WO2012106012A1 - Methods of maintaining sufficient hydrostatic pressure in multiple intervals of a wellbore in a soft formation - Google Patents
Methods of maintaining sufficient hydrostatic pressure in multiple intervals of a wellbore in a soft formation Download PDFInfo
- Publication number
- WO2012106012A1 WO2012106012A1 PCT/US2011/049325 US2011049325W WO2012106012A1 WO 2012106012 A1 WO2012106012 A1 WO 2012106012A1 US 2011049325 W US2011049325 W US 2011049325W WO 2012106012 A1 WO2012106012 A1 WO 2012106012A1
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- WO
- WIPO (PCT)
- Prior art keywords
- pressure
- wellbore
- interval
- pressure regulator
- amount
- Prior art date
Links
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 64
- 238000000034 method Methods 0.000 title claims abstract description 58
- 230000002706 hydrostatic effect Effects 0.000 title claims abstract description 24
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- 238000002955 isolation Methods 0.000 claims description 13
- 238000005086 pumping Methods 0.000 claims description 4
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- 206010017076 Fracture Diseases 0.000 description 11
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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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
-
- 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/12—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using drilling pipes with plural fluid passages, e.g. closed circulation systems
-
- 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
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in 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
- 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
Definitions
- the wellbore includes at least two intervals.
- a liquid is flowed through at least a first and second pressure regulator, wherein at least one of the pressure regulators is located in each of the intervals such that the pressure regulators regulates the amount of pressure exerted by the liquid on the wall of the wellbore.
- all of the pressure regulators are used to maintain the hydrostatic pressure by maintaining liquid communication with each of the intervals.
- a method of maintaining a hydrostatic pressure exerted on a wall of a wellbore in at least a first interva 1 and a second interval of the wellbore comprises the steps of : flowing a liquid through at least a first pressure regulator and a second pressure regulator, wherein the first ;pressure regulator is located in the first interval of the wellbore, wherein the second pressure regulator is located in the second interval of the wellbore, and wherein each of the first and second pressure regulators regulates the amount of pressure exerted by the liquid on the wall of the wellbore; and maintaining the amount of pressure for a specific period of time.
- a method of maintaining a hydrostatic pressure in multiple intervals of a soft subterranean formation comprises the steps of: using a pressure regulator to maintain an amount of pressure exerted by a liquid on the face of the subterranean formation in each of the multiple intervals, wherein the step of using comprises maintaining liquid communication with each of the multiple intervals .
- FIG. 1 is a diagram of a portion of a well system including sand control assemblies comprising a pressure regulator .
- first,” “second,” “third,” etc. are arbitrarily assigned and are merely intended to differentiate between two or more pressure regulators, intervals, sand control assemblies, etc., as the case may be, and does not indicate any particular orientation or sequence. Furthermore, it is to be understood that the mere use of the term “first” does not require that there be any "second, " and the mere use of the term “second” does not require that there be any "third,” etc.
- a “fluid” is a substance having a continuous phase that tends to flow and to conform to the outline of its container when the substance is tested at a temperature of 71 °F (22 °C) and a pressure of one atmosphere “atm” (0.1 megapascals "MPa”) .
- a fluid can be a liquid or gas.
- Oil and gas hydrocarbons are naturally occurring in some subterranean formations.
- a subterranean formation containing oil or gas is sometimes referred to as a reservoir.
- a reservoir may be located under land or offshore. Reservoirs are typically located in the range of a few hundred feet (shallow reservoirs) to a few tens of thousands of feet (ultra-deep reservoirs) .
- a wellbore is drilled into a reservoir or adjacent to a reservoir.
- a well can include, without limitation, an oil, gas, water, or injection well.
- a well used to produce oil or gas is generally referred to as a production well.
- a well includes at least one wellbore.
- a wellbore can include vertical, inclined, and horizontal portions, and it can be straight, curved, or branched.
- the term "wellbore” includes any cased, and any uncased, open-hole portion of the wellbore.
- a near-wellbore region is the
- the near-wellbore region is generally considered to be the region within about 100 feet of the wellbore.
- into a well means and includes into any portion of the well, including into the wellbore or into the near-wellbore region via the wellbore.
- a portion of a wellbore may be an open hole or cased hole.
- a tubing string may be placed into the wellbore.
- the tubing string allows fluids to be introduced into or flowed from a remote portion of the wellbore.
- a casing is placed into the wellbore which can also contain a tubing string.
- a wellbore can contain an annulus .
- annulus examples include, but are not limited to: the space between the wall of the wellbore and the outside of a work string (such as a tubing string) in an open-hole wellbore; the space between the wall of the wellbore and the outside of a casing in a cased- hole wellbore; and the space between the inside of a casing and the outside of a tubing string in a cased-hole wellbore.
- a work string such as a tubing string
- Well completion is generally performed in order to enable production of oil or gas from a reservoir.
- a variety of completion equipment can be used during the
- the specific equipment used for well completion can differ for a cased-hole wellbore versus an open- hole wellbore. Moreover, the specific equipment used for well completion can differ for a consolidated formation versus an unconsolidated or loosely consolidated formation, also known as a "soft formation.”
- part of the formation can cave in and collapse, resulting in a loss of the annular space between the wall of the wellbore and the outside of the work string.
- a fluid overbalance is generally performed by placing a fluid, such as a completion brine, into the annulus at a hydrostatic pressure that exceeds the pressure exerted by fluids in the subterranean formation. In this manner, the greater pressure on the wall of the wellbore helps to keep the formation from collapsing into the annular space.
- hydrostatic pressure means the force per unit area exerted by a column of fluid at rest. Two factors that can affect the hydrostatic pressure are the density of the fluid and the depth of the fluid below the earth's surface or the surface of a body of water.
- a fluid overbalance can also include
- a filtercake can be a relatively impermeable sheath or a permeable network, which binds fines, such as sand, together while allowing fluids to flow through the interconnected pores in the filtercake.
- a filtercake can coat the wall of a wellbore and it can also penetrate a certain depth into the near-wellbore region.
- Sand control is a technique often used in soft openhole formations.
- sand control techniques include, but are not limited to, depositing a filtercake in a portion of the well, using sand control assemblies, and gravel packing.
- a common sequence of sand control techniques is to first deposit a filtercake in the desired portion of the well, then install a sand control assembly in the wellbore, and finally gravel pack the wellbore.
- Sand control assemblies often include a slotted liner and/or a screen.
- a slotted liner can be a perforated pipe, such as a blank pipe.
- the screen usually contains holes that are smaller than the perforations in the slotted liner.
- the liner and/or screen can cause bridging of the fines against the liner or screen as oil or gas is being produced.
- Gravel packing is often performed in conjunction with the use of sand control assemblies. Gravel is proppant having a particle-size class above sand, which is defined as having a largest dimension ranging from greater than 2 millimeters (mm) up to 64 mm.
- a packer and a sand control assembly with a washpipe inside the assembly are usually run in the wellbore with a service tool.
- the gravel is then commonly placed in a portion of an annulus between the wall of the wellbore and the outside of the screen at a location below the packer. The gravel helps to trap and restrain fines from entering the production equipment or plugging the holes in the liner or screen while at the same time stabilizing the
- Fracturing is a common stimulation treatment.
- a treatment fluid adapted for this purpose is sometimes referred to as a "fracturing fluid.”
- the fracturing fluid is pumped at a sufficiently high flow rate and high pressure into the wellbore and into the subterranean formation to create or enhance a fracture in the subterranean formation.
- the fracture provides a highly-permeable flow path for oil or gas to be produced.
- the fracture in soft rock formations will tend to close together after the pumping of the fracturing fluid is stopped.
- a material must be placed in the fracture to keep the fracture propped open.
- a material used for this purpose is often referred to as a "proppant . " It is often desirable to create multiple fractures at multiple downhole locations.
- a wellbore can extend vertically, at an angle, horizontally, and combinations thereof, for several hundreds of feet into a subterranean formation.
- a wellbore can only include one zone, also known as an interval.
- a wellbore can also include multiple zones or multiple
- intervals means the space between two objects.
- an "interval” means the space between two objects.
- completion or stimulation For example, during well completion, a portion of an annulus can be partitioned off from other portions of the annulus. In this manner, portions of the annulus can be sealed so fluids will not flow through the annulus but rather will flow through the tubing string or casing. By sealing portions of the annulus, oil or gas can be produced in a controlled manner through the wellhead via the tubing string or casing.
- one interval of the formation may be relatively impermeable compared to another interval of the formation.
- fracturing of the formation can be performed within the desired intervals.
- the fracture treatment design can be optimized for each interval.
- Hydraulic, hydrostatic, or swellable packers can be utilized to create multiple intervals.
- a common example of an interval in a wellbore is the annular space between two packers.
- a hydraulic packer is hydraulically actuated and carries a packer element.
- a hydrostatic packer is actuated by the pressure in the wellbore and carries a packer element.
- the packer element is a ring fitted on the outside of a mandrel attached to a tubing string or casing. Hydraulic actuation of the packer axially squeezes the packer element to cause radial expansion of the packer element and seals the annulus.
- a swellable packer includes a swellable element, which can swell to a size that is larger than the size of the pre-swelled element.
- the swellable element is a ring fitted around the outside of a portion of a tubing string or casing or a mandrel attached to either.
- the swellable element is normally axially constrained on the top and bottom such that the swellable element can expand in a radial direction only. As the swellable element swells, it expands radially and seals the part of the annulus.
- the term "setting the packer" and all grammatical variations thereof means an act that causes the packer element or swellable element to expanded sufficiently to seal the part of the annulus that the packer is located in.
- top packer means the packer that is closest to the wellhead. Other packers can be situated below the top packer. It should be understood that the use of the words “top” and “below” are meant to describe a position in relation to a wellhead and are not meant to imply a vertical direction. While for a vertical well, the use of the words top and below will refer to a vertical direction, for an inclined or horizontal well, the words do not refer to a
- the "top packer” is the packer that is positioned closest to the packer
- top packer means the part of the subterranean formation that is farther away from the wellhead compared to the top packer.
- Such causes can include, but are not limited to, reduction in the weight of the completion fluid, damage to the filtercake (causing fluid to leak off into the formation) , tool movement which removes part of the filtercake, and a loss of hydrostatic pressure when setting a packer.
- causes can include, but are not limited to, reduction in the weight of the completion fluid, damage to the filtercake (causing fluid to leak off into the formation) , tool movement which removes part of the filtercake, and a loss of hydrostatic pressure when setting a packer.
- hydrostatic pressure when setting a packer can occur because, after a top packer is set, there is generally a loss of fluid communication with the formation situated below the top packer. In soft formations, this loss of fluid communication can allow the formation to cave in and collapse in the annular space below the top packer. Thus, there is a need to be able to perform well completion (including sand control techniques) in a
- a novel method of maintaining a hydrostatic pressure exerted on a wall of a wellbore in at least a first interval and a second interval of the wellbore comprises the steps of: flowing a liquid through at least a first pressure regulator and a second pressure regulator, wherein the first pressure regulator is located in the first interval of the wellbore, wherein the second pressure regulator is located in the second interval of the wellbore, and wherein each of the first and second pressure regulators regulates the amount of pressure exerted by the liquid on the wall of the wellbore; and maintaining the amount of pressure for a specific period of time.
- One of the advantages to the methods described herein is that regardless of whether the potential loss of pressure is a result of loss of a portion of a filtercake, or for some other reason, the methods allow for a relatively constant pressure to be maintained in each of the intervals of the wellbore. Another advantage is that the required pressure needed to maintain the integrity of the formation may vary from interval to interval, and the methods allow for the maintenance of the particular required pressure for each of the intervals. Yet another advantage to the methods is that the pressure can be regulated for each interval at a pressure that is optimal for each
- the pressure regulator can be set to a pressure that is below the fracturing pressure.
- a method of maintaining a hydrostatic pressure exerted on a wall of a wellbore in at least a first interval and a second interval of the wellbore comprises the steps of: flowing a liquid through at least a first pressure regulator and a second pressure regulator, wherein the first pressure regulator is located in the first interval of the wellbore, wherein the second pressure regulator is located in the second interval of the wellbore, and wherein each of the first and second pressure regulators
- a method of maintaining a hydrostatic pressure in multiple intervals of a soft subterranean formation comprises the steps of: using a pressure regulator to maintain an amount of pressure exerted by a liquid on the face of the subterranean formation in each of the multiple intervals, wherein the step of using comprises maintaining liquid communication with each of the multiple intervals .
- Fig. 1 is a diagram of a portion of a well system according to certain embodiments. Any discussion of a particular component of the well system (e.g., a pressure regulator 400) is meant to include the
- embodiments may refer to a first and second pressure regulator, a first and second interval, etc.; however, it is to be
- the wellbore can be a vertical wellbore, angled wellbore, horizontal wellbore, or combinations thereof.
- a subterranean formation can be penetrated by the wellbore.
- the wellbore can be a cased-hole, an open-hole, or a combination of cased-hole and open-hole.
- at least a portion of the wellbore is an open-hole wellbore.
- a portion of the wellbore can contain a casing 101, whereas another portion of the wellbore does not contain the casing 101.
- the wellbore can contain at least one annulus .
- the wellbore can contain an annulus 104 between the wall of the wellbore 102 and the blank pipe 301.
- the wellbore can also contain an annulus 103 between the casing 101 and the blank pipe 301.
- the annulus 104 is intended to be an open-hole annulus; whereas the annulus 103 is intended to be a cased-hole annulus.
- Either one of the annuli 104 or 103 do not have to include the blank pipe 301, but can be a space between a work string (not shown) and either the wall of the wellbore 102 or the casing 101.
- the methods include maintaining a
- first and second intervals are part of a soft formation. More preferably, each of the first and second intervals are part of a soft formation. According to an embodiment, there are more than two intervals of the
- the wellbore can include a multiple interval wellbore.
- a first pressure regulator 400 is located in the first interval and a second pressure regulator 400 is located in the second interval.
- the pressure regulator 400 is preferably part of a sand control assembly.
- the first pressure regulator can be part of a first sand control assembly and the second pressure regulator can be part of a second sand control
- At least the first sand control assembly can be located in the first interval and at least the second sand control assembly can be located in the second interval. More than one sand control assembly can be located in each interval.
- Any of the sand control assemblies can include an upper seal bore 303, a closing sleeve 304, an indicator nipple 305, and a screen 302. According to an embodiment, the upper seal bore
- the sand control assemblies can further include a blank pipe 301.
- the first and second pressure regulators 400 are attached to the screen 302, blank pipe 301, or combinations thereof of the first and second sand control assemblies, respectively.
- the first pressure regulator 400 can be attached to the blank pipe 301 of the first sand control assembly while the second pressure regulator 400 can be attached to the screen 302 of the second sand control assembly.
- the first pressure regulator 400 positioned closest to the wellhead 100 is shown in Fig. 1 as being attached to the blank pipe 301 while the second pressure regulator 400 farthest away from the wellhead 100 is shown in Fig.
- first and second pressure regulators 400 are attached to the outside of the screen 302, blank pipe 301, or combinations thereof of the first and second sand control assemblies, respectively.
- the methods can further include the step of placing at least the first pressure regulator 400 in the first interval and at least the second pressure regulator 400 in the second interval.
- the step of placing can include the step of installing at least the first and second sand control assemblies.
- single trip means that the assemblies are simultaneously run into the wellbore using a string, as opposed to running one assembly and then removing the string to subsequently run another assembly.
- the methods can further include the step of creating at least the first and second intervals in the
- the methods can include the step of placing a top packer 201 and at least two isolation packers 202 in the desired portions of the wellbore.
- the top packer 201 can be a gravel packer.
- the first interval can be located between the top packer 201 and an isolation packer 202a.
- the second interval can be located between two isolation packers 202a and 202b. If there are more than two intervals, then any additional intervals are preferably located between isolation packers (not shown) . While Fig. 1 depicts the first interval being between the top packer 201 and the
- isolation packer 202a and the second interval being between the isolation packer 202a and the isolation packer 202b, there can be multiple intervals located below the isolation packer 202b. Moreover, while only two isolations packers 202a and 202b are depicted, there can be multiple isolation packers located in the wellbore .
- the step of placing any of the packers 201 and/or 202 is performed prior to the step of installing the first and second sand control
- the methods can further include the step of setting the packers 201 and/or 202 after the step of placing the packers 201 and/or 202.
- the packers 201 and 202 can be placed in the wellbore such that after setting, at least one portion of the annulus 103 or 104 is sealed off from another portion of the annulus .
- the step of setting the isolation packers 202a and 202b can be performed after the step of setting the top packer 201.
- subterranean formation comprises the steps of: using all of at least one pressure regulator located in each of the multiple intervals to maintain an amount of pressure exerted by a liquid on the face of the subterranean formation in each of the
- step of using comprises
- the methods can include the step of maintaining liquid communication with each of the multiple intervals located below the top packer 201 after the step of setting the top packer 201.
- liquid communication is maintained in each of the multiple intervals simultaneously.
- at least one pressure regulator 400 is located in each of the multiple intervals.
- all of the at least one pressure regulators 400 located in each of the multiple intervals is used to maintain an amount of pressure exerted by the liquid.
- the face of the subterranean formation 500 can be a wall of a wellbore 102. All of the pressure regulators 400 can be used to maintain liquid
- the pressure regulators 400 can be used to maintain liquid communication by flowing a liquid through each of the regulators.
- the step of maintaining liquid communication can include maintaining liquid communication between the screen, blank pipe, or combinations thereof 302 and/or 301 and the wall of the wellbore 102 or the face of the subterranean formation.
- the liquid communication can include pumping the liquid from the wellhead 100, down the work string (not shown) , through the screen or pipe 302 or 301, through the pressure regulator 400, and into the annulus for each interval 103 and 104.
- liquid communication is maintained between the screen or pipe 302 or 301 and the wall of the wellbore 102 at a position below (in the direction of di) the top packer 201.
- the methods can also include any of the steps necessary for performing sand control.
- the methods can further include the step of depositing a filtercake on at least a portion of the wall of the wellbore 102, and preferably the step of depositing is performed prior to the step of flowing a liquid through at least the first and second pressure regulators 400.
- the step of depositing is also preferably performed before the step of installing the first and second sand control assemblies.
- the filtercake can help prevent collapse of the wall of the wellbore 102, and can be relatively impermeable thus preventing fluids from leaking off into the formation while allowing hydrostatic pressure to be created in the annuli 103 and 104.
- the methods can also include the step of placing gravel in at least a portion of at least one of the intervals. Only one, more than one, or all of the intervals can be gravel packed. The methods can also include the step of creating at least one fracture in at least one of the intervals after the step of maintaining.
- the methods include the step of flowing a liquid through at least the first pressure regulator 400 and the second pressure regulator 400.
- a liquid is flowed through multiple pressure regulators 400 in addition to the first and second pressure regulators.
- a liquid is flowed through all of the at least one pressure regulators located in each of the multiple intervals.
- the step of flowing can include pumping a liquid through the pressure regulator 400.
- the step of flowing comprises simultaneously flowing the fluid through at least the first and second pressure regulators 400.
- the step of flowing can comprise flowing the fluid through a work string, through the inner diameter of the screen 302 or blank pipe 301, through each of the pressure regulators 400, and into the annuli 103 and 104.
- Any of the pressure regulators 400 can further include a backflow device. The back flow device can help prevent fluid from entering the inner diameter of the screen or blank pipe 302 or 301 via the
- the methods include maintaining an amount of pressure exerted by the liquid on the wall of the wellbore 102 or the face of the subterranean formation 500.
- the amount of pressure can be predetermined.
- the amount of pressure can vary.
- the amount of pressure can also be different for each interval or the amount of pressure can be the same for each interval.
- the amount of pressure for the first interval can be the same or different from the amount of pressure for the second interval.
- the pressure regulator 400 can be pre-set to a desired or predetermined amount of pressure.
- the first regulator 400 can be pre-set to 150 psi and the second regulator 400 can be pre-set to 250 psi.
- each of the regulators 400 can be pre-set to the desired or predetermined amount of pressure for each interval.
- the desired or the pre-determined pressure for each interval is the minimum pressure needed to maintain the integrity for that interval.
- the pressure regulator 400 can be pre-set such that the regulator 400 does not allow the pressure exerted on the wall of the wellbore or the face of the subterranean formation to increase above, or fall below, the amount of pressure.
- the amount of pressure is equal to or greater than the fluid
- the amount of pressure is at least sufficient to prevent the majority of the wall of the wellbore 102 or the face of the subterranean formation from collapsing in that interval. Most preferably, the amount of pressure is less than the amount of pressure needed to create a fracture in the subterranean formation for that interval.
- the methods include the step of maintaining the amount of pressure for a specific period of time.
- the specific period of time is the time needed to set the top packer 201, place at least the first and second pressure regulators 400, and set the at least two isolation packers 202.
- the specific period of time is the time needed to complete a sand control technique.
- the specific period of time is the time needed to complete a sand control technique on each interval
- compositions and methods also can “consisting, "comprising, “ “containing, “ or “including” various components or steps, the compositions and methods also can “consist
Abstract
Description
Claims
Priority Applications (6)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP11857649.5A EP2670940B1 (en) | 2011-02-03 | 2011-08-26 | Methods of maintaining sufficient hydrostatic pressure in multiple intervals of a wellbore in a soft formation |
BR112013019777-3A BR112013019777B1 (en) | 2011-02-03 | 2011-08-26 | method of maintaining hydrostatic pressure exerted on a well bore wall |
CN201180066702.4A CN103380262B (en) | 2011-02-03 | 2011-08-26 | The method keeping sufficient hydrostatic pressure in multiple intervals of the well in soft formation |
SG2013056312A SG192110A1 (en) | 2011-02-03 | 2011-08-26 | Methods of maintaining sufficient hydrostatic pressure in multiple intervals of a wellbore in a soft formation |
AU2011357689A AU2011357689B2 (en) | 2011-02-03 | 2011-08-26 | Methods of maintaining sufficient hydrostatic pressure in multiple intervals of a wellbore in a soft formation |
CA2825797A CA2825797C (en) | 2011-02-03 | 2011-08-26 | Methods of maintaining sufficient hydrostatic pressure in multiple intervals of a wellbore in a soft formation |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/020,618 | 2011-02-03 | ||
US13/020,618 US9494000B2 (en) | 2011-02-03 | 2011-02-03 | Methods of maintaining sufficient hydrostatic pressure in multiple intervals of a wellbore in a soft formation |
Publications (1)
Publication Number | Publication Date |
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WO2012106012A1 true WO2012106012A1 (en) | 2012-08-09 |
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PCT/US2011/049325 WO2012106012A1 (en) | 2011-02-03 | 2011-08-26 | Methods of maintaining sufficient hydrostatic pressure in multiple intervals of a wellbore in a soft formation |
Country Status (9)
Country | Link |
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US (1) | US9494000B2 (en) |
EP (1) | EP2670940B1 (en) |
CN (1) | CN103380262B (en) |
AU (1) | AU2011357689B2 (en) |
BR (1) | BR112013019777B1 (en) |
CA (1) | CA2825797C (en) |
MY (1) | MY163040A (en) |
SG (1) | SG192110A1 (en) |
WO (1) | WO2012106012A1 (en) |
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- 2011-08-26 WO PCT/US2011/049325 patent/WO2012106012A1/en active Application Filing
- 2011-08-26 CN CN201180066702.4A patent/CN103380262B/en active Active
- 2011-08-26 AU AU2011357689A patent/AU2011357689B2/en active Active
- 2011-08-26 EP EP11857649.5A patent/EP2670940B1/en active Active
- 2011-08-26 CA CA2825797A patent/CA2825797C/en not_active Expired - Fee Related
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US9494000B2 (en) | 2016-11-15 |
EP2670940B1 (en) | 2021-01-13 |
EP2670940A1 (en) | 2013-12-11 |
SG192110A1 (en) | 2013-08-30 |
BR112013019777A2 (en) | 2016-10-25 |
EP2670940A4 (en) | 2017-07-05 |
CA2825797C (en) | 2016-01-12 |
BR112013019777B1 (en) | 2021-02-17 |
AU2011357689B2 (en) | 2015-05-28 |
CA2825797A1 (en) | 2012-08-09 |
CN103380262B (en) | 2016-11-23 |
US20120199362A1 (en) | 2012-08-09 |
MY163040A (en) | 2017-07-31 |
AU2011357689A1 (en) | 2013-08-22 |
CN103380262A (en) | 2013-10-30 |
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