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Intervention Barriers

• A barrier is defined as a means of containing wellbore pressure and fluids.

• Two effective barriers are required for most intervention operations.

• Consider when barriers are effective (and when they are not) and how to back them up for safety.

• Must be rated to the maximum pressure that can be encountered.

www.GEKEngineering.com 1

Common Barriers • Kill weight fluid column (not just a fluid column) – monitored and

tested • Pipe rams when pipe is in the well • Blind/Blind-Shear when no pipe is in the well • Master valve when pipe is not in the well • CT Flapper valves (dual flappers = one barrier) • Stuffing box/Stripper Rubber • Downhole plugs • Grease seal/ram for braided line (both are one barrier)


1. Nipple

Down

Tree

2. Nipple

Up BOP

Barriers


3-2006

TEST LINETEST LINE

Flanged Choke

Ported w/1-1/2”

NP & Threads

& 2- 10K Needle Valves

Hammer Union

& Bull Plug

3-2006

TEST LINETEST LINE

3-20063-2006

TEST LINETEST LINE

Flanged Choke

Ported w/1-1/2”

NP & Threads

& 2- 10K Needle Valves

Hammer Union

& Bull Plug

What’s Left?

1. Hook up test and kill

lines.

2. Test.

Barriers – last steps


Kill Weight Fluid

KWF = Formation Pore Pressure (psi) / (0.052 * TVD to mid perfs (ft))

where: KWF = kill weight fluid in ppg

TVD

The kill weight fluid must occupy both

the annulus and the tubing with no

voids or other fluids involved.

If the density and level of the fluid are

not monitored, can the fluid be an

effective barrier?


Difference between Surface and Downhole Barriers

• A surface barrier prevents escape of fluids from the well.

• A downhole barrier may also prevent cross-flow between formations.


The barrier during drilling is a well

control barrier that has both hydrostatic

and mechanical control points.

A column of kill weight fluid, monitored

and tested, is a common active barrier.

Multiple barriers


During wireline intervention, the

control method is pressure

control with two or more

barriers.

The barriers for wireline include:

1. Grease or oil seal on the wire

(for dynamic sealing);

2. Packoff for static application

3. Blind/Shear rams

4. Master valve (can cut some

wire, but poses a risk of valve

damage).

Double Bariers


Barriers for Intervention with

Coiled Tubing

Barriers include:

1. Stuffing Box

2. Coiled Tubing BOP

3. Annular Preventer (for

sealing around BHA string)

4. Pipe ram below circulating

cross or Tee.

5. Master Valves – when CT and

BHA are above the top

Master Valve.

Stacked Barriers


Barriers for Producing Wells – usually only

one barrier for many areas:

1. Almost all flow/gathering lines,

separators and pipelines.

2. The flow cross, choke body and other

areas above the tubing hanger

3. Below the tubing hanger for gas lift

supply

4. At any open shoe with gas lift supply

5. Uncemented casing below the packer

Producing Wells – One Barrier


Live Well Workovers

• Top Hole - plug (WL or CT) set at or below packer - top of well is isolated.

Used for:

press test

pickle/cleanout

tubing replacement

fluid unload/swap

equalizing plug www.GEKEngineering.com 11

Typical Conditional Barriers

• Considered a barrier during certain operations but not at other times.

• Examples: – Pipe rams – barrier only when pipe is in the well

– Blind ram, master valve, stripper rubber – barrier only when pipe is out of the well

– Braided line rams – barrier only with grease injection


Layout for a CT BOP


Ram blocks

Lower left – slip blocks

Lower Right – seal blocks

Upper Right – shear or

cutter blocks

Ram Internals


CT BOP w/ kill port


Greased ram section in a BOP prior to the job. Effect of excess grease?

Rams are heavily greased – Cleaning?


Open ram


CT Crushed by ram closure – now, how do you recover it?

Rams for CT must:

1. Center the CT in the BOP body

2. Center the CT in the ram element www.GEKEngineering.com 18

BOP accumulator – pressure

source

Accumulator


What if the flow cross leaks? Control point?


No secondary control below a flow cross


One approach to control


An effective

BOP rig-up.

Note dual valves

and flow control

below the flow

cross.

Stacked BOP


Develop Both Sides?

May be practical for high risk wells.


Unusual Cases

• When running a BHA that cannot be sealed with a pipe ram or cut with a blind shear. Is a special barrier needed for the BHA?

• When changing the elements on a ram or stripper rubber. Is a backup needed?


The Two Barrier Rule

• Barriers may be the same in some instances.

• Both must be capable of controlling the full well pressure.

• Many barriers are conditional – may need back-up.


Some Special Cases

• Snubbing or hydraulic workover – The two (minimum) pipe rams are barriers, but a blind-shear is required for a second barrier while pipe is in the well.

• What is needed when an pipe ram element has to be changed?

• A second blind or blind-shear or master valve or other device is required when pipe is out of the well.


Hydraulic Workover Units


Pipe seal

elements

Pipe ram elements


Hydraulic

workover unit

showing the

gas bypass tube

between pipe

rams.

Hydraulic Workover BOP set


Special cases, continued

• Large BHA or BHA that cannot be cut.

– Annular preventer?

– Downhole valves (SSSV as a barrier????) – SSSV’s are not a good barrier if an object can be dropped from the tool. A dropped object can breach/break the seal offered by flapper type SSSV.

– Pressure operated downhole valves


Special cases, continued

• Fracturing Tree Saver

– Hydraulic deployment

– Second set of valves – temporarily replaces wellhead valve control

– Stinger with seal isolates and “locks-out” wellhead valves


Tree Saver – isolates existing wellhead with hydraulically

deployed stinger with external seals and second set of valves.

Frac Iron

Connection

Remote operated

master valve Manual operated

master valve

Hydraulic cylinders

Mandrel or stinger – with

seals on exterior

Hydraulic pistons

Existing master

valve on well

Well master

valve is closed

Vent

Valve

Tree saver inserted

and locked down.


Special Cases, continued

• What is stability of the barrier?

– To outgassing (seal face failure)

– To high or low temperatures (does it weaken barrier?)

– To corrosion (components weakened by attack?)

– To erosion – erosion of sealing surfaces

– To high or low pressure spikes

– To high or low tensile loads


Special Example - Inflatable Packers

• Are they barriers?

• What is the reliability?

• Do they stay put?

• Has a great deal to do with how much they are expanded and where they are placed. – Good reliability when set in pipe

– Good reliability when placement “slide” is short (less than 1000 ft)

– Good reliability when expansion from initial to set is less than 2x.


Quiz - Barriers

1. What type of equipment must not be sheared in a well control attempt?

2. What type of event or action may render the following barriers useless?

a. Blind ram, no pipe in the hole.

b. Pipe ram w/ pipe in the hole.

c. Stripper rubber on Coiled Tubing.

d. Grease injector with E-line in the well.

e. Flappers on coiled tubing.

3. For each challenge in problem 2, what is a possible solution?


Quiz – Barrier Failure Recovery from Problem #2.

Failure Type Cause Recovery

Blind Ram, face seals destroyed.

Pipe Ram, w/ pipe in hole, no seal.

Stripper rubber leaking on CT

Grease leaking on E-line grease injector, not holding pressure.

Flappers not preventing backflow on cleanout.


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Intervention Barriers - gekengineering.comgekengineering.com/Downloads/Free_Downloads/Intervention_Barrier… · Intervention Barriers ... The barrier during drilling is a well control