Well Control - Basic Knowledge 1

Keeping trip records, pump output figures, slow circulating rate pressure losses, and having crews trained up and well control conscious are all good drilling practices. Trip records help in tracking the progress of the drilling operation and identifying any issues or trends. Pump output figures help in monitoring the efficiency of the drilling fluid circulation system. Slow circulating rate pressure losses help in detecting any potential wellbore problems. Having crews trained up and well control conscious ensures that the drilling operation is conducted safely and efficiently. Therefore, all of the above practices should be followed for effective drilling operations.

Hydrostatic pressure is the pressure exerted by a column of fluid at rest. This means that when a fluid is not in motion, the pressure it exerts is due to the weight of the fluid above it. This pressure is evenly distributed in all directions and increases with depth. Therefore, the given statement is true.

Closing the BOP's (Blowout Preventers) would be the secondary method of controlling a blowout if primary control has been lost. Blowout Preventers are designed to seal the wellbore and prevent the uncontrolled flow of fluids during drilling operations. If primary control measures fail, closing the BOP's can help regain control over the well by stopping the flow of fluids and preventing further escalation of the blowout situation.

If the proper drillpipe pressure schedule is not followed during a kill operation, it can lead to an imbalance in bottomhole pressure (BHP). This imbalance can result in BHP being either too high or too low. If BHP is too high, it can cause another influx of fluids into the wellbore. On the other hand, if BHP is too low, it can cause losses of fluids from the wellbore. Therefore, not following the proper drillpipe pressure schedule during a kill operation can result in either influxes or losses, making the statement true.

All of the given options can be possible indicators of a kick. An increase in flow can occur when the formation fluids enter the wellbore, causing an increase in the overall fluid flow. A drilling break refers to a sudden decrease in drilling rate, which can indicate that the drill bit has encountered a formation with higher pressure. An increase in pit volume can occur when formation fluids enter the wellbore and displace the drilling mud, causing an increase in the volume of fluid in the mud pits. Gas cut mud refers to the presence of gas in the drilling mud, which can indicate that formation fluids, including gas, have entered the wellbore.

The correct mud weight in the hole is the primary method for preventing blowouts. Blowouts occur when the pressure from the formation exceeds the pressure exerted by the mud column in the wellbore. By maintaining the correct mud weight, the pressure in the wellbore can be balanced with the formation pressure, preventing blowouts. This is achieved by carefully monitoring and adjusting the density of the drilling mud to ensure it is sufficient to counteract the formation pressure.

A blowout refers to an uncontrolled flow of fluid, such as oil or gas, from the wellbore to the surface. This can occur when the pressure in the wellbore exceeds the pressure that can be contained by the well's safety systems. It is a dangerous and potentially catastrophic event that can result in the release of large amounts of hydrocarbons, posing risks to personnel, equipment, and the environment.

The statement is explaining what the slow circulating rate pressure loss is, which is the pressure needed to circulate mud at a chosen speed in the system. Therefore, the statement is true.

The smaller the pit gain, the lower pressures are likely to be. The quicker you close it in the smaller the pit gain.

Slow circulating rate pressure losses should be taken in all of the mentioned scenarios. These losses should be monitored and recorded as soon as practical after coming on tour, when there is a change in mud weight, after drilling a large footage, or when there are changes in the BHA or bit nozzle. By taking these measurements, the drilling team can assess the efficiency of the drilling process and make necessary adjustments to maintain the desired mud weight and optimize drilling operations.

psi/ft = pressure/feet

The correct answer is Drillers. In the drilling process, the Drillers method of well control is used to circulate the influx out of the well before circulating kill mud round the system. This method involves maintaining a constant bottom hole pressure while circulating the influx out of the well. It allows for controlled and gradual removal of the influx, ensuring the safety and stability of the well.

Wait & Weight is the method of well control that has only one circulation and allows for pumping kill mud weight right from the start. This method involves monitoring the wellbore pressure while circulating the drilling fluid, and making necessary adjustments to the mud weight as needed to maintain well control. By using this method, the drilling team can quickly respond to any pressure changes and prevent a blowout from occurring.

psi/ft = ppg x .052

The statement is true because the U-Tube is a tool used to measure the difference between the Shut-In Drill Pipe Pressure (SIDPP) and the Shut-In Casing Pressure (SICP). When the well is shut in and the pressures have stabilized, the U-Tube will be balanced, indicating that there is no difference between the SIDPP and SICP. This balance is independent of the difference between the two pressures, meaning that even if the pressures are not equal, the U-Tube will still be balanced.

Hydrostatic Pressure is affected by the length of the column of fluid and the weight of the column of fluid.

If pumping is not possible and gas migration is suspected, the best method of well control would be the volumetric method. This method involves monitoring the wellbore pressure and fluid levels to detect any changes or irregularities. By closely monitoring these parameters, any indications of gas migration can be identified and appropriate actions can be taken to control the well.

The pit volume should remain constant during the second circulation.

When you pump a slug, the bottom hole pressure is not affected. A slug is a volume of fluid that is pumped into the wellbore to displace another fluid. The purpose of pumping a slug is to remove or separate different fluids in the wellbore, such as oil and water. While the slug may cause changes in the pressure at other points in the wellbore, it does not directly affect the bottom hole pressure. Therefore, the statement that bottom hole pressure is not affected when you pump a slug is true.

APL acts on the bottom of the hole.

The main purpose of the choke is to control back pressure.

We tend to keep the hole full these days - whether or not we put the correct amount in for the steel removed is another matter.

The bigger the pit gain the higher SICP is likely to be. SIDPP is not affected by the size of the influx.

You kill the well using the gauge on the remote choke panel so this is what you should use for recording slow circulating rate pressure losses.

All pressures in the wellbore will increase with gas migration with the exception of bubble pressure which will remain constant.