EP2957715B1 - Ensemble pour le compactage de gravier «toe-to-heel» et circulation en sens inverse de la boue en excès - Google Patents

Ensemble pour le compactage de gravier «toe-to-heel» et circulation en sens inverse de la boue en excès Download PDF

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Publication number
EP2957715B1
EP2957715B1 EP15168402.4A EP15168402A EP2957715B1 EP 2957715 B1 EP2957715 B1 EP 2957715B1 EP 15168402 A EP15168402 A EP 15168402A EP 2957715 B1 EP2957715 B1 EP 2957715B1
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EP
European Patent Office
Prior art keywords
workstring
assembly
screen
bore
port
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Legal status (The legal status 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 status listed.)
Not-in-force
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EP15168402.4A
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German (de)
English (en)
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EP2957715A2 (fr
EP2957715A3 (fr
Inventor
John Broussard
Christopher A. HALL
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Weatherford Technology Holdings LLC
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Weatherford Technology Holdings LLC
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Filing date
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Priority claimed from US14/282,692 external-priority patent/US10082007B2/en
Application filed by Weatherford Technology Holdings LLC filed Critical Weatherford Technology Holdings LLC
Publication of EP2957715A2 publication Critical patent/EP2957715A2/fr
Publication of EP2957715A3 publication Critical patent/EP2957715A3/fr
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Publication of EP2957715B1 publication Critical patent/EP2957715B1/fr
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/04—Gravelling of wells
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/124—Units with longitudinally-spaced plugs for isolating the intermediate space
    • 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
    • E21B43/02—Subsoil filtering
    • E21B43/08—Screens or liners

Definitions

  • Horizontal wells that require sand control are typically open hole completions.
  • stand-alone sand screens have been used predominately in these horizontal open holes.
  • operators have also been using gravel packing in these horizontal open holes to deal with sand control issues.
  • the gravel is a specially sized particulate material, such as graded sand or proppant, which is packed around the sand screen in the annulus of the borehole.
  • the gravel acts as a filter to keep any fines and sand of the formation from migrating with produced fluids.
  • a prior art gravel pack system 20 illustrated in Fig. 1A extends from a packer 14 downhole from casing 12 in a borehole 10, which is a horizontal open hole.
  • a packer 14 downhole from casing 12 in a borehole 10, which is a horizontal open hole.
  • operators attempt to fill the annulus between the assembly 20 and the borehole 10 with gravel (particulate material) by pumping slurry of fluid and gravel into the borehole 10 to pack the annulus.
  • For the horizontal open borehole 10 operators can use an alpha-beta wave (or water packing) technique to pack the annulus.
  • This technique uses a low-viscosity fluid, such as completion brine, to carry the gravel.
  • the system 20 in Fig. 1A represents such an alpha-beta type.
  • a wash pipe 40 into a screen 25 and pump the slurry of fluid and gravel down an inner workstring 45.
  • the slurry passes through a port 32 in a crossover tool 30 and into the annulus between the screen 25 and the borehole 10.
  • the crossover tool 30 positions immediately downhole from the gravel pack packer 14 and uphole from the screen 25.
  • the crossover port 32 diverts the flow of the slurry from the inner workstring 45 to the annulus downhole from the packer 14.
  • another crossover port 34 diverts the flow of returns from the wash pipe 40 to the casing's annulus uphole from the packer 14.
  • the slurry moves out the crossover port 32 and into the annulus.
  • the carrying fluid in the slurry then leaks off through the formation and/or through the screen 25.
  • the screen 25 prevents the gravel in the slurry from flowing into the screen 25.
  • the fluids passing alone through the screen 25 can then return through the crossover port 34 and into the annulus above the packer 14.
  • the gravel drops out of the slurry and first packs along the low side of the borehole's annulus.
  • the gravel collects in stages 16a, 16b, etc., which progress from the heel to the toe in what is termed an alpha wave. Because the borehole 10 is horizontal, gravitational forces dominate the formation of the alpha wave, and the gravel settles along the low side at an equilibrium height along the screen 25.
  • the gravel pack operation When the alpha wave of the gravel pack operation is done, the gravel then begins to collect in stages (not shown) of a beta wave. This forms along the upper side of the screen 25 starting from the toe and progressing to the heel of the screen 25. Again, the fluid carrying the gravel can pass through the screen 25 and up the wash pipe 40. To complete the beta wave, the gravel pack operation must have enough fluid velocity to maintain turbulent flow and move the gravel along the topside of the annulus. To recirculate after this point, operators have to mechanically reconfigure the crossover tool 30 to be able to washdown the pipe 40.
  • shunts disposed on the screen divert pumped packing slurry along the outside of the screen.
  • Fig. 1B shows an example system 20 having shunts 50 and 52 (only two of which are shown).
  • the shunts 50/52 for transport and packing are attached eccentrically to the screen 25.
  • the transport shunts 50 feed the packing shunts 52 with slurry, and the slurry exits from nozzles 54 on the packing shunts 52.
  • the gravel packing operation can avoid areas of high leak off in the borehole 10 that would tend to cause bridges to form and impair the gravel packing.
  • Prior art gravel pack assemblies 20 for both techniques of Figs. 1A-1B have a number of challenges and difficulties.
  • the crossover ports 32/34 may have to be re-configured several times.
  • the slurry pumped at high pressure and flow rate can sometimes dehydrate within the system's crossover tool 30 and associated sliding sleeve (not shown). If severe, settled sand or dehydrated slurry can stick to service tools and can even junk the well.
  • the crossover tool 30 is subject to erosion during frac and gravel pack operations, and the crossover tool 30 can stick in the packer 14, which can create extremely difficult fishing jobs.
  • US 2013/000899 A1 (Broussard ) describes a gravel packing assembly gravel for packing a horizontal borehole. Operators wash down the borehole using an inner string in a first position by flowing fluid from the inner string through the apparatus toe. Operators then gravel pack by moving the inner string to one or more flow ports between a screen and the toe. Slurry flows into the borehole from the flow ports, and returns from the borehole flow through the screen. The gravel in the slurry can pack the borehole in an alpha-beta wave from toe to heel. In another condition, operators can move the inner string to a second flow port so slurry can flow into the borehole through a shunt extending from the second flow port. When gravel packing is done, operators move the inner string to a port collar in a liner of the assembly to cement the liner in the borehole.
  • US 2013/062066 A1 (Broussard ) describes a multi-zone formation treatment assembly having sections disposed on a tubular structure in a borehole.
  • An isolation element disposed on the tubular structure that isolates a borehole annulus around the section from the other sections, and a flow valve disposed on the tubular structure is selectively operable between opened and closed conditions permitting and preventing fluid communication between the through-bore and the borehole annulus.
  • a screen disposed on the tubular structure communicates with the borehole annulus, and a closure disposed on the tubular structure at least prevents fluid communication from the through-bore to the screen.
  • a workstring of the assembly can be manipulated in the tubular structure relative to each section in the same trip to: open the flow valve, position in the through-bore relative to the open flow valve, deliver the treatment from an outlet to the section through the open flow valve, and close the flow valve.
  • the subject matter of the present disclosure is directed to overcoming, or at least reducing the effects of, one or more of the problems set forth above.
  • a multi-zone apparatus and method are used for treating a formation.
  • the apparatus can be used for formation treatments, such as frac operations, frac pack operation, gravel pack operations, or other operations.
  • the apparatus includes a body (e.g., tubular structure, liner, production string, etc.) and a workstring.
  • the body of the assembly is disposed in the borehole and defines a through-bore.
  • One or more sections are disposed on the body, and each of the one or more sections comprises isolation element, a port, a screen, and a closure.
  • the isolation element disposed on the body isolates a borehole annulus around the section from the other sections.
  • the port disposed on the body permits fluid communication between the through-bore and the borehole annulus, and the screen disposed on the body communicates with the borehole annulus.
  • the closure disposed on the body at least preventing fluid communication from the through-bore to the screen.
  • the workstring defines an outlet and is manipulated in the body relative to each section.
  • the workstring in a first mode of operation delivers the treatment from the outlet to the borehole annulus of section through the port.
  • the workstring in a second mode of operation receives reverse circulation from the through-bore into the outlet.
  • the port for a given one of the one or more sections is disposed toward the toe, and the screen for the given section is disposed toward the heel.
  • the port delivers slurry as the treatment and gravel packs the annulus of the given section from toe to heel.
  • the screen filters the fluid returns from the slurry into the through-bore of the body.
  • the port for a given one of the one or more sections is disposed toward the heel, and the screen for the given section is disposed toward the toe.
  • the port delivers slurry as the treatment and gravel packs the annulus of the given section from heel to toe.
  • the screen filters the fluid returns from the slurry, and the section has a bypass delivering the fluid returns to the through-bore of the body uphole of the port.
  • the port comprises a flow valve selectively operable between opened and closed conditions permitting and preventing fluid communication between the through-bore and the borehole annulus.
  • the flow valve can include a sleeve movable in the through-bore between (a) the closed condition preventing fluid communication through the port and (b) the opened condition permitting fluid communication through the port.
  • the workstring can be configured to at least open the flow valves of the one or more sections.
  • the workstring can have an actuating tool operable to open and close the flow valves of the one or more sections in the same trip in the through-bore.
  • the closure is selectively operable between (a) a closed condition preventing fluid communication between the through-bore and the screen and (b) an opened condition permitting fluid communication between the through-bore and the screen.
  • the closure can include a sleeve movable in the through-bore between (a) the closed condition preventing fluid communication through at least one flow port in the body, the at least one flow port in communication with the screen, and (b) the open condition permitting fluid communication through the at least one flow port.
  • the closure can include a one-way valve disposed in fluid communication between the screen and the through-bore, the one-way valve in the open condition permitting fluid communication from the screen into the through-bore and in the closed condition preventing fluid communication from the through-bore to the screen.
  • Figs. 2A-2B show a multi-zone screened system 200 according to the present disclosure being run-in hole.
  • the system 200 can be used for formation treatments, such as frac operations, frac pack operation, gravel pack operations, or other operations.
  • the system 200 includes a production string or liner 225 (e.g., tubular structure or body) that extends into a borehole 10 from a liner packer 14 supported in casing 12. This borehole 10 can be a horizontal or deviated open hole.
  • the system 200 also has a hydraulic service tool 202 made up to the packer 14 and has an inner workstring 210 made up to the service tool 202.
  • the liner 225 can have a float shoe 220 at its end. Meanwhile, along its length, the liner 225 can have one or more screen sections 240A-B ( Fig. 2B ) and one or more ported housings 230A-B. In general, the ported housings 230A-B may be disposed next to or integrated into one or more of the screen sections 240A-B. As discussed below, use of the one or more screen sections 240A-B and ported housings 230A-B provide one or more slurry packing points for a gravel packing operation.
  • Each of the ported housings 230A-B has body or flow ports 232A-B for diverting flow. Internally, each of the ported housings 230A-B has seats 234 defined above and below the outlet ports 232A-B for sealing with the distal end of the inner workstring 210 as discussed below. To prevent erosion, the flow ports 232A-B on the ported housings 230A-B can have a skirt, such as the skirt 236 for the flow ports 232A on the ported housings 230A.
  • These alternate path devices 250 can be shunts, tubes, concentrically mounted tubing, or other devices known in the art for providing an alternate path for slurry.
  • the alternate path devices 250 are referred to as shunts herein for simplicity.
  • the shunts 250 communicate from the flow ports 232B to side ports 222 toward the distal end of the system 200 or other directions for use during steps of the operation.
  • the inner workstring 210 extending from the service tool 202 disposes through the screen sections 240A-B of the system 200.
  • the inner workstring 210 can have a reverse taper to reduce circulating pressures if desired.
  • the system 200 On the end of the screen sections 240A-B, the system 200 has a shoe track 220 with a float shoe 226 and seat 224.
  • the float shoe 226 has a check valve, sleeve, or the like (not shown) that allows for washing down or circulating fluid around the outside the screen sections 240A-B when running in the well and before the packer 14 is set.
  • the inner workstring 210 On its distal end, the inner workstring 210 has outlet ports 212 isolated by seals 214. When running in, one of the seals 214 can seal the end of the inner workstring 210 inside the shoe track 220, as shown in Fig. 2B . In this way, fluid pumped downhole the inner workstring 210 can exit the check valve (not shown) in the float shoe 226 at the end of the shoe track 220 to washout the borehole 10.
  • the outlet ports 212 can locate and seal by the seals 214 in the ported housings 230A-B disposed between each of the screen sections 240A-B.
  • seals 214 located on either side of the string's outlet ports 212 seal inside seats 234 on the ported housings 230A-B.
  • the seals 214 can use elastomeric or other types of seals disposed on the inner workstring 210, and the seats 234 can be polished seats or surfaces inside the housings 230A-B to engage the seals 214.
  • the reverse arrangement can be used with seals on the inside of the housings 230A-B and with seats on the inner workstring 210.
  • the system 200 is run-in hole for wash down.
  • the service tool 202 sits on the unset packer 14 in the casing 12, and seals 204 on the service tool 202 do not seal in the packer 14 to allow for transmission of hydrostatic pressure.
  • the distal end of the inner workstring 210 fits through the screen sections 240A-B, and one of the string's seals 214 seals against the seat 224 near the float shoe 226. Operators circulate fluid down the inner workstring 210, and the circulated fluid flows out the check valve in the float shoe 226, up the annulus, and around the unset packer 14.
  • the gravel can pack the annulus in an alpha-beta wave, although other variations can be used.
  • the gravel drops out of the slurry and first packs along the low side of the annulus in the borehole 10.
  • the gravel collects in stages that progress from the toe (near housing 230A) to the heel in an alpha wave. Gravitational forces dominate the formation of the alpha wave, and the gravel settles along the low side at an equilibrium height along the screen sections 240A-B.
  • the borehole 10 fills in a beta wave along the system 200.
  • the gravel begins to collect in the beta wave along the upper side of the screen sections 240A-B starting from the heel (near the packer 14) and progressing to the toe of the assembly 200. Again, the fluid carrying the gravel can leak through the screen sections 240A-B and up the annulus between the inner workstring 210 and the liner 225.
  • the slurry can flow out of the ports 232B and into the surrounding annulus if desired. This is possible if one or more of the ports 232B communicate directly with the annulus and do not communicate with one of the alternate path devices or shunt 250. All the same, the slurry can flow out of the ports 232B and into the alternate path devices or shunts 250 for placement elsewhere in the surrounding annulus. Although shunts 250 are depicted in a certain way, any desirable arrangement and number of transport and packing devices for an alternate path can be used to feed and deliver the slurry.
  • this second stage of pumping slurry may be used to further gravel pack the borehole.
  • pumping the slurry through the shunts 250 enables operators to evacuate excess slurry from the inner workstring 210 to the borehole without reversing flow in the string 210 from the first flow direction (i.e ., toward the string's port 212). This is in contrast to a reverse direction of flowing fluid down the annulus between the string 210 and the housings 230A-B/screens 240A-B to evacuate excess slurry from the string 210.
  • the slurry travels from the port 212, through flow ports 232B, and through the shunts 250. From the shunts 250, the slurry then passes out the side ports or nozzles 254 in the shunts 250 and fills the annulus around shoe track 220. This provides the gravel packing operation with an alternate path different from the system's primary path of toe-to-heel. In this way, the shunts 250 attached to the ported housing 230B above the lower screen section 240A can be used to dispose of excess gravel from the workstring 210 around the shoe track 220. The shunts 250 carry the slurry down the lower screen section 240A so a wash pipe is not needed at the end of the section 240A.
  • a bypass 258 defined in a downhole location of the system 200 allows for returns of fluid during this process.
  • This bypass 258 can be a check valve, a screen portion, sleeve, or other suitable device that allows flow of returns and not gravel from the borehole to enter the system 200.
  • the bypass 258 as a screen portion can have any desirable length along the shoe track 220 depending on the implementation.
  • operation may reach a "sand out" condition or a pressure increase while pumping slurry at ports 232B.
  • a valve, rupture disc, or other closure device 256 in the shunts 250 can open so the gravel in the slurry can then fill inside the shoe track 220 after evacuating the excess around the shoe track 220. In this way, operators can evacuate excess gravel inside the shoe track 220. As this occurs, fluid returns can pass out the lower screen section 240A, through the packed gravel in the annulus, and back through upper screen section 240B to travel uphole.
  • the lower ported housing 230A can have a bypass, another shunt, or the like (not shown), which can be used to deliver fluid returns past the seals 214 and seats 234 and uphole.
  • the previous system 200 filled the open hole annulus with an alpha-beta type wave and then filled the annulus around the toe with an alternate path.
  • the system 200 can use an additional alternative path device or shunt 260 to fill the open hole annulus while circulating in the gravel pack operation.
  • the operation of the system 200 is similar to that discussed previously.
  • the system 200 has one or more ported housings 230A-B for the slurry to exit and has one or more screen sections 240A-B.
  • shunts 260 may be used exclusively.
  • the slurry can be pumped out through one or more of the housing's ports 232A at the same time.
  • the system 200 can gravel pack zones from toe-to-heel, from heel-to-toe, and combinations thereof.
  • the disclosed system 200 can be used in a number of versatile ways to gravel pack the annulus of a borehole.
  • the string's outlet ports 212 can locate in one or more different ported housings 230A-B to gravel pack around the screen sections 240A-B in an alpha-beta wave or alternative path.
  • the inner workstring 210 can be moved to multiple housings 230A-B to pack a single zone from multiple points or to gravel pack the same zone from a first direction and then from a different direction (e.g., first from bottom to top and then from top to bottom using shunts 250/260).
  • the inner workstring 210 can be used to pump treatments of different types into a surrounding zone.
  • the system 200 of Figs. 2A through 6B can be used to perform frac packing from one point and then gravel packing (via shunts 250 and/or 260) from another point along the screen sections 240A-B.
  • frac packing operators perform a frac treatment by delivering large volumes of graded sand, proppant, or the like into the annulus and into the formation at pressures exceeding the frac gradient of the formation. The graded sand or proppant enters fractures in the borehole 10 to keep the fractures open.
  • operators can then perform a gravel pack operation to fill the annulus with gravel.
  • the gravel pack and frac treatment can be performed at the same time.
  • the disclosed system 200 can deliver the frac treatment and gravel slurry through the multiple ported housing 230A-B into the annulus around the screen sections 240A-B. Dispersing the frac treatment and slurry through the multiple ports 232A-B can provide more even distribution across a greater area.
  • the frac treatment can exit from the lower ported housing 230A, and fluid returns can pass through the screen section 240B adjacent to the casing annulus until the fracture is complete.
  • the inner workstring 210 can be moved to the upper ported housing 230B so that gravel slurry can flow through shunts 250 and/or 260 to gravel pack the annulus.
  • a reverse operation could be done in which frac treatment can exit upper housing 230B so that gravel packing can be done primarily at the lower housing 230A using toe-to-heel gravel packing.
  • the system 200 may reduce the chances of sticking. Because the system 200 can have a smaller volumetric area around the exit points, there may be less of a chance for proppant sticking around the gravel pack ports 212. As slurry exits near the end of the inner workstring 210, only a short length of pipe has to travel upward through remaining slurry or dehydrated sand that may be left. If sticking does occur around the gravel pack ports 212, a shear type disconnect (not shown) can be incorporated into the inner workstring 210 so that the lower part of the inner workstring 210 can disconnect from an upper part of the inner workstring 210. This allows for the eventual removal of the inner workstring 210.
  • Figure 7 shows a system 300 segmenting several compartmentalized reservoir zones.
  • the system 300 can be used for formation treatments, such as frac operations, frac pack operation, gravel pack operations, or other operations.
  • the system 300 includes a production string or liner 325 (e.g., tubular structure or body) and includes an inner workstring 310.
  • the liner 325 extends into a borehole 10 from a liner packer 14 supported in casing 12. Again, this borehole 10 can be a horizontal or deviated open hole.
  • the liner 325 has multiple gravel pack sections 302A-C separated by packers 360/370.
  • the packers 360/370 and gravel pack sections 302A-C are deployed into the well in a single trip.
  • One packer 360/370 or a combination of packers 360/370 can be used to isolate the gravel pack sections 302A-C from one another.
  • Any suitable packers can be used and can include hydraulic or hydrostatic packers 360 and swellable packers 370, for example. Each of these packers 360/370 can be used in combination with one another as shown, or the packers 360 or 370 can be used alone.
  • the hydraulic packers 360 provide more immediate zone isolation when set in the borehole 10 to stop the progression of the gravel pack operations in the isolated zones.
  • the swellable packers 370 can be used for long-term zone isolation.
  • the hydraulic packers 360 can be set hydraulically with the inner workstring 310 and its packoff arrangement 314, or the packers 360 can be set by shifting sleeves (not shown) in the packers 360 with a shifting tool (not shown) on the inner workstring 310.
  • Each gravel pack section 302A-C can be similar to the assemblies 200 as discussed above in Figures 2A through 6B .
  • each gravel pack section 302A-C has two screens 340A-B, alternate path devices or shunts 350, and ports 332A-B and can have the ported housings and other components discussed previously.
  • the string's outlet ports 312 with its seals 314 isolates to the lower flow ports 332A to gravel pack and/or frac the first gravel pack section 302A.
  • the inner workstring 310 can be moved so that the outlet ports 312 isolates to upper flow ports 332B connected to the shunts 350 to fill the annulus around the lower end of the first gravel pack section 302A.
  • a similar process can then be repeated up the hole for each gravel pack section 302A-C separated by the packers 360/370.
  • excess slurry can be evacuated from the inner workstring 310 to the annulus before the workstring 310 is moved between sections 302A-C.
  • FIG. 8-9 another multi-zone screened system 400 includes an inner workstring 410 and a screened assembly 420.
  • the system 400 can be used for formation treatments, such as frac operations, frac pack operation, gravel pack operations, or other operations.
  • the screened assembly 420 has a production string or liner 425 (e.g., tubular structure or body) that extends into a borehole 10 from a liner packer 14 supported in casing 12.
  • the liner 425 can have a float shoe 422 or the like, and sections 428A-C disposed on the liner 425 can each have an isolation element 429, a flow valve 430, a screen 440, and a closure 450.
  • the workstring 410 positions in the assembly 420 to open the various valves 430 and treat portions of the formation.
  • the workstring 410 has external seals 416 disposed near outlet ports 412.
  • a dropped ball 414 can seat in a distal seat of the workstring 410 to divert fluid flow down the workstring 410, out the outlet ports 412, and to the open ports 432 in the valve 430 to treat the surrounding formation.
  • the flow devices 440 disposed on the assembly 420 include wellscreens 446 and the closures 450 (i.e., one-way or check valves, sliding sleeves, etc.).
  • the closures 450 can be configured in different ways and can include ball, poppet, or disk type check valves that are concentrically or eccentrically mounted on the outer radius of the screen's basepipe.
  • the closures 450 can be part of a housing that directs flow into a basepipe and can attach to the wellscreens to ensure fluid flow is filtered of solids.
  • multiple closures 450 can be installed on each joint to reduce and even out pressure drops across the screen joints to promote complete development of the beta wave during gravel packing.
  • the closures 450 can be mounted into the basepipe and can allow flow into a housing mounted on the radial exterior of the basepipe and attached to the wellscreen 446.
  • the operation for the system 400 of Figure 8 involves running the screened assembly 420 downhole and setting the packers 429 to create the multiple isolated sections 428A-C down the borehole annulus 15. Once the packers 429 are set, operators apply a frac treatment successively to each of the isolated sections 428A-C by selectively opening the selective valves 430 with a shifting tool 418 on the workstring 410.
  • the shifting tool 418 can be a "B" shifting tool for shifting the inner sleeve 434 in the valve 430 relative to the valve's ports 432.
  • opening a given valve 430 involves engaging the shifting tool 418 in an appropriate profile of the valve's inner sleeve 434 and moving the inner sleeve 434 with the workstring 410 to an opened condition so that the assembly's through-bore 425 communicates with the borehole annulus 15 via the now opened ports 432.
  • the seals 416 on the workstring 410 can engage and seal against inner seats 438, surfaces, seals, or the like in the valve 430 or elsewhere in the assembly 420 on both the uphole and downhole sides of the opened ports 432.
  • the seals 416 can use elastomeric or other types of seals disposed on the inner workstring 410, and the seats 438 can be polished seats or surfaces inside the valve 30 or other parts of the screened assembly 420 to engage the seals 416.
  • the reverse arrangement can be used with seals on the inside of the valve 430 or the screened assembly 420 and with seats on the workstring 410.
  • treatment fluid is flowed down the through-bore 415 of the workstring 410 to the sealed and opened ports 432 in the valve 430.
  • the treatment fluid flows through the outlet ports 412 in the workstring 410 and through the opened ports 432 to the surrounding borehole annulus 15, which allows the treatment fluid to interact with the adjacent zone of the formation.
  • the multi-zone system 400 of Figure 8 can have higher rates compared to a conventional single trip multi-zone system and can improve reservoir performance.
  • the system 400 can have any suitable length and spacing, offers the option to step down one casing size, does not require perforating, and does not require a clean-out trip. Consideration should be given to potential sticking the workstring 410 during operation and to annulus packing that can occur for a particular implementation.
  • the multi-zone screened system 400 of Figure 9 also has a workstring 410 and screened assembly 420, as with the previous embodiment of Figure 8 .
  • this system 400 has slurry dehydration or bypass tubes 480 disposed along the various sections 428A-C.
  • the tubes 480 help dehydrate slurry intended to frac or gravel pack the borehole annulus 15 of the sections 428 during a frac pack or gravel pack type of operation.
  • the tubes 480 can act as a bypass for fluid returns during the operation.
  • treatment fluid flows from the workstring 410 seated in a valve 430, through the opened ports 432, and into the borehole annulus 15, the wellscreen 446 screens fluid returns from the annulus 15, and the fluid returns can flow into the assembly 420 downhole of the engagement of the workstring 410 in the assembly 420.
  • the tubes 480 can, therefore, allow these fluid returns to flow from the downhole section of the assembly 420 to the micro-annulus between the workstring 410 and the inside of the assembly 420 uphole of the sealed engagement of the workstring 410 with the ports 432. From this point, the fluid returns can then flow to the surface.
  • the multi-zone system 400 of Figure 9 can have higher rates compared to a conventional single trip multi-zone system 400 and can improve reservoir performance. Furthermore, the system 400 can have any length and spacing, offers the option to step down one casing size, does not require perforating, does not require a clean-out trip, and can give good annulus packing. Consideration should be given to potential sticking of the workstring 410 for a particular implementation.
  • the multi-zone system 400 can use flow devices 440 disposed on the assembly 420, and the flow device 440 includes the wellscreen 446 and the closure 450 ( i.e., one-way or check valves).
  • FIGs 10A-10B one embodiment of a flow device 540 that can be used for the disclosed systems 400 is shown in a partial cross-sectional view and a detailed view, respectively.
  • the flow device 540 is a screen joint having a screen jacket 550 (i.e., wellscreen) and an inflow control device 560 (i.e., one-way or check valve) disposed on a basepipe 542.
  • Figure 10C shows the inflow control device 560 in an isolated view without the basepipe 542 and the screen jacket 160.)
  • the flow device 540 is deployed on a completion string (422: Figs. 8-9 ) with the screen jacket 550 typically mounted upstream of the inflow control device 560, although this may not be strictly necessary.
  • the basepipe 542 defines a through-bore 545 and has a coupling crossover 546 at one end for connecting to another joint or the like. The other end 544 can connect to a crossover (not shown) of another joint on the completion string (422). Inside the through-bore 545, the basepipe 542 defines pipe ports 548 where the inflow control device 560 is disposed.
  • the inflow control device 560 can be similar to a FloReg deploy-assist (DA) device available from Weatherford International. As best shown in Figure 10B , the inflow control device 560 has an outer sleeve 562 disposed about the basepipe 152 at the location of the pipe ports 548. A first end-ring 564 seals to the basepipe 542 with a seal element 565, and a second end-ring 566 attaches to the end of the screen jacket 550. Overall, the sleeve 562 defines an annular space around the basepipe 542 communicating the pipe ports 548 with the screen jacket 550. The second end-ring 566 has flow ports 570 that separate the sleeve's annular space into a first inner space 576 communicating with the screen 550 and second inner space 578 communicating with the pipe ports 548.
  • DA FloReg deploy-assist
  • the screen jacket 550 is disposed around the outside of the basepipe 542.
  • the screen jacket 550 can be a wire wrapped screen having rods or ribs 554 arranged longitudinally along the base pipe 542 with windings of wire 552 wrapped thereabout to form various slots. Fluid can pass from the surrounding borehole annulus to the annular gap between the screen jacket 550 and the basepipe 542.
  • the screen jacket 550 can use any other form of screen assembly, including metal mesh screens, pre-packed screens, protective shell screens, expandable sand screens, or screens of other construction.
  • the inflow control device 560 has a number (e.g., ten) of flow ports 570.
  • the inflow control device 560 as shown in Figures 10A-10C may lack the typically used restrictive nozzles and closing pins for the internal flow ports 570.
  • the flow ports 570 may be relatively unrestricted flow passages and may lack the typical nozzles, although a given implementation may use such nozzles if a pressure drop is desired from the screen jacket 550 to the basepipe 542.
  • the inflow control device 560 does include port isolation balls 572, which allow the device 560 to operate as a one-way or check valve.
  • the port isolation balls 572 can move to an open condition (to the right in Fig. 10B ) permitting fluid communication from the screen's inner space 576 to the pipe's inner space 578 or to a closed condition (to the left in Fig. 10B against a seat end 574 of the flow port 570) preventing fluid communication from the pipe's inner space 578 to the screen's inner space 576.
  • the inflow control device 560 can facilitate fluid circulation during deployment and well cleanup and can be used in interventionless deployment and setting of openhole packers.
  • the isolation balls 572 maximize fluid circulation through the completion shoe (420: Figs. 8-9 ) of the frac system (20) to aid efficient deployment of the completion string (22) and system (20).
  • the housing components (562, 564, 565, & 566) are disposed on the basepipe 540, the isolation balls 572 are retained in-place.
  • the isolation balls 572 can prevent formation surging, thereby reducing damage to the formation.
  • the isolation balls 572 within the device 560 can be configured to erode over a period of time, allowing access to the interval for workover activity such as stimulation.
  • the flow ports 570 can include nozzles (not shown) that restrict flow of screened fluid (i.e., inflow) from the screen jacket 550 to the pipe's inner space 578.
  • the inflow control device 560 can have ten nozzles, although they all may not be open. Operators can set a number of these nozzles open at the surface to configure the device 560 for use downhole in a given implementation. Depending on the number of open nozzles, the device 560 can thereby produce a configurable pressure drop along the string of such flow devices 540.
  • Figures 11A-11B illustrate another multi-zone screened system 400 according to the present disclosure used for an open hole completion.
  • the system 400 can be used for formation treatments, such as frac operations, frac pack operation, gravel pack operations, or other operations.
  • the system 400 has a workstring 410 that disposes in a screened assembly 420 to open the various valves 430 and treat portions of the formation, but the workstring 410 in this arrangement does not seal inside the assembly 420 when delivering the treatment at various points in the formation.
  • a service packer 17 can be used between the workstring 410 and the casing 12 to isolate the internal through-bore 425 of the assembly 420.
  • the workstring 410 has a service tool 417 disposed above the liner packer 16.
  • the service tool 417 can be used for hydraulically setting the packer 16.
  • the uphole components of the system 400 can be used for circulating, squeeze, and reverse out operations as is known in the art.
  • the workstring 410 has one or more outlet ports 412 and has hydraulically actuated shifting tools 418a-b. Both of the shifting tools 418a-b can be actuated with applied pressure against a ball when seated in the workstring 410.
  • One shifting tool 418b can open the valves 430 when the workstring 410 is run downhole in the assembly 420, while the other shifting tool 418a can close the valves 430 when the workstring 410 is run uphole in the assembly 420.
  • opening and closing the flow devices 440 with the shifting tools 418a-b as discussed below.
  • one shifting tool 418b is run facing down, while the other tool 418a is run facing up.
  • Other arrangements can be used, and other types of shifting tools can be used as well.
  • the shifting tools 418a-b can each be a hydraulically actuated version of an industry standard B shifting tool.
  • the shifting ball (74) is dropped in the workstring 410, the application of hydraulic pressure down the workstring 410 actuates the shifting tools 418a-b so that they expose spring-loaded keys for shifting the valves 430 and flow devices 440 open or closed.
  • the shifting tools 418a-b may be actuated together with the same ball 414 or actuated separately with different sized balls 414 depending on the configuration.
  • the assembly 420 has a production string 422 supported from a packer 16 in the casing 12.
  • the string 422 has isolation devices 429, valves 430, and flow devices 440.
  • the isolation devices 429 which can be packers, seal the borehole annulus 15 around the assembly 420 and separate the annulus 15 into various zones or sections 428A-C.
  • Each section 428A-C has at least one of the valves 430 and at least one of the flow devices 440, both of which can selectively communicate the string's through-bore 425 with the borehole annulus 15 as detailed below.
  • the assembly 420 has a bottom seat 422 for engaging a setting ball 424 to close off the shoe 420 during frac, gravel pack, or frac pack operations.
  • the selective valve 430 is disposed uphole of the flow device 440 in each of the various sections 428A-C.
  • the selective valve 430 can be disposed downhole of the flow device 440 in each section 428A-C.
  • a given section 428A-C may have more than one valve 30 and/or flow device 440.
  • the selective valves 430 have one or more ports 432 that can be selectively opened and closed during operation. In this arrangement as with others discussed above, each of the selective valves 430 can be opened to communicate their ports 432 with the surrounding annulus 15 by using the shifting tool 418a on the workstring 410.
  • the valves 430 can be sliding sleeves having a movable closure element 434, such as an inner sleeve or insert, which isolates or exposes ports 432 in the sliding sleeve's housing.
  • the flow devices 440 also have one or more ports 442 that can be selectively opened and closed during operation.
  • Each of the flow devices 440 also includes a closure and a screen 446.
  • the closure in this arrangement includes a first closure element 444 that selectively opens and closes flow through the flow ports 442 and includes a second closure element 450 that at least prevents fluid flow from the through-bore 425 through the screen 446.
  • This system 400 is a single trip, multi-zone system as discussed in previous embodiments. Briefly, the assembly 420 is run downhole as part of the production string 422 or liner system deployed in the borehole, and the liner packer 16 is set hydraulically. Treatments are then performed for the various zones or sections 428A-B of the borehole annulus 15 by selectively opening the valves 430.
  • the flow devices 40 are then opened in the assembly 420 with the workstring 410 in the same trip in the wellbore by opening the first closure element 444 (e.g., inner sleeve) to expose the flow ports 442.
  • the first closure element 444 e.g., inner sleeve
  • the flow devices 440 screen fluid from the borehole annulus 15 into the string's through-bore 425.
  • the flow device's second closure element 450 functions to prevent flow in the reverse direction.
  • the flow device's second closure element 450 which can use one-way or check valve, can prevent fluid loss into the formation while pulling out the workstring 410 from the assembly 420 and while performing production.
  • valves 430 and flow devices 440 are closed on the assembly 420 when run in the borehole.
  • operators set the packers 429 along the assembly 420 with the appropriate procedures to create the multiple isolated sections 428A-C down the borehole annulus 15. Once the packers 429 are set, operators can then commence with applying treatment successively to each of the isolated sections 428A-C by selectively opening and then closing the selective valves 430 with the shifting tools 418a-b on the workstring 410.
  • the selective valve 430 for the lower section 428A is opened, but its accompanying flow device 440 remains closed.
  • operators position the workstring 410 near the valve 430 and drop the shifter ball (414) to the shifting tools 418a-b on the workstring 410.
  • Operators then pressure up the workstring 410, and the applied pressure in the workstring's bore 415 acts against the seated ball (414) and actuates the shifting tools 418a-b.
  • the opening tool e.g., 418b
  • operators open the valve 430 e.g., by shifting the inner sleeve 434 in the valve 430 open).
  • operators bleed off the applied pressure and reverse the flow so that the seated ball (414) in the workstring 410 can be reversed out through the workstring's bore 415 to the surface.
  • the flow device 440 can be a sliding sleeve having a movable closure element 444, such as an inner sleeve or insert, which isolates or exposes the ports 442 in the sliding sleeve's housing.
  • the flow device 440 can be opened to communicate its ports 442 with the surrounding annulus 15 through its screen 446 by using the shifting tool 418a on the workstring 410. In this way, the flow device 440 when closed does not communicate the string's through-bore 425 with the borehole annulus 15 through screens 446, but the flow device 440 when opened allows screened fluid from the annulus 15 to pass through the screen 446 on the device 440 and into the through-bore 425.
  • the system 400 can use a live annulus technique (if the service packer 17 is not used or can be removed, or the system 400 can use a pure squeeze technique with the service packer 17 in the casing 12.
  • the closure on the flow device 440 at least prevents fluid flow through the ports 442 and screen 446 from the through-bore 425 to the borehole annulus 15. Preventing the flow out of the screen 446 can be accomplished by either the first or second closure elements 444 and 450 or by both. Preferably, the first closure element 444 also prevents fluid flow from the borehole annulus 15 into the through-bore 425 via the screen 446.
  • fluid from the borehole annulus 15 can flow along a second flow path through the screens 446, closure elements 450, and opened ports 442.
  • the second closure elements 48 e.g., one-way or check valves
  • the workstring 410 is removed from the assembly 420.
  • the assembly 420 is prepared to receive production through the screens 446, closure elements 450, and opened ports 442 via the second flow path.
  • operation of this system 400 can reduce the time and risk involved in performing the treatment because no service tool needs to seal in the assembly 420. Moreover, pickup and operations time are reduced. Essentially, the workstring 410 can be run in during the liner setting trip so that no added runs are needed. Cleanout and opening/closing of the ports 432 and 442 in the valves 430 and flow devices 440 are all done in the same trip.
  • the present example of the system 400 is described for an open hole, but the system 400 for a cased hole would be the same except that the isolation packers 429 may be different. Because the system 400 does not use dropped balls in the assembly 420 to open the valve 430 or flow devices 440, the number of stages that can be deployed downhole is not limited by the required step-down sizes in balls and seats. Moreover, no balls or seats are left in the assembly 420 after treatment operations so the operation does not need a separate milling operation, which can be time consuming and can encounter its own issues. In essence, the wellbore is ready to receive production tubing after the operation is completed.
  • sand slurry is introduced into the annulus uphole of the wellscreens and is circulated downhole (i.e., from heel to toe).
  • the toe-to-heel system as disclosed for example in Figures 2A-7 reverses that flow path and introduces the sand slurry into the screen annulus at the toe of the well and circulates it uphole. Further details related to this system are provided in U.S. Appl. 12/913,981, filed 28-OCT-2010 .
  • the toe-to-heel system of Figures 2A-7 is designed so that any excess sand slurry in the workstring can be disposed of downhole in a dedicated annulus in the well.
  • the toe-to-heel system of Figures 2A-7 is designed so that any excess sand slurry in the workstring can be emptied downhole in a dedicated annulus in the well.
  • a toe-to-heel system 600 disclosed in Figures 12A-12D equips each wellscreen 640 with closure elements 645 (e.g., check valves or the like).
  • closure elements 645 e.g., check valves or the like.
  • the closure elements 645 on the screens 640 prevent fluid flow inside the screens 640 from passing outside the screens 640, but allow fluid flow from outside the screens 640 to pass inside the assembly 620. This allows operators to apply pressure inside the screen liner assembly 620 after gravel packing in order to reverse circulate and remove excess slurry from the workstring 610 after completing a gravel pack.
  • the system 600 includes a packer 14 that sets in the casing 12 above the area of a wellbore to be produced from or injected into.
  • a screen liner assembly 620 is spaced out across one or more zones of interest. If there are multiple zones, packers 670 (either open hole or cased hole) are spaced out to isolate one screen section 602A-C from the other. The packers 670 do not require shunts running through them to gravel pack multiple zones, but they could be equipped this way.
  • the assembly 620 and packers 670 are run downhole in a single trip.
  • This system 600 segments several compartmentalized reservoir zones so that multiple gravel pack operations as well as frac operations can be performed.
  • the system 600 has several gravel pack sections 602A-C separated by packers 670, which seal in the open hole to isolate one zone from another.
  • One or more packers 670 can be used to isolate each of the gravel pack sections 602A-C from one another. Any suitable packers can be used and can include hydraulic packer, hydrostatic packers, and swellable packers, for example.
  • the packers 670 provide zone isolation when set in the borehole 10 to stop the progression of the treatment operations in the isolated zones.
  • Each section 602A-C can be similar to the systems 200, 300, and 400, as discussed above.
  • Each section 602A-C has a screen 640 and ports 650.
  • the screens 640 include a closure element 645 (e.g., one-way valve, check valves, or the like).
  • Ports 650 adjacent the screens 640 may or may not include valves 652 or selective sleeves.
  • This system 600 has a workstring 610 that disposes in the assembly 620 to treat (e.g., gravel or frac pack) portions of the formation.
  • the workstring 610 has external seals 612 disposed near outlet ports 614.
  • a dropped ball 414 can seat in a distal seat of the workstring 610 to divert fluid flow down the workstring 610, out the outlet ports 612, and to the ports 650 in the assembly 620 to treat the surrounding formation.
  • other configurations can be used for the workstring 610.
  • the workstring 610 deploys in the first section 602A and performs washdown by communicating the string's outlet port 612 with the float valve 626 on the float shoe 620 of the system 600.
  • the packers 670 are set to create the multiple isolated sections down the borehole annulus 15.
  • the packers 670 can be set hydraulically, hydrostatically, with RFID tags, or with pressure pulses.
  • the string 610 can be selectively positioned at any one of the various sections 602A-C along the system 600.
  • the string's outlet ports 612 with its seals 614 isolate to the flow ports 650 to gravel pack and/or frac pack the annulus 15 around given gravel pack section 602A-C.
  • the inner workstring 610 can be moved so that the outlet ports 612 isolate from these flow ports 650 so reverse circulation can be performed to remove excess slurry from the workstring 610 before moving it to the next gravel pack section 602A-C.
  • a similar process can then be repeated up the hole for each gravel pack section 602A-C separated by the packers 670.
  • the string's outlet ports 612 with its seals 614 isolates to the flow ports 650 to gravel pack and/or frac pack the first gravel pack section 602A.
  • the flow ports 650 include a valve, then the valve may be opened, for example, by shifting a sleeve open. Slurry communicated down the workstring 610 exits the outlet ports 612 and passes through the section's ports 650 to flow into the isolated annulus of this first section 602A. Gravel from the slurry then gravel packs in the annulus from toe-to-heel as described herein, and fluid returns from the slurry pass through the screen 640 and into the annular space between the liner 630 and the workstring 610. The fluid returns can then flow uphole past the packer 14 to the casing 12 and the surface.
  • the ports 650 may have selective valves or sleeves 652 that can be opened with a shifting tool 616 on the workstring 610, although these components may not be necessary in every embodiment.
  • the shifting tool 616 can be a "B" shifting tool for shifting the valve 652 relative to the ports 650.
  • opening a given valve 652 involves engaging the shifting tool 616 in an appropriate profile of the valve 652 and moving the valve 652 with the workstring 610 to an opened condition so that the assembly's through-bore 625 communicates with the borehole annulus 15 via the now opened ports 650.
  • the seals 614 on the workstring 610 can engage and seal against inner seats 654, surfaces, seals, or the like at the ports 650 in the assembly 620 on both the uphole and downhole sides.
  • the seals 614 can use elastomeric or other types of seals disposed on the inner workstring 610, and the seats 654 can be polished seats or surfaces inside the assembly 620 to engage the seals 614.
  • the reverse arrangement can be used with seals on the inside of the assembly 620 and with seats on the workstring 610. Additionally, some embodiments may lack seals and seats altogether and may instead rely on opening and closing the valves 652 on the ports 650 to control fluid flow.
  • treatment fluid is flowed down the through-bore of the workstring 610 to the ports 650 at the first zone 602A.
  • the treatment fluid flows through the outlet ports 612 in the workstring 610 and through the ports 650 to the surrounding borehole annulus 15, which allows the treatment fluid to interact with the adjacent zone of the formation.
  • fracture treatment with proppant can be pumped, or gravel in a slurry can be pumped into the annulus.
  • Gravel packing from toe-to-heel in the system 600 allows fluid returns to pass through the screen 640 and dehydrate the slurry intended to gravel pack the borehole annulus 15 of the sections 602A-C during a gravel or frac pack type of operation.
  • fluid returns R can flow through the screen 640 and pass through the check valve 645 on the screen 640 and into the through-bore 625 of the assembly 620.
  • the wellscreen 640 screens fluid returns from the annulus 15, and the fluid returns can flow into the assembly 620 uphole of the engagement of the workstring 610 in the assembly 620. From this point, the fluid returns can then flow to the surface.
  • the workstring 610 can be manipulated to an intermediate position so that the outlet ports 612 communicate inside the screen liner assembly 620.
  • operators can manipulate the workstring 610 to engage the shifting tool 616 in the valve 652 to close the ports 650.
  • the shifting tool 616 can engage another suitable profile on the valve 652 to move the valve 652 and close the ports 650.
  • the workstring 610 can be moved in the assembly 620 to an intermediate position that allows for excess slurry to be removed from the workstring 610 before moving the workstring 610 to a new zone 602B.
  • any excess slurry in the workstring 610 can flow into the assembly 620 while the workstring 610 is manipulated, and any gravel, proppant, sand, or the like in the slurry can cause problems with the workstring 610 sticking, fouling valves, etc.
  • the workstring 610 can be moved in the assembly 620 to another zone 602B to perform treatment. Operators repeat this process up the assembly 620 to treat all of the sections 602A-C. Once the treatment is complete, the system 600 may not need a clean-out trip.
  • gravel packing can be accomplished where the wellscreens 640 are able to be pressurized on the inside.
  • This allows the system 600 to be operated under reverse circulation that exerts pressure inside the assembly 620. Being able to reverse circulation this way makes it possible to perform single zone toe-to-heel gravel packs and subsequently reverse out the excess slurry.
  • the system 600 also makes it possible to perform multiple gravel packs at different points in the wellbore, reversing out after each individual gravel pack operation.
  • the workstring 610 inside the assembly 620 can be positioned at each pumping point in the assembly 620, starting at the lowest point for example, and deliver the gravel pack slurry into the annulus 15, circulating in a toe-to-heel fashion.
  • the workstring 610 is repositioned so that pressure applied to the casing 12 and inside the assembly 620 results in reverse circulating of any excess slurry up the workstring 610. Once that slurry has been removed, the workstring 610 is raised to the next pumping location, and the steps are repeated.

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Claims (15)

  1. Procédé de traitement de formation pour un trou de forage (10), le procédé comprenant les étapes consistant à :
    isoler un espace annulaire de trou de forage (15) du trou de forage (10) autour d'un ensemble (600) pour créer une pluralité de zones isolées (602), l'ensemble (600) de présentant dans chaque zone isolée (602) un orifice (650) et un crible (640) faisant communiquer un trou traversant (625) de l'ensemble (600) avec l'espace annulaire de trou de forage (15) ;
    positionner un train de tiges de travail (610) dans le trou traversant (625) de l'ensemble (600) ;
    traiter l'espace annulaire de trou de forage (15) de chacune des zones isolées (602) grâce aux étapes consistant à :
    ouvrir un premier clapet (652) au niveau de l'orifice (650) de la zone isolée (602) avec le train de tiges de travail (610) ;
    fermer de manière étanche une sortie (612) du train de tiges de travail (610) au niveau de l'orifice (650) de la zone isolée (602),
    faire s'écouler de la boue faisant office de traitement vers le bas du train de tiges de travail (610), hors de la sortie (612), et vers l'orifice (650),
    créer un massif de gravier dans l'espace annulaire de trou de forage (15) de la zone isolée (602) grâce à du gravier présent dans la boue,
    filtrer des retours fluides de la boue en provenance de l'espace annulaire de trou de forage (15) de la zone isolée (602) et allant dans le trou traversant (625) de l'ensemble (600) à travers le crible (640) et à travers un deuxième clapet (645) situé au niveau du crible (640),
    empêcher la circulation des retours fluides dans le trou traversant (625) de revenir vers l'espace annulaire de trou de forage (15) en sortant des premier et deuxième clapets (652, 645) des autres zones isolées (602) présentes sur l'ensemble (600) ; et
    retirer le traitement excédentaire, hors du train de tiges de travail (610) grâce aux étapes consistant à : fermer de manière étanche la sortie (612) par rapport au premier clapet ouvert (652) de l'orifice (650), faire circuler de manière inverse vers le bas dans le trou traversant (625) de l'ensemble (600) et jusque dans la sortie (612) du train de tiges de travail (610), et empêcher la circulation inverse dans le trou traversant (625) de communiquer avec l'espace annulaire de trou de forage (15) à travers les premier et deuxième clapets (645, 625) des cribles (640) et les orifices (650) des zones isolées (602).
  2. Procédé selon la revendication 1, comprenant une étape consistant à positionner initialement l'ensemble dans un tubage présentant des perforations, dans une colonne perdue élargie présentant des fentes, ou dans un trou en découvert, et éventuellement dans lequel l'étape d'isolation de l'espace annulaire de trou de forage du trou de forage (10) autour de l'ensemble pour créer des zones isolées comprend une étape consistant à mettre en prise des éléments d'isolation (670) présents sur l'ensemble contre une paroi du tubage, une paroi de la colonne perdue élargie, ou une paroi du trou en découvert.
  3. Procédé selon la revendication 1 ou 2, dans lequel l'étape d'ouverture du premier clapet (652) au niveau de l'orifice (650) au niveau de la zone isolée (620) avec le train de tiges de travail (610) comprend une étape consistant à décaler un manchon (652) dans l'ensemble (600) en l'éloignant de l'orifice (650) avec le train de tiges de travail (610).
  4. Procédé selon la revendication 1, 2 ou 3, comprenant en outre une étape consistant à fermer le premier clapet (652) de l'orifice (650) au niveau de la zone isolée (602) avec le train de tiges de travail (610) après l'étape de retrait de la boue excédentaire hors du train de tiges de travail (610).
  5. Procédé selon l'une quelconque des revendications 1 à 4, dans lequel l'étape de traitement de la zone isolée (602) comprend les étapes consistant à :
    faire circuler la boue faisant office de traitement à partir de l'orifice (650) agencé en direction de la pointe, créer un massif de gravier dans l'espace annulaire (15) de la zone isolée (602) à partir de la pointe vers le talon, et filtrer les retours fluides dans le trou traversant (625) de l'ensemble (600) à travers le crible (640) agencé en direction du talon.
  6. Procédé selon l'une quelconque des revendications 1 à 4, dans lequel l'étape de traitement de la zone isolée (602) comprend les étapes consistant à :
    faire circuler la boue faisant office de traitement à partir de l'orifice (650) agencé en direction de la zone d'inflexion, créer un massif de gravier dans l'espace annulaire (15) de la zone isolée (602) entre la zone d'inflexion et les fonds de trou,
    filtrer les retours fluides allant dans le trou traversant (625) de l'ensemble (600) à travers le crible (640) agencé en direction du fonds de trou, et
    dériver les retours fluides vers le trou traversant (625) de l'ensemble (600) au-dessus de l'orifice (650).
  7. Procédé selon l'une quelconque des revendications 1 à 6, dans lequel l'étape consistant à empêcher la circulation des retours fluides dans le trou traversant (625) de revenir vers l'espace annulaire de trou de forage (15) en sortant des deuxièmes clapets (645) au niveau des cribles (640) comprend une étape consistant à faire fonctionner des clapets anti-retour (645) agencés en communication entre les cribles (640) et le trou traversant (625).
  8. Procédé selon l'une quelconque des revendications 1 à 7, comprenant en outre une étape consistant à préparer les zones isolées (602) en vue d'une production grâce aux étapes consistant à :
    fermer les premiers clapets (652) présents au niveau des orifices (650) de l'ensemble (600) au niveau des zones isolées (602) avec le train de tiges de travail (610) ; et
    permettre une communication fluidique à partir de l'espace annulaire de trou de forage (15) jusque dans le trou traversant (625) à travers le crible (640) et les deuxièmes clapets (645) au niveau des zones isolées (602).
  9. Procédé selon la revendication 8, comprenant en outre une étape consistant à tamiser un fluide de production en provenance de l'espace annulaire de trou de forage (15) de la zone isolée et allant dans le trou traversant (625) de l'ensemble à travers le crible (640) et les deuxièmes clapets (645).
  10. Procédé selon l'une quelconque des revendications 1 à 9, dans lequel l'ensemble (600) comprend :
    un corps (620) agencé dans le trou de forage (10) et définissant un trou traversant (625) ;
    une ou plusieurs section(s) (602) agencée(s) sur le corps (620), chacune parmi la ou les section(s) (602) comprenant :
    un élément d'isolation (670) agencé sur le corps (620) et isolant l'espace annulaire de trou de forage (15) autour de la section (602) par rapport aux autres sections (602),
    l'orifice (650) agencé sur le corps (620) et permettant une communication fluidique entre le trou traversant (625) et l'espace annulaire de trou de forage (15),
    le premier clapet (652) agencé sur le corps (620) et pouvant être utilisé de manière sélective pour ouvrir une circulation de fluide à travers l'orifice (650) et pour fermer une circulation de fluide à travers l'orifice (650) ;
    le crible (640) agencé sur le corps (620) et communiquant avec l'espace annulaire de trou de forage (15), et
    le deuxième clapet (645) agencé sur le corps (620), ledit deuxième clapet (645) permettant une communication fluidique entre le crible (625) et le trou traversant (625) et empêchant une communication fluidique entre le trou traversant (625) et le crible (640).
  11. Procédé selon l'une quelconque des revendications 1 à 10, dans lequel le premier clapet (652) comprend un manchon pouvant être déplacé dans le trou traversant (625) entre (a) un état fermé empêchant une communication fluidique à travers l'orifice (650) et (b) un état ouvert permettant une communication fluidique à travers l'orifice (650).
  12. Procédé selon l'une quelconque des revendications 1 à 11, dans lequel le train de tiges de travail (610) comprend un outil d'actionnement (616) pouvant servir à ouvrir et fermer les premiers clapets (652) dans le trou traversant (625) au cours de la même manoeuvre, l'outil d'actionnement (616) pouvant éventuellement être utilisé de manière hydraulique.
  13. Procédé selon l'une quelconque des revendications 1 à 12, dans lequel le train de tiges de travail (610) comprend des premiers joints étanches (614) adjacents à la sortie (612), et dans lequel l'ensemble (600) comprend des deuxièmes joints étanches (654) agencés dans le trou traversant (625) à proximité adjacente de l'orifice (650), les deuxièmes joints étanches (654) venant en prise avec les premiers joints étanches (614) et isolant une communication fluidique de la sortie (612) avec l'orifice (650).
  14. Procédé selon l'une quelconque des revendications 1 à 13, dans lequel l'élément d'isolation (670) comprend au moins une parmi une garniture d'étanchéité gonflable, une garniture d'étanchéité mise en place de manière hydraulique, une garniture d'étanchéité mise en place de manière hydrostatique, et une garniture d'étanchéité mise en place de manière mécanique.
  15. Procédé selon l'une quelconque des revendications 1 à 14, dans lequel le deuxième clapet (645) comprend un clapet anti-retour agencé en communication fluidique entre le crible (640) et le trou traversant (625), le clapet anti-retour à l'état ouvert permettant une communication fluidique entre le crible (640) et le trou traversant et, à l'état fermé, empêchant une communication fluidique entre le trou traversant (625) et le crible (640) et éventuellement dans lequel le clapet anti-retour comprend : une enveloppe agencée sur le corps (620) et faisant communiquer le crible (640) avec au moins un orifice de circulation situé dans le corps (620) ; et une bille anti-retour agencée mobile dans l'enveloppe, ladite bille anti-retour permettant une communication fluidique entre le crible (640) et le au moins un orifice de circulation et empêchant une communication fluidique entre le au moins un orifice de circulation et le crible (640).
EP15168402.4A 2014-05-20 2015-05-20 Ensemble pour le compactage de gravier «toe-to-heel» et circulation en sens inverse de la boue en excès Not-in-force EP2957715B1 (fr)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US14/282,692 US10082007B2 (en) 2010-10-28 2014-05-20 Assembly for toe-to-heel gravel packing and reverse circulating excess slurry

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EP2957715A2 EP2957715A2 (fr) 2015-12-23
EP2957715A3 EP2957715A3 (fr) 2015-12-30
EP2957715B1 true EP2957715B1 (fr) 2017-10-18

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EP (1) EP2957715B1 (fr)
AU (1) AU2015202733B2 (fr)
CA (1) CA2892410A1 (fr)
NO (1) NO3124015T3 (fr)
RU (1) RU2599751C1 (fr)

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US11879311B2 (en) 2018-11-07 2024-01-23 Schlumberger Technology Corporation Method of gravel packing open holes

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US6464006B2 (en) * 2001-02-26 2002-10-15 Baker Hughes Incorporated Single trip, multiple zone isolation, well fracturing system
US8511380B2 (en) * 2007-10-10 2013-08-20 Schlumberger Technology Corporation Multi-zone gravel pack system with pipe coupling and integrated valve
US9447661B2 (en) * 2010-10-28 2016-09-20 Weatherford Technology Holdings, Llc Gravel pack and sand disposal device
US9260950B2 (en) * 2010-10-28 2016-02-16 Weatherford Technologies Holdings, LLC One trip toe-to-heel gravel pack and liner cementing assembly
US20130062066A1 (en) * 2011-07-12 2013-03-14 Weatherford/Lamb, Inc. Multi-Zone Screened Fracturing System
US8770290B2 (en) * 2010-10-28 2014-07-08 Weatherford/Lamb, Inc. Gravel pack assembly for bottom up/toe-to-heel packing
CA2789859C (fr) * 2011-09-16 2016-12-20 Weatherford/Lamb, Inc. Dispositif d'elimination du sable et du gravier
RU2578064C2 (ru) * 2012-01-06 2016-03-20 Везерфорд Текнолоджи Холдингз, ЛЛК Компоновка цементирования хвостовика и установки гравийного фильтра от носка к пятке в одном рейсе

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Publication number Priority date Publication date Assignee Title
US11879311B2 (en) 2018-11-07 2024-01-23 Schlumberger Technology Corporation Method of gravel packing open holes

Also Published As

Publication number Publication date
AU2015202733B2 (en) 2016-06-16
EP2957715A2 (fr) 2015-12-23
NO3124015T3 (fr) 2018-08-25
RU2599751C1 (ru) 2016-10-10
CA2892410A1 (fr) 2015-11-20
AU2015202733A1 (en) 2015-12-10
EP2957715A3 (fr) 2015-12-30

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