Chapter 3 Kick Indicatos and Detection

Question 1

Common causes of abnormal pressures are?

Answer 1

Under-compaction in massive shale beds, 
Salt beds, 
Mineralization, 
Tectonic causes, 
Faulting, 
Diapirism, and 
Reservoir vertical height.

Question 2

After a formation containing gas has been drilled, gas may continue to weep or be flushed into the open wellbore. This situation is most common after drilling low permeability formation with formation pressure nearly balanced or slightly underbalanced by wellbore pressure such as when drilling a transition zone. What is happening?

Answer 2

Back Ground Gas .

Question 3

Oil and synthetic oils are soluble to methane and other gases encountered while drilling. They have high gas solubility to natural gas, carbon dioxide and hydrogen sulphide. Which of three is harder to detect?

Answer 3

H2S

Question 4

How to perform a Hard Shut-In (Step 3)?

Answer 4

• If flow is suspected or confirmed, open HCR against a fully closed choke manifold valve or a positively sealing, closed choke.
• Close selected BOP
• Confirm that the well is shut-in and flow has been stopped.
• Inform supervisors.

Question 5

The two main kick detection methods are?

Answer 5

1) Increase in flow from the well relative to that pumped into the well.
2) Increase in pit level.

Question 6

Which IRP must be followed if planned an UBD or MPD well? But does not contain to Coil Tubing.

Answer 6

IRP 22 - “Underbalanced drilling and Managed pressure drilling operations using jointed pipe.” An industry recommended practice (IRP) for the Canadian oil and gas industry volume 22 - May 2011

Question 7

This document states that primary well control is the maintenance of hydrostatic pressure in the well bore that is equal to or greater that the formation pressure to prevent formation flow. What API is this referring to?

Answer 7

Referring to API-RP59, Which is the API recommended practice for well control operations.

Question 8

True or False: It has been statically proven that the use of an RCD (Rotating Control Device) to close in the well makes drilling operations safer.

Answer 8

True.

Question 9

True or False: In MPD (Manage Pressure Drilling) Hydrostatic plus RCD (Rotating Control Device) is the primary well control.

Answer 9

True

Question 10

List the kick indicators in MPD (Manage Pressure Drilling) Operations?

Answer 10

Increase in return flow rate, Increase in pit levels, Increase in annular pressures, Increase in standpipe pressures, and Abnormal Choke Openings

Question 11

When drilling a horizontal well and you take a kick what is going to happen to the self adjusting choke?

Answer 11

It is going to open as the pressure increase, making the well go underbalance.

Question 12

True or False: A given mud weight reduction measured at the surface due to oil and/or saltwater invasions will cause a much greater decrease in the bottom hole pressure that a similar mud which is cut by gas?

Answer 12

True

Question 13

Whose responsibility is it to see that the rig crews are thoroughly schooled in the necessity of keeping the hole full and maintaining records of actual fluid volumes used or returned during trips?

Answer 13

It is the responsibility of the Drilling Supervisor or also known as the Drill Site Manager.

Question 14

Define the Bubble Point pressure?

Answer 14

It is the pressure at which the first bubble of free gas breaks out of solution with a given solution gas/liquid ratio at a given temperature.

Question 15

Why is kick detection more difficult with OBM than WBM?

Answer 15

Experience has shown that formation gas dissolved in OBMs breaks out and expands at or near the surface.

Question 16

What happens to OBM’s density with increased pressure?

Answer 16

Density will increase because volume decreases due to compressibility.

Question 17

What happens to OBM’s density with increased temperature?

Answer 17

Density will decrease because volume increases due to thermal expansion.

Question 18

Why would you use a Hard Shut-in versus a Soft Shut-in?

Answer 18

A Hard Shut-in is faster than a Soft Shut-in and therefore minimizes the size of the kick.

Question 19

Why not just keep the HCR closed from the start of a Hard Shut-in?

Answer 19

So that it does not become stuck closed due to a pressure differential.

Question 20

In a horizontal well a kick is detected but the influx is still in the horizontal section of the well. The SIDPP is 0kPa and the SICP is 0kPa. What type of kick is this?

Answer 20

Swab kick as the SIDPP and the SICP is zero.

Question 21

Why can kick detection be difficult with MPD?

Answer 21

The closed system will want to compensate for the increased surface pressure that the influx will cause. If undetected, the choke will want to open and further reduce EBHP allowing more influx into the well.

Question 22

List the kick indicators in MPD operations:

Answer 22

• Increase in return flow rate
• increase in Pit Levels
• Increase in Annular Pressures
• Increase in Standpipe Pressures
• Abnormal Choke Openings