WO2016099454A1 - Debris control systems, apparatus, and methods - Google Patents
Debris control systems, apparatus, and methods Download PDFInfo
- Publication number
- WO2016099454A1 WO2016099454A1 PCT/US2014/070544 US2014070544W WO2016099454A1 WO 2016099454 A1 WO2016099454 A1 WO 2016099454A1 US 2014070544 W US2014070544 W US 2014070544W WO 2016099454 A1 WO2016099454 A1 WO 2016099454A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- ported sub
- wellbore
- depth
- fluid
- casing
- Prior art date
Links
- 238000000034 method Methods 0.000 title claims abstract description 24
- 239000012530 fluid Substances 0.000 claims abstract description 48
- 238000002347 injection Methods 0.000 claims abstract description 10
- 239000007924 injection Substances 0.000 claims abstract description 10
- 238000012360 testing method Methods 0.000 claims abstract description 9
- 230000015572 biosynthetic process Effects 0.000 claims description 36
- 238000004891 communication Methods 0.000 claims description 16
- 238000011282 treatment Methods 0.000 claims description 10
- 238000005086 pumping Methods 0.000 claims description 7
- 238000007789 sealing Methods 0.000 claims description 7
- 239000002904 solvent Substances 0.000 claims description 7
- 230000008901 benefit Effects 0.000 description 8
- 239000004568 cement Substances 0.000 description 8
- 230000000694 effects Effects 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- 239000002253 acid Substances 0.000 description 2
- 230000003466 anti-cipated effect Effects 0.000 description 2
- 238000004140 cleaning Methods 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000005553 drilling Methods 0.000 description 2
- 230000002706 hydrostatic effect Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 239000003849 aromatic solvent Substances 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 239000004020 conductor Substances 0.000 description 1
- 238000011109 contamination Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 239000003599 detergent Substances 0.000 description 1
- 239000006260 foam Substances 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 238000005304 joining Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 239000003921 oil Substances 0.000 description 1
- 150000007524 organic acids Chemical class 0.000 description 1
- 235000005985 organic acids Nutrition 0.000 description 1
- 238000012856 packing Methods 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 239000000344 soap Substances 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/063—Valve or closure with destructible element, e.g. frangible disc
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/10—Well swabs
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/008—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/06—Sleeve valves
Definitions
- DFITs Diagnostic fracture injection tests
- fluid is pumped horizontally through the toe or vertically through perforations of the wellbore.
- the pressure at the wellhead is then monitored for an extended period of time.
- Cementing residue, pipe dope, or other debris can obstruct the flow path from the wellbore to the formation, making pressure data uninterpretable, unreliable, or otherwise causing the DFIT to fail.
- the debris in the wellbore may further interfere with hydraulic fracturing treatments. The accumulated debris can be difficult, if not impossible, to remove without costly intervention.
- Figure 1 depicts an example debris control system, in accordance with some embodiments.
- Figure 2 depicts another example of the debris control system of Figure 1 , in accordance with some embodiments.
- Figure 3 depicts yet another example of the debris control system of Figure 1 , in accordance with some embodiments.
- Figure 4 depicts yet another example of the debris control system of Figure 1 , in accordance with some embodiments.
- FIG. 5 is a flow diagram of an example method of debris control, in accordance with some embodiments.
- Figure 6 depicts an example completion system, in accordance with some embodiments. Detailed Description
- Figures 1-5 illustrate example methods, apparatus, and systems for debris control during well construction, and other operations, using a first ported sub and a second ported sub attached to a casing, so that when the casing is inserted into a wellbore, the first ported sub is positioned deeper in the wellbore than the second ported sub.
- the first ported sub is actuated to provide fluid communication between the wellbore and a formation, such that a fluid can be pumped through the first ported sub to move debris out of the wellbore and into the formation.
- the wellbore is then sealed and the second ported sub is actuated to allow fluid communication between the wellbore and the formation, such that a diagnostic fracture injection test (DFIT) or a hydraulic fracturing treatment may be performed without interference from the debris that has passed through the first ported sub.
- DFIT diagnostic fracture injection test
- a hydraulic fracturing treatment may be performed without interference from the debris that has passed through the first ported sub.
- FIG. 1 depicts an example debris control system 100, in accordance with some embodiments.
- the debris control system 100 generally comprises a first ported sub 102 and a second ported sub 104 attached to a casing 106 for use in a wellbore 108.
- the debris control system 100 further comprises a first landing collar 110 and a second landing collar 112 attached to the casing 106.
- a guide shoe 114 is attached to an end of the casing 106 to guide the casing 106 into the wellbore 108.
- a float collar 1 16 is attached to the casing 106.
- the debris control system 100 is installed on the casing 106 so that when the casing 106 is run into the wellbore 108, the guide shoe 114 is deeper than the float collar 1 16, which is, in turn, deeper than the first landing collar 1 10.
- the landing collar 1 10 is deeper than the first ported sub 102, which is, in turn, deeper than the second landing collar 112.
- the second landing collar 112 is, in turn, deeper than the second ported sub 104.
- depth is relative to the casing 106 once inserted into the wellbore 108. That is, an element A having a “deeper” depth than element B indicates that element A has a position on the casing 106 that would be further into the wellbore 108 than element B, once the casing 106 is inserted into the wellbore 108.
- the second landing collar 112 comprises an inner diameter that is greater than an inner diameter of the first landing collar 110, such that a wiper dart 120 inserted into the casing 106 passes through the inner diameter of the second landing collar 1 12, and lands in the first landing collar 1 10, substantially sealing the casing 106 at the first landing collar 1 10 against the incursion of fluid.
- At least one of the first ported sub 102 and the second ported sub 104 comprises a sliding sleeve. Further, in some embodiments, at least one of the first ported sub 102 and the second ported sub 104 comprises a hydraulically activated sliding sleeve. In some embodiments, at least one of the first ported sub 102 and the second ported sub 104 can be actuated to facilitate fluid communication between the wellbore 108 and a formation 1 18. In some embodiments, at least one of the first ported sub 102 and the second ported sub 104 establishes the fluid communication between the wellbore 108 and the formation 1 18 independently, without intervention of a perforating gun or some other ancillary mechanism. In some embodiments, at least one of the first ported sub 102 and the second ported sub 104 only requires the imposition of absolute casing pressure (applied pressure and hydrostatic pressure) to be actuated.
- At least one of the first ported sub 102 and the second ported sub 104 comprises a variable-sized inner mandrel to create a piston area and atmospheric chamber inside a ported housing.
- the piston area and atmospheric chamber generate a hydraulic force on the inner sleeve as the inner diameter of the ported sub (102, 104) is exposed to pressure (both hydrostatic and applied).
- the inner mandrel is fastened in place by shear fasteners, for example, shear pins, shear screws, or the like.
- the number of shear fasteners can be manipulated to achieve different pressure requirements for actuation.
- the shear fasteners are sheared and the inner mandrel is allowed to move, exposing the ports of the ported sub (102, 104) and facilitating fluid communication between the wellbore 108 and the formation 1 18.
- both the first ported sub 102 and the second ported sub 104 are in a closed position, such that the ports of the ported subs 102, 104 do not facilitate fluid communication between the wellbore 108 and the formation 1 18.
- FIG. 2 depicts another example of the debris control system 100 of Figure 1 , in accordance with some embodiments.
- the wiper dart 120 has passed through the wellbore 108 and the inner diameter of the second landing collar 1 12 to control the amount of debris in the wellbore 108, and landed in the first landing collar 1 10 to seal the wellbore 108.
- the first ported sub 102 has been actuated such that it is in an open position to facilitate fluid communication between the wellbore 108 and the formation 1 18.
- hydraulic pressure is used to open the first ported sub 102.
- a fluid is pumped through the wellbore 108 to move debris from the wellbore 108 to the formation 1 18, via the first ported sub 102.
- the debris may comprise, for example, cementing residue, pipe dope, solids, or the like.
- the fluid comprises primarily water.
- the fluid comprises a solvent cleaning fluid, for example, a solvent acid, acids, organic acids, aromatic solvents, paraffinic solvents, soaps, detergents, a combination of these, or the like.
- the fluid is chosen to treat specific anticipated pipe debris.
- the second ported sub 104 has not been actuated and remains in a closed position, such that the second ported sub 104 does not facilitate fluid communication between the wellbore 108 and the formation 1 18. That is, the actuation of the first ported sub 102 does not result in actuation of the second ported sub 104.
- the second ported sub 104 is actuated by application of a greater pressure than is required to actuate the first ported sub 102.
- both the first ported sub 102 and the second ported sub 104 comprise hydraulically actuated sliding sleeves with shear fasteners, and the shear fasteners on the second ported sub 104 comprise greater shear strength than those on the first ported sub 102.
- the illustrated embodiment further depicts a wiper plug 202 passing through the casing 106 of the wellbore 108.
- the wiper plug 202 is dimensioned to land and latch into the second landing collar 1 12 to seal the wellbore 108 at a lesser depth than the depth of the first ported sub 102.
- the debris control system 100 does not include the second landing collar 1 12, and instead the wiper plug 202 is dimensioned to land and latch into the first ported sub 102 to seal the wellbore 108.
- the debris control system 100 does not use the wiper plug 202.
- the first ported sub 102 is plugged, for example, by debris, sealing the wellbore 108 from the formation 1 18 where the debris has been disposed.
- FIG 3 depicts yet another example of the debris control system 100 of Figure 1 , in accordance with some embodiments.
- the wiper plug 202 has landed and latched into the second landing collar 1 12, to seal the wellbore 108 from the formation 1 18.
- the sealed wellbore creates a "disposal zone" of sorts, such that debris is trapped between the wiper plug 202, the wiper dart 120 and the formation 1 18.
- the wellbore 108 is sealed from the formation 1 18 by debris plugging the first ported sub 102.
- the second ported sub 104 has been actuated, such that the second ported sub 104 facilitates fluid communication between the wellbore 108 and the formation 1 18.
- hydraulic pressure is used to open the second ported sub 104.
- the second ported sub 104 may be used for at least one of: a DFIT or a hydraulic fracturing treatment without interference from the debris that has passed through the first ported sub 102, or is otherwise trapped below the wiper plug 202.
- FIG 4 depicts yet another example of the debris control system 100 of Figure 1 , in accordance with some embodiments.
- the debris control system 100 does not include the second landing collar 1 12 of the wiper plug 202.
- the first ported sub 102 is actuated in accordance with Figure 2 to facilitate fluid communication between the wellbore 108 and the formation 1 18 to pass debris to the formation 1 18. Debris eventually plugs the first ported sub 102 to seal the wellbore 108 from the debris that has passed through the first ported sub 102 to the formation 1 18.
- the second ported sub 104 is then actuated to facilitate fluid communication between the formation 1 18 and the wellbore.
- the second ported sub 104 is in the open position to facilitate a DFIT or a hydraulic fracturing treatment without interference from the debris that was passed to the formation 1 18 via the first ported sub 102.
- FIG. 5 is a flow diagram of an example method 500 of debris control, in accordance with some embodiments.
- the method 500 is described with reference to the debris control system 100 of Figures 1-4.
- a plurality of tools comprising components of the debris control system 100 are installed on the casing 106.
- the debris control system 100 is installed at the toe of the casing 106.
- the first ported sub 102 is disposed at a first depth that is deeper than a depth at which the second ported sub 104 is disposed.
- the first landing collar 1 10 is disposed at a depth that is deeper than a depth at which the first ported sub 102 is disposed.
- the second landing collar 1 12 is disposed between the first ported sub 102 and the second ported sub 104.
- one or more well completion operations are performed.
- the casing 106 is run into the wellbore 108.
- the completion operations comprise pumping cement down the casing 106 to the guide shoe 1 14, where it continues to flow up the annulus between the casing 106 and the wellbore 108, isolating the wellbore from the formation 1 18.
- the wiper dart 120 is landed in the first landing collar 1 10 to prevent u- tubing of cement (e.g., the return of cement into the wellbore) during the completion operations.
- the second landing collar 1 12 has an inner diameter that is greater than an inner diameter of the first landing collar 1 10, such that the wiper dart 120 passes through the second landing collar 1 12 to seat in the first landing collar 1 10 and seal the wellbore 108.
- the first ported sub 102 is actuated, enabling fluid communication between the wellbore 108 and the formation 1 18 via ports on the first ported sub 102.
- hydraulic pressure is used to actuate the first ported sub 102.
- pressure is applied to shear one or more shear fasteners of the first ported sub 102 to actuate the first ported sub 102.
- the second ported sub 104 has not been actuated and remains in a closed position at this point, such that the second ported sub 104 does not facilitate fluid communication between the wellbore 108 and the formation 1 18. That is, the actuation of the first ported sub 102 does not result in actuation of the second ported sub 104.
- the second ported sub 104 is actuated by application of a greater pressure than is required to actuate the first ported sub 102.
- both the first ported sub 102 and the second ported sub 104 comprise hydraulically actuated sliding sleeves with shear fasteners, and the fasteners on the second ported sub 104 comprise greater shear strength than the fasteners on the first ported sub 102.
- fluid is pumped through the wellbore 108 to pass debris from the wellbore 108 and provide a cleaned wellbore 108.
- the fluid passes the debris from the wellbore 108 to the formation 1 18 via the first ported sub 102.
- the debris may comprise, for example, cementing residue, pipe dope, solids, or the like.
- the fluid comprises primarily water.
- the fluid comprises a solvent.
- the fluid comprises a solvent cleaning fluid.
- the fluid is chosen to treat specific anticipated pipe debris.
- it is determined whether the first ported sub 102 is plugged by debris. For example, in at least one embodiment, this determination is made by increasing excessive pressure, based on an inability to maintain injection rate, or a combination of these.
- the method proceeds to block 512, whereby a wiper plug 202 is landed and latched into the second landing collar 1 12.
- the wiper plug 202 seals the wellbore 108 between the first ported sub 102 and the second ported sub 104, so as to separate the cleaned wellbore from the debris that has been passed through the first ported sub 102 to the formation 1 18.
- the wiper plug 202 is landed and latched into the first ported sub 102, such that the wellbore 106 is sealed by the wiper plug 202 at the first ported sub 102.
- the method 500 proceeds to block 514, whereby the second ported sub 104 is actuated, enabling fluid communication between the wellbore 108 and the formation 1 18 via ports on the second ported sub 104.
- hydraulic pressure is used to actuate the second ported sub 104.
- pressure is applied to shear one or more shear fasteners of the second ported sub 104 to actuate the second ported sub 104.
- a diagnostic fracture injection test or a hydraulic fracturing treatment is performed using the second ported sub 104.
- a second fluid is pumped through the second ported sub 104.
- the fluid comprises non-damaging treated water, a compatible field brine, oil, gas, foam, a combination of these, or the like.
- data is collected, and a DFIT analysis is performed on the data.
- the DFIT comprises a small volume, cost- effective, short duration and low-rate injection test followed by an extended shut-in period.
- the DFIT comprises breaking down the formation 1 18 and estimating fracture pressure, closure pressure, pore pressure, and permeability.
- the DFIT is performed in an effort to optimize a hydraulic fracturing treatment.
- the debris control system 100 allows the DFIT or hydraulic fracturing treatment to be performed/applied using the second ported sub 104 without interference from the debris that has passed through the first ported sub 102 to the formation 1 18, or that is otherwise separated by the wiper plug 202. Without the debris control system 100, cementing residue, pipe dope, or other debris might obstruct the flow path from the wellbore to the formation, making collected data uninterpretable, unreliable, or otherwise causing the DFIT to fail. The debris in the wellbore would further interfere with hydraulic fracturing treatments. Without the debris control system 100, accumulated debris requires costly intervention to remove.
- Figure 6 depicts a well completion system 600, in accordance with some embodiments.
- Well completion occurs after the wellbore 602 has been drilled, but before the well 604 can be put into production.
- Well completion can include many operations, such as casing, cementing, perforating, gravel packing, production tree installation, DFIT, hydraulic fracturing, among others.
- Casing operations help ensure that the wellbore 602 will not collapse when drilling fluids are removed from the wellbore 602 and protect the drilling fluids from contamination by other materials of the wellbore 602.
- the casing operations generally comprise joining sections of tube (or joints), for example steel or other metal, to form a casing 606.
- the casing 606 is then run into the wellbore 602.
- Different diameters of casing 606 may be used at different locations within the wellbore 602.
- a casing program may include production casing, intermediate casing, surface casing, conductor casing, or the like, each comprising a different diameter tube for the casing 606.
- An accurate casing program is essential to ensuring that the well can flow properly given the wellbore conditions.
- the well completion system 600 further comprises the debris control system 100 of Figures 1-3 installed at the toe of the casing 606.
- the guide shoe 1 14 guides the first joint of the casing 606 into the wellbore 602. After the debris control system 100 and any other tools have been installed on the casing 606, the casing 606 is run to depth into the wellbore 602 and cementing operations begin. Cement is pumped down the casing 606 to the guide shoe 1 14, where it continues to flow up the annulus between the casing 606 and the wellbore 602, isolating the wellbore from the formation.
- the space between the guide shoe 1 14 and the float collar 1 16 define a shoe track 612.
- the purpose of the shoe track 612 is to avoid over-displacing cement during cementing operations.
- the float collar 1 16 e.g., an auto-fill float collar
- the shoe track 612 may comprise a single section of the casing 606 or multiple joints of the casing 606.
- one or more centralizers 614, 615 keep the casing 606 off the wall of the wellbore 602 to ensure proper cementing operations.
- Some applications may further utilize scratchers to remove wall cake and ensure that the cement bonds to the wall of the wellbore 602.
- the well completion system 600 comprises an open-hole completion.
- the wiper dart 120 is used during the initial cementing operation, to pass through the inner diameter of the second landing collar 1 12, and landing at the first landing collar 1 10.
- the wiper dart 120 activates the first landing collar 1 10 and prevents cement slurry from flowing back into the wellbore 602 (e.g., u-tubing) by sealing the wellbore 602 at the first landing collar 1 10.
- the debris control system 100 may then be used to clean the wellbore 602 and to facilitate performing DFITs or hydraulic fracturing treatments.
Abstract
Description
Claims
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
AU2014414065A AU2014414065B2 (en) | 2014-12-16 | 2014-12-16 | Debris control systems, apparatus, and methods |
PCT/US2014/070544 WO2016099454A1 (en) | 2014-12-16 | 2014-12-16 | Debris control systems, apparatus, and methods |
US15/516,843 US20170247981A1 (en) | 2014-12-16 | 2014-12-16 | Debris control systems, apparatus, and methods |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US2014/070544 WO2016099454A1 (en) | 2014-12-16 | 2014-12-16 | Debris control systems, apparatus, and methods |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2016099454A1 true WO2016099454A1 (en) | 2016-06-23 |
Family
ID=56127112
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2014/070544 WO2016099454A1 (en) | 2014-12-16 | 2014-12-16 | Debris control systems, apparatus, and methods |
Country Status (3)
Country | Link |
---|---|
US (1) | US20170247981A1 (en) |
AU (1) | AU2014414065B2 (en) |
WO (1) | WO2016099454A1 (en) |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US11359461B2 (en) | 2019-12-06 | 2022-06-14 | Baker Hughes Oilfield Operations Llc | Wellbore system for interventionaless cleanout |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4436155A (en) * | 1982-06-01 | 1984-03-13 | Geo Vann, Inc. | Well cleanup and completion apparatus |
US5669445A (en) * | 1996-05-20 | 1997-09-23 | Halliburton Energy Services, Inc. | Well gravel pack formation method |
US20080060815A1 (en) * | 2002-02-13 | 2008-03-13 | Howlett Paul D | Wellhead seal unit |
US20100218941A1 (en) * | 2009-02-27 | 2010-09-02 | Muthukumarappan Ramurthy | Determining the Use of Stimulation Treatments Based on High Process Zone Stress |
US20110253376A1 (en) * | 2010-04-15 | 2011-10-20 | Mark Wayne Krpec | Tool for removing debris from a wellbore |
Family Cites Families (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8146416B2 (en) * | 2009-02-13 | 2012-04-03 | Schlumberger Technology Corporation | Methods and apparatus to perform stress testing of geological formations |
CA2870984C (en) * | 2012-04-27 | 2017-02-21 | Kobold Services Inc. | Methods and electrically-actuated apparatus for wellbore operations |
US9410399B2 (en) * | 2012-07-31 | 2016-08-09 | Weatherford Technology Holdings, Llc | Multi-zone cemented fracturing system |
GB2508710B (en) * | 2012-10-16 | 2015-05-27 | Petrowell Ltd | Flow control assembly |
US9670750B2 (en) * | 2013-08-09 | 2017-06-06 | Team Oil Tools, Lp | Methods of operating well bore stimulation valves |
-
2014
- 2014-12-16 AU AU2014414065A patent/AU2014414065B2/en not_active Ceased
- 2014-12-16 US US15/516,843 patent/US20170247981A1/en not_active Abandoned
- 2014-12-16 WO PCT/US2014/070544 patent/WO2016099454A1/en active Application Filing
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4436155A (en) * | 1982-06-01 | 1984-03-13 | Geo Vann, Inc. | Well cleanup and completion apparatus |
US5669445A (en) * | 1996-05-20 | 1997-09-23 | Halliburton Energy Services, Inc. | Well gravel pack formation method |
US20080060815A1 (en) * | 2002-02-13 | 2008-03-13 | Howlett Paul D | Wellhead seal unit |
US20100218941A1 (en) * | 2009-02-27 | 2010-09-02 | Muthukumarappan Ramurthy | Determining the Use of Stimulation Treatments Based on High Process Zone Stress |
US20110253376A1 (en) * | 2010-04-15 | 2011-10-20 | Mark Wayne Krpec | Tool for removing debris from a wellbore |
Also Published As
Publication number | Publication date |
---|---|
US20170247981A1 (en) | 2017-08-31 |
AU2014414065B2 (en) | 2018-08-16 |
AU2014414065A1 (en) | 2017-04-27 |
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