WO2012095473A2 - Procédé pour la récupération de pétrole lourd et de bitume utilisant une combustion in situ - Google Patents

Procédé pour la récupération de pétrole lourd et de bitume utilisant une combustion in situ Download PDF

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Publication number
WO2012095473A2
WO2012095473A2 PCT/EP2012/050403 EP2012050403W WO2012095473A2 WO 2012095473 A2 WO2012095473 A2 WO 2012095473A2 EP 2012050403 W EP2012050403 W EP 2012050403W WO 2012095473 A2 WO2012095473 A2 WO 2012095473A2
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WO
WIPO (PCT)
Prior art keywords
well
reservoir
substantially vertical
oxygen
wells
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Application number
PCT/EP2012/050403
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English (en)
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WO2012095473A3 (fr
Inventor
Edmund Lau
Original Assignee
Statoil Canada Limited
Gordon, Kirsteen
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 Statoil Canada Limited, Gordon, Kirsteen filed Critical Statoil Canada Limited
Priority to CA2824168A priority Critical patent/CA2824168A1/fr
Priority to RU2013137758/03A priority patent/RU2013137758A/ru
Publication of WO2012095473A2 publication Critical patent/WO2012095473A2/fr
Publication of WO2012095473A3 publication Critical patent/WO2012095473A3/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • E21B43/243—Combustion in situ
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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. optimizing the spacing of wells
    • E21B43/305—Specific pattern of wells, e.g. optimizing the spacing of wells comprising at least one inclined or horizontal well

Definitions

  • the present invention provides a well arrangement suitable for the recovery by an in situ combustion process of hydrocarbons from a subterranean reservoir having a toe end and a heel end, said well arrangement comprising a substantially vertical injection well, a substantially horizontal oil production well, and a plurality of substantially vertical vent wells for removal of flue gases extending into the upper portion of the reservoir and substantially aligned along the line of said horizontal production well.
  • the invention also provides a subterranean reservoir comprising a plurality of the well arrangements and a method for recovering hydrocarbons from the subterranean reservoir.
  • Heavy hydrocarbons e.g. bitumen
  • bitumen represent a huge natural source of the world's total potential reserves of oil.
  • Present estimates place the quantity of heavy hydrocarbon reserves at several trillion barrels, more than 5 times the known amount of the conventional, i.e. non-heavy, hydrocarbon reserves. This is partly because heavy hydrocarbons are generally difficult to recover by conventional recovery processes and thus have not been exploited to the same extent as non-heavy hydrocarbons.
  • Heavy hydrocarbons possess very high viscosities and low API (American Petroleum Institute) gravities which makes them difficult, if not impossible, to pump in their native state.
  • heavy hydrocarbons are characterised by high levels of unwanted compounds such as asphaltenes, trace metals and sulphur that need to be processed appropriately during recovery and/or refining.
  • Some methods have been developed to extract and process heavy hydrocarbon mixtures.
  • the method that is used most often commercially today for heavy hydrocarbon recovery from subterranean reservoirs is steam assisted gravity drainage (SAGD).
  • SAGD steam assisted gravity drainage
  • two horizontal wells are drilled approximately five meters apart then steam is injected into the reservoir through the upper wellbore permeating the oil sand.
  • SAGD steam assisted gravity drainage
  • a row of vertical injection wells is completed in the upper part of the reservoir, at least one gas production well, spaced laterally from the row of injection wells, is also provided and a horizontal production well is positioned below the injection interval.
  • Oxygen-containing gas typically air
  • a discrete combustion chamber exists around the base of each injection well but as combustion proceeds a common combustion chamber forms between each of the injection wells.
  • the combustion zone or area has fronts comprising hot gases that serve to heat up hydrocarbon in their vicinity. This results in the production of heated heavy hydrocarbon of lower viscosity than the native hydrocarbon (the "upgraded hydrocarbons") that drains downwardly through the chamber under the influence of gravity.
  • hydrocarbon is produced from the horizontal production well lying below the injection interval.
  • the gases produced from the in situ combustion flow through the reservoir toward the gas production wells.
  • the gas production wells are spaced laterally from the row of injection wells as well as the production well.
  • US2009/0321073 discloses a method for recovering hydrocarbon using in situ combustion wherein the combustion products are more efficiently removed from the combustion zone.
  • oxygen is injected via an injection well to the bottom of the reservoir and flows to the combustion front.
  • Heated oil drains to the reservoir floor and is withdrawn at a rate such that the horizontal well is liquid full throughout the burned out zone.
  • Hot combustion gases are withdrawn from a region near the reservoir ceiling via a concentric well that may be concentric to the injection well, i.e. surround the injection well.
  • US'073 teaches that the horizontal production well preferably defines a heel and a toe, with the heel being proximate to the injection well. As a result, the combustion front in US'073 advances from the heel towards the toe.
  • the present invention provides a well arrangement suitable for the recovery by an in situ combustion process of hydrocarbons from a subterranean reservoir the configuration of which is such that there is a maximisation of both combustion and gravity drives, with efficient production of both the mobilised liquids and the combustion flue gases. Furthermore, the number of wells that need to be drilled is minimised.
  • a well arrangement suitable for the recovery by an in situ combustion process of hydrocarbons from a subterranean reservoir having a toe end and a heel end said well arrangement comprising:
  • a method for recovering hydrocarbons from a subterranean reservoir comprising providing a subterranean reservoir with at least one well arrangement according to the first aspect of the present invention and carrying out the following steps:
  • the present invention relates to particular well arrangements for the recovery of hydrocarbons.
  • well arrangement is used to refer to an ordered grouping or organised structure of a number of wells within a reservoir.
  • well refers to a hole drilled into the reservoir for use in the recovery of hydrocarbons.
  • well is often used interchangeably with wellbore.
  • subterranean reservoir refers to a collection or accumulation that exists below the surface of the earth, e.g. under a sea or ocean bed.
  • a hydrocarbon reservoir is therefore a mass of hydrocarbons that has accumulated in the porous rock existing below the earth's surface.
  • the present invention is particularly applicable to the recovery of hydrocarbons from off-shore subterranean reservoirs, i.e. from reservoirs existing below a sea or ocean bed.
  • a typical subterranean reservoir comprises at least two distinct zones. Nearest to the earth's surface is a covering of overburden which does not comprise any hydrocarbon. Below the overburden lies at least one portion of the reservoir that contains hydrocarbons. This is referred to herein as the hydrocarbon-containing portion of the reservoir.
  • the hydrocarbon-containing portion of the reservoir comprises an upper portion and a lower portion.
  • the upper portion generally refers to the uppermost 50% of the hydrocarbon-containing reservoir, more preferably the uppermost 40% and still more preferably the uppermost 30% of the reservoir.
  • This portion is the portion of the hydrocarbon-containing reservoir that is nearest the surface of the reservoir.
  • the lower portion generally refers to the deepest portion of the reservoir, preferabaly the lowermost 50% of the hydrocarbon-containing reservoir, still more preferably the lowermost 40% of the reservoir and still more preferably the lowermost 30% of the reservoir.
  • a substantially vertical vent well we mean a wellbore that is vertical or near-vertical for the removal of flue gases (i.e. gases produced in the reservoir as a result of the combustion of the hydrocarbons in said reservoir).
  • substantially vertical is meant that the well is at an angle of 75-90° to the earth's surface, more preferably at an angle of 80-90° to the earth's surface, still more preferably at an angle of 85-90° to the earth's surface, most preferably perpendicular to the earth's surface, for at least 90 % of the total length of the vertical well, more preferably for at least 95 % of the total length of the vertical well.
  • the substantially vertical vent wells extend into the upper portion of the reservoir, i.e. the lower end of said vent well is completed in the upper portion of the reservoir. This maximises the collection of the flue gases as they are generated during the combustion process.
  • the well arrangement of the present invention comprises a plurality of vent wells that are substantially aligned along the line of the substantially horizontal production well.
  • the vent wells are preferably aligned in a row.
  • the vent wells are equally spaced apart along the row.
  • the final vent well in a row is in the vicinity of the heel of the production well (see below).
  • the number of vent wells present in a well arrangement will depend on a number of factors, e.g. the type of the reservoir, the amount of hydrocarbon present, the size of the injection and vent wells etc, but generally 3 to 10 vent wells will be present, more preferably 4 to 8 vent wells.
  • the well arrangement has a substantially vertical injection well extending into the upper portion of the reservoir suitable for the injection of oxygen-rich gas into the reservoir.
  • the oxygen-rich gas can, for example, be air, oxygen or recycled gas with oxygen added.
  • a preferred oxygen-rich gas for use in the methods of the present invention comprises at least 20% by volume oxygen.
  • Particularly preferred oxygen-rich gases comprise at least 30 % by volume, more preferably at least 40 % by volume oxygen.
  • Particularly preferred oxygen-rich gas comprises 20-100 % by volume oxygen, more preferably 30-90 % by volume oxygen, still more preferably 40-85 % by volume oxygen, e.g. about 50 to 80 % by volume oxygen.
  • a substantially vertical injection well we mean a wellbore that is vertical or near- vertical for the injection of oxygen-rich gas into the reservoir.
  • substantially vertical is meant that the well is at an angle of 75-90° to the earth's surface, more preferably at an angle of 80-90° to the earth's surface, still more preferably at an angle of 85-90° to the earth's surface, most preferably perpendicular to the earth's surface, for at least 90 % of the total length of the vertical well, more preferably for at least 95 % of the total length of the vertical well.
  • the substantially vertical injection well extends into the upper portion of the reservoir, i.e. the lower end of said injection well is completed in the upper portion of the reservoir.
  • the well arrangement of the present invention has a substantially horizontal oil production well, positioned in the reservoir in a position below the lower end of the vertical injection well and substantially aligned with it.
  • a substantially horizontal oil production well we mean a horizontal or near-horizontal wellbore that is configured to capture the mobilised hydrocarbons and water produced as a result of the combustion process of the present invention.
  • substantially horizontal is meant that the well is within 15° of being parallel to the earth's surface, more preferably within 10° of being parallel to the earth's surface, still more preferably within 5° of being parallel to the earth's surface, e.g. parallel to the earth's surface, for at least 90 % of the total length of the substantially horizontal well, more preferably for at least 95 % of the total length of the substantially horizontal well.
  • Each producer well also preferably comprises a further section, typically a substantially vertical section, which extends from the horizontal well to the surface.
  • This further, e.g. vertical, section is preferably integral with the horizontal well. This enables gases and fluids to be injected and/or pumped into and out of the wells to the reservoir surface.
  • vertical refers here as given above.
  • the horizontal producer well together with its vertical section, define a shape that is sometimes likened to a foot.
  • the part of the well where the vertical section meets or joins the horizontal well is generally referred to as the heel and the end of the horizontal well as the toe.
  • heel and toe is also applied in relation to the reservoir.
  • the heel part of the reservoir refers to the part of the reservoir in which the heel of the production well is present and the toe part of the reservoir refers to the part in which the toe of the production well is present.
  • the horizontal oil production well is located in a position that is below the lower end of the plurality of vent wells and substantially aligned with them. By this we mean that it is disposed below the end of the vent wells and aligned or near-aligned with the line of the plurality of vent wells.
  • the distance between the bottom of the injection well and the production well is about 2-20 metres, more preferably about 5-10 metres.
  • the production well is located in the lower portion of the reservoir.
  • lower portion is meant the lower 50% of the total height of the oil-bearing reservoir, e.g. the lower 10-50% of the total height of the oil-bearing reservoir.
  • the production well is fitted with a slotted liner conventional in the art to permit ingress of hydrocarbon mixture from the reservoir.
  • the substantially horizontal production well should be configured to segregate gas and liquid flows such that the hydrocarbons and water are carried by it and transported to the heel section from where they are transferred (see below), whereas the gas is vented via the casing.
  • the horizontal well can be suitably configured to permit a small amount of gas to enter through the tubing and be retained.
  • the well arrangements and methods of the invention are based on an in situ combustion process wherein a gas is injected into the oil-bearing formation where it combusts with hydrocarbon present therein.
  • a combustion front forms and the area of formation adjacent to the combustion front is heated and upgraded, resulting in the viscosity of any hydrocarbon present in this zone being reduced.
  • gravity forces it downwards towards the substantially horizontal production well from where it can be produced.
  • the well arrangement of the present invention reduces the pressure difference between the substantially vertical injection well and the substantially horizontal production well, as a result of which there is considerably improved control of propagation and sweep of the combustion front to maximise the effects of both combustion and gravity drives. This is partly achieved because the injection well is always located in a relatively close location to the combustion front. Furthermore, the well arrangement efficiently produces the mobilised liquids (i.e. softened, flowable hydrocarbons and water) and combustion flue gases.
  • the toe end of the substantially horizontal production well is preferably on the updip side.
  • the substantially vertical injection well is initially located at the toe end of the subterranean reservoir.
  • the substantially vertical vent wells are configured such that they can be switched to act as a substantially vertical injection well.
  • the injection well and vent wells are preferably aligned.
  • the injection well and the vent wells are also of similar, e.g. identical, length.
  • This arrangement is particularly efficient because as the combustion front spreads from the toe end of the reservoir, away from the initial substantially vertical injection well, when it reaches the first of the substantially vertical vent wells it is then possible to switch the operation of said vent well so that it operates as an injection well.
  • the next substantially vertical vent well along the line of the substantially horizontal production well is opened so that it is able to act as a vent to the flue gases generated by the combustion front.
  • the mobilised hydrocarbons produced using the well arrangement of the present invention can be recovered from the substantially horizontal production well by any means known in the art, e.g. by pumping it from the production well to the surface.
  • hydrocarbons are recovered from the horizontal production well through tubing located near the heel end of said reservoir, usually by pumping through said tubing.
  • hydrocarbons is used to refer to a combination of different hydrocarbons, i.e. to a combination of various types of molecules that contain carbon atoms and, in many cases, attached hydrogen atoms.
  • Hydrocarbons may comprise a large number of different molecules having a wide range of molecular weights.
  • hydrocarbons Generally at least 90 % by weight of the "hydrocarbons" in the reservoir consists of carbon and hydrogen atoms. Up to 10% by weight may be present as sulphur, nitrogen and oxygen as well as metals such as iron, nickel and vanadium (i.e. as measured sulphur, nitrogen, oxygen or metals). These are generally present in the form of impurities of the desired hydrocarbon mixture.
  • a heavy hydrocarbon mixture comprises a greater proportion of hydrocarbons having a higher molecular weight than a relatively lighter hydrocarbon mixture.
  • a heavy hydrocarbon mixture preferably has an API gravity of less than about 15°, preferably less than 12°, still more preferably less than 10°, e.g. less than 8°. It is particularly preferred if the API gravity of the heavy hydrocarbon mixture to be recovered is from about 5° to about 15°, more preferably from about 6° to about 12°, still more preferably about 7° to about 12°, e.g. about 7.5- 9°.
  • Examples of heavy hydrocarbon mixtures that typically have API gravities falling in these ranges are bitumens, tars, oil shales and oil sand deposits.
  • a plurality of the well arrangements of the present invention may be located in a single reservoir as an array of substantially horizontal production wells, substantially vertical injection wells and substantially vertical vent wells. Such arrays enable the pressure difference between the substantially vertical injection wells and the substantially horizontal production wells to be reduced, optimising the effects of both combustion and gravity drives. While maintaining an overall gas balance, the air and vent gas rates of the individual injection wells and vent wells may be varied periodically in such arrays to encourage cross flows between the well units. The aim of this is to improve the areal sweep of the combustion front.
  • the second aspect of the present invention is a method for recovering hydrocarbons from a subterranean reservoir comprising providing a reservoir with at least one well arrangement according to the first aspect of the present invention and carrying out the following steps: (i) injecting an oxygen rich gas via said substantially vertical injection well into said hydrocarbon reservoir and opening the substantially vertical vent well that is closest to said substantially vertical injection well along the line of the substantially horizontal production well towards the heel end; (ii) combusting said oxygen rich gas in said hydrocarbon reservoir thereby heating, upgrading and reducing the viscosity of said hydrocarbon mixture;
  • the well arrangement of the present invention has the potential to reduce the pressure difference between the substantially vertical injection well and the substantially horizontal production wells, as a result of which it is possible to achieve considerably improved control of propagation and sweep of the combustion front compared to the SAGD and COSH techniques of the prior art.
  • the well arrangement makes it possible to maximise the effects of both combustion and gravity drives.
  • it efficiently produces the mobilised liquids (i.e. softened, flowable hydrocarbons and water) and combustion flue gases.
  • Adoption of the method of the second aspect of the present invention enables these to be achieved to the fullest possible effect.
  • the oxygen-rich gas is typically injected into the formation using conventional equipment for the handling of gases.
  • the oxygen-rich gas is injected into the formation at a pressure less than the fracturing pressure of the formation.
  • the oxygen-rich gas is injected into the formation at a pressure that is greater than the reservoir pressure.
  • the oxygen-rich gas is injected at a pressure that is -0-20 bar, preferably 5-20 bar, e.g. about 10 bar, greater than the reservoir pressure.
  • the oxygen-rich gas comprises a mixture, e.g. of oxygen and C0 2
  • the gases may be mixed prior to injection or co-injected.
  • the gases are mixed prior to injection.
  • the formation Prior to the injection of the oxygen-rich gas, the formation is preferably heated. This ensures that ignition and combustion will occur when the oxygen-rich gas is injected.
  • the formation is heated prior to injection by steam, in particular, by cyclic steam stimulation. Steam may be injected into the formation using conventional techniques.
  • the preheating stage is preferably continued until the reservoir reaches a high enough temperature to maintain combustion.
  • the preheating step achieves a reservoir temperature of 150-300°C, still more preferably 200-250°C.
  • the generation of steam is, however, an energy consuming and C0 2 producing process, therefore the amount of steam used is preferably minimised.
  • the C0 2 produced during steam generation may optionally be captured and stored in a formation and/or incorporated into the oxygen-rich gas injected into the formation.
  • the methods of the present invention may also employ an ignition device. Any commercially available device may be used, e.g. a downhole burner. When present, the ignition device is preferably placed in the injection well. Preferred ignition devices achieve temperatures of at least 300°C, e.g. 300-500°C.
  • the oxygen-rich gas used for combustion can, for example, be air, oxygen or recycled gas with oxygen added, as previously discussed. Air is preferred.
  • the oxygen rich gas is air injected at a rate of from 25,000 to 100,000 nrVday.
  • this intake of oxygen air comprising approximately 20% oxygen gas is sufficient to ensure in situ heat generation in the reservoir.
  • the flue gases are vented to regulate the reservoir pressure after injection of the oxygen rich gas at a pre-determined operating pressure (e.g. about 10 bar greater than the reservoir pressure).
  • a pre-determined operating pressure e.g. about 10 bar greater than the reservoir pressure.
  • the flue gases are vented at from 80-95%, e.g. 85- 90% the rate of injection of the oxygen rich gas to regulate the reservoir pressure.
  • the flue gases vented via said substantially vertical vent wells are captured and then re-injected into said subterranean reservoir via the previous substantially vertical injection well. This has two desirable effects. First, it maximises oxygen usage in the burnt chamber. Second, it reduces emission of green house gases into the Earth's atmosphere which makes this embodiment particularly environmentally favourable.
  • the mobilised hydrocarbons recovered from the production well preferably have an API of 9-20°, more preferably 10-17°, still more preferably 1 1 -15°.
  • the hydrocarbons in the reservoir undergo upgrading during recovery that increases the API of the mobilised hydrocarbons by up to 5°, e.g. by 1 to 5°.
  • the term "upgrading” generally refers to the process of altering a hydrocarbon mixture to have more desirable properties, e.g. to reduce the average molecular weight of the hydrocarbons present in the mixture and correspondingly its viscosity. Upgrading during the recovery process is therefore generally desirable. In in situ combustion processes, upgrading is believed to occur by thermal cracking. At the same time, however, the temperature of the reservoir needs to be controlled so that the combustion area, as well as the combustion gases, is contained in the part of the formation where they are desired. In the method of the present invention, the injection rate of the oxygen rich gas and the concentration of oxygen in said gas are carefully controlled to ensure that combustion is maintained at the desired temperature and in the correct areas of the reservoir.
  • the liquid (i.e. mobilised hydrocarbons and water) production rate is controlled based on the temperature at the bottom of the reservoir in the vicinity of the substantially horizontal production well. Typically, this will be in the region of 300°C. This is to avoid heat damage and coking in the substantially horizontal production well.
  • a low casing gas pressure should be used in the substantially horizontal production well to draw the combustion surface down in the reservoir.
  • the aim of this is to optimise the energy utility.
  • the heat from the combustion will heat the injected water such that it produces superheated steam.
  • the superheated steam will propagate to the combustion front, and into the formation heating the bitumen and mobilising it so that it can be recovered.
  • This provides an additional heat-based effect akin to the SAGD recovery effect (it is different to ISC where upgrading occurs due to the combustion leaving behind a "coke” component).
  • the water can also provide temperature control, as water is a good regulator due to its high latent heat of vaporization.
  • each substantially vertical vent well in turn moving from the toe end towards the heel end, it is switched to act as a substantially vertical injection well and the next vent well along the line of said substantially horizontal production well between said substantially vertical injection well and said heel end is opened to act as the new vent well.
  • the previous substantially vertical injection well is either shut-in or is converted to a substantially vertical flue gas injector or is used for water disposal when the subsequent vent well is converted to become the new substantially vertical injection well.
  • Figure 1 is a top schematic view of a subterranean reservoir comprising three well arrangements according to the present invention
  • Figures 2 and 3 are isometric schematic views of the subterranean reservoir comprising one of said well arrangements after combustion has been initiated (depicted at different times);
  • Figure 4 is a top schematic view of a subterranean reservoir where a pattern has been depleted and the line drive operation is being continued by the addition of new pattern on the heel side of the depleted pattern.
  • FIG. 1 shows a top schematic view of a subterranean reservoir comprising three well arrangements according to the present invention in the initial configuration before combustion has begun.
  • a covering of overburden (not shown in Figure 1 ) lies above the oil-bearing formation 1 .
  • Vertical injection wells 2 are drilled downward through the overburden. The injection wells 2 are completed in the upper portion of said oil-bearing formation 1. Vent wells 3 are also drilled through the overburden and are completed in the upper portion of the oil-bearing formation.
  • the production well 6 is substantially horizontal and is aligned with, and positioned below, the row of vent wells 3. The production well 6 is located in a lower region of the oil-bearing formation 1 .
  • the production well 6 is preferably provided with a liner (not shown) as is conventional in the art.
  • the air injection wells 2 are located at the toe ends 4 of the horizontal wells 6, while the vent wells 3 are configured such that they are approximately equally spaced along the horizontal wells 6 and the final vent wells 3 are at the heel ends 5 of said horizontal wells 6.
  • Preheating may be achieved by injecting steam through the injection wells 2 and optionally through the vent wells 3 and/or the production wells 6. It is generally desirable to inject steam through all types of wells so fluid communication between the injection wells 2, vent wells 3 and production wells 6 is achieved. Oil may be recovered in production wells 6 during this preheating step. When the reservoir is sufficiently heated, combustion may be started.
  • FIGs 2 and 3 show isometric schematic views of the subterranean reservoir comprising one of said well arrangements after combustion has been initiated ( Figures 2 and 3 depicting different stages after combustion has been initiated). Features that are also shown in Figure 1 are designated by the same reference numeral. The overburden through which the wells are drilled can be seen in Figures 2 and 3 (see 7).
  • Oxygen-rich gas is injected into injection well 2 located at the toe end of the reservoir to initiate combustion. Thereafter a combustion chamber forms around the injection well 2. The combustion chambers naturally spread and eventually form a continuous chamber that links all of the injection wells 2 in the entire reservoir. The front of the combustion zone 8 heats heavy hydrocarbon in its vicinity thereby increasing the hydrocarbon mobility and enabling it to flow. Under the forces of gravity, the mobilised heavy hydrocarbon flows downwards towards production well 6, from there the partially upgraded heavy hydrocarbon is lifted to the surface facilities via well 6.
  • FIG. 2 shows an isometric schematic of a well arrangement shortly after combustion has been initiated and Figure 3 shows an isometric schematic of the same well arrangement some time later.
  • the combustion front 8 As the combustion front 8 approaches the first vent well 3 (see Figure 2), it is switched to act as an injection well 2 (see Figure 3) and the next vent well 3 along the line of said horizontal production well 6 between said injection well 2 and said heel end 5 is opened to act as the new vent well 3.
  • the first injection well 2 After the vent well 3 has been converted to an injection well 2, the first injection well 2 is either shut-in or it is converted to a flue gas injector or used for water disposal.
  • FIG. 4 depicts a top schematic view of a subterranean reservoir where an oil bearing formation 1 has been depleted and the line drive operation is being continued by the addition of new patterns on the heel side of the depleted oil bearing formation 1.
  • new horizontal wells 6' are laid in continuation at the beginning (toe end 4') of the new oil bearing formation V.
  • injection wells 2' are completed in the upper portion of said oil-bearing formation V.
  • Vent wells 3' are also drilled through the overburden and are completed in the upper portion of the oil-bearing formation V.
  • the production well 6' is substantially horizontal and is aligned with, and positioned below, the row of vent wells 3'.
  • the heating, combustion and switching from vent to injection well procedure is conducted as previously and the mobilised heavy hydrocarbon is lifted from production well 6' to the surface.
  • the well arrangement and method of the present invention has a number of clear advantages over the prior art well arrangements and methods:
  • the well arrangement of the present invention reduces the pressure difference between the injection well and the horizontal wells, as a result of which there is considerably improved control of propagation and sweep of the combustion front, thus maximising the effects of both combustion and gravity drives.
  • the well arrangement of the present invention efficiently produces the mobilised liquids (i.e. softened, flowable hydrocarbons and water) and combustion flue gases;
  • the preferred embodiment of the well arrangement of the present invention that allows the swapping of functions from vent wells to injection wells all along the length of the horizontal production well as the combustion front continues to develop and reaches each in turn provides a clear advantage over alternative prior art arrangements owing to the efficiency of operation that is possible; this is due to the minimisation of the number of wells that has to be drilled and the maximisation of both the effects of both combustion and gravity drives that results; and

Abstract

L'invention porte sur un agencement de puits approprié pour la récupération d'hydrocarbures à partir d'un réservoir souterrain par un procédé de combustion in situ, ledit agencement de puits comprenant : un puits d'injection vertical s'étendant dans la partie supérieure dudit réservoir approprié pour l'injection de gaz riche en oxygène dans ledit réservoir ; un puits de production de pétrole horizontal, placé dans ledit réservoir en un endroit au-dessous de l'extrémité inférieure dudit puits d'injection et pratiquement aligné avec celle-ci ; et une pluralité de puits d'évent verticaux pour l'évacuation de gaz effluents, lesdits puits d'évent verticaux s'étendant dans la partie supérieure dudit réservoir et étant pratiquement alignés le long de la ligne dudit puits de production horizontal ; ainsi que sur un procédé de récupération d'hydrocarbures à partir d'un réservoir souterrain comprenant l'utilisation d'un réservoir souterrain doté d'au moins un agencement de puits selon la présente invention, la mise en œuvre d'une combustion in situ à l'aide dudit agencement de puits et la récupération d'hydrocarbures mobilisés à partir du puits de production horizontal.
PCT/EP2012/050403 2011-01-13 2012-01-12 Procédé pour la récupération de pétrole lourd et de bitume utilisant une combustion in situ WO2012095473A2 (fr)

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Application Number Priority Date Filing Date Title
CA2824168A CA2824168A1 (fr) 2011-01-13 2012-01-12 Procede pour la recuperation de petrole lourd et de bitume utilisant une combustion in situ
RU2013137758/03A RU2013137758A (ru) 2011-01-13 2012-01-12 Способ добычи тяжелой нефти и битума с использованием внутрипластового горения

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Application Number Priority Date Filing Date Title
GB1100549.3 2011-01-13
GBGB1100549.3A GB201100549D0 (en) 2011-01-13 2011-01-13 Process for the recovery of heavy oil and bitumen in situ combustion

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WO2012095473A2 true WO2012095473A2 (fr) 2012-07-19
WO2012095473A3 WO2012095473A3 (fr) 2013-06-27

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Cited By (5)

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WO2014075166A1 (fr) * 2012-11-14 2014-05-22 Nexen Energy Ulc Utilisation du drainage par gravité à l'aide de vapeur à l'oxygène (« sagdox ») dans la récupération de bitume dans des zones pauvres (« lz-sagdox »)
CN104594863A (zh) * 2014-11-24 2015-05-06 中国石油天然气股份有限公司 一种强化火烧油层开采油藏的方法
CN104594865A (zh) * 2014-11-25 2015-05-06 中国石油天然气股份有限公司 一种可控反向火烧油层开采稠油油藏的方法
RU2570865C1 (ru) * 2014-08-21 2015-12-10 Евгений Николаевич Александров Система для повышения эффективности эрлифта при откачке из недр пластового флюида
CN106050207A (zh) * 2016-07-29 2016-10-26 中国石油天然气股份有限公司 一种向油层中注入煤粉的设备和火烧油层的点火方法

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CN107939373B (zh) * 2018-01-17 2019-03-15 西南石油大学 一种新型火烧油层稠油开发井网结构及方法

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US20090321073A1 (en) 2006-01-03 2009-12-31 Pfefferle William C Method for in-situ combustion of in-place oils

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2014075166A1 (fr) * 2012-11-14 2014-05-22 Nexen Energy Ulc Utilisation du drainage par gravité à l'aide de vapeur à l'oxygène (« sagdox ») dans la récupération de bitume dans des zones pauvres (« lz-sagdox »)
RU2570865C1 (ru) * 2014-08-21 2015-12-10 Евгений Николаевич Александров Система для повышения эффективности эрлифта при откачке из недр пластового флюида
CN104594863A (zh) * 2014-11-24 2015-05-06 中国石油天然气股份有限公司 一种强化火烧油层开采油藏的方法
CN104594863B (zh) * 2014-11-24 2017-09-01 中国石油天然气股份有限公司 一种强化火烧油层开采油藏的方法
CN104594865A (zh) * 2014-11-25 2015-05-06 中国石油天然气股份有限公司 一种可控反向火烧油层开采稠油油藏的方法
CN106050207A (zh) * 2016-07-29 2016-10-26 中国石油天然气股份有限公司 一种向油层中注入煤粉的设备和火烧油层的点火方法
CN106050207B (zh) * 2016-07-29 2019-05-07 中国石油天然气股份有限公司 一种向油层中注入煤粉的设备和火烧油层的点火方法

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CA2824168A1 (fr) 2012-07-19
WO2012095473A3 (fr) 2013-06-27
RU2013137758A (ru) 2015-02-20

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