WO2015080872A1 - System and method for re-fracturing multizone horizontal wellbores - Google Patents
System and method for re-fracturing multizone horizontal wellbores Download PDFInfo
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- WO2015080872A1 WO2015080872A1 PCT/US2014/065532 US2014065532W WO2015080872A1 WO 2015080872 A1 WO2015080872 A1 WO 2015080872A1 US 2014065532 W US2014065532 W US 2014065532W WO 2015080872 A1 WO2015080872 A1 WO 2015080872A1
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- Prior art keywords
- location
- fractured
- tubing string
- horizontal wellbore
- previously
- Prior art date
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- 238000000034 method Methods 0.000 title claims abstract description 60
- 239000000463 material Substances 0.000 claims abstract description 62
- 239000012530 fluid Substances 0.000 claims abstract description 23
- 238000012360 testing method Methods 0.000 claims abstract description 20
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 13
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 13
- 230000015572 biosynthetic process Effects 0.000 claims description 29
- 238000012856 packing Methods 0.000 claims description 27
- 238000005086 pumping Methods 0.000 claims description 6
- 229920001187 thermosetting polymer Polymers 0.000 claims description 6
- 239000004576 sand Substances 0.000 claims description 5
- 238000004140 cleaning Methods 0.000 claims description 4
- 239000000835 fiber Substances 0.000 claims description 3
- 239000002245 particle Substances 0.000 claims description 3
- 238000004519 manufacturing process Methods 0.000 abstract description 17
- 239000004215 Carbon black (E152) Substances 0.000 abstract description 2
- 206010017076 Fracture Diseases 0.000 description 85
- 208000010392 Bone Fractures Diseases 0.000 description 74
- 238000005755 formation reaction Methods 0.000 description 28
- 230000008901 benefit Effects 0.000 description 7
- 208000006670 Multiple fractures Diseases 0.000 description 5
- 238000007789 sealing Methods 0.000 description 5
- 239000000499 gel Substances 0.000 description 4
- 238000002955 isolation Methods 0.000 description 4
- 238000005253 cladding Methods 0.000 description 2
- 230000007423 decrease Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000004458 analytical method Methods 0.000 description 1
- 229910001570 bauxite Inorganic materials 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000012512 characterization method Methods 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 230000007717 exclusion Effects 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 230000002452 interceptive effect Effects 0.000 description 1
- 239000013618 particulate matter Substances 0.000 description 1
- 230000037361 pathway Effects 0.000 description 1
- 239000011347 resin Substances 0.000 description 1
- 229920005989 resin Polymers 0.000 description 1
- 230000004936 stimulating effect Effects 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/261—Separate steps of (1) cementing, plugging or consolidating and (2) fracturing or attacking the formation
-
- 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
- E21B43/14—Obtaining from a multiple-zone well
-
- 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
- the embodiments described herein relate to a system and method for re-fracturing select locations, such as prior perforations, prior fractures, and/or prior fracture clusters, of the formation of a multizone horizontal wellbore.
- the formation may also re-fracture the formation through a sliding sleeve left open during a prior hydraulic fracturing process.
- Natural resources such as gas and oil may be recovered from subterranean formations using well-known techniques. For example, a horizontal wellbore may be drilled within the subterranean formation. After formation of the horizontal wellbore, a string of pipe, e.g., casing, may be run or cemented into the well bore. Hydrocarbons may then be produced from the horizontal wellbore.
- a horizontal wellbore may be drilled within the subterranean formation.
- a string of pipe e.g., casing
- Hydrocarbons may then be produced from the horizontal wellbore.
- the casing may be perforated and fracturing fluid may be pumped into the wellbore to fracture the subterranean formation.
- the fracturing fluid is pumped into the well bore at a rate and a pressure sufficient to form fractures that extend into the subterranean formation, providing additional pathways through which fluids being produced can flow into the well bores.
- the fracturing fluid typically includes particulate matter known as a proppant, e.g., graded sand, bauxite, or resin coated sand, may be suspended in the fracturing fluid. The proppant becomes deposited into the fractures and thus holds the fractures open after the pressure exerted on the fracturing fluid has been released.
- Another method to increase the production of hydrocarbons from a wellbore is to attempt to fracture the formation through ported collars or tubulars within the wellbore.
- these ported collars may be selectively closed by a sliding sleeve, which may be actuated to an open position by various means such as by the use of a shifting tool or by the application of a pressure differential.
- fracturing fluid may be pumped down the well and out the port in an attempt to fracture the formation to increase production of hydrocarbons.
- a production zone within a wellbore may have been previously fractured, but the prior fracturing may not have adequately fractured the formation leading to inadequate production from the production zone. Even if the formation was adequately fractured, the production zone may no longer be producing at adequate levels. Over an extended period of time, the production from a previously fractured horizontal wellbore may decrease below a minimum threshold level.
- One technique in attempting to increase the hydrocarbon production from the wellbore is the addition of new fractures within the subterranean formation.
- One potential problem in introducing new fractures in the formation is that fracturing fluid pumped into the wellbore may enter prior fractures formed in the subterranean formation instead of creating new fractures.
- Expandable tubulars or cladding procedures have been used within a wellbore in an attempt to block the flow path of the fracturing fluid to the old fractures, instead promote the formation of new fracture clusters.
- the use of expandable tubulars or cladding may not adequately provide the desired results and further, may incur too much expense in the effort to increase products from the wellbore. A more efficient way to increase the production of a horizontal wellbore is needed.
- the present disclosure is directed to a method and system for re-fracturing select locations of a formation in a multizone horizontal wellbore that have been previously fractured or were attempted to be fractured that overcomes some of the problems and disadvantages discussed above.
- One embodiment is a method for re-fracturing a location of a formation of a multizone horizontal wellbore comprising hydraulically isolation a first location from a portion of the multizone wellbore uphole from the first location, the first location having been previously hydraulically fractured at least once and hydraulically re-fracturing the first location.
- the method comprises providing a first diverting material proximate to the first location after the first location has been hydraulically re-fractured, wherein the first diverting material hydraulically isolates the re-fractured first location from the multizone horizontal wellbore uphole of the first location.
- the method comprises hydraulically isolating a second location from a portion of the multizone horizontal wellbore uphole of the second location, the second location having been previously hydraulically fractured at least once and hydraulically re-fracturing the second location.
- the method comprises providing a second diverting material proximate to the second location after the second location has been re-fractured, wherein the second diverting material hydraulically isolates the re-fractured second location from a portion of the multizone horizontal wellbore uphole of the second location.
- the first location may be a fracture cluster farther downhole of the multizone horizontal wellbore and wherein hydraulically isolating the first location may include creating a seal with a packing element connected to a coiled tubing string to seal an annulus between the coiled tubing string and a casing of the multizone horizontal wellbore uphole of the first location.
- the method may include cleaning out at least a portion of the multizone horizontal wellbore prior to hydraulically isolating the first location.
- the method may include cleaning out at least a portion of the multizone horizontal wellbore after re-fracturing the first and second locations to remove the first and second diverting materials from the multizone horizontal wellbore.
- the method may include producing hydrocarbons from the re-fractured first and second locations of the multizone horizontal wellbore.
- the first and second diverting material may comprises one or more of a thermoset plastic, a thermoset polymer, a sand plug, disintegrating frac balls, a gel, a cross-linked gel, frac balls, dissolving material, fiber laden diversion fluid, particulates, or a bridge of degradable particles.
- the method may include determining whether to hydraulically re-fracture the first location prior to hydraulically re-fracturing the first location and determining whether to hydraulically re-fracture the second location prior to hydraulically re-fracturing the second location.
- the method may include logging the first and second locations with a logging tool.
- Hydraulically isolation the second location may include providing a third diverting material between the first and second locations and creating a seal with a packing element connected to a coiled tubing string to seal an annulus between the coiled tubing string and a casing of the multizone horizontal wellbore uphole from the second location, wherein the third diverting material is provided prior to creating the seal uphole from the second location.
- One embodiment is a system for re-fracturing a plurality of locations within a multizone horizontal wellbore comprising a first tubing string positioned within a multizone horizontal wellbore, the first tubing string extending from a surface location to a first location in the multizone horizontal wellbore.
- the first location being a lowermost previously fractured location along the multizone horizontal wellbore.
- the system comprises a packing element connected proximate to an end of the first tubing string, the packing element adapted to repeatedly seal an annulus between the first tubing string and a casing of the multizone horizontal wellbore, the end of the first tubing string being adapted to permit the hydraulic re- fracturing of selected locations within the multizone horizontal wellbore.
- the system comprises a plurality of diverting material, each of the plurality of diverting material positioned proximate to a previously fractured location to selectively hydraulically isolate the previously fractured location.
- the first tubing string may be a coiled tubing string.
- the first tubing string may be comprised of a section of rigid tubing connected to a lower end of a coiled tubing string.
- the system may include a testing device connected to a second tubing string, the testing device adapted to determine whether a previously fractured location should be re-fractured, wherein the second tubing string is positioned within the multizone horizontal wellbore prior to the first tubing string being positioned within the multizone horizontal wellbore.
- the testing device may be a logging device.
- One method is a method for selectively re-fracturing one or more previously fractured locations within a wellbore comprising positioning a packing element uphole of a first previously fractured location, the packing element being connected to a tubing string and actuating the packing element to seal an annulus between the tubing string and a casing uphole of the first previously fractured location.
- the method comprises pumping fluid down the tubing string to re-fracture the first previously fractured location and providing a first diverting material proximate the re-fractured first previously fractured location.
- the method comprises unsetting the packing element and positioning the packing element uphole of a second previously fractured location.
- the method comprises actuating the packing element to seal the annulus between the tubing string and the casing uphole of the second previously fractured location and pumping fluid down the tubing string to re-fracture the second previously fractured location.
- the method comprises providing a second diverting material proximate the re-fractured second previously fractured location.
- the method may include positioning a testing device proximate to the first previously fractured location and determining that the first previously fractured location should be re- fractured prior to re-fracturing the first previously fractured location and positioning the testing device proximate to the second previously fractured location and determining that the second previously fractured location should be re-fractured prior to re-fracturing the second previously fractured location.
- the method may include removing the first and second diverting materials and producing hydrocarbons from the re-fractured first and second previously fractured locations.
- the method may include determining a third previously fractured location should not be re-fractured prior to positioning the packing element uphole of the second previously fractured location, wherein the third previously fractured location is positioned between the first previously fractured location and the second previously fractured location.
- the method may include providing a third diverting material proximate the third previously fractured location prior to positioning the packing element uphole of the second previously fractured location.
- FIG. 1 shows a tubing string positioned in a portion of a multizone horizontal wellbore that includes a plurality of locations that previously have been hydraulically fractured;
- FIG. 2 shows a tubing string providing a cleanout procedure on a portion of a multizone horizontal wellbore that includes a plurality of locations that previously have been hydraulically fractured;
- FIG. 3 shows an actuated packer on a tubing string creating a seal above the lowermost location of a multizone horizontal wellbore that has previously been hydraulically fractured
- FIG. 4 shows re-fracturing the lowermost fracture location of a multizone horizontal wellbore
- FIG. 5 shows the placement of a diverting material to hydraulically isolate the lowermost location after it has been re-fractured
- FIG. 6 shows an actuated packer on a tubing string creating a seal above a location that has previously been hydraulically fractured
- FIG. 7 shows re-fracturing a location of a multizone horizontal wellbore
- FIG. 8 shows the placement of a diverting material to hydraulically isolate a location that has been re-fractured as shown in FIG. 7;
- FIG. 9 shows a portion of a multizone horizontal wellbore that has been re-fractured with the tubing string removed, the diverting material has been removed from the multizone horizontal wellbore permitting the production of hydrocarbons from the re-fractured locations within the horizontal wellbore;
- FIG. 10 shows a tubing string comprised of coiled tubing and rigid tubing positioned within a portion of a multizone horizontal wellbore with diverting material hydraulically isolating a location that is not to be re-fractured;
- FIG. 11 shows re-fracturing a location of a multizone horizontal wellbore.
- FIG. 1 shows a schematic of a multizone horizontal wellbore 1 within a well formation 5.
- the horizontal wellbore 1 includes a plurality of zones A, B, and C that each may contain a plurality of locations 10a, 10b, 10c, 20a, 20b, 20c, 30a, 30b, and 30c that have been previously fractured.
- the locations 10a, 10b, 10c, 20a, 20b, 20c, 30a, 30b, and 30c may be prior fractures, fracture clusters, or perforations within a casing.
- each location may include one or more fracture clusters that have been previously fractured or were attempted to be previously fractured.
- the location may also be a fracture port in a ported completion that has been left open after a prior fracturing operation in an attempt to fracture the formation behind the fracture port.
- the system and method disclosed herein may be used to re-fracture the formation 5 through the ported completion disclosed in U.S. patent application no.
- FIG. 1 shows three zones or segments of the multizone horizontal wellbore 1.
- FIG. 1 shows three previously fractured locations per zone or segment, for illustrative purposes only.
- a multizone horizontal wellbore 1 may include a various number of zones or segments such as A, B, and C that have been previously fractured, as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.
- the number of previously fractured locations within each zone or segment may vary.
- the previously hydraulically fractured locations may comprise a perforation through casing that was attempted to be fractured, a fracture or fracture cluster in the formation, or a fracture port in a completion.
- a previously fractured location includes any location within a wellbore that has been previously subjected to a fracturing treatment, in an attempt to fracture the formation at that location, whether or not the formation actually fractured.
- the previously fractured locations will be referred to as a fracture cluster, but such locations should not be limited to those previously fractured locations that resulted in a fracture cluster and may include any of the above noted, or other fracture locations.
- a production zone may have as few as a single fracture cluster or may include more than ten (10) fracture clusters.
- the multiple zones of a multizone horizontal wellbore 1 may include a plurality of fracture clusters 10, 20, and 30 that extend into the formation 5 that surrounds the casing 6 of the multizone horizontal wellbore 1.
- the formation 5 is fractured by a plurality of fracture clusters 10, 20, and 30 to increase the production of hydrocarbons from the wellbore.
- the rate of production from the horizontal wellbore decreases below a minimum threshold value it may be necessary to re-fracture selected fracture clusters 10, 20, and 30 within the wellbore 1, as discussed below.
- a tubing string 7 may be positioned within the casing 6 of the horizontal wellbore 1. Fluid may be pumped down the tubing string 7 and out the end 9 of the tubing string and reverse circulated up the annulus to clean out the horizontal wellbore 1 prior to the re-fracturing process as shown in FIG. 2.
- the tubing string 7 may include a testing device 50 that may be used to determine whether a fracture cluster, such as 10a, 10b, 10c, 20a, 20b, 20c, 30a, 30b, or 30c, should be re-fractured.
- the testing may be a logging device.
- the testing device 50 may indicate that a fracture cluster should be skipped in the re-fracturing process.
- the testing device 50 may determine various parameters that may be helpful to determine whether a location should be re-fractured such as casing integrity, wellbore characterization, formation evaluation, and/or production analysis.
- a tubing string 7 may be positioned within the casing 6 of the horizontal wellbore 1 having a packer or sealing element 8, hereinafter referred to as a packer.
- the packer 8 may be actuated to create a seal in the annulus between the tubing string 7 and the casing.
- the tubing string 7 may be comprised of various tubulars that permit locating and operating a packer or sealing element, as discussed below, within the horizontal wellbore 1 and also permit the pumping of fluid down the tubing string 7 to a desired location along the horizontal wellbore 1.
- the tubing string 7 may be coiled tubing that extends from the surface to the location of the fracture cluster 10a positioned farthest downhole of the horizontal wellbore 1.
- a tubing string 7 comprised of a rigid tubular section 70 connected to coiled tubing 75, as shown schematically in FIG. 10. It may be preferred use only a relative short length of rigid tubing 70 in comparison to the overall length of the tubing string 7 due to the greater weight of rigid tubing 70 in comparison to coiled tubing 75.
- the packer 8 may be positioned uphole of the lowermost fracture cluster 10a and actuated to create a seal between the tubing string 7 and the casing 6 of the horizontal wellbore 6.
- FIG. 3 shows the packer 8 actuated to hydraulically isolate the lowermost fracture cluster 10a from the portion of the horizontal wellbore 1 located above the actuated packer 8.
- Various packers and/or sealing elements may be used to in connection with the tubing string 7 to hydraulically isolate the fracture cluster 10a as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.
- the packer 8 includes a sealing element may be repeatedly actuated and/or energized to create a seal between the tubing string 7 and the wellbore casing 6. Debris within the annulus may potentially interfere with the repeated actuation of the packer 8.
- the packer 8 may include a debris exclusion device, such as one or more cups, positioned downhole from the packing element, which may help to prevent debris and/or material within the wellbore from interfering with the creation of a seal by the sealing element of the packer 8.
- a debris exclusion device such as one or more cups
- FIG. 4 shows that fluid is pumped down the tubing string 7 and out the end 9 of the tubing string 7 to hydraulically re-fracture cluster 110a, which was previously fractured fracture cluster 10a (shown in FIG. 1-3).
- a diverting material 40 may be placed within the horizontal wellbore 1 proximate to the re-fractured cluster 110a as shown in FIG. 5. The diverting material 40 hydraulically isolates the re-fractured cluster 110a from subsequent re-fracturing procedures within the horizontal wellbore 1.
- the diverting material 40 may be various materials that may be positioned within the wellbore 1 using the tubing string 7 that hydraulically isolates a fracture cluster from the portion of the wellbore 1 uphole from the diverting material 40.
- the diverting material 40 may be, but is not limited to, thermoset plastics, thermoset polymers, sand plugs, disintegrating frac balls such as this offered for sale by Baker Hughes under the trademark IN-TALLICTM, gels, cross-linked gels, frac balls, dissolving material, fiber laden diversion fluid, particulates, and/or a bridge of degradable particles as would be recognized by one of ordinary skill in the art having the benefit of this disclosure.
- the diverting material 40 is pumped down the tubing string 7 and positioned proximate to the re- fractured cluster 1 10a to hydraulically isolate the re-fractured cluster 110a during the re- fracturing process of an additional fracture cluster within the horizontal wellbore 1.
- the tubing string 7 may be moved uphole to position the packer 8 above the next fracture cluster 10b that is to be re-fractured.
- the adjacent fracture cluster may not be the next fracture cluster to be re-fractured. Instead, a fracture cluster or multiple fracture clusters may be passed over during the re-fracturing process. Diverting material may be pumped down the tubing string 7 to isolate a passed over fracture cluster during the re-fracturing of the next fracture cluster.
- FIG. 6 shows the packer 8 actuated to hydraulically isolate the fracture cluster 10b from the uphole portion of the horizontal wellbore 1.
- the diverting material 40 positioned adjacent the lower re-fractured cluster 110a in combination with the actuated packer 8 hydraulically isolates fracture cluster 10b from the rest of the horizontal wellbore 1. Once the fracture cluster 10b is isolated, fluid may be pumped down the tubing string 7 to re-fracture the cluster 110b as shown in FIG. 7. Diverting material 40 may be positioned adjacent the re- fractured cluster 110b after the re-fracturing process has been completed to hydraulically isolate the re-fracture cluster 110b from the uphole portion of the horizontal wellbore 1, as shown in FIG. 8.
- Hydraulically isolating the re-fractured cluster 110b permits the re-fracturing of another fracture cluster uphole from the re-fractured cluster 110b.
- This process of using a packer and diverting material may be repeated to re-fracture all desired fracture clusters, as would be recognized by one of ordinary skill in the art having the benefit of this disclosure.
- the diverting material 40 placed within the horizontal wellbore 1 to hydraulically isolate sections of the horizontal wellbore needs to be removed once it is desired to produce from the hydraulically isolated clusters and/or once all of the desired fracture clusters have been re- fractured.
- FIG. 9 shows a horizontal wellbore 1 from which all of the diverting material 40 adjacent re-fractured clusters 110a and 110b has been removed permitting production of hydrocarbons from re-fractured clusters 110a and 110b.
- the diverting material 40 may be removed by various means as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.
- the diverting material may be removed by performing a clean-out procedure in the horizontal wellbore 1.
- the diverting material may be adapted to dissolve over a predetermined amount of time or dissolve upon the injection of a particular chemical into the horizontal wellbore.
- FIG. 10 schematically shows a tubing string 7 that is comprised of a coiled tubing 75 connected to a rigid tubular section 70. Due to the length of the horizontal wellbore, it may not be practical to for the entire string 7 to be comprised of rigid tubulars 70, which is heavier than coiled tubing 75. Instead, a short section, in comparison to the length of the horizontal wellbore 1, of rigid tubing 70 may be connected to another type of tubing string, such as coiled tubing 75.
- a tubing string 7 may include a testing device 50 may have already been used to determine whether a fracture cluster, such as 10a, 10b, 10c, 20a, 20b, 20c, 30a, 30b, or 30c, should be re-fractured.
- the testing may be a logging device.
- the testing device 50 may indicate that a fracture cluster should be skipped in the re-fracturing process.
- FIG. 10 shows that fracture cluster 10b was not re-fractured, but instead fracture cluster 10c was re-fractured as re-fractured cluster 110c. Diverting material 40 is positioned proximate to fracture cluster 10b to isolate fracture cluster 10b during the re-fracturing of fracture cluster 110c.
- the packer 8 Prior to pumping fluid down the tubing string 7, the packer 8 is energized above fracture cluster 10c.
- the actuated packer 8 in combination with the diverting material 40 adjacent to fracture cluster 10b isolates fracture cluster 10c during the re-fracturing process so that the fluid re-fractures cluster 110c and is not leaked off into fracture cluster 10b.
- Diverting material 40 may be used to isolation multiple fracture clusters that have been determined non-beneficial to re-fracture as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.
- FIG. 11 shows the re-fracturing of a wellbore location 200b, which includes two fracture clusters 310b and 310c that have been previously fractured.
- location 200a Prior to re-fracturing location 200b, location 200a, which includes fracture cluster 310a, has been re-fractured.
- Diverting material 40 has been placed within the wellbore 1 to isolate location 200a during the re-fracturing of location 200b. After re-fracturing location 200b, diverting material may be positioned above location 200b and the packer 8 may be located above location 200c to permit the re-fracturing of location 200c.
- Location 200c may include a plurality of fracture clusters such as 220a, 220b, and 220c, as shown in FIG. 11. After re-fracturing location 200c, the location 200c may be hydraulically isolated and the packer 8 may be positioned above the next location 200d that is to be re-fractured.
- the next location 200d may include a single fracture cluster or a plurality of fracture clusters 230a, 230b, and 230c, as shown in FIG. 11.
- a location such as location 200c
- a - section of horizontal wellbore containing multiple fracture clusters B - section of horizontal wellbore containing multiple fracture clusters
- C - section of horizontal wellbore containing multiple fracture clusters 1 - multizone horizontal wellbore
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- Engineering & Computer Science (AREA)
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- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Excavating Of Shafts Or Tunnels (AREA)
- Earth Drilling (AREA)
- Physical Or Chemical Processes And Apparatus (AREA)
- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
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Priority Applications (8)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
AU2014355043A AU2014355043A1 (en) | 2013-11-27 | 2014-11-13 | System and method for re-fracturing multizone horizontal wellbores |
MX2016006715A MX2016006715A (es) | 2013-11-27 | 2014-11-13 | Sistema y metodo para re-fracturar perforaciones de pozo horizontales de multizonas. |
NZ719851A NZ719851A (en) | 2013-11-27 | 2014-11-13 | System and method for re-fracturing multizone horizontal wellbores |
BR112016010923-6A BR112016010923B1 (pt) | 2013-11-27 | 2014-11-13 | Método para refraturar poços horizontais de múltiplas zonas |
CA2931186A CA2931186C (en) | 2013-11-27 | 2014-11-13 | System and method for re-fracturing multizone horizontal wellbores |
EP14866378.4A EP3074592B1 (en) | 2013-11-27 | 2014-11-13 | Method for re-fracturing multizone horizontal wellbores |
CN201480064834.7A CN105765162B (zh) | 2013-11-27 | 2014-11-13 | 用于再压裂多区段水平井筒的系统和方法 |
RU2016125305A RU2663844C2 (ru) | 2013-11-27 | 2014-11-13 | Система и способ проведения повторного гидравлического разрыва пласта в многозонных горизонтальных скважинах |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
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US14/091,677 | 2013-11-27 | ||
US14/091,677 US9366124B2 (en) | 2013-11-27 | 2013-11-27 | System and method for re-fracturing multizone horizontal wellbores |
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WO2015080872A1 true WO2015080872A1 (en) | 2015-06-04 |
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Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
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WO2017217966A1 (en) * | 2016-06-13 | 2017-12-21 | Halliburton Energy Services, Inc. | Treatment isolation in restimulations with inner wellbore casing |
WO2020210303A1 (en) * | 2019-04-08 | 2020-10-15 | Saudi Arabian Oil Company | Fracturing rock formations |
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EP3074592A4 (en) | 2017-08-23 |
NZ719851A (en) | 2020-07-31 |
BR112016010923B1 (pt) | 2022-05-10 |
RU2016125305A (ru) | 2018-01-09 |
EP3074592A1 (en) | 2016-10-05 |
RU2663844C2 (ru) | 2018-08-10 |
RU2016125305A3 (US07223432-20070529-C00017.png) | 2018-06-05 |
US20150144347A1 (en) | 2015-05-28 |
CN105765162A (zh) | 2016-07-13 |
AU2014355043A1 (en) | 2016-05-26 |
US9366124B2 (en) | 2016-06-14 |
CA2931186C (en) | 2018-12-04 |
CN105765162B (zh) | 2019-11-19 |
MX2016006715A (es) | 2016-08-17 |
BR112016010923A2 (US07223432-20070529-C00017.png) | 2017-08-08 |
AR098562A1 (es) | 2016-06-01 |
CA2931186A1 (en) | 2015-06-04 |
EP3074592B1 (en) | 2023-01-11 |
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