Blowout Preventers (BOP) VDO Training

All drilling rigs have the Blow Out Preventer because it is a mandatory equipment for well control, therefore personnel who has work relating to drilling operation must learn about the BOP. Learning via VDO training gives you several advantages as clear descriptions with relating images, etc so learners can learn faster and get correct massage.

This VDO below teaches about the BOP and we also provide the full VDO transcript as usual to accelerate learning capability.

Full VDO Transcript

37-Blowout-Preventers-(BOP)--Drilling-Engineer-2
The Blowout Preventer, BOP Stack, consists of several large valves stacked on top of each other. These large valves are called blowout preventers. Manufacturers rate BOP Stacks to work against pressure as low as 2,000 per square inch or psi, and as high as 15,000 psi. That’s about 14,000 kilo pascals to over 100,000 kilo pascals. Rigs usually have two kinds of preventers. On top is an annular preventer. It’s called an annular preventer because it surrounds the top of the wellbore in the shape of a ring or an annulus. Below the annular preventer are ram preventers.

 
The shut-off valves in ram preventers close by forcing or ramming themselves together. The choke line is a line through which well fluids flow to the choke manifold when the preventers are closed. Even though the preventers shut in the well, the crew must have a way to remove or circulate the kick in the mud out of the well. When the BOP shut in the well, mud and formation fluids exit through the choke line to the choke manifold. The manifold is made up of special piping and valves. The most important valve is the choke. The choke is a valve that has an adjustable opening. Crew members circulate the kick through the choke to keep back pressure on the well.

 
Keeping the right amount of back pressure prevents more kick fluids from entering the well. At the same time, they can get the kick out of the well and put in heavier mud to kill the well, that is, regain control of it. The well fluids leave the choke manifold and usually go to a mud-gas separator. A mud-gas separator separates the mud from the gas in the kick. The clean mud goes back to the tanks; the gas is flared or burned a safe distance away. When the well takes a kick and the BOPs are opened, well fluids force mud to flow up the wellbore and into the BOP stack. When the driller closes the annular BOP, flow stops. Usually, drillers close the annular BOP first. The closed annular BOP diverse the flow of the choke line, which goes to the choke manifold. The driller can open a valve from the choke line and safely circulate the kick out of the well through the choke manifold.

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