US20150300092A1 - Slow Drilling Assembly and Method - Google Patents
Slow Drilling Assembly and Method Download PDFInfo
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- US20150300092A1 US20150300092A1 US14/431,719 US201214431719A US2015300092A1 US 20150300092 A1 US20150300092 A1 US 20150300092A1 US 201214431719 A US201214431719 A US 201214431719A US 2015300092 A1 US2015300092 A1 US 2015300092A1
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- 238000000034 method Methods 0.000 title claims abstract description 83
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B7/00—Special methods or apparatus for drilling
- E21B7/04—Directional drilling
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/20—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B29/00—Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
- E21B29/002—Cutting, e.g. milling, a pipe with a cutter rotating along the circumference of the pipe
- E21B29/005—Cutting, e.g. milling, a pipe with a cutter rotating along the circumference of the pipe with a radially-expansible cutter rotating inside the pipe, e.g. for cutting an annular window
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B3/00—Rotary drilling
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B4/00—Drives for drilling, used in the borehole
- E21B4/04—Electric drives
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/11—Perforators; Permeators
- E21B43/116—Gun or shaped-charge perforators
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B7/00—Special methods or apparatus for drilling
- E21B7/04—Directional drilling
- E21B7/06—Deflecting the direction of boreholes
- E21B7/061—Deflecting the direction of boreholes the tool shaft advancing relative to a guide, e.g. a curved tube or a whipstock
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- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (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)
- Mechanical Engineering (AREA)
- Earth Drilling (AREA)
Abstract
A wellbore tubular-conveyed drill assembly comprising a wellbore tubular, an electrical drilling mechanism coupled to an outside surface of the wellbore tubular, wherein the electrical drilling mechanism has a refracted position and an extended position, wherein the electrical drilling mechanism drills one or more openings in a subterranean formation when in the extended position, and a power source coupled to the electrical drilling mechanism. A method comprising extending an electrical drilling mechanism in a direction away from a wellbore tubular, wherein the electrical drilling mechanism is coupled to an outside surface of the wellbore tubular, and drilling one or more openings in a subterranean formation with the electrical drilling mechanism.
Description
- None.
- Not applicable.
- Not applicable.
- Wellbores are sometimes drilled into subterranean formations that contain hydrocarbons to allow recovery of the hydrocarbons. After completion of drilling, some or all of a wellbore may be lined, for example, with casing. A production string may be placed in a wellbore for production of fluids from the wellbore. In some wellbores, downhole power is available and can operate various production equipment, such as valves, chokes, sensors, etc. It is possible that excess downhole power can be available, creating an opportunity for operation of additional equipment downhole.
- Disclosed herein is a wellbore tubular-conveyed drill assembly comprising a wellbore tubular, an electrical drilling mechanism coupled to an outside surface of the wellbore tubular, wherein the electrical drilling mechanism has a retracted position and an extended position, wherein the electrical drilling mechanism drills one or more openings in a subterranean formation when in the extended position, and a power source coupled to the electrical drilling mechanism.
- Also disclosed herein is a method comprising extending an electrical drilling mechanism in a direction away from a wellbore tubular, wherein the electrical drilling mechanism is coupled to an outside surface of the wellbore tubular, and drilling one or more openings in a subterranean formation with the electrical drilling mechanism.
- Further disclosed herein is a method comprising providing a wellbore tubular-conveyed drill assembly coupled to an outside surface of a wellbore tubular, wherein the wellbore tubular-conveyed drill assembly has a continuous hollow channel extending therethrough, coupling the continuous hollow channel to an interior of the wellbore tubular, pressurizing the interior of the wellbore tubular with a drilling fluid, directing the drilling fluid through the continuous hollow channel, and drilling one or more openings in a subterranean formation with the wellbore tubular-conveyed drill assembly.
- These and other features will be more clearly understood from the following detailed description taken in conjunction with the accompanying drawings and claims.
- For a more complete understanding of the present disclosure and the advantages thereof, reference is now made to the following brief description, taken in connection with the accompanying drawings and detailed description:
-
FIG. 1A is a cut-away side view of an embodiment of a wellbore tubular-conveyed drill assembly in a wellbore operating environment; -
FIG. 1B is a cut-away side view of an embodiment of the wellbore tubular-conveyed drill assembly, shown in a retracted position; -
FIG. 1C is a cut-away side view of the embodiment of the wellbore tubular-conveyed drill assembly ofFIG. 1B , shown in an extended position; -
FIG. 2A is cut-away side view of another embodiment of a wellbore tubular-conveyed drill assembly in a refracted position; -
FIG. 2B is a cut-away side view of the embodiment of the wellbore tubular-conveyed drill assembly ofFIG. 2A , shown in an extended position; -
FIG. 3A is a cut-away side view of yet another embodiment a wellbore tubular-conveyed drill assembly, shown in a refracted position; -
FIG. 3B is a cut-away side view of the embodiments of the wellbore tubular-conveyed drill assembly ofFIG. 3A , shown in an extended position; -
FIG. 4A is a side view of an embodiment of an electrical drilling mechanism; -
FIG. 4B is a side view of another embodiment of an electrical drilling mechanism; -
FIG. 4C is a side view of yet another embodiment of an electrical drilling mechanism; -
FIG. 5 is a cut-away side view of an embodiment of the wellbore tubular-conveyed drill assembly comprising an embodiment of a deflector; and -
FIG. 6 is a cut-away side view of an embodiment of the wellbore tubular-conveyed drill assembly comprising another embodiment of a deflector. - In the drawings and description that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawing figures are not necessarily to scale. Certain features may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of principles, and is not intended to limit the claims to the embodiments illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed infra may be employed separately or in any suitable combination to produce desired results.
- Unless otherwise specified, any use of any form of the terms “connect,” “engage,” “couple,” “attach,” or any other term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described. In the following discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . ”. Reference to up or down will be made for purposes of description with “up,” “upper,” “upward,” or “upstream” meaning toward the surface of the wellbore and with “down,” “lower,” “downward,” or “downstream” meaning toward the terminal end of the well, regardless of the wellbore orientation. Reference to in or out will be made for purposes of description with “in,” “inner,” or “inward” meaning toward the center or central axis of the wellbore, and with “out,” “outer,” or “outward” meaning toward the wellbore tubular and/or wall of the wellbore. The various characteristics mentioned above, as well as other features and characteristics described in more detail below, will be readily apparent to those skilled in the art with the aid of this disclosure upon reading the following detailed description of the embodiments, and by referring to the accompanying drawings.
- Disclosed herein are wellbore tubular-conveyed assemblies and methods related to drilling of openings in a subterranean formation. In embodiments, the assemblies and methods may utilize available downhole power to increase long term production of a subterranean formation. Embodiments of the assemblies and methods contemplate drilling techniques which may occur over relatively long periods of time so as to provide a novel “slow” drilling technique. The slow drilling assemblies and methods disclosed herein may provide production from relatively small openings drilled in a subterranean formation, which may increase the overall recovery from the subterranean formation above production amounts conventionally provided in a wellbore. Using the embodiments disclosed herein, production may be increased by increasing the producing area of the wellbore; as such, the disclosed assemblies and methods may increase revenue from increased production. Many different embodiments of the disclosed assemblies and methods may be used in the same wellbore.
- Referring to
FIG. 1A , an example of a wellbore operating environment is shown. As depicted, the operating environment comprises adrilling rig 111 positioned on the earth'ssurface 107 which extends over and around awellbore 102 that penetrates asubterranean formation 101 for the purpose of producing hydrocarbons. The disclosed methods may include drilling awellbore 102, and thewellbore 102 may be drilled into thesubterranean formation 101 using any suitable drilling technique. Thewellbore 102 may extend substantially vertically away from the earth'ssurface 107. In alternative operating environments, all or a portion of thewellbore 102 may be vertical, deviated at any suitable angle, horizontal, and/or curved. Thewellbore 102 may comprise a new wellbore, an existing wellbore, a straight wellbore, an extended reach wellbore, a sidetracked wellbore, a multi-lateral wellbore, other types of wellbores for drilling and completing one or more production zones, or combinations thereof. Further, thewellbore 102 may be used for any suitable purpose, e.g., hydrocarbon production, water production, injection, etc. In an embodiment, all or a portion of thewellbore 102 may be used for purposes other than or in addition to hydrocarbon production, such as uses related to geothermal energy. - The
drilling rig 111 may comprise aderrick 108 with arig floor 109 through which thewellbore tubular 110 extends downward from thedrilling rig 111 into thewellbore 102. Thedrilling rig 111 may comprise a motor-driven winch and other associated equipment for extending the wellbore tubular 110 into thewellbore 102 to position the wellbore tubular-conveyeddrill assembly 120 at a selected depth. While the operating environment depicted inFIG. 1 refers to astationary drilling rig 111 for lowering and setting thewellbore tubular 110 and wellbore tubular-conveyeddrill assembly 120 coupled thereto within a land-basedwellbore 102, in alternative embodiments, mobile workover rigs, wellbore servicing units (such as coiled tubing units), and the like may be used to lower thewellbore tubular 110 and wellbore tubular-conveyeddrill assembly 120 coupled thereto into thewellbore 102. It should be understood that awellbore tubular 110 and wellbore tubular-conveyeddrill assembly 120 coupled thereto may alternatively be used in other operational environments, such as within an offshore wellbore operational environment. - A
production string 115 comprising thewellbore tubular 110 may be inserted and lowered into thewellbore 102 for production of one or more fluids fromsubterranean formation 101. While the disclosed assemblies and methods are described in the context of hydrocarbon production, it should be understood the assemblies and methods may be utilized in conjunction with other tubular strings which may be lowered into thewellbore 102 for various other purposes, e.g., water production, workover procedures, treatment procedures, or combinations thereof. Further, it should be understood that thewellbore tubular 110 is equally applicable to any type of wellbore tubular being inserted into a wellbore, including as non-limiting examples, drill pipe, production tubing, rod strings, coiled tubing, or combinations thereof. - The embodiment shown in
FIG. 1A illustrates the wellbore tubular 110 as part of aproduction string 115 which has been lowered into thewellbore 102 formed in thesubterranean formation 101. The wellbore tubular 110 and wellbore tubular-conveyeddrill assembly 120 coupled thereto may be conveyed into thewellbore 102 in any conventional manner, and the wellbore tubular-conveyeddrill assembly 120 may be conveyed into thewellbore 102 bywellbore tubular 110. The wellbore tubular-conveyeddrill assembly 120 may be configured to minimize a footprint in the annulus around the wellbore tubular 110 so as to minimize obstruction of fluid(s) produced from thesubterranean formation 101. In an embodiment, the wellbore tubular-conveyeddrill assembly 120 may be located in a pocket (e.g., a side pocket mandrel) of thewellbore tubular 110. - Embodiments of the disclosed assemblies and methods may be used in lined wellbores, unlined wellbores, and wellbores having both lined and unlined portions. As seen in
FIG. 1A , thewellbore 102 may be lined with aliner 104, e.g., casing. In alternative operating environments, a vertical portion, a deviated portion, a horizontal portion, or combinations thereof of thewellbore 102 may be cased and cemented, said portions of thewellbore 102 may be uncased, or combinations thereof. In embodiments, theliner 104 may be perforated, unperforated, or combinations thereof. In an embodiment where awellbore 102 has anon-perforated liner 104, the wellbore tubular-conveyeddrill assembly 120 may comprise a perforating charge to perforate theliner 104. To extend theassembly 120 into thesubterranean formation 101, theassembly 120 may drill through the liner 104 (e.g., casing and any associated sealant such as an annular cement sheath) of linedwellbore 102, theassembly 120 may use a perforation charge to create a perforation in theliner 104 of thewellbore 102, or combinations thereof. Likewise, to extend theassembly 120 into thesubterranean formation 101, theassembly 120 may drill through thewall 105 of thewellbore 102, use a perforation charge to create a perforation in thewall 105 of thewellbore 102, or combinations thereof. - In an embodiment, the wellbore tubular-conveyed
drill assembly 120 may be coupled to theoutside surface 112 of thewellbore tubular 110. In alternative or additional embodiments, part or all of the wellbore tubular-conveyeddrill assembly 120 may be interiorly located in the production tubing of awellbore tubular 110. Although one wellbore tubular-conveyeddrill assembly 120 is shown inFIG. 1A , it should be understood that more than one wellbore tubular-conveyeddrill assembly 120 may be coupled to the outside surface ofwellbore tubular 110 and/or other wellbore tubulars in theproduction string 115. The wellbore tubular-conveyeddrill assembly 120 may be placed anywhere on the circumference of thewellbore tubular 110, and in embodiments, multiple wellbore tubular-conveyed drill assemblies may be placed along the circumference of a given length of thewellbore tubular 110. Regardless of the type of operational environment the wellbore tubular-conveyeddrill assembly 120 is used, it should be understood that the wellbore tubular-conveyeddrill assembly 120 may serve to form one or more side boreholes and increase production of fluids from thesubterranean formation 101 through thewellbore 102. - Referring to
FIG. 1B , an embodiment of the wellbore tubular-conveyeddrill assembly 120 may be seen placed inwellbore 102. The wellbore tubular-conveyeddrill assembly 120 may comprise thewellbore tubular 110, anelectrical drilling mechanism 150 coupled to theoutside surface 112 of thewellbore tubular 110, and apower source 140 coupled to theelectrical drilling mechanism 150. Theelectrical drilling mechanism 150 may have a retracted position and an extended position, and theelectrical drilling mechanism 150 may drill one or more openings in thesubterranean formation 101 when in the extended position. Theelectrical drilling mechanism 150 is shown inFIG. 1B in the retracted position. In the embodiment ofFIG. 1B , theelectrical drilling mechanism 150 may comprise aflexible rod 157 and adrill bit 180 coupled to theflexible rod 157, and theelectrical drilling mechanism 150 may be configured to extend theflexible rod 157 so as to engage thedrill bit 180 with theliner 104,wellbore wall 105, and/orsubterranean formation 101. In embodiments, theelectrical drilling mechanism 150 may comprise one ormore perforating charges 192 to perforate aliner 104 of thewellbore 102, awall 105 of thewellbore 102, thesubterranean formation 101, or combinations thereof. The wellbore tubular-conveyeddrill assembly 120 may optionally comprise ahousing 130 coupled to theoutside surface 112 of thewellbore tubular 110, and theelectrical drilling mechanism 150 may be at least partially contained in thehousing 130 when in the refracted position. Thedrill bit 180 may be coupled to and rotated bymotor 156. Theelectrical drilling mechanism 150 may include a propulsion mechanism 160 (e.g., coupled to theflexible body 157 in the embodiment ofFIG. 1B ) to extend theelectrical drilling assembly 150 in a direction away from thewellbore tubular 110. For example, thepropulsion mechanism 160 may drive thedrill bit 180 in a direction away from the wellbore tubular 110 (e.g., in a radial direction) and into thesubterranean formation 101. - “A direction away” as used herein may refer to a general movement away from the wellbore tubular 110 (e.g., away from a central longitudinal axis defined by the wellbore tubular 110) without limitation as to the angle between the direction of movement and the longitudinal axis of the
wellbore tubular 110, and without limitation to any intermittent or transient movements toward the wellbore tubular 110 when the overall or net movement is away from thewellbore tubular 110. For example, theelectrical drilling mechanism 150 may follow a path which requires moving upward within thewellbore 102, moving outward to theliner 104 orwall 105 ofwellbore 102, moving backward toward thewellbore tubular 110, or combinations thereof in any sequence, and such movements may be considered “a direction away” for purposes of the disclosure. In another example, repeated (e.g., piston-like) movements of theelectrical drilling mechanism 150 toward theliner 104 orwall 105 of thewellbore 102 may be considered “a direction away” for purposes of the disclosure. The term “a direction away” may also refer to the movements of theelectrical drilling mechanism 150 in the embodiments described herein. In an embodiment, “a direction away” means any net amount of movement beyond thewellbore wall 105 and into the surroundingsubterranean formation 101 in any direction relative to an initial starting point. - Referring to
FIG. 1C , the embodiment of the wellbore tubular-conveyeddrill assembly 120 ofFIG. 1B may be seen in the extended position.Motor 166 of thepropulsion mechanism 160 has extended theflexible rod 157 from thehousing 130 of the wellbore tubular-conveyeddrill assembly 120. Theflexible rod 157 of theelectrical drilling mechanism 150 has extended toward thewall 105 of thewellbore 102 so as to move thedrill bit 180 in a direction away from thewellbore tubular 110 and engage thedrill bit 180 with thesubterranean formation 101. The perforation charge (reference numeral 192 inFIG. 1B ) has createdperforation 103 in liner 104 (additionally or alternatively, the wall 105) of thewellbore 102. In alternative or additional embodiments having a linedwellbore 102, thedrill bit 180 may drill through theliner 104 of thewellbore 102. InFIG. 1C , theelectrical drilling mechanism 150 has drilled through any portion of theliner 104 which was not perforated to an appropriate size by the perforation charge and extended through theperforation 103. Further, theelectrical drilling mechanism 150 has drilled through thewall 105 of thewellbore 102, and into thesubterranean formation 101. Thedrill bit 180 has drilled anopening 106 in thesubterranean surface 101. -
Motor 166 of thepropulsion mechanism 160 may be coupled to thepower source 140 viacable 155. In embodiments,motor 156 may likewise be coupled topower source 140, for example, through a connection to thepropulsion mechanism 160, directly to thepower source 140, or combinations thereof. In alternative or additional embodiments, thepropulsion mechanism 160 and/ormotor 156 may be coupled to a battery with or without need for cables, such ascable 155. In alternative or additional embodiments, thepropulsion mechanism 160 and/ormotor 156 may be coupled to a power source external to the wellbore tubular-conveyeddrill assembly 120. Examples of external power sources may include sources in downhole tools and/or components, sources in a side pocket mandrel, sources at the surface, the like, or combinations thereof. In alternative or additional embodiments, themotor 166 of thepropulsion mechanism 160 may be coupled to a battery, which is coupled to a power source. In alternative or additional embodiments, themotor 156 may be coupled to a battery, which is coupled to a power source. - The
power source 140 may comprise any device capable of being electrically coupled and/or providing power to theassembly 120. In an embodiment, thepower source 140 may be an on-board DC battery coupled to themotor 166,motor 156, or another battery withinassembly 120, for example. Alternatively, thepower source 140 may be located on the rig surface. Current may be delivered to theassembly 120 through wireless power transmission or a power wireline connected to theassembly 120, such ascable 155. For example, thepower source 140 may comprise a downhole generator, such as a fluid turbine, that may be used to convert fluid flow into power to theassembly 120. - In embodiments,
motor 166 may move with theflexible rod 157, or may associate with moving parts which move theflexible rod 157, while themotor 166 remains stationary. Thecable 155 may be of suitable length for extending and retracting theelectrical drilling mechanism 150. Thehousing 130 may have a shape suitable for containing theelectrical drilling mechanism 150 therein. In the embodiment ofFIG. 1C , theflexible rod 157 may have a cylindrical shape, andhousing 130 may correspondingly have a cylindrical shape. Length of extension, drilling time, drilling rate, and useful life for the disclosed assemblies are described hereinbelow. - In embodiments, one or more openings (e.g., opening 106) may be drilled in the
subterranean formation 101 with one or more electrical drilling mechanisms, e.g.,electrical drilling mechanism 150. As theelectrical drilling mechanism 150 drills, cuttings are formed. Because of the relatively small size of the disclosed assemblies (discussed hereinbelow), cuttings may also be relatively small compared to cuttings formed in conventional drilling. In an embodiment where one or more openings are drilled during production of fluid(s) in thewellbore 102 from thesubterranean formation 101, the fluid(s) may remove the cuttings. In an alternative embodiment, the cuttings may be removed with fluid (e.g., production fluid, formation fluid, drilling or treatment fluid, combinations thereof, etc.) flowing through the disclosedassembly 120. For example, theflexible rod 157 and thedrill bit 180 of the wellbore tubular-conveyeddrill assembly 120 may be hollow and have a continuous channel extending therethrough (e.g., longitudinally). The channel may be coupled to the interior of thewellbore tubular 110, and fluid may be directed into the hollow channel formed in theflexible rod 157 and thedrill bit 180 of the wellbore tubular-conveyed drill assembly 120 (e.g., concurrent with drilling of the well, concurrent with producing the well, after production subsides, etc.). The fluid (e.g., a production or formation fluid) may be pressurized in the wellbore tubular 110 so as to force fluid through the hollow channel and out of thedrill bit 180 of the wellbore tubular-conveyeddrill assembly 120, thereby circulating fluid and the cuttings out ofopening 106. In an additional or alternatively embodiment, the production string 115 (e.g., the wellbore tubular 110) may be plugged below the wellbore tubular-conveyeddrilling assembly 120 to pressurize fluid through the hollow channel and out of thedrill bit 180 of the wellbore tubular-conveyeddrill assembly 120. -
FIG. 2A shows a cut-away side view of another embodiment of a wellbore tubular-conveyeddrill assembly 220 in a retracted position. In embodiments, theassembly 220 may comprise anelectrical drilling mechanism 250 coupled to anoutside surface 212 of awellbore tubular 210. In alternative or additional embodiments, theelectrical drilling mechanism 250 may be interiorly located in the production tubing of awellbore tubular 210. Theelectrical drilling mechanism 250 may comprise arotating drill rod 270 configured to rotate so as to engage the liner (e.g., of the type ofliner 104 shown inFIGS. 1A-1C ), thewellbore wall 205, and/or thesubterranean formation 201. Therotating drill rod 270 may comprise one or more cutting surfaces 272 along at least a portion of a length thereof. A cuttingsurface 272 may comprise cutting teeth, a diamond bit, a cutting bit, an auger, or combinations thereof, for example. In alternative or additional embodiments, the cuttingsurface 272 may extend along the circumference of therotating drill rod 270. In embodiments, theassembly 220 may be held in a retracted position via a holding mechanism (e.g., latch, clip, bracket, magnet, abutment, electromechanical lock, the like, or combinations thereof), an electric motor (e.g.,motor 266 of propulsion mechanism 260), an adhesive (e.g., chemical or time or pressure or temperature activated release, the like, or combinations thereof), or combinations thereof. -
FIG. 2B shows a cut-away side view of the embodiment of the wellbore tubular-conveyeddrill assembly 220 ofFIG. 2A in an extended position.Motor 266 may move theassembly 220 to the extended position so as to engage a wall 205 (alternatively or additionally, a liner) of thewellbore 202 and drill into thesubterranean formation 201. In an embodiment,motor 266 may move or rotate theassembly 220 about a pivot point located on theoutside surface 212 of thewellbore tubular 210. In an alternative embodiment, an adhesive holding theassembly 220 in a refracted position may release due to elapsed time, chemical environment, temperature, pressure, or combinations thereof. The release may cause theassembly 220 to pivot. In an embodiment,assembly 220 may be braced (e.g., weighted, unbalanced, spring-loaded, etc.) to pivot upon release. In the embodiment shown inFIG. 2B , the wellbore tubular-conveyeddrill assembly 220 has pivoted at end 274 (extendingelectronic drilling mechanism 250 by pivoting) so as to engage the liner (e.g., of the type ofliner 104 shown inFIGS. 1A-1C ), thewellbore wall 205, and/or thesubterranean formation 201 withopposite end 276. Upon pivot, theopposite end 276 of therotating drill rod 270 may move in the direction (e.g., an arc) shown by arrow A. Theopposite end 276 may engage the liner and/or thewall 205 of thewellbore 202 and then drill into thesubterranean formation 201 in the direction shown by arrow A, as themotor 266 of thepropulsion mechanism 260 pivots theassembly 220. Gravity may also act to pivot theassembly 220 while drilling alternatively or in addition to a pivoting force provided by themotor 266. Therotating drill rod 270 may rotate (e.g., clockwise or counterclockwise) along a longitudinal axis thereof, e.g., in the direction shown byarrow B. Motor 256 may be coupled to therotating drill rod 270 so as to rotate therotating drill rod 270 along the longitudinal axis thereof. As therotating drill rod 270 of theelectrical drilling mechanism 250 drills intosubterranean formation 201, opening 206 is formed, and fluids may be produced from opening 206 so as to supplement the fluid(s) produced from thesubterranean formation 201 in thewellbore 202. Power may be supplied tomotor 266 ofassembly 220 in any manner as described herein (e.g., a downhole power source such as a fluid turbine or other power source described hereinbelow). -
FIG. 3A is a cut-away side view of an embodiment of wellbore tubular-conveyeddrill assemblies outside surface 312 ofwellbore tubular 310. Theassemblies Assembly 320 may compriseelectrical drilling mechanism 350 contained inhousing 330,assembly 322 may compriseelectrical drilling mechanism 352 contained inhousing 332,assembly 324 may compriseelectrical drilling mechanism 354 contained inhousing 334, andassembly 326 may compriseelectrical drilling mechanism 356 contained inhousing 336. Thehousings outside surface 312 of thewellbore tubular 310. Thehousings electrical drilling mechanisms wellbore tubular 310 is lowered into thewellbore 302, while fluids are produced from thewellbore 302, while other tools/components/assemblies operate in thewellbore 302, or combinations thereof. Aperforation charge 392 may be placed on one or more of theassemblies assembly 324. In the embodiment ofFIG. 3A , theperforation charge 392 may be placed on thehousing 334 ofassembly 324. In additional or alternative embodiments, a perforation charge may be placed on an electrical drilling mechanism, or a combination of a housing and electrical drilling mechanism. Theperforation charge 392 may be detonated at an appropriate time when engaged with thesubterranean formation 301, either automatically or on command. In one or more embodiments,housings outside surface 312 of the wellbore tubular 310 atpoints housings assemblies points housings FIG. 3A ) so as to provide a desired path or trajectory for theelectrical drilling mechanisms liner 104 shown inFIGS. 1A-1C ),wellbore wall 305, and/orsubterranean formation 301 when theassemblies housings FIG. 3A the angles of the ends ofhousing 330 are different than the angles of the ends ofhousing housing 336, thereby providing differing trajectories for theelectrical drilling mechanisms subterranean formation 301. -
FIG. 3B is a cut-away side view of the embodiment of the wellbore tubular-conveyeddrill assemblies FIG. 3A , shown in the extended position. Each of theassemblies electrical drilling mechanisms liner 104 shown inFIGS. 1A-1C ),wellbore wall 305, and/orsubterranean formation 301. Theelectrical drilling mechanisms FIG. 3B may operate independently of one another. In additional or alternative embodiments, theelectrical drilling mechanisms FIG. 3A ,electrical drilling mechanism 354 has engaged thesubterranean formation 301 and drilledopening 304 beforeother assemblies Electrical drilling mechanism 356 has engaged thesubterranean formation 301 and drilledopening 306.Electrical drilling mechanisms respective housings -
Cable 355 has suppliedelectrical drilling mechanism 354 with power from a power source (e.g., a downhole power source or any other power source as described herein), as hascable 357 forelectrical drilling mechanism 356. In an embodiment,electrical drilling mechanisms - In an embodiment, extending the
electrical drilling mechanism 350 may comprise pivoting a housing (e.g., one or more ofhousings electrical drilling mechanism 350 from within of the housing. As can be seen inFIG. 3B , thehousings wellbore tubular 310. Thehousings electrical drilling mechanisms liner 104 shown inFIGS. 1A-1C ) and/orwall 305 of the subterranean formation 301 (i.e., guide in a direction away from the wellbore tubular 310); thus,housings FIGS. 3B may have a dual function of guiding theelectrical drilling mechanisms subterranean formation 301 as themechanisms housings mechanisms wellbore 302. As can be seen inFIG. 3B , different angles of the ends of housings may provide different paths or trajectories for the electrical drilling mechanisms contained therein. Housings may provide an about horizontal path or trajectory for electrical drilling mechanisms, ashousing 330 provides forelectrical drilling mechanism 350, for example. Housings may provide an upwardly sloping path or trajectory for electrical drilling mechanisms, ashousing 332 provides forelectrical drilling mechanism 352 and ashousing 334 provides forelectrical drilling mechanism 354, for example. Housings may also provide downwardly sloping paths or trajectories, ashousing 336 does forelectrical drilling mechanism 356, for example. - The propulsion mechanisms of the electrical drilling mechanisms may be placed on the front, back, or combinations thereof. For example,
propulsion mechanism 360 is placed on the back ofelectrical drilling mechanism 350.FIG. 3B showspropulsion mechanisms electrical drilling mechanisms Propulsion mechanism 364 ofelectrical drilling mechanism 354 has provided traction in theopening 304 to pull theelectrical drilling mechanism 354 further againstsubterranean formation 301 as theelectrical drilling mechanism 354 drills. Likewise,propulsion mechanism 366 of theelectrical drilling mechanism 356 has provided traction in theopening 306 to pull theelectrical drilling mechanism 356 further againstsubterranean formation 301. Becauseelectrical drilling mechanism 354 has an upward path or trajectory whileelectrical drilling mechanism 356 has a downward path or trajectory, thepropulsion mechanism 364 may use more power thanpropulsion mechanism 366. In embodiments, after being guided byhousings electrical drilling mechanisms -
FIG. 4A shows a side view of an embodiment of anelectrical drilling mechanism 450, for example, of the type that may be used in the embodiments ofFIG. 3 . Theelectrical drilling mechanism 450 may be coupled to a power source (e.g., a downhole power source of the type described herein) via acable 455. Theelectrical drilling mechanism 450 may comprise aspool 453 carried aboard theelectrical drilling mechanism 450. Thespool 453 may provide a length of cable as theelectrical drilling mechanism 450 moves away from the retracted position. The length of thecable 455 may be made available byspool 453 so that theelectrical drilling mechanism 450 unwinds thespool 453 as theelectrical drilling mechanism 450 drills into a subterranean formation. In embodiments, thespool 453 may have a reel configuration, an end-feed configuration (which may feed lengths ofcable 455 from the interior or outside of the spooled cable 455), or combinations thereof. In embodiments, thespool 453 may have a conical shape, a cylindrical shape, or combinations thereof. In embodiments with aspool 453, thecable 455 may be carried aboardelectrical drilling mechanism 450 and lengthened when theelectrical drilling mechanism 450 drills further into the subterranean formation; thus, theelectrical drilling mechanism 450 does not have to drag or pull lengths of cable in order to extend further into the subterranean formation. Moreover, risks of catching or tangling thecable 455 are minimized because theelectrical drilling mechanism 450 may carry thecable 455 and release lengths ofcable 455 as needed. Thecable 455 may have an end attached to a housing of the disclosed assemblies, for example. In an alternative or additional embodiment, thecable 455 may enable communication with and/or control of theelectronic drilling mechanism 450. - The
electrical drilling mechanism 450 may comprise abody 451, and thebody 451 may comprise thecable 455 and associatedspool 453, apropulsion mechanism 460, and amotor 456 for operating thedrill bit 480. Thedrill bit 480 may be operably coupled to themotor 456. Thepropulsion mechanism 460 may comprise amotor 466 andwheels 462 coupled to themotor 466. InFIG. 4A thepropulsion mechanism 460 has sixwheels 462 associated withmotor 466; however, it should be understood any number of wheels may be used which would be suitable for burrowing theelectrical drilling mechanism 450 through subterranean formations as thedrill bit 480 drills therein. In the embodiment ofFIG. 4A , thedrill bit 480 comprises a single drill head 482. Thedrill bit 480 may have a diameter of suitable size so as to allowwheels 462 into an opening in the subterranean formation. The diameter of thedrill bit 480 may be, for example, two inches or less. Thedrill bit 480 may be of any configuration known in the art for engaging subterranean formations. For example, thedrill bit 480 may comprise a fixed blade bit, a roller cone bit, a reamer-type bit, or any other type of bit. InFIG. 4A , thewheels 462 are positioned on thebody 451 of theelectrical drilling mechanism 450 adjacent the drill bit 480 (e.g., adjacent the front), however, in alternative or additional embodiments (e.g.,assembly 350 inFIG. 3B ), thewheels 462 may be positioned adjacent the end of theelectrical drilling mechanism 450 opposite the drill bit 480 (e.g., adjacent the back). Themotors motors motors - In an embodiment, the
electrical drilling mechanism 450 of the wellbore tubular-conveyed assembly may include anexplosive charge 490. In an embodiment, theexplosive charge 490 may detonate (e.g., manually or automatically) upon reaching a terminal or predetermined distance in the openings in the subterranean formation formed by the electrical drilling mechanism 450 (e.g., upon reaching the end ofcable 455 onspool 453.). The detonation of explosives may aid in fracturing the subterranean formation to increase production of fluid(s) therefrom. Explosives and detonation techniques may be of any suitable type known to those skilled in the art with the aid of this disclosure. -
FIG. 4B shows a side view of another embodiment of theelectrical drilling mechanism 452. The configuration of theelectrical drilling mechanism 452 shares a common configuration with theelectrical drilling mechanism 450 ofFIG. 4A . Theelectrical drilling mechanism 452 may have apropulsion mechanism 460 comprising amotor 466,wheels 462 coupled to themotor 466, and atrack 464 wrapped around thewheels 462. Thetrack 464 may be of any suitable configuration for providing traction for theelectrical drilling mechanism 452 in an opening formed in a subterranean formation. Thedrill bit 481 of theelectrical drilling mechanism 452 may havemultiple heads drill bit 481 may be of a suitable size so thattrack 464 may fit into an opening in a subterranean formation drilled by thedrill bit 481. Thedrill bit 481 may be of any configuration known in the art for engaging subterranean formations, including fixed blade bits, roller cone bits, reamer-type bits, etc. In an embodiment,drill bit 481 may contain anexplosive charge 490, and thedrill bit 481 may be configured such thatexplosive charge 490 is effective as a shaped charge. -
FIG. 4C shows a side view of yet another embodiment of anelectrical drilling mechanism 454. The configuration of theelectrical drilling mechanism 454 shares a common configuration with theelectrical drilling mechanism 450 ofFIG. 4A . Theelectrical drilling mechanism 454 may further comprise a telescoping body havingtelescoping members propulsion mechanism 460. Thepropulsion mechanism 460 may compriseslips slips slips slips electrical drilling mechanism 454 to advance to an extended position by extension and contraction of theslips Slips drill bit 480.Slips drill bit 480 drills an opening into a subterranean formation, slip 461 may contract radially inward and slip 463 may expand radially outward from theelectrical drilling mechanism 454 so an engaging surface thereof contacts the subterranean formation. Thetelescoping members electrical drilling mechanism 454 then expand longitudinally so as to drive thedrill bit 480 into the subterranean formation. When thetelescoping members electrical drilling mechanism 454 so an engaging surface thereof contacts the subterranean formation. Slip 463 may then contract and thetelescoping members slips telescoping members electronic drilling mechanism 454 drills into the subterranean formation. -
FIG. 5 shows a cut-away side view of an embodiment of a wellbore tubular-conveyeddrill assembly 520 comprising an embodiment of adeflector 532. The wellbore tubular-conveyeddrill assembly 520 is in the retracted position. Thedeflector 532 may direct theelectrical drilling mechanism 550 in a direction away from wellbore tubular 510 so as to engage the liner (e.g., of the type ofliner 104 shown inFIGS. 1A-1C ) and/or thewall 505 of thewellbore 502 and thesubterranean formation 501. In embodiments such as the one shown inFIG. 5 , thedeflector 532 may be located adjacent an end of thehousing 530, for example, above thehousing 530. Thedeflector 532 may have anend 535 adjacent to thehousing 530 so thatelectrical drilling mechanism 550 may extend from within of thehousing 530, through thedeflector 532, and urged toward the liner (e.g., of the type ofliner 104 shown inFIGS. 1A-1C ) and/or thewall 505 of thewellbore 502. In alternative embodiments, thedeflector 532 is not utilized in conjunction with a housing and still serves to direct theelectrical drilling mechanism 550. As seen inFIG. 5 , thedeflector 532 may have anend 534 having a curved taper or other directional shape. Theend 534 may have anopening 533 facing the liner (e.g., of the type ofliner 104 shown inFIGS. 1A-1C ) and/orwall 505 of thewellbore 502. Theend 534 may have a curved or other contour which may guide theelectrical drilling mechanism 550 through theopening 533 in a direction away from thewellbore tubular 510. In an embodiment, thedeflector 532 may be extendable and retractable from and to thehousing 530. In other embodiments, thedeflector 532 may be integrally formed with thehousing 530. In an alternative embodiment, thedeflector 532 may be located below thehousing 530. -
FIG. 6 shows a cut-away side view of an embodiment of a wellbore tubular-conveyeddrill assembly 620 comprising another embodiment of adeflector 632. The wellbore tubular-conveyeddrill assembly 620 is in the retracted position. Thedeflector 632 may direct theelectrical drilling mechanism 650 in a direction away from wellbore tubular 610 so as to engage the liner (e.g., of the type ofliner 104 shown inFIGS. 1A-1C ) and/or thewall 605 of thewellbore 602. In embodiments such as the one shown inFIG. 6 , thedeflector 632 may be located adjacent an end of thehousing 630, for example, below thehousing 630. Thedeflector 632 may have anend 633 adjacent to thehousing 630 so thatelectrical drilling mechanism 650 may extend from within of thehousing 630, through thedeflector 632, and guided toward the liner (e.g., of the type ofliner 104 shown inFIGS. 1A-1C ) and/orwall 605 of thewellbore 602. In alternative embodiments, thedeflector 632 is not utilized in conjunction with a housing and still serve to direct theelectrical drilling mechanism 650. Thedeflector 632 may have a curvature which allowselectrical drilling mechanism 650 to pass therethrough to engage with thewall 605 of thewellbore 602 and thus, thesubterranean formation 601. In an embodiment, thedeflector 632 may be extendable and retractable from and to thehousing 630. In other embodiments, thedeflector 632 may be integrally formed with thehousing 630. In an alternative embodiment, thedeflector 632 may be located above thehousing 630. - The slow drilling techniques embodied by the disclosed assemblies and methods may use available downhole power to increase production in a wellbore. In such an embodiment, the power source may supply power for the purpose of operating the assemblies described herein. The power source may be carried with, attached, incorporated within or otherwise suitably coupled to an assembly. In embodiments, the power source may comprise a power generation device, a battery, bursts of electromagnetic radiation from downhole components, or combinations thereof, for example. In embodiments, the power source may further comprise one or more wirelines (e.g., a cable as described herein) coupled to a battery, one or more other power sources, an assembly described herein, or combinations thereof. In embodiments, the power source may be located at the surface, within the wellbore, or both.
- In embodiments, the power generation device may comprise a generator. The generator may comprise a turbo-generator configured to convert fluid movement into electrical power, a thermoelectric generator configured to convert differences in temperature into electrical power, a conventional fuel-operated generator, a galvanic cell, or combinations thereof, for example. Suitable power generation devices are disclosed in U.S. application Ser. No. 13/031,513 to Roddy, et al., which is incorporated herein by reference in its entirety. In an embodiment, the power source and/or power generation device may be sufficient to power assemblies, for example, in the range of from about 0.5 to about 10 watts, alternatively, from about 0.5 to about 1.0 watts.
- In embodiments, a battery may comprise an internal battery, an external battery, or combinations thereof. In an embodiment, the battery may comprise a lithium ion battery. A battery may be charged prior to and/or after placement of the assemblies into a wellbore. A battery may be rechargeable or otherwise powered and/or recharged by other downhole power sources such as heat capture/transfer and/or fluid flow. In an embodiment, a battery may be inductively rechargeable by a recharging unit lowered into the wellbore via a wireline. For example, a battery charger (e.g., an inductive charger) may be lowered into the wellbore periodically to charge one or more batteries associated with one or more assemblies.
- In the one or more of the various embodiments described herein, a motor may comprise any electrically-powered motor known to those skilled in the art which is suitable for rotating a drill bit so as to drill into subterranean formation and/or for extending the electrical drilling mechanism. For example, a motor may comprise a gear box. Alternatively or additionally, a motor may comprise a hydraulic motor known to those skilled in the art which may be coupled to an electrically-powered pump. In embodiments, a motor may utilize or drive tracks, channels, wheels, cogs, or combinations thereof to extend the electrical drilling mechanism.
- In one or more embodiments, the disclosed assemblies and methods may be utilized during production of fluids in the wellbore, such as before or after maximum production is achieved. In an embodiment, the slow drilling techniques embodied in the disclosed assemblies and methods may be utilized in the first few days of production of a wellbore so as to boost initial production levels. In additional or alternative embodiments, the slow drilling techniques embodied in the disclosed assemblies and methods is implemented over the life of a well so as to offset production subsidence due to depletion, plugging, sanding, or combinations thereof, for example. In alternative embodiments, the slow drilling techniques embodied in the disclosed assemblies and methods may be delayed until production of fluid from the subterranean formation in the wellbore subsides. For example, drilling the one or more openings may be delayed until production subsides. In embodiments where the disclosed assemblies and methods are utilized with drill strings, it may be possible for a well to begin production of fluids through the openings before drilling of the wellbore is complete. In alternative or additional embodiments, it may be possible to begin production of the wellbore while drilling (i.e., before completion of the wellbore) because of the openings formed in the walls of the wellbore (i.e., into the subterranean formation) by the disclosed assemblies and methods.
- Embodiments of the assemblies and methods contemplate drilling techniques which may occur continuously, intermittently, or combinations thereof over relatively long periods of time so as to provide a novel “slow” drilling technique. In an embodiment, drilling one or more openings may operate continuously. Drilling may commence and operate continuously until an event happens, such as depletion of a battery, disconnection of a power source, failure of an assembly, failure of an electrical drilling mechanism, or combinations thereof. In an embodiment, drilling one or more openings may operate intermittently. Drilling may start and stop—by control with constant power availability, by usage of battery than needs recharging after power depletion, or combinations thereof. For example, the power source may charge the battery (e.g., battery pack) to full capacity, and the wellbore tubular-conveyed drill assembly operates until the battery drains of power. The battery may then be charged by a power source, and the wellbore tubular-conveyed drill assembly operates in this cycle until failure. Alternatively, drilling may occur intermittently subject to available excess or non-utilized downhole power being intermittently available. In this way, excess or non-utilized downhole power is used to further enhance production. In an embodiment, drilling one or more openings may operate both continuously and intermittently. For example, one assembly in accordance with the disclosed embodiments may operate continuously as described above while another operates intermittently as described above.
- The slow drilling techniques disclosed herein may be further characterized by the useful life, drilling rate, extension length, and drilling time. The disclosed assemblies may drill openings in a wall of a wellbore and into a subterranean formation over a time of years by drilling and extending a distance of inches per month. In embodiments, the useful life of the disclosed assemblies and methods may comprise about 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17, 18, 19, or 20 years, for example. In embodiments, the drill rate of the disclosed assemblies and methods may be about 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 24, 36, 48, or 60 or greater inches per month, for example. In one or more embodiments, the disclosed assemblies may operate until failure, i.e. the useful life may be the time it takes for the assembly to fail. Many electrical drilling mechanisms may be coupled to the outside surface of a wellbore tubular, and when one or more fails (i.e., reaches a useful life due to, for example, manufacturing flaws, unexpected downhole forces, etc.) others may continue to drill over time as power becomes available. In embodiments, the electrical drilling mechanisms may extend from about 1 ft to about 50 ft or more over the useful life; alternatively, from about 5 ft to about 20 ft; alternatively, from about 10 ft to about 15 ft. In embodiments, an electrical drilling mechanism may drill for any amount of time when power is available. Such amounts of time may include, for example, a few hours, minutes, or days per month; a few weeks or months a year; a few years per lifetime of the well.
- Embodiments of the electrical drilling mechanism may operate without control, with control, or combinations thereof. When operating without control, the electrical drilling mechanism may operate when power is available from power source and be inoperable when power is not available. In other embodiments, an amount of programming may be embedded in an assembly so an electrical drilling mechanism drills only after extension from a housing, for example. When operating with control, control may be automated with an electronic controller (e.g., a PID controller, a fuzzy logic controller, etc.). In other embodiments, control may be manual (e.g., by an operator input or programming at the surface).
- The propulsion mechanisms disclosed herein may operate to direct the electrical drilling mechanisms in a direction away from the wellbore tubular and into the opening formed in the subterranean formation. The propulsion mechanisms may have various techniques for driving the electrical drilling mechanism in a direction away from the wellbore tubular into the subterranean formation, including pushing, pivoting, pulling, or combinations thereof. For example,
FIGS. 1B and 1C show apropulsion mechanism 160 which operates to push theelectrical drilling mechanism 150 in theopening 106 formed in thesubterranean formation 101.FIGS. 2A and 2B show apropulsion mechanism 260 which operates to pivot theelectrical drilling mechanism 250 to create opening 206 in the subterranean formation.FIG. 3B showspropulsion mechanisms electrical drilling mechanisms propulsion mechanism 360 operates to pushelectrical drilling mechanism 350.FIG. 4C shows apropulsion mechanism 460 which utilizes both pulling and pushing to drive theelectrical drilling mechanism 454 in a direction away from a wellbore tubular. - The assemblies and methods disclosed herein may operate to drill openings through the wall of a wellbore and into a subterranean formation. Although a direction of the openings is not limited, the openings may generally comprise side boreholes, for example. The openings drilled according to the disclosure may produce fluid(s) from the subterranean formation. Additionally, the assemblies and methods may be used to fracture the subterranean formation to increase production of fluid(s) therefrom. As discussed above, fracturing may occur by detonating an explosive charge in one or more openings. Fracturing may also occur by flowing fracturing fluid into an opening under fracturing conditions (e.g., hydraulic fracturing one or more boreholes produced by slow drilling as described herein).
- The following are nonlimiting, specific embodiments in accordance with the present disclosure:
- A first embodiment, which is a wellbore tubular-conveyed drill assembly comprising:
- a wellbore tubular;
- an electrical drilling mechanism coupled to an outside surface of the wellbore tubular, wherein the electrical drilling mechanism has a retracted position and an extended position, wherein the electrical drilling mechanism drills one or more openings in a subterranean formation when in the extended position; and
- a power source coupled to the electrical drilling mechanism.
- A second embodiment, which is the assembly of the first embodiment, wherein the electrical drilling mechanism comprises a flexible rod and a drill bit coupled to the flexible rod, wherein the electrical drilling mechanism is configured to extend the flexible rod to engage the drill bit with the subterranean formation.
- A third embodiment, which is the assembly of any of the first to second embodiments, wherein the electrical drilling mechanism comprises:
- a drill bit; and
- a propulsion mechanism configured to drive the drill bit in a direction away from the wellbore tubular into the subterranean formation.
- A fourth embodiment, which is the assembly of any of the first to third embodiments, wherein the electrical drilling mechanism comprises:
- a spool carried aboard the electrical drilling mechanism, wherein the spool provides a length of cable as the electrical drilling mechanism moves away from the retracted position.
- A fifth embodiment, which is the assembly of any of the third to fourth embodiments, wherein the propulsion mechanism comprises:
- a plurality of wheels for burrowing the electrical drilling mechanism through the subterranean formation.
- A sixth embodiment, which is the assembly of any of the third to fifth embodiments, wherein the propulsion mechanism further comprises:
- a track wrapped around the plurality of wheels for providing traction for the electrical drilling mechanism in an opening formed in the subterranean formation.
- A seventh embodiment, which is the assembly of any of the third to sixth embodiments, wherein the electrical drilling mechanism further comprises a telescoping body associated with the propulsion mechanism, wherein the propulsion mechanism comprises:
- at least two slips associated with the telescoping body.
- An eighth embodiment, which is the assembly of any of the first to seventh embodiments, wherein the electrical drilling mechanism comprises a rotating drill rod configured to rotate and engage the subterranean formation, wherein the rotating drill rod comprises a cutting surface along at least a portion of a length thereof.
- A ninth embodiment, which is the assembly of any of the first to eighth embodiments, wherein the electrical drilling mechanism pivots at one end so as to engage the subterranean formation with an opposite end.
- A tenth embodiment, which is the assembly of any of the first to ninth embodiments, wherein the electrical drilling mechanism comprises one or more perforating charges.
- An eleventh embodiment, which is the assembly of any of the first to tenth embodiments, further comprising a housing coupled to the outside surface of the wellbore tubular, wherein the electrical drilling mechanism is at least partially contained in the housing when in the refracted position.
- A twelfth embodiment, which is the assembly of the eleventh embodiment, wherein the housing is configured to pivot relative to the wellbore tubular.
- A thirteenth embodiment, which is the assembly of any of the first to twelfth embodiments, further comprising a deflector configured to direct the drilling mechanism in a direction away from the wellbore tubular.
- A fourteenth embodiment, which is a method comprising:
- extending an electrical drilling mechanism in a direction away from a wellbore tubular, wherein the electrical drilling mechanism is coupled to an outside surface of the wellbore tubular; and
- drilling one or more openings in a subterranean formation with the electrical drilling mechanism.
- A fifteenth embodiment, which is the method of the fourteenth embodiment, further comprising:
- drilling a wellbore; and
- inserting a production string comprising the wellbore tubular into the wellbore.
- A sixteenth embodiment, which is the method of any of the fourteenth to fifteenth embodiments, wherein the one or more openings increase a producing area of the wellbore.
- A seventeenth embodiment, which is the method of any of the fourteenth to sixteenth embodiments, further comprising:
- producing a fluid through at least one of the one or more openings.
- An eighteenth embodiment, which is the method of any of the fourteenth to seventeenth embodiments, further comprising:
- producing a fluid from a subterranean formation.
- A nineteenth embodiment, which is the method of any of the seventeenth to eighteenth embodiments, wherein drilling the one or more openings occurs during producing the fluid, the method further comprising:
- removing a cutting from the wellbore with the fluid produced from the subterranean formation.
- A twentieth embodiment, which is the method of any of the fourteenth to nineteenth embodiments, further comprising:
- delaying drilling the one or more openings until production of the fluid subsides.
- A twenty-first embodiment, which is the method of any of the fourteenth to twentieth embodiments, wherein drilling one or more openings occurs intermittently, continuously, or combinations thereof.
- A twenty-second embodiment, which is the method of any of the fourteenth to twenty-first embodiments, wherein drilling one or more openings occurs over a period of time greater than one year.
- A twenty-third embodiment, which is the method of any of the fourteenth to twenty-second embodiments, wherein extending the electrical drilling mechanism comprises:
- pivoting the electrical drilling mechanism.
- A twenty-fourth embodiment, which is the method of any of the fourteenth to twenty-third embodiments, further comprising:
- pivoting a housing in a direction away from the wellbore tubular, wherein extending the electrical drilling mechanism comprises extending the electrical drilling mechanism from within the housing.
- A twenty-fifth embodiment, which is the method of any of the fourteenth to twenty-fourth embodiments, wherein extending the electrical drilling mechanism comprises:
- driving the electrical drilling mechanism in a direction away from the wellbore tubular into the subterranean formation.
- A twenty-sixth embodiment, which is the method of any of the fourteenth to twenty-fifth embodiments, wherein extending the electrical drilling mechanism comprises:
- guiding the electrical drilling mechanism in the direction away from the wellbore tubular.
- A twenty-seventh embodiment, which is the method of any of the fourteenth to twenty-sixth embodiments, further comprising:
- creating a perforation in a liner or a wall of the wellbore, wherein the electrical drilling mechanism extends through the perforation.
- A twenty-eighth embodiment, which is the method of any of the fourteenth to twenty-seventh embodiments, further comprising:
- detonating an explosive charge within the one or more openings.
- A twenty-ninth embodiment, which is the method of any of the fourteenth to twenty-eighth embodiments, further comprising:
- fracturing the subterranean formation via the one or more openings.
- A thirtieth embodiment, which is the method of any of the fourteenth to twenty-ninth embodiments, further comprising:
- operating the electrical drilling mechanism until failure.
- A thirty-first embodiment, which is a method comprising:
- providing a wellbore tubular-conveyed drill assembly coupled to an outside surface of a wellbore tubular, wherein the wellbore tubular-conveyed drill assembly has a continuous hollow channel extending therethrough;
- coupling the continuous hollow channel to an interior of the wellbore tubular;
- pressurizing the interior of the wellbore tubular with a drilling fluid;
- directing the drilling fluid through the continuous hollow channel; and
- drilling one or more openings in a subterranean formation with the wellbore tubular-conveyed drill assembly.
- A thirty-second embodiment, which is the method of the thirty-first embodiment, further comprising:
- extending the wellbore tubular-conveyed drill assembly in a direction away from the wellbore tubular.
- A thirty-third embodiment, which is the method of any of the thirty-first to thirty-second embodiments, further comprising:
- providing a production string comprising the wellbore tubular; and
- plugging the production string below the wellbore tubular-conveyed drill assembly.
- At least one embodiment is disclosed and variations, combinations, and/or modifications of the embodiment(s) and/or features of the embodiment(s) made by a person having ordinary skill in the art are within the scope of the disclosure. Alternative embodiments that result from combining, integrating, and/or omitting features of the embodiment(s) are also within the scope of the disclosure. Where numerical ranges or limitations are expressly stated, such express ranges or limitations should be understood to include iterative ranges or limitations of like magnitude falling within the expressly stated ranges or limitations (e.g., from about 1 to about 10 includes, 2, 3, 4, etc.; greater than 0.10 includes 0.11, 0.12, 0.13, etc.). For example, whenever a numerical range with a lower limit, Rl, and an upper limit, Ru, is disclosed, any number falling within the range is specifically disclosed. In particular, the following numbers within the range are specifically disclosed: R=Rl+k*(Ru−R1), wherein k is a variable ranging from 1 percent to 100 percent with a 1 percent increment, i.e., k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, . . . , 50 percent, 51 percent, 52 percent, . . . , 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent. Moreover, any numerical range defined by two R numbers as defined in the above is also specifically disclosed. Use of the term “optionally” with respect to any element of a claim means that the element is required, or alternatively, the element is not required, both alternatives being within the scope of the claim. Use of broader terms such as comprises, includes, and having should be understood to provide support for narrower terms such as consisting of, consisting essentially of, and comprised substantially of Accordingly, the scope of protection is not limited by the description set out above but is defined by the claims that follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated as further disclosure into the specification and the claims are embodiment(s) of the disclosed subject matter.
Claims (33)
1. A wellbore tubular-conveyed drill assembly comprising:
a wellbore tubular;
an electrical drilling mechanism coupled to an outside surface of the wellbore tubular, wherein the electrical drilling mechanism has a retracted position and an extended position, wherein the electrical drilling mechanism drills one or more openings in a subterranean formation when in the extended position; and
a power source coupled to the electrical drilling mechanism.
2. The assembly of claim 1 , wherein the electrical drilling mechanism comprises a flexible rod and a drill bit coupled to the flexible rod, wherein the electrical drilling mechanism is configured to extend the flexible rod to engage the drill bit with the subterranean formation.
3. The assembly of claim 1 , wherein the electrical drilling mechanism comprises:
a drill bit; and
a propulsion mechanism configured to drive the drill bit in a direction away from the wellbore tubular into the subterranean formation.
4. The assembly of claim 1 , wherein the electrical drilling mechanism comprises:
a spool carried aboard the electrical drilling mechanism, wherein the spool provides a length of cable as the electrical drilling mechanism moves away from the retracted position.
5. The assembly of claim 3 , wherein the propulsion mechanism comprises:
a plurality of wheels for burrowing the electrical drilling mechanism through the subterranean formation.
6. The assembly of claim 3 , wherein the propulsion mechanism further comprises:
a track wrapped around the plurality of wheels for providing traction for the electrical drilling mechanism in an opening formed in the subterranean formation.
7. The assembly of claim 3 , wherein the electrical drilling mechanism further comprises a telescoping body associated with the propulsion mechanism, wherein the propulsion mechanism comprises:
at least two slips associated with the telescoping body.
8. The assembly of claim 1 , wherein the electrical drilling mechanism comprises a rotating drill rod configured to rotate and engage the subterranean formation, wherein the rotating drill rod comprises a cutting surface along at least a portion of a length thereof.
9. The assembly of claim 1 , wherein the electrical drilling mechanism pivots at one end so as to engage the subterranean formation with an opposite end.
10. The assembly of claim 1 , wherein the electrical drilling mechanism comprises one or more perforating charges.
11. The assembly of claim 1 , further comprising a housing coupled to the outside surface of the wellbore tubular, wherein the electrical drilling mechanism is at least partially contained in the housing when in the retracted position.
12. The assembly of claim 11 , wherein the housing is configured to pivot relative to the wellbore tubular.
13. The assembly of claim 1 , further comprising a deflector configured to direct the drilling mechanism in a direction away from the wellbore tubular.
14. A method comprising:
extending an electrical drilling mechanism in a direction away from a wellbore tubular, wherein the electrical drilling mechanism is coupled to an outside surface of the wellbore tubular; and
drilling one or more openings in a subterranean formation with the electrical drilling mechanism.
15. The method of claim 14 , further comprising:
drilling a wellbore; and
inserting a production string comprising the wellbore tubular into the wellbore.
16. The method of claim 14 , wherein the one or more openings increase a producing area of the wellbore.
17. The method of claim 14 , further comprising:
producing a fluid through at least one of the one or more openings.
18. The method of claim 14 , further comprising:
producing a fluid from a subterranean formation.
19. The method of claim 17 , wherein drilling the one or more openings occurs during producing the fluid, the method further comprising:
removing a cutting from the wellbore with the fluid produced from the subterranean formation.
20. The method of claim 14 , further comprising:
delaying drilling the one or more openings until production of the fluid subsides.
21. The method of claim 14 , wherein drilling one or more openings occurs intermittently, continuously, or combinations thereof.
22. The method of claim 14 , wherein drilling one or more openings occurs over a period of time greater than one year.
23. The method of claim 14 , wherein extending the electrical drilling mechanism comprises:
pivoting the electrical drilling mechanism.
24. The method of claim 14 , further comprising:
pivoting a housing in a direction away from the wellbore tubular, wherein extending the electrical drilling mechanism comprises extending the electrical drilling mechanism from within the housing.
25. The method of claim 14 , wherein extending the electrical drilling mechanism comprises:
driving the electrical drilling mechanism in a direction away from the wellbore tubular into the subterranean formation.
26. The method of claim 14 , wherein extending the electrical drilling mechanism comprises:
guiding the electrical drilling mechanism in the direction away from the wellbore tubular.
27. The method of claim 14 , further comprising:
creating a perforation in a liner or a wall of the wellbore, wherein the electrical drilling mechanism extends through the perforation.
28. The method of claim 14 , further comprising:
detonating an explosive charge within the one or more openings.
29. The method of claim 14 , further comprising:
fracturing the subterranean formation via the one or more openings.
30. The method of claim 14 , further comprising:
operating the electrical drilling mechanism until failure.
31. A method comprising:
providing a wellbore tubular-conveyed drill assembly coupled to an outside surface of a wellbore tubular, wherein the wellbore tubular-conveyed drill assembly has a continuous hollow channel extending therethrough;
coupling the continuous hollow channel to an interior of the wellbore tubular;
pressurizing the interior of the wellbore tubular with a drilling fluid;
directing the drilling fluid through the continuous hollow channel; and
drilling one or more openings in a subterranean formation with the wellbore tubular-conveyed drill assembly.
32. The method of claim 31 , further comprising:
extending the wellbore tubular-conveyed drill assembly in a direction away from the wellbore tubular.
33. The method of claim 31 , further comprising:
providing a production string comprising the wellbore tubular; and
plugging the production string below the wellbore tubular-conveyed drill assembly.
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US2012/051627 WO2014031098A1 (en) | 2012-08-20 | 2012-08-20 | Slow drilling assembly and method |
Publications (1)
Publication Number | Publication Date |
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US20150300092A1 true US20150300092A1 (en) | 2015-10-22 |
Family
ID=50150260
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US14/431,719 Abandoned US20150300092A1 (en) | 2012-08-20 | 2012-08-20 | Slow Drilling Assembly and Method |
Country Status (2)
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US (1) | US20150300092A1 (en) |
WO (1) | WO2014031098A1 (en) |
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WO2014031098A1 (en) | 2014-02-27 |
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