Size 438 Pump
p-Down Plug an
nd Perfo
orating P
Procedu
ures
O
Operating
g Proced
dures
1
Scope
e
A
All Operation
ns should to be used in conjunction
c
with local HS
SE&S, qualiity and field service proccedures
e
a
as a guidelin
ne for the tec
chnical proce
edures deterrmined as im
mportant to tthe proper fu
unction of the
e
equipment.
T
The efficient and safe de
eployment off perforating
g gun/plug co
ombinations in a horizon
ntal pump do
own
e
environmentt is dependent on properr pre-job planning along with followin
ng deployme
ent procedures that
h
have been developed through field experience
e
along
a
with de
erived calculations.
If you see so
omething outt of the ordin
nary that is cause
c
for co ncern, do no
ot think yourr way through the
p
problem. Sto
op the pumps. There is not
n a time to react.
B
Baker Hughe
es composite
e plugs shou
uld always be
b stored in a closed envvironment aw
way from raiin, snow,
a
and other na
atural elemen
nts.
Note
The
T flow rate
es for this do
ocument are intended fo
or 5.5 inch ca
asing.
The
T values may
m change according to
o casing size
e and/or welll
geometry.
g
If values
v
differr from what iis listed, reco
ord in editab
ble fields
of
o the docum
ment.
T
Throughout the
t operation, high pressures can be encounterred in surfacce lines. If the lines break, fluids
a
and/or gas can
c escape. Lines can sttrike personn
nel. Always assume all llines are pre
essurized.
G
ARNING
WA
High pressurized surface line
es can strike
e personnel
Possibility of se
erious injury
y or death
 Do not enter the presssure pumping
g exclusion zone
 Wear safetty glasses a
and hard hat
 Wear safetty shoes
2 Tool Makeup
M
Procedure
es
C
Conduct rig up
u of the wirre line accorrding to standard operat ing procedures.
O
Only Baker Hughes
H
and essential pe
ersonnel sho
ould be pressent in the pe
erforating exxclusion zone while
rrunning and arming perfo
orating guns
s.
© 2012-2012 BAKE
ER HUGHES INCO
ORPORATED (UNPUBLISHED WOR
RK). All rights rese
erved. Terms and conditions of use: By accepting thiss document, the
re
ecipient agrees this document (together with the contents) is confidentia
al and proprietary property of Bakerr Hughes Incorporrated and includes valuable trade
ssecrets, proprietary information of Bak
ker Hughes (collectively “information”)). Baker Hughes rettains all rights unde
er copyright laws a
and trade secret law
ws of the United
S
States of America and
a other countries. The recipient furth
her agrees the doc
cuments may not be
e distributed, transsmitted, copied or re
eproduced in whole
e or part by any
m
means, without express written consen
nt of Baker Hughes
s, and may not be used
u
in any way de
etrimental to Baker Hughes.
Page 1 of 9
Pump-Down Plug and Perforating Procedures

Do not enter restricted area unless authorized.

Do not drop or impact perforating guns and firing heads under any circumstances

Verify certification of all lifting equipment

Employ clear communications and proper handling techniques
Step
1.
2.
3.
4.
5.
6.
Action
Prepare the first gun/plug run. Insure there is no “screen out” during the fracturing operation prior to final
preparation of the guns.
Generate a tool diagram through measurement of the outside diameter of the various string components,
along with their individual lengths. This will be used in the event the entire or partial assembly is left in
the well and needs to be fished.
The setting tool and composite pump down plug should be made up in the vertical position after the
lubricator and gun assembly are up in the air. If this is not possible, make sure the plug is at the bottom
of the lubricator when hoisting up to blow out preventers. The use of a gun dolly or holly dolly allows for
the horizontal makeup of the plug.
At the designated time, install the pressure control equipment and gun/plug assembly on the well head
and perform the pressure testing of the system.
Ensure that the cable head is bumped up against the grease head by holding down on the wire line, and
once this has been accomplished begin test to required pressure.
Pressure up slowly, allowing the air to bleed off, or use a manual bleed off assembly.
NOTICE
7.
8.
RISK OF SEVERE EQUIPMENT DAMAGE
Pressuring up too quickly can damage the wireline from
superheating of trapped air. Wireline can be severed or
severely damaged. Bleed all trapped air out of the system.
Pressure up slowly.
Bleed pressure off to 100 psi (6.9 bars) above well head pressure prior to opening the master control
valve per pressure control operations.
Place a chalk mark on one side of the drum 90˚ from the wireline pointing up. Count number of wraps
from that flange to where the wireline is on the drum. Record this number. This will provide extra
verification you are where you started from when coming back out of the hole.
Page 2 of 9
Pump-Down Plug and Perforating Procedures
Recommended Operational Practices Direct Shear Wireline Adapter Kit Part List 1.
Before deploying the 438 Composite Bridge or Frac Plug, it is recommended that a clean flush be pumped down to the top perforations 2.
BHI recommends a gauge ring run prior to running any composite plug. IF a gauge ring plug cannot be made do not deploy the first plug faster than 200 ft/min. 3.
Before deploying the plug record the work order numbers for the plug and power charge. 4.
BHI guarantees composite plug performance for 72 hours down hole. Consider deploying a second plug should this time limit be exceeded. 5.
Ensure all perforations have fired before deploying frac ball. 6.
Frac ball should be landed on seat at a rate of 10 bbl/min 7.
Contact BHI district with any quality or operation concerns related to BHI products. Assembly Instructions Step Action 1.
Slide the Adapter Sleeve Bushing (1) onto the E‐4 WLPSA. 2.
Thread Adjusting Nut (5) onto the E‐4 setting tool. Torque connection to 200 ft‐lb (100 lbs with a 24 in wrench) and install Set Screws (3). 3.
Thread Setting Sleeve (4), with right‐hand rotation, past Adjusting Nut (5). Slide the Setting Sleeve up the E‐4 to expose the setting mandrel of the E‐4. 4.
Thread Tension Sleeve (7) onto shear ring. Torque connection to 200 ft‐lb. A backup is required on the shear ring. 5.
Thread Tension Mandrel (6) into Tension‐ Sleeve (7) until it shoulders on the frac plug upper sleeve, hand tight only, and insert Set Screws (8). Thread the Tension Mandrel (6) onto the bottom of the E‐4 setting tool. Torque connection to 200 ft‐lb, and insert Set Screws (9). 7.
Slide Setting Sleeve (4) over the top of the E‐4 until the threads contact. Insert Shear Screws (10) flush into the Setting Sleeve and thread, with left‐hand rotation, the Setting Sleeve until the Shear Screws shoulder on the Tension Sleeve (7) and close the crosslink gap on the E‐4, hand tight only. 8.
Slide the Adapter Sleeve Bushing (1) down to the Setting Sleeve (4) and insert Set Screws (2). 6.
Page 3 of 9
Pump-Down Plug and Perforating Procedures
3 Run in Hole Procedures
Note
Step
1.
Action
Upon permission given from the company man on location, open crown valve, counting the number of
turns to open valve. Verify with company man on number of turns it takes to open the valve.
Note
2.
4.
Ensure the pressure is near equal between the lubricator and well.
After equalizing the well pressure with the lubricator, begin the descent into the well and, after reaching
200 ft (60 m) below surface, the acquisition system can be turned on and approved two-way radios can
be utilized, establishing communications with the pressure pumping control van.
Note
3.
The flow rates for this document are intended for 5.5 inch casing.
The values may change according to casing size and/or well
geometry. If values differ from what is listed, record in editable fields
of the document.
If the company representative insists on higher rates and pressures
in order to increase speed, they must agree to accept the additional
risk of losing the assembly in the well.
Most plug suppliers recommend a maximum descent speed of 200 ft/min (60 m/min). When approaching
the vertical kickoff point, note the tension of the line and assembly.
Just prior to reaching the kickoff point, begin pumping at a rate of 2 bbl/min (330 lpm) At this point note
the total tension on the line. When pumping, do not exceed 600 lbs (270 kg) of line weight over the line
and tool tension. Excess pump pressure could cause an unscheduled cablehead release. Prior to
entering the kickoff, begin recording the CCL log. This will allow an efficient graphical display of collar
lengths while pumping down. Apparent collar lengths greater than 40 ft (12 m) indicate the tool string is
not moving as fast as the wireline.
Pump Rate (bbl/min)
5.
When moving into the horizontal, begin increasing the pump rates no greater than 2 to 3 bbl/min (330 to
500 lpm) until the optimum rate is achieved in the horizontal without exceeding the maximum rate as
calculated from the chart.
Pump Rate (bbl/min)
6.
Monitoring tension and speed:
The amount of surface tension should be such that a small amount of force is needed to hold back the
down hole assembly, being just enough to keep excess slack out of the line. When entering and
travelling through the horizontal, keep in mind that the surface tension will decrease under normal
operating conditions unless there is an abnormal pumping increase. Do not exceed 600 lbs (270 kg)
over normal running tension to avoid a potential unscheduled cablehead release.
A. At 40° deviation, the string weight should be approximately two-thirds of the vertical
B. At the horizontal, the tension should be approximately two-thirds of the tension in the 40° angle
section. Adjust line speed to avoid having the tension drop below 50% of the tension in the 40°
angle section
Page 4 of 9
Pump-Down Plug and Perforating Procedures
Step
7.
Action
Moving into the horizontal, increase the pumping rates at 2 to 3 bbl/min (330 to 500 lpm) until 200 ft/min
(60 m/min) is achieved. Do not exceed the fluid velocity rates as established by the flow calculator chart.
Pump Rate (bbl/min)
Descent Speed (ft/min)
Note
8.
If the company representative requests higher rates and pressures
in order to increase speed, they must agree to accept the additional
risk of losing the assembly in the well.
Use the torque limiter control to fine tune the speed and also provide the accommodation of allowing the
line speed to increase if a flow or pressure surge is encountered, thus avoiding a potential unscheduled
cablehead release.
A. Deployment speeds significantly less than the desired 200 ft/min (60 m/min) could indicate
sand accumulation in the pipe and may require stopping the pumps and moving the assembly
back into the vertical section until the sand can be flushed. Pumping a flush while in the well
should involve keeping the flow rates at a level that will not cause the line tension to exceed
600 lbs (270 kg) over neutral weight.
Descent Speed (ft/min)
B. A sudden increase in the pump pressure could also indicate sand accumulation in the pipe.
Stop the pumps, stop spooling, and reevaluate the situation.
4 Correlation and Setting / Perforating
Step
1.
Action
Have the correlation log on hand to note short joints and previous perforated intervals.
NOTICE
2.
3.
4.
When approaching the anticipated setting depth, begin slowing the line while gradually decreasing pump
rates.
Stop the assembly 20 ft (6 m) below the anticipated setting depth. Stop the pumps and begin logging up
at the desired speed. Record collars up through the short or marker joint and continue until the correct
depths are positively defined.
Document all depth corrections. Tie into short joint in the vertical. Verify tie in is correct with company
representative.
NOTICE
5.
6.
7.
8.
9.
Do not run the assembly past previous perforations.
In the event the tool becomes stuck, record all over pulls
during process to free tool assembly.
Adjust the odometer to reflect the corrected depth.
After correlation is correct, go into record mode and log all collars, tension curve, and speed, while being
pumped down to stopping point on each stage. Pump the assembly down to 20 ft. (6 m) below the
setting depth, stop the pumps and then pull the assembly back up to the setting depth, insuring that
normal line tension is obtained coming up.
Set the plug and then, if possible, verify the plug is set by pressuring up on the casing.
To verify the bridge plug is set, pick up 100 ft (30 m) and pump down again.
Set the plug switch back to CCL mode to verify that tool is stroking. It can be determined from the CCL if
the plug has set. If no indication from CCL is possible, verify the plug is set by pressuring up on the
casing. If no indication, pull up hole then pump back down and tag plug while monitoring pump pressure
for increases in pressure.
Page 5 of 9
Pump-Down Plug and Perforating Procedures
Step
10.
Action
Begin perforating operations:
Note
Standard practice is to begin operations by setting the plug with
negative (-) DC power and then shooting the first gun with positive
(+). Maintain consistency throughout operations.
After firing the first gun, begin pumping in to the well at a low (1 bbl/min) rate to flow any perforating or
formation debris past the setting sleeve.
11. Continue perforating until all selections have been completed.
NOTICE
In the event the tool becomes stuck, record all over pulls
during process to free tool assembly.
5 Pulling Out of Hole (POOH)
Step
1.
2.
3.
Action
Record a collar log through the horizontal and marker joints to insure depth accuracy.
Pull out of the horizontal section at a rate not to exceed the ability to stop the hoist if the assembly
becomes stuck or encounters a sand bridge or accumulation.
Set the torque limiter as per procedures to avoid unscheduled cablehead release or cable damage.
When the vertical section is reached, maintain a speed to 75 to 100 ft/min (23 to 30 m/min) for at least 3
minutes in order to help re-establish the torque profile of the cable that was lost when travelling through
the horizontal section.
4.
Ascent Speed (ft/min)
5.
Shut down the hoist at 200 ft (60 m) below the surface and hold a brief operations/safety meeting with
the crew, follow the Ballistic Safety Checklist and communicate with all pumping and other personnel to
follow radio silence procedures.
6 Controlled Rig Down Procedure
Step
1.
2.
3.
4.
5.
6.
7.
Action
Close the tool trap.
Bring the assembly into the lubricator, following hoisting procedures.
Verify a pressure control operator is in the man lift watching for the tool trap to open and close. He will
raise his hand up when the trap opens and he will lower his hand when the trap closes. Our operators on
the ground can watch these signals, giving voice commands to the operator in the unit.
Hold down on the wireline and walk the bottom hole assembly into the riser until the assembly has
bumped up against the grease head.
Verify with the pressure control operator he saw that the tool trap did open and close and verify with the
operator on the ground he saw the hand signals from the pressure control operator in the man lift.
Verify the mark on your drum is exactly in the same position, and number of wraps on drum is the same
as it was prior to running in hole.
After all parties agree you are bumped up against the grease head, company man will then give
permission for the pressure control operator to close the crown valve. Count the number of turns it takes
to close the valve and verify with company representative that it is correct.
Note
8.
No one is to close the valve without approval from company
representative on location.
Bleed pressure off lubricator assembly.
Page 6 of 9
Pump-Down Plug and Perforating Procedures
Step
9.
Action
Stand lubricator back.
NOTICE
10.
11.
12.
Lay assembly down and verify all guns have shot.
Install night cap on top of tool trap before turning well over to fracturing company.
Repeat above process until all stages have been completed.
Note
13.
14.
Guns that have been run down hole may contain trapped
pressure inside when brought to surface. If any connection
on a blank gun or an unfired gun is difficult to break, assume
the gun contains trapped pressure. Follow trapped pressure
release procedures of gun providing company location or
contact a Baker Hughes representative to locate a trapped
pressure release procedure.
Re-head line after every three runs or as required by local operating
environment, documenting this on the JDS and cable book for
permanent record.
(OPTIONAL) Record CCL, tension and depth for each run, in and out of the hole. After the job, include
this on a CD with the meta file of all correlations for distribution to the customer.
Lay down assembly following location-specific procedures if applicable.
Warranty: BHI warrants that the product included shall conform to BHI’s published specifications. If any of the Products fail to conform to such specifications upon inspection by BHI, BHI at its option, shall repair or replace the non‐
conforming Products with the type originally furnished or issue credit to the Customer for the purchased product value, provided BHI is notified thereof in writing within thirty (30) days after delivery of the particular Products. BHI’s warranty obligations shall not apply if the non‐conformity was caused by: (i) failure to properly store the Products by any person, party or entity other than BHI, (ii) unauthorized modification, alteration or repair of the Products by any person, party or entity other than BHI, (iii) use or handling of the Products by any person, party, or entity in a manner inconsistent with BHI’s recommendations, (iv) failure to maintain or service the Products as recommended by BHI, (v) abnormal operating conditions such as and not limited to, abrasive materials, corrosion due to aggressive fluids or incorrect specifications provided (or estimated) by Customer or (vi) vandalism or force majeure. BHI always recommends to have a Baker Hughes representative at the well site at the time of the deployment to check well conditions and verify operational envelope range. Page 7 of 9
P
Pump-Down Plug
P
and Perfforating Proce
edures
Net Flow Rate Past
P
4.38 in. OD Plug in 5.5 in. 15.5 lb/ft. Casing
g
P
4.38 in. OD Plug in 5.5 in. 17.0 lb/ft. Casing
g
Net Flow Rate Past
Page 8 of 9
P
Pump-Down Plug
P
and Perfforating Proce
edures
Net Flow Rate past
p
4.38 in. OD Plug in 5.5 in. 20.0lb/f.t Casing
g
P
4.38 in. OD Plug in 5.5 in. 23.0 lb/ft. Casing
g
Net Flow Rate Past
Page 9 of 9