US20140251596A1 - Single vertical or inclined well thermal recovery process - Google Patents

Single vertical or inclined well thermal recovery process Download PDF

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Publication number
US20140251596A1
US20140251596A1 US13/785,747 US201313785747A US2014251596A1 US 20140251596 A1 US20140251596 A1 US 20140251596A1 US 201313785747 A US201313785747 A US 201313785747A US 2014251596 A1 US2014251596 A1 US 2014251596A1
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Prior art keywords
area
formation
high mobility
well
hydrocarbons
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Abandoned
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US13/785,747
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English (en)
Inventor
Simon D. Gittins
Subodh Gupta
Arun Sood
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Cenovus Energy Inc
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Cenovus Energy Inc
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Priority to US13/785,747 priority Critical patent/US20140251596A1/en
Assigned to CENOVUS ENERGY INC. reassignment CENOVUS ENERGY INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: SOOD, ARUN, GITTINS, SIMON D., GUPTA, SUBDOH
Priority to US14/195,518 priority patent/US20140251608A1/en
Priority to CA2844345A priority patent/CA2844345C/fr
Publication of US20140251596A1 publication Critical patent/US20140251596A1/en
Abandoned legal-status Critical Current

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    • 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
    • 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]
    • 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]
    • E21B43/2408—SAGD in combination with other methods
    • 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
    • E21B43/2401—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection by means of electricity
    • 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
    • E21B43/2405—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection in association with fracturing or crevice forming processes

Definitions

  • SAGD Steam Assisted Gravity Drainage
  • X-DrainTM a trademarked and patented concept by GeoSierra/Halliburton involves a single vertical well that employs a SAGD-type process. Emanating from the vertical well are a number of highly permeable vertical planes, similar to vertical hydraulic fractures, with the fractures propped or held open by a permeable propping agent. Each such plane has its own azimuth so that the effect, when viewed from above, is geometrically similar to a hub (the vertical well) and spokes (the induced multi-azimuth vertical planes). Steam is injected into the upper portion of the well and moves outward through the highly permeable propping agent contained within these multi-azimuth vertical planes to mobilize the bitumen at the faces of each plane.
  • Imperial Oil has practiced a cyclic steam stimulation process at their Cold Lake oil sands operation using vertical and inclined wells.
  • the viability of the recovery process depends on the use of formation fracturing during the injection cycle to create a largely vertical fracture that spans a significant vertical portion of the formation.
  • flow of heated fluids to the well during the production cycle takes advantage of gravity drainage to a limited degree
  • the principal means of bringing the fluids to the wellbore at commercial flow rates during the production phase of the cycle is the imposition of a pressure gradient (i.e., the creation of a pressure sink at the wellbore during its production phase).
  • a pressure gradient i.e., the creation of a pressure sink at the wellbore during its production phase.
  • the present disclosure provides a method of producing viscous hydrocarbons from a subterranean oil sands formation using a single well gravity-dominated process, comprising the steps of operating a single vertical or inclined well , the wellbore having an injection means and a production means, the injection means being positioned in the wellbore closer to the surface than the production means; providing an area of high mobility adjacent the production means; injecting a mobilizing fluid through the injection means into the formation to mobilize the viscous hydrocarbons in the formation; and substantially concurrently producing hydrocarbons through the production means; wherein the viscous hydrocarbons are produced using a predominantly gravity-dominated process.
  • the injection and/or production operations may be continuous.
  • the injection and/or production operations may proceed on an interrupted basis.
  • the injection and production means are isolated from each other in the wellbore.
  • the area in the formation adjacent the injection means is absent an induced fracture.
  • the step of providing an area of high mobility may comprise mobilizing the hydrocarbons around the production means to form the area of high mobility. Mobilizing the hydrocarbons may include introducing heat into the area. This may be done by electric or electromagnetic heating or by injecting heated fluids into the area.
  • providing the area of high mobility may comprise altering the matrix structure of the area such as through dilation of the formation area.
  • providing an area of high mobility may comprise replacing native fluids in this area with high mobility fluids such as water, light hydrocarbons, non-condensing gases and combinations thereof.
  • providing an area of high mobility comprises removing reservoir material in the area and filling the area with high permeability material such as gravel.
  • the area of high mobility may comprise a naturally occurring or pre-existing area of high mobility.
  • the gravity-dominated recovery process is steam-assisted gravity drainage (SAGD).
  • the gravity-dominated recovery process is a solvent or solvent-assisted process.
  • the single well is a vertical or substantially vertical well or an inclined well.
  • FIG. 1 is a depiction of one example of a single well completion of the present disclosure.
  • the present disclosure provides a method or process for the recovery of viscous hydrocarbons from a subterranean reservoir using a single vertical or inclined well, the performance of which is improved by the inclusion of certain features as described herein.
  • the recovery process is a gravity-dominated process but may also include drive or displacement mechanisms to a lesser degree.
  • the hydrocarbons produced using the single well gravity dominated recovery process described herein are immobile hydrocarbons or mobile hydrocarbons which benefit from a thermal recovery process, i.e. while the hydrocarbons may have some mobility, it may not be sufficient to be commercially effective for production or the mobility may be increased with a thermal recovery process to improve production.
  • the hydrocarbons are heavy oil and/or bitumen.
  • the recovery process is a thermal or thermal and solvent process.
  • steam, light hydrocarbons, hot water, or suitable combinations thereof may be used as the injection fluid.
  • these injection fluids, such as steam and light hydrocarbons may be injected as a mixture or as a succession or alternation of fluids.
  • light hydrocarbons include C 3 to C 10 hydrocarbons such as propane, butane and pentane.
  • a vertical well implies a well that is substantially or predominantly vertical, but may include sections or segments that are not vertical.
  • reference to an inclined well implies a well that is substantially or predominantly inclined to the vertical at an angle less than 90 degrees, but which is not either substantially vertical or substantially horizontal, yet may include sections or segments that are vertical or horizontal.
  • a single well may include an individual wellbore whose openings to the reservoir have been configured to allow for both injection and production, as would be contemplated in a gravity-dominated recovery process, such as a SAGD operation.
  • This disclosure provides a method for altering the abovementioned conical convergent flow geometry in the case of a single vertical or inclined well being used to carry out a gravity-dominated recovery process, such as SAGD, so that the flow restriction, and its attendant high pressure losses and deleterious effects on the steam chamber, are ameliorated. Furthermore, it does so without requiring vertical fractures, multi-azimuth vertical planes, or induced fractures adjacent the injection means, such as those described in the prior art.
  • a well is provided in a subterranean formation having an overburden 1 , a pay zone 2 with viscous hydrocarbons to be produced, and an underburden 3 .
  • a first upper set of perforations 4 are positioned near the top of the pay zone 2 and a second lower set of perforations 6 are positioned near the bottom of the pay zone.
  • a conduit 7 for injecting fluids, such as steam, into the formation extends to the upper set of perforations 4 .
  • a conduit 8 for producing fluids from the formation extends to the lower set of perforations 6 .
  • the conduits 7 and 8 may be tubing or other means known in the art.
  • conduits 7 and 8 are positioned within the well and/operated under conditions so that injected fluids from conduit 7 are not produced directly from conduit 8 through the wellbore rather than injected into the formation. This may require, for example, that conduit 7 and 8 be positioned a suitable distance apart or they may be isolated within the well by means known in the art, such as a packer 5 shown in FIG. 1 . The positioning of conduit 7 and 8 or use of other means to isolate them will depend on the particular well and formation and is within the knowledge of the skilled person.
  • the present method is a method of recovering hydrocarbons from a reservoir using a single well gravity-dominated recovery process in the presence of a high mobility zone 9 .
  • the high mobility zone 9 is located substantially opposite the producing interval of the single vertical or inclined well.
  • the high mobility zone 9 may be either pre-existing or artificially established. Operation of the recovery process occurs at a single well and, as illustrated in this aspect, involves injecting steam into the reservoir through the upper set of perforations 4 and producing mobile and mobilized fluids from the reservoir through the lower set of perforations 6 , all under conditions that allow gravity drainage to predominate.
  • the operation of the recovery process at the single well includes injecting steam through the upper set of perforations 4 while substantially concurrently producing mobile hydrocarbons from the producer at the lower set of perforations 6 .
  • Substantially concurrently means that while it is preferred that the hydrocarbons will be produced at the same time that steam or other fluids are injected into the formation, it is recognized that this is not always possible. Therefore, the injecting and producing may be sequential or alternating, and may be continuous or interrupted, during part of the recovery process. However, it is preferred that the injection and production will operated mainly on a concurrent basis.
  • a high mobility zone as a feature of the present method.
  • Mobility as used here, accords with traditional reservoir engineering usage and as such is defined as the permeability of a porous medium to a resident fluid divided by the resident fluid viscosity.
  • the high mobility zone that is a feature of the present method involves a zone that is substantially horizontal in orientation (e.g., a layer or a pancake-like structure) located in the generally lower portion of the reservoir, preferably opposite the producing perforations, where those perforations will be typically located in the lower portion of the reservoir.
  • the shape of the high mobility zone can be irregular so long as it functionally mimics or approximates a layer or pancake-like structure, as one ordinarily skilled in the art would understand.
  • a basal high mobility zone is not already present, it can be artificially induced or created.
  • the exact means of creating this zone will depend on a number of factors including the specific formation and viscosity of the hydrocarbons. It is well within the knowledge of the skilled person to select an appropriate method to create the high mobility zone.
  • the high mobility zone can be created by removing the reservoir material, as for example by mining or by drilling and under-reaming, and filling the cavity thus created with high permeability material such as, for example, gravel. If the basal portion of the reservoir initially contains, as its native fluid, a high saturation of relatively immobile bitumen, then a basal high mobility zone can be created using known techniques for increasing the mobility of resident bitumen, such as for example by heating or solvent addition.
  • the formation may be heated using electric heating, electromagnetic heating, or injecting heated fluids into the formation.
  • the high mobility zone can be created by dilation of the reservoir or other such techniques which alter matrix structure.
  • the high mobility zone can also be created by replacing native fluids in this lower region with high mobility fluids, such as water, light hydrocarbons or non-condensing gases, or combinations thereof. Any one or more of these methods as well as other known methods can be used by a skilled person to create the high mobility zone as required in a particular formation.
  • a horizontally oriented pancake-like high mobility zone that surrounds a vertical well is to be emplaced within the reservoir, using techniques such as those recited above, at a level that is opposite the producing interval.
  • the dimensions of this high mobility zone, and the make-up of the fluids which reside in its pores, can be selected by those ordinarily skilled in the art by means of simulation or developed guidelines.
  • a gravity-dominated recovery process such as SAGD, is employed, steam enters the reservoir from the wellbore through an upper open interval of the single vertical well.
  • the tendency of the mobilized bitumen to flow along a downward convergent path to the producing interval and thereby be subjected to excessive pressure loss will be countered by the presence of the basal high mobility zone, which will provide a more energy efficient conduit for the mobilized bitumen to reach the producing interval at the wellbore.
  • the presence of the basal high mobility zone either eliminates or mitigates the tendency of the converging fluids to quench or otherwise impede the progress of the steam chamber.
  • Prior art recovery methods may use a naturally occurring basal high mobility zone, such as a basal water zone, as a means of injecting or introducing heat into the reservoir.
  • a basal high mobility zone such as a basal water zone
  • the prior art methods do not utilize a high mobility feature, whether natural or created, for purposes of production or for purposes of enhancing the operation of the overlying gravity drainage mechanism.
  • a naturally occurring high mobility zone is present at or near the base of the reservoir, then certain characteristics of that zone will determine whether there is a need for alterations to the geometry or state of that zone so that it may be used as the high mobility zone in the present recovery process. For example, to ensure that hot downward-draining bitumen from the SAGD process does not cool excessively when it encounters a naturally occurring basal high mobility zone, it may be desirable to replace some portion of a native fluid, or the native fluids, resident in this basal high mobility zone with one or more different fluids. These replacing fluids can be selected for reasons of inherent properties, such as heat capacity, density, viscosity or miscibility with bitumen.
  • they can be selected for reasons of fluid state, such as would be the case if it was desired to replace a cold native fluid with a similar or alternative fluid, or fluids, that will impose a higher temperature on the high mobility zone and thence on the downward-draining bitumen.
  • the presence of a high mobility zone will prevent or ameliorate flow effects that are deleterious to productivity.
  • SAGD recovery process the presence of a high mobility zone will facilitate the drainage of oil and water to the producing interval of the well.
  • the highly convergent flow patterns associated with a single vertical or inclined well process will result in hold up of the oil and water, and consequent quenching or reduction in size of the steam chamber.
  • CA 2,732,198 requires the use of two fractured zones, one adjacent to the injector and one adjacent to the producer. However, it has been found by the present inventors that two high mobility zones are not necessary. Having only one high mobility zone adjacent the producer is sufficient to aid in hydrocarbon production using the vertical well as disclosed herein. Further, it is not necessary to fracture the formation. A high mobility zone adjacent to the producer can be created using other methods and still produce beneficial results in recovering hydrocarbons.
  • the present disclosure requires only a single high mobility feature, either created or naturally present, opposite the producing interval.
  • the additional required feature in CA 2,723,198 (Shuxing) of a fracture created opposite an upper set of perforations would allow steam injected at these upper perforations to move some lateral distance outward from the wellbore.
  • the present disclosure achieves this same lateral spreading without need of an additional fracture, as required by Shuxing.
  • steam injected at a set of perforations with no associated fracture will not only move upwards, but will also flare laterally outwards, thereby providing a broad region within which bitumen can be mobilized.
  • the present disclosure achieves lateral extension of mobility within the reservoir without need of a fracture opposite the upper perforations.
  • the disclosed recovery process may also be applied at an inclined well.
  • it may be desirable to modify, especially in a horizontal aspect, the geometry of the high mobility zone, firstly with respect to the concentricity or eccentricity of its placement relative to the point or region over which it intersects the wellbore, and secondly with respect to its compass orientation.
  • a vertical or inclined well in a single well SAGD process may be influenced by local lithology, as well as by operating considerations. This would include the inclination of the well itself with respect to the vertical, the placement of the injection and production openings along the wellbore and the geographic placement and horizontal extent of the basal high mobility zone. With respect to the placement of the injection and production openings, it should be clearly understood that the present process contemplates the possibility of not just a single set of injection openings and a single set of production openings.
  • the present process reflects a well configuration, whether vertical or inclined, wherein the producing interval is substantially opposite the basal high mobility zone.
  • the open or completion interval at the producer is at or below the base of the pay, so that the gravity mechanism can be operative vertically throughout the pay. This is in contrast to the situation in horizontal well SAGD where the horizontal producer is not situated at the very base of the pay but rather is typically located some distance above the base of pay and, as such, may not recover substantial amounts of underlying oil.
  • gravity-dominated thermally based recovery processes such as SAGD.
  • gravity-dominated solvent-assisted processes such as for example the Solvent Aided Process (SAP), which employs a suitable hydrocarbon solvent, or combinations thereof, in conjunction with steam, will also function beneficially with the present process.
  • SAP Solvent Aided Process
  • Still another gravity-dominated recovery process alternative involves introducing a suitable solvent and water into the reservoir and heating the mixture as appropriate.
  • additives that may also be employed in the practice of the present method include non-condensing gases and surfactants.
  • a start-up process is required to established communication between the injector and producer wells.
  • start-up processes such as for example hot fluid wellbore circulation, the use of selected solvents such as xylene, or the application of geomechanical techniques such as dilation. Techniques such as these can also be employed as a means of accelerating start-up in the present recovery process.

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US13/785,747 2013-03-05 2013-03-05 Single vertical or inclined well thermal recovery process Abandoned US20140251596A1 (en)

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US13/785,747 US20140251596A1 (en) 2013-03-05 2013-03-05 Single vertical or inclined well thermal recovery process
US14/195,518 US20140251608A1 (en) 2013-03-05 2014-03-03 Single vertical or inclined well thermal recovery process
CA2844345A CA2844345C (fr) 2013-03-05 2014-03-03 Procede de recuperation thermique de puits inclines ou verticaux uniques

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Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20140096961A1 (en) * 2010-05-11 2014-04-10 R.I.I. North America Inc. Thermal mobilization of heavy hydrocarbon deposits
US10487636B2 (en) 2017-07-27 2019-11-26 Exxonmobil Upstream Research Company Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes
US11002123B2 (en) 2017-08-31 2021-05-11 Exxonmobil Upstream Research Company Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation
US11142681B2 (en) 2017-06-29 2021-10-12 Exxonmobil Upstream Research Company Chasing solvent for enhanced recovery processes
US11261725B2 (en) 2017-10-24 2022-03-01 Exxonmobil Upstream Research Company Systems and methods for estimating and controlling liquid level using periodic shut-ins

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN110541693B (zh) * 2019-08-29 2021-09-28 中国石油化工股份有限公司 低渗透厚层砂岩油藏co2驱泄复合开发方法

Citations (6)

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Publication number Priority date Publication date Assignee Title
US3958636A (en) * 1975-01-23 1976-05-25 Atlantic Richfield Company Production of bitumen from a tar sand formation
US5826655A (en) * 1996-04-25 1998-10-27 Texaco Inc Method for enhanced recovery of viscous oil deposits
US20030173072A1 (en) * 2001-10-24 2003-09-18 Vinegar Harold J. Forming openings in a hydrocarbon containing formation using magnetic tracking
US20070284108A1 (en) * 2006-04-21 2007-12-13 Roes Augustinus W M Compositions produced using an in situ heat treatment process
US20100089584A1 (en) * 2008-10-13 2010-04-15 David Booth Burns Double insulated heaters for treating subsurface formations
US7798221B2 (en) * 2000-04-24 2010-09-21 Shell Oil Company In situ recovery from a hydrocarbon containing formation

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3958636A (en) * 1975-01-23 1976-05-25 Atlantic Richfield Company Production of bitumen from a tar sand formation
US5826655A (en) * 1996-04-25 1998-10-27 Texaco Inc Method for enhanced recovery of viscous oil deposits
US7798221B2 (en) * 2000-04-24 2010-09-21 Shell Oil Company In situ recovery from a hydrocarbon containing formation
US20030173072A1 (en) * 2001-10-24 2003-09-18 Vinegar Harold J. Forming openings in a hydrocarbon containing formation using magnetic tracking
US20070284108A1 (en) * 2006-04-21 2007-12-13 Roes Augustinus W M Compositions produced using an in situ heat treatment process
US20100089584A1 (en) * 2008-10-13 2010-04-15 David Booth Burns Double insulated heaters for treating subsurface formations

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20140096961A1 (en) * 2010-05-11 2014-04-10 R.I.I. North America Inc. Thermal mobilization of heavy hydrocarbon deposits
US9534482B2 (en) * 2010-05-11 2017-01-03 R.I.I. North America Inc. Thermal mobilization of heavy hydrocarbon deposits
US11142681B2 (en) 2017-06-29 2021-10-12 Exxonmobil Upstream Research Company Chasing solvent for enhanced recovery processes
US10487636B2 (en) 2017-07-27 2019-11-26 Exxonmobil Upstream Research Company Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes
US11002123B2 (en) 2017-08-31 2021-05-11 Exxonmobil Upstream Research Company Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation
US11261725B2 (en) 2017-10-24 2022-03-01 Exxonmobil Upstream Research Company Systems and methods for estimating and controlling liquid level using periodic shut-ins

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CA2844345A1 (fr) 2014-09-05

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