the wells 1 are connected via a pipeline 2 or the like to a first separator 3, which in this embodiment is a three phase separator for separating oil, water and gas from each other.
  • a first separator 3 which in this embodiment is a three phase separator for separating oil, water and gas from each other.
  • the sepa- rator is a gravity separator, but it should be understood that also other types of separators might be used instead or as a complement to the one shown in this embodiment.
  • a separator for separating solid particles such as sand from the extracted oil might as well be included in the three phase separator, which then becomes a four phase separator, or separately upstream the three phase separator.
  • the device 5 comprises a vessel into which the gas is injected. Inside the vessel there is an elevated pressure (above atmospheric pressure). Water is also introduced into the vessel.
  • the device 5 preferably comprises a venturi tube for mixing gas and water, as shown in the figure.
  • the device 5 is arranged at a sub-sea level or a top-side level and the wa- ter is sea water, which is pumped into the vessel by means of a pump 6.
  • a natural gas hydrate is thus formed by injecting the gas into a wa- ter-filled system, here the vessel 5.
  • a water/gas ratio control system (not shown) including pressure and/or temperature sensors, gas and water flow meters, and control apparatus for controlling the amount of introduced water etc. should be part of the inventive system.
  • the water/gas ratio should be such that a gas hydrate-water slurry is formed in the device 5.
  • the separator 3 and the device 5 could either be arranged top side at the platform or at a sub-sea level.
  • the invention includes both alternatives.
  • Top side arrangement results in no sub-sea processing.
  • the required pressure, between 30 and 60 bar for normal sea water temperature, for generating the hydrate could then be used in the 1st stage gravity separator 3.
  • the gas from further separators on the platform can then be used as fuel gas on the latter.
  • the separator 3 and the pump 6 are preferably arranged at a sub-sea level as well.
  • a sub-sea pump for pumping oil from the separator 3 to the topside is then likely to be needed.
  • a pump 7 has been indicated in the figure.
  • the sea water for injection can be obtained locally at the sub-sea installation or transported from the topside, enabling pre- treatment of the water.
  • Such pre-treatment may preferably include the addition of surface active chemicals for improving the hydrate pumpability, removal of oxygen from the water, addition of biocides, etc.
  • a thermo active agent such as methanol might be added to the water.
  • the inventive system includes means or devices (not shown) for such pre-treatment of the water.
  • the injection device 10 may be arranged in a plurality of ways. Here it is proposed to comprise a first tube 13 and a second tube 14 that are generally coaxial and define an inner flow path for the hydrate slurry and an outer annular flow path for the production water.
  • the warmer production water contributes to the melting of the slurry just before the latter entries into the reservoir.
  • the system may comprise any suitable means for enabling any hot medium, such as hot cooling water or any other me- dium already in use in an oil extraction plant or system, to exchange heat with the hydrate slurry.
  • Chemicals or agents for melting the hydrate could also be added to the hydrate slurry in the region of or downstream the pump 12.
  • An example of such an agent is salt, methanol or glycol.
  • the slurry is mixed with the production water.
  • mixing with production water may result in precipitation of sulphate scale and hydrate melting near the top of the injection well.
  • One solution to the scaling problem is to have a sulphate removal unit in- eluded in the system.
  • a scale inhibitor known per se, is introduced into the system in which the slurry and the production water are mixed. The system thereby comprises any suitable means for adding such an inhibitor.
  • Oil separated from the gas and the production water in the separator 3 is further transported via one or more pipes 15 to a top side platform or all the way to land where it is taken further care of.
  • additional separators (not shown) for further separation of rest gas and rest water will be needed somewhere downstream the first separator 3.
  • Such additional separators are typically located on the platform in todays plants, but might as well be located at a sub- sea level in the future.
  • melting of the hydrate slu ⁇ y may begin as soon as the slurry has passed the injection pump 12 in order to promote efficient injection of the gas and water to avoid clogging.
  • a plurality of ways of heating the slurry should be obvious for a man skilled in the art without going beyond the scope of the invention.
  • the formation into which the hydrate slu ⁇ y is injected could be any natural reservoir, such as a water reservoir located at a level above an oil reservoir from which the gas has been extracted. It also might be any hydro carbon reservoir, including an oil and/or a gas reservoir.

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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)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
  • Feeding, Discharge, Calcimining, Fusing, And Gas-Generation Devices (AREA)

Abstract

L'invention concerne un procédé d'injection de gaz dans un réservoir. Ledit procédé consiste à produire un hydrate de gaz à partir dudit gaz, et à injecter l'hydrate de gaz dans le réservoir. L'invention concerne également un système d'injection de gaz dans un réservoir, comportant un dispositif (5) destiné à produire un hydrate de gaz à partir dudit gaz, ledit hydrate de gaz devant être injecté dans le réservoir.
PCT/IB2001/001560 2000-08-31 2001-08-29 Procede et systeme destines a injecter un gaz dans un reservoir WO2002018746A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU2001284323A AU2001284323A1 (en) 2000-08-31 2001-08-29 A method and a system for injecting a gas into a reservoir

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NO20004337 2000-08-31
NO20004337A NO315990B1 (no) 2000-08-31 2000-08-31 Fremgangsmate og system for injisering av gass i et reservoar

Publications (1)

Publication Number Publication Date
WO2002018746A1 true WO2002018746A1 (fr) 2002-03-07

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Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/IB2001/001560 WO2002018746A1 (fr) 2000-08-31 2001-08-29 Procede et systeme destines a injecter un gaz dans un reservoir

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AU (1) AU2001284323A1 (fr)
NO (1) NO315990B1 (fr)
WO (1) WO2002018746A1 (fr)

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2004083601A1 (fr) * 2003-03-22 2004-09-30 Caltec Limited Systeme et procede de pompage de fluides polyphasiques
WO2008051087A1 (fr) 2006-10-27 2008-05-02 Statoilhydro Asa Système de traitement sous-marin
WO2015018945A3 (fr) * 2013-08-09 2015-04-09 Linde Aktiengesellschaft Traitement de flux de puits sous-marin
WO2021209172A1 (fr) * 2020-04-15 2021-10-21 Vetco Gray Scandinavia As Séparation de phase sous-marine et réinjection de gaz dense au moyen d'une pompe

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2514071A1 (fr) * 1981-10-06 1983-04-08 Chaudot Gerard Procede de production de gisements d'hydrocarbure avec reinjection d'effluents dans le gisement ou dans le ou les puits et installation pour la mise en oeuvre dudit procede
US4424866A (en) * 1981-09-08 1984-01-10 The United States Of America As Represented By The United States Department Of Energy Method for production of hydrocarbons from hydrates
US4813484A (en) * 1987-12-28 1989-03-21 Mobil Oil Corporation Chemical blowing agents for improved sweep efficiency
EP0780167A1 (fr) * 1995-12-19 1997-06-25 Canon Kabushiki Kaisha Procédé et dispositif pour diffuser une solution chimique, injecter un liquide et procédé de décontamination des sols

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4424866A (en) * 1981-09-08 1984-01-10 The United States Of America As Represented By The United States Department Of Energy Method for production of hydrocarbons from hydrates
FR2514071A1 (fr) * 1981-10-06 1983-04-08 Chaudot Gerard Procede de production de gisements d'hydrocarbure avec reinjection d'effluents dans le gisement ou dans le ou les puits et installation pour la mise en oeuvre dudit procede
US4813484A (en) * 1987-12-28 1989-03-21 Mobil Oil Corporation Chemical blowing agents for improved sweep efficiency
EP0780167A1 (fr) * 1995-12-19 1997-06-25 Canon Kabushiki Kaisha Procédé et dispositif pour diffuser une solution chimique, injecter un liquide et procédé de décontamination des sols

Cited By (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8257055B2 (en) 2003-03-22 2012-09-04 Caltec Limited System and process for pumping multiphase fluids
GB2414280A (en) * 2003-03-22 2005-11-23 Caltec Ltd A system and process for pumping multiphase fluids
GB2414280B (en) * 2003-03-22 2007-11-14 Caltec Ltd A system and process for pumping multiphase fluids
WO2004083601A1 (fr) * 2003-03-22 2004-09-30 Caltec Limited Systeme et procede de pompage de fluides polyphasiques
DK178832B1 (da) * 2006-10-27 2017-03-06 Statoil Petroleum As Undersøisk behandlingssystem
US20100032164A1 (en) * 2006-10-27 2010-02-11 William Bakke Sub sea processing system
EP2087201A4 (fr) * 2006-10-27 2015-07-22 Statoil Petroleum As Système de traitement sous-marin
US9435186B2 (en) 2006-10-27 2016-09-06 Statoil Petroleum As Sub sea processing system
WO2008051087A1 (fr) 2006-10-27 2008-05-02 Statoilhydro Asa Système de traitement sous-marin
WO2015018945A3 (fr) * 2013-08-09 2015-04-09 Linde Aktiengesellschaft Traitement de flux de puits sous-marin
WO2021209172A1 (fr) * 2020-04-15 2021-10-21 Vetco Gray Scandinavia As Séparation de phase sous-marine et réinjection de gaz dense au moyen d'une pompe
GB2609578A (en) * 2020-04-15 2023-02-08 Vetco Gray Scandinavia As Subsea phase-separation and dense gas reinjection by using a pump
GB2609578B (en) * 2020-04-15 2024-04-03 Vetco Gray Scandinavia As Subsea phase-separation and dense gas reinjection by using a pump

Also Published As

Publication number Publication date
NO315990B1 (no) 2003-11-24
AU2001284323A1 (en) 2002-03-13
NO20004337D0 (no) 2000-08-31
NO20004337L (no) 2002-03-01

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