Wellhead equipment Introduction Based on API 6a & NACE

Wellhead Equipment
Introductions

Well Head Usages
• Casing & Tubing Hanging
• Reservoir & Drilling Fluid Flow Control
• Fluid flow Rate Adjustments
• Well Safety

Well Head Types
• Based On Bore Size
• Based On Working Pressure: (PSI)
• Based on Material Class:
• Block Types:
• 2000
• 3000
• 5000
• 10000
• 15000
• 20000
• AA
• BB
• CC
• DD
• EE
• FF
• HH
• Y-BLOCK
• I-BLOCK
• Sweep Bend
• Cross Type

Casing Head Scheme.
Casing Head Housing
Casing Head Spool(s)
Tubing Head Spool
BOP's Stack

Casing Head Housing
These units are designed for moderate duty service
where ease of operation is desired.
useful in:
• low pressure
• high temperature service.
Units are available in:
• nominal flange sizes to 13 5/8"
• pressures to 5000 psi.
casing head housings are available with either:
• female threaded
• slip-on (weld) lower connection.
the slip-on connection housing has a 1/2" NPT test
port, which allows testing of the weld integrity.

Casing Head Housing
2000 psi casing head spools and Higher pressure
rated spools are provided standard with 2 1/16"
studded side outlets.
Other thread sizes, studded side outlet sizes or
extended side outlets are also available.
Flanged outlets are threaded internally for valve
removal control plugs unless otherwise
specified. Threaded outlets may be equipped
with valve removal nipples if required.
The casing head housing may be furnished with a
landing base when required. Landing bases are
used to distribute suspended tubular loads over
a larger surface area and reduce bearing loads
on surface pipe.

Casing head spools are provided with a restricted area
packoff in the lower ID profile to isolate annulus
pressure and allow for transition to higher
pressures in the upper connections.
The lower flange connection contains a 1/2" NPT test
port, which allows positive testing of annulus seals.
ID profiles of WS casing heads provide for a bit guide
above the lower connection.
The bit guide protects wellbore tubulars while
maintaining the greatest casing access. Other bore
dimensions are available if required.
Profile diameters are based on API minimum restricted
bore calculations for the lightest casing weight.
Casing Head Housing

Non-Auto Casing Hangers
Non-Auto casing hanger is designed for
general service where control of annulus
pressure in the casing head bowl is not
critical.
Sharp hardened inner teeth support
suspended casing weight up to 60% of the
pipe body yield strength. A minimum
weight of only 5000 lbs, is required to
initiate hanger operation.
primary seal may be used in conjunction with
the WS-4 casing hanger to add annulus
sealing capabilities. Self energizing O-ring
seals isolate pressure at the casing wall
and casing head bore providing positive
sealing to 5000 psi

Auto Casing Hangers
Auto casing hanger is designed for critical
service and deep well completions where
high casing weights place an unacceptable
strain on conventional slip mechanisms.
The integral sealing element is automatically
energized with release of the casing weight. A
tooth profile on the back of tapered slip
elements help restrict radial loading and
increase ultimate capacity.
casing hangers are capable of supporting 80% of
the pipe body yield strength. Working
pressure to 15,000 psi is acceptable with
adequate suspended load to fully energize
seal.

Semi-Auto Casing Hangers
Semi-Auto casing hanger is designed for critical
service where well control throughout
completion operations is essential.
The integral sealing element is automatically
energized with release of the casing weight.
When light casing loads or changes in operating
conditions dictate the seal may be re-
energized manually after removal of the BOP.
This type casing hanger is capable of supporting
70% of the pipe body yield strength.

Tubing Head Spools
• Primary functions of tubing head
– Suspend tubing with hanger
– Seal between tubing and annulus
– Provide access ports to annulus
• Gas-lift gas
• Inhibitor injection
• Circulating the well
– Provide mounting for adapter flange
or Xmas tree

Tubing Head Spools
These units are designed for heavy duty and
severe service conditions or where the
operator anticipates other factors which
may limit the effectiveness of a tapered
profile.
They are especially useful in high pressures
or where tubing weight makes it
necessary to reduce hoop stresses in the
wellhead body.
Units are available in nominal flange sizes of
7 1/16" and 9" with pressure ratings to
20,000 psi.
tubing head spools are provided with a
restricted area packoff in the lower ID
profile to isolate annulus pressure and
allow for transition to higher pressures in
the upper connections.

Tubing Head Spools cont.
secondary seal is standard for spools up to
5,000 psi and integral P seals are utilized
for10,000 through 20,000 psi equipment.
The lower flange connection contains a
1/2" NPT test port, which allows positive
testing of annulus seals.
Two 2 1/16" studded side outlets are standard
on all tubing head spools. Other studded
side outlet sizes, extended side outlets or
threaded side outlets are available.
Flanged outlets are threaded internally for
valve removal control plugs unless
otherwise specified.
ID profiles of tubing heads provide for a
guide above the lower connection. Profile
diameters are based on API minimum
restricted bore calculations for the
lightest casing weight.
This guide protects wellbore tubulars and
directs the tubing string into the open
bore during the running operations

Tubing Hangers
Straight profiles allow for greater suspended tubular loads
without exceeding hoop stress design criteria in the
wellhead body.
hangers are provided with WHI’s model H back pressure valve
for use in well control during completion and workover
operations.
the feature of extended neck design to isolate wellbore fluids
and protect the API ring seal from damage or corrosion.
is a split wraparound mandrel used to provide annulus sealing
capability for well control. Seals are mechanically energized
with the tubing head lockscrews.
hangers have an additional feature of two control line ports to
the extended neck model. These ports are accessed through
the tubing head adapter.

Back Pressure & Check ValvesBack Pressure & Check Valves
• Installed into tubing hanger toInstalled into tubing hanger to
close in a well, (for tree removal)close in a well, (for tree removal)
• Single or double check availableSingle or double check available
to release bore pressureto release bore pressure
• Run through polished rodRun through polished rod
lubricatorlubricator SealSeal
HandlingHandling
ThreadThread
HangerHanger
ThreadThread
ValveValve
SpringSpring
ValveValve
StemStem

Secondary Seals - PACK OFF
All spools are provided with a secondary seal in the lower
flanged connection. This seal allows for annulus
pressure control as well as the possibility of increases
in pressure rating between the lower and upper
connection. These seals have been designed for
efficient operation and reliability at various conditions.
self energizing O-ring seals maintain annulus pressure
isolation. The seal can be changed to allow a range of
casing sizes within the same spool. This type of seal is
applicable to 5,000 psi pressure rated service.
The integral P seal incorporates a mechanically energized
elastomer ring to maintain annulus pressure isolation.
Anti-extrusion materials allow for higher pressure
service than conventional O-rings. The seals are
energized by injecting plastic packing behind the seal
ring. This allows for reenergizing the seal while a spool
is still in service.
The floating P seal operates in the same manner as our
integral P seal while allowing for interchangeability
within the spool. Floating P seals provide dependable
service through 15,000 psi pressure rating.

FLANGES
Pack-off flanges are designed to fit over wellbore casing and
provide an auxiliary seal. With the flange in place, a jump in
pressure rating can be achieved in a minimum of space. The
flange allows the operator to test between the flange and the
annular seal in the section above or below.
P.O.F. is available in all nominal flange and casing sizes. Flanges
with a working pressure rating of 2,000 and 3,000 psi are
provided standard with pressure energized O-ring seals .
Flanges with pressure ratings of 5,000 to 15,000 psi are
provided standard with two integral P seals
Crossover flanges (Adaptor flanges) are used where a change in
flange size or a decrease in flange pressure rating is required with
no need for an annulus pressure seal. Flanges are typically double
studded to minimize wellhead stack height and reduce cost .
If required, the operator may specify a height for the flange. The units
may also be provide to a specified height with through bolted
flanges to achieve required spacing. WXF is available in all
nominal flange size and pressure ratings

Companion flanges are available in nominal flange sizes from 2
1/16" to 5 1/8" and pressure ratings to 5,000 psi. Threaded
connections are either line pipe or upset tubing of the same
nominal size as the flange. Since pressure ratings are limited by
the rated working pressure of the threaded connection, other
thread types can be furnished on request
Blind flanges are available in nominal flange sizes from 1 13/16" to 5
1/8" and pressure ratings to 20,000 psi
Blind flanges are available in nominal flange sizes from 1 13/16" to
5 1/8" and pressure ratings to 20,000 psi. Flanges to 10,000 psi
are provided standard with one 1/2" LP gage port connection.
Flanges for 15,000 and 20,000 psi service are provided
standard with one 9/16" auto clave gage port connection
Weld neck flanges are available in nominal flange sizes from 1
13/16" to 5 1/8" and pressure ratings to 20,000 psi

FeaturesFeatures
Tubing StringTubing String
Handling ThreadHandling Thread
Annular SealAnnular Seal
Tubing HangerTubing Hanger
LockLock
ScrewsScrews
BPV ProfileBPV Profile
Tubing SpoolTubing Spool
Neck SealNeck Seal

Ball Valve with Adapter PackoffBall Valve with Adapter Packoff
Fail Close ActuatorFail Close Actuator
Tubing HangerTubing Hanger
Plastic Injection PortsPlastic Injection Ports
TestTest
PortsPorts
BPV ThreadBPV Thread

GASKET SELF SEALING
RING
BX
RX

 The stem rotates
 The gate moves up and
down
X-mas tree valve

Xmas Tree Selection
Well Type Water Oil Gas
3000 3000 30005000 5000 5000 1000010000Rating (psi(
Tree Type
Flanged
Monoblock
Yes
No
No
Yes
Yes
No
No
Yes
No
Yes
No
Yes
No
Yes
No
Yes

Multiple Completions
• Cases where more than one completion
string installed
–Each string independently suspended
–Must seal off tubing casing annulus
• either independently or collectively
–Independent control of fluid flow in each
string

Stage 1: Casing Head Housing
Step 1: Conductor 30”
1. Install the conductor 30” in advance.
2. Cut the conductor to the required height.
3. Before installing the Casing Head Housing, confirm with the
Superintendent that the top of conductor is at the right
height.

Step 2: Surface Casing Prepare
1. Inspect casing head housing assembly (CHH( including
their seal areas, to make sure they are in good condition
without any damage. Repair or replace if necessary.
2. Lift base plate onto the outer circle of the 20” casing, and
just lie down to the top side of 30” conductor.
3. Place the CHH onto the slide car and move it to close the
conductor.

Step 3: Install Casing Head Housing (CHH(
1. Lift casing head vertically and check the bottom 20” inside
surface and grease injection seal, then coat grease on 20”
inside bore;
2. Mark 7.2m above the drilling platform on the 20" casing and
then cut it, the distance between the cutting head face of
20" casing and the cutting head face of 30" casing is
200mm;
3. Polish and clean the head face of 30“, 20” casing
separately and make sure they are on the horizontal level,
and then polish the head face of 20“ casing to make sure
there is not defect on outer 10mm 30 DEG chamfer angle;
4. Polish the outer surface 20" with the emery cloth and grater
and then check it to make sure it is smooth and there is not
any neck defect;

Step 3: Install Casing Head Housing (CHH( Cont.
5. Lift the casing head vertically, check the bottom of the 20"
inner bore and make sure there is not any defect and clean
it with water then make it dry;
6. Lift casing head on the top of 20" casing. As per
requirement to put casing head in alignment with gate valve
then land off slowly;
7. Weld the bottom of the casing head housing with 9-5/8"
casing, warm-up in advance, after welding keep the surface
chilling for 1 hour to make sure the welding is secure and
reliable.
8. With cementing of surface casing ready, slack off the
weight of surface casing string.

Step 4: Clean the Casing Head Housing (CHH(
1. Clean out inside the CHH with water hose or clean-out tool.
2. Shut off water and inspect if any dirties remained inside. If
necessary, clean again.
3. Clean top flange surface and ring groove of CHH.

Stage 2: TEST PLUG / COMB. TOOL & WEAR BUSHING
Step 1: BOP Test
1. Clean the ring grooves of the flanges of CHH, riser adapter (if required(, drilling spools.
2. Take right ring gaskets and apply a light coat of grease to them.
3. Apply a coat of grease to the ring grooves and place the ring gaskets into the grooves.
4. Install drilling spool and BOP stack onto top of CHH. make up the bolts and nuts.
5. Inspect the connection threads and O-rings of test plug.
Replace defected ones.
1. Apply a light coat of oil to O-rings.
2. Run down one stand of three drill pipes and at
a comfortable level lock the final one into Kelly
bushing slips of Rotary Table.

Step 1: BOP Test
8. Make up one drill pipe 4-1/2” IF to the top box of test plug and lift the test plug.
9. Make up bottom box of the test plug to the top of drill pipe that locked in the Kelly
bushing slips.
10. Remove the Kelly bushing slips to lift the test plug.
11. Lower the test plug through the BOP stack and drilling spool and seat it in CHH.
12. Slack off the block hook to release the test plug sitting in CHH.
13. Open one side outlet valve, close BOP pipe rams and increase water pressure to the
required pressure rating for test.
14. Hold the test pressure at the rating for a period as required by the Superintendent.
Any leakage will be read from a pressure drop of the gauge and/or test fluid witnessed
out of the side valve of CHH.

Step 2: Run down Wear Bushing.
1. With pressure test qualified, open the BOP rams to lift the test plug and drill pipes.
2. Remove the drill pipe from the test plug.
3. Divert the test plug and make up again the drill pipe to the test plug /combination tool for running
down wear bushing.
4. Lift the combination tool and make the ears of combination tool into the groove of wear bushing,
rotate the combination tool 1/4 turn clockwise to gear into wear bushing.
5. Check O-rings of wear bushing and replace defected ones.
6. Apply a light coat of grease to O-rings.
7. Lift combination tool / wear bushing, lower them through the BOP stack and seat in CHH.
8. Rotate the combination tool 1/4 counter-clockwise to release it from wear bushing and lift the
combination tool.
9. Run down drill bit and drill the next section as required.

Stage 3: SLIP CASING HANGER
Step 1: BOP Test
1. Clean the ring grooves of the flanges of CHH, riser adapter (if required(, drilling
spools.
2. Take right ring gaskets and apply a light coat of grease to them.
3. Apply a coat of grease to the ring grooves and place the ring gaskets into the grooves.
4. Install drilling spool and BOP stack onto top of CHH. And make up the bolts and nuts.
5. Inspect the connection threads and O-rings of test plug. Replace defected ones.
6. Apply a light coat of oil to O-rings.
7. Run down one stand of three drill pipes and at a comfortable level lock the final one
into Kelly bushing slips of Rotary Table.
8. Make up one drill pipe 4-1/2” IF to the top box of test plug and lift the test plug.

Step 1: BOP Test
9. Make up bottom box of the test plug to the top of drill pipe that locked in the Kelly
bushing slips.
10. Remove the Kelly bushing slips to lift the test plug.
11. Lower the test plug through the BOP stack and drilling spool and seat it in CHH.
12. Slack off the block hook to release the test plug sitting in CHH.
13. Open one side outlet valve, close BOP pipe rams and increase water pressure to the
required pressure rating for test.
14. Hold the test pressure at the rating for a period as required by the Superintendent.
Any leakage will be read from a pressure drop of the gauge and/or test fluid witnessed
out of the side valve of CHH.

Step 2: Run down Wear Bushing.
1. With pressure test qualified, open the BOP rams to lift the test plug and drill pipes.
2. Remove the drill pipe from the test plug.
3. Divert the test plug and make up again the drill pipe to the test plug/combination tool
for running down wear bushing.
4. Lift the combination tool and make the ears of combination tool into the groove of
wear bushing, rotate the combination tool 1/4 turn clockwise to gear into wear
bushing.
5. Check O-rings of wear bushing and replace defected ones.
6. Apply a light coat of grease to O-rings.
7. Lift combination tool / wear bushing, lower them through the BOP stack and seat in
CHH.
8. Rotate the combination tool 1/4 counter-clockwise to release it from wear
9. Run down drill bit and drill the next section as required.

Step 1: Retrieve Wear Bushing
1. Drill the section to required depth.
2. Make up drill pipe to combination tool and lower it through BOP stack.
3. According the marks, when the combination tool in the CHH, slowly lower the
combination tool till it seems to be supported by wear bushing.
4. Rotate the combination tool clockwise until the drill pipe drops approximately 4.5”.
This indicates the lift ears of combination tool geared into the slots of wear bushing.
5. Slack off all weight to make sure the combination tool is seated down and rotate the
combination tool clockwise 1/4 turn to engage the lift ears of combination tool fully into
the slots of wear bushing.
6. Check to ensure all tie down screws have been retracted.
7. Slowly lift the combination tool and wear bushing through BOP stack.
8. Release the wear bushing with combination tool.

Step 2: Slip Casing Hanger
Clean out CHH.
1.Make up drill pipe to clean-out tool
2.Run the clean-out tool through BOP stack into CHH
3.Jet a high-pressure water to clean the bowl of CHH.

Prepare Before running Slip Casing Hanger..
1.Mark on the casing circle on the basis of the top head face of the casing head housing,
lift up the casing about 200mm above the marking..
2.Clean and inspect surface of casing circle and surface of casing head housing inner
bore, make sure that there is not any defect, then coat the butter on the inner bore.
3.Fold the two board on the casing, and then put it on the top head face of casing head
housing.
4.Clean the casing hanger which have been removable in advanced, put it on the Ha Fu
board and fasten the Ha Fu studs symmetrically.
5.Tight down the slip properly, lift the casing appropriately, ensure it is in the same with
the casing head housing, and then remove the Ha Fu board.
6.Slowly put down the casing hanger, meanwhile pay attention to the change of the hook,
when the hanging load is reduced to 0, fix the hook and hang the casing to wait for the
cementing of the casing.

Prepare Before running Slip Casing Hanger..
7.When the casing is cementing, slowly low down the hook, If the casing hanger is seated
on the shoulder successfully, remove the elevator and BOP.
8.Mark on the 150mm of the casing above the basis of head face of casing head housing.
9.Cut down the casing with gas cutting, then polish the top head face of the casing head
housing with manual rasping machine, ensure the corner is 30°×10 chamfer.
10.Clean and inspect the ring groove and ring gasket of casing head top head face,
ensure that there is not any defect then coated the butter on the ring groove, clean the
ring gasket then put it into the ring groove.
11.Top up the hydraulic oil in the cavity of casing head housing, which is helpful for the as
below pressure testing job, mean wile coat the butter on the surface of casing.

Stage 1: Casing Head Spool
Step 1: Install Casing Head Spool (CHS)
1. Remove Drilling Spool and BOP Stack.
2. Clean top flange of CHH and check the flange face and ring gasket groove to make
sure no damage. Repair or replace CHH if serious damage found.
3. Lift the CHH on the slide cart.
4. Move the slide cart close to CHH and lift CHS about 1 meter above CHH.
5. Clean and check CHH especially its flange faces and ring grooves against defects.
Take a new correct ring gasket and check against defects.
6. Apply a light coat of oil to the ring gasket and grooves of CHS and CHH. Place the
ring gasket into the ring groove of top flange of CHH.

Step 1: Install Casing Head Spool (CHS)
7. Align four or more studs with nuts in the stud holes of bottom flange of CHS.
8. Lower CHS slowly at a speed of no more than 1m/min while keep the bottom flange of
CHS horizontally and make sure the studs going through the stud holes of top flange
of CHH.
9. Make up all the studs and nuts to connect CHS to CHH.

Step 2: Pressure Test
Grease Injection
1.Check the test pump, high hoses and fitting to make sure they are in good condition. Fill
the sleeve with grease.
2.Un-screw the blanking plugs of upper injection port and its corresponding vent port of
bottom flange of CHS.
3.Make up the injection nipple to the upper injection port.
4.Use the test pump to inject grease until the grease comes out of the corresponding vent
port, make up the blanking plug into the vent port.

Grease Injection
5.Inject grease to increase the injection pressure to maximum pressure rating or 80% of
the casing collapse pressure, or as per required by the Superintendent, whichever is less.
6.With the pressure stabilized, hold the pressure at the duration of 15 minutes or as per
instructions by the Superintendent.
7.With the pressure test approved by the Superintendent, remove the pump and fittings
and make up the blank plug into the injection port.
8.Repeat above step 2.5.1.2 to 2.5.1.7 to finish grease injection into lower injection port.

Pressure Test
1.Remove the grease sleeve from the high-pressure hose line and fill the pump with light
hydraulic oil.
2.Un-screw the blanking plug of the test port between the two injection seals and remove
the check valve.
3.Make up the high-pressure nipple to the test port.
4.Hand-pump the oil to increase the pressure to maximum pressure rating or 80% of
the casing collapse pressure, or as per required by the Superintendent, whichever
is less.

Pressure Test
5.Hold the pressure at the duration of 15 minutes or as per instructions by the
Superintendent. No pressure drop read from the pump pressure gauge will be qualified.
6.With a satisfactory test achieved, open the check valve of hand pump to release
pressure, and remove the fittings. Make up the check valve and blanking plug into the test
port.
7.Un-screw the blanking plug of the test port between the lower injection seal, ring gasket
and body seal of slip casing hanger, and remove its check valve.
8.Make up the nipple to the test port.

Pressure Test
9.Hand-pump the oil to increase the pressure to maximum
pressure rating or 80% of the casing collapse pressure, or
as per required by the Superintendent, whichever is less.
10.With a satisfactory test achieved, open the check valve of
hand pump to release pressure, and remove the fittings. Make
up the check valve and blanking plug into the test port.
11.Install drilling spool and BOP stack onto CHS
12.Repeat above Part 1- Stage 2 for BOP test and running
down

PLUG TESTER RUNNING SCHEM.

WEAR BUSHING RUNNING SCHEM.

CLEAN OUT SCHEM.

1. Repeat the procedures of above Part 1 - Stage 3 Running Slip Casing Hanger

Stage 1: Tubing head Spool
Refer from Figure 27 to 30.
1. Install THS with the same procedure as installing CHS.
2. Pressure Test with the same procedure as above Part 2 Stage 2 Pressure Test.

Stage 2: TUBING HANGER
Step 1: Prepare before running tubing hanger
Inspect the Tubing Hanger and Pup Joint to verify:
•bore is clean and free of debris
•threads are clean and undamaged
•metal seals are clean and undamaged
•Seal area inside THS is clean and undamaged
Make up BPV inside the Tubing Hanger.
• Check BPV and running tool.
• Make up BPV to running tool.
• Install BPV into Tubing Hanger.
• Release the running tool from BPV and retrieve the running tool.

Step 2: Run down Tubing Hanger.
1. Run the tubing string to designed depth.
2. Lock the last stand of tubing by Kelly bushing slips at a comfortable level in the
rotary table for installation of Tubing Hanger.
3. Orient the tubing hanger with the body MX metal seal downward and make up the
landing tubing to top box end of Tubing Hanger.
4. Apply a light coat of oil to the seals of Tubing Hanger including metal-to-metal
seals.
5. Suspend the hanger with the pup joint at about 1 meter above the final stand of
tubing string.
6. Lower the tubing hanger to make pup joint just contact the top end of final tubing.

Step 2: Run down Tubing Hanger.
7. Make up the pup joint to the top end of final stand of tubing string.
8. Slightly lift the whole tubing string to remove the Kelly bushing slips.
9. Carefully run down the tubing hanger / tubing string through the BOP stack and
into THS.
10. Launch the Tubing Hanger onto the shoulder in THS and slack off all
11. Make tie down screws to hold tubing hanger and energize MX body metal seal.

Stage 1: CHRISTMAS TREE
Step 1: Install Christmas Tree
1. Lift the Christmas Tree assembly and check to confirm:
 bore is clean and free of debris.
 Seal area in tubing head adapter is clean and undamaged.
 Ring grooves and threads are clean and undamaged.
 All valves are fully open
 Use leveling rule or instrument to verify the bottom flange is horizontal.
 Clean and apply a light coat of oil to ring gasket, ring grooves.
 Place the ring gasket into the ring groove of top flange of THS.

Step 1: Install Christmas Tree
2. Run down Christmas Tree assembly at a speed of no more than 1 m/min.
3. With the adapter bottom flange approaching the extended neck of Tubing hanger,
place four or more studs with nuts in cross alignment into the stud holes of top
flange of THS to make sure the tubing head adapter in alignment with the THS.
4. Launch the Christmas tree assembly onto THS.
5. Make up the studs and nuts in an alternating cross pattern to connect Christmas
tree with THS.

Step 2: Pressure Test to Tubing Hanger seals
Grease Injection to the seal of Tubing Hanger
1.Check the test pump, grease sleeve, high-pressure hoses and fitting to make sure
they are in good order. Fill the sleeve with grease.
2.Un-screw the blanking plugs of injection port and its corresponding vent port of
bottom flange of Tubing Head Adapter.
3.Make up the injection nipple to the injection port.
4.Use the test pump to inject grease until the grease comes out of the corresponding
vent port, make up the blanking plug into the vent port.
5.Inject grease to increase the injection pressure to maximum pressure rating or 80%
of the tubing collapse pressure, or as per required by the Superintendent, whichever is
less.
6.With the pressure stabilized, hold the pressure at the duration of 15 minutes or as
per required by the Superintendent.
7.With the pressure stabilized, remove the pump and fittings and make up the blank
plug into the injection port.

Step 2: Pressure Test to Tubing Hanger seals
Pressure Test to Injection Seals of Tubing Hanger
1.Remove the grease sleeve from the high-pressure hose line and fill the hand pump
with light hydraulic oil.
2.Un-screw the blanking plug of the test port between the injection seal, ring gasket
and body seal of Tubing Hanger and remove the check valve thereof.
3.Make up the high-pressure nipple to the test port.
4.Hand-pump the oil to increase the pressure to maximum pressure rating or 80% of
the tubing collapse pressure, or as per required by the Superintendent, whichever is
less.
5.Hold the pressure at the duration of 15 minutes or as per instructions by the
Superintendent. No pressure drop will be qualified.
6.With a satisfactory test achieved, open the check valve of hand pump to release
pressure, and remove the fittings.
7.Make up the check valve and blanking plug into the test port.

Step 3: Pressure Test for X-mas Tree
1. Close the wing gate valves & open the master valves & swab valves of Christmas Tree
2. Connect clean water supply to Tree cap union.
3. Increase the pressure to maximum pressure rating or 80% of the tubing collapse
pressure, or as per required by the Superintendent, whichever is less.
4. Hold the pressure for 15 minutes or as required by the Superintendent. No pressure drop
will qualify MS metal seal.
5. With a satisfactory test is achieved, discharge the water supply pump, remove the water
supply line from Tree cap.
6. Make up BPV running tool to the tree cap to retrieve the BPV.
7. Make up Tree cap union.

ConventionalConventional
WellheadsWellheads
API 6 AAPI 6 A

Agenda
1. API 6 A
2. Wellhead
3. Control Lines
4. Wear bushing & Running Tool
5. BPV & VR Plugs
6. Gaskets
7. Ball Valve with Adapter
8. Block Tree
9. Conventional & Compact Wellheads
10. Feedback – Discussion

API 6 A – ISO 10423
API 6A :
•Wellhead
•Christmas Tree Equipment
This specification includes detailed requirements:
•tubular suspension equipment
•valves and fittings used at the location of oil and gas wells
Specification 6A pressure rating from 2000 to 20,000 psi maximum rated working pressures

API 6A APPLICABLEAPI 6A APPLICABLE
EQUIPMENTEQUIPMENT
API 6A Applicable Equipment
Wellhead
Equipment
Connectors and Fittings Casing and Tubing
Hangers
Valves and Chokes Loose
Connectors 1
Other
Equipment
casing head housings cross-over connectors mandrel hangers single valves weld neck connections actuators
casing head spools tubing head adaptors slip hangers multiple valves blind connectors hubs
tubing head spools top connectors actuated valves threaded connectors presure boundary
penetrations
cross-over spools tees and crosses valves prepared for
actuators
adaptor and spacer
connections
ring gaskets
multi-stage head housings
and spools
fluid sampling devices check valves bull plugs running and testing
tools (in Annex H)
adaptor and spacer spools chokes valves removal plugs wear bushings
(in Annex H)
surface and underwater
safety valves and actuators

back-pressure valves

Charpy V-Notch test
• Quantitative Results:
• The quantitative result of the impact tests the energy
needed to fracture a material and can be used to measure
the toughness of the material and the yield strength.
• Qualitative Results:
• can be used to determine the ductility of a material. If the
material breaks on a flat plane, the fracture was brittle,
and if the material breaks with jagged edges or shear lips,
then the fracture was ductile.
Charpy V Notch Impact Requirements (10 mm x 10 mm)
Temperature Minimum Average Impact Value
Traverse Direction J (ft lb)
Temp Class Test Temp °C (°F) PSL 1 PSL 2 PSL 3 and PSL 4
K -60 (-75) 20 (15) 20 (15) 20 (15)
L -46 (-50) 20 (15) 20 (15) 20 (15)
N -46 (-50) 20 (15) 20 (15) 20 (15)
P -29 (-20) - 20 (15) 20 (15)
R -18 (0) - - 20 (15)
S -18 (0) - - 20 (15)
T -18 (0) - - 20 (15)
U -18 (0) - - 20 (15)
V -18 (0) - - 20 (15)

Temperature & Pressure Class
Temperature
Classification
Operating Range
(min) °C (max) (min) °F (max)
K -60 82 -75 180
L -46 82 -50 180
N -46 60 -50 140
P -29 82 -20 180
R room temperature room temperature
S -18 60 0 140
T -18 82 0 180
U -18 121 0 250
V 2 121 35 250
X 1 -18 180 0 350
Y 1 -18 345 0 650
1 Reference Annex G for details of design and temperature rating of equipment for use at elevated
temperatures.
Note: Annex G is not intended as a material selection guide for high temperature use. Some alloys are
embrittled after repeated or prolonged exposure to elevated temperatures. Care should be used in selection of
alloys for these ratings. If plated or coated materials are used at temperatures greater than 180° C (350° F),
cracking potential can be increased.
API Pressure Rating in MPa API Pressure Rating in PSI
13.8 2,000
20.7 3,000
34.5 5,000
69 10,000
103.5 15,000
138 20,000

Material Class and Min Material
Req.
Material Class
Minimum Material Requirements
Body, Bonnet, End & Outlet Connections
Pressure-Controlling Parts, Stems & Mandrel
Hangers
AA - General Service Carbon or Low-alloy Steel Carbon or Low-alloy Steel
BB - General Service Carbon or Low-alloy Steel Stainless Steel
CC - General Service Stainless Steel Stainless Steel
DD - Sour Service a Carbon or Low-alloy Steel b Carbon or Low-alloy Steel b
EE - Sour Service a Carbon or Low alloy Steel b Stainless Steel b
FF - Sour Service a Stainless Steel Stainless Steel b
HH - Sour Service a CRAs bcd CRAs bcd
ZZ - Sour Service User Defined User Defined
a As defined by NACE MR0175/ISO 15156 in compliance with NACE MR0175/ISO 15156.
b In compliance with NACE MR0175/ISO 15156.
c CRA required on retained fluid wetted surfaces only. CRA cladding of low alloy or stainless steel is
permitted.
d CRA as defined in Clause 3 of this International Standard. NACE MR0175/ISO 15156 definition of CRA
does not apply.
Material Classes DD, EE, FF and HH require compliance to NACE MR0175 (ISO
15156) and responsibility for the choice rests with the purchaser.
Examples of Designations
Class FF-1.5 means:
a) material class FF
b) rated at 1.5 psia

Material Selection
0 to <0.05 psia 0.05 to 0.5 psia >0.5 and <1.5 psia1 >1.5 psia1
0 to <7 psia
AA Non-Sour
Non-Corrosive
DD-0.5 or EE-0.5
Sour
Non-Corrosive
DD-1.5 or EE-1.52
Sour
Non-Corrosive
DD-NL or EE-NL3
Sour
Non-Corrosive
7 psia to
30 psia
BB Non-Sour
Slightly Corrosive
EE-0.5
Sour Slightly Corrosive
2
EE-1.5
Sour
Slightly Corros
EE-NL3
Sour
Slightly Corrosive
>30 psia to
<200 psia
CC Non-Sour
Moderately to Highly
Corrosive
FF-0.5
Sour Moderately to
Highly Corrosive
FF-1.52
Sour Moderately to
Highly Corrosive
FF-NL3
Sour Moderately to
Highly Corrosive
200 psia and up
Corrosion resistant
alloys may be needed
CC or HH Non-Sour
Highly Corrosive
FF-0.5 or HH-0.5
Sour
Highly Corrosive
FF-1.5 or HH-1.5
Sour
Highly Corrosive
FF-NL or HH-NL Sour
Highly Corrosive
It is recommended that Corrosion Resistant Alloys be considered beginning at
CO2 partial pressures of 200 psia.
Consult with engineering for material selection . Additional factors should be considered.

Material Selection
H2S above .5 psia
NACE sour service
based on equipment working pressure
The latest edition of NACE MR0175 is referenced by API 6A 19th edition
(effective 2-1-05) for sour service, and does not allow 17-4 SS for tubing hanger mandrels or stems above 0.5
psia H2S partial pressure unless the customer supplies or approves material specifications per section 4.2.3.3 to
build ZZ trim equipment for a specific application. The
manufacturer cannot rate ZZ equipment for a specific H 2S partial pressure.

H2S BELOW .05 psia
non-NACE
H2S .05 to 0.5 psia
NACE sour service
Non-Corrosive
CO2
BELOW 7 psia
based on flowing pressure
API service: CO2 below 7 psia &
AA H2S below 0.05 psia
general API material requirements for this material class
alloy bodies & bonnets, alloy internal parts alloy tubing hanger mandrels & stems
WG Products Wellhead, Tbg Head: AA Adpt, Tee, Tree Cap: AA
Valves 5M & below: AA
Valves 10M & up: BB w/ 17-4 SS stem
Tbg Hgr: AA (low alloy 110 ksi)
API service: CO2 below 7 psia &
DD-0,5 H2S 0.05 to 0.5 psia
low alloy NACE bodies & bonnets, low alloy NACE internal parts low alloy NACE tubing hanger mandrels &
stems
*SS can be used for internal parts, tubing hanger mandrels, or stems
WG Products Wellhead, Tbg Head: EE-NL Adpt, Tee, Tree Cap: EE-NL
Valves 5M & below: DD-NL
Valves 10M & up: EE-0,5 w/ 17-4 SS stem
Tbg Hgr: DD-NL (low alloy 80 ksi max)
*use FF-0,5 (17-4 SS) tbg hanger if >80 ksi req'd
Customer has the option to specify materials for ZZ Material Class
API service: DD-NL CO2 below 7 psia & H2S above 0.5 psia
low alloy NACE bodies & bonnets, low alloy NACE internal parts low alloy NACE tubing hanger mandrels & stems
*SS can be used for internal parts EXCEPT tubing hanger mandrels & stems
Valves (all) chk w/ eng - trims vary by model & working pressure
Tbg Hgr: DD-NL (low alloy 80 ksi max)
*use HH-NL (Inconel) tbg hanger if >80 ksi req'd
Slightly Corrosive
CO2
7 to 30 psia
API service: CO2 7 to 30 psia &
BB H2S below 0.05 psia
alloy bodies & bonnets, SS internal parts
SS tubing hanger mandrels & stems
WG Products
Wellhead, Tbg Head: AA . Adpt, Tee, Tree Cap: AA
Valves (all): BB
Tbg Hgr: CC (17-4 SS)
API service: CO2 7 to 30 psia &
EE-0,5 H2S 0.05 to 0.5 psia
general API material requirements for this material class low alloy NACE bodies & bonnets, SS NACE
internal parts SS tubing hanger mandrels & stems
Valves (all): EE-0,5 w/ 17-4 SS stem
Tbg Hgr: FF-0,5 (17-4 SS)
API service: EE-NL CO2 7 to 30 psia & H2S above 0.5 psia
general API material requirements for this material class low alloy NACE bodies & bonnets, SS NACE
internal parts CRA NACE tubing hanger mandrels & stems
Valves (all): EE-NL w/ Inconel stem
Tbg Hgr: HH-NL (Inconel)
Moderately to
Highly Corrosive
CO2
ABOVE 30 psia
API service: CO2 above 30 psia
CC H2S below 0.05 psia
SS bodies & bonnets, SS internal parts
SS tubing hanger mandrels & stems
WG Products
Wellhead, Tbg Head: N/A unless unless exposed to well flow
Adpt, Tee, Tree Cap: CC Valves (all): CC
Tbg Hgr: CC (17-4 SS)
API service: CO2 above 30 psia
FF-0,5 H2S 0.05 to 0.5 psia
SS NACE bodies & bonnets, SS NACE internal parts
SS NACE tubing hanger mandrels & stems
WG Products
Wellhead, Tbg Head: N/A unless exposed to well flow
Adpt, Tee, Tree Cap: FF-NL (any fittings are inconel) Valves (all): FF-0,5 w/ 17-4 SS stem
Tbg Hgr: FF-0,5 (17-4 SS)
API service: FF-NL CO2 above 30 psia
H2S above 0.5 psia
SS NACE bodies & bonnets, SS NACE internal parts
CRA NACE tubing hanger mandrels & stems
WG Products
Wellhead, Tbg Head: N/A unless exposed to well flow
Adpt, Tee, Tree Cap: FF-NL (any fittings are inconel) Valves (all): FF-NL w/ inconel stem
Tbg Hgr: HH-NL (Inconel)
For CO2 partial pressures above 200 psia, recommended considering additional factors that influence the effect of CO2, are including:
Temperature pH Sand production Types and relative amounts of produced hydrocarbons
H2S level Chloride ion concentration Water production and composition
consult with engineering to determine if HH-NL should be recommended for some or all components in your assembly
API service: HH-NL CO2 200 psia +
H2S above 0.5 psia
Needed Products
general API material requirements for this material class Wellhead, Tbg Head: use EE-NL unless exposed to well flow CRA NACE (inconel clad) bodies & bonnets, CRA NACE internal parts Adpt, Tee, Tree Cap: HH-NL (any fittings are
inconel) CRA NACE tubing hanger mandrels & stems Valves (all): HH-NL
Tbg Hgr: HH-NL

PSL Definition
API Specification 6A (ISO 10423) recommends product specification levels
(PSLs) for equipment with quality control requirements for various service
conditions. PSLs apply to primary equipment:
•tubing heads
•tubing hangers, hanger couplings
•tubing head adapters
•lower master valves
All other wellhead parts are classified as secondary. The PSL for secondary
equipment may be the same or less than the PSL for primary equipment.

Quality Control Due to PSL
PSL-1 PSL-2 PSL-3 PSL-3G PSL-4
Drift Test Yes Yes Yes Yes Yes
Hydrostatic
Test
Yes Yes Yes, Extended Yes, Extended Yes, Extended
Gas Test _ _ – Yes Yes
Assembly
Traceability
_ _ Yes Yes Yes
Serialization _ Yes Yes Yes Yes

Quality Control Due to PSL
PSL-1 PSL-2 PSL-3 PSL-4
Tensile Testing Yes Yes Yes Yes
Impact Testing K, L K, L, P Yes Yes
Hardness Testing Sampling Single Multiple Multiple
Dimensional
Verification
Sampling Sampling Yes Yes
Traceability _ Yes Yes Yes
Chemical Analysis _ Yes Yes Yes
Visual
Examination
Yes Yes _ _
Surface NDE _ Yes Yes Yes
Weld NDE _ Yes Yes Yes
Serialization _ _ Yes Yes
Volumetric NDE _ _ Yes Yes

Welding Parts Quality Control due to
PSLQuality Control Requirements for Welding
Weld Type Stages PSL 1 PSL 2 PSL 3/3G Preparation
Pressure containing
Preparation - - a
no welding permitted
Completion -
a, b and
(c or d)
a, b, (c or d), and e
Non-pressure containing
Preparation - - a
Completion - a a and e
Repair
Preparation - h h
Completion -
a, b, and
(f or g)
a, b, e and
(f or g)
Weld metal overlay (ring grooves, stems, valve-bore
sealing mechanisms and choke trim)
Preparation - - b b
Completion - b b b
Weld metal corrosive resistant alloy overlay (bodies,
bonnets and end and outlet connections)
Preparation a a a a
Completion a,b a,b a, b, i a, b, i
a Visual examination.
b Penetrant testing inspection for non-ferromagnetic materials and magnetic particle testing for ferromagnetic material.
c Radiation (radiography or imaging) examination. d Ultrasonic examination.
e Hardness test (weld).
f Ultrasonic examination only if weld is greater than 25% of wall thickness or 25 mm (1 in), whichever is less.
g Radiation (radiography or imaging) examination only if weld is greater than 25% or wall thickness for PSL 2 or 20% of wall
thickness for PSL 3, or 25 mm (1 in), whichever is less.
h Penetrant or magnetic particle as applicable for material defects only.
i Measurement of overlay thickness, testing of bond integrity and volumetric examination
shall be according to the manufacturer’s specifications. If the overlay is considered part of the manufacturer’s design criteria or of
the design criteria of API 6A, volumetric examinations shall be in accordance with the methods and acceptance criteria of
7.4.2.3.15.
Note: preparation = surface preparation, joint preparation, fit up and preheat completion = after all welding, post-weld heat
treat and machining

Welding Parts Quality Control due to
PSL
PSL-1 PSL-2 PSL-3 PSL-4
Weld Procedure
Qualification
ASME SECT. IX
With
Hardness Survey
Same as PSL-1 plus Base
Metal Grouping
Same as PSL-2 plus Chemical
Analysis and PWHT Controls
No Welding Allowed
Except for Corrosion Resistant
Alloy Overlays
Welder Performance
Qualification
ASME SECT. IX
Same as PSL-1 plus
Hole Qualification
Same as PSL-2
No Welding Allowed
Alloy Overlays
Welding Consumables,
Instrument Calibration
Documented Controls
Required
Same as PSL-1 Same as PSL-1
No Welding Allowed
Alloy Overlays
Visual Exam of
Weld
_ Required Required
No Welding Allowed
Alloy Overlays
Weld Surface
NDE: PT/MT
_ Required Required
No Welding Allowed
Alloy Overlays
Weld Volumetric
NDE: UT/RT
_
Required For All
Fabrication Welds and
Repair Welds
>25% of Wall
Required For All Fabrication
Welds and Repair Welds
>20% of Wall
No Welding Allowed
Alloy Overlays
Weld Hardness
Testing
_ _ Required
No Welding Allowed
Alloy Overlays

2SV Performance Requirement PR-2

Design validation for PR2 actuators
In order to simulate the actual service conditions, the actuator installed on a
gate valve 7-1/16" (bore:6-3/8"),5000 psi working pressure.
The test medium was hydraulic fluid.
a) Actuator seal test at room temperature:
Two pressure tests performed on the actuator the test medium was water.
1. A test performed at 1000 psi (20% of working pressure) for 3 minutes.
2. A test performed at 5000 psi (100% of working pressure) for 3 minutes.
The above tests were repeated for three times and no leakage observed during
each test.

b) Dynamic open/close pressure cycling test at room temperature:
A dynamic test performed on the actuator at room temperature. The test fluid
was hydraulic oil
Prior to operating the actuator, the gate valve was at closed position and
subjected to a differential pressure of 5000 psi.
The above cycle repeated for 160 times.
The operating hydraulic pressure required to set the valve to open position was
about 1500 psi. The test completed successfully.

c) Dynamic open/close pressure cycling test at maximum rated actuator
temperature:
A dynamic test performed on the actuator at 121 "C. The test fluid was water.

d) Dynamic open/close pressure cycling test at minimum rated actuator
temperature:
A dynamic test performed on the actuator at -18°C. The test fluid was water
(with additives to prevent freezing).

e) Pressure/Temperature cycles:
At the end of last step, the temperature raised to room temperature. A test
pressure of 2500 psi applied to the actuator and the temperature was set to
121°C. During the temperature changes, the pressure was maintained between
2500 to 5000 psi.
After the temperature and pressure stabilization, the pressure was held for one
hour.
It is obvious that the temperature change is less than 0.5C per minute, so the
temperature is stable in this case. The change in pressure between minutes
380th to 440th is about 90 psi (less than 250 psi) so the pressure is stabilized.

The one hour hold period is from minutes 440th
to 500th and the change in
pressure within this period is about 30 psi. The maximum allowed pressure
change is 250 psi, so the test completed successfully.
The temperature reduced to -18°C while maintaining the test pressure between
2500 to 5000 psi.
After the temperature and pressure stabilization, the pressure was held for one
hour. No leakage observed.

The temperature increased to room temperature while maintaining the pressure
between 2500 to 5000 psi then the pressure released.
The temperature increased to 121°C and a pressure of 5000 psi applied to the
actuator. After a hold period of one hour no leakage observed.
The pressure released and the temperature reduced to -18°C and a pressure of
5000 psi applied to the actuator. After a hold period of one hour no leakage
observed.
A pressure test performed at room temperature at 5000 psi for one hour and no
leakage observed.
A pressure test performed at room temperature at 500 psi for one hour and no
leakage observed.

Wellhead equipment Introduction Based on API 6a & NACE

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