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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout196-128 • Pick. l ( —OdIa
12)60
Regg, James B (DOA)
From: Jones,Jeffery B (DOA)
Sent: Friday, November 18, 2016 6:08 PM ` \ 1(1Z-411Q,
(IZ4I/Q"
To: Regg,James B (DOA)
Subject: well deficiency re-inspection PBF 16-08 & 11-09A
Attachments: Deficiency Report BPXA PBF 16-8 1-1-16 JJ.pdf; Deficiency Report BPXA PBF 11-09A
1-1-16 JJ.pdf
Jim, ✓
I inspected the repairs to BPXA PBF wells 16-08 and 11-09A today.The leaking VR plug and LDS on 16-08 have been
repaired and the wellhead has been cleaned.The wellhouse on 11-09A was modified to allow more room for the
flowline to exit the wellhouse and it looks good also. C.;•- - : •- • • • :: _ - . -- .
Thanks,
Jeff B.Jones
Petroleum Inspector
Alaska Oil & Gas Conservation Commission
N. Slope Ofc: 907-659-2714
Mobile: 907-744-4446
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,
contains information from the Alaska Oil and Gas Conservation Commission
(AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It
may contain confidential and/or privileged information. The unauthorized
review, use or disclosure of such information may violate state or federal law. If
you are an unintended recipient of this e-mail, please delete it, without first
saving or forwarding it, and, so that the AOGCC is aware of the mistake in
sending it to you, contact Jeff B. Jones at 907-659-2714 or
jeff.jones@alaska.gov.
SCANNED JUN 2 020
• i(-0`7 A
Regg, James B (DOA) (Cl 6 Iaf3c'
From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>
Sent: Thursday, November 17, 2016 3:20 PM
To: DOA AOGCC Prudhoe Bay
Cc: Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep; Cocklan-vendl, Mary E
Subject: FW: Deficiency report fixed
Attachments: 3605_001.pdf
I see this in our in box and don't have record of it being forwarded to AOGCC.
dico
Well: 11-09
OK [‘4 . G GREATER
Pa'�" 6 , �, .. - i _
nteq Well Events Per v es • n *°r. n ;nnu u Press • r r
Home User Settings Help
OperNotes 11-09 05/Nov/2016 HWSP for cody and aaron to cut backing and fix
Ope rNotes 11-09 02/Nov/2016 WO K540463 to replace WH backing and secure
OperNotes 11-09 01/Nov/2016 State tested well. Passed. Written up for backinc
Lee Hulme
Well Ops Compliance Rep
BP Exploration (Alaska) Inc.
Office: (907) 659-5332 scANNED JUN 0 $2017
Cell: (907) 229-5795
Harmony — 7187
(Alternate: Vince Pokryfki)
From: AK, OPS FS2 DS Ops Lead
Sent: Tuesday, November 08, 2016 2:32 PM
To: AK, OPS FF Well Ops Comp Rep
Subject: Deficiency report fixed
This deficiency was fixed on 11/5/16.Thanks Josh.
From: FS2scanner@abp.com [mailto:FS2scanner@bp.com]
Sent: Tuesday, November 08, 2016 2:28 PM
To: AK, OPS FS2 DS Ops Lead
Subject: Attached Image
1
• •
State of Alaska
Oil and Gas Conservation Commission
Deficiency Report
Location: PBF well 11-09A - Date: 11/1/16
PTD: 1961280
Operator: BPXA Type Inspection: SVS test
Operator Rep: Josh McQueen Inspector: Jeff Jones
Position: Lead Operator
ttI]
is-1 i c,
Op. Phone: 659-5494 Correct by(date): To bE mined
Op. Email: akopsfs2dsopslead@bp.com Follow Up Req'd:
Detailed Description of Deficiencies Date Corrected
The flowline is stressed because it's contacting the wellhouse and has 11-4- IL
pulled the wellhead over off vertical, affecting the surface and
cwnductorpipe ... I l-5'Ic
Attachments:
Operator Rep
Signatures:
42,
GIô') 44.-IV AOGCC Inspector
*After signing,a py o this •rm is to b eft with the operator.
Follow-up Instructions
Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date
Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up
inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than
the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of
deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action.
Revised 2/2016
_ - • •
\k\,eki`a
State of Alaska
Oil and Gas Conservation Commission
Deficiency Report
Location: PBF well 11-09A Date: 11/1/16
PTD: 1961280 -
Operator: BPXA Type Inspection: SVS test
Operator Rep: Josh McQueen Inspector: Jeff Jones
Position: Lead Operator .i :I —
Op.Phone: 659-5494 Correct by(date): To be determined
Op. Email: akopsfs2dsopslead@bp.com Follow Up Req'd:
Detailed Description of Deficiencies Date Corrected
The flowline is stressed because it's contacting the welihouse and has
pulled the wellhead over off vertical, affecting the surface and
conductor pipe We ,
Attachments:
Signatures: ( °, jr
Operator Rep -
e t C: . .d.64.1 AOGCC Inspector -
*After signing,a py o this :rm is to b eft with the operator.
Follow-up Instructions
Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date
Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up
inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than
the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of
deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action.
Revised 2/2016
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BP Exploration (Alaska) Inc.
Attn: Well Integrity Coordinator, PRB -20
Post Office Box 196612
Anchorage, Alaska 99519 -6612
December 21, 2010
N JAN. 4 20 01;,7,r4,7:::'
a ; F
Mr. Tom Maunder
Alaska Oil and Gas Conservation Commission
333 West 7 Avenue : x ~; atiCiS® ' 44s
Anchorage, Alaska 99501
Subject: Corrosion Inhibitor Treatments of GPB DS 11 1q6 / D.8
Dear Mr. Maunder, /1.— O ?A
Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS
11 that were treated with corrosion inhibitor in the surface casing by conductor annulus.
The corrosion inhibitor is engineered to prevent water from entering the annular space
and causing external corrosion that could result in a surface casing leak to atmosphere.
The attached spreadsheet represents the well name, API and PTD numbers, top of
cement depth prior to filling and volumes of corrosion inhibitor used in each conductor.
As per previous agreement with the AOGCC, this letter and spreadsheet serve as
notification that the treatments took place and meet the requirements of form 10 -404,
Report of Sundry Operations.
If you require any additional information, please contact me or my alternate, Gerald
Murphy, at 659 -5102.
Sincerely,
Torin Roschinger
BPXA, Well Integrity Coordinator
• •
BP Exploration (Alaska) Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off
Report of Sundry Operations (10 -404)
DS -11
Date: 12/21/10
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name PTD # API # cement pumped cement date inhibitor sealant date
ft bbls ft na gal
11 -01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010
11 -02 1811280 50029206490000 NA Sealed NA NA 6/25/2010
11 -03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010
11-04A 1940230 50029204800100 NA Sealed NA NA 6/25/2010
11 -05A 1961570 50029206700100 NA Sealed NA NA 6/25/2010
11 -06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010
11 - 07 1811770 50029206877000 NA Sealed NA NA 6/25/2010
11 -08 1842290 50029212450000 NA Sealed NA NA 6/27/2010
4 11 - 081• 1961280 50029214020100 NA 25 NA 42.50 6/29/2010
11 -10 1851590 50029213940000 NA 5 NA 28.90 6/30/2010
11 -11 1851410 50029213820000 NA Sealed _ NA NA 6/27/2010
11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010
11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010
11 -16 1860780 50029215817000 NA Sealed NA NA 6/27/2010
11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010
11 -18 1861120 50029216070000 NA Sealed NA NA 6/27/2010
11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010
11 -23A 1940810 50029216100100 NA Sealed NA NA 7/1/2010
11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010
11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010
11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010
11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010
11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010
11 -29 1940250 50029224660000 NA 0.2 NA 1.70 6/28/2010
11-31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010
11 -32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010
11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010
11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009
11 -35 1940650 50029224760000 NA _ 0.6 NA 5.10 6/30/2010
11 -37 1961740 50029227160000 NA 4 NA 42.50 7/1/2010
11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010
~.....: OPERABLE: 11-09A (PTD # 1961280) Tubing integrity restored Page 1 of 2
~ ~ ~
Schwartz, Guy L (DQA)
_ _ _ _ _ _ _ ~oc~
From: NSU, ADW Well Integrity Engineer [NSUADWWeillntegrityEngineer@BP.com] ~~^/ '~.~'~
Sent: Tuesday, June 30, 2009 7:56 AM ~'
To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, FS2 DS Ops
Lead; GPB, FS2/COTU OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW We!!
Operations Superoisor; Engel, Harry R; Rossberg, R Steven; GPB, Wells Opt Eng; GPB, EOC
Specialists
Cc: Quy, Tiffany; Chivvis, Robert; NSU, ADW Well Integrity Engineer
Subject: OPERABLE: 11-09A (PTD #1961280} Tubing integrity restared
All,
Well 11-09A (PTD #1961280) passed a TIFL on 06/29/09 after the screened orifice was changed out. The
passing test confirms that tubing integrity has been restored. The we~l has been reclassified as Operable.
Please call with any questions or concerns.
Thank you,
Torin Roschinger (alt. Anna Dube)
Well Integrity Coordinator
Office (907) 659-5102
Cell (406) 570-9630
Pager (907) 659-5100 E~. 1154
y,Ca'^SCv.?~~wra !=,t)t . .._ f~J~1~.,:
From: NSU, ADW Well Integrity Engineer
Sent: Thursday, June 25, 2009 10;14 AM
To: 'jim.regg@alaska.gov'; 'tom.maunder@alaska.gov'; 'Schwartz, Guy L(DOA)'; GPB, F52 DS Ops Lead; GPB, FS2jCOTU OTL; GPB, Area Mgr East
(FSl/2/COTU/Seawater); NSU, ADW Well Operadons Supervisor; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists
Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer; GPB, Gas liR Engr
Subject: UNDER EVALUATION - 11-09A (PTD #1961280) for TxIA Comm
All,
Well 11-09A (PTD #1961280) failed a TiFt on 06/24/09 when the wellhead pressures were tubing/IA/OA equal to
2440/2300/880. While #he IA fluid level remained unchanged, the IA pressur~ has continued to build pressure
indicating TxIA communication. The well has been reclassified as Under Evaluation on a 28 day clock starting
06/20/09.
The plan forward includes:
1. D: TIFL - FAIIED
2. S: Change out gas lift valves
3. D: Re-TIFL
A 90-day TIO glot and wellbore schematic have been included far reference.
« File: 11-09A TIO Plot.doc» « File: 11-09A.pdf»
7/20/2009
___,.,'OPERABLE: 11-09A (PTD #1961280) Tubing integrity restored Page 2 of 2
~ ~
Please cali with any questions or concerns.
7hank you,
Torin Roschinger (alt. Anna Dube)
Well Integrity Coordinator
Office (907) 659-5102
Celi (406) 570-9630
Pager (907) 659-5100 E~. 1154
7/20/2009
~~ = cNv
'WEILHEAD = GR,4Y
i~CTUATOR = BAKER C
KB. ELEV - _ 57'
BF. ELEV -
KOP _ 2099'
Max Angle = 94° @ 12426'
Datum MD = NA
Datum TVD = -8800' SS
13-3/8" CSG, 72#, L-80, ID = 12.347"
•
11-0 9 A SAFETY NOTES: W ELL ANGLE > 70` @ 11581'
***CHROME TBG AND NIPPLES**"
2198~ 5-1/2" HES X NIP (9-CR), ID = 4.562"
GAS LIFf MANDRELS
, ST MD ND DEV TYPE VLV LATCH PORT DATE
2507~ 3
2 3592
6689 3273
4966 55
61 MMG
KBG DOM
SO RKP
BK 16
20 02/T2/09
02/12/09
1 8403 6203 37 KBG DN1Y BK 0 01/31l09
5-1/2" TBG, 17#, 13CR-80 VAM TOP, 6286~
.0232 bpf, ID = 12.347"
TOP OF 7" SCAB LNR 6368~
7" SCAB LNR, 29#, L-80, .0371 bpf, ID = 6.184" 6709~
TOP OF 7" LNR 6709~
~ 9-5/8" CSG, 47#, L-80, ID = 8.681" H 6826~
Minimum ID = 3.725" @ 11402'
4-1/2" HES XN NIPPLE
¢sv BPN 7093'
4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 11414'
.0152 bpf, ID = 3.958"
TOP OF 4-1/2" LNR ~-{ 11648~
7" LNR, 29#, L-80 ABMOD, .0371 bpf, ID = 6.184" ~-i 11790~
PERFORAT-ON SUMMARY
REF LOG: ?
ANGLE AT TOP PERF: 90° @ 11800'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE
2-3/4" 4 11800 - 11996 O 09/10/96
2-3/4" 4 12010 - 12080 O 09/10/96
2-3/4" 4 12140 - 12268 O 09/10/96
2-3/4" 4 12405 - 12680 O 09l10/96
2-3/4" 4 12700 - 12810 O 09/10/96
2-3/4" 4 12865 - 13237 O 09/10/96
6286~ --~ 5-1/2" X 4-1/2" HES XO, ID = 3.958" ~
6368~ 9-5/8" X 7" BKR ZXP PKR, ID = 6.276"
I MILLOUT WINDOW 6826' - 6876' ~
6709~ 9-5/8" X 7" BKR ZXP LTP, ID = 6.276"
6723' 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.184"
11271~ 4-1/2" HES X NIP (9-CR), ID = 3.813"
11292~ 7" X 4-1/2" BKR PREM PKR, ID = 3,870"
11330~ 4-1l2" HES X NIP (9-CR), ID = 3.813"
11402' 4-1/2" HES XN NIP (9-CR), ID = 3.725"
11415~ 4-1/2" WLEG, ID = 3.958"
11648~ 7" X 4-1/2" S-6 LTP, ID = 3.888"
11659~ 7" X 4-1/2" TNV DTH HGR,
ID = 3.922"
12299' ~4-1/2" TIW MLAS- I
CV (12299'- 12327')
PBTD H 13238'
~ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" H 13329~
DATE REV BY COMMENTS DATE REV BY COMMENTS
1985 ORIGINAL COMPLETION
09/11/96 N2ES SIDEI'RACi( (11-09A)
02/01/09 D16 RWO & FCO (11-09A)
02/03/09 PJC DRLG DRAFT CORRECTIONS
04/17/09 MD/JMD DRLG DRAFT CORRECTIONS
PRUDHOE BAY UNfT
WELL: 11-09A
PEF2Mff Na ~1961280
A PI No: 50-029-21402-01
SEC 28, T11 N, R15E, 1155' FSL & 377' FEL
BP Exploration (Alaska)
.~
~, ~ ~
Well 11-09A (PTD #1961280)
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O:U28/09 OA/Dd/09 94/17/09 D4/18/09 04R5/09 05/0?/09 OSiO~i~[5 C5/15~09 0523J09 05/30tP3 05/06/W 06I13J09 06/20/09
`VG~
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1. Operations Performed: '~i1C~10 fagg
^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well
^ Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other
^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension
2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number:
BP Exploration (Alaska) Inc. ®Development- ^ Exploratory 196-128
3. Address: ^ Service ^ Stratigraphic 6. API Number:
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21402-01-00 -
7. KB Elevation (ft): 57 1' , 9. Well Name and Number:
PBU 11-09A'
8. Property Designation: 10. Field /Pool(s): _
ADL 028322 ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool
11. Present well condition summary
Total depth: measured 13329 ~ feet
true vertical 8717' ~ feet Plugs (measured) None
Effective depth: measured 13238' feet Junk (measured) None
true vertical 8717' feet
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 110' 20" 110' 110' 1490 470
Surface 2507' 13-3/8" 2507' 2482' 3450 1950
Intermediate 6826' 9-5/8" 6826' 5032' 6870 4760
Production
Liner 5436' 7" 6354' - 11790' 4794' - 8734' 8160 7020
Liner 1681' 4-1/2" 11648' - 13329' 8711' - 8717' 8430 7500
``~"
"~
~~~' ~~ ~~ ~ ~ ~~
Perforation Depth MD (ft): 11800' - 13237' '
"
Perforation Depth TVD (ft): 8734' - 871 T
5-1/2", 17# x 4-1/2", 12.6# 13Cr80 11415'
Tubing Size (size, grade, and measured depth):
Packers and SSSV (type and measured depth): 7" x 4-112" Baker Premium packer 11292'
12. Stimulation or cement squeeze summary:
Intervals treated (measured): w~" r0~ ~(~~
SZ~« ~/« - a ooa
Treatment description including volumes used and final pressure: hl~ yY~
13. Re resentative Dail Avera a Production or In'ection Data
Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure
Prior to well operation:
Subsequent to operation: g29 33,474 -0- 1,380 740
14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ,
^ Exploratory ®Development ^ Service
® Daily Report of Well Operations
16. Well Status after work:
® Well Schematic Diagram '® Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
Contact Mackie Derrick, 564-5891 N/A
Printed Name T rrie Hubble Title Drilling Technologist
., O ~ Prepared By Name/Number
Signature Phone 564-4628 Date Terrie Hubble 564-4628
.:Form>10-404 Revised 0412006
STATE OF ALASKA 6~~~ 4~:8 I~®
A OIL AND GAS CONSERVATION CO SION ~ ~ ~ ~~0~
REP T OF SUNDRY WELL OPETIONS
~~ u:rt ~.a s we 3~7
' ion
Submit Original Only
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•
11-09A, Well History (Pre Rig Workover)
Date Summary
12/30/08 MIRU CTU. Makeup BHA #1 w/2.25" BDN and RIH. Tag at 11023 CTM. Dispalce coil and tbg w/1% XS
KCL. Clean out sand/fill from 11023 to 11200. Micromotion meter acting up. Pull up hole to 1085Q
12/31/08 Mlcromotion meter problems. Put new micromotion meter in. Having seal problems. Developed
blockage in reel. Freeze protect well with 32 bbls of 60/40 meth. POOH and attempt to clear blockage.
Blockage in reel and coil is clear. Freeze protect coil and all lines with 40 bbls of 60/40 methanol.
SAFETY STAND DOWN.
01/01/09 Discuss Safety Issues. End safety stand down. Calibrate Micromotion Meter. RIH w/ 2.25 BDN. Tagged
top of sand at 11214 ctmd. Load hole with 1 % XS KCL. Reverse circulate to hard tag at 11219' ctmd.
Attempt to jet with no success. POOH. Makeup and RIH with Baker milling string with 3.80" pirahna mill.
Tag SSSV nipple at 2209' ctmd and rotate through. Tag #1 and #3 gas-lift mandrells at 4110' & 9515'
ctmd. Rotated through both of them. Stopped at 11242. NO fuel truck. Getting low on fuel. PUH and
Stop at 9600. Recip back in hole. Fuel truck on location. RIH Taq obstruction at 11238. Milled from
11238 to 11250.
01/02/09 Continue milling from 11249' to 11301'. Had hard stalls at 11301'. Pulled heavy, POOH from 11250' to
11138' (28k to 30k). POOH and chased final flo pro sweep out of hole at 80%. Lay in methanol to freeze
protect tubing at 2550 (39bbls of 60/40 methanol). Makeup PDS logging tools with 3.5" JSN. RIH. Tag
at 11250' ctmd. Log from tag depth to 9200'. POOH and recover data. Depth correction was 0' to LDL
Log (04-Sept-2000). Tag depth corelated to 10' pup joint above GLM #4. Makeup Baker 3-1/8" Venturi
Junk Basket. Go on weather stand by.
01/03/09 /End weather standby. RIH w/3.13" Venturi Basket. Tag at 11243' ctmd while pumping 60/40 meth.
Venturied down to a tag at 11300' ctmd. While pulling up hole, had a 5k over pull at 11243'. CT was able
to run in hole then pulle throng successfully. Continued pulling up hole with a 10k overpull for to
10211'. RIH and the picked up normally. POOH pumping 32 bbls of 60/40 meth down tubing to freeze
protect well. At surface, recovered approximately 1 cup of steel, packing and sand fragments. Steel
fragments included a steel spring 1/4" x 1"long. Go to weather standby.
01/04/09 End weather standby. Makeup BHA #4 -Expro 2.625" camera. RIH with Expro Camera. At 8680'.
Called to find out where LRS was at. Still working on unit. POOH. OOH.
01/05/09 T/I/O = 1700/700/25 Temp = SI Assist CTU with Camera job (RWO Prep). Pumped 3 bbls meth, 5 bbls
diesel, 243 bbls 140°F fresh water and 105 bbls 35°F borough water followed by a 5 bbl meth cap down
the Tbg. Final WHP's = 800/507/132. CTU in control of well on LRS departure.
01/05/09 RIH w/ 2.625 Expro Camera with mule shoe on bottom. Tag down repeatedly at 11242' CTM. Pump 250
bbls of hot water from hot water p ant wit c ay s a i izer and 100 bbls of borough freshwater with clay
stabilizer. Log from 11190' to tag depth at 11238' ctmd. First pass was pumping at 0.5 bpm. Second
pass was with static well conditions. POOH freeze protecting well with 40 bbls of 60/40 meth. Picture
information was not definitive. Decision was made to attempt to cut the tubing using the tag depth as a
no-qo. Begin making up tools.
01/06/09 RIH with 2.25 Underreamer with 3.75 No Go. 21.60' from No Go to Cutters. Sat down at 3900', 7924',
8047', 9465', 11100'. Could not get past 11226' CTM. Tried several times at various RIH speeds. Tried
once pumping. POOH. Makeup PDS logging toolstring simulating last toolstring with 3.75" No Go and
RIH. Stopped at #1 gas-lift mandell. Tried several times to get by mandrell. Could not get past. POOH.
Log shows centralizer setting down in gas-lift mandrell. Changed No Go out from 3.75" to 3.5". RIH
w/PDS logging toolstring simulating last toolstring with 3.50" No Go.
01/07/09 Continue RIH w/PDS logging toolstring simulating last toolstring with 3.50" No Go. Sat down at 11245'
M. Log up to 9200 aint ag at i e . oo a a rom ogs + .
correction). Log indicated BHA is tagging down at the same depth as the Jan-2 tag depth at 11248'.
Perform weekly BOPE test. RDMO CTU. E-line to jet cut tubing as next step.
01/07/09 ARRIVE LOCATION, WELL SHUT-IN. BEGIN E-LINE RIG UP FOR STRING SHOT AND JET CUT.
Page 1 of 2
11-09A, Well History (Pre Rig Workover)
Date Summary
01/08/09 SSV OPEN, INITIAL PRESSURES = 0/700/0. TAGGED TD AT 11251'. SHOT TWO STRAND STRING
SHOT FROM 11237' - 11249' AS PER PE. RAN 3.65" SCP POWERCUTTER AND CUT THE 4-1/2"
TUBING AT 11225' IN THE MIDDLE OF THE FIRST FULL JOINT ABOVE GLM AT 11259'. DSO
NOTIFIED OF TREE VALVE PLACEMENT, WELL LEFT SHUT-IN AND SECURE, SSV OPEN. FINAL
PRESSURES 350/700/0. JOB COMPLETE.
01/08/09 T/I/0= 200/740/40 Temp=S1 Circ-Out TxIA (Pre RWO). Loaded fluids, currently rigging up to well.
01/09/09 Circ-Out TxIA, CMIT TxIA PASSED to 1000 psi (4 attempts) (Pre RWO). Pumped into the Tbg with a 5
bbl neat methanol spear followed by 1017 bbls of 1 % KCI down Tbg thru jet cut C~3 11285' taking return up
the IA to the flowline of 11-30. Pumped into the Tbg with 155 bbls of diesel for freeze protect. U-tubed
freeze protect TxIA for 1 hour. CMIT TxIA lost 40/30 psi in the 1st 15 min and 20/30 psi in the 2nd 15 min
and 30/10 psi in the 3rd 15 min for a total loss of 90/70 psi in 45 min test.
01/10/09 MIT-OA PASSED to 2000 psi (2nd attempt) (Pre RWO). Pressured up OA with 5 bbls crude. OA lost 30
psi in 1st 15 min and 10 psi in 2nd 15 min for a total loss of 40 psi in 30 min test. Bled pressure back.
Final WHPs 0/0/0 WV, SV =shut MV, SSV, IA, OA =open.
01/10/09 T/I/O vac/0/0 Set 5" gray bpv thru tree pre rig. Used 1-2" ext tag at 106" no problems.
Page 2 of 2
i ~!
BP EXPLORATION Page 1 of 18
Operations Summary .Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
Date From - To Hours I; Task Code NPT Phase I~ Description of Operations
1/11/2009 07:00 - 12:00 5.00 MOB P PRE Move off of 1-29 and stage on pad. Break down BOP stack
and remove double gates. Begin putting stack back together
with single gate ram bodies. Welder work on repairs in pits.
12:00 - 21:30 9.50 MOB P PRE Finish reconfiguring BOP stack. Install Blind rams and 2-7/8" x
5" VBRs. Install BOP stack on Transport cradle. Install rear
booster wheels. Welder continue repairs in pits. Rig down
tuggers and cattle chute. Bridle up in preparation for laying
derrick over.
21:30 - 22:00 0.50 MOB P PRE PJSM on laying derrick over with Rig-Crew and Doyon
Tourpusher. Discuss hazards associated with laying derrick
over and assign people to positions. Discuss upcoming rig
move and necessary footwear and arctic gear if working
outside.
22:00 - 22:30 0.50 MOB P PRE Lay derrick over.
22:30 - 00:00 1.50 MOB P PRE Move rig around Nabors 2ES rig, shop and camp. Begin move
to DS 11.
1/12/2009 00:00 - 02:00 2.00 MOB P PRE Move to DS 11. At 0015-hrs, Rig stops in front of Tarmac pad
to be measured by CPS before passing under any electrical
lines. At 0130-hrs, rig is moving under powerlines just in front
of FS 2.
02:00 - 02:30 0.50 MOB P PRE Stage rig on DS 11. PJSM on removing booster wheels with
Rig Crew and Doyon Tourpusher. Discuss hazards associated
with removing booster wheels, spill pontential and positions of
people.
02:30 - 06:00 3.50 MOB P PRE Remove rear booster wheels. Put BOP stack on pedestal in
cellar. Adjust timing on kick over cylinders for raising the
derrick.
06:00 - 12:00 6.00 MOB P PRE PJSM to raise the derrick. Raise derrick and R/U floor
equipment. Bridle Down. R/U Top Drive. Inspect Derrick
Climber. Perform houskeeping throughout rig while waiting on
pad prep.
12:00 - 23:00 11.00 MOB P PRE Continue housekeeping throughout rig while continuing to wait
on pad prep. Change out cable on Driller's side tugger.
Perform maintenance on Top Drive., Install door going into
shaker room. Gravel truck on location at 2130-hrs to finish
leveling pad around well.
23:00 - 00:00 1.00 MOB P PRE Spread herculite and lay matting boards around 11-09A. Rig
slop tank on location at 2315-hrs.
1/13/2009 00:00 - 00:30 0.50 MOB P PRE Finish spreading herculite and laying mats around well. Hold
PJSM with Rig Crew on moving rig over well. Discuss hazards
associated with moving the rig and assign people to positions.
00:30 - 02:00 1.50 MOB P PRE Spot rig over well 11-09A. Shim rig in place.
02:00 - 05:00 3.00 KILL P DECOMP RU to circulate out freeze protection. Spot rig slop tank and
Mud Pump #2 module. Gauge on top of tree showing 40-psi,
Bleed pressure off. Monitor gauge and pressure slowly climbs.
Function master valve and pressure stays at 0-psi. Take on
110-degree Seawater to pits. RU double IA valve. RU line
from OA to slop tank. Accept rig at 0400-hours.
05:00 - 09:00 4.00 WHSUR P DECOMP PU DSM and RU. Fil u rica or wi res wa er and test to
500-psi. Good test. Pull BPV. Can't pull BPV and pull rod
ap ears to be stuck in tree. R/U to steam tree. Slowly move the
-
BPV up through the tree, close Manual Master a vea a~
0 - rs. op wor ing he BPV at the top Swab Valve,
Printed: 2/16/2009 11:53:11 AM
•
BP EXPLORATION Page 2 of 18
Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Number:
Rig Name: DOYON 16 Rig
N
Date ~~~ From - To ~ Hours ~ Task ~ Code ~ NPT ~ Phase 1 Description of Operations
1/13/2009 05:00 - 09:00 4.00 WHSUR P DECOMP re-wrap the tree with Herculite and resume steaming to thaw
the ice plug on top of the BPV. Stop steaming, unscrew
lubricator connection, P/U on lubricator and the BPV comes
easily with an ice "popsicle" wrapped around the pull rod.
09:00 - 10:00 1.00 WHSUR P DECOMP PJSM with crew, truck drivers, Toolpusher and WSL to discuss
the well kill circulation and also to discuss the ice plug that
occurred when POH with the BPV. The crew and drivers were
asked to identify hazards pertinent to their reponsibilities rather
than read specific procedures.
10:00 - 12:00 2.00 WHSUR P DECOMP Pump Hi-Vis sweep and follow with 120E seawater to circulate
out diesel freeze protect fluid and crude oil, methanol, and
other wellbore fluids. P/T Lines to 2000-psi. Bring pump up to
6-BPM, 430-psi pump Hi-Vis sweep and chase with hot
seawater. See diesel through the gas buster and OA bleeds a
little diesel to the cuttings tank. Returns clean up before full
wellbore circulation of 600-Bbls, but continue pumping for
another 60-Bbls. S/I to monitor well.
12:00 - 12:30 0.50 WHSUR P DECOMP Monitor well and well is dead. The OA had been open to the
Cuttings Tank during the entire well kill circulation, but the only
time any fluids were seen from the line was for a few minutes
at the very beginning of the pumping cycle.
12:30 - 13:00 0.50 WHSUR P DECOMP Drain tree and R/U for DSM to set BPV and Cameron to set
their dart in the BPV for the BOPE test.
13:00 - 13:30 0.50 WHSUR P DECOMP Service rig.
13:30 - 16:00 2.50 WHSUR P DECOMP PJSM. P/U Lubricator and install on tree. DSM install K- lu
BPV. Cameron install test dart in BPV. P/T the darted BPV to
3500-psi above and 1000-psi from below.
16:00 - 17:30 1.50 WHSUR P DECOMP PJSM. Blow down circulating lines and manifold. Drain tree.
N/D tree and set outside cellar. Hold a second PJSM to N/D
the tree and to fill out THA cards as well as identify the Task
Leaders. The forklift operator described the way the tree has to
be rigged with lifting gear to keep from rolling it while pulling it
out of the cellar. The Gray trees are the heaviest trees in GPB.
17:30 - 19:00 1.50 WHSUR P DECOMP Nlpple down Adaptor Flange. Inspect Hanger threads.
Function lock-down screws.
19:00 - 20:30 1.50 BOPSU P DECOMP PJSM. Nipple up BOP Stack dressed with 2 7/8" x 5" VBPRs.
Change out both air boots. Function all rams.
20:30 - 21:00 0.50 BOPSU P DECOMP Rig up and fill test equipment. Circulate system.
21:00 - 22:00 1.00 BOPSU P DECOMP Start BOPE test. However the kill line HCR Valve on the
Koomey Unit was leaking in both the open and closed position.
Abort BOPE test.
22:00 - 22:30 0.50 BOPSU N RREP DECOMP PJSM. Review LOTO proceedures for working on the Koomey
Unit system. Discuss proper tools needed to make repairs.
Remind each member involved to have a handover with their
alternate at crew change before repairs continue.
22:30 - 00:00 1.50 BOPSU N RREP DECOMP Re lace the kill line 4-wa valve on the Koome Unit.
However, the replaced valve continues to still leak.
1/14/2009 00:00 - 08:00 8.00 BOPSU N RREP DECOMP Discuss with Rig Mechanic the continuing leaking problem.
Replace the kill line 4-way valve, again. Trouble shoot HCR
Valve on BOP Stack. Change out HCR Valve.
08:00 - 09:00 1.00 BOPSU P DECOMP Test BOPE to 250-psi low, 3500-psi high with 2-7/8" and 4-1/2"
test joints. Use 2-7/8" test joint in the Hydrill. Getting a
hydraulic fluid leak-off into the BOP stack. Stop testing. Call
Printed: 2/16/2009 11:53:11 AM
BP EXPLORATION
Operations Summary Report
Legal Well Name: 11-09A
Page 3 of 18
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
Date From - To Hours Task Code NPT Phase Description of Operations
1/14/2009 108:00 - 09:00
09:00 - 11:00
11:00 - 12:00
12:00 - 19:30
19:30 - 23:00
23:00 - 00:00
1/15/2009 100:00 - 01:15
1.00 BOPSU P DECOMP AOGCC with an update at 0800-hours. John Crisp, said that he
will await our next call because the AOGCC needs to be
present for this ROPE test.
2.00 BOPSU N RREP DECOMP Troubleshoot hydraulic fluid leak into the BOP Stack. Do not
find anything requiring repair; suspect that something may
have gotten stuck in a seal, but nothing obvious.
1.00 BOPSU P DECOMP Resume PT on BOPE with a good VBR test against the 2-7/8"
test joint. Resume BOPE tests following BP BOPE testing
protocol. Hydril element failed.
7.50 BOPSU N DECOMP PJSM to change out Hydril conducted by Driller and
Toolpusher. Also attended by AOGCC Inspector, John Crisp,
and WSL. Every aspect of the removal of the element was
discussed with tasks assigned to various personnel. The Driller
took the assignment as Task Leader in the cellar but also
designated the Pitwatcher and Toolpusher as his relief Task
Leaders. The AOGCC Inspector witnessed the testing of the
H2S and Combustible gas alarms throughout the rig. He will
return when ROPE testing resumes.
3.50 BOPSU P DECOMP Hydril element change-out completed. Call out AOGCC Rep.
Resume BOPE test per BP/AOGCC requirements at 250/3500
psi. Test VBPRs with 4 1/2" and 2 7/8" test joints. Test
Annular with 2 7/8" test joint. Test Accumulator System. Tests
witnessed by AOGCC Rep, John Chrisp. Good test.
1.00 BOPSU P DECOMP Blow down lines. Rig down test equipment. Install Dutch
System.
1.25 WHSUR P DECOMP PJSM. Pick u Lubricator. Pressure test to 500 si. Pull Dart.
Pull TWCV. Lav down Lubricator.
01:15 - 01:30 0.25 WHSUR P
01:30 - 02:15 0.75 PULL P
02:15 - 03:30 I 1.251 PULL I P
03:30 - 13:30 I 10.00 I PULL I P
13:30 - 14:30 I 1.001 PULL I P
14:30 - 16:30 I 2.001 PULL I P
DECOMP Pull Dutch System.
DECOMP Pick-up 4 1/2" Itco Spear (3.947" Nom Catch). Plant Spear.
BOLDS. Pull Hanger free at 200K. Pull Hanger to floor at
130K with no problems.
DECOMP Circulate Well. Total = 600 bbls. Monitor well; static. (Rig up
Halco Spooling Unit while circulating). (Also hold PJSM to lay
down tubing and spool control lines while circulating).
DECOMP Release and lay down Spear. Break out and lay down Tubing
Hanger. Blow down Top Drive. Start POOH with 4 1/2" tubing.
Single down in Pipe Shed. Spool Control Line. Use constant
circulation method to keep hole full. Stop after pulling ten joints
and monitor well. Continue POOH. 40-joints out at 0645-hours.
B/O and VD SSSV; recover 61-SS Bands and all of the dual
1/4" SS Control Lines. 55-jts ~ 0715. 60-jts ~ 0800-hours.
85-jts ~ 0900-hrs. First GLM POH at 0925-hrs. 100-jts at
0930-hrs. 165-jts ~ 1145-hrs. 203-jts ~ 1330-hrs. The tubing
is now severe) corroded and is deformin in the ton s. Joint
#204 is so badly corroded that the manual slips and dog collars
have deformed the tubing. Call for manual tubing cutters from
Tool Services. Call Doyon Casing for additional slips. Utilize
the Varco SDMLs that were on "standby" and dog collar to land
the tubing. Discuss situation with ADW RWO Superintendent
and RWO Engineer.
DECOMP PJSM and THA to discuss the plan forward. See Remarks for
additional information.
DECOMP Attempt to pull one more joint and the elevators crushed the
Printed: 2/16/2009 11:53:11 AM
BP EXPLORATION Page 4 of 18
Operations .Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
Date ~ From - To Hours Task Code NPT Phase ! Description of Operations
~ - ----
1/15/2009 14:30 - 16:30 2.00 PULL P DECOMP pipe under the collar. Stop operations and call ADW Engineer,
RWO Superintendent, and Baker Fishing. All parties agree the
following course of action: PJSM to clearly describe the
procedure, P/U slowly on the tubing with the slip-type elevators,
allow the manual slips (Varco SDMLs) to ride, slack off and
use the power tongs with the backups reconfigured to backup
on the collars, P/U on joint, use link tilt to move joint toward
skate, place plastic bucket around pin end of joint and let slide
down pipe skate while driller lowers elevators. Decide not to
use a dog collar due to the added complexity as well as the
increased safety hazard from pinch points or potential of pipe
parting. All floor hands to stay off the rig floor while pulling and
lowering pipe. Doyon 16 Motorman wrote a new procedure .
titled, "Pulling and Laying Down Swiss Cheese Tubing", which
will be incorporated in their Operations Procedures Manual.
16:30 - 20:00 3.50 PULL P DECOMP Start POH and have good success. The external corrosion
almost completely disappeared after the first two joints were
POH and L/D, although there are holes from internal corrosion
on some spots of most tubes. #216 ~ 1700-hours. #226 ~
1720-hrs. Set Floor Safety valve and S/D for Lunch. Continue
to lay down remaining 4 1/2" tubin. (Tongs crushed Jt # 255,
256, 263. Cut with manual tubing cutter). Recovered a total of
269 joints and a 19.14' Jet Cut Stub. O.D. = 5". Good cut.
20:00 - 21:00 1.00 PULL P DECOMP Rig down tongs and handling equipment. Clear and clean
floor.
21:00 - 23:00 2.00 PULL P DECOMP PJSM. Bring BHA #1 to floor and make up as follows: 5 7/8"
OD x 4 1/2' ID special uide hoe, vers ot, xtention,
Bumper Sub, Oil Jar, XO, 9 ea 4 7/8" Drill Collars, XO,
Intensifier, XO.
23:00 - 00:00 1.00 PULL P DECOMP Single in with BHA #1, picking up 4" Drill Pipe from Plpe Shed.
1/16/2009 00:00 - 09:00 9.00 PULL P DECOMP Continue to single in with BHA #1 and 4" Drill Pipe from Pipe
Shed. Lightly tagged top of 7" x 29 Ib/ft Liner at 6,365' md.
PUW = 132K, SOW = 98K, RTW = 116K. (Needed slight
rotation to enter Liner top). (Have _8,300' picked up at 06:00
hrs). No fluid losses while RIH.,
09:00 - 10:00 1.00 FISH P DECOMP 0900-hrs, P/U single joint an IH under stand #115. RIH with
stand #115; parameters: Up wt 230K-Ibs, Down wt 125K-Ibs,
pump rate 2.8-BPM, 240-psi, Rotating wt 163K-Ibs, Free
Torque SK-Ib-ft. Stop rotating and slowly RIH and tag 27' in,
exact) at 11,225 , t e e- me cu o ep ase in wi
-.5-1 K-Ibs WOB to shine up the top of the cutoff. Stop rotating
at 28' in. P/U to check weight, close to same P/U wt. RIH
slowly and mark for additional swallow for the overshot. We
know the tubing is fragile, so ease in with the swallow and ain
3', but don't want to mash more tubing. Decide to POH to see if
we have any fish.
10:00 - 16:30 6.50 FISH P DECOMP POH and S/B DP in Derrick. No fluid losses while POH.
1600-hours at DCs. No fish, but there were scratch marks
about 12" inside the dress-off mill. We had made -3' of
progress after tagging, so it is likely that the corroded tubing
was piling up as we slowly RIH. Call ADW engineer and decide
to RBIH with a shoe and Washpipe.
Printed: 2/16/2009 11:53:11 AM
~ ~
BP EXPLORATION Page 5 of 18
- Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
i
Date ~ From - To Hours ' Task Code NPT Phase Description of Operations
1/16/2009 16:30 - 21:00 4.50 FISH P DECOMP PJSM to make up Washpipe BHA. (Had to wait on 2
replacement joints of Washpipe due to wrong threads. Also
had to wait on hotshot truck to deliver the two joints). Make-up
BHA #2 as follows: 6" x 4 7/8" Shoe, 4 joints of 5 3/4"
Washpipe, Washover Boot Basket, Bumper Sub, Oil Jar,
Pump-Out-Sub, XO, 9 each 4 7/8" Drill Collars.
21:00 - 00:00 3.00 FISH P DECOMP Trip in with BHA #2 and Drill Pipe from the derrick. Had to
rotate slightly to get into the 7" Liner top at 6,365' md.
Continue to RIH with caution due to tight tolerances between
the BHA O. D. and the 7" 29 Ib/ft Liner I. D.
1/17/2009 00:00 - 02:00 2.00 FISH P DECOMP Continue to trip in with BHA #2 and Drill Pipe from the Derrick.
Stop to cut and slip Drilling Line.
02:00 - 02:15 0.25 FISH P DECOMP PJSM for cutting and slipping Drill Line.
02:15 - 03:30 1.25 FISH P DECOMP Cut and slip Drilling Line (114'). Inspect Draw works brakes.
Inspect Dyno-Matic linkage.
03:30 - 09:30 6.00 FISH P DECOMP Continue in looking for top of Fish. PUW = 230K. SOW =
125K with pumps off. Pump rates. Pump #1 = 2.5 bpm/270
psi. Pump #2 = 3.0 bpm/270 psi. RTW = 165K, 50 RPMs,
Pump #2 at 4.0 bpm/530 psi. Taaaed top of Fish at 11,229'
md. Start to washover fish with 50 rpms, pump #2 at 4.0/510
psi. Depth at 06:00 hrs _11,245' md. Pump HiVis sweep at
0800-hours. Maximum depth of 11,248' and we appear to be
spinning on something, making no head way. Decide to POH to
check shoe and confer with Baker. Increase circulating rate to
7-BPM, 1420-psi. Will continue milling until sweep comes back,
then POH to check the shoe. No fluid lost to formation during
this operation.
09:30 - 14:30 5.00 FISH P DECOMP PJSM. POH and S/B DP in Derrick. Stand #20 POH at
1100-hours. #45 ~ 1155-hrs. #65 ~ 1230-hrs. #85 ~
1300-hrs. #105 ~ 1330-hrs. Drill collars at 1430-hours.
14:30 - 15:30 1.00 FISH P DECOMP S/B DCs in Derrick. Find fish in the shoe, and shoe is worn out.
The fish consisted of the 23' long cutoff, acollar with2-3" of
body that was not milled over, and the top 1' of the 10' pup joint
that is screwed into the GLM. All of the cutoff joint and 2/3s of
the collar was wadded u inside the bottom wash i e 'oint.
Recovered 15-Ibs of steel cuttings from the boot basket. New
to of fish is 11,250'.
15:30 - 16:00 0.50 FISH P DECOMP Clear and clean rig floor.
16:00 - 17:00 1.00 FISH P DECOMP PJSM. M/U (second Washpipe assembly) BHA #3.
17:00 - 20:45 3.75 FISH P DECOMP Trip in with BHA #3 and 4" Drill Pipe from Derrick. Rotate
slightly to pass through 7" Liner top. Continue in hole.
20:45 - 00:00 3.25 FISH P DECOMP Looking for expected top of fish at 11,250' md. PUW = 235K.
SOW = 134K. RPMs = 60/9K Torque. RTW = 165K. Pump
#1 at 30 spm/210 psi, 40 spm/270 psi. Pump #2 at 30 spm/280
psi, 40 spm/450 psi. Bring Pump #2 on at 5.0 bpm/550 psi.
Tag top of fish at 11,249.8' md. Continue to wash over top of
Fish. Unable to swallow Fish. Slow progress. It is assume
_ that the top of Fish is "balling up" below the shoe. Got down to
11,252' md. No further progress made.
1/18/2009 00:00 - 01:00 1.00 FISH P DECOMP End second washover attempt. Circulate bottoms up at 7.0
bpm/1310 psi. Monitor Well static.
01:00 - 05:30 4.50 FISH P DECOMP PJSM. Pump "dry job". Blow down Top Drive. Trip out with 4"
Drill Pipe and BHA #3. Stand back 10 stands. Monitor Well.
Printed: 2/16/2009 11:53:11 AM
• s
BP EXPLORATION Page 6 of 18
Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
Date From - To Hours I Task Code NPT Phase ~ Description of Operations
1/18/2009 01:00 - 05:30 4.50 FISH P DECOMP Continue TOOH. No losses or gains while POH.
05:30 - 08:00 2.50 FISH P DECOMP Finsh POOH. Lay down BHA #3. Do not find anything inside
wash i e, but the shoe is worn out with no car i e remaining
on the outside of the mill. Over 2" of the Metal Muncher shoe
was worn away with only one row of buttons remaining inside
the shoe. Call ADW engineer to discuss RIH with a bladed junk
mill to grind up the twisted, rotten tubing pup joint remaining at
the top of the GLM..
08:00 - 08:30 0.50 FISH DECOMP Clear and clean Rig Floor.
08:30 - 10:00 1.50 FISH P DECOMP PJSM. M/U BHA: 5-bladed, flat-bottom Junk Mill, 3-ea 4-3/4"
Boot Baskets, Bit Sub, Bumper Sub, Oil Jar, Pump-out Sub,
and XO-sub. RIH on 3-stands of DCs.
10:00 - 14:00 4.00 FISH P DECOMP RIH BHA and DCs on DP from Derrick. 20-stands RIH at
1055-hours. 45 ~ 1150-hrs. Find 7" Liner top at 6365' with very
light tag. P/U and M/U to Top Drive; slowly rotate to the right
and enter the liner with no difficulty or drag. B/O from Top
Drive. Continue RIH with DP from Derrick. (No losses or gains
IH Stop at 11,215' and M/U to Top Drive; get
parameters: P/U wt 230K-Ibs, S/O wt 132K-Ibs, Rot wt
165K-Ibs, 7-BPM, 990-psi, 60-RPM, Free torque 10K-Ib-ft.,
14:00 - 21:30 7.50 FISH P DECOMP Slowl RIH and tag at 11,250'. Mill with 1-2K-Ibs WOB,
60-RPM, 13K-Ib-ft milling torque. Change out drilling line
spools and lift the Arctic Grade 1000-gallon day fuel tank to the
rig roof with hydraulic crane--more information in "Remarks".
Mllled up the 4 1/2" Pup Joint from 11,250' down to the steel _
_ collar on top of GLM#4 at 11259' Continue to mill up steel
collar and top of GLM #4 to 11,260'. Pump sweeps as needed.
Mlx and pump a final 20 bbl sweep and chase back to surface
at 11.5 bpm/2400 psi. Recovered fine metal shavings on
magnets.
21:30 - 22:00 0.50 FISH P DECOMP PJSM. Pump dry-job. Blow down lines and top Drive. Monitor
Well static. Trip out with 4" Drill Pipe standing back in Derrick.
(pulled 10 stands. Stop and flow check well).
22:00 - 00:00 2.00 FISH P DECOMP Continue to trip out with 4" Drill Pipe and BHA #4.
1/19/2009 00:00 - 02:00 2.00 FISH P DECOMP Finish tripping out with 4" Drill Pipe and BHA #4.
02:00 - 02:30 0.50 FISH P DECOMP Lay down BHA #4. Junk MIII ~50% worn. Clean Boot Baskets
and recovered ~1 gallon of fine metal shavings and -1/2 pound
of sm to med pieces of rotten Tubing.
02:30 - 03:30 1.00 FISH P DECOMP Clear and clean floor.
03:30 - 04:00 0.50 FISH P DECOMP PJSM. Bring BHA #5 to the floor.
04:00 - 05:00 1.00 FISH P DECOMP Make u BHA #5 as follows: 6" x 4 3/4" Shoe, 3 Joints of 5
3/4" TSS Washpipe, Washover Boot Basket, Bumper ub, Oil
Jar, Pump-Out Sub, XO Sub, 9 ea $ 7/8" Drill Collars.
05:00 - 10:30 5.50 FISH P DECOMP Trip in with BHA #5 and 4" Drill Pipe from Derrick. Stop above
7" Liner top to get parameters, then slowly RIH through liner
top with no difficulty. Continue RIH.
10:30 - 18:00 7.50 FISH P DECOMP Stop RIH and get parameters: Up wt 235K-Ibs, Down wt
126K-Ibs, Rotating wt 164K-Ibs, 4.5-BPM, 460-psi. Tag fish at-
11 259' and be in to washover fish at 60-RPM with 2-5K-Ibs
WOB, 10-18K-Ib-ft, then increasing WOB to 8K-Ibs. Vary the ',
pump rate from 1.2-BPM at 160-psi to 5-BPM at 560-psi. Pump
a Hi-Vis sweep every hour on the 1/2-hour. Make it past the
GLM and its bottom collar as well as the 10' pup joint and into
Printed: 2/16/2009 11:53:11 AM
~ ~
BP EXPLORATION
Operations Summary Report
Legal Well Name: 11-09A
Page 7 of 18 ~
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
Date From - To Hours I Task Code NPT Phase Description of Operations
1/19/2009 10:30 - 18:00 7.50 FISH P DECOMP the top collar of the full joint at 11,275' at 1500-hours. Make it
through that collar at 1530-hours. 1700-hours milling at
-11,282'. 1745-hours milling at 11,292', in the middle of the full
18:00 - 22:00 4.00 FISH P DECOMP Continue milling operations. Stop foward progress at 11,306'
to sweep the hole at a high rate. Increase pump rate to 12.0
bpm/2720 psi to clean bottoms up. Returns =some sand.
Resume milling. Continue down to 11 312'. No further
progress. (total progress made = Milled/Washover 52 in 10.5
22:00 - 23:30 1.50 FISH P DECOMP Mix a Hi-Vis Sweep. Circulate Sweep back to surface at 12.0
bpm/2640 psi.
23:30 - 00:00 0.50 FISH P DECOMP POOH. Overpull = 290K then broke back. Have 10 - 15K drag
while pulling the Washpipe up hole 52'. Blow down lines. Blow
down Top Drive.
1/20/2009 00:00 - 04:45 4.75 FISH P DECOMP Monitor Well static. Continue POOH with 4" Drill Pipe, BHA #5
and part of the Fish. Continue dragging 10 - 15K in the 7"
Liner. Fish hung up at 9,011'. Work free. Continue POOH.
Stand back Drill Collars.
04:45 - 05:45 1.00 FISH P DECOMP Lay down Oil Jars, Bumper Sub, and Boot Basket. Lay down
top joint of Wash pipe. Pull the next two joints above rotary
Table. Part of Fish is inside.
05:45 - 06:00 0.25 FISH P DECOMP PJSM. Discuss laying down remaining BHA and Fish. Discuss
method to break out the trapped fish, which may require
several stops to revise the extraction process. Crewmen
described what they would be doing to stay out of the line of
fire for various operations.
06:00 - 07:30 1.50 FISH P DECOMP Break off Milling Shoe to get at fish. Recover the pup joint from
the bottom of the GLM and the remains of the GLM with
chunks of junk from the previous flat-bottom milling operation.
Called AOGCC to alert them of impending weekly BOP test for
sometime this afternoon. Jeff Jones, AOGCC Inspector,
returned call immediately to waive State's right to witness the
test.
07:30 - 08:30 1.00 FISH P DECOMP P/U and M/U new 4-3/4" Washover Shoe and RIH on 2-joints of
nLrashpipe
08:30 - 13:30 5.00 FISH P DECOMP RIH Washpipe BHA #6 on DP and DCs from Derrick. Above
the 7" Liner at 1100-hours, P/U and rotate two revolutions and
~~ slowly drop through the liner top. Continue RIH. Park BHA at
_11,154'
13:30 - 14:00 0.50 FISH P DECOMP Service rig floor equipment
14:00 - 17:00 3.00 FISH P DECOMP Prep for fluid swap. PJSM. Displace Well with clean Sea
Water at 8.0 bpm/1550 psi. Total bbls pumped = 675. blow
down lines and Top Drive.
17:00 - 18:30 1.50 FISH P DECOMP Pick up Halco 9 5/8" RTTS Storm Packer. Set -100' below
Rota Table. Pull 1 stand. Test Packer at 1000 psi x 10
minutes. Record on chart. good test.
18:30 - 19:00 0.50 FISH P DECOMP Rig up test equipment.
19:00 - 00:00 5.00 FISH P DECOMP Test BOPE per BP/AOGCC requirements at 250/3500 psi.
Tested VBPRs with 2 7/8" and 4" Test Joints. Tested Annuluar
with 2 7/8" Test Joint. Test Koomey Unit. The State's right to
witness the test was waived by J. Jones.
,1/21/2009 00:00 - 01:30 1.50 FISH P DECOMP Complete BOPE test. Rig down test equipment. Blow down
Printed: 2/16/2009 11:53:11 AM
~ ~
BP EXPLORATION
Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A
Event Name: WORKOVER
Contractor Name: DOYON DRILLING INC.
Rig Name: DOYON 16
i
Date From - To Hours Task I Code NPT
1/21/2009 00:00 - 01:30 1.50 FISH P
01:30 - 02:30 1.00 FISH P
02:30 - 06:00 3.501 FISH P
Page 8 of 18 ~
Spud Date:
Start: 1 /12/2009 End:
Rig Release: 2/1 /2009
Rig Number:
Phase Description of Operations
DECOMP lines. Pull Test Plug. Install Wear Bushing.
DECOMP RIH with 1 stand of Drill Pipe. Release and pull Halco 9 5/8"
RTTS Storm Packer. Lay down same.
DECOMP Resume Washover and Milling operations. PUW = 240K.
SOW = 132K. RTW = 170K. Pump #1 = 30 spm/200 psi, 40
spm/340 psi. Pump #2 = 30 spm/250 psi, 40 spm/450 psi.
Free rotation = 60 RPMs/14K torque. Tagged top of remaining
Fish at 11,302'. Continue to washover and mill down to
06:00 - 14:30 8.50 FISH P DECOMP Continue milling until no further progress made. Pumped
Hi-Vis sweeps as needed. Final static taa 11,320'. Total
footage milled this run = 18'. Started seeing a fluid loss of -2.0
bph while milling.
14:30 - 16:00 1.50 FISH P DECOMP Mixed and pumped a final 20 bbl Hi-Vis sweep and chase back
to surface at 11.0 bpm/2360 psi. Total volume pumped = 611
bbls. Monitor Well static. Pump dry-job. Blow down lines and
Top Drive. Set down 5K weight on Shoe.
16:00 - 21:15 5.25 FISH P DECOMP Start to trip out with 4" Drill Pipe and BHA #6. Had 45 - 50K
overoull from 11.320' - 10.869' Had to qumo out of hole
21:15 - 23:15 I 2.001 FISH I P
23:15 - 00:00 I 0.75 I FISH I P
1/22/2009 100:00 - 04:15 4.251 FISH I P
04:15 - 04:30 0.25 FISH P
04:30 - 06:00 1.50 FISH P
06:00 - 07:30 I 1.50 I FISH I P
07:30 - 12:00 I 4.501 FISH I P
12:00 - 17:00 I 5.001 FISH I P
17:00 - 18:00 I 1.001 FISH I P
Continue to trip out. Sawa 10K - 15K overpull at 6,700'.
Continue to trip out. Stand back Drill Collars.
DECOMP Lay down BHA #6. Shoe was 100% gone. Recovered -6' of
Basket. Recovered _ 20 Ibs of metal cuttings and misc sized
pices of rotten tubing. Clear and clean floor. Discuss plan
forward for next BHA with Day WSL, Baker Fishing Tool
Supervisor, Anch Supervisor and Anch Engineer.
DECOMP Make up BHA #7 as follows: 6" Junk Mill, 3 ea Boot Baskets,
Bit Sub, Bumper Sub, Oil Jar, Pump out Sub, XO, 9 ea 4 7/8"
Drill Collars.
DECOMP Trip in with BHA #7 and 4" Drill Pipe from Derrick. Saw
"bobble" at 6,365' and at the 7" Liner top. Continue in 7" Liner.
Tagged early at 11,082' (expected tag was 11,320'). Fish was
hanging up on previous TOH. During "faring" to get free, part
of the fish broke off and is hun u at the resent to de th_.
DECOMP PJSM. Prep to Cut and slip Drilling Line.
DECOMP Cut and slip Drilling Line. Adjust brakes. Check out and
service Top Drive. Lube Dyno-Matic coupler.
DECOMP Push junk down hole from 11082 ft to 11322 ft. Roate at 60
rpm's ant 10,000 ft-Ibs of torque, with 1,000 - 5,000 Ibs WOB.
DECOMP Mill on junk and packer at 11322 ft. Initial Parameters- P/U =
235,000 Ibs S/O Wt = 135,000 Ibs. Free Torque = 10,000 ft
-Ibs at 60 rpm's. Pump rate at 1.5 to 7.5 bpm with 60 to 1250
psi. Mill from 11322 ft to 11324 ft.
DECOMP Continue to mill on packer from 11324 ft to 11327 ft. See good
torque an mi tilling off, work at 60-80 rpm's and 10-15,000
Ibs WOB. Circulate around sweep at 8 bpm. See rubberjust
ahead of sweep. Loose circulate momentarily after sweep at
surface. Shut -down pumps and flow check well. No flow,
fluid level falling.
DECOMP Circulate bottoms up at 8 bpm and 1250 psi. Loosing 18 bph
while circulating initially. Losses subsided after pumping -100
Printed: 2/16/2009 11:53:11 AM
~ ~
BP EXPLORATION Page 9 of 18
Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
-Date From- To Hours Task' Code NPT Phase Description of Operations
1/22/2009 17:00 - 18:00 1.00 FISH P DECOMP bbls.
18:00 - 18:30 0.50 FISH P DECOMP Monitor Well, static. Pump dry-job. Blow down lines and Top
Drive.
18:30 - 22:00 3.50 FISH P DECOMP Trip out with 4" Drill Pipe, 4 7/8" Drill Collars.
22:00 - 22:30 0.50 FISH P DECOMP Pull BHA #7. Mill 80% gone. Break out and lay down BHA #7.
Clean Boot Baskets. Recovered 57 Ibs of metal cuttings and
misc sized peices of rotten tubing.
22:30 - 23:00 0.50 FISH P DECOMP Clear and clean floor.
23:00 - 00:00 1.00 FISH P DECOMP Make up BHA #8 as follows: 6" x 4 3/4" Shoe, Washpipe,
Washpipe Extention, Washpipe Extention, Washpipe
Extention, Washpipe Boot Basket, Bumper Sub, Oil Jar,
Pump-Out-Sub, XO Sub, 9 ea Drill Collars.
1/23/2009 00:00 - 00:30 0.50 FISH P DECOMP Finish making up BHA #8.
03:00 - 05:00 2.00 FISH P DECOMP Trip in with BHA #8 and 4" Drill Pipe from the Derrick.
05:00 - 07:00 2.00 FISH P DECOMP PUW = 244K. SOW = 130K. Pump #1 at 30 spm/150 psi, at
40 spm/250. Pump #2 at 30 spm/190 psi, at 40 spm/350 psi.
RPMs =60. Torque = 11 K ft/Ibs. RTW = 170K. Tagged
Packer at 11,327'. Burn over remains of acker with 6" x 4-
3/4" Burn Shoe.
07:00 - 10:00 3.00 FISH P DECOMP Wash down over tail pipe below backer washing away sand,
burn over 1 tubing collar and 1 X Nipple. Required -5,000 Ibs
WOB to wash /burn through everything. Pump sweeps to
clean hole.
10:00 - 12:30 2.50 FISH P DECOMP Pump 20 bbl high Visc Sweep and Chase out of hole at 11 bpm
and 2060 psi. Returns had a good amount of rubber, iron, and
sand. Still seeing quite a bit of sand in returns after sweep.
Pump second 20 bbl High Visc Sweep at same rate. Hole
cleaned up after second Sweep.
12:30 - 20:30 8.00 FISH P DECOMP Monitor Hole10 mins and Pump Dry Job. POOH and Stand
~ Back Drill Pipe. Seeing constant 5-7,000 Ibs coming off
bottom. Notice hole swabbing after pulling first 5 stands.
Check for flow, no flow. Circulate bottoms up at 10 bpm and
1230 psi. Continue to pull out of hole. Still Swabbing.
Repeat flow check and circulate bottoms up again. No gas or
flow seen after circulations. Advise Town and continue to pull
out of hole. Hole fill on target after second circulation. Stop to
monitor Well for 15 minutes with one stand left before BHA.
Fluid level in riser remains static.. No Trip Tank gain. Stand
back Drill Collars.
20:30 - 21:00 0.50 FISH P DECOMP Pull BHA #8 and recovered Fish. PJSM. Lay down Fish.
Recovered what was left of the Packer, 2 ea 10' Pup Joints,
X-Nipple, and -4-ft of the Pup Joint below the X-Nipple. Total
lenght recovered - 26.24'. (Fish remaining in hole = -16'
remains of the Pup Joint and the WLEG. Top o is`Ti fs
twisted, man led, and rotten. Remaining length = -17'). Clean
Boot Basket. Recovered -10 Ibs of metal cuttings and misc
sized pieces of rotten tubing.
21:00 - 21:30 0.50 FISH P DECOMP Clear and Clean Floor. Discuss plan forward with Day WSL,
BFT Supervisor, and Anch Supervisor.
21:30- 22:30 1.00 FISH P DECOMP Make up BHA #9 as follows: 6" x 4 3/4" Shoe, Poor Boy Finger
Basket, 3 ea 5 3/4" Washpipe Exts, Top Bushing, Bumper
Sub, Oil Jar, Pump-Out-Sub, XO, 9 ea 4 7/8" Drill Collars.
22:30 - 00:00 1.50 FISH P DECOMP Trip in with BHA #9 and 4" Drill Pipe from the Derrick.
Printed: 2/16/2009 11:53:11 AM
~ ~
BP EXPLORATION Page 10 of 18
Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
Date i From - To Hours I Task Code ~ NPT Phase Description of Operations
__. __.
1/24/2009 00:00 - 02:15 2.25 FISH P DECOMP Continue to trip in with BHA #9 and Drill Pipe. Had to rotate to
get through the 7" Liner top at 6,563' md. Normal Drill Pipe
displacement every 5 stands.
02:15 - 03:00 0.75 FISH P DECOMP PUW = 250K. SOW = 125K. Pump #1 at 30 spm/150 psi, at
40 spm/240 psi. Pump #2 at 30 spm/190 psi, 40 spm/320 psi.
RPMs = 60. Torque = 13K ft/Ibs. RTW = 170K. Start ease in
with Pump #2 at 1.5 bpm/70 psi. No rotation. Did not see a
tag. However, saw "bobbles" starting at 11,362'. Continue
Gown to 11,397' where sand bottom got soild with 5K weight on
Shoe. Repeat with same results.
03:00 - 04:30 1.50 FISH P DECOMP Pick-up to 11,352'. Mix and pump a 20 bbl Hi-Vis and chase
back to surface at 9.0 bpm/1310 psi. Total pumped = 700 bbls.
Barrel for barrel returns. Some sand in returns. Looks mostly
like 100 mesh. Shut down pumps. Monitor Well for 10
minutes. Fluid level in riser remains static. Pump Dry-Job".
Ease back in and tag at 11,397.5'. with 10K weight on Shoe.
04:30 - 08:30 4.00 FISH P DECOMP rip out with 4" Drill Plpe, BHA #9, and Fish. Normal drag.
First 5 stands pulled. Normal 2.8 bbls hole fill. Next 5 stands
pulled also normal hole fill. Stop with 10 stands pulled.
Monitor Well for 10 minutes, static. Continue tripping out of the
7" Liner, slowly. POOH through 9-5/8" casing and stop to
monitor hole prior to POOH w/ BHA
08:30 - 10:00 1.50 FISH P DECOMP POOH and Stand Back DC's. Break Out BHA. No Fish.
B/O Wash Pipe Extensions and Empty Boot Baskets.
Collected -15 Ibs of iron and sand. Clean and Clean Rig Floor.
10:00 - 11:00 1.00 FISH P DECOMP Wait on Rotary Shoe from Baker Fishing and Bushing
Extension from Grapple. Run Diagnostics and Trouble Shoot
problems on TOTCO.
11:00 - 12:00 1.00 FISH P DECOMP M/U BHA with 6" x 4-1/2" Rotary Shoe, Bushings, Overshot
Grapple with 4-1/2" Nominal Size, Wash Pipe Extensions and
Drill Collars. Total Length = 323.44 ft
12:00 - 14:00 2.00 FISH P DECOMP RIH with 4" DP from Derrick.
14:00 - 14:30 0.50 FISH P DECOMP Tag Up momentarily just above the liner top with -5,000 Ibs.
Continued down to liner top with out seeing anything. Rotate
through liner top and continue in the hole. Tag up again on
something just inside top of liner at 6419 ft. Took up to 10,000
lbs. Required 15,000 Ibs over pull to come off. M/U Top
Drive and circulate at 3.5 bpm and 120 psi. Pipe took 5,000
Ibs with circulation to pull up hole then _10,000 Ibs to work
down initially.
14:30 - 15:00 0.50 FISH P DECOMP Take Parameters P/u Wt = 133,000 Ibs S/O Wt = 100,000 Ibs.
Rotating Wt = 117,000 Ibs with 40 rpm's and 5,000 ft-Ibs of
torque. Work through area where took weight, taking aound
3,000 Ibs to work through initially. Make multiple passes
through 6419 ft area, then make pass with no pumps or
rotation.
15:00 - 15:30 0.50 FISH P DECOMP B/O Top Drive and Blow Down. Continue to trip in the hole.
Taking some wt going in the hole. Take -8,000 Ibs at 6540 ft.
P/U and Work up and down through area. Decide to PUH
and Check against liner top might have fish.
15:30 - 16:00 0.50 FISH P DECOMP Pull Up Hole above Liner Top at 6365 ft. S/O and Tag Liner
-2-3 ft hi her that what have seen revious. P/U and Make a
rotation and try again. Seeing same thing.
Printed: 2/16/2009 11:53:11 AM
• •
BP EXPLORATION Page 11 of 18
Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
Date From - To Hours Task -Code NPT .Phase Description of Operations
1/24/2009 16:00 - 18:00 2.00 FISH P DECOMP POOH and Stand Back DP from Liner Top.
18:00 - 18:30 0.50 FISH P DECOMP Stand Back DC's and look at BHA. Found Leading Edge of
Rotary Shoe slightly peeled out make the OD of the shoe a
little bit lar er than 6".
18:30 - 21:30 3.00 FISH P DECOMP Discuss plan forward. Send Shoe to BFT to be modified. Wait
on Shoe.
21:30 - 22:00 0.50 FISH P DECOMP Make up BHA same as before: 6" x 4 1/2" Dress Off Shoe,.
Bushing, 5 7/8" Overshot w/4 1/2" Grapple, Bushing, Washpipe
Entention, Washpipe Extention, Washpipe Extention,
Washpipe Boot Basket, Bumper Sub, Oil Jar, Pump-Out-Sub,
XO, 9 ea Drill collars.
22:00 - 00:00 2.00 FISH P DECOMP Trip in with BHA #10 re-run and 4" Drill Pipe from the Derrick to
7" Liner top. Kelly-up to go through Liner Top. PUW = 131 K.
SOW = 100K. RPMs = 10. Rotate and slowely pass through
Liner Top at 6,365' and with no problems. Continue in 7" Liner
1....1.:.... {... {L,.. {:wN
1/25/2009 00:00 - 01:45 1.75 FISH P DECOMP Continue trip in. Stop at 11,292'. Kelly up and get parameters.
PUW = 250K, SOW = 128K. Pump #2 at 30 spm/230 psi, at
40 spm/340 psi. RPMs = 60. Torque = 13K fUlbs. RTW =
174K. Ease down looking for top of fish. Tag Fish at 11,369'.
Wash and rotate at 4.0 bpm/300 psi at 60 RPMs.
01:45 - 03:30 1.75 FISH P DECOMP Dress off and swallow Fish. Pump pressure increased to 700
psi. Pull up 10K over string weight to plant Overshot. Pull up
to 25K over and allow Jar to fire. Continue to cycle Jar at 25K
over. After 4 cycles, Fish came free. Now have 25K drag.
Bring pump back on line at 1.5 wpm/120 psi, and pump string
out of hole. Stand back three stands. Now pulling normal
string weight. Drop dart to open Pump-Out-Sub.
03:30 - 05:00 1.50 FISH P DECOMP Saw Pump-Out-Sub open at 2420 psi. Increase pump rate to
11.0 bpm/1380 psi. Circulate and condition Well. Pumped 620
bbl total. Monitor Well for 10 minutes. Fluid level in riser
remains static. Pump Dry job. Blow down Top Drive.
05:00 - 08:45 3.75 FISH P DECOMP Pull 10 Stands. Monitor Well, static. Continue to trip out with
4" Drill Pipe, BHA #10, and Fish.
08:45 - 10:00 1.25 FISH P DECOMP Stand Back DC's and B/O BHA. Found fish in Overshot.
Recovered 12.4 ft of tb with WLEG attached. Top 6 inches of
fish was mangled pipe. L/D Fish and BHA. Consult town on
next run in the hole. Wash Pipe showed signs of junk down
hole some areas that were junk cut pretty heavily.
10:00 - 10:30 0.50 FISH P DECOMP Clear and Clean Rig Floor.
10:30 - 12:00 1.50 CLEAN P DECOMP Rebuild Pump Out Sub. M/U BHA for Clean Out Sand and
Junk Iron on bottom of hole. 6" Shoe on 5-3/4"
Extensions, Boot Baskets, Casing Scraper, Bumper Sub, Jars,
Pump Out Sub, and DC's. Total Length = 325.24 ft
12:00 - 15:45 3.75 CLEAN P DECOMP RIH with BHA on DP. Rotate through top of liner at 6365 ft.
Continue in the hole to 11300 ft.
15:45 - 16:15 0.50 CLEAN P DECOMP M/U Top Drive and Take Initial Parameters of P/U Wt =
230,000 Ibs S/O Wt = 130,000 Ibs Rotate Wt = 175,000 Ibs
with 40 rpm's and 10000 ft Ibs torque. Pump Pressure = 830
', psi at 6 bpm. Shut down pumps and Tag Top of Junk /Sand
at 11371. Break connection at rig floor and drop ball for RCJB.
16:15 - 17:00 0.75 CLEAN P DECOMP Circ at 3 bpm and 200 psi at while ball falls, work Scraper
Printed: 2/16/2009 11:53:11 AM
•
BP EXPLORATION
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date From - To
1 /25/2009 116:15 - 17:00
17:00 - 18:15
18:15 - 21:30
21:30 - 23:00
23:00 - 00:00
1 /26/2009 00:00 - 02:45
02:45 - 04:00
04:00 - 04:30
04:30 - 05:15
05:15 - 06:00
06:00 - 09:00
09:00 - 12:00
12:00 - 13:00
13:00 - 16:30
16:30 - 17:00
11-09A
11-09A
W ORKOVER Start: 1 /12/2009
DOYON DRILLING INC. Rig Release: 2/1/2009
DOYON 16 Rig Number:
Hours Task ~ Code ~ NPT ~ Phase
Page 12 of 18
Spud Date:
End:
Description of Operations
0.75 CLEAN P DECOMP across 11350 ft. Bring Pumps up to 8.5 bpm and 1980 psi.
S/O and Mill on junk on top of sand for 15 mins. Required
3-5,000 Ibs WOB to work through. Clean Out sand to 11423
ft.
1.25 CLEAN P DECOMP Mix and pump a Hi-Vis sweep. Chase back to surface at 8.5
bpm/2,000 psi.
3.25 CLEAN P DECOMP Pull three stands and set back in Derrick. Pick-up 9 singles
from Pipe Shed. Continue washing sand from 11,423'. Pump
rate 8.5. bpm/2040 psi. Washing sand ahead of some junk.
Noticed an abrupt 300 psi decrease (?). Having trouble with
junk causing stall out and sticking problems. Got down to
11 501' md. Clean-out tar et = 11,648' . No further progress
made. Discuss plan forward with Day WSL, Anch Supervisor,
Anch Eng. All agree to POOH and clear RCJB.
1.50 CLEAN P DECOMP Mix and pump Hi-Vis sweep and c ase ac o surface at 10.2
bpm/2340 psi. (Keep Drill Pipe moving while circulating).
Monitor fluid level in the riser, static.
1.00 CLEAN P DECOMP Trip out with 4" Drill Pipe and BHA #11. Stop with 10 stands
pulled and monitor fluid level in riser for 10 minutes, static.
Pump dry job. Blown down Top Drive. Continue to trip out.
2.75 CLEAN P DECOMP Continue to trip out with 4" Drill Pipe and BHA #10. Normal
hole fill. Stop at the top of the 7" Liner and monitor fluid level in
the riser, static. Continue tripping out. Monitor Well before
standing back last stand.
1.25 CLEAN P DECOMP Lay down BHA. Break out RCJB. Recovered large pieces of
milled up and rotten tubing that were found jammed up in the
to of the tool and had most of the jets plugged. (This might
explain the sudden 300 psi pressure drop noticed during the
clean-out). Recovery =One piece of twisted tubing -1-ft long,
several large flat pieces, and several small pieces of tubing.
Clean out Boot Baskets. Recovered _ 1 gal of metal fines and
sand. The second Boot Basket was empty. The Oil Jar had a
piece of metal sticking out of the top seal. One Boot Basked
had two braces that were found cracked.
0.50 CLEAN DECOMP Clear and clean floor.
0.75 CLEAN P DECOMP Make u the same RCJB for run #2. Plck-up new Oil Jar.
Leave out the Casing Scraper (Packer setting area and RBP
setting area has been scrapped several times). Also leave out
the damaged Boot Basket.
0.75 CLEAN P DECOMP Trip in with RCJB Run #2 and 4" Drill Pipe from the Derrick.
3.00 CLEAN P DECOMP Continue to trip in. PUW = 255K. SOW = 130K. RTW = 170
K. RPMs = 60. Torque = 13K ft/Ibs.
3.00 CLEAN P DECOMP Tag top of sand at 11,484'. Drop Ball. Increase pump rate to
8.5 bpm/1600 psi. Wash down to 11,500'. Tagged junk.
Milled through junk. Continue to wash through sand down to
1.00 CLEAN P DECOMP Mix and pump a Hi-Vis sweep. Chase back to surface at 9.0
bpm/2050 psi. Noticed a 500 psi drop in pressure during the
circulation.
3.50 CLEAN P DECOMP Monitor fluid level in riser static. Trip out with 4" Drill Pipe and
BHA.
0.50 CLEAN P DECOMP Lay down BHA. The RCJB has parted (box snapped) at the jet
housing connectiori. so oun a crac m a oo as e
Printed: 2/16/2009 11:53:11 AM
BP EXPLORATION Page 13 of 18
Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
Date From - To Hours Task. Code NPT Phase Description of Operations
1/26/2009 16:30 - 17:00 0.50 CLEAN P DECOMP brace.
17:00 - 18:00 1.00 CLEAN P DECOMP Clear and clean floor. Discuss fishing tool to catch remaining
section of the RCJB left in hole. Empty Boot Basket.
Recovered a few small pieces of milled tubing, metal fines, and
sand.
18:00 - 18:30 0.50 FISH P DECOMP Make up BHA #13 as follows: 6" Box Tap, Bumper Sub, Oil
Jar, Pump-Out-Sub, XO Sub, 9 ea Drill Collars.
18:30 - 00:00 5.50 FISH P DECOMP Trip in with BHA #13 and 4" Drill from Derrick. Stop above 7"
Liner Top. Kelly up. Bring Pump #1 on at 14 spm/30 psi.
RPMs = 12. Rotate through Liner Top with no problems.
Continue trip in with caution. Set down at 6,848' (?). Pick-up
clean. Tag at same spot. Kelly up and bring pump on at 3.0
bpm/130 psi. Rotate through at 10 RPMs with no problems.
Continue in hole with caution.
1/27/2009 00:00 - 00:30 0.50 FISH P DECOMP Continue to trip in with BHA #13 and 4" Drill Pipe from the
Derrick.
00:30 - 01:30 1.00 FISH P DECOMP Kelly up. PUW = 250K. SOW = 127K. Initial Pump pressure
at 30 spm/370 psi. RTW = 175K. at 40 RPMs. Torque = 10K.
Increase pump rate to 10.1 bpm/1810 psi. Rotate at 20 RPMs
and wash down to top of fish at 11,600'. Pull up hole and let
pump stabilize back at 30 spm/370 psi. Run back down to
TOF. Continue to rotate and push fish to 11,606'. Pressure
jumped up to 440 psi. Torque stalled out at 14K. Pull up hole.
Pressure remained at 440 psi (good sign). Bring pump off line
and let pressure drop to 0 psi. Rotate back down to 11,606'
without pump. Pull up hole -60'. Bring pump back on line at
30 spm. Pressure once again stabilized at 440 psi.
-60-ft. Bring pump back on line at 30 spm. Pressure once
again stabilized at 440 psi. Fish should be on.
01:30 - 06:30 5.00 FISH P DECOMP Monitor Well, static. Blow down Top Drive. Trip out with 4"
Drill Pipe standing back in Derrick. Stop at the 7" Liner Top.
Monitor well, static. Continue to trip out.
06:30 - 07:00 0.50 FISH P DECOMP PJSM, B/O and UD BHA and Fish.
07:00 - 07:30 0.50 FISH P DECOMP Clear and clean rig floor. Flush BOP stack using stack washer.
07:30 - 09:30 2.00 FISH P DECOMP PJSM with Rig Crew about BOP testing. Pull wear ring. Set
test plug. RU to test ROPE.
09:30 - 14:30 5.00 FISH P DECOMP . Test BOPE per AOGCC regs and BP procedures. Test to
250-psi low and 3500-psi high. Hold and chart all tests for
5-minutes. BP WSL and Doyon Toolpusher witness all tests.
AOGCC rep Lou Grimaldi waived witness of BOP test at
0630-hrs on 1/27/2009.
14:30 - 15:00 0.50 FISH P DECOMP R/D BOPE test equipment. Pull test plug. Install wear ring.
15:00 - 15:30 0.50 CLEAN P DECOMP PJSM on MU 2-7/8" PAC Clean out BHA. R/U 2-7/8" handling
equipment and power tongs.
15:30 - 17:30 2.00 CLEAN P DECOMP P/U & M/U Clean out BHA with 2-7/8" PAC DP, Clean out
Shoe, and 4-3/4" DC from pipe shed.
17:30 - 23:00 5.50 CLEAN P DECOMP RIH w/ Clean Out BHA on 4" DP from Derrick, breaking
circulation every 30 stands.
23:00 - 00:00 1.00 CLEAN P DECOMP Hold PJSM on Slipping and Cutting Drilling Line. Discuss
procedures and hazards associated with slipping on completely
new line. Hang Blocks with Super Tugger. Remove line from
deadman and spool new line on until splice and sufficient line
are on drum.
Printed: 2/16/2009 11:53:11 AM
BP EXPLORATION Page 14 of 18
Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
Date From - To ;Hours Task Code NPT Phase
1/28/2009 00:00 - 02:00 2.00 CLEAN P DECOMP
02:00 - 06:00 I 4.001 CLEAN I P I I DECOMP
06:00 - 12:00 6.001 CLEAN P I I DECOMP
12:00 - 20:30 I 8.501 CLEAN I P I I DECOMP
Description of Operations
Continue to Slip & Cut Drilling Line. Spool all old line off of the
drum and dispose of line in metal dumpster. Remove Dog nut
from old line and install on new line. Install Dog nut on drum
and spool new line onto drum. Tighten and adjust dead man.
Slip on a total of 1780' of Drilling line. Unhang blocks.
Obtain Clean out Parameters. PU wt = 235K-Ibs, SO wt =
125K-Ibs, Rot wt = 162K-ibs. Rotate at 60-RPM with 12K-Ibs-ft
of free torque. Pump at 9-BPM with 2760-psi. Slow pump
down to 2-BPM with 230-psi. Tag sand at 11,606'. Pump
20-bbl Hi Vis sweep at 5-BPM with 750-psi. Chase sweep at
9-BPM with 2620-psi and continue washing down. Did not see
4-1/2" liner top. PU and shut down rotation. RIH and see
bobble at 11646'. PU again and slow pumps to 2-BPM with
120-psi. Lightly tag 4-1/2" liner top at 11 646'. Resume clean
out with irntia parameters once t rough liner top. Pump
second 20-bbl Hi Vis sweep and chase at 10-BPM with
2780-psi. Work stand as it is pulling ~10K-Ibs over coming up
hole. Once second sweep is well outside of the bit, pump
20-bbl Hi Vis sweep at 5.5-BPM with 870-psi. Chase sweep at
10-BPM with 2730-psi and continue working pipe. PU wt at
10-BPM = 230K-Ibs, SO wt = 125K-Ibs. MU std #105 and wash
down with same clean out parameters. When std #105 all the
way down (first section of perfs at 11,800' exposed), pump
another 20-bbl Hi Vis sweep. Seeing heavy sand returns at
bottoms up and with fourth sweep. Work stand while waiting of
sweep o roun a corner an move up the back side.
Continue to work each stand and pump sweep prior to making
each connection. Losses are negligible as of 0600-hrs.
Continue to wash and rotate wit a ove parameters, cleaning
out sand plug down to 12,522'. Pump 10-bbl Hi Vis sweeps
prior to each connection. Pump at 10-BPM with 2950-psi.
Rotate at 60-RPM with 2-3K-Ibs-ft of free torque. Run 3K-Ibs
WOB.
Continue to clean out sand from 12,522' with above
parameters. Continue to pump 10-bbl Hi Vis sweeps prior to
every connection. Unable to make any further progress at
13,228' with 5K-Ibs WOB and 15K-Ibs-ft of torque. PU and
attempt to wash further ahead twice. Still unable to make any
progress. Confer with RWO engineer and decide clean out to_
13,228' is sufficient. Loss rate -50-BPH while pumping at
20:30 - 21:30 1.001 CLEAN I P I DECOMP
21:30 - 22:00 I 0.501 CLEAN P DECOMP
22:00 - 23:30 1.501 CLEAN P DECOMP
23:30 - 00:00 0.50 ~ CLEAN P DECOMP
Pump 20-bbl Hi Vis sweep at 6-BPM with 1070-psi. Chase
sweep at 11-BPM with 3000-psi. Continue to work pipe while
circulating. Heavy sand throughout circulation, cleaning up
after sweep came ac .
Monitor well -Static. Pump Dry Job. Stand back 1-std. Blow
down Top Drive.
POH from 13,228' to 11,646', standing back 4" DP in derrick.
Have to rotate slowly and pump to get out of 4-1/2" liner top.
RIH and confirm 4-1/2" liner top at 11,646' by tagging lightly
without pumps or rotation.
Circulate at 3-BPM with 280-psi while waiting for dirty vac truck
to arrive for displacement. Hold PJSM with rig crew, Doyon
Printed: 2/16/2009 11:53:11 AM
•
BP EXPLORATION Page 15 of 18
Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
I
Date From - To ;Hours Task Code NPT Phase I Description of Operations
1/28/2009 23:30 - 00:00 0.50 CLEAN P DECOMP tourpusher, BP WSL & WSLf, and CH2MHill truckpusher and
truck drivers. Discuss hazards associated with working
outdoors in foul weather, spill potential, positions of people and
communication.
1/29/2009 00:00 - 02:00 2.00 CLEAN P DECOMP Pump 40-bbl Hi Vis Sweep at 5.5-BPM with 610-psi. Chase
sweep at 8.5-BPM with 1400-psi, displacing well with 590-bbls
of clean, 100-degree 8.45-ppg Seawater. Circulate until fluid
weight stablizes at 8.4+-ppg indicating new seawater.
02:00 - 02:30 0.50 CLEAN P DECOMP Monitor well -Static. Pump Dry Job. Stand back 1-std of 4"
DP. Blow down Top Drive.
02:30 - 05:30 3.00 CLEAN P DECOMP POH from 11646', standing back 4" DP in derrick. Loss rate
while POH = 15-BPH.
05:30 - 08:30 3.00 CLEAN P DECOMP PJSM, L/D 4-3/4" DC and Clean Out BHA.
08:30 - 09:30 1.00 CLEAN P DECOMP Clean and Clear Rig Floor.
09:30 - 10:00 0.50 CLEAN P DECOMP M/U Stack Washer to Top Drive and flush BOP stack. Blow
down Top Drive.
10:00 - 15:30 5.50 CLEAN P DECOMP P/U and M/U 7" RBP. RIH with 4" DP from derrick to 11339'.
15:30 - 15:45 0.25 CLEAN P DECOMP P/U single from shed and make up to top drive. Obtain
perameters prior to setting the RBP: P/U wt = 123K-Ibs, S/O wt
= 237K-Ibs. RIH to 11355' and pick back up to string weight to
ensure stretch is out of pipe. Put 3 left hand turns in string and
set down 20K-Ibs on RBP and let torque out of string. To
confirm release P/U 25', put 3 left hand turns in string and S/O
to string weight. UD single to pipe shed. RBP set at 11350'
COE.
15:45 - 16:30 0.75 CLEAN P DECOMP R/U test equipment. Test RBP, 9-5/8" and 7" csg to 3500-psi
for 30-charted min. Good test. R/D test equipment.
16:30 - 17:30 1.00 CLEAN P DECOMP Stand back 3-stds of 4"-DP. P/U and M/U RTTS to 1-std of 4"
DP and RIH. Make up to Top Drive. Obtain perameters prior
to setting RTTS: P/U wt = 122K-Ibs, S/O wt = 237K-Ibs. P/U
~6" to get in the up stroke, put 1 right hand turn in string, S/O
all string weight, and break out Top Drive. RTTS set at 98'.
Back out 21 left hand turns. Pull 1-std of DP. B/O & UD RTTS
running tool
17:30 - 18:00 0.50 CLEAN P DECOMP R/U test equipment. Test above RTTS to 1,000-psi for
-c a e min. oo test. test equipment.
18:00 - 18:30 0.50 CLEAN P DECOMP PJSM for N/D stack C/O 9-5/8" Pack Off and tubing spool.
P/U single jt of 4" DP and pull wear ring. Drain BOP stack.
Begin cleaning mud pits.
18:30 - 19:00 0.50 WHSUR P DECOMP M/U XOs to Cameron Pack Off pulling tool and attempt to
screw into Pack Off. Discuss with Cameron Reps and decide
to N/D BOP stack and inspect Pack Off threads. Two tested
barriers in place for N/D are 1) 7" RBP at 11,350' and 2) 9-5/8"
RTTS at 98'.
19:00 - 20:30 1.50 BOPSU P DECOMP Pull riser. Begin to ND BOP stack and tubing spool. Break
bolts between BOP stack and tubing spoof. Remove
secondary IA valve. Monitor OA and test port for pressure -
none noted.
20:30 - 22:30 2.00 WHSUR N HMAN DECOMP Attempt to install 2-1/16" VR plug in IA valve but it does not fit.
Discontinue work on ND BOP stack until solution is found.
Cameron Rep discovers Vetco-Gray "New Standard" spool
requires a unique VR plug. Cameron Rep locates correct VR
plug at CSP and leaves to retrieve it. Work on Top Drive.
Printed: 2/16/2009 11:53:11 AM
BP EXPLORATION Page 16 of 18
Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
~
I Phase Description of Operations
Date ~ From - To Hours- Task Code NPT
1/29/2009 20:30 - 22:30 2.00 WHSUR N HMAN DECOMP Chan a rams from 2-7/8" x 5" VBRs to 3-1/2" x 6" VBRs.
22:30 - 00:00 1.50 WHSUR P DECOMP Install VR plug in Tubing spool. Check OA and test port for
pressure -none noted. BOLDS on Csg Pack Off. Stand back
BOP stack. Inspect Csg Pack Off threads and they are full of
sand. Pull existing Tbg spool. Csg Pack Off comes free with
Tbg spool. Remove Tbg spool and Pack Off from cellar.
Clean API ring groove and Csg neck in preparation for
installing new Pack Off and Tbg spool.
1/30/2009 00:00 - 00:30 0.50 WHSUR P DECOMP PU Pack Off running tool and "J" into new Pack Off. Install
9-5/8" Csg Pack Off in wellhead. RILDS.
00:30 - 02:30 2.00 WHSUR P DECOMP PU new Tbg spool. NU Tbg spool and BOP stack.
02:30 - 03:30 1.00 WHSUR P DECOMP Cameron rep RU and test new 9-5/8" Csg Pack Off to 5000-psi
for 30-minutes. Good test. RD Cameron test equipment.
03:30 - 04:30 1.00 BOPSU P DECOMP Finish NU BOP stack. Use Sweeney wrench to ensure proper
torque.
04:30 - 05:30 1.00 BOPSU P DECOMP Set test plug. Fill test jt. RU to test BOP break and 3-1/2" 6"
VBRs. Test BOP break and VBRs per AOGCC regs and BP
procedures. Test VBRs with 4" and 5-1/2" test jts. Test to
250-psi low pressure and 3500-psi high pressure. Hold and
chart all tests for 5-minutes. All tests witnessed by BP WSL
and Doyon Tourpusher. AOGCC rep Bob Noble waived
witness of test on 1/28/2009.
05:30 - 06:00 0.50 BOPSU P DECOMP RD Test Equipment. Pull test plug. Set wear ring.
06:00 - 07:30 1.50 CLEAN P DECOMP PU RTTS retrieval tool. MU to std of 4" DP. RIH. Engage and
release 9-5/8" RTTS. POH & UD RTTS. RIH with 3-stds of
4"DP from derrick., Engage and Release RBP.
07:30 - 09:00 1.50 CLEAN P DECOMP CBU ~ 10-BPM with 2060-psi. Loss rate = -15-BPH while
circulating.
09:00 - 09:30 0.50 CLEAN P DECOMP Monitor well. Static. Blow Down Top Drive.
09:30 - 12:00 2.50 CLEAN P DECOMP POH. UD 4"DP from 11350' to 7826'.
12:00 - 19:00 7.00 CLEAN P DECOMP Continue UD 4"DP from 7826' to surface. Loss rate =
-12-BPH while POH.
19:00 - 20:00 1.00 CLEAN P DECOMP UD RBP & Running tool. P/U wear ring puller and pull wear
ring. Clean and clear rig floor.
20:00 - 22:00 2.00 BUNCO RUNCMP PJSM with rig crew, BP WSL & WSLf, Doyon Tourpusher,
Baker Completion Tech, and Doyon Casing Rep on R/U and
run completion. R/U torque turn equipment, compensator,
double stack tongs, and stabbing board. M/U landing jt
assembly. P/U 5-1/2" x 4-1/2" XO assembly and M/U 4' long,
5-1/2" pup jt on top in order to allow derrick hand to reachit
from the stabbing board. UD XO assembly.
22:00 - 00:00 2.00 BUNCO RUNCMP Run with new 4-1/2", 12.6# 13Cr80 Vam Top tubing completion
-
with following tailpipe jewelry: WLEG with "XN" Nipple, iea
4-1/2" Bakerlocked Jt, "X"-Nipple with RHC-M plug, 7" x 4-1/2"
S-3 Packer, 4-1/2" "X" Nipple. Utillize Torque Turn services
and M/U 4-1/2" Vam Top connections to 4440-Ibs/ft of torque.
Bakerlock all connections below packer. Use Jet Lube Seal
Guard on all connections. At 2245-hrs, all tailpipe jewelry RIH.
Continue to RIH with 4-1/2" 12.6# 13cr80 Vam Top tubing.
1/31/2009 00:00 - 06:00 6.00 BUNCO RUNCMP Run 4-1/2" 12.6# 13cr80 Vam Top x 5-1/2" 17# 13cr80 Vam
Top HC Completion. Utilize Torque Turn equipment for each
connection. MU 4-1/2" Vam Top to 4440-ft-Ibs Optimum
torque. MU 5-1/2" Vam Top HC to 6580-ft-Ibs Optimum torque.
Printed: 2/16/2009 11:53:11 AM
•
BP EXPLORATION Page 17 of 18
Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
Date From - To Hours Task Code NPT Phase Description of Operations
1/31/2009 00:00 - 06:00 6.00 BUNCO RUNCMP Use Jet Lube Seal Guard thread compound on all
connections. At 0145-hrs, 45-jts of 4-1/2" 12.6# 13cr80
VamTop tubing RIH. At 0345-hrs, 90-jts of 4-1/2" 12.6# 13cr80
VamTop tubing RIH. At 0530-hrs, RIH with 4-1/2" 12.6#
13cr80 Vam Top x 5-1 /2" 17# 13cr80 Vam Top HC XO. Loss
rate while RIH = -8-BPH.
06:00 - 14:30 8.50 BUNCO RUNCMP Continue RIH with 5- 17# 13Cr80 Vam Top HC tubing to
11,386'.
14:30 - 15:00 0.50 BUNCO RUNCMP Change out elevators to 4". P/U & M/U Hanger and Landing Jt
Assembly. Land Tubing. Cameron Rep RILDS.
15:00 - 16:00 1.00 BUNCO RUNCMP PJSM with rig crew, WSL, Doyon Toolpusher, CH2MHILL,
Baker Tech, and Cameron Rep to Reverse Circulate. Discuss
spill potentials while offloading fluid and volumes of fluids to
reverse circulate. Due to pressure required to set Pkr, decide
to test lines to 4200-psi. Discuss the hazards of high pressure
testing. Designate spill champion. R/U to reverse circulate
120-deg F seawater and Corrosion Inhibitor.
16:00 - 16:15 0.25 BUNCO RUNCMP Pressure test lines to 4,200-psi. Good test.
16:15 - 20:30 4.25 BUNCO RUNCMP Reverse Circulate 225-bbls of 120-degree 8.5-ppg seawater at
3-BPM with 210-psi. Follow with 375-bbls of Corrosion
Inhibited 120-degree 8.5-ppg seawater at 3-BPM with 200-psi.
Took 10-bbls to get returns at beginning of circulation.
20:30 - 22:30 2.00 BUNCO RUNCMP Drop Ball and Rod to set 7" x 4-1/2" Baker Premier Production
Packer. Set packer with 4,200-psi and hold for tubing test.
After 15-min pressure dropped 100-psi. Bleed off pressure to
0- si. Pressure up to 3,500-psi for charted 30-min. Good test.
Bleed Tubin Pressure to 2,500- si. Pressure u and test IA
to 3,500-psi for charted 30-min. Good test. Quickly bleed off
tubing pressure and observe DCR valve shear at 2,200-psi.
Circulate through sheared DCR valve both ways.
22:30 - 00:00 1.50 BUNCO RUNCMP Cameron Tech T-bar in J-Style TWC. Test above TWC to.
3.500-osi for charted 10-min. Good test. Test below TWC to
2/1/2009 00:00 - 00:30 0.50 BOPSU P RUNCMP Blow down all lines. Drain BOP stack in preparation for ND.
00:30 - 02:00 1.50 BOPSU P RUNCMP Pull Riser. ND BOP stack. Barriers in place for N/D BOP's 1)
Ball & Rod on seat with kill wt fluid in the well bore. 2) TWC
set inside tbg hanger then test above and below.
02:00 - 04:00 2.00 WHSUR P RUNCMP NU new 13-5/8" x 7-1/16" Adapter flange.
04:00 - 05:00 1.00 WHSUR P RUNCMP Cameron wellhead tech RU and test Adapter flange & Tubing
hanger to 5000-psi for 30-minutes. Good test.
05:00 - 06:00 1.00 WHSUR P RUNCMP NU new 7-1/16" 5000-psi Production Tree with 6-3/8" bore. Fill
tree with diesel and test to 5000-psi for 10-minutes. Good test.
09:00 - 10:00 1.00 WHSUR P RUNCMP PU DSM lubricator and pressure test to 500-psi. Pull TWC.
10:00 - 12:00 2.00 WHSUR P RUNCMP Hold PJSM on pumping diesel freeze protection. RU Little Red
Services. Pressure test all lines to 3500-psi. Good Test. Little
Red Services reverse circulate in 150-bbls of diesel freeze
protection at 2-BPM with 200-psi
12:00 - 12:30 0.50 WHSUR P RUNCMP Continue to reverse in diesel freeze protection at 2-BPM with
500-psi.
12:30 - 13:30 1.00 WHSUR P RUNCMP Tie in Annulus and tubing. Allow diesel to U-tube.
13:30 - 15:30 2.00 WHSUR P RUNCMP Wait for DSM to arrive to set BPV. Prep throughout rig for
upcoming move.
Printed: 2/16/2009 11:53:17 AM
•
BP EXPLORATION Page 18 of 18
Operations Summary Report
Legal Well Name: 11-09A
Common Well Name: 11-09A Spud Date:
Event Name: WORKOVER Start: 1/12/2009 End:
Contractor Name: DOYON DRILLING INC. Rig Release: 2/1/2009
Rig Name: DOYON 16 Rig Number:
Date From - To Hours Task Code NPT Phase Description of Operations
2/1/2009 15:30 - 16:00 0.50 WHSUR P RUNCMP PU DSM lubricator and ressure test to 500- si usin diesel.
Set BPV. LD lubricator.
16:00 - 17:00 1.00 WHSUR P RUNCMP Test BPV from below to 1000-psi for 10-charted minutes using
Little Red Services.
17:00 - 17:30 0.50 WHSUR P RUNCMP Blow down all circulating lines and Mud Pump #1. RD Little
Red Services.
17:30 - 18:00 0.50 WHSUR P RUNCMP Remove double annulus valve on IA. Install all gauges on tree.
Ensure no pressure on IA or OA. Secure Well. Rig Released
at 1800-hrs.
Printed: 2/16/2009 11:53:11 AM
TREE =r CIW
WELLHEAD = GRAY
ACTUATOR = AXELSON
KB. ELEV..- _. 58'
BF. ELEV...- __
KOP = 2099'
Max Angle = 94` @ 12426'
Datum MD = 11970'
Datum TVD = 8800' SS
~ _ 11-0 9 A #* HRH T~ ~W ELL ANCO~E >74° ~a 11581'
13-3/8" CSG, 72#, L-80, ID = 12.347" i"'i 2507'
5-1e`2"' TBG, 17#, 13CR-80 VAM TOP HC, 6286'
.0232 bpf. ID = 4.892"
TOP OF7"LNR-SCAB 6354'
7" LNR -SCAB, 29#, L-80, .0371 bpf, ID = 6.184" 6709'
--
TOP OF 7" LNR 6709'
9-5/8" CSG, 47#, L-80, ID = 8.681" 6826'
rni iQ = 3.725 11402'
-1 t2" Ni PLE
~ ¢sv BP ~.-~ 7093' ~--~~
4-112" TBG, 12.6#: 13CR-80 VAM TOP HC, .0152 bpf, ID = 3.958"' 11415°
TOP OF 4-1 /2" LNR 11648'
7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~~ 11790'
PERFORATION SUMMARY
REF LOG: ?
ANGLE AT TOPPERF: 90° @ 11800'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE
2-3/4" 4 11800 - 11996 C 09/10/96
2-3/4" 4 12010 - 12080 C 09/10/96
2-3/4" 4 12140 - 12268 C 09/10/96
2-3/4" 4 12405 - 12680 C 09/10/96
2-3/4" 4 12700 - 12810 C 09/10/96
2-3/4" 4 12865 - 13237 C 09/10/96
2198' S-112" C-{ES X NIP, iD = 4.562"
GAS C_CF7 MANDRELS
ST MD ND DEV TYPE VLV LATCH PORT DATE
3 3592 3273 55 MMG OM RK 16 02~12l09
2 6689 4966 61 KBG SO BK 20 02112j09
1 8403 6203 37 KBG DMY BK 0 01131/09
6286' S-1l2" X 4-112°' XO, ID = 3.958"
MILLOUT WINDOW 6826' - 6876'
11271' 4-112° ICES X N1P, ID = 3.813
11292` 7" X 4-112" BKR PREM PKR, ID = 3.870
11330' 4-112" HES X N(P, ID = 3.813„
11402' 4-112" HES XN NIP, CD = 3.725"
11415` 4-112" WLEG, 1D = 3.958„
12299, ~~4-1/2" TNV MLAS- I
CV (12299' - 12327')
PBTD H 13238'
4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" f-J 13329'
DATE REV BY COMMENTS DATE REV BY COMMENTS
1985 ORIGINAL COMPLETION
09111196 N2ES SIDETRACK 11-09A
02101109 D16 RWO & FCO (11-09A}
0203109 PJC DRLG DRAFT UPDATES
02/16/09 SWC/SV GLV C/O (02/12/09)
PRUDHOE BAY UNIT
WELL: 11-09A
PERMIT No: 1961280
API No: 50-029-21402-01
SEC 28, T11N, R15E, 1159' FSL & 377' FEL
BP Exploration (Alaska)
SELL, ~
<<
_ _ _ ~~.
ProActive Diagnostic Services, Inc.
To: AOGCC
Christine Mahnken
333 W. 7th Ave
Suite 100
Anchorage, Alaska 99501
(907) 793-1225
RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by returning
a signed copy of this transmittal letter to the following
BP Exploration (Alaska], Inc.
Petrotechnical Data Center
Attn: Joe Lastufka
LR2-1
900 Benson Blvd.
Anchorage, Alaska 99508
and
9 '~~I t ~
ProActive Diagnostic Services, Inc.
Attn: Robert A. Richey
130 West International Airport Road
Suite C
Anchorage, AK 99518 ~ ~ ~`~3~ ~~.:" ~~~"" ~' ~~~'
Fax: (907] 245-8952
1) Coil Flag 02-Jan-09 (run 1) 11-09A EDE 50-029-21402-01
2) Coil Flag 07zJan-09 (run 2) 11-09A EDE 50-0.29-21402-01
„~
,~ _,t
-~, ~
Signed . ~' ~ Date : _~'ar~,=~, ~l. ~'`~_
Print Name: -,. ..
PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 89518
PHONE: (907)245-8951 FAX: X9071245-88952
E-MAIL : pclsas~chor~cgeC~snerncartrloU.corra WEBSITE : www.rraen~c~s°yl~sa.e:o~r'
C:\Documents and Settings\Ownet\Dasktop\Transmit_BP.docx
~'~
<II. (STATE OF ALASKA (
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed:
AbandonD SuspendD Operation Shutdown 0 Perforate D WaiverD OtherD
Alter CasingD Repair WellD Plug PerforationsŒ] Stimulate D Time ExtensionO
Change Approved ProgramD Pull TubingD Perforate New Pool 0 Re-enter Suspended Well 0
2. Operator 4. Current Well Class: 5. Permit to Drill Number:
Name: BP Exploration (Alaska), Inc. 196-1280
Development ŒJ Exploratory 0
3. Address: P.O. Box 196612 6. API Number
Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-21402-01-00
7. KB Elevation (ft): 9. Well Name and Number:
57.10 11-09A
8. Property Designation: 10. Field/Pool(s):
ADL-0028322 Prudhoe Bay Field / Prudhoe Oil Pool
11. Present Well Condition Summary:
Total Depth measured 13329 feet
true vertical 8717.3 feet Plugs (measured) None
Effective Depth measured 11100 feet Junk (measured) 11258
true vertical 8369.0 feet
Casing Length Size MD TVD Burst Collapse
Conductor 80 20" 91.5# H-40 33 - 113 33.0 - 113.0 1490 470
Liner 5436 7" 29# L-80 6354 - 11790 4794.3 - 8733.9 8160 7020
Liner 1681 4-1/2" 12.6# L-80 11648 - 13329 8710.8 - 8717.3 8430 7500
Production 6795 9-5/8" 47# L-80 31 - 6826 31.0 - 5031.7 6870 4760
Surface 2475 13-3/8" 72# L-80 32 - 2507 32.0 - 2481.8 4930 2670
Perforation depth:
Measured depth:
True vertical depth: RECE\VEO
Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 29 - 11372 JAN 2 1 2004
2-7/8" 6.5# L-80 @ 11253 - 11269 . \0\'\
Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 11327 O.~ & Gas Cons. Comm\SS
4-1/2" Eclipse Patch Packer @ 11253 A\aska' p. hQf3ge
4-1/2" Eclipse Patch Packer @ 11263 t'\"t
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13 Representative Dailv Averaae Production or Iniection Data
Oil-Bbl I Gas-Mef Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 814 I 18.9 2666 2000 1672
Subsequent to operation: Well Shut-In 2200 Vacuum
14. Attachments: 15. Well Class after proposed work:
ExploratoryD DevelopmentŒ] ServiceD
Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D
OilŒ] GasD WAG 0 GINJD WINJD WDSPLD
Daily Report of Well Operations. ~ Prepared by Garry Catron (907) 564-4657.
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
Contact Garry Catron N/A
Printed Name Garry Catron ¡ (!; ~ 2004 Title Production Technical Assistant
Signature . C~ Phone 564-4657 Date 1/20/04
Form 10-404 Revised 12/2003 r C; I N A L - Bfl JAN 2 2 200~
. ( (
11-09A
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
EVENT SUMMARY
09/09/03 T/I/O = 1120/2100/300, TEMP = S/I. IA FL FOR COIL. IA FL BELOW SCAB LINER TOP AT
63541.
09/09/03 CONTINUED FROM WSR OF 9/8/03. TAG HYDRATE PLUG AT 1525 CTMD. WASH AND
JET THROUGH ICE TO 27001. RIH TO 5000'
POH, LOAD TBG WITH 1.5 VOL 1 % KCL. BLEED IA TO 1600 PSI. LOAD IA WITH 1 % KCL,
SO/BLEED IA FROM 2600 TO 1600. ON LINE LOAD IA. PUMP DOWN TUBING.
INJECTIVITY AT 2 B/M IS 1927 AND RISING. IAP-2350. SO MONITOR AND BURP GAS
FROM IA AND TUBING. JOB IN PROGRESS.
09/10/03 Bled lAP. Circulated KCL down well taking returns up IA. Circulated until fluid packed (800
bbls). Shut in returns and checked injectivity. Final injectivity = 3.0 bpm @ 1640 psig WHP.
Inject 135 bbls crude down IA to freeze protect. Static WHP = 0 psi, lAP = 200 psi. Re-check
injectivity= 2.75 bpm @ 1950 psi WHP. RIH and tag w/3" nozzle at 112721 ctmd. Mix up and
pump 6400# of 20/40 sand with 1600# of 100 mesh (33 bbls slurry). Start building WHP with
6 bbls slurry out nozzle. Start PUH and lay in remainder of slurry.
09/11/03 T/I/O = VACNAC/120. TBG AND IA FL1S. (FOR SECURE). TBG AND IA FL1S NEAR
SURFACE.
09/11/03 Sand plug set @ 11100'-11800'
FLUIDS PUMPED
BBLS
417 50/50 Methanal
134 Crude
37 20/40 Sand & 100 Mesh Slurry
7 40# Gel
1485 1 % KCL
2080 TOTAL
Page 1
( (.
. ',~ ~
TREE = GRA Y GEN 3
WELLHEAD = GRAY 11 0 9A SAFETY NOTES: 70° @ 11581' AND 90° @
ACfUð. TOR = AXELSON - 11803'
KB. a.EV = 57'
BF. ELEV =
KOP = 2099'
Max Angle = 94 @ 12426' &\ 4-1/2" CAMCO BAL-O SSSV NIP D = 3812"
DatumMD= 11970' ., , .
Datum TVD = 8800' SS
GA S LlFf fvVU'ÐRELS
ST W TVD DEV TYPE VLV LATCH FORT DATE
13-3/8" CSG, 72#, L-80, D = 12.347" 1 4108 3558 59 CA-KBG INTGR..
2 7595 5567 51 CA-KBG INTGR..
Minimum ID = 2.441 @ 11253' 3 9483 7064 47 CA-KBG INTGR..
4 11258 8494 53 CA-KBG INTGR..
4-1/2" AVA DWP TBG PATCH
TOP OF 7" LNR - SCAB MLLOUTWNDOW 6826' - 6876'
TOPOF SAND (09/11103)
9-5/8" CSG, 47#, L-80, ID= 8.681" 4-1/2" AVA ONPRETRTBG PATŒf SET 10/31/96
BTM HALF OF BROKEN OGLV DRIVEN AR=>ROX
7" INTO POCKET OF GLM #4 - SET 09/24196
-i 7" X 4-1/2" BAKER 5-3 PKR I
11350' -I 4-1/2" I-ESX NIP, D = 3.812" I
7093' 11372' 4-1/2" TLBING TAIL
I I~ a.rvo TT NOT LOGGID I
4-1/2" lBG, 12.6#, L-80, .0152 bpf, ID = 3.958"
-i FB SA NDBA CK (05/13/02) I
7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11790'
12299' 4-1/2" TIW MLA 5-
CV (12299' - 12327')
ÆRFORA llON SLMMARY
REF LOG: ?
ANGLE AT TOP PERF: 90 @ 11800'
Note: Refer to Production DB for historical perf data
SIZE SPF INTffiV AL Opn/Sqz DATE
2-3/4" 4 11800 - 11996 C 09/10/96
2-3/4" 4 12010- 12080 C 09/10/96
2-3/4" 4 12140 - 12268 C 09/10/96
2-3/4" 4 12405 - 12680 C 09/10/96
2-3/4" 4 12700 - 12810 C 09/10/96 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958"
2-3/4" 4 12865 - 13237 C 09/10/96
DA TE REV BY COMrvENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT
1985 ORIGINAL COMPLETION Wa.L: 11-09A
09/13/96 LAST WORKOVERlSDTRKD ÆRMT f\b: 1961280
02107/02 RNITP CORRECllONS API f\b: 50-029-21402-01
05/17/03 KLC/lLH PffiF CORREeTONS SEe 28, T11 N, R15E. 3288.57' FEL & 2144.32' FN...
09/11/03 JA FA<K SAND DUMP
8P Exploration (Alaska)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown_ Stimulate _ Plugging_ Perforate_
SAND PLUG Pull tubing _ Alter casing_ Repair well _ Other_X SAND PLUG
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet)
BP Exploration (Alaska), Inc. Development__X RKB 57 feet
3. Address Exploratow___ 7. Unit or Property name
P. O. Box 196612 Stratigraphic__
Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit
4. Location of well at surface 8. Well number
4125' FNL, 377' FEL, Sec. 28, T11 N, R15E, UM (asp's 707142, 5952869) 11-09A
At top of productive interval 9. Permit number / approval number
3200' FNL, 4980' FEL, Sec. 22, T11 N, R15E, UM (asp's 707634, 5959090) "., 196-128
At effective depth 10. APl number
2180' FNL, 3375' FEL, Sec. 22, T11N, R15E, UM (asp's 709208, 5960153) 50-029-21402-01
At total depth 11. Field / Pool
2146' FNL, 3291' FEL, Sec. 22, T11N, R15E, UM (asp's 709291, 5960190) Prudhoe Bay Field / Prudhoe Bay Pool
12. Present well condition summary
Total depth: measured 13329 feet Plugs (measured) Sand Plug pumped (05-13-2002)
true vertical 8718 feet
Effective depth: measured 13238 feet Junk (measured) BTM Half of Broken OGLV Driven Approx 7" into
true vertical 8717 feet Pocket of GLM#4 @ 11258' (09/24/1996)
Casing Length Size Cemented Measured Depth True Vertical Depth
Conductor 110' 20" 2000# Poleset 140' 140'
Surface 2477' 13-3/8" 291 sx CS III, 3000 sx 2507' 2482'
CS Ill, 600 sx Class 'G'
Intermediate 6796' 9-5/8" 354 sx CS I, 700 sx 'G' 6826' 5032'
Liner 5436' 7" 387 sx Class 'G' 6354' - 11790' 4794' - 8734'
Sidetrack Liner 1681' 4-1/2" 25 bbls Class 'G' 11648' - 13329' 8711' - 8717'
Perforation depth: measured Open Perfs 11800'-11996', 12010'-12080', 12140'-12268', 12405'-12680', 12700'-12810',
12865'-13237'
true vertical Open Perfs 8734'-8733', 8733'-8733', 8733'-8732', 8725'-8716', 8716'-8717', 8718'-8717'
Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, TBG @ 11327' MD. 4-1/2" 12.6# L-80, Tubing Tail @ 11372'.
4-1/2" AVA DWP RETR TBG PATCH SET @ 11253' (10/31/1~9~6)-~ ? .... ~;"~ l ~ ,~ !.~i ~""~i
Packers & SSSV (type & measured depth) 7" x 4-1/2" BKR S-3 PKR @ 11327'. ;':'~"~. i~i
4-1/2" Camco BAL-O SSSV Nipple @ 2211' MD.
13. Stimulation or cement squeeze summary ..~U
Intervals treated (measured) (see attached)
Treatment description including volumes used and final pressure ~.SI(~,. ~J] '~",
14. Representative Daily Averaqe Production or Iniection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation Shut-In
Subsequent to operation Shut-In
15. Attachments 16. Status of well classification as:
Copies of Logs and Surveys run __
Daily Report of Well Operations __Oil ('~ Gas __ Suspended _ Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
8CANNED JUL 3 O'at 31 2002
Title: Technical Assistant 1
DeWayne R. Schnorr ~ Prepared by DeWayne R. Schnorr 564-5174
Form 10-404 Rev 06/15/88 ·
SUBMIT IN DUPLICATE
12/01/2001
12/O2/2OO 1
1 2/O8/2OO2
1 2/1 2/2OO2
04/26/2002
05/13/2002
05/16/2OO2
12/O 1/O2
12/02/02
12/08/O2
12/12/O2
O4/26~O2
05/13/O2
05/16/O2
11.-09A
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
ANN-COMM: CALCIUM CARBONATE WELL KILL
ANN-COMM: MONITOR LOAD & KILL
ANN-COMM: SECURE TROUBLE WELL
ANN-COMM: BLEED TBG - SECURE WELL
ANN-COMM: AC-EVAL
SAND PLUG: SAND PLUG
SAND PLUG: AC-MONITOR
EVENT SUMMARY
LOADED IA WITH 9.6 PPG NACL BRINE CAPPED WITH 100' OF DIESEL.
PUMPED A FULLBORE 40 BBL, 40 PPB SIZED CALCIUM CARBONATE PILL WITH
16 BBLS OF IT BEHIND PIPE. ESTIMATE TOP OF PILL WAS LEFT AT 11648' (2
BBLS ABOVE PERFS). 9.6 PPG NACL STACKED ON TOP TO NEAR SURFACE
WITH 200' DIESEL CAP. DID NOT BRIDGE PERFS ENOUGH TO BUILD WHP FOR
LOCKUP. SECURED WELL, CALL OUT FOR TBG/IA FLUID LEVEL MONITORING.
TIO = 210/1100/380. TBG FL @ 2111', IA FL @ 5460'.
LOAD & SECURE WELL. PUMP 340 BBL 9.6# INHIB BRINE. CAP W/DIESEL.
PUMP 50 BBL 50# SIZED CACO3 PILL DOWN TUBING DISPLACE W/165 BBL 9.6
BRINE. LEFT I BBL ON CACO3 PILL ABOVE PERFS. INCREASED PRESSURE
100 PSI FINAL 514 PSI. PRESSURE HOLDING FLAT. TURN OVER TO DHD FOR
FUTURE ANALYSIS.
T/I/O = 160/900/350 INITIAL TBG FL @ SURFACE. INITIAL IA FL @ 4760' (255
bbls). BLED TBG FROM 160 PSI to 50 PSI. FINAL WHP's 50/900/350.
T/I/O = 2160/2200/350 MONITOR WHP's--(CHECK A SECURED WELL). TBG FL @
9582', IA FL @ 9584'. FLOWLINE AND AL LINE ARE NOT IN SERVICE AND ARE
DISCONNECTED.
FLUID PACKED IA AND TBG WITH SEAWATER. INITIAL INJECTIVITY AFTER
FLUID PACK ==> 7 BPM @ 1850 PSI. FULLBORED 17,500# OF 20x40 RIVER
SAND INTO 4-1/2" LINER IN 2 STAGES. FINAL INJECTIVITY ==> 1 BPM @ 2200
PSI. FP'D IA WITH 200 BBLS DIESEL. DSM TO RIG JUMPER LINE FROM IA TO
TBG TO FP TBG.
T/I/O = 40/40/300 MONITOR WHP's POST FB SANDBACK TO SECURE. TBG FL
AT 1000' (15 BBLS). IA FL AT 480' (20 BBLS).
$6ANNED JUL $1 2002
Page I
11-09A
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
Fluids Pumped
BBLS
0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL (
0 TEST)
15 METHANOL
10 METHANOL-NEAT
23O DIESEL
332 SEAWATER
693 INHIBITED SEAWATER
580 9.6 PPG BRINE
570 9.6 PPG BRINE W/CL
30 HIGH VIS BRINE
40 HIGH VIS PILL
40 35 PPB CACO3
50 10.6 PPG 50# SIZED CACO3 PILL
66 SAND SLURRY (17,000# 20x40 RIVER SAND, 500# SILICA FLOUR)
22 CLEAN 40 PPT GEL
2678 TOTAL
JUL 3 200
Page 2
PERMIT DATA
AOGCC Individual Well
Geological Materials Inventory
T DATA PLUS
Page: 1
Date: 08/12/98
RUN RECVD
96-128 CCL
96-128 DIR SRVY
96-128 SSV/D
96-128 LDT/CN
96-128 PIL
96-128 BHC/SL
96-128 CN
96 - 128 BHP
96-128 7170
96-128 NGP-TVD
96-128 NGP-MD
96-128 7932
96-128 RST
96-128 DEFT
96-128 RST SIGMA/B
96-128 RST P~LAS VEL
96-128
020-10172 '
cl:r~o oo o- 11718
¢~~0000-117~3
~DT/CNTG/SDT
~/5677- 8715
7737-13329
.
~'~~-~4,6,7 SPERRY Ge
I~1400-13200
~11400-13200
11400-13200
PROD/INJP-SPIN/ ;~//TEM/PRES 11400-13200
FINAL 09/06/96
1 09/16/96
FINAL 10/11/96
FINAL 10/11/96
FINAL 10/11/96
FINAL 10/11/96
FINAL 10/11/96
FINAL 10/11/96
10/11/96
FINAL 02/19/97
FINAL 02/19/97
03/26/97
FINAL 12/23/97
FINAL 12/23/97
FINAL 12/23/97
FINAL 12/23/97
FINAL 12/23/97
10-407 ~COMPLETION DATE ~/~t / ~,~
DAILY WELL OPS R ~ //~ / ~ / TO ~/?~. / ~/
Are dry ditch samples required? yes ~d received?
Was the well cored? yes ~__~Analysis & description received?
Are well tests required?l, ,!yes ?~no~2 Received? ~
Well is in compliance ~0
In~tial
COMMENTS
3//? /
ye's~
GeoQuest
500 W. International Airport Road
Anchorage, AK 99518-1199
ATTN: SherrJe
NO. 11668
Company:
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
12/23/97
Field: Prudhoe Bay
Floppy
Well Job # Log Description Date BL RF Sepia Disk
LIS
Tape
D.S. 11-09A PROD. & INJECTION PROFILE LOG 9711 1 8 I 1
D.S. 11-09A DIGITAL FLUID IMAGING LOG DEFT 9 7111 8 I 1
D.S. 11-09A RST SIGMA LOG 971 1 1 8 I 1
D.S. 11-09A RST WATER FLOW 97111 8 I 1
D.S. 11-09A RST PHASED VELOCITY 971 1 1 8 1 I
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521.
0 F! ! I--I-- ! r~J I~ SE F:I~./I C E S
WELL LOG TRANSMITTAL
To: State of Alaska March 26, 1997
Alaska Oil and Gas Conservation Comm.
Attn.: Loft Taylor
3001 Porcupine Dr. ~"'
Anchorage, Alaska 99501
MWD Formation Evaluation Logs - D.S. 11-09A,
RE: AK-MW-60111
The technical data limed below is being submitted herewith. Please acknowledge receipt by returning a
signed copy of this transmittal letter to the attention off
Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518
1 LDWG formatted Disc with verification listing.
API#: 50-029-21402-01.
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc. Company
spemmy-sur,
WELL LOG TRANSM1TFAL
To: State of Alaska February 19, 1997
Alaska Oil and Gas Conservation Comm. \.~"t~
Attn.' Loft Taylor
3001 Porcupine Dr. F2k32
Anchorage, Alaska 99501
RE: MWD Formation Evaluation Logs DS 11-09A, AK-MW-60111
The technical data listed below is being submitted herewith. Please address any problems or concems
to the attention of.'
Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, t/G, Anchorage, AK 99518
DS ll-09A:
2" x 5"MD Gamma Ray Logs:
50-029-21402-01
2" x 5" TVD Gamma Ray Logs:
50-029-21402-01
1 Blueline
1 Folded Sepia
1 Blueline
1 Folded Sepia
i'%-'!- ...... -' ... . · ~
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc. Company
GeoQuest
500 W. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrie
NO. 10704
Company:
Field:
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Prudhoe Bay (Cased Hole)
1/16/97
Well Job # Log Description Date BL RF Sepia LIS Tape
A-43 LEAK DETECTION 9 61 2 21 I 1
B- 19 PRODUCTION PROFILE 9 61 2 2 3 1 1
C-29 ORIENTED WHIPSTOCK 9 61 2 0 3 I 1
D- 1 LEAK DETECTION 9 61 2 0 4 1 1
D-3 LEAK DETECTION 961 21 4 I 1
.,,
D-23 BAKER WHIPSTOCK 9 61 2 0 4 I 1
GC-3D INJECTION PROFILE 9 61 21 9 I 1
H- 0 8 PRODUCTION PROFILE 9 61 2 2 4 I 1
H- 1 5 PERFORATING RECORD 9 61 2 21 I 1
H-25 PERFORATING RECORD 9 61 221 I 1
J-03 PERFORATING RECORD 9 61 2 2 6 I 1
M-4 PRODUCTION PROFILE 9 61 21 5 I 1
N-20 GAMMA RAY/CCL 961 21 7 1 1
N-21 JET CLFFI'ER RECORD 9 61 2 2 8 I 1
R-18A PRODUCTION PROFILE W/DEFT 9 61 2 0 5 1 1
S- 16 PERFORATING RECORD 9 61 2 2 0 I 1
S- 33 PRODUCTION LOG 9 61 2 2 7 1 1
X-19B MULTI-LATERAL PRODUCTION PROFILE 9 61 2 0 9 I 1
Y-01 CHEMICAL CUTTER 9 61 2 2 3 I 1
Z-20 (21-20-11-12) TEMPERATURE LOG 9 61 21 3 1 I
Lp~ · / ~1
70 .o0~
77 ' 0?-5
7~ ·
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc.
Petrotectnical Data Center MB3-3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
Date Delivered:
Schlumberger GeoQuest
500 W. International Airport Road
Anchorage, Alaska 99618-1199
STATE OF ALASKA
ALASKA._ ,L AND GAS CONSERVATION CO,,,MISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed:
Operation shutdown Stimulate Plugging Pedorate
Pulltubing ~ Alter casing ~ Repair well Other X
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P.O. Box 100360, Anchorage, AK 99510-0360
4. Location of well at surface
1155' NSL, 377' WEL, Sec 28, T11N, R15E, UM
At top of productive interval
2080' NSL, 300' EWL, Sec 22, T11N, R15E, UM
At effective depth
At total depth
3134' NSL, 1973' EWL, Sec 22, T11 N, R15E, UM.
5. Type of Well
Development
Exploratory
Stratigraphic
Service
X
6. Datum of elevation(DF or KB)
57 RKB feet
7. Unit or Property
Prudhoe Bay Unit
8. Well number
11-09A
9. Permit number/approval number
96-147 ~ ~ ~ '--
10. APl number
50 - 029-21402-01
11. Field/Pool
Prudhoe Bay Oil Pool
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
Casing Length
Conductor 11 O'
Surface 2449'
Intermediate 6772"
Liner 5436'
Liner 1681'
13329 feet Plugs(measured)
8718 feet
13328 feet
8717 feet Junk(measured)
Size Cemented Measured depth True vertical depth
20" 2000# Poleset 110' 110'
13-3/8" 2500 Sx PF 'E' & 500 Sx PF 'C' 2507' 2507'
9-5/8" 600 Sx Class G 6826' 5033'
7" 300 Sx Class G 6354 - 11790' 8734'
4-1/2" 220 Sx Class G 11648 - 13329' 8718'
Perforation depth:
measured 11800- 11996'; 12010- 12080'; 12140- 12268'; 12405- 12680'; 12700- 12810';
12865 - 13237'
true vertical 8734 - 8733'; 8733 - 8733'; 8733 - 8732'; 8725 - 8716'; 8716 - 8717'; 8718 - 8717'
Tubing (size, grade, and measured depth) 4-1/2", 12.6#, Tbg @ 11372' MD.
Packers and SSSV (type and measured depth) Baker S-3 Packer @ 11327' MD; 4-1/2", Camco BaI-O SSSV @ 2211' MD
13. Stimulation or cement squeeze summary
Intervals treated(measured) see Attached
Treatment description including volumes used and final pressure
RECEIVED
DEC,.. 03 ]'395
14.
Prior to well operation
Subsequent to operation
Representative Daily Averaqe Production or Injection Data · ·
OiI-Bbl Gas-Mcf Water-Bbl ua~f~j,~,~ess UT~rtch0 r..,l¢ou p in g ~'ressure
9367 7962 270 -- 290
9988 13414 460 -- 331
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations
16. Status of well classification as:
Oil ~ Gas Suspended
Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed ~¢¢,~~ ~'~. ~ Title Engineering Supervisor
Form 10-404 Rev 06/15/88
Date //-/O6- ~
SUBMIT IN DUPLICATE~-~%
11-09A
TUBING PATCH INSTALLATION
DESCRIPTION OF WORK COMPLETED
10/30/96'
RIH & set a 4-1/2" AVA DWP Retrievable Tubing Patch at 11253.5 - 11268.5' MD (seal to seal),
over GLM #4. POOH w/running tool. Rigged down.
Returned the well to production & obtained a valid welltest.
RECEIVED
DEC 0 5 ~09S
Alaska Oil & ~as Cons, C~mmis,,~iot~
Anchorage
STATE OF ALASKA
ALASKA O,L AND GAS CONSERVATION COMiw,SSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
[] Oil [] Gas [] Suspended [] Abandoned [] Service
,
2. Name of Operator 7. Permit Number
ARCO Alaska Inc. 96-128 96-174
3. Address 8. APl Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21402-01
.................. ~ ~ 9. Unit or Lease Name
4. Location of well at surface
I . .. .... Prudhoe Bay Unit
1155' NSL, 377' WEL, SEC. 28, T11N, R15E
At top of productive interval
3134' NSL, 1973' EWL, SEC. 22, TllN, R15E ·
................. ~ / Prudhoe Bay Field / Prudhoe Bay
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool
KBE = 57.10I ADL 028322
12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., or Aband]15. Water depth, if offshore . 16. No. of Completions
08/22/96 09/05/96 09/11/96 N/A MSLI One
17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~21. Thickness of Permafrosl
13329 8718 F~ 13238 8717 FT~ []Yes •No I (Nipple) 2211' MD} 1900' (Approx.)
22. Type Electric or Other Logs Run
MWD, GR, DIR, RES, NEU, DEN
23. CASING, LINER AND CEMENTING RECORD
CASING SE'I-rING DEPTH HOLE
SIZE VVT. PER ET. GRADE TOP BO'I-I'OM SIZE CEMENTING RECORD AMOUNT PULLED
20" 91.5# H-40 Surface 110' 30" 2000# Poleset
13-3/8" 68# / 72# K-55 / L-80 Surface 2507' 17-1/2" 2500 sx PF 'E', 400 sx PF 'C', 100 sx PF 'C'
9-5/8" 47# L-80 Surface 6826' 12-1/4" 600 sx Class 'G'
7" 29# L-80 6354' 11790' 8-1/2" 300 sx Class 'G'
4-1/2" 12.6# L-80 11648' 13329' 6" 220 sx Class 'G'
24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD
and interval, size and number). SiZE DEPTH SET (MD) PACKER SET (MD)
2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 11372' 1 1327'
MD TVD MD TVD
11800' - 11996' 8734' - 8733'
12010' - 12080' 8733' - 8733' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC.
12140' - 12268' 8733' - 8732'
12405' - 12680' 8725' - 8716' DEPTH INTERVAL (MD) AMOUNT & K~ND OF MATERIAL USED
12700' - 12810' 8716' - 8717' Freeze Protect with 137 Bbls of Diesel
12865' - 13237' 8718' - 8717'
27. PRODUCTION TEST
Date First Production IMethod of Operation (Flowing, gas lift, etc.)
October 13, 1996 I Gas Lift
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO
TEST PERIOD I~
I
Flow Tubing Casing PressureCALCULATED ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORE)
Press. 24-HouR RATE
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
~.-) :~*~(~ ~ J. '~.,
Form 10-407 Rev. 07-01-80 Submit In Duplicate
'~- Geologic Markers. 30. F~,rmation Tests
Measured True Vertical Include interval tested, pressure data, all fluids recovered
Marker Name Depth Depth and gravity, GOR, and time of each phase.
Top of Sadlerochit 11108' 8376'
Zone 3 11202' 8451'
Zone 2 11272' 8506'
Zone 2B 11330' 8550'
Zone 2A 11444' 8626'
Zone I 11572' 8687'
31. List of Attachments
Summary of Daily Drilling Reports, Surveys
32. I hereby certify that/th~ fore--nd correct to the best of my knowledge
Signed
ganSto~ /~'/',~* .-.,,,~-'~C-~.~C:~ Title Senior Drilling Engineer Date // /,--- ~ -- ~',~.
Prepared By Name/Number: Terrie Hubble, 564-4628
INSTRUCTIONS
GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and
leases in Alaska.
ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water
supply for injection, . observation, injection for in-situ combustion.
.
ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given ~n other spaces
on this form and in any attachments.
ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item
16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional
interval to be separately produced, showing the data pertinent to such interval.
ITEM 21: Indicate whether from ground level (Gl) or other elevation (DF, KB, etc.).
ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of
the cementing tool.
ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In,
Other-explain.
ITEM 28: If no cores taken, indicate 'none'.
Form 10-407 Rev. 07-01-80
SUMMARY OF DALLY OPERATIONS
SHARED SERVICES DRILLING - BPX ! ARCO
WelIName: 11-09A Rig Name: Nabors 2ES AFE: 4J0327
Accept Date: 08/1 5/96 Spud Date: 08/22/96 Release Date: 09/1 1/96
Aug 16 1996 (5)
Rig moved 100 %. Removed Hanger plug. Circulated at 4880 ft. Installed Hanger
plug. Removed Xmas tree. Rigged up All functions. Tested All functions. Removed
Hanger plug. Made up BHA no. 1 .
Aug 17 1996 (6)
Fished at 24 ft. Circulated at 4480 ft. Laid down fish. Installed Bore protector.
Made up BHA no. 2. Singled in drill pipe to 4800 ft. Serviced Block line, Fished at
4878 ft. Circulated at 4878 ft. Pulled out of hole to 0 ft. Laid down fish,
Aug 18 1996 (7)
Laid down fish. Made up BHA no. 3. R.I.H. to 7000 ft. Fished at 7007 ft. Pulled out
of hole to 0 ft. Laid down fish. Made up BHA no. 4. R.I.H. to 7055 ft. Rigged up
Logging/braided cable equipment. Fished at 7055 ft. Rigged down Logging/braided
cable equipment. Fished at 7055 ft. Pulled out of hole to 0 ft. Laid down fish. Conduct
braided cable operations - 3/16 size cable.
Aug 19 1996 (8)
Made up BHA no. 5. R.I.H. to 10020 ft. Cut Tubing at 10020 ft. Pulled out of hole to
75 ft. Pulled BHA. -Made up BHA no. 6. R.I.H. to 5000 ft. Serviced Block line. R.I.H.
to 7100 ft. Fished at 7100 ft.
Aug 20 1996 (9)
Fished at 7100 ft. Pulled out of hole to 0 ft. Pulled BHA. Ran Drillpipe in stands to
3000 ft. Laid down 3000 ft of Drillpipe. Made up BHA no. 7. R.I.H. to 7093 ft. Set
Bridge plug at 7093 ft with 0 psi. Tested Casing - Via annulus and string. Circulated
at 7093 ft. Pulled out of hole to 0 ft. Pulled BHA. Made up BHA no. 8. R.I.H. to 6825
ft. Milled Casing at 6826 ft.
Aug 21 1996 (10)
Milled Casing at 6876 ft. Circulated at 6876 ft. Pulled out of hole to 682 ft. Pulled
BHA. Made up BHA no. 9. R.I.H. to 6821 ft. Washed to 6976 ft. Circulated at 69'76 ft.
Operations Summary for: 11-0f~,.
Aug 22 1996 (11)
Circulated at 6976 ft. Displaced slurry - 58 bbl. Held 800 psi pressure on 6 bbl
squeezed cement. Pulled Drillpipe in stands to 600 ft. Held safety meeting. Pulled
Drillpipe in Stands to 0 ft. Tested BOP stack. Made up BHA no. 10. R.I.H. to 5125 ft.
Serviced Block line. R.I.H. to 6339 ft. Washed to 6415 ft. Drilled cement to 6602 ft.
Held safety meeting. Drilled cement to 6829 ft. Circulated at 6829 ft. Drilled to 6829 ft.
Aug 23 1996 (12)
Drilled to 6983 ft. Held safety meeting. Drilled to 7610 ft. Held safety meeting.
Drilled to 7737 ft. Circulated at 7737 ft. Pulled out of hole to 5000 ft.
Aug 24 1996 (13)
Pulled out of hole to 661 ft. Pulled BHA. Made up BHA no. 11 . R.I.H. to 4500 ft.
Held safety meeting. R.I.H. to 6744 ft. Serviced Block line. Serviced Draw works.
R.I.H. to 7657 ft. Washed to 7737 ft. Drilled to 8012 ft. Held safety meeting. Drilled
to 8305 ft.
Aug 25 1996 (14)
Drilled to 8738 ft. Circulated at 8738 ft. Held safety meeting. Pulled out of hole to
7657 ft. R.I.H. to 8738 ft. Drilled to 9052 ft. Serviced Washpipe. Drilled to 9335 ft.
Held safety meeting. Drilled to 9742 ft. Circulated at 9742 ft.
Aug 26 1996 (15)
Circulated at 9742 ft. Pulled out of hole to 9610 ft. R.I.H. to 9742 ft. Drilled to 9842 ft.
Serviced Mud shakers. Drilled to 9931 ft. Held safety meeting. Drilled to 10305 ft.
Serviced Pistons. Drilled to 10518 ft. Held safety meeting. Drilled to 10746 ft.
Aug 27 1996 (16)
Drilled to 11028 ft. Held safety meeting. Drilled to 11310 ft. Circulated at 11310 ft.
Pulled out of hole to 6997 ft. Held safety meeting. Serviced Block line. Pulled out of
hole to 653 ft. Pulled BHA. Made up BHA no. 12.
Aug 28 1996 (17)
Made up BHA no. 12. R.I.H. to 11310 ft. Drilled to 11317 ft. Held safety meeting.
Drilled to 11475 ft. Circulated at 11475 ft. Pulled out of hole to 189 ft. Pulled BHA.
Held safety meeting. Made up BHA no. 13. R.I.H. to 6787 ft. Serviced Block line.
R.I.H. to 11475 ft.
Page 2
Operations Summary for: 11-09A
Aug 29 1996 (18)
R.I.H. to 11475 ft. Drilled to 11550 ft. Held safety meeting. Drilled to 11790 ft.
Circulated at 11790 ft. Pulled out of hole to 11790 ft. R.I.H. to 11790 ft. Circulated
at 11790 ft. Pulled out of hole to 11790 ft. R.I.H. to 11790 ft. Circulated at 11790 ft.
Pulled out of hole to 10500 ft. Held safety meeting. Pulled out of hole to 187 ft.
Pulled BHA.
Aug 30 1996 (19)
Held safety meeting. Ran electric logs. Held safety meeting. Ran electric logs.
Held safety meeting. Ran electric logs. Rigged up Casing handling equipment.
safety meeting. Ran Casing to 200 ft (7 in OD).
Held
Aug 31 1996 (20)
Ran Casing to 5061 ft (7 in OD). Held safety meeting. Rigged up sub-surface
equipment - Liner hanger. Ran Casing on landing string to 11790 ft. Circulated at
11790 ft. Displaced slurry - 60.2 bbl. Reverse circulated at 6709 ft. Pulled Drillpipe
in stands to 4888 ft. Laid down 1812 ft of Drillpipe. Ran Drillpipe to 600 ft (5 in-
OD).
Sep I 1996 (21)
Ran Drillpipe to 5358 ft (5 in OD). Serviced Block line. Laid down 180 ft of HWDP.
Tested BOP stack. Made up BHA no. 14. Held safety meeting. R.I.H. to 11672 ft.
Circulated at 11672 ft. Tested Casing - Via annulus and string.
Sep 2 1996 (22)
Tested Casing - Via annulus and string. Pulled out of hole to 6700 ft. Held safety
meeting. Serviced .Block line. Pulled out of hole to 6000 ft. Held safety meeting.
Pulled out of hole to 184 ft. Pulled BHA. Made up BHA no. 15. R.I.H. to 6709 ft.
Functioned downhole tools at 6709 ft. Circulated at 6706 ft. Pulled out of hole to
4700 ft. Held safety meeting. Pulled out of hole to 1229 ft. Pulled BHA. Worked on
BOP - Top ram.
Sep 3 1996 (23)
Worked on BOP - Top ram. Held safety meeting. Ran Casing on landing string to
6367 ft. Held safety meeting. Set Retrievable packer at 6367 ft with 3500 psi. Tested
Casing - Via annulus and string. Pulled Drillpipe in stands to 0 ft. Made up BHA no.
16. R.I.H. to 11672 ft. Drilled cement to 11706 ft. Held safety meeting. Drilled
installed equipment - Landing collar. Circulated at 11800 ft.
Page
Operations Summary for: 11-09~
Sep 4 1996 (24)
Circulated at 11800 ft. Drilled to 12034 ft. Held safety meeting. Drilled to 12502 ft.
Held safety meeting. Drilled to 12534 ft. Circulated at 12534 ft. Pulled out of hole to
6200 ft.
Sep 5 1996 (25)
Pulled out of hole to 4000 ft. Serviced Block line. Pulled out of hole to 185 ft.
BHA. Made up BHA no. 17. R.I.H. to 12534 ft. Drilled to 13005 ft.
Pulled
Sep 6 1996 (26)
Drilled to 13329 ft. Circulated at 13329 ft. Pulled out of hole to 11790 ft. R.I.H. to
13329 ft. Circulated at 13329 ft. Pulled out of hole to 185 ft. Pulled BHA. Rigged up
Casing handling equipment.
Sep 7 1996 (27)
Rigged up Casing handling equipment. Ran Casing to 1690 ft (4.5 in OD).
Circulated at 1690 ft. Ran Casing on landing string to 11790 ft. Circulated at 11790 ft.
Ran Casing on landing string to 13329 ft. Circulated at 13329 ft. Mixed and pumped
slurry- 46.6 bbl. Displaced slurry- 165.5 bbl. Reverse circulated at 11647 ft.
Serviced Block line. Pulled Drillpipe in stands to 0 ft. Tested Well control.
Sep 8 1996 (28)
Tested Well control. Made up BHA no. 18. R.I.H. to 11669 ft. Reamed to 11819 ft.
R.I.H. to 13188 ft. Drilled installed equipment - Landing collar. Tested Casing - Via
annulus and string. Drilled installed equipment - Landing collar. Circulated at 13238
ft. Tested Casing - Via annulus and string. Circulated at 13238 ft. Pulled out of hole
to 12320 ft. Circulated at 12320 ft.
Sep 9 1996 (29)
Circulated at 12320 ft. Pulled out of hole to 1700 ft. Pulled BHA. Made up BHA no.
19. R.I.H. to 8067 ft. Worked toolstring at 8067 ft. Pulled out of hole to 1700 ft.
Functioned downhole tools at 1700 ft. R.I.H. to 10135 ft. Functioned downhole tools
at 10135 ft. R.I.H. to 13238 ft. Functioned downhole tools at 13238 ft.
Sep 10 1996 (30)
Functioned downhole tools at 13238 ft. Pulled out of hole to 7300 ft. Serviced
Block line. Pulled out of hole to 1700 ft. R.I.H. to 13238 ft. Perforated from 11800 ft to
13237 ft. Circulated at 11491 ft. Laid down 1300 ft of 5 in OD drill pipe. Serviced
Block line. Laid down 10182 ft of 5 in OD drill pipe. Pulled BHA.
Page 4
Operations Summary for: 11-0,9..
Sep 11 1996 (31)
Pulled BHA. Rigged up Tubing handling equipment. Ran Tubing to 11372 ft (4.5 in
OD). Circulated at 11372 ft.
Sep 12 1996 (32)
Set packer at 11330 ft with 4000 psi. Tested Tubing. Tested Casing. Rigged down
Tubing handling equipment. Rigged down BOP stack. Installed Xmas tree. Tested All
tree valves. Removed Hanger plug. Testdd Casing. Circulated at 2200 ft. Installed
Hanger plug.
Page 5
SPE~-~-'Y-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
SHARED SERVICES DRILLING
PBU/DS ll-09A
500292140201
NORTH SLOPE BOROUGH
COMPUTATION DATE: 9/13/96
DATE OF SURVEY: 090396
MWD SURVEY
JOB NUMBER: AK-MW-60111
KELLY BUSHING ELEV. = 57.10 FT.
OPERATOR: ARCO ALASKA INC
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS
INCLN
DG MN
COURSE DLS TOTAL
DIRECTION RECTANGULAR COORDINATES
DEGREES DG/100 NORTH/SOUTH EAST/WEST
VERT.
SECT.
6799.00 5019.50 4962.40
6800.00 5019.97 4962.87
6829.00 5033.58 4976.48
6913.23 5077.17 5020.07
6944.93 5095.47 5038.37
61 49
61 52
62 10
55 27
54 1
N 12.70 E .00 3564.87N 235.85E
N 12.74 E 5.93 3565.73N 236.04E
N 12.97 E 1.25 3590.70N 241.74E
N 12.56 E 7.98 3660.93N 257.66E
N 12.39 E 4.56 3686.21N 263.25E
1719.79
1720.32
1736.04
1780.14
1795.88
6977.21 5114.77 5057.67
7008.52 5134.13 5077.03
7040.37 5154.18 5097.08
7071.62 5174.28 5117.18
7103.56 5195.64 5138.54
52 30
51 6
50 50
49 4
46 58
N 12.22 E 4.70 3711.48N 268.77E
N 12.05 E 4.49 3735.53N 273.94E
N 11.87 E .93 3759.74N 279.07E
N 11.68 E 5.72 3783.16N 283.95E
N 11.48 E 6.56 3806.42N 288.72E
1811.56
1826.41
1841.28
1855.60
1869.75
7135.30 5217.64 5160.54
7166.94 5240.22 5183.12
7198.58 5263.18 5206.08
7230.37 5286.34 5229.24
7291.19 533~.91 5274.81
45 15
43 39
43 17
43 12
39 42
N 11.28 E 5.44 3828.84N 293.23E
N 11.06 E 5.11 3850.58N 297.52E
N 10.84 E 1.21 3871.95N 301.66E
N 10.60 E .61 3893.36N 305.71E
N 9.50 E 5.86 3932.99N 312.75E
1883.31
1896.39
1909.17
1921.88
1945.00
7385.16 5404.33 5347.23
7478.19 5476.17 5419.07
7572.15 5549.40 5492.30
7667.17 5624.21 5567.11
7741.40 5682.49 5625.39
39 28
39 24
38 10
37 57
38 34
N 7.20 E 1.58 3992.23N 321.45E
N 7.60 E .28 4050.84N 329.06E
N 7.80 E 1.32 4109.17N 336.95E
N 7.60 E .27 4167.23N 344.79E
N 7.80 E .87 4212.79N 350.95E
1977.91
2009.57
2041.36
2073.00
2097.83
7835.62 5755.63 5698.53
7927.95 5827.12 5770.02
8023.73 5902.03 5844.93
8118.74 5976.80 5919.70
8213.46 6052.09 5994.99
39 34
38 55
38 10
38 0
36 42
N 8.20 E 1.09 4271.60N 359.22E
N 8.20 E .70 4329.43N 367.56E
N 7.20 E 1.03 4388.57N 375.56E
N 7.40 E .21 4446.71N 383.00E
N 8.70 E 1.61 4503.61N 391.04E
2130.17
2162.16
2194.40
2225.71
2257.03
8308.25 6127.91 6070.81
8402.45 6203.01 6145.91
8496.69 6278.04 6220.94
8591.82 6353.68 6296.58
8686.00 6428.40 6371.30
37 3
37 12
37 15
37 24
37 35
N 8.30 E .46 4559.87N 399.45E
N 8.00 E .25 4616.17N 407.51E
N 8.20 E .14 4672.62N 415.55E
N 9.10 E .59 4729.65N 424.22E
N 8.10 E .68 4786.34N 432.79E
2288.42
2319.51
2350.64
2382.60
2414.31
8780.03 6502.93 6445.83 37 32
8873.65 6577.59 6520.49 36 40
8968.03 6653.22 6596.12 36 47
9062.04 6728.30 6671.20 37 12
9155.41 6802.65 6745.55 37 15
N 8.30 E .14 4843.08N 440.97E
N 9.80 E 1.33 4898.86N 449.85E
N 10.20 E .28 4954.46N 459.65E
N 9.70 E .53 5010.18N 469.43E
N 9.20 E .33 5065.90N 478.70E
2445.70
2477.31
2509.68
2542.08
2574.03
SPEk~<Y-SLrN DRILLING SERVICES
ANCHOtLAGE ALASKA
PAGE
SHARED SERVICES DRILLING
PBU/DS ll-09A
500292140201
NORTH SLOPE BOROUGH
COMPUTATION DATE: 9/13/96
DATE OF SURVEY: 090396
MWD SURVEY
JOB NUMBER: AK-MW-60111
KELLY BUSHING ELEV. = 57.10
OPEtLATOR: ARCO ALASKA INC
FT.
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS
INCLN
DG MN
COURSE DLS TOTAL
DIRECTION RECTANGULAR COORDINATES
DEGREES DG/100 NORTH/SOUTH EAST/WEST
VERT.
SECT.
9250.69 6878.54 6821.44
9344.45 6953.35 6896.25
9438.64 7028.53 6971.43
9530.99 7102.35 7045.25
9625.68 7178.28 7121.18
37 9
37 0
37 4
36 47
36 34
N 9.70 E .33 5122.72N 488.16E
N 9.40 E .25 5178.46N 497.54E
N 9.90 E .33 5234.40N 507.05E
N 9.20 E .55 5289.12N 516.25E
N 8.60 E .44 5345.01N 525.01E
2606.60
2638.65
2670.90
2702.37
2733.91
9688.37 7228.59 7171.49 36 42
9782.89 7304.59 7247.49 36 14
9877.87 7381.22 7324.12 36 12
9972.87 7458.01 7400.91 35 55
10067.51 7534.66 7477.56 35 54
N 8.30 E .34 5382.01N 530.50E
N 8.10 E .50 5437.62N 538.52E
N 8.90 E .50 5493.13N 546.81E
N 10.60 E 1.09 5548.24N 556.28E
N 10.40 E .13 5602.83N 566.40E
2754.53
2785.28
2816.25
2848.11
2880.35
10161.42 7610.91 7553.81
10254.25 7686.45 7629.35
10350.63 7764.43 7707.33
10443.37 7839.51 7782.41
10535.30 7914.63 7857.53
35 30
35 34
36 24
35 27
34 56
N 10.20 E .44 5656.76N 576.20E
N 9.50 E .44 5709.92N 585.43E
N 10.30 E 1.00 5765.71N 595.17E
N 9.70 E 1.09 5819.31N 604.63E
N 11.10 E 1.04 5871.43N 614.19E
2912.01
2942.84
2975.24
3006.45
3037.13
10629.18 7990.94 7933.84
10722.73 8066.53 8009.43
10816.63 8142.43 8085.33
10911.50 8218.42 8161.32
11006.20 8294.12 8237.02
36 18
35 52
36 15
37 16
36 34
N 11.50 E 1.48 5925.05N 624.90E
N 10.20 E .94 5979.17N 635.28E
N 9.80 E .48 6033.61N 644.88E
N 10.40 E 1.14 6089.52N 654.84E
N 11.10 E .86 6145.42N 665.45E
3069.50
3101.77
3133.47
3166.12
3199.35
11101.73 8370.78 8313.68 36 40
11193.80 8444.23 8387.13 37 28
11224.94 8468.83 8411.73 38 12
11256.89 8493.97 8436.87 38 0
11329.06 8549.76 8492.66 40 42
N 10.70 E .27 6201.39N 676.23E
N 11.80 E 1.13 6255.83N 687.06E
N 11.90 E 2.32 6274.52N 690.99E
N 13.20 E 2.58 6293.77N 695.27E
N 12.20 E 3.84 6338.42N 705.32E
3232.76
3265.58
3277.03
3289.05
3317.02
11360.34 8572.72 8515.62 44 49
11391.83 8594.20 8537.10 49 5
11422.76 8613.56 8556.46 53 24
11455.74 8632.47 8575.37 56 37
11485.91 8648.74 8591.64 58 10
N 11.70 E 13.22 6359.19N 709.71E
N 11.80 E 13.56 6381.72N 714.40E
N 12.60 E 14.05 6405.29N 719.50E
N 15.00 E 11.44 6431.52N 725.95E
N 22.10 E 20.47 6455.59N 734.04E
3329.78
3343.54
3358.12
3375.05
3392.55
11518.18 8664.98 8607.88 61 25
11549.51 8678.93 8621.83 65 43
11580.74 8690.76 8633.66 69 46
11612.81 8701.11 8644.01 72 37
11675.09 8718.44 8661.34 75 10
N 26.80 E 16.12
N 32.20 E 20.65
N 37.10 E 19.46
N 43.50 E 20.89
N 55.90 E 19.55
6480.95N 745.60E
6505.34N 759.42E
6529.09N 775.86E
6552.22N 795.50E
6590.80N 841.05E
3413.74
3436.58
3461.51
3489.07
3546.66
SPE~.¥~f-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
SHARED SERVICES DRILLING
PBU/DS ll-09A
500292140201
NORTH SLOPE BOROUGH
COMPUTATION DATE: 9/13/96
DATE OF SURVEY: 090396
MWD SURVEY
JOB NUMBER: AK-MW-60111
KELLY BUSHING ELEV. = 57.10 FT.
OPERATOR: ARCO ALASKA INC
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS
INCLN
DG MN
COURSE DLS TOTAL
DIRECTION RECTANGULAR COORDINATES
DEGREES DG/100 NORTH/SOUTH EAST/WEST
VERT.
SECT.
11707.01 8725.94 8668.84 77 40
11737.55 8731.23 8674.13 82 20
11771.19 8733.94 8676.84 88 25
11802.57 8734.26 8677.16 90 24
11832.33 8734.04 8676.94 90 27
N 61.30 E 18.23 6606.95N 867.53E 3577.48
N 63.00 E 16.24 6621.00N 894.11E 3607.51
N 63.13 E 18.05 6636.18N 923.99E 3641.01
N 63.25 E 6.32 6650.33N 952.00E 3672.37
N 63.37 E .45 6663.69N 978.58E 3702.11
11864.13 8733.67 8676.57
11896.12 8733.24 8676.14
11927.23 8732.98 8675.88
11959.28 8732.75 8675.65
11990.69 8732.77 8675.67
90 51
90 40
90 16
90 33
89 20
N 63.50 E 1.32 6677.92N 1007.02E
N 62.70 E 2.56 6692.39N 1035.55E
N 63.80 E 3.76 6706.39N 1063.33E
N 64.10 E 1.26 6720.46N 1092.12E
N 63.30 E 4.59 6734.38N 1120.28E
3733.90
3765.87
3796.96
3829.01
3860.40
12052.01 8733.27 8676.17
12115.59 8733.34 8676.24
12146.96 8733.19 8676.09
12178.90 8732.90 8675.80
12209.55 8732.58 8675.48
89 43
90 9
90 24
90 39
90 33
N 64.80 E 2.52 6761.21N 1175.41E
N 64.80 E .68 6788.28N 1232.94E
N 65.00 E 1.02 6801.59N 1261.34E
N 65.00 E .78 6815.08N 1290.29E
N 65.40 E 1.34 6827.94N 1318.11E
3921.71
3985.29
4016.66
4048.60
4079.24
12239.91 8732.25 8675.15
12270.55 8731.82 8674.72
12301.82 8730.91 8673.81
12332.75 8729.43 8672.33
12364.19 8727.64 8670.54
90 40
90 56
92 22
93 6
93 26
N 66.80 E 4.63 6840.24N 1345.86E
N 67.20 E 1.57 6852.21N 1374.07E
N 67.50 E 4.64 6864.24N 1402.91E
N 68.70 E 4.55 6875.77N 1431.57E
N 67.20 E 4.88 6887.55N 1460.66E
4109.59
4140.21
4171.44
4202.29
4233.63
12394.85 8725.67 8668.57
12426.21 8723.52 8666.42
12458.19 8721.47 8664.37
12489.81 8719.62 8662.52
12518.97 8717.86 8660.76
93 55
93 56
93 23
93 19
93 33
N 69.00 E 6.06 6898.96N 1489.05E
N 67.80 E 3.82 6910.48N 1518.14E
N 67.10 E 2.80 6922.72N 1547.61E
N 67.00 E .37 6935.02N 1576.68E
N 67.80 E 2.85 6946.21N 1603.55E
4264.18
4295.41
4327.29
4358.84
4387.92
12550.49 8716.39 8659.29
12582.24 8715.94 8658.84
12612.77 8716.09 8658.99
12644.30 8716.25 8659.15
12675.90 8716.39 8659.29
91 47
89 50
89 35
89 49
89 40
N 66.90 E 6.30 6958.33N 1632.60E
N 67.00 E 6.15 6970.76N 1661.81E
N 66.70 E 1.26 6982.76N 1689.88E
N 67.80 E 3.56 6994.96N 1718.95E
N 67.60 E .77 7006.95N 1748.19E
4419.38
4451.10
4481.61
4513.12
4544.68
12708.24 8716.42 8659.32
12739.82 8716.26 8659.16
12771.39 8716.30 8659.20
12802.11 8716.76 8659.66
12833.73 8717.36 8660.26
90 13
90 20
89 32
88 44
89 5
N 67.50 E 1.70 7019.30N 1778.08E
N 68.00 E 1.63 7031.25N 1807.31E
N 66.40 E 5.67 7043.49N 1836.41E
N 67.70 E 4.97 7055.46N 1864.69E
N 66.00 E 5.49 7067.89N 1893.76E
4576.99
4608.53
4640.08
4670.77
4702.37
SPE,~.~-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
SHARED SERVICES DRILLING
PBU/DS ll-09A
500292140201
NORTH SLOPE BOROUGH
COMPUTATION DATE: 9/13/96
DATE OF SURVEY: 090396
MWD SURVEY
JOB NUMBER: AK-MW-60111
KELLY BUSHING ELEV. = 57.10 FT.
OPERATOR: ARCO ALASKA INC
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS COURSE DLS TOTAL
INCLN DIRECTION RECTANGULAR COORDINATES VERT.
DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT.
12867.49 8717.72 8660.62 89 39 N 67.30 E 4.20 7081.27N 1924.75E 4736.11
12897.45 8717.91 8660.81 89 37 N 66.80 E 1.67 7092.95N 1952.33E 4766.05
12928.49 8718.22 8661.12 89 13 N 66.90 E 1.33 7105.15N 1980.87E 4797.07
12960.29 8718.46 8661.36 89 54 N 66.50 E 2.48 7117.73N 2010.08E 4828.85
12991.81 8718.29 8661.19 90 42 N 67.40 E 3.82 7130.07N 2039.08E 4860.35
13023.16 8717.98 8660.88 90 24 N 65.90 E 4.89 7142.49N 2067.86E 4891.69
13055.19 8717.68 8660.58 90 40 N 67.50 E 5.07 7155.16N 2097.27E 4923.70
13086.66 8717.17 8660.07 91 10 N 68.20 E 2.71 7167.02N 2126.41E 4955.12
13117.41 8716.51 8659.41 91 17 N 67.20 E 3.27 7178.69N 2154.86E 4985.83
13148.56 8716.13 8659.03 90 7 N 67.80 E 4.22 7190.61N 2183.63E 5016.95
13180.82 8716.27 8659.17 89 22 N 67.70 E 2.31 7202.82N 2213.49E 5049.17
13212.54 8716.63 8659.53 89 19 N 67.30 E 1.28 7214.96N 2242.79E 5080.86
13243.74 8716.92 8659.82 89 37 N 67.50 E 1.18 7226.95N 2271.59E 5112.03
13275.27 8717.18 8660.08 89 25 N 68.50 E 3.24 7238.76N 2300.83E 5143.51
13284.82 8717.27 8660.17 89 28 N 67.20 E 13.63 7242.36N 2309.67E 5153.05
13329.00 8717.63 8660.53 89 34 N 67.20 E .22 7259.48N 2350.40E 5197.20
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
HORIZONTAL DISPLACEMENT = 7630.49 FEET
AT NORTH 17 DEG. 56 MIN. EAST AT MD = 13329
VERTICAL SECTION RELATIVE TO WELL HEAD
VERTICAL SECTION COMPUTED ALONG 65.01 DEG.
TIE-IN SURVEY AT 6,799.00' MD
WINDOW POINT AT 6,829.00' MD
PROJECTED SURVEY AT 13,329.00' MD
SPE~.~.~-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
SHARED SERVICES DRILLING
PBU/DS ll-09A
500292140201
NORTH SLOPE BOROUGH
COMPUTATION DATE: 9/13/96
DATE OF SURVEY: 090396
JOB NUMBER: AK-MW-60111
KELLY BUSHING ELEV. = 57.10 FT.
OPERATOR: ARCO ALASKA INC
INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES
NORTH/SOUTH EAST/WEST
MD-TVD VERTICAL
DIFFERENCE CORRECTION
6799.00 5019.50 4962.40 3564.87 N 235.85 E
7799.00 5727.41 5670.31 4248.51 N 355.90 E
8799.00 6517.97 6460.87 4854.52 N 442.64 E
9799.00 7317.59 7260.49 5447.05 N 539.86 E
10799.00 8128.21 8071.11 6023.34 N 643.10 E
1779.50
2071.59 292.09
2281.03 209.43
2481.41 200.39
2670.79 189.38
11799.00 8734.28 8677.18 6648.72 N 948.81 E 3064.72 393.93
12799.00 8716.69 8659.59 7054.28 N 1861.81 E 4082.31 1017.59
13329.00 8717.63 8660.53 7259.48 N 2350.40 E 4611.37 529.06
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
SPEk~-SUN DRILLING SERVICES
A/qCHOR3~GE ALASKA
PAGE
SHARED SERVICES DRILLING
PBU/DS ll-09A
500292140201
NORTH SLOPE BOROUGH
COMPUTATION DATE: 9/13/96
DATE OF SURVEY: 090396
JOB NUMBER: AK-MW-60111
KELLY BUSHING ELEV. = 57.10 FT.
OPERATOR: ARCO ALASKA INC
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES
NORTH/SOUTH EAST/WEST
MD-TVD VERTICAL
DIFFERENCE CORRECTION
6799.00 5019.50 4962.40
6876.41 5057.10 5000.00
7044.96 5157.10 5100.00
7190.22 5257.10 5200.00
3564.87 N 235.85 E
3630.81 N 250.90 E
3763.21 N 279.80 E
3866.31 N 300.58 E
1779.50
1819.30 39.80
1887.86 68.56
1933.12 45.25
7323.93 5357.10 5300.00
7453.50 5457.10 5400.00
7581.94 5557.10 5500.00
7708.94 5657.10 5600.00
7837.53 5757.10 5700.00
3953.63 N 316.20 E
4035.30 N 326.99 E
4115.17 N 337.77 E
4192.75 N 348.22 E
4272.80 N 359.40 E
1966.83 33.71
1996.40 29.57
2024.84 28.44
2051.84 27.00
2080.43 28.59
7966.47 5857.10 5800.00
8093.73 5957.10 5900.00
8219.71 6057.10 6000.00
8344.83 6157.10 6100.00
8470.38 6257.10 6200.00
4353.38 N 370.99 E
4431.44 N 381.02 E
4507.30 N 391.61 E
4581.69 N 402.63 E
4656.85 N 413.27 E
2109.37 28.94
2136.63 27.26
2162.61 25.97
2187.73 25.12
2213.28 25.55
8596.12 6357.10 6300.00
8722.22 6457.10 6400.00
8848.10 6557.10 6500.00
8972.87 6657.10 6600.00
9098.20 6757.10 6700.00
4732.23 N 424.64 E
4808.21 N 435.91 E
4883.82 N 447.25 E
4957.31 N 460.17 E
5031.73 N 473.11 E
2239.02 25.74
2265.12 26.10
2291.00 25.88
2315.77 24.77
2341.10 25.32
9223.79 6857.10 6800.00
9349.15 6957.10 6900.00
9474.45 7057.10 7000.00
9599.30 7157.10 7100.00
9723.93 7257.10 7200.00
5106.71 N 485.42 E
5181.25 N 498.00 E
5255.67 N 510.76 E
5329.47 N 522.66 E
5403.04 N 533.57 E
2366.69 25.59
2392.05 25.36
2417.35 25.30
2442.20 24.85
2466.83 24.63
9847.98 7357.10 7300.00
9971.74 7457.10 7400.00
10095.22 7557.10 7500.00
10218.17 7657.10 7600.00
10341.53 7757.10 7700.00
5475.69 N 544.08 E
5547.59 N 556.16 E
5618.82 N 569.33 E
5689.23 N 581.96 E
5760.40 N 594.21 E
2490.88 24.05
2514.64 23.76
2538.12 23.48
2561.07 22.95
2584.43 23.35
10464.96 7857.10 7800.00
10587.22 7957.10 7900.00
10711.09 8057.10 8000.00
10834.83 8157.10 8100.00
10960.10 8257.10 8200.00
5831.66 N 606.74 E
5900.73 N 619.96 E
5972.46 N 634.07 E
6044.22 N 646.71 E
6118.46 N 660.16 E
2607.86 23.43
2630.12 22.26
2653.99 23.87
2677.73 23.73
2703.00 25.27
11084.67 8357.10 8300.00 6191.37 N 674.34 E 2727.57 24.57
SPE,, .f-SUN DRILLING SERVICES
ANCHOR3~GE ALASKA
PAGE 7
SHARED SERVICES DRILLING
PBU/DS ll-09A
500292140201
NORTH SLOPE BOROUGH
COMPUTATION DATE: 9/13/96
DATE OF SURVEY: 090396
JOB NUMBER: AK-MW-60111
KELLY BUSHING ELEV. = 57.10 FT.
OPERATOR: ARCO ALASKA INC
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES MD-TVD VERTICAL
NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION
11210.06 8457.10 8400.00
11338.84 8557.10 8500.00
11502.21 8657.10 8600.00
13329.00 8717.63 8660.53
6265.57 N 689.10 E 2752.96 25.40
6344.73 N 706.68 E 2781.74 28.77
6468.41 N 739.64 E 2845.11 63.37
7259.48 N 2350.40 E 4611.37 1766.26
THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN
THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS
10/10/96
GeoQuest
500 W. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrie
NO. 10470
Company:
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Field: Prudhoe Bay
Floppy
Well Job # Log Description Date BL RF Sepia Disk
D.S. 11-09A 96254 DITE~SDT~LDT/CNTG 960829 1
D.S. 11-09A PHASOR INDUCTION LOG 960829 I 1
D.S. 11-09A BOREHOLE COMPENSATED SONIC LOG 960829 I 1
D.S. 11-09A COMP NEUTRON LITHO-DENSlTY LOG 960829 I 1
D.S. 11-09A COMPENSATED NEUTRON LOG 960829 I 1
I D.S. 11-09A BOREHOLE PROFILE LOG 960829 1 1
D.S. 11-09A SUB SEA VERTICAL DEPTH 960829 I I
SIGNED:
Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you.
OCT 1 1 199G
DATE: AJ~I$~';.~. Oil & GB$ Cons. Commlssio~
September 18, 1996
AOGCC
Howard Okland
3001 Porcupine Dr
Anchorage, AK 99501
Re: Distribution of Survey Data 11-09A
Dear Mr. Oakland,
Enclosed are two hard copies of the above mentioned file(s).
Well ll-09A ~(,"'" I~D survey, tie in point 6,799.00', window point 6829.00', interpolated
depth 13,329.00'.
Please call me at 563-3256 if you have any questions or concerns.
Regards,
-5
William T. Allen
Operations Support Engineer
Attachments.
· ~as ,.,on.s. C,o m mj$sion
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252
MEMORANDUM
TO:
THRU:
David Johns~
Chairman
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: September 7, 1996
Blair Wondzell, ,J~ ~
P. !. Supervisor ~/~'~
FROM: Bobby Fos~'-~ SUBJECT:
Petroleum Inspector
FILE NO: AFMIIGDD.doc
BOPE Test - Nabors 2ES
ARCO - PBU - DS 11-09A
PTD # 96-0128
Prudhoe Bay Field
Saturday, September 7, 1996: ! traveled this date to ARCO's PBU DS11-09A and
witnessed the bope test on Nabors rig 2ES.
As the attached AOGCC BOPE Test Report shows there were no failures. The crew
did a very good job and was well trained on the testing procedure.
The rig was clean and all equipment seemed to be in good working order. The
location was clean and there was good access to all areas of the rig.
Summary: I withessed the BOPE test on ARCO's DS 11-09A being drilled by
Nabors 2ES - test time 2.5 hours - No failures.
Attachment · AFMIIGDD.XLS
X UNCLASSIFIED
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report
OPERATION: Drig: X Workover:
Drlg Contractor: NABORS
Operator: ARCO
Well Name: DS1'i-OgA
Casing Size: 7"X4.5" Set @
Test: Initial Weekly
,
Rig No. 2ES PTD#
Rep.:
Rig Rep.:
13, 76'1' Location: Sec.
X Other
DATE: 9,/7/96
96-0128 Rig Ph.# 65g-4836
GENE BECK
ROBERT FRENCH
28 T. 11N R. 15E Meridian Urn.
MISC. INSPECTIONS:
Location Gen.: OK
Housekeeping: OK (Gert)
PTD On Location YES
Standing Order Posted YES
Well Sign OK
Drl. Rig OK
Hazard Sec. YES
FLOOR SAFETY VALVES:
Upper Kelly / IBOP
Lower Kelly / IBOP
Ball Type
Inside BOP
Quan.
Test
Pressure
500/5,000
500/5,000
500/5,000
500/5,0,00
P/F
P
P
P
BOP STACK:
Annular Preventer
Pipe Rams
Lower Pipe Rams
Blind Rams
Choke-Ln. Valves
HCR Valves
Kill Line Valves
Check Valve
Quan. Test Press. P/F
300,3,0o0 P
1 500/5,000 P
P
500/5,000.
500/5,000
2 500/5,000
I 500/5,000
' N/A
MUD SYSTEM: Visual Alarm
Trip Tank YES YES
Pit Level Indicators YES 'YES
Flow Indicator YES YES
Meth Gas Detector YES YES
H2S Gas Detector ~"ES ~ES'
CHOKE MANIFOLD:
No. Valves 14
No. Flanges 32
Manual Chokes 1
Hydraulic Chokes 1
Test
Pressure
500/5,000
500/5,000
Functioned
Funcb'oned
P/F
P
P
P
ACCUMULATOR SYSTEM:
System Pressure
Pressure After Closure
200 psi Attained After Closure
System Pressure AttainedMast=,
Blind Switch Covers:
Nitgn. Btl's: 4 ~2100
3,000 t P
..1,60.0 . P
v ,,,,,,uL~ 2g sec.
-'----- minutes --~--- sec.
Remet~--.
YES YES
Psig.
Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 22 Repair or Replacement of Failed
Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to
the AOGCC Commission Office ~: 'Pax No 276-7542 Inspector North Slope Pager No. 659-3607 or 3687
If your call is not returned by the inspector within 12 hours please contact the P. i. Supervisor at 279-1433
I I I I II
REMARKS:
Distribution:
orig-Wetl File
c - Oper.tRig
c - Database
c - Trip Rpt File
c - Inspector
STATE WITNES~ REQUIRED?
YES X NO
24 HOUR NOTICE GIVEN
YES NO
X
I II
Waived By:
W~tnessed By:
BOBBY D. FOSTER
F1-021L (Rev. 12/94) AFMIIGDD.XLS
HOWARD OKLAND
Attn. ALASKA OIL + GAS CONSERVATION
3001 PORCUPINE DRIVE
ANCHORAGE
AK, 99501.
Dear Sir/Madam,
Reference:
~co ~ ~ (~
ll-09A
PRUDHOE BAY
NORTH SLOPE, AK
Enclosed, please find the data as described below:
Prints/Films: 1 CCL FINAL BL+RF
RECEIVED
Date:
RE:
S EP O G '~99Po
5
Transmittal of Data
ECC #: 6777.00
Sent by: HAND CARRY
Data: MISC
Run # 1
Please sign and return to: Attn. Rodney D. Paulson
Western Atlas Logging Services
5600 B Street
Suite 201
Anchorage, AK 99518
or ~ ~o (~o~) ~-~0~
Received by Date:
·
i I II
DS 11-9A
TREE: 5-~/16" Gray Gen 111 [~(~]~(~(~ (~(~)(]~l(~i](~
WELLHEAD: Gray Gan III (Sidetrack out of 9 SIS"
~.~8"" !
~ , ~ SSSv ~n~lng Nipple
Proposed ~a~ Lift
~ ~s LI~ ~ANDRE~
4 ~ TBA TBA
' ~ 3 TBA TBA
~, 2' TBA
TBA TBA
. ?"~X ~ 5/8~ Ha~ger~cker Final ~a~ Lift Design TB~
Milled !
EZOV
out tubing
Packer 8queeze ~ ' 7", gg ~, DSO Liner &12,066',- 13,781' MD_ I
behind7/11 ~84'1/2" ~
8queezedPedoratlon~ ~ ~ ~(C(
12,Se4'-12,eS~'MD ~ ~.bo<~.~' ~000~
I I r
DATE REVISED BY COMMENTS
..... PRUDHOE BAY UNIT
8-19-96 W, Aube~ Revised Sidetrack Completion WELL: DS 11
.... AP! NO ~-02g-21402-01
Phone 907 5~-4825 SEC, 28~ T11N; R15E
II
Fax ;07
iii liB _ I
BP Expiration
II I
RECEIVED
AUG i 9 199~
Alaska Oil & Gas Cons. Commission
Anchore, go
~U~ 19 '96
FAX
02:52PM SHRRED SERVICES DRILLIHG
p.1
~ Date 8/19/96
~ Number of pafles in~,ludin~l cover sheet 2
TO: Blair Wondzell FROM: Winton Aubert
AOGGC BP Exploration SSD
P. 0. Box 196612
Anchorage, AK 99519
Phone 279-1433 Phone 907 564-4825
Fax £76.754£ Fax 907 564.5193
Phone ...... Phone
ICC:
REMARKS: [~ Urgent [] Foryour review r~ Reply ASAP F~ P/ease Comment
Attached is~ the revised oompletion schematic for Well DS 11-9A as we discussed. Thank you.
Winton Aubert
RECEIVED
Alaska Oil & G-Ds Cons. 6omm~ssioH
Anchor~.gP,
TONY KNOWLE$, GOVERNOR
ALASKA OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
July 25, 1996
..
Terry Jordan, Senior Drilling Engineer
ARCO Alaska, Inc.
P O Box 196612
Anchorage, AK 99519-6612
Re;
Well #"
Company
Permit #
Surf Loc
Btrnhole Loc
Prudhoe Bay Unit 11-09A
ARCO Alaska, Inc.
96-128
1155' NSL, 377' WEL, SEC. 28, T1 IN, R15E, UM
3143' NSL, 3282' WEL, SEC. 22, T1 iN, R15E, UM
Dear Mr. Jordan:
Enclosed is the approved application for permit to re-drill the above referenced well.
The permit to re-drill does not exempt you from obtaining additional permits required by
law from other governmental agencies, and does not authorize conducting re-drilling
operations until all other required permitting determinations are made.
Blowout prevention equipment (BOPE) must be tested in accordance with
20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a
representative of the Commission to witness a test of BOPE installed prior to drilling a
new hole. Notice may be given by contacting the Commission's petroleum field inspector
on the North Slo~607.
,
Chairman
BY ORDER OF THE COMMISSION
dlf/encl
c: Dept ofFish & Game, Habitat Section - w/o encl
Dept of Environmental Conservation- w/o encl
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
[] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil
la. Type of work [] Re-Entry [] Deepen~ [] Service [] Development Gas [] Single Zone [] Multiple Zone
2. Name of Operator i5. Datum Elevation (DF or KB) 10. Field and Pool
ARCO Alaska Inc. Plan RTE = 57.7 Prudhoe Bay Field / Prudhoe
3. Address 16. Property Designation Bay Pool
P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028322
4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025)
1155' NSL, 377' WEL, SEC. 28, T11N, R15E Prudhoe Bay Unit
At top of productive interval 8. Well Number Number U-630610
2482' NSL, 4702' WEL, SEC. 22, T11 N, R15E 11-09A
At total depth 9. Approximate spud date Amount $200,000.00
3143' NSL, 3282' WEL, SEC. 22, T11N, R15E 07/28/96
12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
ADL 028325 3143'I No Close Approach 2560 13781' MD / 8748' TVD
16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)}
Kick Off Depth 10000' Maximum Hole Angle 90° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig
i18. Casing Program Setting Depth
Size Specifications Top Bottom Quantity of Cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
8-1/2" 7" 29# L-80 BTC-Mod 2366' 9850' 6770' 12216' 8748' 308 sx Class 'G'
6" 4-1/2" 12.6# L-80 BTC-Mod 1715' 12066' 8710' 13781' 8748' 203 sx Class 'G'
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs(measured) ORIGINAL
true vertical feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented MD TVD
Structural
Conductor
Surface
Intermediate R ~ E F. IV
Production
Liner
JUL 2 5 199~
Alaska 0il 8,. G;ts Cons. Commission
Perforation depth: measured Anchor%co
true vertical
20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program
[] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements
Contact Engineer Name/Number: Zelijko Runje, 564-4825 Prepared By Name/Number Terrie Hubble, 564-4628
21. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ¢~// 'l~
Tern/Jordan Title Senior Drilling Engineer Date -~.
Commission Use Only
Per~it Number I APl Number I Appr°val Date I See c°ver letter
/(,~_,~' ..,,,,/~__.. ~ 50- ~ ~--~ --- 2.. ? ~::2 ~_..-- o // ~ - ~..~t_ for other requirements
Conditions of Approval: Samples Required [] Yes..~No Mud Log Required [] Yes~No
Hydrogen Sulfide Measures ~t'es [] No Directional Survey Required .~ Yes [] No
Required Working Pressure for BO'--PE [] 2M; [] 3M; '~ 5M; [] 10M; [] 15M
Other: Urlginal Signed By by order of e~
Approved By nm,!,4 ~A~ !,-,h,-,-.,,.~ Commissioner the commission Dat -"~-.-~
Form 10-401 Rev. 12-01-85
Submit In Triplicate
I Well Name: IDS 11-9A
Redrili Summary
Type of Well (producer or injector):
Producer
Surface Location:
Pilot Hole Bottom Hole Location:
1,155' FSL 377' FEL Sec 28, T11N, R15E
Not applicable
Sadlerochit Zone 1 Lateral
2,482' FSL 4,702' FEL Sec 22, T11 N, R15E
3,143' FSL 3,282' FEL Sec 22, T11 N, R15E
Start of Horizontal Location:
End of Horizontal Location:
I AFE Number: I 4J0327 I
I Ri~l: I Nabors2ES
I Estimated Start Date: I July 28, 1996 I
IUD.' 1~3,781' I I TVD=
Operating days to complete: I 25
I KBE: +_57.7'
Well Design (conventional, slimhole, etc.) I Horizontal Sidetrack
Formation Markers:
Formation Tops MD TVD (SS)
K-15 10000 6818' KOP
K-10 10484 7219'
K-5 11011 7718'
Sadlerochit 11615' 8290'
Zone 3 11689' 8360'
Zone 2C 11757' 8425'
Zone 2B 11800' 8465'
Zone 2A/Romeo 11902' 8555'
Zone 1 12002' 8625' 7" casing point (12,216' MD, @ 90° in Zone 1)
TD of Well 137819' 8690' 4-1/2" liner point
Casinq/'rubinq Proqram:
'~1~ Y T
Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm
Tbg O.D. MD/TVD MD/TVD
8-1/2" 7" 29# L-80 BTC-MO D 2366' 9850'/6770' 12216'/8748'
Lower Lateral
6" I 4-1/2" 12.6# L-80 BTC- MO D 1715' 12066'/8710' 13781 '/8748'
Cementinq Proqram:
Lead Cement Tail Cement
Casin~/Liner Sx / Wt / Yield Sx / Wt / Yield Comments
Premium Tail to 1,000 above Sag;
7" 41 / 11.0/3.24 267/15.7/1.14 Tail FW=0; 50% excess;
Lead TOC 200' above liner top; 30%
excess; Pump time = 4+ hrs;
4-1/2" None 203 / 15.7 / 1.17 Class G' 30% excess; TOC 200' above
liner top; Pump time = 4+ hrs;
Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as listed.
Logging Program:
12-1/4" Hole
8-1/2" Hole
6" Hole
Cased Hole:
Not applicable
MWD GR/Directional to TD;
Triple combo on wireline to Romeo (horizontal);
DPC logs are contigency;
MWD G R/Directional/Resistivity
None planned
Mud Proqram:
Intermediate Mu"~ Properties: 1 8-1/2" hole section: LSND
Density Yield 10 sec 10 min pH Fluid
(PPG) PV Point gel gel Loss
Initial 9.8 10-12 8-12 4-8 8-12 9.0-9.5 <8
Final 9.8 16-20 8-12 LSYP 12-16 16-20 9.0-9.5 HTHP-<15.0
Hazards/Concerns Cretaceous MW to be at least 9.8 ppg.
Utilize hi vis sweeps to assist hole cleaning
Monitor LSYP and increase if problems occur trying to clean the hole.
Potential high torque could require lubricant use.
Reduce APl fluid loss to <6 cc before drilling K shales section.
Differential sticking due to higher MW.
Production Mud Properties: ! 6" hole section: Baroid Sheardril
Depth Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
Initial 8.8-9.0 50-60 30-40 15-20 18-24 8.5-9.0 <6
Final 8.8-9.0 50-60 30-40 15-20 18-24 8.5-9.0 <6
Hazards/Concerns Lost Circulation due to overbalance in Sadlerochit.
Differential sticking with overbalance situation.
Perform report daily checks on KCI concentrations in Xanvis KCI system.
Potential high torque could require lubricant use.
Directional:
I KOP: I 10,000' MD (Sidetrack from 9-5/8" casing)
I Maximum Hole Angle: I900
Tan~lent Angle 18.75°
Close ApprOach Well: None
Well Control:
Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is
capable of handling maximum potential surface pressures.
Diverter, BOPE and drilling fluid system schematics on file with AOGCC.
Disposal
No annular injection permits will be submitted for the DS 11-9A sidetrack program.
DS 11-9A Horizontal Sidetrack
Operational Summary
,
,
.
,
.
.
.
.
.
10.
11.
P&A well. Test cement to 1,500 psi. Tag cement minimum of 100' above top
perforation @ 12,494' MD. Cut the 5-1/2" tubing @ +10,400' MD.
MIRU Nabors 2ES drilling rig.
Pull 5-1/2" tubing.
Test 9-5/8" casing to 3,500 psi for 10 minutes.
RIH and set EZSV at ___10,250' MD (255' below proposed 9-5/8" section).
PU section mill, TIH and spot +_15 bbl (_+205') of 18.0 ppg milling fluid from
EZSV (10,250' MD) to 10,045' MD. Space out and mill section from 9,995' MD
to 10,04'5' MD. POOH.
TIH with open-ended drillpipe. Mix and spot a 17.0 ppg cement kick-off plug
(per recommended practices) from 9,795' to 10,145' MD. POOH a minimum of
12 stands. Perform a hesitation squeeze. Do not exceed a final squeeze
pressure of 2,000 PSI and do not displace cement any closer than 100' above
section top.
..
NOTE: Final cement volume should insure slurry placement 100' below
milled section, 50' across milled section and 200' inside casing above milled
section.
PU directional BHA and TIH. Tag TOC. MINIMUM WOC TIME IS 12 HOURS.
Dress off cement plug to 10,000' MD (5' below top of section), kick-off and
directionally drill 8-1/2" hole to +-12,216' MD (+-90°). POOH.
Run and cement 7" liner from +-12,216' MD and tie back into 9-5/8" casing at
+-9,850' MD. POOH and LD liner running tools.
PU directional BHA and drill 6" horizontal hole to +13,781' MD (final inclination
at +-90°) at an azimuth of +-65°. Planned lateral interval is +-1,565'. POOH.
NOTE: Inclination, azimuth and overall lateral length may be shortened by
onsite geologist. MW in this interval will be _+9.0 ppg.
Run a 4-1/2", L-80 slotted liner to TD. Top of liner will be at +12,066' MD.
NOTE: A wiper trip may be made prior to running production liner.
DS 11-9A Horizontal Sidetrack
Proposed Drilling Operations
Page 2/2
12.
RU and run 4-1/2", L-80, production tubing with 7" x 4-1/2" permanent
production packer inside the7" liner at_+11,700' MD (+20° inclination). Test
tubing to 4,000 psi. Test tubing-casing annulus to 3,500 psi.
13. Set two way check and test to 1,000 psi.
14. ND BOPE. NU tree and test to 5,000 psi.
15. Freeze protect well and release rig.
Drilling Hazards
DS 11 is an H2S pad. Although the maximum documented H2S
concentration in the last year on the DS 11-9 well is 4 ppm, appropriate
H2S precautions are to be observed at all times while the drilling rig is
on location. These precautions include, but are not limited to:
Proper training of all onsite personnel, unescorted visitors and
temporary onsite personnel;
Monitors with both audible and visual alarms;
Access to 5-minute emergency escape air packs;
Personal H~S monitors;
Working wind indicator;
Posted evacuation routes (minimum of two);
Muster points in designated safe areas;
KOP will occur in the K-10. MW should be at minimum 9.8 ppg to maintain hole
stability. Shublik B interval may be fractured resulting in lost circulation. 7" liner will
be set across these intervals.
Sadlerochit interval has an estimated pore pressure of -+7.9 ppg EMW. Lost
circulation may occur due to overbalance conditions. A small (25') fault is anticipated
in the the final build interval. Lost circulation is possible but not likely. No faulting is
currently mapped in the target polygon. There are no known drilling close
approaches. No other known drilling hazards are expected.
Anadrill Schlumberger
Alaska District
1111 East 80th Avenue
Anchorage, AK 99518
(907) 349-4511 Fax 344-2160
DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING
Well ......... : DSll-09A (PA) (HA ST)
Field ........ : PRUDHOE BAY, DSll
Computation..: Minimum Curvature
UD:"~ ........ : FEET
su~ce Lat..: 70.27467288 N
surface Long.: 148.32427208 W
LOCATIONS - ALASKA Zone: 4
Legal Description X-Coord Y-Coord
Surface ...... : 1155 FSL 377 FEL S28 TllN R15E UM 707141.49 5952869.22
Tie-in/KOP...: 1940 FSL 168 FEL S21 TllN R15E UM 767169.90 5958937.11
TA/%GET (BSL).: 2482 FSL 4702 FEL S22 T11N R15E UM 707900.00 5959500.00
BHL. (ESL) .... : 3143 FSL 3282 FEL S22 TllN R15E UM 709300.00 5960200.00
PROPOSED WELL PROFILE
STATION
IDENTIFICATION
=~ ~ z .......
TIE-IN SURVEY
TO' OF WINDOW
KO__.J3RVE 8/100
K-10
Prepared ..... : 07/19/96
Vert sect az.: 65.01
KB elevation.: 57.70 ft
Mag33etic Dcln: +28.605 (E)
Scale Factor.: 0.99994874
Convergence..: +1.57744997
ANADRILL AKA-DPC
APPROVED
FOR PERMITTING
ONLY
PLAN
MEAS INCLN DIRECTION VERT-DEPTHS SECT COORDINATES-FROM STATE-PLANE TOOL DL/
DEPTH A/qGLE AZI/~ TVD SUB-S DIST WELLHEAD X Y FACE 100
9900 48.92
9995 49.11
10000 49.12
10100 41.96
10200 35.09
10300 28.72
10400 23.27
10484 19.98
10500 19.53
10600 18.58
355.54 6810 6752 2739 6065.12 N 195.46 E 707169.90 5958937.11 21L <TIE
355.44 6872 6815 2764 6136.84 N 189.80 E 707162.27 5959008.64 18L 0.21
355.44 6876 6818 2766 6140.61 N 189.50 E 707161.87 5959012.40 155R 6.21
0.45 6946 6888 ~.2793 6211.84 N 186.76 E 707157.17 5959083.53 152R 8.00
7.05 7024 6966 2823 6273.89 N 190.56 E 707159.26 5959145.66 146R 8.00
16.26 7109 7051 2854 6325.57 N:.. .200.83 E 707168.10 5959197.59 139R 8.00
29.72 7199 7141 2886 6365.85 N 217.38 E 707183.53 5959238.32 127R 8.00
45.64 7277 7219 2913 6390.24 N 23~.82 E 707201.30 5959263.20 l12R 8.00
49.26 . 7292 7234 2918 6393.96 N 239.87 E 707205.24 5959267.03 108R 8.00
73.76. 7387 7329 2950 6409.35 N 267.88 E 707232.81 5959283.19 85R 8.00
/zoo CURV'Z
10618 18.75
78.11 7403 7346 2956 6410.71 N 273.31 E 707238.21 5959284.70
8.00
(Anadrill (c)96 l109;uP4 3.0b.03 9:19 AM P)
DSii-09A (P4) (HA ST)
S TAT ION
IDENTIFICATION
K-5
TOP SAD / LCU
TOP ZONE 3
TOP ZONE 2C
CURVE Z7/100
ZONE 2B
TOP ZONE 2A/ROMEO
MEAS
DEPTH
11011
11615
11689
11757
11793
11800
11800
11900
11902
12000
INCLN
ANGLE
18.75
18.75
18.75
18.75
18.75
19.77
19.83
36.58
36.97
53.48
GOC 12002 53.89
TOP ZONE 1 12002 53.89
12100 70.41
12200 87.36
7" LINER POINT 12216 90.00
END 17/100 CURVE 12216
TARGET (BSL)******** 12216
TD (ESL) 13781
BASE SADLEROCHIT
90.00
90.00
90.00
(A~adrill (c) 96 1109AP4 3.0b.03 9:19 AM P)
DIRECTION
AZIMUTH
78.11
78.11
78.11
78.11
78.11
77.37
77.33
70.96
70.88
68.28
PROPOSED WELL PROFILE
VERT-DEPTHS SECT
TVD SUB-S DIST
7776 7718 3079
8348 8290 3268
8418 8360 3291
8483 8425 3313
8517 8459 3324
8523 8465 3326
8523 8465 3326
8611, 8553 3373
8613 8555 3374
8681 8624 3443
68.23 8683 8625 3445
68.23 8683 8625 3445
66.58 8728 8670 3531
65.22 8747 8690 3628
65.01 8748 8690 3644
COORDINATES-FROM
WE~
6436.76 N 397.01 E
6476.77 N 587.00 E
6481.67 N 610.25 E
6486.21 N 631.84 E
6488.60 N 643.18 E
65.01 8748 8690 3644
65.01 8748 8690 3644
65.01 8748 8690 5209
8753 8695
6489.04 N 645.18
6489.06 N 645.29
6502.60 N 690.33
6503.05 N 691.64
6527.37 N 756.31
6528.09 N 758.12
6528.09 N 758.12
6561.21 N 837.46
6601.17 N 926.69
6607.72 N 940.81
6607.72 N 940.81 E
6607.72 N 940.81 E
7268.95 N 2359.63 E
07/19/96
Page
STATE-PLANE
X Y
707361.13 5959314.14
707549.94 5959359.36
707573.05 5959364.90
707594.50 5959370.04
707605.78 5959372.74
707607.76 5959373.22
707607.87 $959373.25
707652.52 5959388.03
707653.82 5959388.52
707717.79 5959414.60
707719.57 5959415.38
707719.57 5959415.38
707797.97 5959450.67
707886.06 5959493.06
707900.00 5959500.00
707900.00 5959500.00
707900.00 5959500.00
709300.00 5960200.00
ANADRILL
~r.- ~z.
AKA-DPC
APPROVED
FOR PERMITTING
TOOL DL/
FACE 100
0.00
0.00
0.00
0.00
14L 0.00
13L 17.00
13L 17.00
7L 17.00
7L 17.00
5L 17.00
5L 17.00
5L 17.00
5L 17.00
4L 17.00
17.00
17.00
17.00
0.00
~3
O
l-lC-g6 0g:58 Anadriy]l DPC gO7'~ 44 2160 P.06
SHARED SEFIV ICES OR ILL ING
<~>o -, DSli-OgA (P4) (HA ST)
VERTICAL SECTION VIEW
500 Section at: 65.01
'TVD Scale · I inch = lO00 feet
_ Dep Scale.' I inch = lO00 feet
tO00
Drawn ..... '07/19/96
:1500 ' '
AnadrJ 11 Schlumberger
i ii lllll iii
Marker IUen'tification MO BKB SECTN INCLN
2000 A) HE-IN SURVEY ggo0 6B10 2739 48.92
% ·
2500 ~ O) END 8/tO0 CURVE S06~8 7403 2956 ~8.75
~ E) CURVE $7/~00 ~1793 8517 3324 ]8.75
,~ F) 7' LINER POINT 12216 8748 3644 go.o0
, G) END 17/lO0 CURVE 12216 8748 3644 ~.00
3000 ,-. \ "' H) TARGEI (BSL)m*mMM*** 1221~ 8748 3644 90.00
~ I) TO (ESL) 1378! 8748 5209 90.00
3500 '"" ' ' I ' J ..........
4000
', ANA DRILL AKA-[~PC
·
~5oo,, ~.~t)v~m'
',, FORPER/~AITTING
sooo',--,, - ~, ................ '%. ¢lhJl_. .._~¥
.
-- mi ! ii _ ,
5500 =
·
\
·
6000 ' ' ' \,. .......
6500 \
%
7000 ' ~ -~,
7500~- , \ · ,
'.~-'~nd............................ -- .............
BO00 ,,
8~oo 3~2~-~ ~-- :E_: .~-"'-:: ...... - ........
._ ___ - .......
"~ ' ~': :--- : .......... :: ;-' :r;;-- ~.~ ~ ._:
t e~ ' ~, ........
F I
9000- · ,,,
o 5oo ~ooo · 500 2o00 2~--~o 30oo 3500 400,' 4500 5000 5500 6000 6500
.) Section Oeparture
1-19-96 09:59 Anadr~..]l DPC 907 44 2160 P.08
SHARED SERV ICES DR I LC ING
Marker Identification 14D N/S E/W
A) TIE-IN D~qVEY ggo0 6065 N t95 E ~
8} TOP O~ WINOON 9995 6t37 N 190
E
C) K~ C~VE 8/100 10000 6t41 N ~ E
O} E~ 8/~ C~VE ~OB~B 64~$ N 273
E
E) C~ $7/~00 ~1793 6489 N 643 E
F] 7' LIaR POINT 12256 ~OB N g45 E
G} E~ ~7/~ CURVE 122~6 6608 N 94t E
H) TA~T (B~}mm~m 12216 6~8 N g4t E
I) TD {E~} 1378~ 7269 N 23~ E
·im mmllllm m m m i
DS~-OgA (P4) (HA ST)
PLAN VlEN
....
CLOSURE ..... : 7642 feet at Azimuth ~7.98
DECLINATION.: +28.605 (E]
SCALE ....... : 1 inch = 1500 feet
DRAWN ....... : 07/19/9§
i mm
Anadri l] Schlumberger
mm
_ _
.
STATE OF ALASKA
ALASKA Olu AND GAS CONSERVATION COMM:SSION
APPLICATION FOR SUNDRY APPROVAL
1. Type of Request: [] Abandon
.
[] Suspend [] Plugging [] Time Extension [] Perforate
[] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other
[] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack
Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB)
ARCO Alaska Inc. I [] Development RKB = 58'
[] Exploratory 7. Unit or Property Name
Address [] Stratigraphic Prudhoe Bay Unit
P.O. Box 196612, Anchorage, Alaska 99519-6612 []Service
Location of well at surface
1155' NSL, 377' WEL, SEC'. 28, T11N,'-R15E
At top of productive interval '-
1673' SNL, 263' WEL, SEC. 21, T11N, R15E
At effective depth
At tot_al depth
1378' SNL, 246' WEL, SEC. 22, T11N, R15E
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
12740 feet
8808 feet
12643 feet
8725 feet
Casing
Length Size
Structural
Conductor 110'
Surface 2449'
Intermediate
Production 12101'
Liner 831'
Plugs (measured)
Junk (measured)
Cemented
8. Well Number
11-09
9. Permit Number
85-167
10. APl Number
50-029-21402
11. Field and Pool
Prudhoe Bay Field / Prudhoe Bay
Pool
)UPLiCATE
20" 2000 sx Poleset 110' 110'
13-3/8" 2500 sx PF 'E', 50O sx PF 'C', 100 sx PF 'C' 2507' 2507'
9-5/8" 600 sx Class 'G' 12159' 8312'
7" 375 sx Class 'G' 12736' 8803'
REC !V D
Perforation depth: measured 12594'- 12614', 12618'- 12638'
JUL 2 5 i998
true vertical 8683' - 8700', 8704' - 8721' Naska 0il & Gas Cons. Co,~rn,~ss~on
Tubing (size, grade, and measured depth) 5-1/2', 17#, L-80 at 11859'; 4-1/2", 12.6, L-80 tail at 11965'
Packers and SSSV (type and measured depth) Camco BaI-O SSSV at 2187'; BOT HB Packer at 11864'
13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch
14. Estimated date for commencing operation
July 23, 1996
16. If proposal was verbally approved
15. Status of well classifications,as:
[] Oil [] Gas [] Suspended
Service
Name of approver Date approved
Contact Engineer Name/Number: Zelijko Runje, 564-4825 Prepared By Name/Number Terrie Hubble, 564-4628
17. ! hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ~f¢..~ ~(~
Terry Jordan , Title Senior Drilling Engineer
Commission Use Only
Conditions of Approval: Notify Commission so representative may witness
Plug integrity_ BOP Test__ Location clearance __
Mechanical Integrity Test__ Subsequent form required 10-
Date
IApproval No. C~ ~,..
Approved by order of the Commission
Commissioner Date
Form 10-403 Rev. 06/15/88 Submit In Triplicate
· WELL PERMIT CHECKLIST COMPAN _, ..' ' WELL NAM PROGRAa:expn d ,red - rvnwellboreseg F-lann. disposaiparareq []
FIELD&POOL~/~ ~./~ INIT CLASS/~,/' /~ ? ~OL AR~ ~~ UN'T~ Ii ~~ O~OFF SHORE ~ ~
ADMiNisTRATiON
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
Permit fee attached ......................
Lease number appropriate ..................
Unique well name and number ................
Well located in a defined pool .................
Well located proper distance from ddg unit boundary ....
Well located proper distance from other wells ........
Sufficient acreage available in drilling unit. ..........
If deviated, is wellbore plat included .............
Operator only affected party ..................
Operator has appropriate bond in force ............
Permit can be issued without conservation order .....
Permit can be issued without administrative approval ....
Can permit be approved before 15-day wait. ........
ENGINEERING
REMARKS
APPR DD. D. D~
GEOLOGY
14. Conductor string provided ................... Y N'~ , _p_
15. Surface casing protects ail known USDWs .......... Y IV-/ r ~-
16. CMT vol adequate to circulate on conductor & surf cog .... Y N)
17. CMT vol adequate to tie-in long string to surf csg ...... .~.% N/. __
18. CMl' will cover all known productive horizons ......... ~,,~N
19. Casing designs adequate for C, T, B & permafrost ..... (.~N . __
20. Adequate tankage or reserve pit ................ Y~N -
21. If a re-drill, has a 10-403 for abndnmnt been approved .... ~::~ N ~ ~_,2_~'J--¢/ "' (~,~-
22. Adequate wellbore separation proposed ............ r,,~N
23. If diverter required, is it adequate ................ ~
24. Ddlling fluid program schematic & equip list adequate .... ~ N
25. BOPEs adequate ........................ t,,,~ N
26. BOPE press rating adequate; test to :~-~-~-~-~-~-~-~-~-(.~O'C) psig.,~ N
27. Choke manifold complies w/APl RP-53 (May 84) ...... f~ U ~ ~
28. Work will occur without operaUon shutdown .......... ~r~ N
29. Is presence of H2S gas probable .............. ~ N
30. Permit can be issued w/o hydrogen sulfide measures .... Y N ///.~9 ~ Z~
31. Data presented on potential overpressure zones ....... ~ //~,,,,(~¢--j ,
32. Seismic analysis of shailow gas zones .............
33. Seabed condition survey (if off-shore) ............ N
34. Contact name/phone for weekly progress report~, ,.....//.. Y N lexp~o~tary on~y] ~
ENGINEERING: COMMISSION:
B EW~/'~-.~/9~, DWJ~
JDH ~_3r.4'~- JDN
Comments/Instructions:
c)
o
I-3
,.
HOW4~- A:~FOR~list rev 4/96
Well HistorY File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simp!ify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
Sperry-~n Drilling Services
LIS Scan Utility
Non Mar 24 14:58:11 1997
Reel Header
Service name ............. LISTPE
Date ..................... 97/03/24
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Previous Reel Name ....... UNKNOWN
Comments ................. STS LIS Writing Library. Scientific Technical
Services
Tape Header
Service name ............. LISTPE
Date ..................... 97/03/24
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Previous Tape Name ....... UNKNOWN
Comments ................. STS LIS Writing Library. Scientific Technical
Services
Physical EOF
Comment Record
TAPE HEADER
PRUDHOE BAY UNIT
MWD/MAD LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 2
AK-MW-60111
RAY FRENCH
G.W. CRAIG
DS 11-094
500292140201
ARCO .ALASKA~ INC.
SPERRY-SUN DRILLING SERVICES
24-MAR-97
MWD RUN 3
AK-MW-60111
ERIC CRIBBS
G.W. CRAIG
MWD RUN 4
AK-MW-60111
ERIC CRIBBS
G,W. CRAIG
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
MWD RUN 6
AK-MW-60111
ERIC CRIBBS
G,W. CRAIG
MWD RUN 7
AK-MW-60111
RAY FRENCH
G.W. CRAIG
28
llN
15E
1155
377
MICROFILMED
53.10
51.70
· GROUN'D LEVEL:
WELL CASING RECORD
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
REMARKS:
22.80
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
9.625 6829.0
8.500 7.000 11790.0
6.000 13329.0
1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
NOTED.
2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED.
3. MWD RUNS 2 THROUGH 4 ARE DIRECTIONAL WITH
SCINTILLATION TYPE GAMMA
RAY (6 3/4").
4. NO FOOTAGE WAS ACCOMPLISHED ON MWD RUN 5.
5. MWD RUNS 6 AND 7 ARE DIRECTIONAL WITH SCINTILLATION
TYPE GAMMA
RAY (4 3/4").
6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13329'MD,
8715'TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRD = SMOOTHED GAMMA RAY.
$
File Header
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/03/24
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.000
Comment Record
FILE HEADER
FILE NUMBER: 1
EDITED MERGED MWD
Depth shifted and clipped curves; all bit runs merged.
DEPTH INCREMENT: .5000
FILE SUMMARY
PBU TOOL CODE START DEPTH STOP DEPTH
GR 7659.5 13275.5
ROP 7739.5 13327.5
$
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH GR
7657.0 7659.5
10190.0 10192.5
10245.5 10256.0
10279.5 10287.0
10281.5 10289.0
10324.0 10334.0
10327.5 10339.5
10334.0 10344.5
10340.0 10347.5
10341,5 10351.5
10352.0 10360.0
10367.5 10377.5
EQUIVALENT UNSHIFTED DEPTH
10~72.0'
10377.0
10387.0
10396.0
10406.0
10490.0
10508.5
10612.0
10635.0
10638.5
10661.0
10664.5
10688 5
10689 5
10692 5
10700 0
10721 0
10722 5
10740.0
10742 0
10765 5
10767 5
10769 5
10783 0
10785 0
10795.5
10797.0
10829.5
10839.0
10846.5
10848.0
10851.0
10853 0
10893 5
10900 5
10901 5
10905 5
10909 0
10913 0
10916 0
10919 5
10943 5
10946 0
10973 5
10975 5
10979 0
10983 0
11112 5
11126 5
11137 0
11139 5
11146 0
11167 5
11171 5
11174.0
11308.5
11309.5
11322.5
11324.5
11337.5
11338.5
11354.5
11361.5
11365.5
~383 0
10388 5
10397 5
10406 5
10416 5
10498 0
10519 0
10623 0
10644 5
10647 5
10672 0
10675 5
10698 5
10701 0
10704 5
10712.0
10731.5
10733.0
10748.5
10751.5
10774.0
10775.5
10778.0
10794.0
10796.0
10806.0
10807.5
10837.5
10848.5
10858.0
10860.0
10862.5
10864.0
10905.0
10911.0
10912.5
10916.5
10921.0
10926.0
10930.0
10932.5
10955.0
10958.0
10986.5
10987.5
10991.5
10994.5
11118.0
11133.5
11147.0
11149.5
11155.5
11179.0
11184.0
11188.5
11312.5
11313.5
11327.5
11330.0
11345.0
11346.0
11362.5
11366.0
11370.5
iif78.5
11381 0
11408 0
11410 5
11434 0
11438 0
11452 5
11458 0
11460 0
11532 5
11535 0
11554.0
11579.5
11605.0
11608.5
11613.0
11616.0
11620.5
13328.5
$
i.383.0
11385.0
11418.0
11420.0
11440.0
11444.0
11459.0
11464.5
11466.0
11530.0
11532.0
11550.5
11575.5
11601.0
11607.0
11611.0
11615.0
11619.5
13327.5
MERGED DATA SOURCE
PBU TOOL CODE BIT RUN NO
MWD 2
MWD 3
MWD 4
MWD 6
MWD 7
$
REMARKS: MERGED MAIN PASS.
$
MERGE TOP MERGE BASE
7737.0 11310.0
11310.0 11474.0
11474.0 11789.0
11789.0 12534.0
12534.0 13329.0
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ....... ' .... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD FT/H 4 1 68 4 2
GR MWD AAPI 4 1 68 8 3
First
Name Min Max Mean Nsam Reading
DEPT 7659.5 13327.5 10493.5 11337 7659.5
ROP 6.23 3281.1 100.809 11177 7739.5
GR 20.17 276.04 70.5115 11233 7659.5
Last
Reading
13327.5
13327.5
13275.5
First Reading For Entire File .......... 7659.5
Last Reading For Entire File ........... 13327.5
File Trailer
Service 'name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/03/24
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.002
Physical EOF
File Header
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/03/24
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.001
Comment Record
FILE HEADER
FILE NUMBER: 2
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 2
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
GR 7657.0
ROP 7737.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
NGP NATURAL GAMMA PROBE
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
STOP DEPTH
11251.0
11309.5
26-AUG-96
MSC 1.32
DEP 2.041/2.042
MEMORY
11310.0
7737.0
11310.0
34.9
39.6
TOOL NUMBER
NGP 156
8.500
8.5
KCL/Polymer
9.90
51.0
9.8
26500
FLUID' LOSS (C3) :
RESISTIVITY (OHMM)AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
6.8
.000
.000
.000
.000
146.0
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
.6
REMARKS:
OBJECTIVE: Drill tangent down to build section.
RESULTS: PDC bit drilled to bottom of tangent section at
11310' MD.
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 2 AAPI 4 1 68 4 2
ROP MWD 2 FT/H 4 1 68 8 3
First
Name Min Max Mean Nsam Reading
DEPT 7657 11309.5 9483.25 7306 7657
GR 24.26 1360.51 86.4182 7137 7657
ROP 6.23 3281.1 113.133 7146 7737
Last
Reading
11309.5
11251
11309.5
First Reading For Entire File .......... 7657
Last Reading For Entire File ........... 11309.5
File Trailer
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/03/24
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.003
PhysiCal EO'F
File Header
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/03/24
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER: 3
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 3
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
GR 11254.0
ROP 11311.5
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
STOP DEPTH
11416.5
11474.0
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
NGP NATURAL GAMMA PROBE
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT) :
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM) :
FLUID LOSS (C3) :
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
27-AUG-96
MSC 1.32
DEP 2.041/2.042
MEMORY
11474.0
11310.0
11474.0
40,7
53,4
TOOL NUMBER
NGP 53
8.500
8.5
KCL/Polymer
9.90
58.0
9.2
26000
6.5
.000
.000
.000
.000
129.0
HOLE CORRECTION ~£N):
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
REMARKS:
,6
OBJECTIVE: Drill the entire build section to casing
point,
RESULTS: The 2.0 degree motor was not aggressive enough,
POOH for the motor at 11474' MD.
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point ........... .,,,Undefined
Frame Spacing ..................... 60 ,liN
Max frames per record ............. Undefined
Absent value ...................... -999,25
Depth Units .......................
Datum Specification Block sub-type,,,0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 3 AAPI 4 1 68 4 2
ROP MWD 3 FT/H 4 1 68 8 3
First
Name Min Max Mean Nsam Reading
DEPT 11254 11474 11364 441 11254
GR 26.43 276.04 54.2365 326 11254
ROP 21.67 202.62 71.6714 326 11311.5
Last
Reading
11474
11416,5
11474
First Reading For Entire File .......... 11254
Last Reading For Entire File ........... 11474
File Trailer
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/03/24
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.004
Physical EOF
File Header
Service name ............. STSLIB.004
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/03/24
Maximum Physical Record..65535
File Type ................ LO
Previous' File Name ....... STSLIB.003
Comment Record
FILE HEADER
FILE NUMBER: 4
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 4
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
GR 11413.5
ROP 11472.0
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
STOP DEPTH
11732.5
11789.0
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
NGP NATURAL GAMMA PROBE
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT) :
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN) :
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
REMARKS:
28-AUG- 96
MSC 1.32
DEP 2.041/2.042
MEMORY
11789.0
11474.0
11789.0
56.6
82.3
TOOL NUMBER
NGP 156
8.500
8.5
KCL/Polymer
10.00
51.0
8.6
27500
6.5
.000
.000
.000
.000
133.2
.6
OBJECTIVE: Drill the remaining build section to casing
point
RESULTS: With a 2.5 degree motor, the necessary build
rates
were achieved to casing point at a measured depth
of 11789'.
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 t 68 0 1
GR MWD 4 AAPI 4 1 68 4 2
ROP MWD 4 FT/H 4 1 68 8 3
First
Name Min Max Mean Nsam Reading
DEPT 11413.5 11789 11601.2 752 11413.5
GR 22.74 79.36 38.3282 639 11413.5
ROP 14.25 301.67 61.9491 635 11472
Last
Reading
11789
11732.5
11789
First Reading For Entire File .......... 11413.5
Last Reading For Entire File ........... 11789
File Trailer
Service name ............. STSLIB.004
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/03/24
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.005
Physical EOF
File Header
Service name ............. STSLIB.005
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/03/24
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.004
Comment Record
FILE HEADER
FILE NUMBER: 5
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 6
DEPTH INCREMENT: .5 0 0 0
FILE S~RY
VENDOR TOOL CODE START DEPTH
GR 11604.5
ROP 11651.5
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
STOP DEPTH
12484.5
12533.5
04-SEP-96
MSC 1.32
DEP 2.041/2.042
MEMORY
12534.0
11789.0
12534.0
89.3
93.9
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
NGP NATURAL GAMMA PROBE
$
TOOL NUMBER
NGP 156
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT) :
6.000
6.0
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
MUD CHLORIDES (PPM) :
FLUID LOSS (C3) :
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
Sheardril
8.90
47.0
8.5
32000
5.4
.000
.000
.000
.000
133.2
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN) :
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
.6
REMARKS:
OBJECTIVE: Drill cement and out of shoe horizontally.
RESULTS: Drilled cement and out of shoe. Drilled
lateral section down to 12534' MD. POOH.
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical ~log depth u~zts ........... Feet
Data Reference Point .............. Undefined
Frame Spacing.. .................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 6 AAPI 4 1 68 4 2
ROP MWD 6 FT/H 4 1 68 8 3
First
Name Min Max Mean Nsam Reading
DEPT 11604.5 12533.5 12069 1859 11604.5
GR 24.28 88.36 41.3777 1761 11604.5
ROP 1.98 3435.03 1,09.401 1765 11651.5
Last
Reading
12533.5
12484.5
12533.5
First Reading For Entire File .......... 11604.5
Last Reading For Entire File ........... 12533.5
File Trailer
Service name ............. STSLIB.005
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/03/24
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.006
Physical EOF
File Header
Service name ............. STSLIB.006
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/03/24
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.005
Comment Record
FILE HEADER
FILE NUMBER: 6
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 7
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE
GR
ROP
$
LOG HEADER DATA
DATE LOGGED:
START DEPTH STOP DEPTH
12482.5 13276.5
12535.5 13328.5
05-SEP-96
SO~TWAR~
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
MSC 1.32
DEP 2.041/2.042
MEMORY
13329.0
12534.0
13329.0
89.2
93.5
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
NGP NATURAL GAMMA PROBE
$
TOOL NUMBER
NGP 53
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT) :.
6.000
6.0
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM)AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
Sheardril
9.00
51.0
8.6
8500
5.3
.000
.000
.000
.000
133.2
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
.6
REMARKS:
OBJECTIVE: Continue drilling horizontal section to TD.
RESULTS: Drilled lateral section to TD at 13,329 MD.
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datura Specification Block sub-type...0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR ~WD 7 " A~PI 4 1 68
ROP MWD 7 FT/H 4 1 68
Name Min Max Mean Nsam
DEPT 12482.5 13328.5 12905.5 1693
GR 20.17 80.08 43.3747 1589
ROP 20.4 281.91 70.587 1587
First
Reading
12482.5
12482.5
12535.5
Last
Reading
13328.5
13276.5
13328.5
First Reading For Entire File .......... 12482.5
Last Reading For Entire File ........... 13328.5
File Trailer
Service name ............. STSLIB.006
Service Sub Level Name...
Version Number ........... 1.0.0 -
Date of Generation ....... 97/03/24
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.007
Physical EOF
Tape Trailer
Service name ............. LISTPE
Date ..................... 97/03/24
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Next Tape Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Services
Reel Trailer
Service name ............. LISTPE
Date ..................... 97/03/24
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Next Reel Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Services
Scientific Technical
Scientific Technical
Physical EOF
Physical EOF
End Of LIS File
* ALASKA COMPUTING CENTER *
....... SCHLUMBERGER .......
COMPANY NAME : ARCO ALASKA INC.
WELL NAME : DS ll-09A
FIELD NAME : PRUDHOE BAY
BOROUGH : NORTH SLOPE
STATE : ALASKA
API~ER : 500292140201
REFERENCE NO : 96254
RECEIVED
ocr 1 1 199G
Alas~ U, ~. ,.',:;as :.;o~s, Go~'flrnJssJon
N C OFILN D
LIS Tape Verification Listing
Schlunfoerger Alaska Computing Center
16-SEP-1996 16:06
PAGE:
**** REEL HEADER ****
SERVICE NAM~ : EDIT
DATE : 96/09/16
ORIGIN : FLIC
REEL NAM~ : 96254
CONTINUATION # :
PREVIOUS REEL :
CO~ : ARCO ALASKA INC, PRUDHOE BAY, DS ll-09A, API #50-029-21402-01
**** TAPE HEADER ****
SERVICE NAME : EDIT
DATE : 96/09/16
ORIGIN : FLIC
TAPE NAlViE : 96254
CONTINUATION # : 1
PREVIOUS TAPE :
COP~IENT : ARCO ALASKA INC, PRUDHOE BAY, DS ll-09A, API #50-029-21402-01
TAPE ~ER
Prudhoe Bay
OPEN HOLE WIRELINE LOGS
WELL NAME:
API NTJM~ER :
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
ELEVATION (FT FROM MSL O)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
RUN 1
96254
E. Bartz
C. Zarndt
WELL CASING RECORD
1ST STRING
2ND STRING
DS ll-09A
500292140201
ARCO Alaska Inc.
SCHLUMBERGER WELL SERVICES
16-SEP-96
RUN 2 RUN 3
28
liN
1SE
1155
377
53.10
52.10
0.00
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN)DEPTH (FT)
8. 500 9. 625 6876.0
LIS Tape Verification Listing
Schlur~.berger Alaska Computing Center
16-SEP-1996 16:06
3RD STRING
PRODUCTION STRING
CONTAINED HEREINARE THE OPEN HOLE LOGS ON ARCO
ALASKA'S D.S. ll-09A. ALL TOOLS WERE LOGGED IN
THE SAFiE TOOL STRING ON DRILL PIPE (TOUGH LOGGING
CONDITIONS).
$
PAGE:
**** FILE HEADER ****
FILE NAME : EDIT .001
SERVICE : FLIC
VERSION : O01CO1
DATE : 96/09/16
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE H~ER
FILE~ER: 1
EDITED OPEN HOLEMAIN PASS
Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data.
DEPTH INCREMENT: 0.5000
FILE SUA94ARY
LDWG TOOL CODE
DTE
SDN
CNTG
DAS
$
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
START DEPTH STOP DEPTH
11770.0 10050.0
11718.0 10000.0
11700.0 10000.0
11740.0 10000.0
BASELINE DEPTH
$
MERGED DATA SOURCE
LDWG TOOL CODE
$
REMARKS:
.......... EQUIVALENT UNSHIFTEDDEPTH ..........
DTE SDN CNTG DAS
RUN NO. PASS NO.
MERGE TOP MERGE BASE
THIS FILE CONTAINS THE EDITTED MAIN LOG FILE THAT HAS
BEEN CLIPPED. NO DEPTH CORRECTIONS TO A BASELINE
GAMPL~RAYHAVEBEENDONE DUE TO THIS BEING THE
FIRST TOOL STRING RUN INTO THE WELLBORE. THE TOOLS
RUN IN THIS TOOL STRING ARE DTE, DAS, SDN, AND CNTG.
ALL TOOLS WERE DRILL PIPE CONVEYED.
$
LIS Tape Verification Listing
Schlurcberger Alaska Computing Center
16-SEP-1996 16:06 PAGE: 3
LIS FORMAT DATA
TABLE TYPE : CONS
TUNI VALU DEFI
CN ARCO ALASKA INC. Company Name
FN PRUDHOE BAY Field Name
WN DS ll-09A Well Name
APIN 500292140201 API Serial Number
FL 1155' FSL & 0377' FEL Field Location
SECT 28 Section
TOWN 1 iN Township
RANG 1SE Range
COUN NORTH SLOPE Court ty
STAT ALASKA State or Province
NATI USA Na ti on
WITN C. ZARNDT Wi tness Name
SON 630281 Service Order Number
PDAT SEA LEVEL Permanent datum
EPD FT O. Elevation of Permanent Datum
LMF KELLY BUSHING Log Measured From
APD FT 53.1 Above Permanent Datum
EKB FT 53.1 Elevation of Kelly Bushing
EDF FT 52.1 Elevation of Derrick Floor
EGL FT O. Elevation of Ground Level
TDD FT 11789. Total Depth - Driller
TDL FT 11780. Total Depth - Logger
BLI FT 11774. Bottom Log Interval
TLI FT 10000. Top Log Interval
DFT GEL FREE KCL Drilling Fluid Type
DFD G/C3 9.9 Drilling Fluid Density
DFPH 9. 200001 Drilling Fluid Ph
DFV S 51. Drilling Fluid Viscosity
DFL F3 5.8 Drilling Fluid Loss
RMS OH~4~ 0.16 Resistivity of Mud Sample
MST DEGF 74. Mud Sample Temperature
RMFS OH~ 0.129 Resistivity of Mud Filtrate S
MFST DEGF 58. Mud Filtrate Sample Temperatu
RMCS OH~I 0.285 Resistivity of Mud Cake Sampl
MCST DEGF 74. Mud Cake Sample Temperature
TCS 00:00 29-AUG-96 Time Circulation Stopped
TLAB 18:15 29-AUG-96 Time Logger at Bottom
BHT DEGF 196. Bottom Hole Temperature
TABLE TYPE : CURV
DEFI
DEPT Depth
IDPH Phasor Deep Resistivity
IMPH Phasor Medium Resistivity
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
16-SEP-1996 16:06
PAGE:
DEFI
ILD Deep Induction Standard Processed Resistivity
ILM Medium Induction Standard Processed Resistivity
SFL SFL Resistivity Unaveraged
SP Spontaneous Potential
DT Delta-T compressional
RHOB Bulk Density
DRHO Delta RHO
PEF Photoelectric Factor
CALl Caliper
NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr.
ENPH Epithermal Neutron Porosity
CPHI Thermal Neutron Porosity
NCNT RAW NEAR CNT COUNTS
FCNT RAW FAR CNT COUNTS
CRAT Thermal Neutron Ratio Calibrated
NRAT Raw Thermal Neutron Ratio
ENRA Epithermal Neutron Ratio Calibrated
CFEC Corrected Far Epithermal Counts
CNEC Corrected Near Epithermal Counts
CNTC Corrected Near Detector Count Rate
CFTC Corrected Far Detector Count Rate
GR API-Corrected Gamma Ray
TENS Surface Tension
TEND Head Tension
MTE~ Mud Temperature
FIRES MUD Resistivity
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE- 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 116
4 66 1
$ 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 8
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 0
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
16-SEP-1996 16:06
PAGE:
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX)
O0 000 O0 0 1 1 1 4 68 0000000000
DEPT FT 630281
IDPH DTE OPLN~4 630281 O0 000 O0 0 1 1 1 4 68 0000000000
IMPH DTE OA?4~ 630281 O0 000 O0 0 1 1 1 4 68 0000000000
ILD DTE OBl~4 630281 O0 000 O0 0 1 1 1 4 68 0000000000
ILM DTE OHP~I 630281 O0 000 O0 0 1 1 1 4 68 0000000000
SFL DTE OHMM 630281 O0 000 O0 0 1 1 1 4 68 0000000000
SP DTE MV 630281 O0 000 O0 0 1 1 1 4 68 0000000000
DT DAS US/F 630281 O0 000 O0 0 1 1 1 4 68 0000000000
RHOB SDN G/C3 630281 O0 000 O0 0 1 1 1 4 68 0000000000
DRHO SDN G/C3 630281 O0 000 O0 0 1 1 1 4 68 0000000000
PEF SDN BN/E 630281 O0 000 O0 0 1 1 1 4 68 0000000000
CALl SDN IN 630281 O0 000 O0 0 1 1 1 4 68 0000000000
NPHI CNTG PU-S 630281 O0 000 O0 0 1 1 1 4 68 0000000000
ENPH CNTG PU-S 630281 O0 000 O0 0 1 1 1 4 68 0000000000
CPHI CNTG PU-S 630281 O0 000 O0 0 1 1 1 4 68 0000000000
NCNT CNTG CPS 630281 O0 000 O0 0 1 1 1 4 68 0000000000
FCNT CNTG CPS 630281 O0 000 O0 0 1 1 1 4 68 0000000000
CRAT CNTG 630281 O0 000 O0 0 1 1 1 4 68 0000000000
NRAT CNTG 630281 O0 000 O0 0 1 1 1 4 68 0000000000
ENRA CNTG 630281 O0 000 O0 0 1 1 1 4 68 0000000000
CFEC CNTG CPS 630281 O0 000 O0 0 1 1 1 4 68 0000000000
CNEC CNTG CPS 630281 O0 000 O0 0 1 1 1 4 68 0000000000
CNTC CNTG CPS 630281 O0 000 O0 0 1 1 1 4 68 0000000000
CFTC CNTG CPS 630281 O0 000 O0 0 1 1 1 4 68 0000000000
GR DTE GAPI 630281 O0 000 O0 0 1 1 1 4 68 0000000000
TENS DTE LB 630281 O0 000 O0 0 1 1 1 4 68 0000000000
TEND DTE LB 630281 O0 000 O0 0 1 1 1 4 68 0000000000
MTE~IDTE DEGF 630281 O0 000 O0 0 1 1 1 4 68 0000000000
MRES DTE 0H~4~463028i O0 000 O0 0 1 1 1 4 68 0000000000
** DATA **
DEPT. 11774.000 IDPH.DTE -999.250 IMPH.DTE -999.250 ILD.DTE
ILM. DTE -999.250 SFL.DTE -999.250 SP.DTE -999.250 DT.DAS
RHOB.SDN -999.250 DRHO.SDN -999.250 PEF. SDN -999.250 CAL1.SDN
NPHI.CNTG -999.250 ENPH. CNTG -999.250 CP~II.CNTG -999.250 NCNT. CNTG
FCNT. CNTG -999.250 CRAT. ClTTG -999.250 NRAT. CNTG -999.250 ENRA.CNTG
CFEC. CNTG -999.250 CNEC. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG
GR.DTE -999.250 TENS.DTE 2777. 000 TEND.DTE 374. 145 MTEM. DTE
~RES. DTE O. 060
DEPT. 10000.000 IDPH.DTE -999.250 IMPH. DTE -999.250 ILD.DTE
ILM. DTE -999.250 SFL.DTE -999.250 SP.DTE 56.000 DT.DAS
RHOB.SDN 2.393 DRHO.SDN 0.012 PEF. SDN 3.188 CALi.SDN
NPHI. CNTG 39.876 ENPH. CNTG 30.558 CPHI.CNTG 38.289 NCNT. CNTG
FCNT. CNTG 654.950 CRAT. CNTG 3.353 ArRAT. CNTG 3.513 ENRA.CNTG
-999.250
-999.250
-999.250
-999.250
-999.250
-999.250
163.756
-999.250
96.700
8.928
2240.234
4.812
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
16-SEP-1996 16:06
PAGE:
CFEC. CNTG 621.772 CNEC. CNTG
GR.DTE 83.476 TENS.DTE
MRES.DTE 0.074
2991.775 CNTC. CNTG 2068.470 CFTC. CNTG 638.544
1020.000 TEND.DTE 1212.744 MTEM. DTE 136.635
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .001
SERVICE : FLIC
VERSION : O01CO1
DATE : 96/09/16
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .002
SERVICE : FLIC
VERSION : O01CO1
DATE : 96/09/16
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
RUN NUMBER:
TOOL STRINGIER:
PASS NUMBER:
DEPTH INCREMEJVT:
FILE SU~9~ARY
FILE HEADER
FILE NUMBER 2
RAW OPEN HOLEREP~T PASSES
Curves and log header data for each run and tool string in separate files; Tool String #1 fo
Sadlerochit run presented first (primary depth control string used to depth shift the Sadler
interval) followed by files for other main pass tool strings per run.
1
1
1
0.5000
VENDOR TOOL CODE START DEPTH STOP DEPTH
DITE 11774.0 10000.0
LDT 11718.0 10000.0
CNTG 11718.0 10000.0
SDT 11743.0 10000.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE VERSION:
TIME CIRCULATION ENDED:
29-AUG-96
OP 8B0-430
0000 29-AUG-96
LIS Tape Verification Listing
Schlumberger ~_~laska Computing Center
16-SEP-1996 16:06
PAGE:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT) :
TD LOGGER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
LOGGING SPEED (FPHR) :
1815 29-AUG-96
11789.0
11780.0
10000.0
11774.0
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DITE RESISTIVITY CART. DIC-EB 271
DITE RESISTIVITY SONDE DIS-HB 261
SDT SONIC CARTRIDGE SDC-CB 1483
SDT ARRAY SONIC SONDE SLS-WA 1427
LDT DENSITY CART. NSC-E 907
LDT DENSITY SONDE DRS-C 2984
CNTG NEUTRON CART. CNC-GA 63
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT) :
LOGGERS CASING DEPTH (FT) :
8.500
6876.0
6876.0
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
FLUID LOSS (C3):
MAXIMUM RECORDED TENPERATURE (DEGF) :
RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) :
MUD AT MEASURED TEMPERATURE (MT):
MUD AT BOTTOM HOLE TEMPERATURE (BHT):
MUD FILTRATE AT (MT):
MUD FILTRATE AT (BHT) :
MUD CAKE AT (MT):
MUD CAKE AT (BHT):
Gel Free KCL
9.90
51.0
9.2
196.0
O. 160 74.0
O. 129 58.0
O. 285 74.0
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
EPI THERMAL
SANDSTONE
2.65
8.500
TOOL STANDOFF (IN):
0.5
Ail logs run on drill pipe -Tough Logging Conditions.
Four knuckle joints & two "rollovers" run in string.
Six 1.5" standoffs run on Phasor Induction.
Repeat sect. depth not correct due to TLC.
Phasor is anomalous in high resistivities due to high
resistivity formation & conductive mud. RM=.16 @74 deg
beyond limits of tool.
Sandstone matrix 2.65 g/cc used for all porosity
LIS Tape Verification Listing
Schlumberger A-laska Computing Center
16-SEP-1996 16:06
PAGE:
computations.
This file contains the raw repeat data.
$
LIS FORMAT DATA
TABLE TYPE : CONS
TUNI VALU DEFI
CN ARCO ALASKA INC. Company Name
FN PRUDHOE BAY Field Name
WN DS ll-09A Well Name
APIN 500292140201 API Serial Number
FL 1155' FSL & 0377' FEL Field Location
SECT 28 Section
TOWN 1 iN Township
RANG 15E Range
COUN NORTH SLOPE County
STAT ALASKA State or Province
NATI USA Na ti on
WITN C. ZARNDT Wi tness Name
SON 630281 Service Order Number
PDAT SEA LEVEL Permanent datum
EPD FT O. Elevation of Permanent Datum
LMF KELLY BUSHING Log Measured From
APD FT 53.1 Above Permanent Datum
EKB FT 53.1 Elevation of Kelly Bushing
EDF FT 52.1 Elevation of Derrick Floor
EGL FT O. Elevation of Ground Level
TDD FT 11789. Total Depth - Driller
TDL FT 11780. Total Depth - Logger
BLI FT 11774. Bottom Log Interval
TLI FT 10000. Top Log Interval
DFT GEL FREE KCL Drilling Fluid Type
DFD G/C3 9.9 Drilling Fluid Density
DFPH 9.200001 Drilling Fluid Ph
DFV S 51. Drilling Fluid Viscosity
DFL F3 5.8 Drilling Fluid Loss
RMS OH~M 0.16 Resistivity of Mud Sample
MST DEGF 74. Mud Sample Temperature
RMFS OPiMM 0.129 Resistivity of Mud Filtrate S
MFST DEGF 58. Mud Filtrate Sample Temperatu
RMCS OH~M 0.285 Resistivity of Mud Cake Sampl
MCST DEGF 74. Mud Cake Sample Temperature
TCS 00:00 29-AUG-96 Time Circulation Stopped
TLAB 18:15 29-AUG-96 Time Logger at Bottom
BHT DEGF 196. Bottom Hole Temperature
LIS Tape Verification Listing
Schlumberger A~aska Computing Center
16-SEP-1996 16:06
PAGE:
TABLE TYPE : CURV
DEFI
DEPT
CIDP
IDPH
CIMP
IMPH
CDER
IDER
CMER
IMER
CDVR
IDVR
CMVR
IMVR
CILD
ILD
CILM
ILM
IDQF
IMQF
IIRD
IIXD
IIRM
IIX~4
SFLU
SP
GR
TENS
MRES
HTEN
DPHI
RHOB
DRHO
PEF
QLS
QSS
LS
LU
LL
LITH
SSi
SS2
LSHV
SSHV
S1RH
LSRH
LURH
CALI
ENPH
CFEC
Dep th
INDUCTION DEEP PHASOR CONDUCTIVITY
Phasor Deep Resistivity
INDUCTION MEDIUM PHASOR CONDUCTIVITY
Phasor Medium Resistivity
DEEP INDUCTION ENHANCED RESOLUTION PHASOR CONDUCTIVITY
DEEP INDUCTION ENHANCED RESOLUTION PHASOR RESISTIVITY
MEDIUM INDUCTION ENHANCED RESOLUTION PHASOR CONDUCTIVITY
MEDIUM INDUCTION ENHANCED RESOLUTION PHASOR RESISTIVITY
DEEP INDUCTION VERY-E1VHANCED RESOLUTION PHASOR CONDUCTIVITY
DEEP INDUCTION VERY-ENHANCED RESOLUTION PHASOR RESISTIVITY
MEDIUM INDUCTION VERY-ENHANCED RESOLUTION PHASOR CONDUCTIVITY
MEDIUM INDUCTION VERY-ENHANCED RESOLUTION PHASOR RESISTIVITY
Conductivity IL Deep Standard Processed
Deep Induction Standard Processed Resistivity
Conductivity IL Medium Standard Processed
Medium Induction Standard Processed Resistivity
Induction Deep Quality Factor
Induction Medium Quality Factor
Deep Induction Real Intermediate Conductivity
Deep Induction Quad Intermediate Conductivity
Medium Induction Real Intermediate Conductivity
Medium Induction Quad Intermediate Conductivity
SFL Resistivity Unaveraged
Spontaneous Potential
API-Corrected Gamma Ray
Surface Tension
Mud Tempera ture
MUD Resistivity
Head Tension
Density Porosity
Bulk Density
Del ta RHO
Photoelectric Factor
Quality control of long spacing for LDT
Quality control on short spacing for LDT
Long Spacing Computed Count Rate (LL+LU/2)
Long Upper 1-2 Window Count Rate (LUI+LU2)
Long Lower Window Count Rate
Litholog Window Count Rate
Short Spacing 1 Window Count Rate
Short Spacing 2 Window Count Rate
Long Spacing High Voltage
Short Spacing High Voltage
Short Spacing 1 Density
Long Spacing Bulk Density
Long Upper Bulk Density
Caliper
Epithermal Neutron Porosity
Epi thermal Neutron Ratio Calibrated
Corrected Far Epithermal Counts
LIS Tape Verification Listing
Schlumberger A-laska Computing Center
16-SEP-1996 16:06
PAGE:
10
DEFI
CNEC Corrected Near Epithermal Counts
RCEF Raw Corrected Epithermal Far Counts
RCEN Raw Corrected Epithermal Near Counts
NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr.
TNPH Thermal Neutron Porosity
TNRA Thermal Neutron Ratio Calibrated
RTNR Raw Thermal Neutron Ratio
NPOR Neutron Porosity from an Application Program
RCNT RAW NEAR CNT COUNTS
RCFT RAW FAR CNT COUNTS
CNTC Corrected Near Detector Count Rate
CFTC Corrected Far Detector Count Rate
DT Delta-T compressional
TT1 TRANSIT TIME 1
TT2 TRANSIT TIME 2
TT3 TRANSIT TIME 3
TT4 TRANSIT TIME 4
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE- 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 272
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 3
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELaM CODE (HEX)
DEPT FT 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CIDP DTR l~IO 630281 O0 000 O0 0 2 1 1 4 68 0000000000
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
16-SEP-1996 16:06
PAGE: 11
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
IDPH DTR OH~I~ 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CIMP DTR I4~iHO 630281 O0 000 O0 0 2 1 1 4 68 0000000000
IMPH DTR OH~4 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CDER DTR I4MHO 630281 O0 000 O0 0 2 1 1 4 68 0000000000
IDER DTR OH~M 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CMER DTR I~4HO 630281 O0 000 O0 0 2 1 1 4 68 0000000000
IMER DTR OHMM 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CDVR DTR lzk4HO630281 O0 000 O0 0 2 1 1 4 68 0000000000
IDVR DTR OPiMM 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CMV~ DTR I~HO 630281 O0 000 O0 0 2 1 1 4 68 0000000000
IMVR DTR OH~4M 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CILD DTR MI~HO 630281 O0 000 O0 0 2 1 1 4 68 0000000000
ILD DTR OH~M 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CILM DTR I~4~0 630281 O0 000 O0 0 2 1 1 4 68 0000000000
ILM DTR OI4~M 630281 O0 000 O0 0 2 1 1 4 68 0000000000
IDQF DTR 630281 O0 000 O0 0 2 1 1 4 68 0000000000
IMQF DTR 630281 O0 000 O0 0 2 1 1 4 68 0000000000
IIRD DTR I~4}~0630281 O0 000 O0 0 2 1 1 4 68 0000000000
IIYiD DTR I¢k4~0630281 O0 000 O0 0 2 1 1 4 68 0000000000
IIRM DTR I~IHO 630281 O0 000 O0 0 2 1 1 4 68 0000000000
IIX~ DTR Iv~IHO630281 O0 000 O0 0 2 1 1 4 68 0000000000
SFLU DTR OHlV~l630281 O0 000 O0 0 2 1 1 4 68 0000000000
SP DTR MV 630281 O0 000 O0 0 2 1 1 4 68 0000000000
GR DTR GAPI 630281 O0 000 O0 0 2 1 1 4 68 0000000000
TENS DTR LB 630281 O0 000 O0 0 2 1 1 4 68 0000000000
MTEM DTR DEGF 630281 O0 000 O0 0 2 1 1 4 68 0000000000
I4RES DTR OH~4 630281 O0 000 O0 0 2 1 1 4 68 0000000000
HTEN DTR LB 630281 O0 000 O0 0 2 1 1 4 68 0000000000
DPHI LDR PU 630281 O0 000 O0 0 2 1 1 4 68 0000000000
RHOB LDR G/C3 630281 O0 000 O0 0 2 1 1 4 68 0000000000
DRHO LDR G/C3 630281 O0 000 O0 0 2 1 1 4 68 0000000000
PEF LDR 630281 O0 000 O0 0 2 1 1 4 68 0000000000
QLS LDR 630281 O0 000 O0 0 2 1 1 4 68 0000000000
QSS LDR 630281 O0 000 O0 0 2 1 1 4 68 0000000000
LS LDR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
LU LDR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
LL LDR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
LITH LDR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
SSi LDR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
SS2 LDR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
LSHV LDR V 630281 O0 000 O0 0 2 1 1 4 68 0000000000
SSHV LDR V 630281 O0 000 O0 0 2 1 1 4 68 0000000000
S1RH LDR G/C3 630281 O0 000 O0 0 2 1 1 4 68 0000000000
LSRII LDR G/C3 630281 O0 000 O0 0 2 1 1 4 68 0000000000
LURH LDR G/C3 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CALI LDR IN 630281 O0 000 O0 0 2 1 1 4 68 0000000000
ENPH CNR PU 630281 O0 000 O0 0 2 1 1 4 68 0000000000
ENRA CNR 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CFEC CNR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CNEC CNR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
RCEF CNR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
16-SEP-1996 16:06
PAGE:
12
NAME SERVUNIT SERVICE API API API API FILE NUMB NOY~ SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX)
RCEN CNR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
NPHI CNR PU 630281 O0 000 O0 0 2 1 1 4 68 0000000000
TNPH CNR PU 630281 O0 000 O0 0 2 1 1 4 68 0000000000
TNRA CNR 630281 O0 000 O0 0 2 1 1 4 68 0000000000
RTNR CNR 630281 O0 000 O0 0 2 1 1 4 68 0000000000
NPOR CNR PU 630281 O0 000 O0 0 2 1 1 4 68 0000000000
RCNT CNR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
RCFT CNR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CNTC CNR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
CFTC CNR CPS 630281 O0 000 O0 0 2 1 1 4 68 0000000000
DT SDR US/F 630281 O0 000 O0 0 2 1 1 4 68 0000000000
TT1 SDR US 630281 O0 000 O0 0 2 1 1 4 68 0000000000
TT2 SDR US 630281 O0 000 O0 0 2 1 1 4 68 0000000000
TT3 SDR US 630281 O0 000 O0 0 2 1 1 4 68 0000000000
TT4 SDR US 630281 O0 000 O0 0 2 1 1 4 68 0000000000
** DATA **
DEPT.
IMPH. DTR
IMER . DTR
IMVR . DTR
I LM. DTR
I IXD . DTR
S P . D TR
MRES. DTR
DRHO. LDR
LS. LDR
SSI. LDR
S1RH . LDR
ENPH. CNR
RCEF. CNR
TNRAo CNR
RCFT. CNR
TT1. SDR
DEPT.
IMPH. DTR
IMER . DTR
IMVR . DTR
ILM. DTR
I IXD . DTR
S P . DTR
MRES . DTR
DRHO. LDR
LS. LDR
SSi. LDR
S1RH . LD R
ENPH. CNR
11678.500
1950 000
1950 000
1950 000
38 758
-0 017
0 000
0 060
0 127
340. 864
279. 943
2.181
24. 840
842. 825
2. 629
989. 438
501. 000
10936. 500
5. 811
5. 812
5. 811
5. 738
15. 149
28. 625
O. 068
O. 012
344. 453
248. 714
2.307
36.286
CIDP.DTR -0. 934 IDPH. DTR 1950. 000 CIMP.DTR
CDER.DTR -7.570 IDER.DTR 1950.000 CMER.DTR
CDVR.DTR -10. 577 IDVR.DTR 1950. 000 CMVR.DTR
CILD.DTR 2. 592 ILD.DTR 385. 772 CILM. DTR
IDQF.DTR O. 000 IMQF.DTR O. 000 IIRD.DTR
IIRM. DTR 26.127 II~.DTR 4. 368 SFLU.DTR
GR.DTR 65. 029 TENS.DTR 1050. 000 MTEM. DTR
HTEN. DTR -2066.961 DPHI.LDR 5.313 RHOB.LDR
PEF. LDR 9. 481 QLS.LDR -0. 029 QSS.LDR
LU. LDR 326.960 LL.LDR 177.384 LITH.LDR
SS2.LDR 312. 960 LSHV. LDR 1632. 891 SSHV. LDR
LSRH. LDR 2. 434 LURH. LDR 2. 450 CALI.LDR
ENRA. CNR 3.888 CFEC. CNR 954.134 CNEC. CNR
RCEN. ClVR 31 O1. 708 NPHI. CNR 33. 775 TNPH. CNR
R TNR. CNR 2.657 NPOR. CN-R 31 . 337 R CNT. CNR
CNTC. Clv-R 2703. 417 CFTC. Clv-R 1005. 908 DT. SDR
TT2.SDR 355.600 TT3.SDR 508.800 TT4.SDR
CIDP.DTR 173. 406 IDPH.DTR 5.767 CIMP.DTR
CDER.DTR 173 . 258 IDER.DTR 5. 772 CMER.DTR
CDVR.DTR 173 . 510 IDVR.DTR 5. 763 CMVR.DTR
CILD.DTR 174. 889 ILD.DTR 5. 718 CILM. DTR
IDQF.DTR O. 000 IMQF.DTR O. 000 IIRD.DTR
IIRM. DTR 164. 160 IIX~.DTR 12. 792 SFLU. DTR
GR. DTR 302. 751 TENS. DTR 726.000 MTEM. DTR
HTEN. DTR 617.315 DPHI.LDR 17.195 RHOB.LDR
PEF. LDR 4. 065 QLS.LDR -0. 031 QSS.LDR
LU. LDR 330.568 LL.LDR 179.169 LITH.LDR
SS2.LDR 314. 734 LSHV. LDR 1631. 585 SSHV. LDR
LSRH. LDR 2.353 LURH. LDR 2.356 CALI.LDR
ENRA. CNR 5. 059 CFEC. CNR 566.614 CNEC. CNR
-0.253
-3.796
-6.780
25.801
-11.430
354.974
163.209
2.562
0.114
55.184
1664.015
2.835
3709.233
29.972
2831.889
77.900
350.400
172. 098
172. 070
172. 076
174. 265
152. 500
6.840
147. 718
2.366
O. 035
87.516
1657. 301
2. 834
2866. 313
LIS Tape Verification Listing
Schlumk~ger Alaska Computing Center
16-SEP-1996 16:06
PAGE: 13
RCEF. CNR 546.267 RCEN. CNR
TNRA. CN-R 3.447 RTNR.CNR
RCFT. CNR 505.606 CNTC. CNR
TT1.SDR -999.250 TT2.SDR
2539.560 NPHI.CNR
3.591 NPOR.CNR
1738.631 CFTC. CNR
-999.250 TT3.SDR
48.750 TNPH. CNR
44.662 RCNT. CNR
505.951 DT.SDR
-999.250 TT4.SDR
41.739
1777.189
96.300
-999.250
** END OF DATA **
**** FILE TRAILER ****
FILE NA~IE : EDIT .002
SERVICE : FLIC
VERSION : O01CO1
DATE : 96/09/16
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** TAPE TRAILER ****
SERVICE NAME : EDIT
DATE : 96/09/16
ORIGIN : FLIC
TAPE NAME : 96254
CONTINUATION # : 1
PREVIOUS TAPE :
COI~4ENT : ARCO ALASKA INC, PRUDHOE BAY, DS ll-09A, API #50-029-21402-01
**** REEL TRAILER ****
SERVICE NAME : EDIT
DATE : 96/09/16
ORIGIN : FLIC
REEL NAME : 96254
CONTINUATION # :
PRBVIOUSREEL :
COI~IENT : ARCO ALASKA INC, PRUDHOE BAY, DS ll-09A, API #50-029-21402-01
