Well Control Methods and Procedures Flashcards

Question

End of Volumetric Method

Answer 1

When the SICP is stable and not rising. Some gas may be bled off before the SICP stabilizes.

Answer 2

Surface pressure is replaced with hydrostatic pressure by pumping mud into the well on top of the gas. The gas and mud are allowed to change places in the hole and a certain amount of the surface pressure is then bled off.

Answer 3

1. Perform Calculations 2. Lubricate by slowly pumping a given volume into the well 3. Wait for the gas to migrate back to the surface 4. Bleed gas from the well until the surface pressure is reduced by an amount equal to the hydrostatic pressure of th emud pumped in 5. Repeat steps 2 through4 until all of hte gas has been bled off or a desired surface pressure has been reached

Answer 4

A technique that may be used in certain circumstances during drilling operations to pump an influx back into the formation.

Answer 5

When a very large influx has been taken, when conventional methods may cause excessive surface pressures, when displacement of the influx would result in an excessive gas volume at surface (MGS limitations), if the influx contains an unacceptable level of H2S, When stripping back to bottom is not feasible, when there is no pipe in the hole, or to reduce surface operations

Answer 6

The characteristic of the openhole, the rated pressure of the well control equipment and the casing, drill pipe andcasing pressure limits, the type of influx and the relative permeability of the formation, the position of the influx on the hole, the quality of the filter cake at the permeable formation, the consequences of fracturing the openhole, and the possibility of formation damage

Answer 7

1. Calculate surface pressures that would cause fracture 2. Prepare a chart using strokes vs. pumping pressure if heavier mud is used 3. If gas is at surface, used lube and bleed first 4. Bring the pumps up to speed slowly to overcome well pressure 5. Attempt to pump fast enough to exceed gas migration rate 6. As the produced fluids are forced back into the formation, the added hydrostatic should lower pump pressure 7. Stop the pump, shut-in and monitor

Answer 8

1. Kill the well off bottom (not recommended) 2. Use volumetric well control if you have migrating gas 3. Strip back to bottom 4. Strip using volumetric well control if you have migrating gas 5. Snub the drill pipe back in the well

Answer 9

Tripping pipe through the BOPs when the drill string weight is greater than the net upward force created from the wellbore pressures

Answer 10

Forcing pipe through the BOPs when the drill string weight is not sufficient to overcome the net upward force created by wellbore pressures

Answer 11

Is the annular in good condition, rig crews should be aware of the responibilities, an IBOP is required for stripping, the annular element can be changed with pipe in the hole by inserting a split element, ram combination stripping is not recommended, surface pressure determines whether annular stripping is possible (due to rating and increased pressure increases wear), field test show good results at 800 psi but unpredictable at 800 psi, reduce the annular pressure to allow drill pipe to be stripped easier, a a surge dampener is usefull to allow tool joints to pass through the annular without increasing annular pressure

Answer 12

Circulate out the influx if it is above the circulation point, bullhead, or lubricate and bleed if at BOP

Answer 13

Bleed off volume equal to the closed end steel displacment

Answer 14

Maintaining a constant surface pressure by bleeding fluid through the choke as pipe is run (Most preferred)

Answer 15

When the drill string penetrates the influx, the height increases. As the height of the influx increases, hydrostatic pressure decreases and the casing pressure must increase.

Answer 16

1. Calculations: bit depth vs. kick depth, pressure increase due to influx penetration, net upward force vs. downward force, determine appropriate safety factor, and calculate theoreticla bleed volume per stand 2. Stab and make up the IBOP on top of te FOSV 3. Regulate annular closing pressure to permit stripping (A small leak is desirable) 4. Strip into the well until you establish the desired safety factor 5. Continue by stripping to the desired depthwhile bleeding of fhte calculated fluid volumeper stand

Answer 17

1. Calculations: net upwward force vs. downward force, theoreticla bleed volume per stand, determine safety factor, choose PI and MI, bit depth and kick depth, calculate increase in pressure while penetrating bubble 2. Stab and make up IBOP on top of FOSV 3. Regulate annular stripping pressure to permit stripping (A small leak is desirable) 4. Strip into the well until you establish the desired safety factor 5. Continue stripping into the well keeping casing pressure constant 6. When the difference between total fluid bled and pipe displacement equals the MI, strip in while increasing pressure to the next PI step 7. Repeat steps 5 and 6 once the PI has been reached 8. Upon penetrating the bubble: Allow casing pressure to increase by predetermined ammount and adjust step 6 for new MI 9. Repeat steps 5 and 6 until at desired epth

Answer 18

Stripping with volumetric control is complex, eliminate the bubble penetration calculation by adding a safety factor equal to the pressure increase, calculate the MI using the capacity factor around the drill pipe, do not fill the pipe completely to keep track of volumes better, when stripping with volumetric only one step may be achieved before reaching bottom,

Answer 19

If rotating pipe is necessary, the pipe should be reciprocated as well. Several incidents have occurred where pipe being rotated has been severed due to steel components that support rubber annular BOP components

Answer 20

An inhibiting agent that lowers the temperature at which hydrates would be expected to form

Answer 21

Used to dissolve existing hydrate formations