US20120132434A1 - Production Riser - Google Patents

Production Riser Download PDF

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Publication number
US20120132434A1
US20120132434A1 US13/384,490 US201013384490A US2012132434A1 US 20120132434 A1 US20120132434 A1 US 20120132434A1 US 201013384490 A US201013384490 A US 201013384490A US 2012132434 A1 US2012132434 A1 US 2012132434A1
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US
United States
Prior art keywords
ssr
riser
vessel
specialty
joints
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Abandoned
Application number
US13/384,490
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English (en)
Inventor
Charles R. Yemington
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
MY TECHNOLOGIES LLC
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MY TECHNOLOGIES LLC
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from US12/714,919 external-priority patent/US20110011320A1/en
Application filed by MY TECHNOLOGIES LLC filed Critical MY TECHNOLOGIES LLC
Priority to US13/384,490 priority Critical patent/US20120132434A1/en
Assigned to MY TECHNOLOGIES, L.L.C. reassignment MY TECHNOLOGIES, L.L.C. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: YEMINGTON, CHARLES R.
Publication of US20120132434A1 publication Critical patent/US20120132434A1/en
Priority to US14/075,475 priority patent/US20140060415A1/en
Abandoned legal-status Critical Current

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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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/01—Risers
    • E21B17/012—Risers with buoyancy elements
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B27/00—Arrangement of ship-based loading or unloading equipment for cargo or passengers
    • B63B27/24—Arrangement of ship-based loading or unloading equipment for cargo or passengers of pipe-lines
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B35/00—Vessels or similar floating structures specially adapted for specific purposes and not otherwise provided for
    • B63B35/44—Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
    • B63B35/4413—Floating drilling platforms, e.g. carrying water-oil separating devices

Definitions

  • the present invention is directed to a riser for the production of hydrocarbons from fossil hydrocarbon reservoirs deep below the seafloor. Further, the present invention is directed to the interfacing of the riser to a vessel subject to high vessel motions of pitch and roll.
  • the small vessel employs a unique stabilization system for the separation processing equipment on deck.
  • the present invention is directed to a system including a self supporting riser (SSR) which is connected to a well to provide fluid communication to fossil hydrocarbon reservoirs deep below the seafloor.
  • SSR self supporting riser
  • the SSR is constructed of a plurality of joints comprising regular joints and specialty joints that define the SSR and are selected to optimize the SSR for a well in a specific location.
  • a unique aspect of the SSR of the present invention is that while capable of connecting to the wellhead, or tree on the seafloor, it can also be secured to an anchor during operations.
  • the invention is further directed to a small vessel subject to high vessel motions moored to the SSR by a line such as a hawser, the riser providing an anchor to the vessel, and the SSR carrying fluids from the well to the vessel and from the vessel to the well.
  • a line such as a hawser
  • FIG. 1 is a schematic view a self supporting riser (SSR) connected to a well for testing and producing hydrocarbons from a fossil hydrocarbon reservoir deep below the seafloor;
  • SSR self supporting riser
  • FIG. 2 is a schematic cross-sectional view of one embodiment of a self supporting riser (SSR) illustrating multiple tubulars side by side;
  • SSR self supporting riser
  • FIG. 3 is a schematic cross-sectional view of another embodiment of a self supporting riser (SSR) illustrating multiple tubulars in a concentric configuration;
  • SSR self supporting riser
  • FIG. 4 is a schematic view a self supporting riser (SSR) connected to a well for producing hydrocarbons from a fossil hydrocarbon reservoir deep below the seafloor; and a vessel subject to high vessel motions moored to the SSR with the riser providing an anchor to the vessel;
  • SSR self supporting riser
  • FIG. 5 is a schematic top view of a novel production vessel having processing equipment on a stabilized frame on the vessel;
  • FIG. 6 is a schematic side view of a novel production vessel
  • FIG. 7 is a top isometric view of a vessel configuration
  • FIG. 8 is an isometric view of a stabilized frame on the vessel.
  • FIG. 8A is a schematic diagram illustrating a hydraulic system for stabilizing the frame on the vessel.
  • the present invention is directed to a riser system including a self supporting riser (SSR) which is in fluid communication with a well to test and produce fossil hydrocarbon reservoirs deep below the seafloor. Still further the present invention is directed to a self supporting riser (SSR) which is in fluid communication with a well and preferably includes a small vessel with processing equipment on a stable frame on the deck moored to the (SSR) carrying fluids from the subsea well to the processing equipment on the vessel.
  • SSR self supporting riser
  • the present invention uses a small vessel to facilitate operation of processing equipment on board rather than a multi-million dollar platform or a large vessel having large day-rates. It is preferred that the vessel is moored to the SSR so that the small vessel does not require using dynamic positioning to maintain vessel position, further lowing cost.
  • the present invention uses a SSR to provide fluid communication from a well or seafloor production equipment to the small vessel moored to the SSR rather than a riser fixed to a platform or a large vessel.
  • a Self Supporting Riser (SSR) 10 is illustrated on an element of a subsea infrastructure, such as a wellhead 20 .
  • the SSR 10 When placed on the wellhead 20 the SSR 10 provides fluid communication with a well beneath the seafloor.
  • Riser 10 has one or more buoyancy modules 15 and 19 .
  • the uppermost buoyancy module 19 is referred to herein as the near-surface buoyancy module and any module below module 19 is referred to herein as a mid-water buoyancy module.
  • a connector 25 suited to the target wellhead or tree or another element of seafloor infrastructure.
  • a Seafloor Shutoff Device 11 when used may be directly above the connector 25 .
  • a specialty joint 18 with functions of a Blow Out Preventer (BOP) is preferably below the near-surface buoyancy module 19 .
  • Functions of a Blow Out Preventer (BOP) 18 may be to shear tubing or pipe if necessary and provide a seal to fluids in the riser 10 .
  • this SSD 11 can consist of simply activating one or more valves.
  • a specific design of the SSR 10 is only illustrated in FIG. 1 ; however, the present invention as explained in Ser. No. 12/714,919, also includes provisions to assemble an SSR for a particular purpose, water depth, current conditions, or location from an inventory of standardized joints and to recover the joints and assemble some or all of them into a different SSR configuration for a different application.
  • the pre-production of the well is accomplished by opening the well to flow and permitting fluid communication to the SSR.
  • the system of the present invention may allow fluids from the well to a moored vessel over a period of time to determine the material parameters of the reservoir from which the fluids are flowing. While pressure and temperatures are indicated in the drilling procedures, the sustainability of pressure in the reservoir or the amounts of gas and water over time flowing from a specific reservoir are preferably measured by allowing the flow of fluids from the reservoir over time.
  • FIGS. 2 and 3 illustrate that a riser 10 may be of multiple tubular construction; FIG. 2 illustrating one or more side by side tubulars 10 1 and 10 2 with the remaining area either empty or filled with insulation and FIG. 3 illustrating one or more concentric tubulars 10 1 and 10 2 separated by spacers 10 3 surrounded by insulation.
  • FIG. 2 illustrating one or more side by side tubulars 10 1 and 10 2 with the remaining area either empty or filled with insulation
  • FIG. 3 illustrating one or more concentric tubulars 10 1 and 10 2 separated by spacers 10 3 surrounded by insulation.
  • side by side tubular in the riser may be used when the well has more than one tubular in the well casing such as one tubular extending to a reservoir at one depth and another tubular extending to a reservoir at a lower depth, possibly for the purpose of gas reinjection.
  • a concentric tubular riser may be used when double containment is required or when heated water may be used to heat the fluid flowing in the inner tubular where hydrates may form.
  • Riser 10 may be attached to an element of a seafloor infrastructure, such as a wellhead or tree 20 ( FIG. 1 ), throughout production or may be attached to a seafloor anchor 22 such as a pile; or a gravity or embedment anchor ( FIG. 4 ).
  • the lower end of the SSR 10 has provision for a flexible jumper line 26 to connect to the tree 20 for the flow of hydrocarbons from the well and up through the riser 10 .
  • Attachment of the SSR 10 to the seafloor anchor is preferably by a flexible connector 25 , such as two half links of chain 25 ′ which permit inclination in any direction but prevent axial rotation of riser 10 .
  • a flexible connector 25 such as two half links of chain 25 ′ which permit inclination in any direction but prevent axial rotation of riser 10 .
  • Possible alternatives include a section of flexible pipe which bends without buckling or a flexible joint such as is commonly used as a hanger for steel catenary risers.
  • a mechanical connection such as two half links of chain allows the SSR to freely incline from vertical at any compass bearing, thus avoiding bending moment in the SSR near the seafloor. Configuring the mechanical connection between the SSR and the anchor to prevent the SSR from rotating about its axis prevents excessive loads on the flexible pipe 26 shown connected to the well or production equipment.
  • a mechanical connection can be simple, or can be more sophisticated and may include provisions for functions such as connection and release by ROV or other remote means.
  • a swivel can be placed at any location in the SSR 10 to allow the vessel to weather van freely without causing excessive torsion in the riser.
  • the production riser 10 preferably has a swivel 24 mounted above the near-surface buoyancy module 19 . Placing a swivel high in the SSR but below the buoyancy would require a swivel that functions under high tension. Placing the swivel near the seafloor locates it where SSR tension is low, but subjects the swivel to high ambient pressure and places it in a relatively inaccessible location.
  • the swivel 24 (or swivels) is preferably located in the SSR above the load path to the buoyancy as illustrated to avoid both high tension and the complications associated with placing a swivel near the seafloor.
  • a single swivel 24 for flow of fluid between riser 10 and vessel 30 , controls (umbilical 12 ), and connecting the mooring line 36 can be placed as shown, or separate swivels, with or without provisions to avoid mooring line tension on the fluid swivel can be located in the position as shown.
  • the torque required to operate the swivel(s) must be less than the torque rating of the SSR and must be less than the torque required to break out any threaded connections in the SSR.
  • Wind direction current frequently shift gradually from east to south to west to north, or vice versa. Wind shifts such as this can drive a moored vessel multiple times around the mooring point, either clockwise or counter clockwise.
  • Mooring of a small vessel 30 can be as shown in FIG. 4 , where a mooring line(s) 36 extends from the top of the SSR 10 to a mooring buoy 37 that floats on the sea surface, and mooring line(s) 38 extend to the vessel 30 to secure the vessel 30 to the upper part of the SSR 10 .
  • the mooring line 36 attached to the buoy 37 may be installed as part of assembling the production riser 10 .
  • a flexible pipe 27 is shown connected from the upper part of the SSR, preferably through the swivel 24 , to the vessel 30 to provide continuation of the flow path for produced fluids from the well or production equipment below. Buoyancy 28 may be used to support and tend the flexible pipe 27 .
  • a small vessel 30 which is subject to relatively high pitch and roll motions due to its size, is used in the production system of the present invention to avoid overloading the SSR 10 as a larger vessel might.
  • the SSR 10 When not subject to vessel mooring loads the SSR 10 stands upright, subject only to self weight and drag due to ocean currents (as illustrated in FIG. 1 ).
  • FIG. 4 When a vessel 30 is moored to the SSR 10 (illustrated in FIG. 4 ), wind and surface current pull the vessel and the top of the SSR away from the otherwise upright position of the SSR until the resulting offset angle and upward force of the buoyancy create a restoring force to balance the forces on the vessel to secure and moor the vessel.
  • the force of the vessel When the force of the vessel is relaxed or released the SSR restores itself to the nearly vertical attitude where it can survive untended and be ready for subsequent use.
  • Wind, current, or other forces on the moored vessel 30 pull on the hawser line 38 and move the surface buoy 37 until both line 36 and line 38 are taut.
  • the vessel then continues to move and pull on the hawser line 38 until an adequate restoring force is created by pulling the riser off vertical and pulling the surface buoy deeper into the water.
  • the vessel becomes essentially stationary when the restoring force is equal to the force acting to move the vessel. An increase or decrease in forces acting to displace the vessel will cause this geometry to adjust until vessel position is again stable.
  • the horizontal force from a moored vessel 30 pulls the SSR 10 off vertical and consequently causes the top of the SSR to move down to a greater depth below the surface.
  • line 36 is not horizontal, tension in this line includes a vertical component which pulls the surface buoy deeper into the water and increases the tension in the riser.
  • the horizontal restoring force from the buoyancy module 19 is proportional to the total upward force at the top of the riser times the sine of the angle of inclination off vertical of the SSR and this inclination increases as the SSR is pulled further off vertical. Therefore the restoring force increases as the top of the SSR is pulled further from its vertical position.
  • the surface buoy 37 is sufficiently large to prevent it from being pulled completely underwater and the length of line 36 is chosen to achieve the desired relationship between riser tension and riser inclination.
  • Line 36 is always long enough to allow the surface buoy to float with freeboard. Beyond this, making line 36 longer results in greater maximum inclination of the riser and reduced maximum tension in the riser.
  • the total horizontal force at the top of the riser must be reacted by a horizontal force component at the seafloor.
  • a flexible connection 25 the preferred embodiment of which is two half links of chain, allows the horizontal component of riser tension to be transmitted to the anchor 22 without a bending moment in the riser.
  • the depth of the top of the SSR increases as the SSR is pulled off vertical. If the buoyancy module 19 is a sealed gas can, the pressure differential across its hull will increase, and must not be allowed to exceed the rating of the hull. If the buoyancy module 19 is a vented gas can, the gas in it will compress so buoyancy will decrease, and buoyancy must not be allowed to decrease below the required value. In either case these difficulties can be avoided by using umbilical 12 from the vessel to trim the gas fill of the buoyancy module 19 .
  • the umbilical 12 is preferably dressed with the flexible pipe 27 , but can be a separate line from the vessel.
  • a small vessel 30 such as can reasonably be moored to an SSR 10 as described above, exhibits relatively large pitch and roll motions for any given sea state. It is not practical to operate a production system only when the sea is relatively calm. Therefore practical use of a small production vessel moored as above requires a stabilized support on which to mount the fluid processing equipment 29 . Heave (vertical) motions have little effect on the process equipment. Surge and sway motions are typically quite small, but pitch and roll motions require stabilization.
  • the pitch/roll stabilization system described in U.S. Ser. No. 12/714,919 can be used here to support a frame upon which to install process equipment that is sensitive to pitch and roll.
  • the embodiment that has the stable frame above the cylinders is preferred.
  • processing equipment 29 may comprise separator tanks 42 and 43 that separate the gas, the liquid hydrocarbons, and water.
  • the gas is removed from the top of the tanks 42 and 43 and is compressed and transferred to a gas tank 44 .
  • Water settles to the bottom of tanks 42 and 43 and is removed, purified, and discharged.
  • the liquid hydrocarbons are removed from above the water of tanks 42 and 43 and transferred to an oil tank 48 which may be below the deck.
  • the combination of the arrangement of the equipment 29 includes using one, two, or more tanks 42 and 43 as per existing industry practice with flow from line 27 into one or more separator tanks 42 and 43 .
  • the separated oil may be held in tank 48 on vessel 30 or may be transferred to a second vessel or barge (not shown) to be taken to shore.
  • the water may be purified in device 46 , or in a centrifuge 49 ; or treated in a series of centrifuges 49 ; or be treated on another vessel before being returned to the sea. This is not intended to recite all the possible equipment combinations as the specific hydrocarbon and water mixture brought up riser 10 will determine the most suitable combination of equipment.
  • frame 40 can be mounted on and supported by 2 (two) or more pairs of vertically mounted hydraulic cylinders. It is preferred that each cylinder be attached to the vessel deck 31 with the cylinder rods upward, and the rods attached by compliant joints 51 to the frame 40 to accommodate the changes of alignment as the vessel pitches and rolls. Each pair is connected by relatively large diameter hydraulic line connected to the bottom of each pair and a smaller diameter hydraulic line is connected to the top of each pair of cylinders.
  • one pair of cylinders is shown fore ( 52 F) and aft ( 52 A) and the other pair is shown port ( 53 P) to starboard ( 53 S).
  • a reversible pump is mounted between each pair of cylinders, pump 55 between cylinders 52 F and 52 A and pump 57 between cylinders 53 P and 53 S, the pumps are preferably between the non-load bearing chambers of the cylinders. This facilitates pumping at a lower pressure and, with the cylinders mounted with the rod ends up, pumping smaller quantities of fluid thus reducing energy consumption and improving reliability.
  • a feedback signal from an inclinometer is subtracted from a reference signal and the resulting error signal is used to control the direction and speed of the pump, inclinometer 58 controlling pump 57 and inclinometer 59 controlling pump 55 .
  • the pump thus speeds up as the frame tips along the axis between the pair of cylinders and the pump slows down and stops as this axis on the frame becomes level.
  • the inclinometers ( 58 ′ and 59 ′) could alternately be fixed with respect to the deck 31 of the vessel and used to drive the frame 40 in the direction opposite the deck's direction of motion.
  • accelerometers with appropriate signal conditioning could be used as an alternate or complement to inclinometers, and further that a combination of sensors on the deck and on the frame could be used.
  • the frame could be mounted on three cylinders (or any odd number of cylinders) if used with some method of apportioning flow between them to keep the frame level. Pairs of cylinders are preferred for simplicity of the control system. Two pair of cylinders are adequate for the desired performance. If there are 3 or more pairs the system will continue to function after any failure, so long as two pair remain functional and the other pair(s) are not locked in place. Therefore, using 3 or more pairs allows operation to continue normally following a failure and allows one pair to be removed from service for maintenance while the remaining pairs continue to keep the frame level.
  • the pump When transferring fluid from a more heavily loaded cylinder chamber to a less heavily loaded cylinder chamber it may be necessary for the pump to operate as a motor and deliver energy from the load to the power supply. This can be accomplished by, for instance, using hydraulic gear pumps which operate as motors if the pressure of the fluid flowing into the gear motor/pump exceeds the pressure of the fluid flowing out of the device.

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Ocean & Marine Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Architecture (AREA)
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  • Structural Engineering (AREA)
  • Earth Drilling (AREA)
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US13/384,490 2009-07-15 2010-07-14 Production Riser Abandoned US20120132434A1 (en)

Priority Applications (2)

Application Number Priority Date Filing Date Title
US13/384,490 US20120132434A1 (en) 2009-07-15 2010-07-14 Production Riser
US14/075,475 US20140060415A1 (en) 2009-07-15 2013-11-08 Production Riser

Applications Claiming Priority (10)

Application Number Priority Date Filing Date Title
US22560109P 2009-07-15 2009-07-15
US23255109P 2009-08-10 2009-08-10
US25281509P 2009-10-19 2009-10-19
US25323009P 2009-10-20 2009-10-20
US25320009P 2009-10-20 2009-10-20
US12/714,919 US20110011320A1 (en) 2009-07-15 2010-03-01 Riser technology
US12714919 2010-03-01
US35137410P 2010-06-04 2010-06-04
US13/384,490 US20120132434A1 (en) 2009-07-15 2010-07-14 Production Riser
PCT/US2010/041939 WO2011008834A2 (en) 2009-07-15 2010-07-14 Production riser

Related Parent Applications (2)

Application Number Title Priority Date Filing Date
US12/714,919 Continuation-In-Part US20110011320A1 (en) 2009-07-15 2010-03-01 Riser technology
PCT/US2010/041939 A-371-Of-International WO2011008834A2 (en) 2009-07-15 2010-07-14 Production riser

Related Child Applications (1)

Application Number Title Priority Date Filing Date
US14/075,475 Continuation US20140060415A1 (en) 2009-07-15 2013-11-08 Production Riser

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US20120132434A1 true US20120132434A1 (en) 2012-05-31

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US13/384,490 Abandoned US20120132434A1 (en) 2009-07-15 2010-07-14 Production Riser
US14/075,475 Abandoned US20140060415A1 (en) 2009-07-15 2013-11-08 Production Riser

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US (2) US20120132434A1 (ru)
EP (1) EP2454443A4 (ru)
CN (1) CN102498258A (ru)
AP (1) AP3335A (ru)
AU (1) AU2010273447B2 (ru)
BR (1) BR112012001669A2 (ru)
CA (1) CA2768165A1 (ru)
EA (1) EA201290052A1 (ru)
IL (3) IL217547A0 (ru)
MX (1) MX2012000753A (ru)
NZ (1) NZ597591A (ru)
PE (1) PE20121296A1 (ru)
WO (1) WO2011008834A2 (ru)

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US20120085544A1 (en) * 2010-10-12 2012-04-12 Bp Exploration Operating Company Limited Marine subsea free-standing riser systems and methods
US20120152558A1 (en) * 2009-05-26 2012-06-21 Framo Engineering As Heat transport dead leg
US20140326461A1 (en) * 2011-11-29 2014-11-06 Wellstream International Limited Buoyancy compensating element and method
US20150096760A1 (en) * 2013-10-03 2015-04-09 Atlantis Offshore Holding Ltd. Modular Exploration and Production System Including an Extended Well Testing Service Vessel
WO2019009566A1 (ko) * 2017-07-06 2019-01-10 한국해양과학기술원 Ｓｐｍ 시스템에서 라이져의 손상을 방지하는 장치 및 방법

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EP2912259A4 (en) * 2012-10-29 2016-06-15 Shell Int Research LATERAL INLET FLOW DISTRIBUTOR AND USE THEREOF
GB201621525D0 (en) 2016-12-16 2017-02-01 Statoil Petroleum As Tie-in Subsea pipeline
CN107218016A (zh) * 2017-07-13 2017-09-29 安世亚太科技股份有限公司 深海立管下部连接装置
GB2572335B (en) 2018-03-26 2022-09-28 Equinor Energy As Subsea well installation
NO345972B1 (en) * 2019-09-13 2021-11-29 Subseadesign As A wellhead system
CN111561272B (zh) * 2020-05-26 2021-12-07 中海石油(中国)有限公司 一种深水轻型修井立管系统及其安装方法
GB2606147B (en) * 2021-04-26 2024-01-10 Acergy France SAS Mooring renewable energy systems
WO2024044401A1 (en) * 2022-08-26 2024-02-29 Onesubsea Ip Uk Limited Subsea well test fluid reinjection

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Cited By (10)

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US20120152558A1 (en) * 2009-05-26 2012-06-21 Framo Engineering As Heat transport dead leg
US9328586B2 (en) * 2009-05-26 2016-05-03 Framo Engineering As Heat transport dead leg
US20120085544A1 (en) * 2010-10-12 2012-04-12 Bp Exploration Operating Company Limited Marine subsea free-standing riser systems and methods
US8960302B2 (en) * 2010-10-12 2015-02-24 Bp Corporation North America, Inc. Marine subsea free-standing riser systems and methods
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CN102498258A (zh) 2012-06-13
AU2010273447A1 (en) 2012-02-02
EP2454443A4 (en) 2018-04-25
PE20121296A1 (es) 2012-10-20
EP2454443A2 (en) 2012-05-23
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MX2012000753A (es) 2012-04-19
IL240267A0 (en) 2015-09-24
WO2011008834A3 (en) 2011-04-28
CA2768165A1 (en) 2011-01-20
BR112012001669A2 (pt) 2016-04-12
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AP2012006121A0 (en) 2012-02-29
IL240266A0 (en) 2015-09-24

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