WO2012154932A1 - Method and system for fracking and completing wells - Google Patents

Method and system for fracking and completing wells Download PDF

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Publication number
WO2012154932A1
WO2012154932A1 PCT/US2012/037273 US2012037273W WO2012154932A1 WO 2012154932 A1 WO2012154932 A1 WO 2012154932A1 US 2012037273 W US2012037273 W US 2012037273W WO 2012154932 A1 WO2012154932 A1 WO 2012154932A1
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WO
WIPO (PCT)
Prior art keywords
packer
formation
fracking
liner
interval
Prior art date
Application number
PCT/US2012/037273
Other languages
French (fr)
Inventor
Henry A. Baski
Original Assignee
Baski, Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Baski, Inc. filed Critical Baski, Inc.
Priority to CA2835128A priority Critical patent/CA2835128C/en
Publication of WO2012154932A1 publication Critical patent/WO2012154932A1/en

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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
    • 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

Definitions

  • Oil and gas wells can be treated by fracking (hydraulic fracturing) and chemical injections to increase production.
  • the fracking process occurs after a bore hole has been formed through a formation, and is sometimes referred to as completing the well.
  • Fracking forms fractures in a formation that are typically oriented parallel to the maximum induced stresses in the formation and perpendicular to the minimum induced stresses in the formation.
  • a granular proppant material can be injected into the fractures to hold them open.
  • the fractures provide low resistance flow paths through the formation into the well liner.
  • Chemical injections can also be used separately, or in combination with fracking, to increase flow capacity by dissolving materials or changing formation properties.
  • One fracking method involves drilling a horizontal well bore, and inserting a liner into the well bore.
  • the annulus between the liner and the well bore is then filled with cement.
  • the liner is then perforated in sections of typically from 100 to 1000 feet using a perforating device.
  • a packer on a coiled tubing string can be placed at the lower end of the segment and actuated to establish a hydraulic seal. Hydraulic fracturing can then be performed in the sealed perforated segment. The packer can then be released and moved to repeat the process.
  • This prior art fracking method is expensive as the well bore is relatively large and the liner must be made of high strength steel and cemented in place.
  • the packers have a limited life expectancy and a low reliability.
  • only a limited number of stages can be performed. For example, a 4000 feet horizontal well bore can typically only be treated in 10 stages of 400 feet with each stage having 3-4 perforated zones.
  • Another problem is that the high pressures needed for hydraulic fracturing can damage cemented liners.
  • the present disclosure is directed to a method and system for fracking and completing wells that is better, faster and cheaper than prior art methods and systems. In particular, lower cost materials are used, and the downhole perforating operation and external liner pockets are eliminated. Further, more stages can be performed, more fractures can be formed, more proppant can be injected and higher flow rates can be achieved.
  • a method for fracking and completing a well having a well bore through a formation includes the steps of: packer jack fracking a first interval of the formation using a packer to form a first packer fractured formation, deflating and moving the packer to a second interval in the formation; inflating the packer to seal the first packer fractured formation; hydraulically fracturing the first packer fractured formation by injecting a fracking fluid through the packer, and then repeating the packer jack fracking step, the deflating and moving the packer step, the inflating the packer step and the hydraulically fracturing step through successive intervals of the formation.
  • a perforated liner can be placed in a well bore to direct the fracking fluid into the packer fractured formation.
  • the packer jack fracking step can also be used to break apart the liner to provide flow paths for the fracking fluid through the casing into the packer fractured formation.
  • the method can include the steps of: installing a perforated liner in the well bore having a plurality of pre-formed openings therethrough; installing a packer in the perforated liner at a first interval in the formation; packer jack fracking the first interval using the packer to define a first packer fractured formation; deflating and moving the packer to a second interval in the formation; inflating the packer to seal the first packer fractured formation; hydraulically fracturing the first packer fractured formation by injecting a fracking fluid through the packer and the openings in the perforated liner to form a first hydraulically fractured formation; and packer jack fracking the second interval using the packer to define a second packer fractured formation.
  • the hydraulically fracturing step, the deflating and moving step, the inflating step, and the packer fracturing step of the method can then be repeated through as many intervals as is necessary.
  • a second packer can be used to seal the intervals.
  • the method can include essentially the same steps, but without installing the perforated liner and with the packer jack fracking step performed to break at least one opening through the cemented liner.
  • a system for fracking and completing a well having a well bore through a formation comprises: a perforated liner in the well bore having a plurality of pre-formed openings therethrough, a high pressure drill pipe, a packer actuation tool and a packer in the perforated liner configured to fracture and seal successive intervals in the formation.
  • Figure 1 is a schematic cross sectional view illustrating the step in the method of installing a perforated liner in the bore hole
  • Figure 2 is a schematic cross sectional view illustrating the step in the method of installing a packer at a first interval of the formation
  • Figure 2A is a schematic perspective view of the packer taken along section line 2A-2A of Figure 2 and partially cut away to illustrate a reinforced inflatable element of the packer;
  • Figure 2B is a schematic cross sectional view with parts removed taken along section line 2B-2B of Figure 2A illustrating a grooved outer cover of the packer;
  • Figure 3 is a schematic cross sectional view illustrating the step in the method of packer jack fracking using the packer to form a first packer fractured formation;
  • Figure 3 A is a schematic cross sectional view taken along section line 3A-3A of Figure 3 illustrating primary packer jack fracs in the first packer fractured formation;
  • Figure 3B is a schematic cross sectional view taken along section line 3B-3B of Figure 3 illustrating primary and secondary packer jack fracs in the first packer fractured formation;
  • Figure 4 is a schematic cross sectional view illustrating the step in the method of deflating and moving the packer to a second interval in the formation;
  • Figure 5 is a schematic cross sectional view illustrating the step in the method of hydraulically fracturing the first packer fractured formation by inflating the packer to seal the bore hole and injecting a fracking fluid through the packer and the openings in the perforated liner to form a first hydraulically fractured formation with an optional step in the method of using a second packer to seal the first hydraulically fractured formation shown in phantom lines;
  • Figure 6 is a schematic cross sectional view illustrating the step in the method of packer jack fracking the second interval using the packer to define a second packer fractured formation
  • Figure 7 is a schematic cross sectional view taken along section line 7-
  • Figure 7A is a schematic cross sectional view equivalent to Figure 7 illustrating primary and secondary packer jack fracs in the second packer fractured formation
  • Figure 8 is a schematic cross sectional view taken along section line 8-
  • Figure 8A is a schematic cross sectional view equivalent to Figure 8 illustrating primary and secondary hydraulic fracs in the first hydraulically fractured formation
  • Figure 9 is a schematic cross sectional view equivalent to Figure 1 illustrating a step in an alternate method performed on a well having a liner cemented in the well bore;
  • Figure 9A is a cross sectional view taken along section line 9A-9A of Figure 9;
  • Figure 10 is a schematic cross sectional view equivalent to Figure 2 illustrating the step in the alternate method of installing a packer at a first interval of the formation;
  • Figure 11 is a schematic cross sectional view equivalent to Figure 3 illustrating the step in the alternate method of breaking apart the cemented liner and packer jack fracking the formation using the packer to form a first packer fractured formation;
  • Figure 11 A is a schematic cross sectional view taken along section line 1 lA-11A of Figure 11 illustrating an opening through the cemented liner and primary packer jack fracs in a first packer fractured formation;
  • Figure 12 is a schematic cross sectional view equivalent to Figures 4 and 5 illustrating the steps in the method of deflating and moving the packer to a second interval in the formation, inflating the packer to seal the bore hole, and hydraulically fracturing the first packer fractured formation by injecting a fracking fluid through the packer and the opening in the cemented liner to form a first hydraulically fractured formation;
  • Figure 12A is a schematic cross sectional view taken along section line 12A-12A of Figure 12 illustrating formation of the first hydraulically fractured formation
  • Figure 13 is a schematic cross sectional view equivalent to Figure 2 illustrating an optional step in the alternate method of using a second packer to seal the first hydraulically fractured formation;
  • Figure 14 is a schematic cross sectional view illustrating the step in the alternate method of packer jack fracking the second interval using the packer to define a second packer fractured formation
  • Figure 14A is a schematic cross sectional view taken along section line 14A-14A of Figure 14 illustrating formation of a second packer fractured formation
  • Figure 15 is a schematic cross sectional view illustrating the step in the alternate method of hydraulically fracturing the second packer fractured formation by injecting a fracking fluid through the packer and the opening in the cemented liner to form a second hydraulically fractured formation; and [0036] Figure 15A is a schematic cross sectional view taken along section line 15A-15A of Figure 15 illustrating formation of the second packer fractured formation.
  • Figures 1-6 illustrate steps in a method for fracking and completing a well 10.
  • the well 10 can comprise an oil and gas well or alternately another type of well, such as another gas or liquid well such as a recharge water well.
  • the well 10 includes a well bore 12 that extends from a ground surface into a geological formation 14 at a required depth of typically from several hundred to several thousand feet.
  • the well bore 12 extends through the geological formation 14 in a generally horizontal direction.
  • the well bore 12 can also include a vertical segment, which for simplicity is not shown.
  • the well bore 12 can be smaller than in a conventional oil and gas well.
  • a representative diameter of the well bore 12 can be about 6 inches to 8 inches.
  • the method includes the step of installing a perforated liner 16 in the well bore 12 having a plurality of pre-formed openings 18 therethrough.
  • the perforated liner 16 can comprise metal pipe that has been formed or machined with the openings 18 through the sidewalls, and attached in lengths by welding or threaded connections.
  • the perforated liner 16 has no pressure requirements, it can be made of low strength steel with seams, rather than high pressure seamless steel as with a conventional well liner.
  • the perforated liner 16 can be made relatively cheaply relative to a well liner perforated with an in-hole perforating device, and does not require cementing as with a conventional perforated well liner.
  • the diameter D of the perforated liner 16 can be slightly less than the diameter of the well bore 12, such that an annulus 20 is formed between the perforated liner 16 and the well bore 12.
  • a representative diameter D of the perforated liner 16 can be about 5 inches for a 6.25 to 6.75 inch horizontal well bore, but other diameters for these elements can be used.
  • a diameter Do of the openings 18 can be selected as required with from 1/8 inch to 3/4 inch being representative.
  • the density of the openings 18 can be selected as required with up to 500 openings per linear foot being representative. This density is larger than for openings formed in a conventional well liner by a down-hole perforating device.
  • the larger number of openings 18 provides reduced fracturing flow resistances and increased production flow rates compared to a conventional perforated well liner.
  • the openings 18 can also be formed with chamfered edges to further reduce flow resistances and increase flow rates.
  • the method also includes the step of installing a packer 22 in the perforated liner 16 at a first interval II in the formation 14, which is configured to perform a packer jack frac.
  • packer jack frac refers to a fracturing process that depends on a mechanical jacking force exerted on the formation 14 by the packer 22.
  • the packer 22 inflated to a pressure of from 10,000 psia to 30,000 psia, enough force is produced to fracture the formation 14. Further details of the packer jack frac will become more apparent as the description proceeds.
  • the packer 22 is attached to a high pressure tubular 24 and is controlled by a packer actuation tool 26.
  • the packer 22 can comprise a fixed head inflatable packer or a sliding head inflatable packer.
  • One suitable packer is described in US Patent No. 5,778,982, which is incorporated herein by reference.
  • Other suitable packers are commercially available from Baski Inc. of Denver, CO.
  • the packer 22 includes a tubular packer mandrel 32 and an inflatable element 34 attached to the packer mandrel 32 at both ends connected to an inflation tube 42.
  • the packer 32 is shown in an uninflated condition in Figure 2A.
  • the inflatable element 34 comprises a multi layered structure formed of separate layers or plies of resilient elastomeric materials.
  • the inflatable element 34 includes an inner layer 44, middle layers 46, 48 and outer layer 50.
  • the outer layer 50 of the inflatable element 34 can include a plurality of radially spaced circumferential grooves 62 having a desired depth configured to provide a higher frictional force for anchoring the packer 22 to the well bore 12 (or to a liner 58 as will be hereinafter described). This permits higher forces to be applied to the formation 14 by the packer 22 as anchoring friction is maximized due to a higher pressure being applied to the well bore 12 or the perforated liner 16.
  • a packer having an outer member with a grooved construction is further described in US Patent No. 7,721,799, which is incorporated herein by reference.
  • the middle layers 46, 48 can comprise an elastomeric base material reinforced with reinforcing material 52.
  • the reinforcing material 52 can comprise fibers, cable or cord embedded in the elastomeric base material at a desired spacing "x" and a desired angle "a".
  • the construction of the inflatable element 34 allows high pressures and mechanical jacking forces to be achieved.
  • the inflatable element 34 is designed to return to its uninflated shape for moving the packer 22 to other locations in the well bore 12. Further, the construction of the inflatable element 34 permits the packer 22 to be easily cycled from an inflated to an uninflated condition to cycle the mechanical jacking forces.
  • the high pressure tubular 24 can comprise lengths of steel tubing that are joined together by threaded connections.
  • the high pressure tubular is designed to contain the fracking fluid 30 during a hydraulic fracturing step to be hereinafter described.
  • the packer actuation tool 26 is configured to inflate and deflate the packer 22 upon manipulation of the tubular 24 from the surface. This type of tool is also commercially available from Baski Inc. of Denver, CO.
  • the method also includes the step of packer jack fracking the first interval II using the packer 22 to define a first packer fractured formation 28.
  • This step can be performed by inflating the packer 22 to a desired pressure of from 10,000 psia to 30,000 psia for a desired time period of from minutes to hours.
  • This step can also be performed by cycling the packer 22 from an uninflated to an inflated condition over a selected cycle time period of from seconds to hours.
  • the packer jack fracking step forms primary packer jack fracs 36 and possibly secondary packer jack fracs 38.
  • the primary packer jack fracs 36 are oriented generally perpendicular or orthogonal to the ground surface.
  • the secondary packer jack fracs 38 are oriented generally parallel to the ground surface. As shown in Figure 4, the perforated liner 16 has also been deformed in the first packer fractured formation 28.
  • the method also includes the step of deflating and moving the packer 22 to a second interval 12 in the formation 14.
  • the intervals II and 12 can be adjacent to one another or can be spaced with a desired spacing.
  • the method also includes the step of inflating the packer 22 to seal the first packer fractured formation 28 for the subsequent hydraulic fracturing step.
  • this step is performed such that plastic deformation of the perforated liner 16 occurs as indicated by the deformed outwardly bulging portion of the liner 16 in Figure 5.
  • the packer 22 seals the up hole end of the well bore 12 proximate to the second interval 12.
  • the down hole end of the well bore 12 can be unsealed, or optionally, as shown by the phantom lines in Figure 5 a second packer 22A can be used to seal the down hole end of the well bore 12.
  • the second packer 22A can be spaced from the packer 22 with a required spacing, and can be placed and controlled using a second passageway, which for simplicity is not shown. With this method of control, the second packer 22A can be attached to the same high pressure tubular 24 and packer actuation tool 26 as the packer 22.
  • the method also includes the step of hydraulically fracturing the first packer fractured formation 28 by injecting a fracking fluid 30 through the packer 22 and the openings 18 in the perforated liner 16 to form a first hydraulically fractured formation 40.
  • the packer 22 seals the up hole end of the well bore 12.
  • the fracking fluid 30 can be injected from the surface through the high pressure tubular 24, through the packer 22 and through the openings 18 in the perforated liner 16 into the first packer fractured formation 28.
  • chemicals and proppants can also be injected into the first hydraulically fractured formation 40.
  • the system 54 includes the packer 22 and the perforated liner 16.
  • the method also includes the step of packer jack fracking the second interval 12 using the packer 22 to define a second packer fractured formation 56. This step can be performed as previously described for packer jack fracking of the first interval II .
  • Figures 7 and 7 A illustrate the fracking fluid 30 being injected through the packer and into the primary packer jack fracs 36 and the secondary packer jack fracs 38 ( Figure 7A).
  • Figures 8 and 8A illustrate the formation of the first hydraulically fractured formation 40 by injection of the fracking fluid 30 into the primary packer jack fracs 36 and the secondary packer jack fracs 38 (Figure 7 A) to form a plurality of hydraulic fractures 56 ( Figure 8A).
  • FIG. 5 The hydraulically fracturing step ( Figure 5) can then be repeated as previously described to form a second hydraulically fractured formation in the second interval 12.
  • the deflating and moving step ( Figure 4), the inflating step ( Figure 4), and the packer fracturing step ( Figure 3) of the method can then be repeated through as many intervals as is necessary.
  • Figures 9-15 illustrate steps in an alternate method for fracking and completing a well 10A.
  • the well 10A includes a well liner 58 cemented in a well bore 12A with cement 60.
  • the alternate method also includes the step of installing the packer 22 in the liner 58 at a first interval II in the formation 14. This step can be performed substantially as previously described and shown in Figure 2.
  • the alternate method also includes the step of breaking apart the liner 58 and the cement 60 to form at least one opening 64 through the liner 58 and the cement 60.
  • this step can be performed to form a plurality of openings 64 to provide multiple flow paths through the liner 58 and the cement 60.
  • the packer 22 also performs packer jack fracking of the first interval II to define the first packer fractured formation 28.
  • This step can be performed substantially as previously described and shown in Figure 3.
  • a geophone 66 at the surface can be used to monitor the step.
  • the alternate method also includes the step of deflating and moving the packer 22 to a second interval 12 in the formation 14 and inflating the packer 22 to seal the first packer fractured formation 28 for the subsequent hydraulic fracturing step.
  • the packer 22 seals the up hole end of the well bore 12 proximate to the second interval 12.
  • the down hole end of the well bore 12 can be unsealed, or optionally, as shown in Figure 13, a second packer 22 A can be used to seal the down hole end of the well bore 12.
  • the second packer 22 A can be attached to a tubular 60 having a slot 70 for providing a flow path for the hydraulic fracturing step.
  • the alternate method also includes the step of hydraulically fracturing the first packer fractured formation 28 by injecting the fracking fluid 30 through the packer 22 and the openings 64 in the liner 58 and the cement 60 to form a first hydraulically fractured formation 40.
  • the fracking fluid 30 can be injected from the surface through the high pressure tubular 24, through the packer 22 and through the opening 64 in the liner 58 and the cement 60 into the first packer fractured formation 28.
  • chemicals and proppants can also be injected into the first hydraulically fractured formation 40.
  • the alternate method also includes the step of packer jack fracking the second interval 12 using the packer 22 to define a second packer fractured formation 56. This step can be performed as previously described for packer jack fracking of the first interval II .
  • the alternate method also includes the step of hydraulically fracturing the second packer fractured formation 56 by injecting the fracking fluid 30 through the packer 22 and the openings 64 in the liner 58 and the cement 60 to form a second hydraulically fractured formation 72.

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Abstract

A method for fracking and completing a well (10) having a well bore (12) through a formation (14) includes the steps of: packer jack fracking the fonriation using a packer (22) to form a packer fractured formation (28), moving the packer (22) to seal the packer fractured formation (28), and hydraulically fracturing the packer fractured formation (28) by injecting a fracking fluid (30) through the packer (22). These steps can then be repeated through successive intervals (11, 12) of the formation (14). To complete a new well, a perforated liner (16) can be placed in the well bore (12) to direct the fracking fluid (30) into the packer fractured formation (28).

Description

METHOD AND SYSTEM FOR FRACKING ANC COMPLETING WELLS
Cross Reference To Related Applications
[0001] This application claims priority from provisional application no. 61/484,792 filed on 05/11/2011, which is incorporated herein by reference.
Background
[0002] Oil and gas wells can be treated by fracking (hydraulic fracturing) and chemical injections to increase production. The fracking process occurs after a bore hole has been formed through a formation, and is sometimes referred to as completing the well. Fracking forms fractures in a formation that are typically oriented parallel to the maximum induced stresses in the formation and perpendicular to the minimum induced stresses in the formation. Following (or during) fracking, a granular proppant material can be injected into the fractures to hold them open. The fractures provide low resistance flow paths through the formation into the well liner. Chemical injections can also be used separately, or in combination with fracking, to increase flow capacity by dissolving materials or changing formation properties.
[0003] One fracking method involves drilling a horizontal well bore, and inserting a liner into the well bore. The annulus between the liner and the well bore is then filled with cement. The liner is then perforated in sections of typically from 100 to 1000 feet using a perforating device. In addition, a packer on a coiled tubing string can be placed at the lower end of the segment and actuated to establish a hydraulic seal. Hydraulic fracturing can then be performed in the sealed perforated segment. The packer can then be released and moved to repeat the process.
[0004] This prior art fracking method is expensive as the well bore is relatively large and the liner must be made of high strength steel and cemented in place. In addition, in non-cemented liners, the packers have a limited life expectancy and a low reliability. Also due to the complexity of the method, only a limited number of stages can be performed. For example, a 4000 feet horizontal well bore can typically only be treated in 10 stages of 400 feet with each stage having 3-4 perforated zones. Another problem is that the high pressures needed for hydraulic fracturing can damage cemented liners. [0005] The present disclosure is directed to a method and system for fracking and completing wells that is better, faster and cheaper than prior art methods and systems. In particular, lower cost materials are used, and the downhole perforating operation and external liner pockets are eliminated. Further, more stages can be performed, more fractures can be formed, more proppant can be injected and higher flow rates can be achieved.
[0006] However, the foregoing examples of the related art and limitations related therewith are intended to be illustrative and not exclusive. Other limitations of the related art will become apparent to those of skill in the art upon a reading of the specification and a study of the drawings.
Summary
[0007] A method for fracking and completing a well having a well bore through a formation includes the steps of: packer jack fracking a first interval of the formation using a packer to form a first packer fractured formation, deflating and moving the packer to a second interval in the formation; inflating the packer to seal the first packer fractured formation; hydraulically fracturing the first packer fractured formation by injecting a fracking fluid through the packer, and then repeating the packer jack fracking step, the deflating and moving the packer step, the inflating the packer step and the hydraulically fracturing step through successive intervals of the formation. To complete a new well, a perforated liner can be placed in a well bore to direct the fracking fluid into the packer fractured formation. To complete an existing or new well having a cemented liner, the packer jack fracking step can also be used to break apart the liner to provide flow paths for the fracking fluid through the casing into the packer fractured formation.
[0008] For completing a new well, the method can include the steps of: installing a perforated liner in the well bore having a plurality of pre-formed openings therethrough; installing a packer in the perforated liner at a first interval in the formation; packer jack fracking the first interval using the packer to define a first packer fractured formation; deflating and moving the packer to a second interval in the formation; inflating the packer to seal the first packer fractured formation; hydraulically fracturing the first packer fractured formation by injecting a fracking fluid through the packer and the openings in the perforated liner to form a first hydraulically fractured formation; and packer jack fracking the second interval using the packer to define a second packer fractured formation. The hydraulically fracturing step, the deflating and moving step, the inflating step, and the packer fracturing step of the method can then be repeated through as many intervals as is necessary. Optionally, rather than a single packer, a second packer can be used to seal the intervals. For completing an existing or a new well having a liner cemented in the well bore, the method can include essentially the same steps, but without installing the perforated liner and with the packer jack fracking step performed to break at least one opening through the cemented liner.
[0009] A system for fracking and completing a well having a well bore through a formation comprises: a perforated liner in the well bore having a plurality of pre-formed openings therethrough, a high pressure drill pipe, a packer actuation tool and a packer in the perforated liner configured to fracture and seal successive intervals in the formation.
Brief Description of the Drawings
[0010] Exemplary embodiments are illustrated in the referenced figures of the drawings. It is intended that the embodiments and the figures disclosed herein be considered illustrative rather than limiting.
[0011] Figure 1 is a schematic cross sectional view illustrating the step in the method of installing a perforated liner in the bore hole;
[0012] Figure 2 is a schematic cross sectional view illustrating the step in the method of installing a packer at a first interval of the formation;
[0013] Figure 2A is a schematic perspective view of the packer taken along section line 2A-2A of Figure 2 and partially cut away to illustrate a reinforced inflatable element of the packer;
[0014] Figure 2B is a schematic cross sectional view with parts removed taken along section line 2B-2B of Figure 2A illustrating a grooved outer cover of the packer;
[0015] Figure 3 is a schematic cross sectional view illustrating the step in the method of packer jack fracking using the packer to form a first packer fractured formation; [0016] Figure 3 A is a schematic cross sectional view taken along section line 3A-3A of Figure 3 illustrating primary packer jack fracs in the first packer fractured formation;
[0017] Figure 3B is a schematic cross sectional view taken along section line 3B-3B of Figure 3 illustrating primary and secondary packer jack fracs in the first packer fractured formation;
[0018] Figure 4 is a schematic cross sectional view illustrating the step in the method of deflating and moving the packer to a second interval in the formation;
[0019] Figure 5 is a schematic cross sectional view illustrating the step in the method of hydraulically fracturing the first packer fractured formation by inflating the packer to seal the bore hole and injecting a fracking fluid through the packer and the openings in the perforated liner to form a first hydraulically fractured formation with an optional step in the method of using a second packer to seal the first hydraulically fractured formation shown in phantom lines;
[0020] Figure 6 is a schematic cross sectional view illustrating the step in the method of packer jack fracking the second interval using the packer to define a second packer fractured formation;
[0021] Figure 7 is a schematic cross sectional view taken along section line 7-
7 of Figure 6 illustrating primary packer jack fracs in the second packer fractured formation;
[0022] Figure 7A is a schematic cross sectional view equivalent to Figure 7 illustrating primary and secondary packer jack fracs in the second packer fractured formation;
[0023] Figure 8 is a schematic cross sectional view taken along section line 8-
8 of Figure 6 illustrating primary hydraulic fracs in the first hydraulically fractured formation;
[0024] Figure 8A is a schematic cross sectional view equivalent to Figure 8 illustrating primary and secondary hydraulic fracs in the first hydraulically fractured formation;
[0025] Figure 9 is a schematic cross sectional view equivalent to Figure 1 illustrating a step in an alternate method performed on a well having a liner cemented in the well bore; [0026] Figure 9A is a cross sectional view taken along section line 9A-9A of Figure 9;
[0027] Figure 10 is a schematic cross sectional view equivalent to Figure 2 illustrating the step in the alternate method of installing a packer at a first interval of the formation;
[0028] Figure 11 is a schematic cross sectional view equivalent to Figure 3 illustrating the step in the alternate method of breaking apart the cemented liner and packer jack fracking the formation using the packer to form a first packer fractured formation;
[0029] Figure 11 A is a schematic cross sectional view taken along section line 1 lA-11A of Figure 11 illustrating an opening through the cemented liner and primary packer jack fracs in a first packer fractured formation;
[0030] Figure 12 is a schematic cross sectional view equivalent to Figures 4 and 5 illustrating the steps in the method of deflating and moving the packer to a second interval in the formation, inflating the packer to seal the bore hole, and hydraulically fracturing the first packer fractured formation by injecting a fracking fluid through the packer and the opening in the cemented liner to form a first hydraulically fractured formation;
[0031] Figure 12A is a schematic cross sectional view taken along section line 12A-12A of Figure 12 illustrating formation of the first hydraulically fractured formation;
[0032] Figure 13 is a schematic cross sectional view equivalent to Figure 2 illustrating an optional step in the alternate method of using a second packer to seal the first hydraulically fractured formation;
[0033] Figure 14 is a schematic cross sectional view illustrating the step in the alternate method of packer jack fracking the second interval using the packer to define a second packer fractured formation;
[0034] Figure 14A is a schematic cross sectional view taken along section line 14A-14A of Figure 14 illustrating formation of a second packer fractured formation;
[0035] Figure 15 is a schematic cross sectional view illustrating the step in the alternate method of hydraulically fracturing the second packer fractured formation by injecting a fracking fluid through the packer and the opening in the cemented liner to form a second hydraulically fractured formation; and [0036] Figure 15A is a schematic cross sectional view taken along section line 15A-15A of Figure 15 illustrating formation of the second packer fractured formation.
Detailed Description
[0037] Figures 1-6 illustrate steps in a method for fracking and completing a well 10. The well 10 can comprise an oil and gas well or alternately another type of well, such as another gas or liquid well such as a recharge water well. Referring to Figure 1, the well 10 includes a well bore 12 that extends from a ground surface into a geological formation 14 at a required depth of typically from several hundred to several thousand feet. The well bore 12 extends through the geological formation 14 in a generally horizontal direction. The well bore 12 can also include a vertical segment, which for simplicity is not shown. The well bore 12 can be smaller than in a conventional oil and gas well. For example, a representative diameter of the well bore 12 can be about 6 inches to 8 inches.
[0038] As shown in Figure 1, the method includes the step of installing a perforated liner 16 in the well bore 12 having a plurality of pre-formed openings 18 therethrough. The perforated liner 16 can comprise metal pipe that has been formed or machined with the openings 18 through the sidewalls, and attached in lengths by welding or threaded connections. As the perforated liner 16 has no pressure requirements, it can be made of low strength steel with seams, rather than high pressure seamless steel as with a conventional well liner. Further, the perforated liner 16 can be made relatively cheaply relative to a well liner perforated with an in-hole perforating device, and does not require cementing as with a conventional perforated well liner.
[0039] As shown in Figure 1, the diameter D of the perforated liner 16 can be slightly less than the diameter of the well bore 12, such that an annulus 20 is formed between the perforated liner 16 and the well bore 12. A representative diameter D of the perforated liner 16 can be about 5 inches for a 6.25 to 6.75 inch horizontal well bore, but other diameters for these elements can be used. A diameter Do of the openings 18 can be selected as required with from 1/8 inch to 3/4 inch being representative. Further, the density of the openings 18 can be selected as required with up to 500 openings per linear foot being representative. This density is larger than for openings formed in a conventional well liner by a down-hole perforating device. The larger number of openings 18 provides reduced fracturing flow resistances and increased production flow rates compared to a conventional perforated well liner. The openings 18 can also be formed with chamfered edges to further reduce flow resistances and increase flow rates.
[0040] Referring to Figure 2, the method also includes the step of installing a packer 22 in the perforated liner 16 at a first interval II in the formation 14, which is configured to perform a packer jack frac. As used herein, the term "packer jack frac" refers to a fracturing process that depends on a mechanical jacking force exerted on the formation 14 by the packer 22. By way of example, with the packer 22 inflated to a pressure of from 10,000 psia to 30,000 psia, enough force is produced to fracture the formation 14. Further details of the packer jack frac will become more apparent as the description proceeds.
[0041] The packer 22 is attached to a high pressure tubular 24 and is controlled by a packer actuation tool 26. The packer 22 can comprise a fixed head inflatable packer or a sliding head inflatable packer. One suitable packer is described in US Patent No. 5,778,982, which is incorporated herein by reference. Other suitable packers are commercially available from Baski Inc. of Denver, CO. As shown in Figure 2A, the packer 22 includes a tubular packer mandrel 32 and an inflatable element 34 attached to the packer mandrel 32 at both ends connected to an inflation tube 42. The packer 32 is shown in an uninflated condition in Figure 2A. The inflatable element 34 comprises a multi layered structure formed of separate layers or plies of resilient elastomeric materials. More specifically, the inflatable element 34 includes an inner layer 44, middle layers 46, 48 and outer layer 50. As shown in Figure 2B, the outer layer 50 of the inflatable element 34 can include a plurality of radially spaced circumferential grooves 62 having a desired depth configured to provide a higher frictional force for anchoring the packer 22 to the well bore 12 (or to a liner 58 as will be hereinafter described). This permits higher forces to be applied to the formation 14 by the packer 22 as anchoring friction is maximized due to a higher pressure being applied to the well bore 12 or the perforated liner 16. A packer having an outer member with a grooved construction is further described in US Patent No. 7,721,799, which is incorporated herein by reference.
[0042] As also shown in Figure 2A, the middle layers 46, 48 can comprise an elastomeric base material reinforced with reinforcing material 52. The reinforcing material 52 can comprise fibers, cable or cord embedded in the elastomeric base material at a desired spacing "x" and a desired angle "a". The construction of the inflatable element 34 allows high pressures and mechanical jacking forces to be achieved. In addition, the inflatable element 34 is designed to return to its uninflated shape for moving the packer 22 to other locations in the well bore 12. Further, the construction of the inflatable element 34 permits the packer 22 to be easily cycled from an inflated to an uninflated condition to cycle the mechanical jacking forces.
[0043] The high pressure tubular 24 can comprise lengths of steel tubing that are joined together by threaded connections. In addition, to placing the packer 22 at a desired location, the high pressure tubular is designed to contain the fracking fluid 30 during a hydraulic fracturing step to be hereinafter described. The packer actuation tool 26 is configured to inflate and deflate the packer 22 upon manipulation of the tubular 24 from the surface. This type of tool is also commercially available from Baski Inc. of Denver, CO.
[0044] Referring to Figure 3, the method also includes the step of packer jack fracking the first interval II using the packer 22 to define a first packer fractured formation 28. This step can be performed by inflating the packer 22 to a desired pressure of from 10,000 psia to 30,000 psia for a desired time period of from minutes to hours. This step can also be performed by cycling the packer 22 from an uninflated to an inflated condition over a selected cycle time period of from seconds to hours. As shown in Figures 3A and 3B, the packer jack fracking step forms primary packer jack fracs 36 and possibly secondary packer jack fracs 38. The primary packer jack fracs 36 are oriented generally perpendicular or orthogonal to the ground surface. The secondary packer jack fracs 38 are oriented generally parallel to the ground surface. As shown in Figure 4, the perforated liner 16 has also been deformed in the first packer fractured formation 28.
[0045] Referring to Figure 4, the method also includes the step of deflating and moving the packer 22 to a second interval 12 in the formation 14. The intervals II and 12 can be adjacent to one another or can be spaced with a desired spacing.
[0046] Referring to Figure 5, the method also includes the step of inflating the packer 22 to seal the first packer fractured formation 28 for the subsequent hydraulic fracturing step. Preferably this step is performed such that plastic deformation of the perforated liner 16 occurs as indicated by the deformed outwardly bulging portion of the liner 16 in Figure 5. The packer 22 seals the up hole end of the well bore 12 proximate to the second interval 12. The down hole end of the well bore 12 can be unsealed, or optionally, as shown by the phantom lines in Figure 5 a second packer 22A can be used to seal the down hole end of the well bore 12. The second packer 22A can be spaced from the packer 22 with a required spacing, and can be placed and controlled using a second passageway, which for simplicity is not shown. With this method of control, the second packer 22A can be attached to the same high pressure tubular 24 and packer actuation tool 26 as the packer 22.
[0047] As also shown in Figure 5, the method also includes the step of hydraulically fracturing the first packer fractured formation 28 by injecting a fracking fluid 30 through the packer 22 and the openings 18 in the perforated liner 16 to form a first hydraulically fractured formation 40. During this step, the packer 22 seals the up hole end of the well bore 12. In addition, the fracking fluid 30 can be injected from the surface through the high pressure tubular 24, through the packer 22 and through the openings 18 in the perforated liner 16 into the first packer fractured formation 28. In addition to the fracking fluid 30, chemicals and proppants can also be injected into the first hydraulically fractured formation 40.
[0048] Referring to Figure 6, the system 54 includes the packer 22 and the perforated liner 16. As shown in Figure 6, the method also includes the step of packer jack fracking the second interval 12 using the packer 22 to define a second packer fractured formation 56. This step can be performed as previously described for packer jack fracking of the first interval II . Figures 7 and 7 A illustrate the fracking fluid 30 being injected through the packer and into the primary packer jack fracs 36 and the secondary packer jack fracs 38 (Figure 7A). Figures 8 and 8A illustrate the formation of the first hydraulically fractured formation 40 by injection of the fracking fluid 30 into the primary packer jack fracs 36 and the secondary packer jack fracs 38 (Figure 7 A) to form a plurality of hydraulic fractures 56 (Figure 8A).
[0049] The hydraulically fracturing step (Figure 5) can then be repeated as previously described to form a second hydraulically fractured formation in the second interval 12. In addition, the deflating and moving step (Figure 4), the inflating step (Figure 4), and the packer fracturing step (Figure 3) of the method can then be repeated through as many intervals as is necessary. [0050] Figures 9-15 illustrate steps in an alternate method for fracking and completing a well 10A. As shown in Figures 9 and 9A, the well 10A includes a well liner 58 cemented in a well bore 12A with cement 60.
[0051] Referring to Figure 10, the alternate method also includes the step of installing the packer 22 in the liner 58 at a first interval II in the formation 14. This step can be performed substantially as previously described and shown in Figure 2.
[0052] Referring to Figure 11 and 11 A, the alternate method also includes the step of breaking apart the liner 58 and the cement 60 to form at least one opening 64 through the liner 58 and the cement 60. Although for illustrative purposes only one opening 64 is shown, this step can be performed to form a plurality of openings 64 to provide multiple flow paths through the liner 58 and the cement 60. During this step the packer 22 also performs packer jack fracking of the first interval II to define the first packer fractured formation 28. This step can be performed substantially as previously described and shown in Figure 3. As also shown in Figure 11, a geophone 66 at the surface can be used to monitor the step.
[0053] Referring to Figures 12 and 12A, the alternate method also includes the step of deflating and moving the packer 22 to a second interval 12 in the formation 14 and inflating the packer 22 to seal the first packer fractured formation 28 for the subsequent hydraulic fracturing step. The packer 22 seals the up hole end of the well bore 12 proximate to the second interval 12. The down hole end of the well bore 12 can be unsealed, or optionally, as shown in Figure 13, a second packer 22 A can be used to seal the down hole end of the well bore 12. The second packer 22 A can be attached to a tubular 60 having a slot 70 for providing a flow path for the hydraulic fracturing step.
[0054] As also shown in Figure 12, the alternate method also includes the step of hydraulically fracturing the first packer fractured formation 28 by injecting the fracking fluid 30 through the packer 22 and the openings 64 in the liner 58 and the cement 60 to form a first hydraulically fractured formation 40. During this step, the fracking fluid 30 can be injected from the surface through the high pressure tubular 24, through the packer 22 and through the opening 64 in the liner 58 and the cement 60 into the first packer fractured formation 28. In addition to the fracking fluid 30, chemicals and proppants can also be injected into the first hydraulically fractured formation 40. [0055] Referring to Figures 14 and 14 A, the alternate method also includes the step of packer jack fracking the second interval 12 using the packer 22 to define a second packer fractured formation 56. This step can be performed as previously described for packer jack fracking of the first interval II .
[0056] Referring to Figures 15 and 15 A, the alternate method also includes the step of hydraulically fracturing the second packer fractured formation 56 by injecting the fracking fluid 30 through the packer 22 and the openings 64 in the liner 58 and the cement 60 to form a second hydraulically fractured formation 72.
[0057] While a number of exemplary aspects and embodiments have been discussed above, those of skill in the art will recognize certain modifications, permutations, additions and subcombinations thereof. It is therefore intended that the following appended claims and claims hereafter introduced are interpreted to include all such modifications, permutations, additions and sub-combinations as are within their true spirit and scope.

Claims

WHAT IS CLAIMED IS:
1. A method for fracking and completing a well having a well bore through a formation comprising:
packer jack fracking a first interval in the formation using a packer to form a first packer fractured formation;
deflating and moving the packer to a second interval in the formation;
inflating the packer to seal the first packer fractured formation;
hydraulically fracturing the first packer fractured formation by injecting a fracking fluid through the packer; and
repeating the packer jack fracking step, the deflating and moving the packer step, the inflating the packer step and the hydraulically fracturing step through successive intervals of the formation.
2. The method of claim 1 further comprising placing a perforated liner in the well bore to direct the fracking fluid into the packer fractured formation.
3. The method of claim 1 wherein the well includes a liner cemented to the well bore and further comprising breaking an opening in the liner during the packer jack fracking step to provide a flow path through the liner into the packer fractured formation for the fracking fluid.
4. The method of claim 1 wherein the packer includes multi plied reinforcing material.
5. The method of claim 1 wherein the packer includes a plurality of grooves configured to provide a higher frictional force for anchoring the packer.
6. The method of claim 1 wherein the inflating the packer to seal the first packer formation seals an up hole end of the packer fractured formation and further comprising sealing a downhole end of the packer fractured formation using a second packer.
7. A method for fracking and completing a well having a well bore through a formation comprising:
installing a perforated liner in the well bore having a plurality of pre-formed openings therethrough;
installing a packer in the perforated liner at a first interval in the formation; packer jack fracking the first interval using the packer to define a first packer fractured formation;
deflating and moving the packer to a second interval in the formation;
inflating the packer to seal the first packer fractured formation;
hydraulically fracturing the first packer fractured formation by injecting a fracking fluid through the packer and the openings in the perforated liner to form a first hydraulically fractured formation; and
packer jack fracking the second interval using the packer to define a second packer fractured formation.
8. The method of claim 7 further comprising deflating and moving the packer to a third interval in the formation; inflating the packer to seal the second packer fractured formation; and hydraulically fracturing the second packer fractured formation by injecting the fracking fluid through the packer and the openings in the perforated liner to form a second hydraulically fractured formation.
9. The method of claim 7 further comprising repeating the deflating step, the inflating step, the hydraulically fracturing step and the packer jack fracturing step through a plurality of intervals.
10. The method of claim 7 further comprising sealing the first packer fractured formation using a second packer.
11. The method of claim 7 further comprising providing the packer with a plurality of grooves configured to increase a frictional force for anchoring the packer.
12. A method for fracking and completing a well having a well bore through a formation and a liner in cement in a well bore comprising: installing a packer in the liner at a first interval in the formation;
breaking the liner proximate to the first interval using the packer to form at least one first opening through the liner and the cement to provide a first flow path into the first interval;
packer jack fracking the first interval using the packer to define a first packer fractured formation;
deflating and moving the packer to a second interval in the formation;
inflating the packer to seal the first packer fractured formation;
hydraulically fracturing the first packer fractured formation by injecting a fracking fluid through the packer to form a first hydraulically fractured formation; breaking the liner proximate to the second interval using the packer to form at least one second opening through the liner and the cement to provide a second flow path through the liner into the second interval; and
packer jack fracking the second interval using the packer to define a second packer fractured formation.
13. The method of claim 12 further comprising deflating and moving the packer to a third interval in the formation; inflating the packer to seal the second packer fractured formation; and hydraulically fracturing the second packer fractured formation by injecting the fracking fluid through the packer to form a second hydraulically fractured formation.
14. The method of claim 12 further comprising repeating the deflating step, the inflating step, the hydraulically fracturing step and the packer jack fracturing step through a plurality of intervals.
15. The method of claim 12 further comprising sealing the first packer fractured formation using a second packer.
16. The method of claim 12 further comprising providing the packer with a plurality of grooves configured to increase a frictional force for anchoring the packer.
17. A system for fracking and completing a well having a well bore through a formation comprising:
a perforated liner configured for placement in the well bore having a plurality of pre-formed openings therethrough; and
a packer in the perforated liner configured to deform the perforated liner and exert a mechanical jacking force on the formation and to packer jack frac and seal successive intervals in the formation, the packer comprising an inflatable element having a plurality of plies of reinforcing and an outer member having a plurality of grooves configured to increase a frictional force for anchoring the packer.
18. The system of claim 17 further comprising a second packer spaced from the packer and configured to seal the perforated liner during the packer jack frac.
19. The system of claim 18 further comprising a tubular having at least one slot attaching the second packer to the first packer.
20. The system of claim 19 wherein a diameter of the openings is 1/8 inch to 3/4 inches and a density of the openings is less than 500 openings per linear foot.
PCT/US2012/037273 2011-05-11 2012-05-10 Method and system for fracking and completing wells WO2012154932A1 (en)

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