Offshore drilling method

• US 9,157,285 B2
• Filed: 07/06/2012
• Issued: 10/13/2015
• Est. Priority Date: 11/07/2006
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Orbell, Charles R., Leuchtenberg, Christian, Godfrey, Craig W.
• Primary Examiner(s): Sayre, James G
• Application Number:
  US13/542,756
• Publication Number:
  US 20120292106A1
• Time in Patent Office: 1,194 Days
• Field of Search: 166/335, 166/339, 166/344, 166/345, 166/359, 166/367
• US Class Current: 1/1
• CPC Class Codes: E21B 17/01 Risers
• CPC Class Codes: E21B 21/08 Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure valve arrangements therefor E21B21/10
• CPC Class Codes: E21B 21/106 Valve arrangements outside the borehole, e.g. kelly valves valves specifically for maintaining circulation of drilling fluid while connecting or disconnecting tubular joints E21B21/019
• CPC Class Codes: E21B 33/02 Surface sealing or packing
• CPC Class Codes: E21B 33/038 Connectors used on well heads, e.g. for connecting blow-out preventer and riser
• CPC Class Codes: E21B 7/12 Underwater drilling using heave compensators E21B19/09

Abstract

An offshore universal riser system may include a valve module which selectively permits and prevents fluid flow through a flow passage extending longitudinally through a riser string. An anchoring device may releasably secure the valve module in the passage. A method of constructing a riser system may include the steps of installing the valve module in the passage, and installing at least one annular seal module in the passage. The annular seal module may prevent fluid flow through an annular space between the riser string and a tubular string positioned in the passage. Drilling methods may include injecting relatively low density fluid compositions into the annular space, and selectively varying a restriction to flow through a subsea choke in a drilling fluid return line. The riser string, including housings for the various modules and external control systems, may be dimensioned for installation through a rotary table.

Claims

1. A drilling method comprising the steps of:

connecting an injection conduit externally to a riser string, so that the injection conduit is communicable with an internal flow passage extending longitudinally through the riser string;

installing an annular seal module in the flow passage, the annular seal module being positioned in the flow passage between opposite end connections of the riser string;

conveying a tubular string into the flow passage;

sealing an annular space between the tubular string and the riser string utilizing the annular seal module;

rotating a drill bit at a distal end of the tubular string, the annular seal module sealing the annular space during the rotating step;

flowing drilling fluid from the annular space to a surface location; and

injecting a fluid composition having a density less than that of the drilling fluid into the annular space via the injection conduit.

2. The method of claim 1, wherein in the injecting step, the fluid composition comprises Nitrogen gas.

3. The method of claim 1, wherein in the injecting step, the fluid composition comprises hollow glass spheres.

4. The method of claim 1, wherein in the injecting step, the fluid composition comprises a mixture of liquid and gas.

5. The method of claim 1, wherein the riser string includes a portion having at least one valve, at least one accumulator, and at least one actuator externally connected to the riser portion for controlling injection of the fluid composition, and wherein the method further comprises the step of displacing the riser portion with the externally connected valve, accumulator and actuator through a rotary table.

6. The method of claim 1, further comprising the steps of connecting hydraulic control lines externally to the riser string for controlling injection of the fluid composition, and connecting the hydraulic control lines to a subsea hydraulic control system external to the riser string.

7. The method of claim 6, further comprising the step of replacing the hydraulic control system utilizing a subsea remotely operated vehicle.

8. The method of claim 6, further comprising the step of connecting a hydraulic supply line and an electrical control line between the subsea hydraulic control system and a surface hydraulic control system.

9. The method of claim 8, wherein signals for operating the subsea hydraulic control system to selectively supply hydraulic fluid to control injection of the fluid composition are multiplexed on the electrical control line.

10. The method of claim 1, further comprising the step of utilizing at least one sensor to monitor pressure in the injection conduit.

11. A drilling method comprising the steps of:

connecting a drilling fluid return line externally to a riser string, so that the drilling fluid return line is communicable with an internal flow passage extending longitudinally through the riser string;

installing an annular seal module in the flow passage, the annular seal module being positioned in the flow passage between opposite end connections of the riser string;

conveying a tubular string into the flow passage;

sealing an annular space between the tubular string and the riser string utilizing the annular seal module;

rotating a drill bit at a distal end of the tubular string, the annular seal module sealing the annular space during the rotating step; and

flowing drilling fluid from the annular space to a surface location via the drilling fluid return line, the flowing step including varying a flow restriction through a subsea choke externally connected to the riser string to thereby maintain a desired downhole pressure.

12. The method of claim 11, wherein the step of varying the flow restriction further comprises automatically varying the flow restriction without human intervention to thereby maintain the desired downhole pressure.

13. The method of claim 11, wherein the riser string includes a portion having at least one valve, at least one accumulator, and at least one actuator externally connected to the riser portion for operating the subsea choke, and wherein the method further comprises the step of displacing the riser portion with the externally connected valve, accumulator and actuator through a rotary table.

14. The method of claim 11, further comprising the steps of connecting at least one hydraulic control line externally to the riser string for controlling operation of the choke, and connecting the hydraulic control line to a subsea hydraulic control system external to the riser string.

15. The method of claim 14, further comprising the step of connecting the hydraulic control line and an electrical control line between the subsea hydraulic control system and a surface hydraulic control system.

16. The method of claim 15, wherein signals for operating the subsea hydraulic control system to selectively supply hydraulic fluid to control operation of the choke are multiplexed on the electrical control line.

17. The method of claim 11, further comprising the step of utilizing at least one sensor to monitor pressure in the drilling fluid return line.