Snubbing Operations Exam

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1 / 30

With a work string in the hole a leak develops in the upper stripping 8

What would be the first action to take to enable a leak to be repaired?

Close the blind/shear BOP.

Close the lower stripping BOP and a pipe BOP.

Close the blind BOP.

Kill the well.

2 / 30

Which of the following most affect the position (depth) of the balance point? Choose three answers.

Fluid contents of pipe

Pipe weighUfoot.

Size of annular BOP.

Speed of tripping pipe.

Snub force used.

Wellhead pressure.

3 / 30

Which of the following statements is true if a bleed-off line has a built-in choke?

The choke is only opened when a tool joint is being stripped through the annular.

The built-in choke is usually an adjustable choke.

The choke is usually controlled hydraulically from the basket.

The built-in choke is usually a fixed size orifice.

4 / 30

The stripping annular BOP begins to leak as it is used to pull the pipe out of a live well. What action is required to pull the rest of the pipe out of the hole, if no replacements are available?

Continue to pull out of the hole with the seals leaking.

Use the pipe rams to pull out of the hole.

Start pulling out stripping ram to ram.

Nothing can be done, the well will have to be killed.

5 / 30

If the stripping rams are closed, can pipe ram inner seals be changed out with the pipe in the hole?

Yes.

No.

6 / 30

What is the main disadvantage of forward circulating when carrying out a sand clean-out using a snubbing work string?

The sand separation equipment will experience very high velocities.

The annular velocities will be higher than the tubing velocities.

Sand debris will pass across the BOPs rams.

The work string may become blocked with sand debris.

7 / 30

When installing flanges and adaptors of different pressure ratings and material specifications, which component will determine the maximum test pressure of the rig up?

The component with the highest pressure rating.

The component with the lowest pressure rating.

The component with the lowest material specification.

The component with the highest material specification.

8 / 30

When stripping ram to ram on a high pressure gas well, the operator fails to stop the pipe at the correct space out. The pipe tool joint is forced into the upper stripping ram. What is the correct action to take?

Pull back to the correct space out, isolate the well and inspect the upper stripper ram for damage.

Continue the operation using the lower stripping ram and the upper pipe ram.

Continue with the operation, as the stripper ram is designed to have pipe stripped through it.

Kill the well as the upper stripper rams will be damaged.

9 / 30

Two back pressure valves (BPV) are installed as part of the bottomhole assembly (BHA) during snubbing operations. How can a leak in the lower BPV be identified?

It is not possible to identify, unless both of them are leaking.

The pressure gauge indicates a leak.

Well fluid is entering into the pipe and is starting to flow out of the pipe on surface.

It is found by periodical leak tests during operation.

10 / 30

What can you do to achieve a stable pressure test when testing a large volume riser and snubbing BOP stack?

Use the rig pumps at a very high rate, to pump the test volume.

Ensure that all air is expelled from the.stack before applying pressure.

Use sea water as a test medium, as this will have less compressibility than fresh water.

Use nitrogen, as this can be pumped at a high rate without causing any damage to the equipment.

11 / 30

Is it normal practice to have to change out the stripping ram inner seals during an intervention job?

Yes.

No.

12 / 30

During stripping out of the hole in "pipe light", one of the travelling snubber slips malfunctions. What action is required to make the operation safe?

Close the blind/shear BOP immediately, confirm that the work string has dropped into the hole, and then close the Xmas Tree swab valve.

Secure the work string with secondary set of slips, close the safety rams and confirm that they are not closed around a tool joint. If possible, install the stabbing valve. Replace the slips.

Secure the work string with safety rams and confirm that they are not closed around the slip joint. Switch over to the travelling heavy slips and continue with the operation.

Repair and then test the repaired

13 / 30

You are stripping a work string through the annular BOP when there is a leak in the annular BOP. The work string is "pipe light". What action is required?

Position the work sting, install an open stabbing valve, close the safety rams, cut the annular rubber and wrap around the work string.

Run in hole until the work string is in "pipe heavy mode", then position the work string, install an open stabbing valve and change the annular BOP.

Switch to "ram to ram" stripping until the bottomhole assembly (BHA) is out of the hole. Shut in the well and change annular BOP.

Continue stripping out of the hole until the bottomhole assembly (BHA) is almost at surface.

14 / 30

Which of the following BOPs are a shearing device?

Stripping rams.

Blind shear ram.

Pipe rams.

Annular element.

15 / 30

What are the operational requirements for a non-shearable component in the snubbing string?

The component must be able to be deployed using the safety valve.

The BOP riser must be long enough to accommodate the component.

The component must be at the bottom of the string.

The exact position of the component must be known at all times.

16 / 30

In a risk assessment for a snubbing operation, there is an option to kill the well by bullheading.

What must the crew check before they start the intervention operation?

That the PCE certification is valid for at least 1 month.

That the PCE working pressure is suitable for the entire operation.

That the shut-in tubing head pressure (SITHP) does not exceed the pressure rating of the PCE by more than 25%.

That the PCE has been tested to the anticipated shut-in tubing head (SITHP) pressure.

17 / 30

You are snubbing a flush-joint workstring into a gas well.

The shut-in tubing head pressure prevents the use of the stripper bowl. What surface equipment contains well pressure during the operation?

The shear/seal BOP.

The stationary slips.

The BOP pipe rams.

The stripping rams.

18 / 30

Figure SN0-0002 shows a snubbing unit rigged up on a Xmas Tree.

Figure SN0-0002

Perforating guns will be snubbed into a live well.

What will limit the gun length?

The distance between the lower stripping ram BOP and the lower pipe ram BOP.

The distance between the lower stripping ram BOP and the swab valve.

The distance between the upper stripping ram BOP and the lower master gate valve.

The distance between the upper stripping ram BOP and the surface controlled subsurface safety valve (SCSSSV).

19 / 30

At which stage of an operation are the travelling heavy slips used?

When the weight of the workstring is less than the force of the well pressure.

When the weight of the workstring is greater than the force of the well pressure.

When the stationary light slips have failed

When running or pulling oversized BHA components.

20 / 30

While snubbing a tapered workstring into the well, the balance point has just been passed.

You now need to change to running a larger outside diameter (OD) workstring.

How could this affect the operation?

The workstring might buckle at surface.

You will need to run a drift into the workstring due to the change of pipe size.

You could go back to being pipe light.

You will need to recalculate the hydrostatic pressures.

21 / 30

Figure SN0-0002 shows a snubbing unit rigged up on a Xmas Tree.

Figure SN0-0002

During a snubbing operation, flow is coming from the workstring.

The operator closes the upper pipe rams and installs a stab-in valve on top of the workstring , but reports that the upper pipe rams are leaking.

What action is required?

Close the lower pipe rams.

Install a second stab-in valve.

Rig up a kill hose to the workstring and kill the well

Shear the workstring.

22 / 30

You are planning to snub a flush-joint workstring into a high pressure well. What would be good practice to add to the surface rig up?

An extra shear/seal BOP.

An extra annular BOP.

An additional back-pressure valve (BPV).

An extra set of stationary pipe light slips.

23 / 30

You are running a workstring with external collars into the well using stripping rams as the primary barrier.

One of the stripping rams is leaking and is badly worn.

What should you do?

Continue the operation using the annular BOP as the primary barrier.

Kill the well, retrieve the workstring and repair the stripping ram.

Secure the well then continue the operation using the back-up stripping ram.

Secure the well with two tested barriers and repair the stripping ram.

24 / 30

While snubbing a workstring into a well, you notice the tubing make-up equipment is leaving marks below the connections. These marks will damage the stripper sealing element.

How can you avoid this without affecting the integrity of the workstring?

Reduce the torque setting on the tubing make-up equipment.

Reduce the pressure to the stripper sealing element.

Move the snubbing unit away from the central position over the well.

Reduce the gripping force on the tubing make-up equipment.

25 / 30

The crew are preparing to run a snubbing BHA with a non-shearable component.

What must they do to maintain well control while the non-shearable component passes through the BOP stack?

Ensure the BOP riser is longer than the non-shearable component.

Prevent positioning the non-shearable component across the shear/seal BOP when the string is static.

Position the non-shearable component at the bottom of the BHA.

Run the non-shearable component with a release-sub above it.

26 / 30

After an unsuccessful sand cleanout, you decide to run a tapered string.

How should the surface PCE be reconfigured?

Install a new set of rams in the lower stripper BOP only.

Install a longer riser within the surface rig-up to fit the tapered string.

Install two independent ways of isolating each pipe size.

Install a shear/seal BOP just above the Xmas Tree to ensure the workstring will drop if it is sheared.

27 / 30

During a snubbing operation with a workstring in the well, you replaced the lower stripper element of a dual stripper.

How do you confirm integrity of the new lower stripper element?

Open the vent between the srt ip per elements. Apply test pressure below the lower stripper element.

Equalise the pressure between stripper elements. Apply test pressure above the lower stripper element.

Open the well to the lower stripper element and pressure test with well fluids.

Apply test pressure in between the upper and lower stripper elements.

28 / 30

During a snubbing operation, when is the workstring most likely to buckle?

When pressure testing the downhole check valves.

When the first joints are run into the well.

When the workstring is nearly at depth.

When the workstring size changes to a larger diameter.

29 / 30

When stripping 'ram to ram' into a high-pressure gas well, the operator fails to stop the workstring at the correct space out point.

The operator forces the tool joint into the closed lower stripper ram.

What is the correct action to take?

Pull back to the correct space out point, isolate the well and inspect the lower stripper ram for damage.

Continue with the operation, as the stripper ram is designed to have a pipe tool joint stripped through it.

Kill the well, retrieve the workstring and inspect the lower stripper ram for damage.

Continue the operation using the upper stripper ram and the upper pipe ram.

30 / 30

Figure SN0-0002 shows a snubbing unit rigged up on a Xmas Tree.

Figure SN0-0002

With a workstring in the well, the snubbing PCE is leaking from a connection between the stripper rams.

Which barriers should be closed to allow the leak to be safely repaired?

Lower stripper ram and swab valve.

Lower stripper ram and pipe ram.

Upper stripper ram and upper master gate valve.

Upper stripper ram and lower stripper ram.

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