EP2150677B1 - Rig storage system - Google Patents
Rig storage system Download PDFInfo
- Publication number
- EP2150677B1 EP2150677B1 EP08746558.9A EP08746558A EP2150677B1 EP 2150677 B1 EP2150677 B1 EP 2150677B1 EP 08746558 A EP08746558 A EP 08746558A EP 2150677 B1 EP2150677 B1 EP 2150677B1
- Authority
- EP
- European Patent Office
- Prior art keywords
- cuttings
- storage vessel
- cuttings storage
- vessel
- drilling rig
- 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.)
- Not-in-force
Links
- 238000003860 storage Methods 0.000 title claims description 165
- 238000005520 cutting process Methods 0.000 claims description 180
- 238000005553 drilling Methods 0.000 claims description 92
- 239000000463 material Substances 0.000 claims description 55
- 238000012546 transfer Methods 0.000 claims description 40
- 239000012530 fluid Substances 0.000 claims description 36
- 238000000034 method Methods 0.000 claims description 24
- 238000004891 communication Methods 0.000 claims description 4
- 238000009434 installation Methods 0.000 claims description 2
- 239000002002 slurry Substances 0.000 description 42
- 238000000227 grinding Methods 0.000 description 18
- 238000002347 injection Methods 0.000 description 18
- 239000007924 injection Substances 0.000 description 18
- 230000015572 biosynthetic process Effects 0.000 description 11
- 238000004140 cleaning Methods 0.000 description 11
- 239000002245 particle Substances 0.000 description 8
- 239000002699 waste material Substances 0.000 description 7
- 239000000203 mixture Substances 0.000 description 6
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 6
- 230000008569 process Effects 0.000 description 5
- 238000012545 processing Methods 0.000 description 5
- 239000000126 substance Substances 0.000 description 5
- 238000004064 recycling Methods 0.000 description 4
- 239000007787 solid Substances 0.000 description 4
- 230000007613 environmental effect Effects 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 238000000926 separation method Methods 0.000 description 3
- 239000000654 additive Substances 0.000 description 2
- 230000000712 assembly Effects 0.000 description 2
- 238000000429 assembly Methods 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 238000009826 distribution Methods 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 238000002360 preparation method Methods 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 239000000725 suspension Substances 0.000 description 2
- 230000009471 action Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000005336 cracking Methods 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- -1 dry cuttings Substances 0.000 description 1
- 238000001035 drying Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000007667 floating Methods 0.000 description 1
- 230000003311 flocculating effect Effects 0.000 description 1
- 238000009472 formulation Methods 0.000 description 1
- 239000000499 gel Substances 0.000 description 1
- 231100001261 hazardous Toxicity 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 239000010842 industrial wastewater Substances 0.000 description 1
- 230000010354 integration Effects 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 230000008520 organization Effects 0.000 description 1
- 239000000843 powder Substances 0.000 description 1
- 239000002994 raw material Substances 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000013535 sea water Substances 0.000 description 1
- 238000010008 shearing Methods 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 239000011343 solid material Substances 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 239000008400 supply water Substances 0.000 description 1
- 230000000930 thermomechanical effect Effects 0.000 description 1
- UONOETXJSWQNOL-UHFFFAOYSA-N tungsten carbide Chemical compound [W+]#[C-] UONOETXJSWQNOL-UHFFFAOYSA-N 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
- 238000003466 welding Methods 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/06—Arrangements for treating drilling fluids outside the borehole
- E21B21/063—Arrangements for treating drilling fluids outside the borehole by separating components
- E21B21/065—Separating solids from drilling fluids
- E21B21/066—Separating solids from drilling fluids with further treatment of the solids, e.g. for disposal
Definitions
- a drill bit In the drilling of wells, a drill bit is used to dig many thousands of feet into the earth's crust. Oil rigs typically employ a derrick that extends above the well drilling platform or deck. The derrick supports joint after joint of drill pipe connected end-to-end during the drilling operation. As the drill bit is pushed further into the earth, additional pipe joints are added to the ever lengthening "string" or "drill string". Therefore, the drill string typically includes a plurality of joints of pipe.
- Fluid "drilling mud” is pumped from the well drilling platform, through the drill string, and to a drill bit supported at the lower or distal end of the drill string.
- the drilling mud lubricates the drill bit and carries away well cuttings generated by the drill bit as it digs deeper.
- the cuttings are carried in a return flow stream of drilling mud through the well annulus and back to the well drilling platform at the earth's surface. When the drilling mud reaches the platform, it is contaminated with small pieces of shale and rock that are known in the industry as well cuttings or drill cuttings.
- a "shale shaker" is typically used to remove the drilling mud from the drill cuttings so that the drilling mud may be reused.
- the remaining drill cuttings, waste, and residual drilling mud are then transferred to a holding trough or vessel for disposal.
- the drill cuttings are typically stored in large tanks or vessels on the drilling rig platform. These vessels may be large in size, and therefore, may require large spaces on the drilling rig. In some situations, for example with specific types of drilling mud, the drilling mud may not be reused and it must also be disposed.
- the non-recycled drilling mud is disposed of separate from the drill cuttings and other waste by transporting the drilling mud via a vessel to a disposal site.
- Drill cuttings contain not only the residual drilling mud product that would contaminate the surrounding environment, but may also contain oil and other waste that is particularly hazardous to the environment, especially when drilling in a marine environment.
- Another method of disposal includes returning the drill cuttings, drilling mud, and/or other waste via injection under high pressure into an earth formation.
- the injection process involves preparation of a slurry within surface-based equipment and pumping the slurry into a well that extends relatively deep underground into a receiving stratum or adequate formation.
- Material to be injected back into a formation may be prepared into a slurry acceptable to high pressure pumps used in pumping material down a well.
- the particles are usually not uniform in size and density, thus making the slurrification process complex. If the slurry is not the correct density, the slurry often plugs circulating pumps. The abrasiveness of the material particles may also abrade or damage the pump impellers causing cracking.
- Some centrifugal pumps may be used for grinding the injection particles by purposely causing pump cavitations.
- the basic steps in the injection process include the identification of an appropriate stratum or formation for the injection; preparing an appropriate injection well; formulation of the slurry, which includes considering such factors as weight, solids content, pH, gels, etc.; performing the injection operations, which includes determining and monitoring pump rates such as volume per unit time and pressure; and capping the well.
- U.S. Patent No. 6,179,071 discloses that drill cuttings may be stored in a holding tank or multiple tanks on a drilling rig. The holding tank is then connected to a floating work boat with a discharge flow line. Cuttings may then be transferred to the boat via the flow line.
- This closest prior art document shows a system for storing cuttings comprising a drilling rig having a deck supported by two support structures, a cuttings storage vessel and a fluid supply line in fluid communication with the cuttings storage vessel.
- U.S. Patent No. 6,709,216 discloses that cuttings may also be conveyed to and stored in an enclosed, transportable vessel, where the vessel may then be transported to a destination, and the drill cuttings may be withdrawn therefrom.
- the transportable storage vessel has one or several lower conical sections structured to achieve mass flow of the material in the vessel, and withdrawal of the cuttings may include applying a compressed gas to the cuttings in the vessel.
- the transportable vessels are designed to fit within a 20 foot ISO (International Organization for Standardization) container frame. These conical vessels will be referred to herein as ISO-vessels.
- the ISO-vessels may be lifted onto a drilling rig by a rig crane and used to store cuttings.
- the vessels may then be used to transfer the cuttings onto a supply boat.
- the vessels may also serve as buffer storage while a supply boat is not present.
- the storage vessels may be lifted off the rig by cranes and transported by a supply boat.
- Modularized tank cleaning operations may include a water recycling unit of an automatic tank cleaning system, such as described in U.S. Patent Application Publication No. 20050205477 , assigned to the assignee of the present disclosure.
- cuttings containers may be offloaded from the rig to make room for environmental and/or drilling fluid recycling systems.
- Such systems may include a number of mixing, flocculating, and storage tanks to clean industrial wastewater produced during drilling or shipping operations. Examples of such environmental and drilling fluid recycling methods and systems are disclosed in U.S. Patent Nos. 6,881,349 and 6,977,048 , assigned to the assignee of the present disclosure.
- Slurrification systems that may be moved onto a rig are typically large modules that are fully self-contained, receiving cuttings from a drilling rig's fluid/mud recovery system.
- PCT Publication No. WO 99/04134 discloses a process module containing a first slurry tank, grinding pumps, a shale shaker, a second slurry tank, and an optional holding tank. The module may be lifted by a crane on to an offshore drilling platform.
- embodiments disclosed herein relate to a system for storing cuttings including a drilling rig having a deck and at least two support structures, and a least one cuttings storage vessel disposed in at least one of the at least two support structures.
- embodiments disclosed herein relate to a system for storing cuttings including a drilling rig having a deck and at least two support structures, and at least one pressurized vessel disposed in at least one of the at least two support structures, wherein the at least one pressurized vessel is configured to store a material.
- embodiments disclosed herein relate to a method of preparing a drilling rig for cuttings storage including disposing at least one cuttings storage vessel in at least one support structure of the drilling rig.
- the system 1002 for storing and transporting non-free flowing materials and/or free flowing material in accordance with embodiments disclosed herein includes at least one storage vessel 1004 disposed in at least one support structure 1006 of drilling rig 1000.
- Drilling rig 1000 may be an offshore drilling rig having a deck 1005 supported by at least two support structures 1006, or legs.
- the at least one support structure 1006 is coupled to at least one buoyant device 1008, for example, a pontoon.
- buoyant device 1008 for example, a pontoon.
- drilling rig 1000 may include three or four support structures supported by one or more buoyant devices 1008.
- At least one storage vessel 1004 may be constructed or installed in at least one support structure 1006 during fabrication or manufacture of the at least one support structure 1006.
- a support structure 1006 of a drilling rig 1000 may be retrofitted to include at least one storage vessel 1004.
- a hole may be cut in at least one support structure 1006, using any method known in the art.
- At least one storage vessel 1004 may be secured in the support structure 1006 and the cut section from the support structure 1006 may be sealed and welded back into place on the support structure 1006.
- the at least one storage vessel 1004 may be fixedly attached within at least one support structure 1006.
- fixedly attached refers to a substantially permanent connection by, for example, integrally forming or welding.
- the at least one storage vessel 1004 may be removably disposed in at least one support structure 1006.
- storage vessel 1004 may be bolted, locked, or screwed into place within the at least one support structure 1006.
- the at least one storage vessel 1004 may be disposed in at least one support structure 1006 less than 15.24m (50 ft.) above sea level.
- 15.24m 50 ft.
- the location of the at least one storage vessel 1004 above sea level may vary depending on, for example, the particular drilling rig 1000 being used, drilling equipment used, or manufacturing limitations, without departing from the scope of the embodiments disclosed herein.
- only one support structure 1006 may contain at least one storage vessel 1004 storing a material therein. Additionally, in certain embodiments, more than one support structure 1006 may contain at least one storage vessel 1004, but only one or less than all of the storage vessels 1004 may contain a material. In such embodiments, the stored material may add additional weight to a given side or area of drilling rig 1000. However, fluid may be filled into at least one support structure 1006, as known in the art, to counteract or ballast any weight imbalances due to the distribution of stored material in the storage vessels 1004 disposed in at least one support structure 1006. Additionally, disposing the storage vessels 1004 proximate sea level, as discussed above, may also assist in stabilizing and/or reducing the effect of any imbalanced material weight distribution of drilling rig 1000.
- material stored in at least one storage vessel 1004 disposed in at least one support structure 1006 may be transferred or conveyed to an offsite location.
- a least one discharge line 1016 may be operatively connected to an outlet (not shown) of storage vessel 1004.
- a distal end 1020 of discharge line 1016 may be operatively connected to a transport vessel (not shown) disposed on a transport vehicle (not shown), for example, a boat or barge.
- material stored in a first storage vessel 1001a disposed in at least one support structure 1006a may be conveyed via conduit 1003 to a second storage vessel 1001b disposed in the same support structure 1006a.
- the at least one storage vessel 1004 may be pressurized.
- a pressurized storage vessel 1004 may store non-free flowing material, for example, cuttings.
- a pneumatic transfer device (not shown) may be coupled to the at least one storage vessel 1004.
- Pneumatic transfer device may include, for example, a cuttings blower (not shown) and pneumatic transfer lines (now shown), such as disclosed in U.S. Patent Nos. 6,698,989 , 6,702,539 , and 6,709,206 .
- other methods for transferring cuttings to storage vessels 1004 may include augers, conveyors, vacuum suction, and pneumatic blower systems.
- Cuttings stored in storage vessels 1004 in at least one support structure 1006 may be conveyed from the storage vessel 1004 to an offsite location.
- One or more discharge lines 1016 may be coupled to one or more storage vessels 1004 to provide for conveyance of the cuttings from storage vessel 1004 to a transport vehicle (not shown).
- storage vessel 1004 may be pressurized and/or may be operatively coupled to a pneumatic transfer device to transfer the cuttings through an outlet of the storage vessel 1004.
- cuttings may be transferred from the at least one storage vessel 1004 to a transport vessel (not shown) on a transport vehicle (not shown).
- cuttings may be transferred from first storage vessel (1001a in Figure 1B ) to second storage vessel (1001b in Figure 1B ) via conduit (1003 in Figure 1B ).
- two discrete streams of materials may be transferred contemporaneously (i.e., at least partially during the same time interval) to a transport vehicle, for example, a supply boat 5.
- a first supply line 20 may transfer a first material from at least a first storage vessel 21 disposed in at least one support structure 1006 of drilling rig (not shown) to supply boat 5, and a second supply line 22 may transfer a second material from at least a second storage vessel 23 disposed in the at least one support structure 1006 to supply boat 5.
- the first and second materials may also be transferred to a cuttings storage assembly 25 disposed on supply boat 5.
- the first and second materials may be transferred to separate storage vessels; for example the first and/or second material may be transferred to a storage tank (not shown) disposed on or below the deck of supply boat 5.
- the first material may include dry cuttings
- the second material may include a fluid.
- a fluid may include a liquid, slurry, or gelatinous material.
- dry cuttings may include cuttings processed by a separatory or cleaning system, like mechanical and/or thermal processing, such as Thermomechanical Cuttings Cleaner (TCC), commercially available from Thermtech (Bergen, Norway), and VERTI-G TM Dryer, commercially available from M-I LLC (Houston, TX).
- TCC Thermomechanical Cuttings Cleaner
- VERTI-G TM Dryer commercially available from M-I LLC (Houston, TX).
- cuttings may include small amounts of residual fluids, hydrocarbons, and/or other chemical additives used during the cleaning process.
- cuttings storage assembly 25 may include at least one cuttings storage vessel 27.
- the first material and the second material may be transferred to a single cuttings storage vessel 27 of cuttings storage assembly 25.
- the first material and the second material may be transferred to separate cuttings storage vessels 27 of cuttings storage assembly 25.
- a cutting storage vessel 27 disposed on the supply boat 5 may be used in a slurrification system, as disclosed below with reference to cuttings storage vessels disposed on a rig.
- a module (not shown) may be operatively connected to the cuttings storage assembly 25 to incorporate existing cuttings storage vessels 27 into a slurrification system.
- embodiments disclosed herein use storage vessels in two or more operations that are performed on a drilling rig.
- embodiments disclosed herein relate to operating a vessel in at least two operations performed on a rig.
- embodiments disclosed herein relate to using a vessel in both cuttings storage/transfer operations and a second operation. More specifically, embodiments disclosed herein relate to using a cuttings storage vessel as a cuttings storage/transfer vessel and as a component in a slurrification system, such as that disclosed in co-pending U.S. Patent Application Serial No. 60/887,442 .
- storage vessels and vessel assemblies in each of these additional systems will be described below. Additionally, modules that may integrate these vessels and vessel assemblies into more than one additional system will also be discussed.
- storage vessels as described in embodiments disclosed herein may also be used in recycling systems, such as those disclosed in co-pending Application Serial No. 60/887,444 , tank cleaning systems, such as those disclosed in co-pending Application Serial No. 60/887,509 , in-transit slurrification systems, such as those disclosed in co-pending Application Serial No. 60/887,449 , and cuttings processing systems, such as those disclosed in co-pending Application Serial No. 60/887,514 .
- Cuttings transfer systems and slurrification systems are typically independent systems, where the systems may be located on rig 40 permanently or may be transferred to rig 40 from supply boat 46 when such operations are required.
- system module 42 may be located on rig 40 proximate cuttings storage vessels 43, and transfer lines 44 may be connected therebetween to enable use of the cuttings storage vessels 43 with tanks, pumps, grinding pumps, chemical addition devices, cleaning equipment, water supply tanks, filter systems, and other components that may be used in other operations performed at a drilling location, including slurrification of drill cuttings.
- Such integrated systems may allow for existing single use structures (e.g., cuttings storage vessels 43) to be used in multiple operations (e.g., slurrification systems and cuttings storage/transfer).
- vessels 43 may be operated in a tank a slurrification system.
- Module 352 includes an inlet connection 370 configured to connect with outlet 372 of first cuttings storage vessel 302, and an outlet connection 374 configured to connect with an inlet 376 of first cuttings storage vessel 302.
- Inlet connection 370 may be connected to outlet 372 and outlet connection 374 may be connected to inlet 376 by fluid transfer lines, for example, flexible hoses and/or new or existing piping.
- Module 352 further includes a grinding device 354 configured to facilitate the transfer of fluids from the first cuttings storage vessel 302, through the module 352, and back to the first cuttings storage vessel 302. Grinding device 354 is configured to reduce the particle size of solid materials of the drill cuttings transferred therethrough.
- slurrification system 300 further includes a second cuttings storage vessel 390 disposed in the support structure (not shown) of the drilling rig (not shown). Second cuttings storage vessel 390 may be configured to supply cuttings to first cuttings storage vessel 302.
- a pump (not shown), as known in the art, may be used to transfer the cuttings.
- a pneumatic transfer device (not shown), as disclosed above, may be used to transfer the cuttings to the first cuttings storage vessel 302.
- any method for transferring the cuttings to first storage vessel 302 may be used without departing from the scope of embodiments disclosed herein.
- cuttings may be supplied to first cuttings storage vessel 302 from a classifying shaker (not shown) or other cuttings separation or cleaning systems disposed on the drilling rig.
- multiple cuttings storage vessels disposed in the support structure of the drilling rig may be connected to and supply cuttings to first cuttings storage vessel 302.
- each cuttings storage vessel may be configured to supply cuttings of predetermined sizes, for example, coarse cuttings or fines. Cuttings of a selected size may then be provided to first cuttings storage vessel 302 to form a slurry of a predetermined density.
- the cuttings may be transferred to the first cuttings storage vessel 302 by any means known in the art, for example, by a pump or a pneumatic transfer device, as described above.
- fluid supply line 378 may be configured to supply a fluid to first cuttings storage vessel 302.
- the fluid supply line 378 may supply water, sea water, a brine solution, chemical additives, or other fluids known in the art for preparing a slurry of drill cuttings.
- cuttings from the second cuttings storage vessel 390, or other components of the rig's cuttings separation system, as described above, may be transferred into first cuttings storage vessel 302.
- the mixture of fluid and cuttings is transferred to module 352 through the inlet connection 370 of the module 352.
- the mixture may be transferred by a pneumatic transfer device, a vacuum system, a pump, or any other means known in the art.
- the pneumatic transfer device may include a forced flow pneumatic transfer system.
- the mixture of fluid and cuttings is pumped through grinding device 354, wherein the cuttings are reduced in size.
- the mixture, or slurry is then pumped back down to first cuttings storage vessel 302 via outlet connection 374.
- the slurry may cycle back through module 352 one or more times as needed to produce a slurry of a predetermined density or concentration of cuttings as required for the particular application or re-injection formation.
- module 652 further includes a valve 694 disposed downstream of grinding device 654, wherein valve 694 is configured to redirect the flow of the slurry exiting the grinding device 654.
- a PLC 661 may be operatively coupled to module 652 and configured to close or open the valve 694, thereby redirecting the flow of the slurry.
- the PLC 695 may control the valve 694 to move after a pre-determined amount of time of fluid transfer through module 652.
- a sensor (not shown) may be operatively coupled to the valve 694 to open or close the valve when a pre-determined condition of the slurry is met.
- a density sensor (not shown) may be coupled to valve 694, such that, when the density of the slurry exiting grinding device 654 reaches a pre-determined value, valve 694 moves, i.e., opens or closes, and redirects the flow of the slurry from the first cuttings storage vessel 302 to another cuttings storage vessel, a slurry tank, a skip, or injection pump for injection into a formation.
- a conductivity sensor (not shown) may be coupled to valve 694, such that, when the density of the slurry exiting grinding device 654 reaches a pre-determined value, valve 694 moves and redirects the flow of the slurry from the first cuttings storage vessel 302 to another cuttings storage vessel, a slurry tank, a skip, or injection pump for injection into a formation.
- valve 694 moves and redirects the flow of the slurry from the first cuttings storage vessel 302 to another cuttings storage vessel, a slurry tank, a skip, or injection pump for injection into a formation.
- a conductivity sensor may be coupled to valve 694, such that, when the density of the slurry exiting grinding device 654 reaches a pre-determined value, valve 694 moves and redirects the flow of the slurry from the first cuttings storage vessel 302 to another cuttings storage vessel, a slurry tank, a skip, or injection pump for injection into a formation.
- a conductivity sensor may be coupled to valve 694,
- a slurry formed by a slurrification system may be transferred to another cuttings storage vessel, a slurry tank, a skip, or directly injected into a formation.
- Slurry that is transferred to a tank, vessel, skip, or other storage device may be transferred off-site to another work site.
- the storage device may be lifted off of a rig by a crane and transferred to a boat.
- slurry may be transferred via a hose, tubing, or other conduit, from the storage vessel dispose in the at least one leg of the drilling rig to a slurry tank disposed on the boat.
- the slurry may be transported from one work site to another work site for re-injection.
- the slurry may be transported from an offshore rig to another offshore rig.
- the slurry may be transported from an offshore rig to an on-land work site. Further the slurry may be transported from an on-land work site to an offshore work site.
- components of systems 300, 500, and 600 may be interchanged, interconnected, and otherwise assembled in a slurrification system.
- the components of the systems and modules disclosed herein may provide for an interchangeable and adaptable system for slurrification at a drilling location.
- embodiments disclosed herein may provide a materials storage and transport system that reduces the amount of required space on a drilling rig.
- embodiments disclosed herein may provide a method of transferring stored materials to an offsite location.
- embodiments disclosed herein may provide a storage and transport system for cuttings that reduces the amount of required space on a drilling rig.
- embodiments disclosed herein may advantageously provide a slurrification system that reduces the amount of required space at a work site to operate the slurrification system.
- embodiments disclosed herein may provide a slurrification system that reduces the amount of equipment or number of components required to prepare slurries for re-injection into a formation.
- embodiments disclosed herein may provide a safer slurrification system by reducing the number of crane lifts required to install the system.
- embodiments disclosed herein may also provide for systems and methods that more efficiently store and transport non-free flowing and free flowing materials on a drilling rig. Because offshore platform space is often limited, and crane operations to transfer large storage tanks or containers are often expensive and dangerous, embodiments of the present disclosure may decrease the cost of drilling operations by decreasing the number of crane lifts.
Landscapes
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Mechanical Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
- Packages (AREA)
- Underground Structures, Protecting, Testing And Restoring Foundations (AREA)
Description
- Embodiments disclosed herein relate generally to a vessel used for storing and transporting materials on a drilling rig. More specifically, embodiments disclosed herein relate to use of a vessel for cuttings storage and/or transport.
- In the drilling of wells, a drill bit is used to dig many thousands of feet into the earth's crust. Oil rigs typically employ a derrick that extends above the well drilling platform or deck. The derrick supports joint after joint of drill pipe connected end-to-end during the drilling operation. As the drill bit is pushed further into the earth, additional pipe joints are added to the ever lengthening "string" or "drill string". Therefore, the drill string typically includes a plurality of joints of pipe.
- Fluid "drilling mud" is pumped from the well drilling platform, through the drill string, and to a drill bit supported at the lower or distal end of the drill string. The drilling mud lubricates the drill bit and carries away well cuttings generated by the drill bit as it digs deeper. The cuttings are carried in a return flow stream of drilling mud through the well annulus and back to the well drilling platform at the earth's surface. When the drilling mud reaches the platform, it is contaminated with small pieces of shale and rock that are known in the industry as well cuttings or drill cuttings. Once the drill cuttings, drilling mud, and other waste reach the platform, a "shale shaker" is typically used to remove the drilling mud from the drill cuttings so that the drilling mud may be reused. The remaining drill cuttings, waste, and residual drilling mud are then transferred to a holding trough or vessel for disposal. The drill cuttings are typically stored in large tanks or vessels on the drilling rig platform. These vessels may be large in size, and therefore, may require large spaces on the drilling rig. In some situations, for example with specific types of drilling mud, the drilling mud may not be reused and it must also be disposed. Typically, the non-recycled drilling mud is disposed of separate from the drill cuttings and other waste by transporting the drilling mud via a vessel to a disposal site.
- The disposal of the drill cuttings and drilling mud is a complex environmental problem. Drill cuttings contain not only the residual drilling mud product that would contaminate the surrounding environment, but may also contain oil and other waste that is particularly hazardous to the environment, especially when drilling in a marine environment.
- In the Gulf of Mexico, for example, there are hundreds of drilling platforms that drill for oil and gas by drilling into the subsea floor. These drilling platforms may be used in places where the depth of the water may be many hundreds of feet. In such a marine environment, the water is typically filled with marine life that cannot tolerate the disposal of drill cuttings and other waste. Therefore, there is a need for a simple, yet workable solution to the problem of disposing of well drill cuttings, drilling mud, and/or other waste in offshore marine and other fragile environments.
- Traditional methods of disposal include dumping, bucket transport, cumbersome conveyor belts, screw conveyors, and washing techniques that require large amounts of water. Adding water creates additional problems such as added volume, bulk, and transportation. Installing conveyors requires major modification to the rig area and involves extensive installation hours and expense.
- Another method of disposal includes returning the drill cuttings, drilling mud, and/or other waste via injection under high pressure into an earth formation. Generally, the injection process involves preparation of a slurry within surface-based equipment and pumping the slurry into a well that extends relatively deep underground into a receiving stratum or adequate formation. Material to be injected back into a formation may be prepared into a slurry acceptable to high pressure pumps used in pumping material down a well. The particles are usually not uniform in size and density, thus making the slurrification process complex. If the slurry is not the correct density, the slurry often plugs circulating pumps. The abrasiveness of the material particles may also abrade or damage the pump impellers causing cracking. Some centrifugal pumps may be used for grinding the injection particles by purposely causing pump cavitations.
- The basic steps in the injection process include the identification of an appropriate stratum or formation for the injection; preparing an appropriate injection well; formulation of the slurry, which includes considering such factors as weight, solids content, pH, gels, etc.; performing the injection operations, which includes determining and monitoring pump rates such as volume per unit time and pressure; and capping the well.
- In some instances, the cuttings, which are still contaminated with some oil, are transported from a drilling rig to an offshore rig or ashore in the form of a thick heavy paste for injection into an earth formation. Typically, the material is transferred into special skips of about 10 ton capacity which are loaded by crane from the rig onto supply boats. This is a difficult and dangerous operation that may be laborious and expensive.
-
U.S. Patent No. 6,179,071 discloses that drill cuttings may be stored in a holding tank or multiple tanks on a drilling rig. The holding tank is then connected to a floating work boat with a discharge flow line. Cuttings may then be transferred to the boat via the flow line. This closest prior art document shows a system for storing cuttings comprising a drilling rig having a deck supported by two support structures, a cuttings storage vessel and a fluid supply line in fluid communication with the cuttings storage vessel. -
U.S. Patent No. 6,709,216 , and related patent family members, disclose that cuttings may also be conveyed to and stored in an enclosed, transportable vessel, where the vessel may then be transported to a destination, and the drill cuttings may be withdrawn therefrom. The transportable storage vessel has one or several lower conical sections structured to achieve mass flow of the material in the vessel, and withdrawal of the cuttings may include applying a compressed gas to the cuttings in the vessel. The transportable vessels are designed to fit within a 20 foot ISO (International Organization for Standardization) container frame. These conical vessels will be referred to herein as ISO-vessels. - As described in
U.S. Patent No. 6,709,216 and family, the ISO-vessels may be lifted onto a drilling rig by a rig crane and used to store cuttings. The vessels may then be used to transfer the cuttings onto a supply boat. The vessels may also serve as buffer storage while a supply boat is not present. Alternatively, the storage vessels may be lifted off the rig by cranes and transported by a supply boat. - Space on offshore platforms is limited. In addition to the storage and transfer of cuttings, many additional operations take place on a drilling rig, including tank cleaning, slurrification operations, drilling, chemical treatment operations, raw material storage, mud preparation, mud recycle, mud separations, and many others.
- Due to the limited space, it is common to modularize these operations and to swap out modules when not needed or when space is needed for the equipment. For example, cuttings containers may be offloaded from the rig to make room for modularized equipment used for tank cleaning operations. Modularized tank cleaning operations may include a water recycling unit of an automatic tank cleaning system, such as described in
U.S. Patent Application Publication No. 20050205477 , assigned to the assignee of the present disclosure. - In other drilling operations, cuttings containers may be offloaded from the rig to make room for environmental and/or drilling fluid recycling systems. Such systems may include a number of mixing, flocculating, and storage tanks to clean industrial wastewater produced during drilling or shipping operations. Examples of such environmental and drilling fluid recycling methods and systems are disclosed in
U.S. Patent Nos. 6,881,349 and6,977,048 , assigned to the assignee of the present disclosure. - Slurrification systems that may be moved onto a rig are typically large modules that are fully self-contained, receiving cuttings from a drilling rig's fluid/mud recovery system. For example,
PCT Publication No. WO 99/04134 - The lifting operations required to swap modular systems, as mentioned above, may be difficult, dangerous, and expensive. Additionally, many of these modularized operations are self-contained, and therefore include redundant equipment, such as pumps, valves, and tanks or storage vessels.
- There exists a need for more efficient use of deck space and equipment. Additionally, there exists a need to minimize the number or size of lifts to or from a rig. Accordingly, there is a continuing need for systems and methods for efficiently storing and transporting materials, including free flowing materials and non-free flowing materials.
- In one aspect, embodiments disclosed herein relate to a system for storing cuttings including a drilling rig having a deck and at least two support structures, and a least one cuttings storage vessel disposed in at least one of the at least two support structures.
- In another aspect, embodiments disclosed herein relate to a system for storing cuttings including a drilling rig having a deck and at least two support structures, and at least one pressurized vessel disposed in at least one of the at least two support structures, wherein the at least one pressurized vessel is configured to store a material.
- In another aspect, embodiments disclosed herein relate to a method of storing cuttings on a drilling rig including transferring materials from a deck of the drilling rig to a pressurized vessel disposed in a support structure of the drilling rig.
- In another aspect, embodiments disclosed herein relate to a method of preparing a drilling rig for cuttings storage including disposing at least one cuttings storage vessel in at least one support structure of the drilling rig.
- Other aspects and advantages of the invention will be apparent from the following description and the appended claims.
-
-
Figure 1A is a front view of a drilling rig in accordance with embodiments disclosed herein. -
Figure 1B is a cross-sectional view of a support structure of a drilling rig in accordance with embodiments disclosed herein. -
Figure 1C is a perspective view of a storage vessel in accordance with embodiments disclosed herein. -
Figure 1D is a partial perspective view of a storage vessel in accordance with embodiments disclosed herein. -
Figure 2 shows a top view of a system for transferring material from an off-shore rig in accordance with an embodiment of the present disclosure. -
Figure 3 is a side view of a system illustrating use of cuttings storage vessels in a cuttings storage/transfer system and in a module-based system fluidly connected to the cuttings storage vessels in accordance with an embodiment of the present disclosure. -
Figure 4 shows a slurrification system in accordance with embodiments of the present disclosure. -
Figure 5 shows a grinding device in accordance with embodiments of the present disclosure. -
Figure 6 shows a slurrification system in accordance with embodiments of the present disclosure. -
Figure 7 shows a slurrification system in accordance with embodiments of the present disclosure. - In one aspect, embodiments disclosed herein relate to systems and methods for storing and transporting non-free flowing materials, including drill cuttings, and free flowing materials. Drilling locations may include both on-shore and off-shore drill sites, such as drilling rigs, platforms, drill-ships, drilling barges, and the like. In other aspects, embodiments relate to using pressurized vessels for storage and transportation combined with drill cuttings slurrification, cuttings processing (mechanical and thermal drying), tank cleaning, and fluid processing systems.
-
Figure 1A shows adrilling rig 1000 in accordance with embodiments disclosed herein. In particular,drilling rig 1000 includes a system 1002 for storing and transporting non-free flowing and/or free flowing materials. As used herein, non-free flowing materials refer to materials that do not readily flow from a container, for example, cuttings, powders, and dry materials. As used herein, free flowing materials refer to materials that may readily flow from a container, for example, proppants, chemicals, and liquids. In some embodiments a mixture of non-free flowing and free-flowing materials, for example, a slurry, may be stored in the system 1002 ofdrilling rig 1000. - As shown in
Figure 1A , the system 1002 for storing and transporting non-free flowing materials and/or free flowing material in accordance with embodiments disclosed herein includes at least onestorage vessel 1004 disposed in at least onesupport structure 1006 ofdrilling rig 1000.Drilling rig 1000 may be an offshore drilling rig having adeck 1005 supported by at least twosupport structures 1006, or legs. The at least onesupport structure 1006 is coupled to at least onebuoyant device 1008, for example, a pontoon. One of ordinary skill in the art will appreciate that any number ofsupport structures 1006 orbuoyant devices 1008 may be used without departing from the scope of embodiments disclosed herein. For example, in one embodiment,drilling rig 1000 may include three or four support structures supported by one or morebuoyant devices 1008. - In one embodiment, at least one
storage vessel 1004 may be constructed or installed in at least onesupport structure 1006 during fabrication or manufacture of the at least onesupport structure 1006. Alternatively, asupport structure 1006 of adrilling rig 1000 may be retrofitted to include at least onestorage vessel 1004. For example, in one embodiment, a hole may be cut in at least onesupport structure 1006, using any method known in the art. At least onestorage vessel 1004 may be secured in thesupport structure 1006 and the cut section from thesupport structure 1006 may be sealed and welded back into place on thesupport structure 1006. In one embodiment, the at least onestorage vessel 1004 may be fixedly attached within at least onesupport structure 1006. As used herein, fixedly attached refers to a substantially permanent connection by, for example, integrally forming or welding. In alternate embodiments, the at least onestorage vessel 1004 may be removably disposed in at least onesupport structure 1006. For example,storage vessel 1004 may be bolted, locked, or screwed into place within the at least onesupport structure 1006. - In one embodiment, at least one
storage vessel 1004 may be disposed in at least onesupport structure 1006 above sea level. In accordance with certain embodiments, at least onestorage vessel 1004 may be disposed in at least onesupport structure 1006 proximate sea level. Typically, adrilling rig deck 1005 may be disposed approximately 65 to 100 feet (20-30m) above sea level. Thus, in some embodiments, the at least onestorage vessel 1004 may be disposed in at least onesupport structure 1006 less than 4.57m (15 ft.) above sea level. In another embodiment, the at least onestorage vessel 1004 may be disposed in at least onesupport structure 1006 less than 9.14m (30 ft.) above sea level. In yet other embodiments, the at least onestorage vessel 1004 may be disposed in at least onesupport structure 1006 less than 15.24m (50 ft.) above sea level. One of ordinary skill in the art will appreciate that the location of the at least onestorage vessel 1004 above sea level may vary depending on, for example, theparticular drilling rig 1000 being used, drilling equipment used, or manufacturing limitations, without departing from the scope of the embodiments disclosed herein. - As described above, in certain embodiments, only one
support structure 1006 may contain at least onestorage vessel 1004 storing a material therein. Additionally, in certain embodiments, more than onesupport structure 1006 may contain at least onestorage vessel 1004, but only one or less than all of thestorage vessels 1004 may contain a material. In such embodiments, the stored material may add additional weight to a given side or area ofdrilling rig 1000. However, fluid may be filled into at least onesupport structure 1006, as known in the art, to counteract or ballast any weight imbalances due to the distribution of stored material in thestorage vessels 1004 disposed in at least onesupport structure 1006. Additionally, disposing thestorage vessels 1004 proximate sea level, as discussed above, may also assist in stabilizing and/or reducing the effect of any imbalanced material weight distribution ofdrilling rig 1000. - As shown in
Figure 1B , in one embodiment, a plurality ofstorage vessels 1004a may be disposed in at least onesupport structure 1006a in a circular configuration. In such an embodiment, a staircase, conduit, or other equipment may be disposed in the space formed 1010 in the center of the circular configuration. Thus, the plurality ofstorage vessels 1004a may be arranged within the at least onesupport structure 1006a in a manner most convenient for the construction, modification, and use ofsupport structure 1006a. For example, the plurality ofstorage vessels 1004a, disposed in the at least onesupport structure 1006a, may be arranged in a grouping towards the center of support structure, in a square configuration, opposite one another, or stacked on top of one another. Those of ordinary skill in the art will appreciate that the configuration of the plurality ofstorage vessels 1004a may vary without departing from the scope of embodiments disclosed herein. - Referring now to
Figure 1C , in some embodiments, the at least onestorage vessel 1004 has an angledlower section 1012 structured to achieve mass flow of the material in thestorage vessel 1004. In one embodiment, angledlower section 1012 includes one conical angle. These conical vessels may be referred to as ISO-vessels. Exemplary ISO-vessels is an ISO-pump® commercially available from M-I, LLC (Houston, TX). In alternate embodiments, as shown inFigure 1D , the angledlower section 1012 of the at least onestorage vessel 1004 has a plurality ofangled structures 1014, forming, for example, a honeycomb structure, as disclosed in PCT PublicationWO 2007/034215 A1 . - Referring generally to
Figure 1A , in one embodiment, material stored in at least onestorage vessel 1004 disposed in at least onesupport structure 1006 may be transferred or conveyed to an offsite location. In this embodiment, a least one discharge line 1016 may be operatively connected to an outlet (not shown) ofstorage vessel 1004. Adistal end 1020 of discharge line 1016 may be operatively connected to a transport vessel (not shown) disposed on a transport vehicle (not shown), for example, a boat or barge. In some embodiments, as shown inFigure 1B , material stored in a first storage vessel 1001a disposed in at least onesupport structure 1006a may be conveyed viaconduit 1003 to a second storage vessel 1001b disposed in thesame support structure 1006a. - To facilitate the transfer of material from a
storage vessel 1004 to a transport vessel or between storage vessels 1004 (1001a, 1001b), in one embodiment, the at least onestorage vessel 1004 may be pressurized. In such an embodiment, apressurized storage vessel 1004 may store non-free flowing material, for example, cuttings. In this embodiment, a pneumatic transfer device (not shown) may be coupled to the at least onestorage vessel 1004. Pneumatic transfer device may include, for example, a cuttings blower (not shown) and pneumatic transfer lines (now shown), such as disclosed inU.S. Patent Nos. 6,698,989 ,6,702,539 , and6,709,206 . However, those of ordinary skill in the art will appreciate that other methods for transferring cuttings tostorage vessels 1004 may include augers, conveyors, vacuum suction, and pneumatic blower systems. - Still referring to
Figure 1A , in one embodiment, the at least onestorage vessel 1004 disposed in at least onesupport structure 1006 ofdrilling rig 1000 may store cuttings. In this embodiment, a pneumatic transfer device (not shown) may be operatively coupled to the at least one storage vessel. For example, a cuttings blower (not shown) may be disposed on thedeck 1005 ofdrilling rig 1000 and configured to blow cuttings from, for example, a separatory device (not shown) disposed on thedeck 1005, into at least onestorage vessel 1004 disposed in the at least onesupport structure 1006. Thus, by placing thestorage vessel 1004 in the at least onesupport structure 1006 ofdrilling rig 1000, more space may be made available for other equipment and/or operations on thedeck 1005. - Cuttings stored in
storage vessels 1004 in at least onesupport structure 1006 may be conveyed from thestorage vessel 1004 to an offsite location. One or more discharge lines 1016 may be coupled to one ormore storage vessels 1004 to provide for conveyance of the cuttings fromstorage vessel 1004 to a transport vehicle (not shown). In this embodiment,storage vessel 1004 may be pressurized and/or may be operatively coupled to a pneumatic transfer device to transfer the cuttings through an outlet of thestorage vessel 1004. In one embodiment, cuttings may be transferred from the at least onestorage vessel 1004 to a transport vessel (not shown) on a transport vehicle (not shown). In another embodiment, cuttings may be transferred from first storage vessel (1001a inFigure 1B ) to second storage vessel (1001b inFigure 1B ) via conduit (1003 inFigure 1B ). - In one embodiment, as shown in
Figure 2 , two discrete streams of materials may be transferred contemporaneously (i.e., at least partially during the same time interval) to a transport vehicle, for example, asupply boat 5. In this embodiment, a first supply line 20 may transfer a first material from at least a first storage vessel 21 disposed in at least onesupport structure 1006 of drilling rig (not shown) to supplyboat 5, and a second supply line 22 may transfer a second material from at least asecond storage vessel 23 disposed in the at least onesupport structure 1006 to supplyboat 5. The first and second materials may also be transferred to acuttings storage assembly 25 disposed onsupply boat 5. Alternatively, the first and second materials may be transferred to separate storage vessels; for example the first and/or second material may be transferred to a storage tank (not shown) disposed on or below the deck ofsupply boat 5. - In one embodiment, the first material may include dry cuttings, while the second material may include a fluid. One of ordinary skill in the art will appreciate that a fluid may include a liquid, slurry, or gelatinous material. Additionally, one of ordinary skill in the art will appreciate that dry cuttings may include cuttings processed by a separatory or cleaning system, like mechanical and/or thermal processing, such as Thermomechanical Cuttings Cleaner (TCC), commercially available from Thermtech (Bergen, Norway), and VERTI-G™ Dryer, commercially available from M-I LLC (Houston, TX). As such, cuttings may include small amounts of residual fluids, hydrocarbons, and/or other chemical additives used during the cleaning process. Pumps (not shown) may be coupled to the
storage vessels 21, 23 to facilitate the transfer of material, including, for example, dry cuttings, a fluid, or a slurry, from a separatory or cleaning operation on the rig to supplyboat 5. Alternatively, a pneumatic transfer system 26 may be coupled to thestorage vessels 21, 23 to transfer materials, including dry cuttings, fluids, and slurries, to thesupply boat 5. In one embodiment, the pneumatic transfer system 26 may include a forced flow pneumatic transfer system as disclosed inU.S. Patent Nos. 6,698,989 ,6,702,539 , and6,709,216 . Providing contemporaneous transfer of discrete material streams (e.g., dry cuttings, fluids), may reduce the transportation time between a rig and a transport vehicle, such as,supply boat 5. - In one embodiment,
cuttings storage assembly 25 may include at least onecuttings storage vessel 27. As such, the first material and the second material may be transferred to a singlecuttings storage vessel 27 ofcuttings storage assembly 25. In another embodiment, the first material and the second material may be transferred to separatecuttings storage vessels 27 ofcuttings storage assembly 25. In one embodiment, a cuttingstorage vessel 27 disposed on thesupply boat 5 may be used in a slurrification system, as disclosed below with reference to cuttings storage vessels disposed on a rig. In this embodiment, briefly, a module (not shown) may be operatively connected to thecuttings storage assembly 25 to incorporate existingcuttings storage vessels 27 into a slurrification system. - In contrast to the prior art methods, embodiments disclosed herein use storage vessels in two or more operations that are performed on a drilling rig. In one aspect, embodiments disclosed herein relate to operating a vessel in at least two operations performed on a rig. In some aspects, embodiments disclosed herein relate to using a vessel in both cuttings storage/transfer operations and a second operation. More specifically, embodiments disclosed herein relate to using a cuttings storage vessel as a cuttings storage/transfer vessel and as a component in a slurrification system, such as that disclosed in co-pending
U.S. Patent Application Serial No. 60/887,442 . - Use of storage vessels and vessel assemblies in each of these additional systems will be described below. Additionally, modules that may integrate these vessels and vessel assemblies into more than one additional system will also be discussed. One of ordinary skill in the art will appreciate that storage vessels as described in embodiments disclosed herein may also be used in recycling systems, such as those disclosed in co-pending Application Serial No.
60/887,444 60/887,509 60/887,449 60/887,514 - Referring back to
Figure 1A ,storage vessels 1004 disposed within at least onesupport structure 1006 ofdrilling rig 1000 may be used in other systems/operations typically performed on thedeck 1005. For example,storage vessels 1004 may be used in a slurrification system as described in further detail below. In this embodiment, cuttings disposed in at least onestorage vessel 1004 may be combined with a fluid provided by a fluid supply line (not shown) in fluid communication with the at least onestorage vessel 1004. - Referring now to
Figure 3 , a rig 40, including asystem module 42 according to embodiments of the present disclosure, is shown.System module 42 may be located anywhere on rig 40, and in some embodiments is located proximate at least onecuttings storage vessel 43, or a vessel assembly, disposed in at least onesupport structure 41, that may be fluidly connected tosystem module 42 via connection lines 44.Cuttings storage vessels 43 may be detachably connected to a second set ofstorage vessels 45 located on asupply boat 46 by aflexible hose 47.System module 42 may include a slurrification system module. - In operation, cuttings may be transferred to
cuttings storage vessels 43 via one or morepneumatic transfer devices 48 located on rig 40. The cuttings may be stored incuttings storage vessels 43 until they are transferred to supplyboat 46 for disposal thereafter. - Cuttings transfer systems and slurrification systems, as described above, are typically independent systems, where the systems may be located on rig 40 permanently or may be transferred to rig 40 from
supply boat 46 when such operations are required. However, in embodiments disclosed herein,system module 42 may be located on rig 40 proximatecuttings storage vessels 43, andtransfer lines 44 may be connected therebetween to enable use of thecuttings storage vessels 43 with tanks, pumps, grinding pumps, chemical addition devices, cleaning equipment, water supply tanks, filter systems, and other components that may be used in other operations performed at a drilling location, including slurrification of drill cuttings. Such integrated systems may allow for existing single use structures (e.g., cuttings storage vessels 43) to be used in multiple operations (e.g., slurrification systems and cuttings storage/transfer). Thus, when not being used to store or transport cuttings,vessels 43 may be operated in a tank a slurrification system. - Integration of a cuttings storage vessel into a slurrification system is now described with respect to cuttings storage vessel(s) disposed in at least one support structure of a drilling rig. In this embodiment a module may be disposed at the work site proximate the cuttings storage vessel and operatively connected to the cuttings storage vessel, thereby converting the cuttings storage vessel from a vessel for storing cuttings to a component of a slurrification system.
- As described above, previous fluid slurrification systems required the conversion of valuable drilling rig space for storing independent fluid recovery vessels and processing equipment. However, embodiments disclosed herein allow existing structural elements (i.e., cuttings storage vessels) to be used in multiple operations. Modules in accordance with embodiments disclosed herein are relatively small compared to previous systems, thereby preserving valuable drill space, and preventing the need for costly and dangerous lifting operations.
- Referring now to
Figure 4 , aslurrification system 300 incorporating a firstcuttings storage vessel 302 is illustrated.Slurrification system 300 includes amodule 352, or drive unit, configured to operatively connect with the firstcuttings storage vessel 302 disposed in at least one support structure (not shown) of a drilling rig (not shown), and afluid supply line 378.Module 352 may include a containment unit, a skid, a housing, or a moveable platform configured to house select slurrification system components, as described in more detail below. - In this embodiment,
system 300 includes anindependent power source 360 for providing power to components ofmodule 352.Power source 360 is electrically connected to, for example, grindingdevice 354 and/or a programmable logic controller (PLC) 361. Those of ordinary skill in the art will appreciate that such a power source may provide primary or auxiliary power for powering components ofmodule 352. In other embodiments,power source 360 may be merely an electrical conduit for connecting a power source on a rig (not shown) via anelectrical cable 362, tomodule 352. -
Module 352 includes aninlet connection 370 configured to connect withoutlet 372 of firstcuttings storage vessel 302, and anoutlet connection 374 configured to connect with aninlet 376 of firstcuttings storage vessel 302.Inlet connection 370 may be connected tooutlet 372 andoutlet connection 374 may be connected toinlet 376 by fluid transfer lines, for example, flexible hoses and/or new or existing piping.Module 352 further includes a grindingdevice 354 configured to facilitate the transfer of fluids from the firstcuttings storage vessel 302, through themodule 352, and back to the firstcuttings storage vessel 302.Grinding device 354 is configured to reduce the particle size of solid materials of the drill cuttings transferred therethrough. - In one embodiment, grinding
device 354 may include a grinding pump. The grinding pump may be, for example, a centrifugal pump, as disclosed inU.S. Patent No. 5,129,469 . As shown inFigure 5 , acentrifugal pump 458, configured to grind or reduce the particle size of drill cuttings, may have a generallycylindrical casing 480 with aninterior impeller space 482 formed therein.Centrifugal pump 458 may include animpeller 484 with backward swept blades with an open face on both sides, that is, the blades orvanes 485 are swept backward with respect to a direction of rotation of the impeller and are not provided with opposed side plates forming a closed channel between the impellerfluid inlet area 487 and the blade tips. Thecasing 480 has atangential discharge passage 488 formed by acasing portion 490. The concentric casing ofcentrifugal pump 458 and the configuration of theimpeller blades 485 provide a shearing action that reduces the particle size of drill cuttings. Theblades 485 of theimpeller 484 may be coated with a material, for example, tungsten carbide, to reduce wear of theblades 485. One of ordinary skill in the art will appreciate that any grinding pump known in the art for reducing the size of solids in a slurry may be used without departing from the scope of embodiments disclosed herein. - In an alternative embodiment, as shown in
Figure 6 , grindingdevice 554 may include apump 556 and agrinder 557, for example, a ball mill. In this embodiment, cuttings may be injected into thegrinder 557, wherein the particle size of the solids is reduced. Thepump 556 may then pump the slurry back tofirst cuttings vessel 502. In one embodiment, the pump may include a grinding pump, as disclosed above, as a second grinder, for further reduction of the particle size of solids exiting thegrinder 557. - Referring back to
Figure 4 , in one embodiment,slurrification system 300 further includes a secondcuttings storage vessel 390 disposed in the support structure (not shown) of the drilling rig (not shown). Secondcuttings storage vessel 390 may be configured to supply cuttings to firstcuttings storage vessel 302. In one embodiment, a pump (not shown), as known in the art, may be used to transfer the cuttings. In another embodiment, a pneumatic transfer device (not shown), as disclosed above, may be used to transfer the cuttings to the firstcuttings storage vessel 302. One of ordinary skill in the art will appreciate that any method for transferring the cuttings tofirst storage vessel 302 may be used without departing from the scope of embodiments disclosed herein. - In one embodiment,
module 352 may further include a pneumatic control device (not shown) to control the flowrate of air injected into thecuttings storage vessel 302 by a pneumatic transfer device (not shown). In such an embodiment, an air line (not shown) from an air compressor (not shown) may be coupled to the pneumatic control device (not shown) inmodule 352 to control a flow of air into firstcuttings storage vessel 302. - In another embodiment, cuttings may be supplied to first
cuttings storage vessel 302 from a classifying shaker (not shown) or other cuttings separation or cleaning systems disposed on the drilling rig. Additionally, multiple cuttings storage vessels disposed in the support structure of the drilling rig may be connected to and supply cuttings to firstcuttings storage vessel 302. In one embodiment, each cuttings storage vessel may be configured to supply cuttings of predetermined sizes, for example, coarse cuttings or fines. Cuttings of a selected size may then be provided to firstcuttings storage vessel 302 to form a slurry of a predetermined density. One of ordinary skill in the art will appreciate that the cuttings may be transferred to the firstcuttings storage vessel 302 by any means known in the art, for example, by a pump or a pneumatic transfer device, as described above. - During operation of
slurrification system 300,fluid supply line 378 may be configured to supply a fluid to firstcuttings storage vessel 302. One of ordinary skill in the art will appreciate that thefluid supply line 378 may supply water, sea water, a brine solution, chemical additives, or other fluids known in the art for preparing a slurry of drill cuttings. As the fluid is pumped into firstcuttings storage vessel 302, cuttings from the secondcuttings storage vessel 390, or other components of the rig's cuttings separation system, as described above, may be transferred into firstcuttings storage vessel 302. - As first
cuttings storage vessel 302 fills with fluid and cuttings, the mixture of fluid and cuttings is transferred tomodule 352 through theinlet connection 370 of themodule 352. In one embodiment, the mixture may be transferred by a pneumatic transfer device, a vacuum system, a pump, or any other means known in the art. In one embodiment, the pneumatic transfer device may include a forced flow pneumatic transfer system. The mixture of fluid and cuttings is pumped through grindingdevice 354, wherein the cuttings are reduced in size. The mixture, or slurry, is then pumped back down to firstcuttings storage vessel 302 viaoutlet connection 374. The slurry may cycle back throughmodule 352 one or more times as needed to produce a slurry of a predetermined density or concentration of cuttings as required for the particular application or re-injection formation. - Referring now to
Figure 7 , in one embodiment,module 652 further includes avalve 694 disposed downstream of grindingdevice 654, whereinvalve 694 is configured to redirect the flow of the slurry exiting the grindingdevice 654. In one embodiment, aPLC 661 may be operatively coupled tomodule 652 and configured to close or open thevalve 694, thereby redirecting the flow of the slurry. In one embodiment, the PLC 695 may control thevalve 694 to move after a pre-determined amount of time of fluid transfer throughmodule 652. In another embodiment, a sensor (not shown) may be operatively coupled to thevalve 694 to open or close the valve when a pre-determined condition of the slurry is met. For example, in one embodiment, a density sensor (not shown) may be coupled tovalve 694, such that, when the density of the slurry exiting grindingdevice 654 reaches a pre-determined value,valve 694 moves, i.e., opens or closes, and redirects the flow of the slurry from the firstcuttings storage vessel 302 to another cuttings storage vessel, a slurry tank, a skip, or injection pump for injection into a formation. - In another embodiment, a conductivity sensor (not shown) may be coupled to
valve 694, such that, when the density of the slurry exiting grindingdevice 654 reaches a pre-determined value,valve 694 moves and redirects the flow of the slurry from the firstcuttings storage vessel 302 to another cuttings storage vessel, a slurry tank, a skip, or injection pump for injection into a formation. One of ordinary skill in the art will appreciate that other apparatus and methods may be used to redirect the flow of the slurry once a predetermined concentration of cuttings in suspension, density, or conductivity has been met. Commonly, a slurry with a concentration of up to 20% cuttings in suspension is used for re-injection into a formation. However, those of ordinary skill in the art will appreciate that direct injection of slurry, using embodiments of the present disclosure, may provide for an increased concentration of cuttings in the slurry. - A slurry formed by a slurrification system, as described above, may be transferred to another cuttings storage vessel, a slurry tank, a skip, or directly injected into a formation. Slurry that is transferred to a tank, vessel, skip, or other storage device, may be transferred off-site to another work site. In one embodiment, the storage device may be lifted off of a rig by a crane and transferred to a boat. Alternatively, slurry may be transferred via a hose, tubing, or other conduit, from the storage vessel dispose in the at least one leg of the drilling rig to a slurry tank disposed on the boat.
- In one embodiment, the slurry may be transported from one work site to another work site for re-injection. For example, the slurry may be transported from an offshore rig to another offshore rig. Additionally, the slurry may be transported from an offshore rig to an on-land work site. Further the slurry may be transported from an on-land work site to an offshore work site.
- Those of ordinary skill in the art will appreciate that the components of
systems - Advantageously, embodiments disclosed herein may provide a materials storage and transport system that reduces the amount of required space on a drilling rig. In another aspect, embodiments disclosed herein may provide a method of transferring stored materials to an offsite location. In yet another aspect, embodiments disclosed herein may provide a storage and transport system for cuttings that reduces the amount of required space on a drilling rig.
- Furthermore, embodiments disclosed herein may advantageously provide a slurrification system that reduces the amount of required space at a work site to operate the slurrification system. In another aspect, embodiments disclosed herein may provide a slurrification system that reduces the amount of equipment or number of components required to prepare slurries for re-injection into a formation. In yet another aspect, embodiments disclosed herein may provide a safer slurrification system by reducing the number of crane lifts required to install the system.
- Advantageously, embodiments disclosed herein may also provide for systems and methods that more efficiently store and transport non-free flowing and free flowing materials on a drilling rig. Because offshore platform space is often limited, and crane operations to transfer large storage tanks or containers are often expensive and dangerous, embodiments of the present disclosure may decrease the cost of drilling operations by decreasing the number of crane lifts.
- While the invention has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the invention as disclosed herein. Accordingly, the scope of the invention should be limited only by the attached claims.
Claims (14)
- A system for storing cuttings comprising:a drilling rig (1000) having a deck (1005) supported by at least two support structures (1006); anda slurrification system (300) disposed on the drilling rig (1000),
the slurrification system (300) comprising:at least one cuttings storage vessel (1004, 302, 390, 43) disposed in at least one of the at least two support structures (1006);a module (352) configured to operatively connect with the at least one cuttings storage vessel (1004, 302, 390, 43); anda fluid supply line (378) in fluid communication with the at least one cuttings storage vessels (1004, 302, 390, 43). - The system of claim 1, wherein the cuttings storage vessel (1004, 302, 390, 43) comprises a pressurized vessel.
- The system of claim 2, further comprising a pneumatic transfer device operatively connected to the at least one cuttings storage vessel (1004, 302, 390, 43).
- The system of claim 1, wherein a plurality of cuttings storage vessels (1004, 302, 390, 43) disposed in at least one of the two support structures (1006) is arranged in a circular configuration.
- The system of claim 1, further comprising a discharge line (1016) operatively connected to an outlet of the at least one cuttings storage vessel (1004, 302, 390, 43) and configured to allow for the transfer of cuttings from the cuttings storage vessel (1004, 302, 390, 43) to an offsite location.
- The system of claim 5, wherein the offsite location comprises a transport vehicle.
- The system of claim 1, wherein the at least one cuttings storage vessel (1004, 302, 390, 43) is disposed above sea level.
- The system of claim 1, wherein the at least one cuttings storage vessel (1004, 302, 390, 43) is disposed proximate sea level.
- The system of claim 1, wherein the at least one cuttings storage vessel (1004, 302, 390, 43) comprises an angled lower section (1012).
- The system of claim 9, wherein the angled lower section (1012) of the at least one cuttings storage vessel (1004, 302, 390, 43) comprises a plurality of angled structures (1014).
- A method of storing cuttings on a drilling rig (1000) comprising:disposing a slurrification system (300) on the drilling rig (1000),the drilling rig (1000) comprising a deck (1005) supported by at least two support structures (1006), andthe slurrification system (300) comprising:at least one cuttings storage vessel (1004, 302, 390, 43) disposed in at least one of the at least two support structures (1006);a module (352) configured to operatively connect with the at least one cuttings storage vessel (302); anda fluid supply line (378) in fluid communication with the at least one cuttings storage vessel (302); andtransferring materials from the deck (1005) of the drilling rig (1000) to the at least one cuttings storage vessel (1004, 302, 390, 43).
- The method of claim 11, wherein the cuttings storage vessel (1004, 302, 390,43) comprises a pressurized vessel and wherein the transferring comprises actuating a pneumatic transfer device to provide a flow of the materials from the pneumatic transfer device to the pressurized vessel.
- The method of claim 11, further comprising cutting an opening in the at least one support structure (1006) of the drilling rig (1000) for installation of a cuttings storage vessel (1004, 302, 390, 43) therein.
- The method of claim 13, further comprising closing a removed section of the at least one support structure (1006) to seal the cuttings storage vessel (1004, 302, 390, 43) within the at least one support structure (1006).
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US91347707P | 2007-04-23 | 2007-04-23 | |
PCT/US2008/061162 WO2008131385A1 (en) | 2007-04-23 | 2008-04-22 | Rig storage system |
Publications (3)
Publication Number | Publication Date |
---|---|
EP2150677A1 EP2150677A1 (en) | 2010-02-10 |
EP2150677A4 EP2150677A4 (en) | 2014-10-29 |
EP2150677B1 true EP2150677B1 (en) | 2016-10-05 |
Family
ID=39875961
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP08746558.9A Not-in-force EP2150677B1 (en) | 2007-04-23 | 2008-04-22 | Rig storage system |
Country Status (8)
Country | Link |
---|---|
US (1) | US20100084190A1 (en) |
EP (1) | EP2150677B1 (en) |
AR (1) | AR066264A1 (en) |
BR (1) | BRPI0810562A2 (en) |
CA (1) | CA2685008A1 (en) |
EA (1) | EA015298B1 (en) |
MX (1) | MX2009011401A (en) |
WO (1) | WO2008131385A1 (en) |
Families Citing this family (22)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20050242003A1 (en) * | 2004-04-29 | 2005-11-03 | Eric Scott | Automatic vibratory separator |
US8172740B2 (en) * | 2002-11-06 | 2012-05-08 | National Oilwell Varco L.P. | Controlled centrifuge systems |
US8312995B2 (en) | 2002-11-06 | 2012-11-20 | National Oilwell Varco, L.P. | Magnetic vibratory screen clamping |
US8118172B2 (en) * | 2005-11-16 | 2012-02-21 | National Oilwell Varco L.P. | Shale shakers with cartridge screen assemblies |
US8201693B2 (en) | 2006-05-26 | 2012-06-19 | National Oilwell Varco, L.P. | Apparatus and method for separating solids from a solids laden liquid |
US20080083566A1 (en) | 2006-10-04 | 2008-04-10 | George Alexander Burnett | Reclamation of components of wellbore cuttings material |
US8231010B2 (en) | 2006-12-12 | 2012-07-31 | Varco I/P, Inc. | Screen assemblies and vibratory separators |
US8215028B2 (en) * | 2007-05-16 | 2012-07-10 | M-I L.L.C. | Slurrification process |
US7980392B2 (en) | 2007-08-31 | 2011-07-19 | Varco I/P | Shale shaker screens with aligned wires |
US8622220B2 (en) | 2007-08-31 | 2014-01-07 | Varco I/P | Vibratory separators and screens |
US20090145836A1 (en) * | 2007-12-11 | 2009-06-11 | Paul William Dufilho | Vibratory separator screens & seals |
US8133164B2 (en) * | 2008-01-14 | 2012-03-13 | National Oilwell Varco L.P. | Transportable systems for treating drilling fluid |
US20100038143A1 (en) * | 2008-08-14 | 2010-02-18 | George Alexander Burnett | Drill cuttings treatment systems |
US9073104B2 (en) | 2008-08-14 | 2015-07-07 | National Oilwell Varco, L.P. | Drill cuttings treatment systems |
US8113356B2 (en) * | 2008-10-10 | 2012-02-14 | National Oilwell Varco L.P. | Systems and methods for the recovery of lost circulation and similar material |
US8556083B2 (en) | 2008-10-10 | 2013-10-15 | National Oilwell Varco L.P. | Shale shakers with selective series/parallel flow path conversion |
US9079222B2 (en) | 2008-10-10 | 2015-07-14 | National Oilwell Varco, L.P. | Shale shaker |
US9617810B2 (en) * | 2011-12-19 | 2017-04-11 | Nautilus Minerals Pacific Pty Ltd | Delivery method and system |
EP2855831B1 (en) | 2012-05-29 | 2017-07-12 | P.V. Flood Control Corp. | System for containment, measurement, and reuse of fluids in hydraulic fracturing |
US9643111B2 (en) | 2013-03-08 | 2017-05-09 | National Oilwell Varco, L.P. | Vector maximizing screen |
US11136840B2 (en) * | 2015-07-22 | 2021-10-05 | Halliburton Energy Services, Inc. | Multiple platform solids transferring aggregate |
RU2673684C2 (en) * | 2017-04-06 | 2018-11-29 | Общество с ограниченной ответственностью "ЛУКОЙЛ-Инжиниринг" (ООО "ЛУКОЙЛ-Инжиниринг") | Method of construction of offshore oil and gas well with “zero” discharge of drilling waste into the sea |
Family Cites Families (15)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5129469A (en) | 1990-08-17 | 1992-07-14 | Atlantic Richfield Company | Drill cuttings disposal method and system |
US6179071B1 (en) * | 1994-02-17 | 2001-01-30 | M-I L.L.C. | Method and apparatus for handling and disposal of oil and gas well drill cuttings |
GB2327442B (en) | 1997-07-17 | 2000-12-13 | Jeffrey Reddoch | Cuttings injection system |
GB9913909D0 (en) * | 1999-06-16 | 1999-08-18 | Clyde Pneumatic Conveying Limi | Pneumatic conveying |
US6881349B2 (en) | 2002-11-15 | 2005-04-19 | M-I Llc | Method for recycling of oil based drilling fluid contaminated with water and water contaminated with oil based drilling fluid |
US6977048B2 (en) | 2001-04-24 | 2005-12-20 | M-I Llc | Method of recycling water contaminated oil based drilling fluid |
US6709206B1 (en) * | 2001-07-10 | 2004-03-23 | Avenger Tool Co., Llc | Pipe beveller tool |
GB2423781B (en) * | 2003-03-19 | 2007-03-28 | Varco Int | Apparatus and method for moving drilled cuttings |
US7232525B2 (en) | 2004-03-19 | 2007-06-19 | M-I L.L.C. | Automatic tank cleaning system |
GB0519450D0 (en) | 2005-09-23 | 2005-11-02 | Benhar Systems Ltd | Drill cuttings storage and conveying |
US8741072B2 (en) * | 2007-01-31 | 2014-06-03 | M-I Llc | Use of cuttings vessel for tank cleaning |
US8316963B2 (en) * | 2007-01-31 | 2012-11-27 | M-I Llc | Cuttings processing system |
US7770665B2 (en) * | 2007-01-31 | 2010-08-10 | M-I Llc | Use of cuttings tank for in-transit slurrification |
US8083935B2 (en) * | 2007-01-31 | 2011-12-27 | M-I Llc | Cuttings vessels for recycling oil based mud and water |
US7828084B2 (en) * | 2007-01-31 | 2010-11-09 | M-I L.L.C. | Use of cuttings tank for slurrification on drilling rig |
-
2008
- 2008-04-22 MX MX2009011401A patent/MX2009011401A/en not_active Application Discontinuation
- 2008-04-22 EP EP08746558.9A patent/EP2150677B1/en not_active Not-in-force
- 2008-04-22 US US12/597,161 patent/US20100084190A1/en not_active Abandoned
- 2008-04-22 BR BRPI0810562-6A2A patent/BRPI0810562A2/en not_active IP Right Cessation
- 2008-04-22 WO PCT/US2008/061162 patent/WO2008131385A1/en active Application Filing
- 2008-04-22 CA CA002685008A patent/CA2685008A1/en not_active Abandoned
- 2008-04-22 EA EA200970993A patent/EA015298B1/en not_active IP Right Cessation
- 2008-04-23 AR ARP080101708A patent/AR066264A1/en unknown
Also Published As
Publication number | Publication date |
---|---|
US20100084190A1 (en) | 2010-04-08 |
EA015298B1 (en) | 2011-06-30 |
MX2009011401A (en) | 2010-02-09 |
EA200970993A1 (en) | 2010-04-30 |
WO2008131385A1 (en) | 2008-10-30 |
AR066264A1 (en) | 2009-08-05 |
BRPI0810562A2 (en) | 2014-10-21 |
EP2150677A4 (en) | 2014-10-29 |
EP2150677A1 (en) | 2010-02-10 |
CA2685008A1 (en) | 2008-10-30 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
EP2150677B1 (en) | Rig storage system | |
EP2126274B1 (en) | Use of cuttings tank for slurrification on drilling rig | |
US7770665B2 (en) | Use of cuttings tank for in-transit slurrification | |
US8741072B2 (en) | Use of cuttings vessel for tank cleaning | |
EP2113050B1 (en) | Cuttings processing system | |
CA2676880C (en) | High density slurry | |
US8371037B2 (en) | Slurrification process | |
AU2009330223B2 (en) | Waste processing system | |
BRPI0810562B1 (en) | System for storing chips and method for storing chips in a drilling rig | |
NO341447B1 (en) | Hydraulic mass transport system and method for transportation of drilling waste |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
PUAI | Public reference made under article 153(3) epc to a published international application that has entered the european phase |
Free format text: ORIGINAL CODE: 0009012 |
|
17P | Request for examination filed |
Effective date: 20091123 |
|
AK | Designated contracting states |
Kind code of ref document: A1 Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MT NL NO PL PT RO SE SI SK TR |
|
AX | Request for extension of the european patent |
Extension state: AL BA MK RS |
|
DAX | Request for extension of the european patent (deleted) | ||
A4 | Supplementary search report drawn up and despatched |
Effective date: 20140926 |
|
RIC1 | Information provided on ipc code assigned before grant |
Ipc: E21B 19/00 20060101ALI20140922BHEP Ipc: E21B 21/06 20060101AFI20140922BHEP |
|
17Q | First examination report despatched |
Effective date: 20150925 |
|
GRAP | Despatch of communication of intention to grant a patent |
Free format text: ORIGINAL CODE: EPIDOSNIGR1 |
|
INTG | Intention to grant announced |
Effective date: 20160607 |
|
GRAS | Grant fee paid |
Free format text: ORIGINAL CODE: EPIDOSNIGR3 |
|
GRAA | (expected) grant |
Free format text: ORIGINAL CODE: 0009210 |
|
AK | Designated contracting states |
Kind code of ref document: B1 Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MT NL NO PL PT RO SE SI SK TR |
|
REG | Reference to a national code |
Ref country code: GB Ref legal event code: FG4D |
|
REG | Reference to a national code |
Ref country code: CH Ref legal event code: EP |
|
REG | Reference to a national code |
Ref country code: AT Ref legal event code: REF Ref document number: 834855 Country of ref document: AT Kind code of ref document: T Effective date: 20161015 |
|
REG | Reference to a national code |
Ref country code: IE Ref legal event code: FG4D |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R096 Ref document number: 602008046655 Country of ref document: DE |
|
REG | Reference to a national code |
Ref country code: NL Ref legal event code: MP Effective date: 20161005 |
|
REG | Reference to a national code |
Ref country code: LT Ref legal event code: MG4D |
|
REG | Reference to a national code |
Ref country code: NO Ref legal event code: T2 Effective date: 20161005 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: LV Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 |
|
REG | Reference to a national code |
Ref country code: AT Ref legal event code: MK05 Ref document number: 834855 Country of ref document: AT Kind code of ref document: T Effective date: 20161005 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: SE Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: GR Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20170106 Ref country code: LT Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: NL Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: FI Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: AT Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: IS Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20170205 Ref country code: ES Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: PT Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20170206 Ref country code: BE Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: PL Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: HR Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R097 Ref document number: 602008046655 Country of ref document: DE |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: DK Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: CZ Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: SK Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: EE Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: RO Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 |
|
PLBE | No opposition filed within time limit |
Free format text: ORIGINAL CODE: 0009261 |
|
STAA | Information on the status of an ep patent application or granted ep patent |
Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: IT Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: BG Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20170105 |
|
26N | No opposition filed |
Effective date: 20170706 |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R119 Ref document number: 602008046655 Country of ref document: DE |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: SI Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 |
|
REG | Reference to a national code |
Ref country code: CH Ref legal event code: PL |
|
REG | Reference to a national code |
Ref country code: IE Ref legal event code: MM4A |
|
REG | Reference to a national code |
Ref country code: FR Ref legal event code: ST Effective date: 20171229 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: DE Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20171103 Ref country code: MC Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 Ref country code: FR Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20170502 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: LU Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20170422 Ref country code: LI Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20170430 Ref country code: CH Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20170430 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: IE Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20170422 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: MT Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20170422 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: HU Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT; INVALID AB INITIO Effective date: 20080422 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: CY Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20161005 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: TR Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20161005 |
|
PGFP | Annual fee paid to national office [announced via postgrant information from national office to epo] |
Ref country code: NO Payment date: 20200414 Year of fee payment: 13 |
|
PGFP | Annual fee paid to national office [announced via postgrant information from national office to epo] |
Ref country code: GB Payment date: 20200416 Year of fee payment: 13 |
|
REG | Reference to a national code |
Ref country code: NO Ref legal event code: MMEP |
|
GBPC | Gb: european patent ceased through non-payment of renewal fee |
Effective date: 20210422 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: NO Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20210430 Ref country code: GB Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20210422 |
|
P01 | Opt-out of the competence of the unified patent court (upc) registered |
Effective date: 20231216 |