CHAPTER 2 PART 2

Question 1

The mechanical device suspending
the drillstring’s weight;

Answer 1

Swivel

Question 2

Long square or hexagonal steel bar with
a fluid path drilled through the center;

Answer 2

Kelly

Question 3

Short drill collar with male threads
on one end and female on the other;

Answer 3

Kelly Saver Sub

Question 4

Revolving or spinning section
of the drillfloor that provides
power to turn the drillstring in a
clockwise direction (as viewed
from above);

Answer 4

Rotary Table

Question 5

Adapter connecting the rotary table
to the kelly;

Answer 5

Kelly Bushing

Question 5

Device used to grip the
drillstring and suspend it in the
rotary table when making or
breaking a connection;

Answer 5

Slips

Question 5

are the active
tongs during breakout (or
loosening) operations;

Answer 5

Tongs

Question 6

are active
during makeup (or tightening)
operations.

Answer 6

Makeup tongs

Question 6

A drillstring turning device;

Consists of one or more
motors (electric or hydraulic)
connected with appropriate
gearing to a short section of
pipe called a quill, that in turn
may be screwed into a saver
sub or the drillstring itself;

Answer 6

Top Drive or Power Swivel

Question 6

The formation pressure is defined as the
pressure at which a fluid or gas exists in the pores of a permeable
rock. This is also called pore pressure.

Answer 6

Formation Pressure

Question 6

The amount of pressure a formation can
withstand before the formation breaks down as a fracture is
initiated, followed by loss of fluid, also defined as Formation
breakdown pressure.

Answer 6

Fracture Pressure

Question 6

The amount of pressure the formation can
withstand before the formation accepts any fluids.

Answer 6

Leak-Off Pressure

Question 7

A combination of one or more Well
Barrier Elements that together constitute a method of containment
of fluids within a well that prevents uncontrolled flow of fluids into
another formation, or, to escape at surface.

Answer 7

Well Barrier Envelope

Question 8

is achieved by ensuring that the mud
hydrostatic pressure overcomes formation pore pressures.

To maintain primary well control, the well should always be filled
with mud with a density within the mud window.

Answer 8

Primary Well Control

Question 8

is achieved by using valves to prevent
the flow of fluid from the well until such time as the well can be
made safe.

Answer 8

Secondary Well Control

Question 8

A flow of formation fluids into the wellbore during drilling operations.
The kick is physically caused by the pressure in

Answer 8

Kick

Question 8

Signs of a kick:

Sudden increase in mud pit level

Well is flowing despite pump off scenarios i.e., mud circulation is
off

Pit level indicators or mud flowmeters are triggered

Answer 8

Kick Detection

Question 9

Two basic types of BOPs

Answer 9

Annular Preventor

Ram Preventor

Question 10

designed to seal off the
annulus between the
drillstring and the side of
hole

Answer 10

Annular Preventor

Question 11

Designed to seal off the annulus
by ramming large rubberfaced
blocks of steel together;

Answer 11

Ram Preventors

Question 12

seal off
open holes

Answer 12

Blind rams

Question 13

– seal off
around drill pipe

Answer 13

Pipe rams

Question 14

– sever drill
pipe

Answer 14

Shear rams

Question 15

seals a range of tubular
sizes

Answer 15

Variable bore rams

Question 16

spacers between preventers that provide hookups for the choke line and kill line during a kick

Answer 16

Drilling Spool

Question 17

a hydraulic pressure unit that keeps liquid under pressure in the tanks and provides a method to open and close the blowout preventers quickly and reliably.

Answer 17

Accumulator Unit

Question 18

an arrangement of piping and special valves, called choke. In drilling mud is circulated in the choke manifold when a kick occurs.

Answer 18

Choke Manifold

Question 19

attached to the blowout preventer stack, usually directly opposite the choke manifold. Heavy weight fluid is pumped to the kill line into the well bore until balance has been restored.

Answer 19

Kill Line

Question 20

– a pipe attached to the blowout preventer stack out of which kick fluids and mud can be pumped to the choke manifold when a blowout preventer is closed in on a kick.

Answer 20

Choke Line

Question 21

- device that is used to remove gas from the mud coming out of a well when kick is being circulating out.

Answer 21

Mud Gas Separator

Question 22

Safety requires constant monitoring of the drilling process; If drilling problems are detected early remedial action can be taken quickly, thereby avoiding major Problems;

Answer 22

Discussion

Question 23

After invasion of formation fluids into the wellbore, the total volume of drilling fluid increases, and the level of the drilling fluid tank rises;

Answer 23

Volume Detection Method for the Drilling Fluid

Question 24

Flow detection method for returning drilling fluid is also one of the means to detect the kick;

Answer 24

Flow Detection Method for Returning Drilling Fluid

Question 25

If there is a total loss and the mud level cannot be seen at wellhead; Acoustic wave signals can be sent downwards along the wellbore, this signal will be reflected on the gas-liquid interface in the wellbore, and the reflected wave will reach the receiving equipment upwards along the wellbore;

Answer 25

Acoustic Wave Method of Total Loss Detection

Question 26

Mudloggers inspect rock cuttings from the shale shaker at regular intervals; Calculations and cuttings descriptions can be matched with the depth, hence, a log of the formations being drilled can be drawn up;

Answer 26

Mudlogging

Question 27

Mudlogging equipment

Answer 27

gas chromatography.

Question 28

Acoustic Wave Method of Total Loss Detection equipment

Answer 28

bayag ko

Question 29

Flow Detection Method for Returning Drilling Fluid equipment

Answer 29

target-type flowmeter, but also electromagnetic flowmeter and mass flowmeter detection are used.

Question 30

Volume Detection Method for the Drilling Fluid equipment

Answer 30

float-level gauges and ultrasonic-level sensors