WO2019241457A1 - Systèmes et procédés de commande de géométries de fracture à l'aide de tunnels de perforation étendus - Google Patents

Systèmes et procédés de commande de géométries de fracture à l'aide de tunnels de perforation étendus Download PDF

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Publication number
WO2019241457A1
WO2019241457A1 PCT/US2019/036870 US2019036870W WO2019241457A1 WO 2019241457 A1 WO2019241457 A1 WO 2019241457A1 US 2019036870 W US2019036870 W US 2019036870W WO 2019241457 A1 WO2019241457 A1 WO 2019241457A1
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WIPO (PCT)
Prior art keywords
extended perforation
perforation tunnels
well completion
formation
extended
Prior art date
Application number
PCT/US2019/036870
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English (en)
Inventor
Hai Liu
Dmitriy Ivanovich Potapenko
Original Assignee
Schlumberger Technology Corporation
Schlumberger Canada Limited
Services Petroliers Schlumberger
Schlumberger Technology B.V.
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Application filed by Schlumberger Technology Corporation, Schlumberger Canada Limited, Services Petroliers Schlumberger, Schlumberger Technology B.V. filed Critical Schlumberger Technology Corporation
Publication of WO2019241457A1 publication Critical patent/WO2019241457A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/006—Measuring wall stresses in the borehole
    • 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
    • E21B43/11—Perforators; Permeators
    • E21B43/112—Perforators with extendable perforating members, e.g. actuated by fluid means
    • 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
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/18—Drilling by liquid or gas jets, with or without entrained pellets

Definitions

  • the present disclosure generally relates to systems and methods for controlling fracture geometries and, more particularly, to systems and methods for controlling fracture geometries using extended perforation tunnels extending from wellbores.
  • Hydraulic fracturing is an efficient way of increasing productivity of wells in oil and gas bearing formations. Hydraulic fracturing is based on pumping fracturing fluid at high pressure into the wellbore to create localized fractures in the formation to increase the production rates of hydrocarbons.
  • the fracturing fluid may include proppant (e.g., sand, bauxite, ceramic, nut shells, etc.) to hold the fractures open after the frac pump pressure is removed, thereby permitting hydrocarbons to flow from the fractured formation into the wellbore.
  • proppant e.g., sand, bauxite, ceramic, nut shells, etc.
  • the fracturing fluid may include hydrochloric acid and/or other chemicals intended to etch the fracture faces to improve the flow capacity of the fractures.
  • hydrochloric acid and/or other chemicals intended to etch the fracture faces to improve the flow capacity of the fractures.
  • other types of fracture treatments may be utilized including, but not limited to, acid fracturing, slick water fracturing, foam fracturing, proppant-free fracturing, water or steam injection, and others.
  • the overall process for creating a hydraulically fractured wellbore includes two or three primary operations; a drilling operation, an optional casing operation, and hydraulic fracturing operations.
  • Hydraulic fracturing operations were initially performed in single-stage, vertical or near-vertical wells.
  • hydraulic fracturing operations became predominantly utilized in horizontal or near-horizontal sections of single- and multi-stage wells, such as to improve productivity of these horizontal or near-horizontal well sections.
  • Certain embodiments of the present disclosure include a method that includes defining a well completion program comprising creation and stimulation of one or more extended perforation tunnels for a well. The method also includes controlling a fracture geometry of a formation zone in accordance with the well completion program using the one or more extended perforation tunnels oriented in the formation zone prior to fracturing.
  • certain embodiments of the present disclosure include one or more non- transitory computer-readable storage media storing instructions which, when executed, cause at least one processor to perform operations that include defining a well completion program comprising creation and stimulation of one or more extended perforation tunnels for a well.
  • the operations also include controlling a fracture geometry of a formation zone in accordance with the well completion program using the one or more extended perforation tunnels oriented in the formation zone prior to fracturing.
  • FIG. l is a schematic illustration of a well system extending into a subterranean formation, in accordance with embodiments of the present disclosure
  • FIG. 2 is a diagrammatic illustration showing an example of alpha and beta angles at which a given extended perforation tunnel may extend from a borehole, in accordance with embodiments of the present disclosure
  • FIG. 3 is a schematic illustration of a well system having a plurality of extended perforation tunnels extending from a borehole to deliver stimulating fluid, in accordance with embodiments of the present disclosure
  • FIG. 4 is a schematic sectional view of at least a portion of a radial drilling tool system, in accordance with embodiments of the present disclosure
  • FIG. 5 is a schematic view of the radial drilling tool system illustrated in FIG. 4 in a different stage of operation, in accordance with embodiments of the present disclosure
  • FIG. 6 is a schematic view of the radial drilling tool system illustrated in FIGS. 4 and 5 in a different stage of operation, in accordance with embodiments of the present disclosure
  • FIG. 7 is a schematic sectional view of at least a portion of another example radial drilling tool system, in accordance with embodiments of the present disclosure.
  • FIG. 8 is a three-dimensional element of a subterranean formation having X-Y-Z coordinates and being subjected to local stresses, in accordance with embodiments of the present disclosure
  • FIG. 9 is a schematic view of at least a portion of an example wellbore system that includes a plurality of extended perforation tunnels, in accordance with embodiments of the present disclosure.
  • FIG. 10 is a flow chart diagram of at least a portion of a method for defining a program for completing an oil and gas well extending through a subterranean formation, in accordance with embodiments of the present disclosure
  • FIGS. 11-13 illustrate forecasted (i.e., modeled) representations of expected geometries of formation fractures created during fracturing operations, in accordance with embodiments of the present disclosure
  • FIGS. 14-17 are graphs illustrating cumulative oil production profiles for certain fracture geometries, in accordance with embodiments of the present disclosure.
  • FIG. 18 is a block diagram of at least a portion of a processing device configured to execute instructions to implement the techniques described herein.
  • the terms“connect,”“connection,”“connected,”“in connection with,” and“connecting” are used to mean“in direct connection with” or“in connection with via one or more elements”; and the term“set” is used to mean“one element” or“more than one element.”
  • the terms“couple,”“coupling,”“coupled,”“coupled together,” and “coupled with” are used to mean“directly coupled together” or“coupled together via one or more elements.”
  • the terms“up” and“down,”“uphole” and“downhole”, “upper” and“lower,”“top” and“bottom,” and other like terms indicating relative positions to a given point or element are utilized to more clearly describe some elements.
  • these terms relate to a reference point as the surface from which drilling operations are initiated as being the top (e.g., uphole or upper) point and the total depth along the drilling axis being the lowest (e.g., downhole or lower) point, whether the well (e.g., wellbore, borehole) is vertical, horizontal or slanted relative to the surface.
  • a well may be created in a subterranean region by drilling a borehole (e.g., a generally vertical wellbore).
  • a borehole e.g., a generally vertical wellbore.
  • at least one extended perforation tunnel may be created and oriented to extend outwardly from the borehole at least a certain amount (e.g., at least 10 feet, or 3.05 meters) into a formation surrounding the borehole.
  • the extended perforation tunnels may be created to extend outwardly from the borehole at least 5 feet (1.5 meters), at least 10 feet (3.05 meters), at least 15 feet (4.6 meters), at least 20 feet (6.1 meters), or even substantially longer than 20 feet (6.1 meters) (e.g., up to or even greater than 1,600 feet (488 meters), as described in greater detail herein).
  • the borehole may be oriented generally vertically and the extended perforation tunnels may extend outwardly generally horizontally.
  • embodiments may utilize a deviated (e.g., at least partially horizontal) borehole with extended perforation tunnels extending outwardly from the deviated borehole.
  • the extended perforation tunnels may be oriented generally horizontally, generally vertically, or at any desired orientations therebetween.
  • the term“extended perforation tunnel” is intended to mean a secondary borehole that extends from a main borehole at a substantially constant angle for at least 5 feet (1.5 meters), at least 10 feet (3.05 meters), at least 15 feet (4.6 meters), at least 20 feet (6.1 meters), or even substantially longer than 20 feet (6.1 meters) (e.g., up to or even greater than 1,600 feet (488 meters), as described in greater detail herein).
  • Conventional lateral boreholes are typically created by gradually veering from a main borehole at a continually increasing angle (i.e., such that the main borehole and the lateral borehole generally form a curved intersection between the two).
  • the extended perforation tunnels described herein directly extend from a main borehole at a non-zero angle (e.g., contrary to conventional lateral boreholes that extend from a main borehole at an angle that gradually increases from 0 degrees).
  • the non-zero angle directly formed between an extended perforation tunnel and a corresponding main borehole may be an angle substantially greater than 0 degrees, such as greater than 20 degrees, greater than 30 degrees, greater than 45 degrees, greater than 60 degrees, between 60 degrees and 90 degrees, between 70 degrees and 90 degrees, or between 80 degrees and 90 degrees, as described in greater detail herein, As such, the extended perforation tunnels described herein are not connected to a main borehole by a curved intersection, contrary to conventional lateral boreholes.
  • the extended perforation tunnels described herein form relatively sharp transitions from their respective main boreholes.
  • the term “substantially constant angle” is intended to mean an angle that varies along a length of an extended perforation tunnel by no more than a very small amount, such as 5 degrees, 4 degrees, 3 degrees, 2 degrees, 1 degree, or even less.
  • the orientation of the extended perforation tunnels may be selected such that each extended perforation tunnel extends at a desired angle with respect to a direction of principal stresses in the formation.
  • the tunnel azimuths may be oriented in a direction of maximum horizontal stress, minimum horizontal stress, or at a desired other angle with respect to the maximum horizontal stress.
  • the tunnel azimuths (as well as the borehole azimuth) may be relatively constant in certain applications, but they may also vary in other applications, for example, to achieve a desired positioning with respect to a hydrocarbon bearing target zone in a formation.
  • a fracture stimulation of the extended perforation tunnels may be performed to create a network of fractures.
  • a hydraulic fracturing fluid may be pumped downhole and out through the extended perforation tunnel (or extended perforation tunnels) to create fracture networks extending from each extended perforation tunnel.
  • the fracture networks may be created to extend laterally from each extended perforation tunnel, but they also may be created parallel with the extended perforation tunnels and/or at other desired orientations. In general, the orientation of the extended perforation tunnels ensures that the network of fractures extends through a target zone in a hydrocarbon bearing region of the formation.
  • the diameter of the extended perforation tunnels may vary according to the formation and/or other parameters of a given operation.
  • the extended perforation tunnels are generally smaller in diameter than a casing used along the borehole from which they extend.
  • certain embodiments may utilize extended perforation tunnels equal to or larger in diameter than the borehole.
  • the diameter of the extended perforation tunnels may be selected according to parameters of the formation and/or types of equipment used for creating the extended perforation tunnels.
  • the resultant diameter of the extended perforation tunnels may vary depending on the particular technique used to create the extended perforation tunnels (e.g., jetting, drilling, or other suitable technique).
  • the borehole may be drilled at least in part in a non productive zone of the subterranean formation.
  • the non-productive zone may be a zone that contains limited amounts of hydrocarbon fluid or is less desirable with respect to production of hydrocarbon fluid.
  • the borehole may be drilled in non-productive rock and/or in a region with petrophysical and geo-mechanical properties different from the properties of the target zone.
  • the borehole may be drilled in a region of the formation having a substantially higher minimum in situ stress relative to that of the target zone.
  • the extended perforation tunnels may be used in many types of formations (e.g., laminated formations) to facilitate flow of fluid to the extended perforation tunnels through fracture networks even in the presence of pinch points between formation layers.
  • At least one extended perforation tunnel may be created, which intersects the borehole and extends into a target zone (e.g., a productive zone containing hydrocarbon fluid).
  • a target zone e.g., a productive zone containing hydrocarbon fluid
  • a plurality of extended perforation tunnels may be created to extend from the borehole outwardly into the target zone to serve as extended treatment passages.
  • the target zone may be a single region or separate distinct regions of the formation.
  • the borehole may be entirely outside of the target zone, and a plurality of extended perforation tunnels may be created in desired directions to reach the target zone.
  • the extended perforation tunnels may be created generally horizontally, generally vertically, generally along desired angles between horizontal and vertical, in generally opposed directions with respect to each other, or at other orientations with respect to each other.
  • the borehole may extend into or through the target zone.
  • the well stimulation may include hydraulic fracturing of the stimulation zone or zones.
  • a fracturing fluid may be pumped down through the borehole and out through the plurality of extended perforation tunnels.
  • the fracturing fluid is forced under pressure from the extended perforation tunnels out into the surrounding subterranean formation (e.g., into the surrounding hydrocarbon bearing target zone) to fracture the surrounding subterranean formation.
  • the surrounding subterranean formation may be fractured at a plurality of stimulation zones within the overall target zone.
  • the fracturing fluid also may comprise propping agent for providing fracture conductivity after fracture closure.
  • the fracturing fluid may comprise acid such as hydrochloric acid, acetic acid, citric acid, hydrofluoric acid, other acids, or mixtures thereof.
  • the fracturing of the stimulation zones within the target zone enhances production of hydrocarbon fluid from the target zone to the wellbore and ultimately to the surface.
  • the target zone may be a productive zone of the subterranean region containing desired hydrocarbon fluid (e.g., oil and/or gas).
  • the embodiments described herein provide systems and methods for completing a well using extended perforation tunnels and hydraulic fracturing, for example, in formations with more than two formation horizons, for example, where control over fracture geometry may be particularly beneficial.
  • Position and orientation of the extended perforation tunnels are used to control geometry of the fractures, as described in greater detail herein. For example, initiating and propagating hydraulic fractures along an extended perforation tunnel created in a horizontal plane may enable reduced fracture height, which enables more precise fracture positioning within the target zone, and may reduce the risk of fracture growth to problematic areas outside of this targeted pay zone.
  • fracturing from extended perforation tunnels in a direction perpendicular to fracture growth may lead to multiple fractures with increased total contact area with the reservoir.
  • FIG. 1 is a schematic illustration of a well system 10 extending into a subterranean formation 12.
  • the well system 10 enables a methodology for enhancing recovery of hydrocarbon fluid (e.g., oil and/or gas) from a well.
  • hydrocarbon fluid e.g., oil and/or gas
  • a borehole 14 e.g., a generally vertical wellbore
  • the borehole 14 may be drilled into or may be drilled outside of a target zone 16 (or target zones 16) containing, for example, a hydrocarbon fluid 18.
  • the borehole 14 is a generally vertical wellbore extending downwardly from a surface 20. However, certain operations may create deviations in the borehole 14 (e.g., a lateral section of the borehole 14) to facilitate hydrocarbon recovery. In certain embodiments, the borehole 14 may be created in non-productive rock of the formation 12 and/or in a zone with petrophysical and/or geomechanical properties different from the properties found in the target zone or zones 16. [0040] At least one extended perforation tunnel 22 (e.g., a plurality of extended perforation tunnels 22, in certain embodiments) may be created to intersect the borehole 14. In the illustrated embodiment, at least two extended perforation tunnels 22 are created to intersect the borehole 14 and to extend outwardly from the borehole 14. For example, in certain
  • the extended perforation tunnels 22 may be created and oriented laterally (e.g., generally horizontally) with respect to the borehole 14. Additionally, in certain embodiments, the extended perforation tunnels 22 may be oriented to extend from the borehole 14 in different directions (e.g., opposite directions) so as to extend into the desired target zone or zones 16.
  • the extended perforation tunnel 22 is not aligned with the orientation of the borehole 14, but is created at some angle relative to the borehole 14 that is characterized by deviation from the direction of the borehole 14 (e.g., angle alpha: 0-90°) and the azimuthal tangential angle (beta 0-90°).
  • the extended perforation tunnels 22 may be oriented at desired alpha angles (e.g., deviation from the direction of the borehole 14) and beta angles (e.g., the azimuthal tangential angle) as illustrated in FIG. 2.
  • the alpha and beta angles may range between 0° and 90° (e.g., from 45° to 90°, in certain embodiments).
  • the extended perforation tunnels 22 may be oriented from 45° to 90° relative to the direction of the borehole 14.
  • the extended perforation tunnels 22 may be created and oriented at the alpha angle equal or close to 90° and the beta angle equal or close to 0° with respect to the borehole 14.
  • the extended perforation tunnels 22 may be oriented to extend from the borehole 14 in different directions (e.g., opposite directions) so as to extend into the desired zone 16.
  • a stimulation operation e.g., a hydraulic fracturing operation
  • fractures are created, which extend from the extended perforation tunnels 22.
  • the extended perforation tunnels 22 provide fluid communication with an interior of the borehole/wellbore 14 to facilitate flow of the desired hydrocarbon fluid 18 from the extended perforation tunnels 22, into borehole 14, and up through borehole 14 to, for example, a collection location at surface 20.
  • the extended perforation tunnels 22 may be oriented in selected directions based on the material forming the subterranean formation 12 and/or on the location of desired target zones 16.
  • the extended perforation tunnels 22 may be created along various azimuths.
  • the extended perforation tunnels 22 may be created in alignment with a direction of maximum horizontal stress, represented by arrow 24, in the formation 12.
  • the extended perforation tunnels 22 may be created along other azimuths, such as in alignment with a direction of minimum horizontal stress in the formation 12, as represented by arrow 26.
  • the extended perforation tunnels 22 may be created at a desired angle or angles with respect to principal stresses when selecting azimuthal directions.
  • the extended perforation tunnel (or extended perforation tunnels) 22 may be oriented at a desired angle with respect to the maximum horizontal stress in formation 12. It should be noted that, in certain embodiments, the azimuth and/or deviation of an individual extended perforation tunnel 22 may be constant. However, in other embodiments, the azimuth and/or deviation may vary along the individual extended perforation tunnel 22 to, for example, enable creation of the extended perforation tunnel 22 through a desired zone 16 to facilitate recovery of the hydrocarbon fluids 18.
  • At least one of the extended perforation tunnels 22 may be created and oriented to take advantage of a natural fracture 28 or multiple natural fractures 28, which occur in the formation 12.
  • the natural fracture 28 may be used as a flow conduit that facilitates flow of the hydrocarbon fluid 18 into the extended perforation tunnel (or extended perforation tunnels) 22. Once the hydrocarbon fluid 18 enters the extended perforation tunnels 22, the hydrocarbon fluid 18 is able to readily flow into the wellbore 14 for production to the surface 20 and/or other collection location.
  • the diameter and length of the extended perforation tunnels 22 also may vary.
  • the extended perforation tunnels 22 are generally longer than the lengths of perforations created in a conventional perforation operation.
  • the extended perforation tunnels 22 extend from the borehole 14 at least 10 feet (3.05 meters) into the formation 12 surrounding the borehole 14.
  • other embodiments may utilize extended perforation tunnels 22 that extend from the borehole 14 at least 15 feet (4.6 meters) into the formation 12.
  • Yet other embodiments may utilize extended perforation tunnels 22 that extend from the borehole 14 at least 20 feet (6.1 meters) into the formation 12.
  • certain embodiments may utilize extended perforation tunnels 22 substantially longer than 20 feet (6.1 meters).
  • each extended perforation tunnel 22 may extend from the borehole 14 at least 100 feet (30.5 meters), at least 200 feet (61 meters), between 300 feet (91 meters) and 1,600 feet (488 meters), or even more, into the formation 12.
  • each extended perforation tunnel 22 also has a diameter generally smaller than the diameter of borehole 14 (e.g., smaller than the diameter of a casing used to line borehole 14).
  • the tunnel diameter may range, for example, from 0.5 inches (12.7 millimeters) to 5.0 inches (12.7 centimeters).
  • the tunnel diameter may be within a range of 0.5 inches (12.7 millimeters) to 10 inches (25.4 centimeters), within a range of 1 inch (25.4 millimeters) and 5 inches (12.7 centimeters), within a range of 1.5 inches (3.8 centimeters) and 3 inches (7.6 centimeters), and so forth.
  • the extended perforation tunnels 22 may utilize a diameter of 2 inches (5.1 centimeters) or less.
  • other embodiments may utilize extended perforation tunnels 22 having a diameter of 1.5 inches (3.8 centimeters) or less.
  • the actual lengths, diameters, and orientations of the extended perforation tunnels 22 may be adjusted according to the parameters of the formation 12, the target zones 16, and/or objectives of the hydrocarbon recovery operation.
  • FIG. 3 is a schematic illustration of a well system 10 having a plurality of extended perforation tunnels 22 extending from a borehole 14 to deliver stimulating fluid to stimulation zones 30 that are distributed through the target zone(s) 16. Distributing the stimulating fluid under pressure to the stimulation zones 30 creates fracture networks 32.
  • the fracture networks 32 facilitate flow of fluid into the corresponding extended perforation tunnels 22.
  • the stimulation operation may include hydraulic fracturing performed to fracture the subterranean formation 12 (e.g., oil- or gas-bearing target zone 16) so as to facilitate flow of the desired fluid along the resulting fracture networks 32 and into the corresponding extended perforation tunnels 22.
  • fracturing fluid may be pumped from the surface 20 under pressure, down through wellbore 14, into the extended perforation tunnels 22, and then into the stimulation zones 30 surrounding the corresponding extended perforation tunnels 22, as indicated by arrows 34.
  • the pressurized fracturing fluid 34 causes the formation 12 to fracture in a manner that creates the fracture networks 32 in the stimulation zones 30.
  • the extended perforation tunnels 22/stimulation zones 30 may be fractured sequentially.
  • the fracturing operation may be performed through sequential extended perforation tunnels 22 and/or sequentially through individual extended perforation tunnels 22 to cause sequential fracturing of the stimulation zones 30 and creation of the resultant fracture networks 32.
  • the extended perforation tunnels 22 may be created via a variety of techniques, such as various jetting techniques or drilling techniques.
  • drilling equipment may be deployed down into wellbore 14 and used to create the desired number of extended perforation tunnels 22 in appropriate orientations for a given subterranean environment and production operation.
  • the extended perforation tunnels 22 may be created by other suitable techniques, such as jetting techniques, laser techniques, injection of reactive fluid techniques, electrical decomposition techniques, or other tunnel creation techniques.
  • the extended perforation tunnels 22 may be jetted using hydraulic jetting technology similar to hydraulic jetting technologies available from Radial Drilling Services Ltd, Viper Drill of
  • the use of extended perforation tunnels 22 during the stimulation operation enables creation of the fracture networks 32 and/or control of the geometries thereof.
  • the fracture networks 32 provide fractures with an increased density, thus increasing the size of the contact area with respect to each target zone 16 containing the hydrocarbon fluid 18. This, in turn, leads to an increase in well productivity as compared to wells completed without utilizing extended perforation tunnels 22.
  • FIGS. 4-6 are schematic sectional views of a portion of an example downhole radial drilling tool system positioned within a wellbore 14 and operable to from extended perforation tunnels 22 extending from the wellbore 14.
  • FIG. 4 illustrates a portion of a wellbore 14 including a casing 36 (which may be secured by cement 38 or installed open-hole) extending through a subterranean formation 12.
  • a drill string 40 extending through the wellbore 14 includes a deflecting tool 42 operable to deflect or otherwise direct a drilling, cutting, or other boring device toward a sidewall of the wellbore 14 to create an extended perforation tunnel 22.
  • the deflecting tool 42 may be rotatably oriented with respect to the wellbore 14, as indicated by arrow 44, to rotatably align or orient an outlet port 46 of the deflecting tool 42 in an intended direction (e.g., a substantially vertical direction).
  • an axis 48 of the outlet port 46 is oriented substantially orthogonal (e.g., within 5 degrees, within 2 degrees, within 1 degree, or even closer, to exactly orthogonal) to the casing 36 through which the extended perforation tunnel 22 extends.
  • a drilling tool 50 e.g., a flexible casing drilling string, in certain embodiments
  • a drilling, milling, cutting, or other bit 52 may be deployed through the drill string 40, such as via a micro-coil or coiled tubing, to create a perforation 54 (i.e., a hole) through the casing 36.
  • a perforation 54 i.e., a hole
  • the drilling tool 50 may be retracted from the deflecting tool 42 to the surface 20 and a hydraulic jetting tool 56 (i.e., a radial jet cutting tool, in certain embodiments) terminating with a nozzle 58 may be deployed downhole through the drill string 40, such as via a micro-coil or coiled tubing, through the deflection tool 42, and into alignment with or at least partially into the perforation 54.
  • the hydraulic jetting tool 56 may then be operated to discharge a stream 60 of pressurized water or another fluid to create an extended perforation tunnel 22.
  • a combinatory radial drilling tool (not shown) may be utilized to create both the casing perforation 54 and the extended perforation tunnel 22, such as to minimize or reduce the number of lifting/tripping operations.
  • the deflecting tool 42 may be reoriented to create another extended perforation tunnel 22 or moved longitudinally along the wellbore 14 to a selected location (e.g., at another formation zone 16). The process may be repeated until the intended number of extended perforation tunnels 22 are created along the entire wellbore 14 or into several formation zones 16.
  • the deflecting tool 42 is illustrated as being coupled along the drill string 40, in other embodiments, the deflecting tool 42 may be deployed downhole as part of another tool string or otherwise separately from a drill string 40, such as via coiled tubing, and utilized in conjunction with the drilling tool 50 and the jetting tool 56 to create the extended perforation tunnels 22.
  • stimulation e.g., fracturing
  • fracture or other stimulation treatment operations may be performed in one or more of the formation zones 16 along the wellbore 14 before creating extended perforation tunnels 22 in one or more subsequent formation zones 16.
  • FIG. 7 is a schematic sectional view of a portion of a laser cutting tool 62 positioned within a wellbore 14 and operable to create extended perforation tunnels 22 extending from the wellbore 14.
  • the laser cutting tool 62 may be conveyed longitudinally along the wellbore 14 (e.g., via coiled tubing 64).
  • a portion of the laser cutting tool 62 including a laser emitting port 66 may be rotated with respect to the wellbore 14, as indicated by arrow 68, to rotatably align or orient the laser emitting port 66 in an intended direction (e.g., a substantially vertical direction).
  • the laser cutting tool 62 may be operated to emit a laser beam 70 to create the extended perforation tunnel 22.
  • the laser cutting tool 62 may be reoriented to create another extended perforation tunnel 22, or moved longitudinally along the wellbore 14 to a subsequent selected location (e.g., at another formation zone 16), and the process is repeated until the intended number of extended perforation tunnels 22 are created along the entire wellbore 14 or into several formation zones 16.
  • FIG. 8 illustrates a three-dimensional element of a subterranean formation 12 having X-Y-Z coordinates and being subjected to local stresses. The element of subterranean formation 12 is also illustrated with a portion of an extended perforation tunnel 22 extending therethrough.
  • the stresses imparted to the element of subterranean formation 12 may be divided into three principal stresses, namely, a vertical stress 72, a minimum horizontal stress 74, and maximum horizontal stress 76.
  • These stresses 72, 74, 76 are normally compressive, anisotropic, and nonhomogeneous, which means that the stresses on the formation 12 are not equal and vary in magnitude on the basis of direction, which controls pressure operable to create and propagate a fracture, the shape and vertical extent of the fracture, the direction of the fracture, and the stresses trying to crush and/or embed a propping agent during production.
  • a hydraulic fracture will propagate along a direction of maximum horizontal formation stress 76 or along a plane 78 (or another parallel plane) of maximum horizontal formation stress 76 (along a plane 78 perpendicular to the minimum horizontal stress 74).
  • the direction of maximum formation stress 76 may be measured while drilling or otherwise creating a subterranean bore, for example, via an acoustic or nuclear logging while drilling tools. The resulting measurements may then be used to select directions of the wellbore 14 and the extended perforation tunnels 22 for optimal productivity.
  • extended perforation tunnels 22 may be created extending along (i.e., in alignment with, in a direction of) a plane comprising the maximum horizontal formation stress 76. Such orientation of the extended perforation tunnel 22 may result in a hydraulic fracture originating at the extended perforation tunnel 22 propagating longitudinally along the extended perforation tunnel 22. As illustrated in FIG.
  • At least a portion of the extended perforation tunnel 22 may be created at an angle 80 with respect to the true vertical 82 such that the extended perforation tunnel 22 extends along (i.e., is aligned with, extends in a direction 84 along) the plane 78 (along the X-Y plane) and not such that the extended perforation tunnel 22 extends through, across, or diagonally to the plane 78 (along the Y-Z plane).
  • Such orientation 84 of the extended perforation tunnel 22 may result in a hydraulic fracture propagating longitudinally along the extended perforation tunnel 22 (e.g., not diagonally across the extended perforation tunnel 22), facilitating longitudinal and, thus, optimal fluid connection between the extended perforation tunnel 22 and the fracture.
  • the drilling and fracturing methods described herein may facilitate substantial production and efficiency gains in hydraulic fracturing operations.
  • use of the extended perforation tunnels 22 described herein may substantially improve the efficiency of production, such as by promoting production from a greater number of sedimentary layers in the formation 12.
  • Creating these extended perforation tunnels 22 from one or more wellbores 14 may also facilitate substantial production increase to be achieved.
  • the embodiments described herein permit creation of well systems 10 that include a plurality of wellbores 14, each including a corresponding plurality of extended perforation tunnels 22 resulting in production magnification.
  • FIG. 9 is a schematic sectional view of at least a portion of an example wellbore system 86 that includes a substantially vertical wellbore portion 88 and a plurality of extended perforation tunnels 22 extending from such substantially vertical wellbore portion 88 through a casing 36 and one or more formation zones 16 of a subterranean formation 12.
  • the extended perforation tunnels 22 may extend at selected angles 90, 92 with respect to the substantially vertical wellbore portion 88 and/or a true vertical direction 94 and/or a true horizontal direction 96.
  • one or more of the extended perforation tunnels 22 may deviate or otherwise extend from the substantially vertical wellbore portion 88, along the X- Y plane and/or the Y-Z plane, at angles 92 ranging between about -45 degrees and about 45 degrees from the true horizontal 96 (between about 45 degrees and about 135 degrees with respect to the substantially vertical wellbore portion 88 and/or the true vertical 94).
  • angles 92 that are greater than -45 and 45 degrees from the true horizontal 96 are also within the scope of the present disclosure, resulting in extended perforation tunnels 22 that may be substantially vertical or closer to the true vertical 94 than to the true horizontal 96.
  • one or more of the extended perforation tunnels 22 may also extend from the substantially vertical wellbore portion 88 and/or the true vertical 94 along the X- Z plane at any angle 90 (i.e., between zero and 360 degrees) or in any azimuthal direction 98 around the substantially vertical wellbore portion 88 and/or the true vertical 94.
  • the extended perforation tunnels 22 may be created to extend from the substantially vertical wellbore portion 88 in a direction along or aligned with a plane of maximum horizontal formation stress (e.g., along direction 84 and plane 78, as illustrated in FIG. 8), which may result in a hydraulic fracture propagating longitudinally along the extended perforation tunnels 22.
  • the extended perforation tunnels 22 may be created to extend from the substantially vertical wellbore portion 88 in a direction that is transverse (i.e., perpendicular) to the plane of maximum horizontal formation stress, which may result in hydraulic fractures propagating transversely with respect to the extended perforation tunnels 22.
  • the present disclosure is further directed to a method of selecting or otherwise defining a plan or program for completing an oil and gas well by utilizing hydraulic fracturing.
  • the defined well completion program may include creating (e.g., drilling, cutting, etc.) extended perforation tunnels 22 along a wellbore 14, which may be utilized to control direction, location, and quantity of hydraulic fractures created during hydraulic fracturing operations.
  • the embodiments described herein may facilitate synergy between the extended perforation tunnel creating operations and hydraulic fracturing operations, such that the extended perforation tunnel creating operations and hydraulic fracturing operations fit each other.
  • the extended perforation tunnels 22 may comprise various orientations, extend through one or more formation zones 16, and may facilitate higher drainage radii.
  • creating extended perforation tunnels 22 that do not match or that are not harmonized with planned hydraulic fracturing operations may result in non-optimal stimulation of corresponding reservoirs, and may lead to multiple operational problems or issues related to treatment placement, safety, and environmental considerations.
  • the embodiments described herein minimize such risks, and maximize the collective effect of the extended perforation tunnels 22 and hydraulic fracturing.
  • FIG. 10 is a flow chart diagram of at least a portion of a method 100 for defining a program for completing an oil and gas well extending through a subterranean formation 12.
  • the method 100 may include selecting or otherwise defining 102 one or more candidate wells for completion, including via creating extended perforation tunnels 22 and/or hydraulic fracturing.
  • the candidate wells may be defined, for example, based on considerations related to logistics, reservoir quality, completion acceptance (e.g., pressure or pumping rate limitations), and economical feasibility.
  • the method 100 may further include selecting or otherwise defining 104 a criteria for comparing or otherwise evaluating candidate well completion programs (i.e., well completion program scenarios) for one or more of the selected (i.e., target) candidate wells.
  • the evaluation criteria may be defined, for example, based on economic considerations (e.g., NPV, IRR, IPB, payback time, etc.), production targets, and targets for operational efficiency.
  • the method 100 may further include selecting or otherwise defining 106 candidate formation zones into or through which the extended perforation tunnels 22 may be created along or otherwise extending from a wellbore 14.
  • location of the extended perforation tunnels 22 may be defined based on geomechanical and/or petrophysical logs.
  • the extended perforation tunnels 22 may be created to extend through formation zones 16 having a higher reservoir production quality, which may be defined as a function of porosity, permeability, and hydrocarbon saturation.
  • the extended perforation tunnels 22 may also, or instead, be created to extend through formation zones 16 having properties that optimize fracture creation and/or propagation, such as formation zones 16 having lower horizontal stress.
  • location of the formation zones 16 through which the extended perforation tunnels 22 may be created may be defined based on
  • the quantity of stimulated formation zones may be defined based on “limited entry” considerations for a given limit of pumped flow rate, such as when the pumped flow rate is limited by pressure limitations and/or by equipment availability.
  • location of the formation zones for the extended perforation tunnels 22 may also, or instead, be defined based on reservoir quality.
  • the method 100 may further include defining 108 size (e.g., diameter) of an entry point (e.g., opening) in a casing 36 for creating the extended perforation tunnels 22 along the wellbore 14.
  • size of the entry point in the casing 36 may defined based on size (e.g., diameter) of a downhole tool utilized to penetrate the casing 36 prior to creating of the extended perforation tunnels 22, and/or based on size (e.g., diameter) of pre-created holes or other entry points into the formation 12 located in the casing 36, a fracturing sleeve, or other piece of equipment installed along the wellbore 14 and operable to aid in the creating of extended perforation tunnels 22.
  • the size of the entry point in the casing 36 may be further utilized to define efficiency of flow rate distribution between a plurality of extended perforation tunnels 22 using limited entry approach, such as based on perforation friction.
  • the method 100 may further include defining 110 maximum pumping flow rate of fracturing fluid.
  • the maximum pumping flow rate may be defined, for example, using the limited entry approach that is based on quantity of formation zones 16 that are selected to be stimulated via the extended perforation tunnels 22 and/or the size of the entry points in the casing 36 for each of the extended perforation tunnels 22.
  • the maximum pumping flow rate may also be at least partially defined by other entry points, such as previously created holes or perforations, and their effect on fluid distribution between target formation zones 16. If the well is planned to be fracture stimulated in several stages, a staging procedure for creating and stimulating such extended perforation tunnels 22 using hydraulic fracturing may be defined, as described in greater detail herein.
  • the maximum pumping flow rate during each fracturing stage may be limited, for example, by the capability of pumping equipment and pressure limits of completion equipment, among other considerations.
  • the method 100 may further include defining 112 a size of extended perforation tunnels 22 extending from the wellbore 14 through the formation 12.
  • the size (e.g., diameter) of extended perforation tunnels 22 in each formation zone 16 may be defined based on one or more criteria, such as friction of the fracturing fluid pumped through the extended perforation tunnels 22.
  • methods of defining fluid friction may include, for example, lab studies, computations accounting for fluid rheology, and downhole measurements.
  • a diameter of the extended perforation tunnels 22 may be maintained above a threshold size to maintain efficient fluid delivery into the formation 12 because of the friction-related pressure losses caused by a decreased diameter.
  • the diameter of the extended perforation tunnels 22 in each formation zone 16 may be defined based on fracture initiation pressure and locations for fracture initiation.
  • fracture initiation pressure depends on the size of the casing entry points. Accordingly, in certain embodiments, fracture initiation pressure and fracture initiation locations may be controlled by enlarging the diameter of the extended perforation tunnels 22 at locations where fractures are planned to be created.
  • the method 100 may further include defining 114 candidate well completion programs, wherein each candidate well completion program differs with respect to at least one well completion parameter.
  • the well completion parameters may relate to characteristics or features of the extended perforation tunnels 22.
  • a well completion parameter may include the quantity (i.e., number) of the extended perforation tunnels 22 extending into or through at least one candidate formation zone 16.
  • Another well completion parameter may include shape or geometry (e.g., diameter, length, profile, contour, etc.) of the extended perforation tunnels 22. Still another well completion parameter may include an orientation angle of the extended perforation tunnels 22 extending into or through at least one candidate formation zone 16. In certain embodiments, orientation of the extended perforation tunnels 22 in a formation zone 16 may be defined based on simplicity of fracture initiation and propagation. For example, orientation of the extended perforation tunnels 22 in a formation zone 16 may be selected along a direction that maximizes or minimizes likelihood of fracture initiation.
  • fractures may be created only in formation zones 16 completed with extended perforation tunnels 22, and the extended perforation tunnels 22 in other formation zones 16 may not be stimulated and may be utilized during production to drain a portion of the reservoir that was not penetrated by the fractures.
  • orientation of the extended perforation tunnels 22 in a formation zone 16 may also be defined based on expected fracture geometry.
  • a well completion parameter may include quantity (i.e., number) of hydraulic fracturing stages, wherein each stage is operable to stimulate selected one or more of the candidate formation zones 16.
  • the quantity of fracturing stages may be defined based on a quantity of defined candidate formation zones 16 for placement of extended perforation tunnels 22 and maximum pumping flow rate.
  • the quantity of fracturing stages may be defined based on the limited entry approach, which may be utilized to define the quantity of extended perforation tunnels 22 that can be effectively fracture stimulated with proper or otherwise intended fluid distribution between the formation zones 16 during each fracturing stage based on the pumping flow rate limits.
  • one or more of the extended perforation tunnels 22 may not be stimulated, such as because of predesigned orientation and/or geometry of the extended perforation tunnels 22.
  • Another well completion parameter may relate to a hydraulic fracturing treatment plan for at least one fracturing stage, including fracturing fluid pumping flow rate.
  • Such pumping flow rate may be defined based on maximum pumping flow rate, pumping equipment availability for each fracturing stage, and completion equipment limitations for each stage.
  • each fracturing stage except the last one may be performed by pumping a fracturing fluid down a fracturing string with a packer and fracturing plugs for isolating stimulated fracturing zones.
  • the last fracturing zone may be fracture stimulated by pumping the fracturing fluid down the casing after isolating a previous fracturing zone with a fracturing plug. Under such circumstances, maximum pumping flow rate during the last fracturing stage may be higher than during each previous fracturing stage.
  • other well completion parameters may include proppant type and fracturing fluid type.
  • Still other well completion parameters may include fracturing treatment pumping schedule, proppant volumes, and fracturing fluid volumes for each fracturing stage.
  • the pumping schedule and volumes for fracturing treatment for each fracturing stage may be defined based on fracture geometry modeling, such as PKN, P3D, KGD, 3D-coupled fracture propagation models, or other models that may account for fluid dynamics and proppant settling.
  • the pumping schedule may also include fracture geometry modeling that accounts for complexity of fracture network, such as wiremesh or models utilizing Discrete Fracture Network concept.
  • the pumping schedule may also be defined based on aspects of logistics and economics.
  • fracture treatments may be utilized including, but not limited to, acid fracturing, slick water fracturing, foam fracturing, proppant-free fracturing, water or steam injection, and others.
  • other well completion parameters may include considerations related to target formation zones (e.g., pay zones) 16 for stimulation, wherein such formation zones 16 are chosen from a list of defined candidate formation zones 16.
  • stimulation operations may be initiated with respect to selected target formation zones 16 from a list of defined candidate formation zones 16 for creation of extended perforation tunnels 22.
  • Selected candidate formation zones 16 may be stimulated, for example, based on economic considerations and efficiency considerations, such as when stimulating too many formation zones 16 utilizes excessive amount of time.
  • Another consideration may include depths (e.g., true vertical depth (TVD), measured depth (MD)) of candidate target formation zones 16 where the extended perforation tunnels 22 are planned to be created.
  • TVD true vertical depth
  • MD measured depth
  • the extended perforation tunnels 22 may be created just in candidate target formation zones 16. In certain embodiments, the extended perforation tunnels 22 may also, or instead, be created in selected candidate formation zones 16 that are not defined as target zones 16. Such extended perforation tunnels 22 may be predesigned to avoid stimulation during fracturing treatment, such as via orientation or geometry of the extended perforation tunnels 22.
  • Still other well completion parameters may include considerations related to a staging program, such as methodology for transitioning from one fracturing stage to another.
  • the staging program may be defined based on selected well completion methodologies. For example, in certain embodiments, each extended perforation tunnel 22 may be created before performing hydraulic fracturing. Thereafter, the fracturing may be performed either in one fracturing stage or several fracturing stages. Fluid distribution between several extended perforation tunnels 22 during each fracturing stage may be permitted by utilizing the limited entry approach or by utilizing fracture diverters. Each fracture stimulated formation zone may be isolated from other fracturing zones, for example, by utilizing fracturing plugs, packers (e.g., including tubing and completion conveyed packers), and fracturing ports. In certain
  • creation of the extended perforation tunnels 22 and the hydraulic fracturing of the formation zones 16 may be performed sequentially, such as when the extended perforation tunnels 22 are created in one or several formation zones 16 followed by hydraulic fracturing of the formation zones 16. Such process may be repeated for another formation zone 16 or a subsequent set of formation zones 16. Zonal isolation between fracturing stages may also be performed in certain embodiments.
  • the method 100 may further include forecasting 116 the results of two or more of the candidate well completion programs based on, or otherwise with respect to, the defined criteria for evaluating the candidate well completion programs.
  • the forecasting 116 may include modeling or otherwise applying each of the defined candidate well completion programs for at least one of the defined candidate well completion program evaluation criteria.
  • the forecasting 116 may be performed using well behavior modeling during post-fracturing period to generate expected well operating parameters, such as bottom hole flow, bottom hole pressure, production rate, cumulative volumetric production, and expected properties of producing fluid, among other examples. Production forecasting may be performed at least partially based on properties of the formation and designed fracture system.
  • the method 100 may also include selecting or otherwise defining 118 an optimal candidate well completion program from the forecasted results by comparing or otherwise evaluating the forecasted results based on the defined criteria for evaluating the candidate well completion programs.
  • the defining 118 may include comparing or otherwise evaluating at least two of the forecasted results based on or otherwise with respect to the defined evaluation criteria.
  • the optimal well completion program may be defined based on valuation of forecasted results of each candidate well completion program against the defined evaluation criteria.
  • an optimal well completion program may be defined using cumulative production forecast, as described below. The optimal well completion program may depend on number of parameters and may be substantially different for various types of reservoirs.
  • the method 100 may also include controlling 120 a fracture geometry of a formation zone 16 in accordance with the optimal well completion program to optimize the well productivity.
  • controlling 120 the fracture geometry of the formation zone 16 may include creating one or more extended perforation tunnels 22 from the wellbore 14, as described in detail herein, prior to fracturing operations through the one or more extended perforation tunnels 22.
  • the orientation, direction, size, length, and so forth, of the one or more extended perforation tunnels 22 may be guided in accordance with the optimal well completion program to optimize the well productivity.
  • controlling 120 the fracture geometry of the formation zone 16 includes stimulating the formation zone 16 by delivering hydraulic fracturing fluid through the one or more extended perforation tunnels 22, as described in detail herein.
  • the various parameters of the fracturing procedures described herein may be selected and implemented in accordance with the optimal well completion program to optimize the well productivity. Control over the fracture geometry is achieved with the extended perforation tunnels 22 for precise positioning of fracture treatments from wellbores 14 having their own varying geometries.
  • the use of extended perforation tunnels 22, as described herein, may also help avoid fracture growth in non-desired formation layers.
  • candidate well completion programs were defined 114 and hydrocarbon production forecasting 116 was performed for each defined candidate well completion program, such as may permit an optimal candidate well completion program to be defined 118.
  • the well completion parameters that changed or varied between the defined candidate well completion programs included whether extended perforation tunnels 22 were present and orientation of the extended perforation tunnels 22.
  • Some candidate well completion programs included extended perforation tunnels 22 extending along (i.e., aligned with) a direction of fracture propagation, some candidate well completion programs included extended perforation tunnels 22 extending along a direction perpendicular to fracture propagation, and some candidate well completion programs did not include extended perforation tunnels 22.
  • Table 1 set forth below lists the well completion parameters related to the extended perforation tunnels 22, including extended perforation tunnel characteristics and depth (e.g., true vertical depth (TVD), measured depth (MD)) at which well casing perforations and/or extended perforation tunnels 22 were created.
  • extended perforation tunnel characteristics e.g., true vertical depth (TVD), measured depth (MD)
  • forecasting 116 was performed for two formation models, each having a different formation oil saturation and permeability.
  • Table 2 set forth below lists formation model characteristics
  • Table 3 set forth below lists fracture treatment design utilized for each formation model listed in Table 2.
  • the first formation model was assumed to include a constant oil saturation of 0.5 across the reservoir and a homogeneous permeability of 0.10 millidarcys (md).
  • the second formation model was assumed to include a variable oil saturation, including a 0.5 saturation in the pay zone and a 0.1 saturation outside of the pay zone.
  • the second formation model was also assumed to include a heterogeneous permeability of 10.00 md. No fracture growth restriction was considered.
  • FIGS. 11-13 are forecasted (i.e., modeled) representations of expected geometries of formation fractures created during fracturing operations based on the well completion parameters listed in Table 1.
  • FIG. 11 illustrates a vertical wellbore 14 extending through a pay zone 122 of a subterranean formation 12.
  • the wellbore 14 does not have extended perforation tunnels 22 extending therefrom.
  • a formation fracture 124 is illustrated propagating longitudinally along the wellbore 14 and vertically and horizontally through the formation 12 along a plane of maximum horizontal formation stress (i.e., along a direction of fracture propagation).
  • the fracture 124 is illustrated having a height 126 that substantially exceeds a height 128 of the formation pay zone 122, extending above and below the pay zone 122.
  • FIG. 12 illustrates a vertical wellbore 14 extending through a pay zone 122 of a subterranean formation 12.
  • the wellbore 14 has extended perforation tunnels 22 extending therefrom in a direction along a plane of maximum horizontal formation stress.
  • a formation fracture 124 is illustrated propagating along the plane of maximum horizontal formation stress and longitudinally along the extended perforation tunnels 22.
  • the fracture 124 is illustrated located within the pay zone 122, wherein the fracture 124 has a height 130 that is substantially equal to or less than a height 132 of the pay zone 122.
  • FIG. 13 illustrates a vertical wellbore 14 extending through a pay zone 122 of a subterranean formation 12.
  • the wellbore 14 has extended perforation tunnels 22 (one extended perforation tunnel 22 is obstructed from view) extending therefrom in a direction that is transverse (i.e., perpendicular) to a plane of maximum horizontal formation stress.
  • Formation fractures 124 are illustrated propagating in a direction along and parallel to the plane of maximum horizontal formation stress and transverse with respect to the extended perforation tunnels 22.
  • the fracturesl24 are illustrated having a height 134 that slightly exceeds a height 136 of the formation pay zone 122, extending above and below the pay zone 122.
  • FIGS. 14-17 are graphs illustrating forecasted (i.e., modeled) results for defined candidate well completion programs based on or otherwise with respect to an evaluation criteria of forecasted cumulative oil production, indicated along vertical axes, illustrated with respect to time, indicated along horizontal axes.
  • the graphs illustrate the forecasted cumulative well productivity depends on well completion parameters, including the fracture geometries (i.e., extended perforation tunnel characteristics) listed in Table 1 and illustrated in FIGS. 11-13, and on the formation properties listed in Tables 2 and 3.
  • the graphs further illustrate that the highest producing completion (e.g., no extended perforation tunnels 22 (see FIG. 11),
  • the cumulative well productivity associated with a single fracture 124 initiated and propagated from a wellbore 14 without extended perforation tunnels 22 is indicated by profiles 138 (see FIG. 11)
  • the cumulative well productivity associated with a fracture 124 extending longitudinally along extended perforation tunnels 22 is indicated by profiles 140 (see FIG. 12)
  • the cumulative well productivity associated with fractures 124 extending transversely with respect to extended perforation tunnels 22 is indicated by profiles 142 (see FIG. 13).
  • FIG. 14 illustrates the cumulative oil production profiles 138, 140, 142 for the three fracture geometries described above, each having a fracture height that is located within a formation pay zone 122 that has a permeability of 0.10 md.
  • FIG. 14 illustrates that the well completion having fractures 124 extending transversely with respect to the extended perforation tunnels 22, as indicated by profile 142, yield the highest oil production with respect to time.
  • FIG. 15 illustrates the cumulative oil production profiles 138, 140, 142 for the three fracture geometries described above, each having a fracture height that is located within the formation pay zone 122 that has a permeability of 10.00 md.
  • FIG. 15 illustrates that the well completion having a single fracture 124 initiated and propagated from the wellbore 14, as indicated by profile 138, yields the highest oil production with respect to time.
  • FIG. 16 illustrates the cumulative oil production profiles 138, 140, 142 for the three fracture geometries described above, each having a fracture height that exceeds height of the formation pay zone 122 that has a permeability of 0.10 md.
  • FIG. 15 illustrates the cumulative oil production profiles 138, 140, 142 for the three fracture geometries described above, each having a fracture height that exceeds height of the formation pay zone 122 that has a permeability of 0.10 md.
  • FIG. 16 illustrates that the well completion having fractures 124 extending transversely with respect to the extended perforation tunnels 22, as indicated by profile 142, yields the highest oil production with respect to time.
  • FIG. 17 illustrates the cumulative oil production profiles 138, 140, 142 for the three fracture geometries described above, each having a fracture height that exceeds height of the formation pay zone 122 that has a permeability of 10.00 md.
  • FIG. 17 illustrates that that the well completion having a fracture extending longitudinally with respect to the extended perforation tunnel 22, as indicated by profile 140, yields the highest oil production with respect to time.
  • the optimal candidate well completion program may be defined 118 by comparing and/or evaluating the forecasted results illustrated in FIGS. 14-17 based on the defined well evaluation criteria of cumulative oil production. Such comparison indicates that a single fracture 124 initiated and propagated from a well, designated by profile 138 illustrated in FIG.
  • the method 100 described above and illustrated in FIG. 10 may be performed or caused to be performed by a processing device 144 executing coded instructions 146.
  • the processing device 144 may receive information from a wellsite operator and automatically generate and transmit output information to be analyzed by the wellsite operator, and/or operate or cause a change in an operational parameter of one or more pieces of the wellsite equipment described herein.
  • FIG. 18 is a block diagram of at least a portion of a processing device 144 configured to execute instructions 146 to implement the techniques described herein (e.g., any or all of the steps of the method 100 of FIG. 10, as well as other processes).
  • the processing device 144 may form at least a portion of one or more electronic devices utilized at the wellsite or located offsite.
  • the processing device 144 may be in communication with various sensors, actuators, controllers, and other devices of the well system 10.
  • the processing device 144 may be operable to receive coded instructions 146 from human operators and sensor data generated by the sensors, process the coded instructions 146 and the sensor data, and communicate control data to local controllers and/or the actuators to execute the coded instructions 146 to implement at least a portion of the techniques described herein.
  • the processing device 144 may also or instead be operable to receive the coded instructions 146, such as including the information defined via the steps of the method 100 described herein, process such information, and output 116 forecasts or models of the defined candidate well completion programs for analysis or comparison by the human operators.
  • the processing device 144 may also or instead automatically define 118 the optimal candidate well completion program.
  • the processing device 144 may be or include, for example, one or more processors, special-purpose computing devices, servers, personal computers (e.g., desktop, laptop, and/or tablet computers), personal digital assistants, smartphones, internet appliances, and/or other types of computing devices.
  • the processing device 144 may include a processor 148, such as a general-purpose programmable processor.
  • the processor 148 may include a local memory 150, and may execute coded instructions 146 present in the local memory 150 and/or another memory device.
  • the processor 148 may execute, among other things, the machine-readable coded instructions 146 and/or other instructions and/or programs to implement the techniques described herein.
  • the programs stored in the local memory 150 may include program instructions or computer program code that, when executed by the processor 148 of the processing device 144, may cause the well system 10 and/or other devices to perform the techniques described herein.
  • the processor 148 may be, include, or be implemented by one or more processors of various types suitable to the local application environment, and may include one or more of general-purpose computers, special-purpose computers, microprocessors, digital signal processors (DSPs), field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), and processors based on a multi-core processor architecture, as non-limiting examples.
  • DSPs digital signal processors
  • FPGAs field-programmable gate arrays
  • ASICs application-specific integrated circuits
  • processors based on a multi-core processor architecture, as non-limiting examples.
  • DSPs digital signal processors
  • FPGAs field-programmable gate arrays
  • ASICs application-specific integrated circuits
  • processors based on a multi-core processor architecture, as non-limiting examples.
  • other processors from other families are also appropriate.
  • the processor 148 may be in communication with a main memory 152, such as may include a volatile memory 154 and a non-volatile memory 156, perhaps via a bus 158 and/or other communication means.
  • the volatile memory 154 may be, include, or be implemented by random access memory (RAM), static random access memory (SRAM), synchronous dynamic random access memory (SDRAM), dynamic random access memory (DRAM), RAMBUS dynamic random access memory
  • the non-volatile memory 156 may be, include, or be implemented by read-only memory, flash memory, and/or other types of memory devices.
  • one or more memory controllers may control access to the volatile memory 154 and/or non-volatile memory 156.
  • the processing device 144 may also include an interface circuit 160, which may be, include, or be implemented by various types of standard interfaces, such as an Ethernet interface, a universal serial bus (USB), a third generation input/output (3GIO) interface, a wireless interface, a cellular interface, and/or a satellite interface, among others.
  • the interface circuit 160 may also include a graphics driver card.
  • the interface circuit 160 may also include a communication device, such as a modem or network interface card to facilitate exchange of data with external computing devices via a network (e.g., Ethernet connection, digital subscriber line (DSL), telephone line, coaxial cable, cellular telephone system, satellite, etc.).
  • a network e.g., Ethernet connection, digital subscriber line (DSL), telephone line, coaxial cable, cellular telephone system, satellite, etc.
  • one or more of the local controllers, the sensors, and the actuators of the well system 10 may be connected with the processing device 144 via the interface circuit 160, such as may facilitate communication between the processing device 144 and the local controllers, the sensors, and/or the actuators.
  • one or more input devices 162 may also be connected to the interface circuit 160.
  • the input devices 162 may permit the human operators to enter the coded instructions 146, such as control commands, processing routines, operational settings and set-points.
  • the input devices 162 may be, include, or be implemented by a keyboard, a mouse, a joystick, a touchscreen, a track-pad, a trackball, an isopoint, and/or a voice recognition system, among other examples.
  • one or more output devices 164 may also be connected to the interface circuit 160.
  • the output devices 164 may be, include, or be implemented by video output devices (e.g., an LCD, an LED display, a CRT display, a touchscreen, etc.), printers, and/or speakers, among other examples.
  • the processing device 144 may also communicate with one or more mass storage devices 166 and/or a removable storage medium 168, such as may be or include floppy disk drives, hard drive disks, compact disk (CD) drives, digital versatile disk (DVD) drives, and/or USB and/or other flash drives, among other examples.
  • the coded instructions 146 may be stored in the mass storage device 166, the local memory 150, and/or the removable storage medium 168.
  • the processing device 144 may be implemented in accordance with hardware (perhaps implemented in one or more chips including an integrated circuit, such as an ASIC), or may be implemented as software or firmware for execution by the processor 148.
  • firmware or software the implementation may be provided as a computer program product including a non-transitory, computer-readable medium or storage structure embodying computer program code (i.e., software or firmware) thereon for execution by the processor 148.
  • the coded instructions 146 may include program instructions or computer program code that, when executed by the processor 148, may perform the processes and/or operations described herein.

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Abstract

Les systèmes et les procédés de l'invention sont conçus pour définir un programme de complétion comprenant la création et la stimulation d'un ou plusieurs tunnels de perforation étendus pour un puits, et pour commander une géométrie de fracture d'une zone de formation conformément au programme de complétion à l'aide du ou des tunnels de perforation étendus orientés dans la zone de formation avant la fracturation.
PCT/US2019/036870 2018-06-13 2019-06-13 Systèmes et procédés de commande de géométries de fracture à l'aide de tunnels de perforation étendus WO2019241457A1 (fr)

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