WO1997012119A1 - Procede modifie de drainage a commande continue - Google Patents

Procede modifie de drainage a commande continue Download PDF

Info

Publication number
WO1997012119A1
WO1997012119A1 PCT/US1995/012578 US9512578W WO9712119A1 WO 1997012119 A1 WO1997012119 A1 WO 1997012119A1 US 9512578 W US9512578 W US 9512578W WO 9712119 A1 WO9712119 A1 WO 9712119A1
Authority
WO
WIPO (PCT)
Prior art keywords
wells
array
hydrocarbons
formation
fluid
Prior art date
Application number
PCT/US1995/012578
Other languages
English (en)
Inventor
William J. Mccaffrey
Grant W. Boyd
Andrew J. Fox
Wayne P. Kraus
Bryan D. Weir
Original Assignee
Amoco Corporation
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 Amoco Corporation filed Critical Amoco Corporation
Priority to MX9603323A priority Critical patent/MX9603323A/es
Priority to PCT/US1995/012578 priority patent/WO1997012119A1/fr
Priority to US08/682,644 priority patent/US5803171A/en
Publication of WO1997012119A1 publication Critical patent/WO1997012119A1/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
    • E21B43/16—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
    • 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
    • E21B43/30—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

Definitions

  • This invention relates to the general subject of methods for recovering hydrocarbons from subterranean formations, and in particular, to methods and processes for recovering heavy oil by means of injecting fluids into the formation.
  • liquid hydrocarbons commonly known as crude oils
  • Crude oils with an API gravity of 22 degrees or less are generally considered to be heavy crude oils.
  • the market value of heavy crude oils has been traditionally lower than the value of lighter crude oils.
  • hydrocarbon bearing formations can varying in physical composition from consolidated rock to unconsolidated sands, which may affect permeability and porosity.
  • Natural layering and mixing of a variety of natural impermeable materials within a subterranean formation can also occur.
  • the presence of diagenetic clay, or impermeable partial barriers such as mud or mud stone laminations, or calcite lenses within a subterranean formation may affect the ability of hydrocarbons to flow within the formation.
  • the current state of the art reflects both an evolution of technology through general innovative improvement as well as innovation to meet conditions encountered in specific heavy crude, oil bearing subterranean formations.
  • Keplinger, C.H. "Economic Considerations Affecting Steam Flood Prospects", Producers Monthly. Vol. 29, No. 5, May 1965, pp. 14- 20,
  • the Ong Patent teaches either a gravity drainage effect, or a vertical or horizontal sweep of the oil within the reservoir.
  • the Ong Patent teaches the injection of steam through horizontal injection wells located above horizontal production wells, at different pressures with the intention of creating a mild pressure drive to supplement gravity drainage of oil within the reservoir to lower production wells.
  • the Brannan Patent teaches a method combining steam assisted gravity drainage and a significant vertical and horizontal sweeping of oil within the reservoir.
  • the process and invention taught to the Ong Patent is intended to be applied to the production of oil from a reservoir where the oil is sufficiently immobile such that the reservoir is considered impermeable.
  • the process and invention taught by the Brannan Patent is intended to be applied to the production of oil from a reservoir containing oil which is mobile to some extent within the reservoir prior to the application of such process and invention.
  • the Brannan Patent teaches that the use of horizontal injection and production wells in a pattern where the horizontal sections of the wells are parallel but offset from one another in the vertical plane, with the horizontal section of the injection wells being placed in the reservoir above the horizontal sections of the production wells, with the horizontal sections of the production wells being drilled in the reservoir at a point between the base of the reservoir and the midpoint of the reservoir. Steam is injected on a continuous basis through the upper injection wells, while oil is produced through the lower production wells, at a rate which greater than the cumulative rate at which steam is injected into the upper horizontal wells.
  • the Ong Patent teaches the initial and continuous injection of steam through the injection wells in the array, with the application of out of sync CSS to only the production wells in the array for the purpose of creating a permeable path between the injection wells and the production wells. Furthermore, the Ong Patent teaches that CSS may be applied to the production wells either out of sync or in sync, with no stated preferred method or any appreciation of any benefit of such an application.
  • a method for producing hydrocarbons from a subterranean formation.
  • the method comprises the steps of: (i) building an array of at least three horizontal wells, wherein the ho ⁇ zontal sections of all wells in the array are generally located in the bottom-half of the formation, are relatively parallel to one another, and are essentially horizontally co-planar with each other; (ii) establishing injectivity in the formation; (iii) creating thermal and pressure communication between adjacent wells in the array without inducing fractures in the formation; (iv) continuously injecting a fluid through the first outer well in the array; continuously producing hydrocarbons and associated fluids through the well immediately adjacent to such outer well; and (vi) simultaneously applying the steps of continuously injecting and continuously producing to adjacent remaining pairs of wells in the array so that each well in the array subject to continuous injection is offset only by wells subject to continuous production, wherein the hydrocarbons and associated fluids are produced at a cumulative rate of production such that a pressure differential is established between the wells in the array
  • the present invention teaches the application of CSS to groups or arrays of three or more substantially coplanar and parallel horizontal wells, by conducting the injection phase, soak period and production phase of each well, "out of sync" with the wells located immediately adjacent to it in the array.
  • the invention maximizes the benefits of using a heated fluid for injection purposes.
  • the present invention also facilitates recovery of oil from the reservoir through the gravity drainage of oil within the reservoir in combination with the vertical and horizontal sweeping of such oil, as taught by the Brannan Patent, without the need to drill upper injection wells.
  • a fluid such as steam, a solvent or a gas
  • a fluid can be injected on a continuous basis while fluid is produced on a continuous basis from the formation following the method described in the first paragraph of this summary.
  • the present invention teaches that, where the initial application of CSS is required to create thermal and pressure communication between injection and production wells in the array, it is preferable to apply CSS out of sync to both the injection and production wells in the array.
  • a key advantage of the application of out of sync CSS to all wells in the array is that thermal and pressure communication between adjacent wells is established faster at a lower capital cost than if all wells were subject to each phase of the CSS process (i.e., injection, soak period and production) at the same time.
  • the reservoir may be pressured-up and such pressurization maintained over the whole period of time that CSS is being applied.
  • each well undergoing the fluid production phase of the CSS cycle can benefit from increased fluid production as a result of the pressure drive created by the injection of fluids from wells that are adjacent to it and that are undergoing the fluid injection phase of the cycle.
  • the use of out of sync CSS as taught by the invention facilitates the use smaller capacity steam generation equipment, providing immediate economic benefits through reduction of capital costs.
  • the present invention may be practiced as an alternative to the process and invention taught by the Brannan Patent. This would occur, for example, where the reservoir is characterized as having partial, non-continuous impermeable barriers which would hinder the vertical flow of fluids, or where the viscosity of the heavy crude oil within the reservoir may vary considerably over a large range.
  • the preferred method of the present invention is to conduct CSS only in respect of horizontal wells where the horizontal section of each well is located in the lower half of the reservoir. This maximizes the efficiencies of using CSS by preventing the formation of a steam chamber that prematurely contacts the top of the reservoir. It also exposes a greater portion of the vertical cross section of the reservoir at the point of injection to the thermal effects of steam injection.
  • Yet another advantage of the present invention is the savings of electrical power.
  • the surface pumping equipment i.e., pumpjacks used to produce fluids from the wells
  • a significant savings can be realized through the reduction in power usage resulting from not starting up and running the pumpjacks for all of the wells in the array at the same time.
  • FIG. 1 shows by cross section the approximate geometry of the horizontal sections wells drilled as taught by U.S. 5,273,11 1 ;
  • FIG. 2 shows by cross section the approximate geometry of the horizontal sections of the wells drilled as taught by the present invention
  • FIG's. 3 and 4 show by cross section the development of a steam chamber around each horizontal well by the application of CSS in the case of the wells drilled as taught by U.S. 5,273,11 1 (FIG. 3) and as thought by the present invention (FIG. 4);
  • FIG's. 5 and 6 show by cross section the application of CSI to the injection wells as taught by U.S. 5,273,11 1 (FIG. 5) and as thought by the present invention (FIG. 6), with continuous production from the production wells in both cases; and
  • FIG's. 7 and 8 show by cross section the application of CSS to wells drilled in an array as taught by the present invention, with the injection/production phase for each well being out of sync with the wells adjacent to and offsetting such well.
  • FIG. 2 illustrates an array consisting of at least three horizontal wells 10a, 10b and 10c is drilled into a formation 12 having a reservoir containing heavy crude oil.
  • the formation 12 has a top 12t and a bottom 12b.
  • These wells are drilled using means known in the art.
  • the wells are drilled so that the horizontal section of each well is located between the bottom and midpoint of the reservoir.
  • the wells are drilled so that the horizontal sections of all wells in the array are approximately equidistant, relatively parallel to one another, and horizontally coplanar with each other.
  • the present invention allows for the horizontal section of the wells comprising the array to deviate from true parallel and true co-planar by as much as 5 meters.
  • FIG. 1 of the present application corresponds to FIG. 1 of U.S. 5,273,11 1.
  • the wells of FIG. 1 resemble the end points of the letter "W”. Spacing between the horizontal wells in the array of Brannan et al. is not specified and may be varied depending on the nature of the reservoir and the heavy crude oil contained therein.
  • Continuous Steam Injection can begin with the outer wells 10a and 10c in the array being used as injectors and the inner or center well 10b being used to continuously produce heavy crude oil (See FIG. 6).
  • the outer wells may be used for continuous production and the inner well may be used for CSI.
  • the present invention facilitates both methods, with the choice of method being determined by the nature of the particular reservoir in which the process is applied, and the characteristics of the heavy crude oil contained therein.
  • the main rule to follow in practicing the invention is that: while any well is adjacent to a particular well and is on continuous production of fluids, then the particular well in question must be used for continuous injection of fluids; and while any well is adjacent to a particular well and is being used for continuous fluid injection, the particular well in question must be used for continuous fluid production.
  • steam is injected at pressures below the fracture pressure of the formation.
  • the method also comprises Continuous Production (CP) occurring at a rate greater than the cumulative rate of CSI.
  • CP Continuous Production
  • every second well (i.e., the even-numbered wells) in the array is used as an injector during CSI, and the remaining wells (i.e., the odd-numbered wells or the wells "off-setting" the injectors) are used to continuously produce heavy crude oil.
  • the remaining wells i.e., the odd-numbered wells or the wells "off-setting" the injectors.
  • the present invention teaches the application of CSS to all wells in the array in the following described manner until such communication is established:
  • CSS is applied simultaneously to all wells in the array using means that are known in the art, for at least one steam/production cycle to create voidage within the reservoir and provide sufficient injectivity. This causes the formation of steam chambers 14a, 14b and 14c (See FIG. 4) within the reservoir formation 12. Injection pressures are below reservoir fracture pressure. Depending on reservoir conditions and the nature of the heavy crude oil contained therein, further cycles of CSS may be required.
  • CSS of all wells in the array continues with the steam injection and production cycle being applied to each well, "out of sync" with the well or wells adjacent to such well, so that while steam is being injected through a particular well, production is being taken from adjacent wells (See FIG's. 7 and 8).
  • the vertical arrows denote the direction of fluid flow to and from the wells 10a, 10b and 10c.
  • FIG. 7 the center well 10b is in the injection phase (steam being injected through such well).
  • the wells 10a and 10c beside it are in the production phase (fluids being produced through such wells).
  • FIG. 8 the situation is reversed.
  • the reservoir may be pressured-up and pressurization maintained over the whole period of time that CSS is being applied.
  • the wells in the array were cycled simultaneously (i.e., "in sync") between the injection and production phases, then, by the end of the production phase, the drop in reservoir pressure, from the level achieved at the end of the injection phase, would occur sooner and would be larger.
  • all wells in the array were placed on the sar ⁇ e phase of CSS and cycled at the same time, clearly a much larger steam generator would be required. More importantly, one would not be able to build and maintain pressure in the reservoir.
  • CSI and CP may be commenced with the wells in the array, in the manner described above (See FIG. 6).
  • steam is injected into the two outer wells 10a and 10c at a pressure below the fracture pressure of the reservoir using conventional means known in the art.
  • CP from the production well 10b is conducted at a rate greater than the cumulative rate of steam injection into the injection wells.
  • One recommended minimum ratio for rate of injection to rate production is 1 to 1.5. However, the ratio can vary significantly depending on the nature of the reservoir, the native viscosity of the heavy crude oil and the type of fluid injected, as long as the rate of fluid production exceeds the rate of injection.
  • additional horizontal wells may be drilled with the horizontal sections thereof being formed between, parallel to and co-planar with the horizontal sections of the existing wells in the array. Such additional wells would be utilized as either injectors for CSI or producers for CP as reservoir conditions require.

Landscapes

  • 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)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

La présente invention concerne un procédé de production d'hydrocarbures provenant d'une formation souterraine. Ce procédé comprend les étapes suivantes: constitution d'un ensemble d'au moins trois puits horizontaux (10a, 10b et 10c); établissement de l'injectivité dans la formation; établissement d'une communication entre des sections horizontales voisines de puits (10a, 10b et 10c) dans l'ensemble en question; injection d'un liquide par la partie horizontale d'un puits extérieur (10a) pendant la production d'hydrocarbures et de liquides associés par la section horizontale d'un puits (10b) immédiatement voisin du puits extérieur, avec exécution simultanée des opérations d'injection et de production pour des couples de puits (10b et 10c) restants voisins, dans l'ensemble précité, de telle sorte que, par rapport à tout puits particulier (10b) qu'on est en train d'utiliser pour l'injection de liquide, tout puits (10a et 10c) de cet ensemble qui en est immédiatement voisin est utilisé à ce moment pour la production de liquide. Avec ce procédé, les hydrocarbures et les liquides associés sont produits avec un débit cumulé, pour tout l'ensemble, qui établit une différence de pression entre les puits (10a, 10b et 10c) de l'ensemble.
PCT/US1995/012578 1995-09-29 1995-09-29 Procede modifie de drainage a commande continue WO1997012119A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
MX9603323A MX9603323A (es) 1995-09-29 1995-09-29 Proceso de drenaje por arrastre continuo modificado.
PCT/US1995/012578 WO1997012119A1 (fr) 1995-09-29 1995-09-29 Procede modifie de drainage a commande continue
US08/682,644 US5803171A (en) 1995-09-29 1995-09-29 Modified continuous drive drainage process

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US1995/012578 WO1997012119A1 (fr) 1995-09-29 1995-09-29 Procede modifie de drainage a commande continue

Publications (1)

Publication Number Publication Date
WO1997012119A1 true WO1997012119A1 (fr) 1997-04-03

Family

ID=22249876

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US1995/012578 WO1997012119A1 (fr) 1995-09-29 1995-09-29 Procede modifie de drainage a commande continue

Country Status (2)

Country Link
MX (1) MX9603323A (fr)
WO (1) WO1997012119A1 (fr)

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2025862A1 (fr) * 2007-08-17 2009-02-18 Shell Internationale Research Maatschappij B.V. Procédé pour l'amélioration de la récupération de pétrole brut lourd par la combustion in situ en présence d'aquifères forts
WO2013075206A1 (fr) * 2011-11-25 2013-05-30 Archon Technologies Ltd. Procédé de récupération de pétrole par balayage en ligne dans un puits horizontal
US10012064B2 (en) 2015-04-09 2018-07-03 Highlands Natural Resources, Plc Gas diverter for well and reservoir stimulation
US10344204B2 (en) 2015-04-09 2019-07-09 Diversion Technologies, LLC Gas diverter for well and reservoir stimulation
US10982520B2 (en) 2016-04-27 2021-04-20 Highland Natural Resources, PLC Gas diverter for well and reservoir stimulation

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4249777A (en) * 1979-07-24 1981-02-10 The United States Of America As Represented By The Secretary Of The Interior Method of in situ mining
US4598770A (en) * 1984-10-25 1986-07-08 Mobil Oil Corporation Thermal recovery method for viscous oil
US4850429A (en) * 1987-12-21 1989-07-25 Texaco Inc. Recovering hydrocarbons with a triangular horizontal well pattern
US5033546A (en) * 1988-12-30 1991-07-23 Institut Francais Du Petrole Production simulation process by pilot test in a hydrocarbon deposit
US5273111A (en) * 1991-07-03 1993-12-28 Amoco Corporation Laterally and vertically staggered horizontal well hydrocarbon recovery method
US5318124A (en) * 1991-11-14 1994-06-07 Pecten International Company Recovering hydrocarbons from tar sand or heavy oil reservoirs

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4249777A (en) * 1979-07-24 1981-02-10 The United States Of America As Represented By The Secretary Of The Interior Method of in situ mining
US4598770A (en) * 1984-10-25 1986-07-08 Mobil Oil Corporation Thermal recovery method for viscous oil
US4850429A (en) * 1987-12-21 1989-07-25 Texaco Inc. Recovering hydrocarbons with a triangular horizontal well pattern
US5033546A (en) * 1988-12-30 1991-07-23 Institut Francais Du Petrole Production simulation process by pilot test in a hydrocarbon deposit
US5273111A (en) * 1991-07-03 1993-12-28 Amoco Corporation Laterally and vertically staggered horizontal well hydrocarbon recovery method
US5318124A (en) * 1991-11-14 1994-06-07 Pecten International Company Recovering hydrocarbons from tar sand or heavy oil reservoirs

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2025862A1 (fr) * 2007-08-17 2009-02-18 Shell Internationale Research Maatschappij B.V. Procédé pour l'amélioration de la récupération de pétrole brut lourd par la combustion in situ en présence d'aquifères forts
WO2013075206A1 (fr) * 2011-11-25 2013-05-30 Archon Technologies Ltd. Procédé de récupération de pétrole par balayage en ligne dans un puits horizontal
US10012064B2 (en) 2015-04-09 2018-07-03 Highlands Natural Resources, Plc Gas diverter for well and reservoir stimulation
US10344204B2 (en) 2015-04-09 2019-07-09 Diversion Technologies, LLC Gas diverter for well and reservoir stimulation
US10385258B2 (en) 2015-04-09 2019-08-20 Highlands Natural Resources, Plc Gas diverter for well and reservoir stimulation
US10385257B2 (en) 2015-04-09 2019-08-20 Highands Natural Resources, PLC Gas diverter for well and reservoir stimulation
US10982520B2 (en) 2016-04-27 2021-04-20 Highland Natural Resources, PLC Gas diverter for well and reservoir stimulation

Also Published As

Publication number Publication date
MX9603323A (es) 1997-03-29

Similar Documents

Publication Publication Date Title
US5803171A (en) Modified continuous drive drainage process
US5085276A (en) Production of oil from low permeability formations by sequential steam fracturing
US20210277757A1 (en) Pressure assisted oil recovery
US4390067A (en) Method of treating reservoirs containing very viscous crude oil or bitumen
US10024148B2 (en) Hydrocarbon recovery process exploiting multiple induced fractures
CA2046107C (fr) Methode de recuperation d'hydrocarbures dans un puits horizontal decale lateralement et verticalement
US4460044A (en) Advancing heated annulus steam drive
US5305829A (en) Oil production from diatomite formations by fracture steamdrive
US3692111A (en) Stair-step thermal recovery of oil
CA2651527C (fr) Methode et systeme visant a ameliorer un procede de recuperation utilisant un puits de forage horizontal ou davantage
US4487260A (en) In situ production of hydrocarbons including shale oil
US6729394B1 (en) Method of producing a communicating horizontal well network
US9410406B2 (en) Targeted oriented fracture placement using two adjacent wells in subterranean porous formations
US20100170672A1 (en) Method of and system for hydrocarbon recovery
WO1998004807A1 (fr) Procede d'extraction a la vapeur dans un puits unique
US10995596B2 (en) Single well cross steam and gravity drainage (SW-XSAGD)
CA2744749C (fr) Drainage par gravite dans le plan basal
CA2902085C (fr) Systeme de puits separes hydrauliquement et procede de recuperation
WO1998050679A1 (fr) Reseau de puits horizontaux communiquants
US4986352A (en) Intermittent steam injection
US4566537A (en) Heavy oil recovery
CA1310581C (fr) Methode permettant d'accroitre l'efficacite du deplacement superficiel du brutdu cours d'un procede d'extraction de petrole par injection
CA2823598C (fr) Soutenement de fractures orientees ciblees utilisant deux puits adjacents dans des formations poreuses souterraines
WO1997012119A1 (fr) Procede modifie de drainage a commande continue
CA2180267A1 (fr) Procede modifie de drainage a commande continue

Legal Events

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

Ref document number: 2180267

Country of ref document: CA

WWE Wipo information: entry into national phase

Ref document number: 08682644

Country of ref document: US

WWE Wipo information: entry into national phase

Ref document number: PA/a/1996/003323

Country of ref document: MX

AK Designated states

Kind code of ref document: A1

Designated state(s): CA MX US