12.11.2025
Drilling Riser

Semi-submersible rigs have the advantage of being able to move away from a location very quickly, as opposed to a jack up rig. This is a good thing in arctic areas if an iceberg comes rambling down, at 10 miles per hour, strait on collision course with the rig. Semi-submersible rigs are used for exploration, development and sometimes also for production work in deep waters.

Large semi-submersible rigs can be quite self-contained and can operate for long periods without re-supply. They are more like ships in behavior and require additional equipment to control stability in order to function properly.

This equipment includes ballast management systems, motion compensators for keeping the drill string on bottom and a riser pipe that isolates the well from the open sea between sea floor and rig. The riser is a set of large pipes which is locked together with seals and bolts in a special way to ensure flexibility and pressure integrity. The riser may have flotation elements attached on the outside to balance the weight of the riser in the water and minimize weight support from rig as this will limit the rigs load capacity.

The Well control equipment (BOP) used on a semi-submersible rig are normally attached to the top of the wellhead at the seafloor. This equipment is remote controlled from the rig through an umbilical or hoses. The main reason for placing the BOP on the sea floor is to prevent high pressure well conditions to enter the riser. As the riser has to be large enough to allow drill string, bit and various casing sizes to pass through, it also has to be strong enough to withstand high well bore pressures. Most risers can hold up to 5000 psi pressure.

There are drilling setups where BOP‘s are located at surface, but then the riser has to have the same pressure rating as the BOP. If the BOP‘s were located at surface, it would be impossible to disconnect at the sea floor as the well would then be open to the environment.tensioner.

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22.03.2023
Well Control Barriers

Primary well control barrier

During normal drilling operation it will always be the hydrostatic pressure of the drilling fluid that creates the primary barrier to avoid any flow of formation fluid into the well bore. If for any reason the primary barrier is lost the well control equipment together with the drilling fluid in the well bore will be the secondary barrier. This will allow us to re-establish the primary barrier on a safe and efficient way.

Secondary well control barrier

The well control equipment must be able to close and secure the well under all circumstances. Further to that circulation of heavy drilling fluid into the well bore and formation fluid out of the well bore under controlled manner must be possible.

The well control equipment should be able to close on open hole, meaning without tubular, around the bottom hole assembly, BHA for short, and other tubular used in the drilling operation. It should also be able to cut the drill string or lighter tubular and seal the well bore and allow the drill string to be hanged off on the pipe rams or stripped into the well bore.

To avoid single components to create total failure of the system a contingency, i.e. back up function should be built into the system.

All well control equipment must be maintained, function- and pressure tested according to company policy and procedures to assured correct function and integrity when required.

With the well closed in and the drill string in the well bore, formation pressure can be obtained through the drill string by adding shut-in drill pipe pressure, or SIDPP, with pressure hydrostatic.

To secure the drill string and obtain integrity following barriers can be used:

• FOSV, standing for the full opening safety valve,

• One way valves (IBOP, Dart sub),

• Check valves (Drill pipe floats).

To secure the annulus and obtain integrity following barriers can be used:

• Annular Preventer,

• Ram Preventer,

• Shear/Blind Ram,

• Rotating head.

During normal drilling operation two barriers must always be in place where the hydrostatic head of the drilling fluid is one and the BOP’s the other

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