Offshore universal riser system

• US 8,881,831 B2
• Filed: 07/06/2012
• Issued: 11/11/2014
• 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:
  US13/542,875
• Publication Number:
  US 20120292054A1
• Time in Patent Office: 858 Days
• Field of Search: 166/335, 166/345, 166/350, 166/359, 166/367, 166/358, 166/337, 166/363
• US Class Current: 166/367
• 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:

installing a first annular seal module within an internal flow passage extending longitudinally through a riser string, the first annular seal module being secured within the flow passage between opposite end connections of the riser string, and the first annular seal module including a first seal-receiving profile;

installing a second annular seal module within the flow passage, the second annular seal module being secured within the flow passage between opposite end connections of the riser string, and the second annular seal module including a second seal-receiving profile;

installing a first seal within the first annular seal module, while the first annular seal module remains in the flow passage;

installing a second seal within the second annular seal module, while the second annular seal module remains in the flow passage;

sealingly engaging a tubular string within the flow passage with the first and second seals;

retrieving the first seal from the first annular seal module while the first annular seal module remains in the flow passage; and

retrieving the second seal from the second annular seal module while the second annular seal module remains in the flow passage.

2. The method of claim 1, wherein the first and second annular seal modules seal an annular space between the riser string and the tubular string.

3. The method of claim 1, wherein the tubular string rotates within the flow passage while the first and second seals sealingly engage the tubular string.

4. The method of claim 3, wherein at least one of the first and second seals rotates with the tubular string.

5. The method of claim 3, wherein at least one of the first and second seals remains stationary within the riser string while the tubular string rotates.

6. The method of claim 3, wherein at least one of the first and second seals is selectively radially extendable into sealing contact with the tubular string.

7. The method of claim 1, further comprising utilizing at least one sensor to monitor pressure in the flow passage between the first and second annular seal modules.

8. The method of claim 1, wherein each of the first and second annular seal modules includes at least one selective latch member which selectively engages only a respective one of multiple module-receiving profiles in the riser string.

9. The method of claim 1, wherein the first seal includes a first selective latch member which selectively engages the first seal-receiving profile in the first annular seal module.

10. The method of claim 1, wherein the second seal includes a second selective latch member which selectively engages the second seal-receiving profile in the second annular seal module.