# US 7,464,758 B2 · Model HCCV hydrostatic closed circulation valve > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 7,464,758 B2 - Document ID: US7464758B2 - Status: Granted - Kind: B2 - Application number: 11/455,565 - Filed: 2006-06-19 - Published: 2006-10-26 - Granted: 2008-12-16 - Earliest claimed: 2002-10-02 - Assignees: Baker Hughes Incorporated - Inventors: Joseph C. H. Yeo; Anthony J. Orchard; Keith E. Lewis; Christopher L. Weaver - Web page: https://patentgrep.com/patent/US7464758B2 ## CPC - E21B 21/103: {Down-hole by-pass valve arrangements, i.e. between the inside of the drill string and the annulus (valves specifically for maintaining circulation of drilling fluid while connecting or disconnecting tubular joints E21B21/019)} - E21B 33/16: using plugs for isolating cement charge; Plugs therefor {(stage cementing E21B33/146; spacer compositions C09K8/424)} - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS ## Abstract Devices and methods for methods for cleaning of excess cement from a production assembly as well as from the annulus surrounding the production assembly. A hydrostatic closed circulation valve (HCCV) assembly is described that is primarily actuatable between open and closed positions by varying hydraulic pressure in the flowbore of the production assembly. The valve assembly is useful for selectively circulating working fluid into the annulus from the flowbore of the production assembly. ## Claims ### Claim 1 A method for completing a wellbore using a tubular assembly having an axial flowbore and a flow port communicating with a wellbore annulus, the flow port having at least a substantially non-circulating configuration and a substantially circulating configuration, the method comprising: (a) positioning the tubular assembly in the wellbore with the flow port in the substantially non-circulating configuration; (b) at least partially cementing the tubular assembly within the wellbore while the flow port is in the substantially non-circulating configuration; (c) configuring the flow port to be in the substantially circulating configuration; (d) circulating a working fluid through the flow port to substantially remove cement from at least a portion of the tubular assembly; and (e) configuring the flow port to be in the substantially non-circulating configuration. ### Claim 2 (depends on 1) The method of claim 1 wherein configuring the flow port to be in the substantially open position includes applying a first level of fluid pressure. ### Claim 3 (depends on 2) The method of claim 2 wherein the first level of fluid pressure ruptures a frangible rupture member in the flow port. ### Claim 4 (depends on 1) The method of claim 1 wherein configuring the flow port to be in the substantially closed position includes applying a second level of fluid pressure. ### Claim 5 (depends on 4) The method of claim 4 wherein the second level of fluid pressure moves a sleeve that closes the flow port. ### Claim 6 (depends on 4) The method of claim 4 further comprising manually closing the flow port if the second level of fluid pressure fails to close the flow port. ### Claim 7 A system for producing hydrocarbons from a downhole formation, the system comprising: a tubular at least partially cemented in a wellbore traversing the formation, the tubular having a flowbore; and a selective flow device connected to the tubular to provide a fluid path between the flowbore and an annular space surrounding the tubular, the selective flow device having: (i) a substantially closed position while the tubular is being at least partially cemented in the wellbore, and (ii) a substantially open position after the tubular has been at least partially cemented in the wellbore to flow a cement removing fluid into the annular space. ### Claim 8 (depends on 7) The system of claim 7 wherein the selective flow device is pressure activated. ### Claim 9 (depends on 7) The system of claim 7 further comprising a plug member that is landed in a complimentary landing seat within the flowbore to increase pressure in the flowbore. ### Claim 10 (depends on 7) The system of claim 7 wherein a first level of fluid pressure within the flowbore selectively opens the selective flow device. ### Claim 11 (depends on 7) The system of claim 7 wherein a second level of fluid pressure within the flowbore and the annular space closes the selective flow device. ### Claim 12 (depends on 7) The system of claim 7 wherein the selective flow device is substantially closable by a shifting tool. ### Claim 13 (depends on 7) The system of claim 7 wherein the selective flow device includes an opening providing fluid communication between the flowbore and the annular space, the opening including a frangible rupture member that ruptures upon application of a first fluid pressure level thereto. ### Claim 14 (depends on 7) The system of claim 7 wherein the selective flow device comprises: an inner mandrel containing a lateral fluid flow opening; and a first sleeve that is moveable with respect the inner mandrel to selectively open and close the fluid flow opening to fluid flow therethrough.