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Kafe 바로가기국가/구분 | United States(US) Patent 등록 |
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국제특허분류(IPC7판) |
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출원번호 | US-0841131 (2001-04-24) |
발명자 / 주소 |
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출원인 / 주소 |
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인용정보 | 피인용 횟수 : 227 인용 특허 : 227 |
A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2,and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a synthesis gas production temperature. A syn
A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2,and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a synthesis gas production temperature. A synthesis gas generating fluid may be introduced into the portion. Synthesis gas may be produced from the formation Synthesis gas may be used as a feed stream in an ammonia synthesis process. Ammonia may be used as a feed stream in a urea synthesis process.
A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2,and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a synthesis gas production temperature. A syn
A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2,and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a synthesis gas production temperature. A synthesis gas generating fluid may be introduced into the portion. Synthesis gas may be produced from the formation Synthesis gas may be used as a feed stream in an ammonia synthesis process. Ammonia may be used as a feed stream in a urea synthesis process. ed within the body, wherein the chamber is in fluid communication with each of the one or more conduits; an inlet in fluid communication with one of the conduits for pressurizing the chamber; and a sealing element disposed on the body for sealing an annular area between the packer and the wellbore. 11. A packer for sealing an annulus in a wellbore, comprising: a body having one or more conduits formed longitudinally there-through and one or more longitudinal bores disposed there-through, wherein the one or more longitudinal bores comprise a smaller diameter bore and a larger diameter bore; a chamber disposed within the body, wherein the chamber is in fluid communication with each of the one or more conduits; an inlet in fluid communication with one of the conduits for pressurizing the chamber; and a sealing element disposed on the body for sealing an annular area between the packer and the wellbore. 12. A packer for sealing an annulus in a wellbore, comprising: a body having one or more conduits formed longitudinally there-through; a chamber disposed within the body, wherein the chamber is in fluid communication with each of the one or more conduits; an inlet in fluid communication with one of the conduits for pressurizing the chamber; a sealing element disposed on the body for sealing an annular area between the packer and the wellbore; and a release assembly comprising: a lock body disposed on a first end of the body, wherein the lock body comprises a recessed groove formed in an inner surface thereof; an expandable ring disposed within the recessed groove, wherein the expandable ring comprises concentric grooves disposed on an inner surface thereof which mateably engage concentric grooves disposed about an outer surface of the body; a releasable collar at least partially disposed about the expandable ring; and a slideable sleeve at least partially disposed about the releasable collar. 13. The packer of claim 12, wherein the slideable sleeve comprises a recessed groove formed in an inner surface thereof. 14. The packer of claim 13, wherein movement of the slideable member aligns the recessed groove of the slideable member with the releasing collar, allowing the expandable ring to expand and release the packer. 15. The packer of claim 12, wherein the release assembly is disposed within the smaller diameter bore. 16. A packer for sealing an annulus in a wellbore, comprising: a body having one or more conduits formed longitudinally there-through; a chamber disposed within the body, wherein the chamber is in fluid communication with each of the one or more conduits; an inlet in fluid communication with one of the conduits for pressurizing the chamber; a sealing element disposed on the body for sealing an annular area between the packer and the wellbore; and a release assembly comprising: a lock body disposed on a first end of the body; a collapsible member threadably engaged with the body at a first end and shouldered against the lock body at a second end; and a slideable member disposed within the collapsible member. 17. The packer of claim 16, wherein movement of the slideable member allows the collapsible member to collapse inwardly and release the packer. 18. The packer of claim 17, wherein the release assembly is disposed within the larger diameter bore. 19. A packer for sealing an annulus in a wellbore, comprising: a body having one or more conduits formed there-through, wherein the one or more conduits comprise: a seal mandrel disposed therein; and one or more annular cavities formed between an outer surface of the seal mandrel and an inner surface of the mandrel body; and a chamber disposed within the body, wherein the chamber is in fluid communication with each of the one or more conduits. 20. The packer of claim 19, wherein the annular cavities are in fluid communication with the chamber. 21. A packer for sealing an annulus in a wellbore, comprising: a body having on e or more conduits formed there-through, wherein the one or more conduits comprise a seal mandrel disposed therein; and a chamber disposed within the body, wherein the chamber is in fluid communication with each of the one or more conduits, wherein the chamber acts as a manifold for pressure testing the one or more conduits. 22. A packer for sealing an annulus in a wellbore, comprising: a body having one or more conduits formed there-through, wherein the one or more conduits comprise a seal mandrel disposed therein; a chamber disposed within the body, wherein the chamber is in fluid communication with each of the one or more conduits; and an aperture disposed on the body wherein pressurized fluid is applied through the aperture to determine leaks within the one or more conduits. 23. A method of pressure testing conduits of a packer, comprising: flowing a fluid into a body, the body comprising: one or more conduits formed there-through, wherein the one or more conduits comprise a seal mandrel disposed therein and one or more annular cavities formed between an outer surface of the seal mandrel and an inner surface of the body; and a chamber disposed within the body, wherein the chamber is in fluid communication with the annular cavities. 24. A method of pressure testing conduits of a packer, comprising: flowing a fluid into a body, the body comprising: one or more conduits formed there-through, wherein the one or more conduits comprise a seal mandrel disposed therein and one or more annular cavities formed between an outer surface of the seal mandrel and an inner surface of the body; and a chamber disposed within the body, wherein the chamber is in fluid communication with the annular cavities, wherein the chamber acts as a manifold for pressure testing the one or more conduits. 25. A method of pressure testing conduits of a packer, comprising: flowing a fluid into a body comprising: one or more conduits formed there-through, wherein the one or more conduits comprise a seal mandrel disposed therein and one or more annular cavities formed between an outer surface of the seal mandrel and an inner surface of the body; and a chamber disposed within the body, wherein the chamber is in fluid communication with the annular cavities, wherein the fluid flows in a first direction through one of the annular cavities to the chamber and flows in a second direction from the chamber through the remainder of the annular cavities. least one second rate. 2. The method of claim 1 wherein the at least one parameter of interest is selected from a group consisting of (i) permeability, (ii) mobility, (iii) fluid compressibility, (iv) contact points, and (v) pressure. 3. The method of claim 1 wherein the work string is selected from a group consisting of (i) a drill pipe, (ii) a coiled tube and (iii) a wireline. 4. The method of claim 1 wherein extending at least one selectively extendable device is extending at least two expandable packers. 5. The method of claim 1 wherein the first rate is a constant rate. 6. The method of claim 1 wherein the borehole is a non-vertical borehole, the method further comprising orienting the selectively extendable devices and port to include a portion of the borehole wall closest to the surface in the sealed portion of annulus. 7. The method of claim 6 wherein orienting the selectively extendable devices further comprise using an accelerometer to determine orientation of the selectively extendable devices, and adjusting the orientation of the selectively extendable devices until the selectively extendable devices are oriented to a selected direction. 8. The method of claim 1 wherein sensing at least one characteristic of the fluid includes a characteristic selected from the group consisting of (i) pressure, (ii) temperature, (iii) volume, (iv) change in volume, (v) volume change rate, and (vi) compressibility. 9. The method of claim 1 further comprising initiating (c) by issuing a command from a surface location and controlling (c) through (i) using a controller disposed downhole on the work string. 10. A method according to claim 1 wherein increasing the test volume at an at least one second rate further comprises: (i) decreasing the rate of volume increase by a first factor to a second rate when the test volume pressure falls below formation pressure; (ii) allowing the test volume to stabilize while continuing to increase the test volume at the second rate; (iii) decreasing the rate of volume increase by a second factor to a third rate after the test volume pressure stabilizes at the second rate; (iv) allowing the test volume pressure to stabilize while continuing to increase the test volume at the third rate; the method further comprising: (v) holding the test volume constant; (vi) allowing the test volume pressure to stabilize at the constant volume; and (vii) sensing the at least one characteristic of the test volume using the test device when the test volume pressure stabilizes at the constant volume. 11. A method according to claim 10 further comprising: (A) repeating (iii) and (iv) until the test volume pressure increases while sensing the pressure at least twice; (B) increasing the rate of volume increase by a third factor to at least a fourth rate after the test volume pressure begins to increase; and (C) allowing the test volume to stabilize while continuing to increase the test volume at the fourth rate. 12. A method for determining formation pressure of a subterranean formation, the formation having a borehole drilled therein traversing a reservoir containing formation fluid at the formation pressure, the method comprising: (a) conveying a tool into the borehole on a work string, the borehole and work string having an annulus between the borehole wall and work string, the annulus being filled with a fluid; (b) extending at least one selectively extendable device disposed on the tool to seal a portion of the annulus; (c) exposing a port to the sealed portion of the annulus, the port being in fluid communication with a test volume created by (a) and (b), the test volume containing the fluid, the fluid including formation fluid; (d) increasing the test volume at a first rate with a volume control device; (e) monitoring the pressure of the fluid and volume change rate at predetermined time intervals using a test device at least twice while the test volume is being increased at the first
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