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Table of Contents
10 9-7/8" CASING INTERVAL .................................................................................... 2
10.1 Introduction ............... ........ ........... ......... ........ ....................... ........... ............... ................. 2
10.2 Objectives ............................................... ......................................................................... 2
10.3 Concerns ................. ....................... ............... ................................ ........................... ........ 2
10.4 General Drilling Operations Procedure ..... .............................. ...... .......... ............ ........ .. 4
Figure 1: 9-718" Casing OH Section: Drill String - MOP ........................... .......................................... 7
Figure 2: BHA Schematic .............. .............................................................................. ..................... ... 8
10.5 9-7/8" Casing and Cementi ng Operations ....... ........... ... ........... .......... .. ............. ...... ..... 9
10.5. 1 Casing and Cement Preparation ........ .............. .. .................................................................. ... 9
10.5.2 Casing Procedure ........................................................ : ...................................... ................... 10
10.5.3 Cementing 9-718" Casing ....... .. ............. .......... ...................... ........ ..... ......... .... .. ........ ........ .... 12
Attachment s ......... ..... ... ......... ............ .... ....... ......... ................ ........................... ............ ...... ..... .. 14
Attachment 1: 9-718" Casing Diagram ............. ............................... ............................ ........... ............ 15
Attachment 2: 9-718" Casing Landing String - MOP .................... .... ....... ...... , ... ..... ....... .................... 16
Attachment 3: Allaman Tool Pressure Sequence 9-718" ATC Surge Reduction ..... ......................... 17
Interval Notes
Item Comment
Bits 12-1/4' QD507 Hughes (primary)
Underreamers Hughes GuagePro XPR 7 4-7/2" (contingency)
BHA RSS, MWD, PWD, LWD, DDS, GR. Res. FPWD
Speci al equipment 18-3/4" casing hanger and seal assembly running tool, Allaman diverter & DTD, Bore
protector, mud surge tool, Allaman cement head
Drillstring 6-5/8" 32 ppf S-1 35 FH x 6-5/8" 40 ppf S-135 FH x 6-5/8" 40 ppf V-1 50 FH (If requi red
to reach TO, length issue only not tensi on)
Mud system SOBM, Drillout MW =TO MW 13-5/8" hole section (' 13.6 ppg), Projected MW at end
of interval 14. 2 ppg
Casing 9-7/8", 62.8 ppf, Q-125. 0,625" wall. Hyd 523
(only will be run if commercial hydrocarbons are found)
Landing string 6-5/8" 40 ppf S-135 FH
Cementing Foamed nitrogen cement (see detailed cement program)
Anticipated LOT at drillout
14.7 ppg LOT
(start of 13-5/8" interval)
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10 9-7/8" Casing Interval
10.1 Introduction
The objective of this interval is drill through the production interval and set 9-7 /8" long
string at 19,650 ft MD I TVD if a thick enough productive sand is found. The primary well
design is to drill this section with a 12-1/4" hole and no underreamer, however based on
casing point selection the section may required to be set-up with 12-1/4" x 14-1/2" or 10-
5/8" x 12-1/4" hole. It is preferred that 12-1/4" hole be drilled through the productive
interval to help achieve a competent cement job for completions, therefore pri or to drilling
this section the BHA design will be reviewed to best suit the dynamic needs of this well .
As with all sections of this well , the fracture and pore pressure margins are tight, therefore
mud weights and ECD should be managed to permit drilling as deep as possible without
requiring any extra strings of casing.
This section is the primary exploration interval, and should contain small sand units
interbedded throughout, with the anticipated production sand (M56) exi sting at
approximately 18,400' MD I TVD. It is planned that the wellbore will be extended past thi s
sand to determine if more hydrocarbons exist in the M54 interval. Once this object has
been completed, the section TO will be called. As seen on the PP/FG chart, a pressure
ramp occurs below the M54.
10.2 Objectives
Drill section without major losses, well control, or other NPT.
Set long string of 9-7 /8" casing after drilling the M54 sand package, prior to entering
the pressure ramp in the lower Miocene and Oligocene.
Cement 9-7/8 casing per design to achieve isolation and required LOT without
remedial operations.
1 0.3 Concerns
Concern I Hazard Mitiqation of Concern I Hazard
Pore Pressures and Utilize BP GoM procedures during 13-5/8" LOT to ensure accurate measurement.
Fracture Gradients
Wellsite geologists to monitor pore pressure trends to ensure proper analysis of well site pore
pressures. Wellsite leaders. tool pushers. dri ll ers. and crew are responsible for monitoring
drilling trends and will have an active role in ECD management.
Wellsite leaders must ensure that personnel become familiar with wellbore pressure/ECD
management guidelines.
Monitor for Losses I Utilize all avai lable tool s and personnel for ECD management. Limit pump pressures when a
Wellcontrol pack-off is detected or suspected. Pore pressure and fracture gradients are tight in each
inteNal and getting production casing to depth without requiring a contingency liner will be
dependent on pushing both the 16" to 13-5/8" strings as deep as possible. If ECD trends differ
from models a large deal discuss options with Houston.
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Concern I Hazard Mitigation of Concern I Hazard
Surge problems and Optimize running speeds to avoid sudden starts and stops. Utilize Allaman system to minimize
losses while running surge pressures. Also. have a mud surge return tool available to minimize mud losses on the
9-7/8" casing floor whi le running the casing.
Vibration issues Monitor BHA vibration. Utilize all prior lessons learned on 13-5/8" shoe track.
Vary drilling parameters (WOB. RPM. etc) to minimize downhole and/or surface vibrations.
Discuss alternatives with Houston Team.
Casing Wear Casing wear is a critical issue. Install and monitor ditch magnets. Report daily and cumulative
metal volumes on morning report on a daily basis. Watch for trends.
As this well is planned vertical, wear problems should not be a major issue. However. if any
high doglegs are established or unexpected issues downhole (shifting, damage to casing. ect. .. )
then wear may exist. Either way retrieved metal should be monitored for and reported.
Faults The well has been designed not to encounter any major faulting in this interval.
Offsets No major problems encountered on offset wells (if previous casing points are all pushed to all
the required depths). If casing points are not pushed deep enough or pore pressure greatly
differs from the prediction losses could be encountered and a contingency liner needed to reach
TO.
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9-7/8" Casing Interval
10.4 General Drilling Operations Procedure
1. Ensure BOP has been tested (per compliance with approved APD) .
Initiate well control and emergency disconnect drills.
Ensure all personnel are in compliance with MMS Sub Part "0".
2. Ensure 13-5/8" casing and blind shear rams have been tested (per APD
requirements). Record pressure with vol ume pumped. This data will be compared
with the 13-5/8" shoe LOT.
3. Pick-up and run-in-hole with the dril ling assembly complete with Drii-Quip Selective
Retrievable Wear Bushing with Running/Retrievi ng Tool set to leave Wear Bushing
in place on trip out.



Note:
Hole size may change based on 13-5/8" setting depth, and deployment of the
expandable contingency.
The objective is to allow for the entire interval to be drilled using 6-5/8" pipe .
Ensure enough 6-5/8" pipe is on location to reach TO.
Run selectable wear sleeve in drilling BHA, it will be remain in the wel lbore
during drilling, logging, and will be retrieved on the clean-out run BHA.
If formation pressure tool is used, give special attention when picking up BHA
to ensure f ormation pressure probe is correctly oriented in relationship with
the MWD f or down hole measurements. WSL I Drill ing Engineer I Geologist to
discuss formation pressure objectives prior to running BHA in hole.
4. After washing down to liner wiper plugs, drill-out cement and float equipment.
Follow Weatherford FE and plug drill out procedure.
Tag plug, turn drill string 60-80 rpm and pump enough to remove cuttings (40-50
gpm/inch of bit -490 - 613 gpm)
Slowly apply 2 klbs WOB until bit pattern is made then slowly increase WOB to 3-
5 kips.
Maintain WOB. If issues are encountered refer to Weatherford procedure.
5. Clean out rat hole and drill 10' of new hole.
Rev. O.H
Drill-out mud weight is expected to be same as MW at TO of pri or 13-5/8" section
(-13.6 ppg).
Circul ate cuttings above the stack.
Close annular or pipe ram.
Perform LOT per standard GaM LOT procedure (anticipated = - 14.7 ppg
surface EMW)
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A minimum acceptable val ue for a successful LOT will be supplied to the rig prior
to completing the test. If this is not reached contact Houston to discuss options
prior to drilling ahead.
Note:
Prior to LOT, obtain ESD value with MWD. However, if unable to get ESD value
after two attempts, continue LOT. After LOT, make one attempt to get ESD
value.
Shape of LOT curve rather than an actual value will dictate whether a squeeze
job is required.
If surface mud weight is < 0.5 ppg of surface LOT, MMS approval is required.
6.Dril l ahead mud weight to be determined by LOT at shoe.
Adjust mud weight prior to drilling ahead per hole conditions and weight up
schedule.
Estimated mud weight at TD will be 14.2 ppg.
7. Control drill hole using following parameters.
Parameter Guideline
ROP Limit to rate for adequate hole cleaning (as determined by WS Leader and Mud Engineer).
WOB 10 - 50 kips (limited by Vibration. Bit I BHA performance, and Wellbore Inclination)
RPM 120- 160 is planned range. Optimize for ROP, vibration limits. and directional considerations.
Torque Monitor difference between on and off bottom torque. Do not exceed makeup torque of
weakest connection in hole.
ECD / PWD Maintain ECD I PWD of at least 0.3 ppg < LOT value. (Remember to include any mud
compressibility in LOT number.)
Close coordination between BP wellsite leaders, drilling crew. and LWD Engineers will be
required on ECD management to achieve maximum performance. Roles and responsibilities
of all involved parties should be discussed in hole interval planning meeting.
Pump Rates 650 -7 50 is planned range. Optimize for ROP. hole cleaning. and ECD limits.
Mud Weight Drill-out with same mud weight as TO 13-5/8" section. Monitor output and drilling parameters
for indications of increasing formation pressure and adjust mud weight accordingly.
Hole Limit hole deviation to under 3. Rotary steerable tools wi ll be in the hole and dog legs should
Deviation be kept under 1 1100.
Section TO 9-7/8" x 10-3/4" production casing point is designed at 20.200 ft MD I TVD. Objective or this
interval is to drill through the production sands (M56) and test the M54 sands for
hydrocarbons. Final TO 1'Vill be determined by paleo picks and downhole LWD data. The
rigsite and office based teams should confirm final section TO prior to pulling out of the hole.
Prior to drilling more than 100' TVO deeper than permitted hole section TO, MMS
approval is required.
8. Pump weighted I viscous sweeps, as needed, to clean hole and minimize ECD. As
this is a vertical wellbore with sufficient pumps, sweeps should not be required.
9. Continue drilling to TD.
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10. At interval TO, pump a 100 bbl viscous sweep and circulate hole clean (at a
minimum one bottoms up or until shakers clean up).
Rat Hole- Plan to set casing -50' off bottom (unless reamed, then set
150' off bottom or- 50' above pilot hole).
Lower YP to -15 or as hole conditions dictate and keep gels flat.
Prior to POOH, spot a 16.5 ppg weighted SOBM pill in rathole. Monitor
displacement while TOOH.
11. If hole conditions warrant, make a short trip to determine hole conditions and reduce
potential of sticking 9-7/8" liner.
12. POOH into casing shoe, ensuring cement sheath has been removed. If drag is
observed in casing shoe, wash and ream cement sheath until drag is gone.
Attention should be paid, as reamer wi ll still be activated with flow.
13. Continue POOH, recovering wear sleeve.
14. Once bit is at the wellhead, wash the hanger landing profi le.
15. POOH, lay down the BHA, and prepare to log the well bore.
16. Log well per the POOP program
17. Once logging is complete, make up BHA and RIH for a clean-out trip prior to running
casing. Ensure wear bushing tool is set to retrieve on the way out.
18. Stage in the hole to condition mud, without damaging the wellbore.
19. Once in open hole, continue to stage in as necessary and clean out wellbore,
working any tight spots to ensure smooth casing running conditions.
20. POOH and lay down the BHA, retrieve bushing, and prepare to run 9-7/8" casing.
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Figure 1: 9-7/8" Casing OH Section: Drill String- MOP
NOTE: The air weight of spiraled hevi-wate dril l pipe is calculated as 96% of non-spi raled HVVDP.
unes lowest planned mud weight U.2 ppg
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12.25"
9 .625"
s.s
7.875"
s
B"
s
B"
s
B"
s
s
s
8.::5"
6 .625"
a
6.625"
6.625"
Rev. O.H

9-7/8" Casing Interval
Figure 2: BHA Schematic
BHA Schematic
Bp Amer ica Production
Macondo Prospect
BHA 10 #: 10
12l i 4" Gee-Pilot
BHA Conf iguration
Length
1: 9
18.39'
2.8J'
10'
25'
3.8'
21'
26.7'
3.8'
17'
6'
7'
270'
4'
270'
32'
600'
30'
Doscrlpllon
12 114"Fulldr1Cll ong gouge PDC
9600 Sorlco GcoPilot
12 118" IB StabiliZer BFF
Flox Collar w/ OM
8" PWD...GR.RES..DDS
12 1/8" l n-Une StabiNzar
s OBA T Sonic
s Goo Top
12 118" In-Line StabiHzer
a Pulser
Filler Sub
12 IB Stabliz:c
9 x S 114" Dnll Collats
C110r Sub
9 x 6 518" HWOP
H-E OtillinQ J;:u
20 x 6 516" HWDP
6 SIS" DP
Box 5-518" FH
6 518" DP
Box 6-518" FH
20 X 6 SIB" HWOP
Box 6-518" FH
H-E DrilliniJ Jar
Box 6-518" FH
9 x 6 SIB" HWf)P
Sox 6-5111" FH
Crw..s Over Sub
1 ' 9 x 6 114" Onll Collrus
:l
t. il
u
'
Box 6- 518" R<>g
12 1/8" IB Float
Vo.lii'C
Box 6-518" RiiQ
Filter Sub

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a Pulsar
Box i>-518" Reg
12 118" ln-Lino Slobrllzer
Box 5-518" Reg
B" GcoTap
Box 6-5-'8 " Reg
B" OBAT Sonrc
Box 6-518" R<>g
R()X 6-5/R" Rr.g
8" PWO. GRRES DDS
Box 6- 518" R<>g
l=lcx Coll,,r WI OM
Box 6-518" Reg
12 1/8" IB Stab<llzer -
BFF
Be 6- SIS" R<-'9
9600 Serioo GooPilot
Box 6-518" Rog
12 1/ 4"Fulldri!t long
gauge POC
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10.5 9-7/8" Casing and Cementing Operations
10.5.1 Casing and Cement Preparation
Rev. O.H
Prior to shipping, primary float equipment should have been bucked up and
thread-locked onto a joint of pipe. Inspect shoe and float collar joints for debris
prior to picking up.
Ensure cement, additives, and fresh and seawater samples are sent to cement
company lab for final lab testing.
Prior to shipment, verify casing has been drifted to 8-1/2". Visually inspect to
ensure there is no debris in pipe. A laser caliper of all joints should have been
completed, engineer should supply to the rig prior to running the casing.
Prepare 9-7/8" casing tally. Inspect threads and clean as required.
Boost riser while rigging up casing equipment (not while running 16", as mud can
flow up ~ h r o u g h casing) .
Calculate swab/surge pressures for various running speeds. Select an
acceptable speed to ensure 'formation breakdown pressure isn't exceeded.
Prior to running casing, rabbit 6-5/8" running string to 2-3/4 in drift I D.
Ensure any crossover required in landing string is rented, inspected, and has a
specific request to provide material certifications to rig and engineer. These certs
are to be used to verify proper load carrying capabil ities.
Ensure all crossovers in string do NOT have internal square shoulders as these
have proven to hang up drill pipe darts.
Make-up primary Drii-Quip casing hanger running tool and place on riser skate
Ensure wellhead protector sleeve has been pulled prior to running casing.
Ensure that a 9-7 /8" Halliburton Fast drill is on location for remedial cement job or
temporary abandonment.
750 ton equipment should be used for this section, ensure inspected and ready
to use prior to running casing.
Centralizers will be run every joint for the first 5 joints, followed by every other
j oint from the shoe to 500' above productive int erval. Check system which is
supplied to ensure it's in proper working fashion.
Rig up Allaman Top Drive Surface Cement Equipment as follows and place on
riser skate or stand back in derrick:
- 6-5/8" DP singled (drifted to 2-5/8")
- 15' DP pup jt
- Full open safety valve
- ATC dual Dart Cement Head
o A TC 2.375" bottom DP dart (pre-i nstalled)
o ATC 2.5" top DP dart (pre-installed)
- ATC positive launch indicator sub (PLI)
- Full open safety valve
o Function test valve to verify alignment versus the bore is centered
- 6-5/8"DP single (drifted to 2-3/4")
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10.5.2 Casing Procedure
1. Rig-up 22' bails for Fil l and Circulate Tool.
Item Ftg Size Wall ppf Grade Connection
Shoe Jt with Guide
-45' 9-7/8" 0.625" 62.8 0125 Hydril 523
Shoe
Shoe Track Jts -210' 9-7/8" 0.625" 62.8 0125 Hydril523
Float Collar Jt with
-45 9-7/8" 0.625" 62.8 0125 Hydril523
L47WA noat collar
Casing Jts -xx,xxx' 9-7/8" 0.625" 62.8 0 125 Hydril 523
2"" Position Hanger
(9-7/8) w/1" Position
-5 NA NA NA NA Hydril523
Dummy Hanger (13-
3/8)
Dual ATC Wiper Plug
NA NA NA NA NA 4-1 /2" IF
Subsea system
18-3/4" Casi ng
Hanger & Seal
-8' NA NA N.A. NA 4-1/2" IF x 6-5/8FH
Assembl y Running
Tool
Landing String -480' 6-5/8" 0.625" 40 S-135 FH
ATC Diverter Sub -6'
9-1/4" N/A N/A Q-125 FH
Landi ng String -x,xxx' 6-5/8" 0.625" 40 S-135 FH
Centralizer details: Bow springs every jt for the first 5 jts, followed by every
other jt to 500' above productive interval.
Casing ID: 8.625"
Casing drift: 8.5"
Casing collar 0 0 : 9.875"
Connection Size Minimum Torque Required Optimum Torque Maximum Torque
9-7/8 in 25,000 ft-lbs 30.000 ft-lbs 187.000 ft-lbs (yield)
Have Hydril thread representative on location to inspect casing threads and
connection make-up.
Thread lock first (5) casing joints.
Monitor well via choke and kill lines.
Casing swedge required is required as the casing length > water depth
2. Pickup and run 9-7/8" shoe track:
Apply a thin coating of API-modified t hread dope to pin end only, as needed.
Check for proper thread make-up.
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Notes:
Recommended Well Control consideration while running this casing:
If fill-ups are marginal, there are two options:
Convert auto-fill float equipment to a positive float collar and run
casing conventionally.
Run 1-7/8" wash-down ball in place in ATC Diverter Sub to minimize
time required to close tool. With 1-7/8" wash-down ball on seat, if you
observe any type of increased returns while running drill pipe, stop
running drill pipe and screw top drive into drillstring. Commence
pumping. It shoulol take 20 to 30 strokes to pressure-up on ball to close I
diverter sub and then blow ball.
3. Continue running 9-7/8" casing:
Take returns to trip tank.
Verify casing is filling through auto-fill float equipment.
Run -xx,xxx' ft of 9-7/8" casing@ approximately 1 minute per jt.
4. Observe and record pick-up and slack-off weights before entering open hole
5. Pick up off the skate: hanger joint, 2"d position hanger (9-7/8") and 1
51
position
dummy hanger (13-3/8") along with running tool and seal assembl y. Record casing
weight.
6. Free drop the 2-1/4" float conversion ball pri or to entering open hole.
7. After entering the open hole change running speeds based on hole conditions and
modeling. Esti mated to be 2 mps.
8. Makeup ATC Diverter Sub - (4) stands above top of 1
51
position casing hanger
running tool. Review surge pressure calculations running speeds with Allaman rep
to determine optimum drill pipe-running speed. (For All aman Tool pressure
sequence, see Attachment 5.)
ATC dual subsea plug system
Dril-quip casing hanger I seal assembly running tool
-(4) stands 6-5/8" FH DP
A TC Diverter Test Device
6-5/8" 40 ppf FH Drill pipe (inspected to 95%)
Ensure all DP has been drifted with a 2-3/4" in. drift prior to or while running
Note: casing.
Do not circulate the drill string (will close the diverter)
9. Pick up the ATC cement head and land out the 1s
1
position hanger:
Rev. O.H
Do not pick-up or rotate once the hanger has landed until the cement job is
complete.
After landing out, start pumping slowly to close ATC Diverter Sub.
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Wash-down ball will be on seat so pressure up to 1000 psi slowly and hold same
for 2 minutes.
Continue to increase pump pressure until ball yields seat with 2400 psi.
Stop pumped and let the 2-1/4" ball free fall to ATC dual plug system
Pressure up to 800 psi (test running tool and landing string for pressure integrity)
Increase pressure to 2600 psi and yield the seat. This will launch the 3-1/2" float
conversion ball.
Circulate 3-1/2" ball down to the float collar and convert (-600 psi I may not be
seen). Max fl ow rate not to exceed 12 bpm.
10. Circulate and condition the drilling fluid (1.5 x pipe volume), unless loss returns are
experienced or more time is required to properly clean up the mud for the cement
job.
10.5.3 Cementing 9-718" Casing
Test Pressures and Volumes are provided for reference, review APD for final values.
1. After conditioning the mud, mix and pump the foam spacer.
2. Once the cement is ready to pump downhole, launch the 2.375" bottom dart; a 1400
psi pressure increase will be seen as the dart exits the PLI sub. (Min displacement
rate= 5 bpm)
3. Mix and pump foam cement (per Halliburton detailed program).
4. After the cement has been pumped, launch the 2.5" top wiper dart; a 1700 psi
pressure increase will be seen as the dart exits the PLI sub.
5. Displace as fast as possible to catch up to the slugging cement/darts.
Rev. O.H
Once indication that the cement has been caught continue displacing unti l 5 bbl s
before the bottom dart reaches the diverter sub.
Displacement may be limited to slow speeds, if not slow pump rates to 5 bpm.
When the dart yields the diverter seat, a 1200 psi pressure spi ke will be seen.
Continue displacing the bottom dart down to the bottom plug. The bottom dart
will land out and release the bottom plug with 1200 psi above circulating
pressure.
Continue to displace j ob, until 5 bbls before the top dart reaches the diverter.
Slow pumps to 5 bpm, an 1800 psi pressure increase over circulating pressure
will be seen when the seat yields.
Continue displacing the top dart down to the top plug. The top dart will land out
and release the bottom plug with 1800 psi above circulating pressure.
Continue with displacement at max displacement rate (do not slow)
Bump the bottom plug without slowing displacement rate, plug wi ll shift to allow
circulation with 1200 psi above circulating pressure.
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Displace top wiper plug to the landing collar at max rate and land out with 500 psi
above circulating pressure. The plugs will land / lock I non-rotate together.
It is responsibility of Driller, Mud Engineer, and Mud Logger to closely monitor
and agree on amount of mud lost during casing job. Report mud losses for
different phases of job as follows:
Bbls lost while PU and running casing.
Note: Bbls lost while TIH with casing on landing string.
Bbls lost while washing casing to bottom, if required.
Bbls lost while circulating, after casing is landed.
Bbls lost while pumping and displacing cement.
Bbls left behind pipe.
6. Release the pressure to check if floats are holding. Allow max of 10-15 bbls to flow
back if floats aren't holding, then pump back the same. Hold pressure until cement
has sufficient time to set-up.
7. Release the subsea running tool.
Set 20 kips down on the running tool and mark the drill pipe at the rotary table for
vertical movement.
Rotate the drill string 5-6 turns to the right or until the string drops about 10
inches (rotation releases the running tool and lands the seal assembly, indicated
by the 10 inch drop).
Set drill string weight down on the seal assembly (per Dril-quip rep) to energize
the resilient seals.
Close the drill pipe rams and pressure test: Build quickly to 3000 psi , then
increase to 6500 psi and ensure, seals are holding. Finally increase pressure to
10,000 psi and hold for 10 seconds. This provides the force required to establish
a metal to metal seal and lock down the seal assembly to the casing hanger.
8. Pick up running tool from the wellhead. Approximately 60-90 kips over-pull will be
required to shear the pins
9. Once fully release from the hanger, position the cement plug launcher above the
wellhead and circulate (drop a nerf ball) one drill string volume.
10. Trip back in the hole and land running tool with 30 kips down. Re-test the casing
hanger to 6,500 psi for 1-2 minutes to ensure seals are still effective.
11. POOH with the running tool.
12. Test casing prior to releasing (pressure will be supplied to the rig).
Rev. O.H Page 13 of 17 Jan 2010
BP-HZN-MBI 00100398
bp GoM Exploration Wells
J\1/t.Jcondo
0
~ -:- ; j
MC 252 #1- Macondo Prospect
41Jf
9-7/8" Casing Interval
Attachments
No. Title
1 9-7 /8" Casing Diagram
2 9-7/8" Casing Landing String- MOP
3 Allamon Tool Pressure Sequence
Rev. O.H Page 14 of 17 Jan 201 0
Confidential
BP-HZN-MBI 00100399
bp
0
.
~
--
Float Collar
9-718"
0-125
62.8 #1ft
Full
Joint
Q-125
62.8 i#ft
Full
Joint
-.
-..-,.,.,..,.. ....
.-- .... __
9-7!8"
Q-125
62.8 i#ft
Full
Joint
"--..
::; , . . . : . ~ - -
--
9-718"
Q-125
62.8 #ift
Full
Joint
' " .. ~
- ..:.,;-;...
-
9-7/8"
Q- 125
62.8 #'ft
Full
Joint
~ - .. : ; . ~ ~
9-7!8"
Q-125
62.8 i#ft.
Full
Joint
... ~ : . : ; : , , . . -::-.....: ~
-
Float Shoe
Rev. O.H
Confidential
GoM Exploration Wells
MC 252 #1- Macondo Prospect
9-7/8" Casing Interval
Mac o n d o
Attachment 1:
9-718" Casing Diagram
~
Jl ': ;; I
9-7/8" Casing Shoe Diagram
I
Made up on shore
Centralized
l
r
Made up on shore
Centrali zed
+
t\.l ade up on shore
Central ized
1
r
Made up on shore
Cent alized
r
Made up on shore
Centralized
1
11
Henger
2"' Hanger
9-7!8"
Q.'l25
62.8 #1ft
Full
Joint
9-7!8"
Q-125
62.8 #/ft
Full
Joint
~
~
NOTE: Back up equipment on site includes:
Bow spring ce ntrali zers
Float equipment
Casrng hanger
NOTE: Float collar is a Weatherford model L47W.A .
auto-fill double valve float collar
NOTE: Centralizers will be run on the 1st 5 joints
followed by every other jt to 500' above the
productive interval
Page 15 of 17 Jan 2010
BP-HZN-MBI 00100400
Confidential
bp
~ ~
~ J
62.8
62.8
GoM Exploration Wells
MC 252 #1 - Macondo Prospect
9-7/8" Casing Interval
Attachment 2:
9-7/8" Casing Landing String- MOP
I RT includes ~ n e r hanger, seal assembly, and running tool
Rev. O.H Page 16 of 17
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Jan 201 0
BP-HZN-MBI 00100401
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No
1
2
3
4
5
6
7
8
9
10
11
12
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14
15
16
17
18
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Drop the 2-1/4" ball
GoM Exploration Wells
MC 252 #1 - Macondo Prospect
9-7/8" Casing Interval
Attachment 3:
Allaman Tool Pressure Sequence
9-718" A TC Surge Reduction
Operati on
Pressure up and shift driferter seat (hold for 2 minutes)
Yield the diverter ball seat
Test Dril-quip subsea RT and landinq string intergri ty
Yield ball seat and release 3-1/2" tl oat conversion ball
Convert float equipment
Launch the bottom dart throuqh PLI sub
Yield the diverter ball seat
Release the bottom plug
Release the top dart throuqh the PLI sub
Yield the diverter ball seat
Release the top pluq
Bump the bottom plug
Bump the top pluq
Pressure up on Casinq hanqer seal assembly
Pressure up to confi rm no leaks on seal assembly
Set casing hanqer seal assembly and lock down
Re-test casi nq hanqer seal assembl y
Rev. O.H Page 17 of 17
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aeon d o
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~ -
Anti cip<tted
Pr essure
-
1000
2400
800
2600
600
1400
1200
1200
"1700
1800
1800
1200
500
3000
6500
10000
6500
Jan 2010
BP-HZN-MBI 00100402