Blow Out Preventer is one of the most critical equipment on the rig therefore it is very important that you need to understand it. This VDO demonstrates the basic of BOP with a lot of colorful pictures which will help you learn about it. We also add full VDO transcript in order to help people fully understand this topic. We wish you would love this.
Full VDO Transcript Deails
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 pressures as low as 2m000 pounds per square inch or psi and as high as 15,000 psi. That is about 14,000 kPa to over 100,000 kPa.
Rigs usually have two kinds of preventers, on top is an annular preventer it is called an annular preventer because it surrounds the top of the well bore in the shape of a ring or an annulus. Below the annular preventer are ram preventers. The shutoff valves in RAM preventers close my forcing or ramming themselves together.
The choke line is a line through which well fluids flow through the choke manifold when the preventers are closed. Even though the preventers shut in the well the core members 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 kicks to the choke to keep back pressure on the well. Keeping the right amount of back pressure prevents more tick fluids from entering the well. At the same time they can get the kick out of the well and putting 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 burn a safe distance away. When the well takes a kick and the BOPs are open, well fluids force mud to flow the well bore 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 diverts the flow of the choke like which goes to the choke manifold. The driller can open a line on the choke line and safely circulate the kick through the choke manifold.