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Home My WebLink About203-149By Grace Christianson at 2:55 pm, May 15, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.05.15 14:21:49 - 08'00' Sean McLaughlin (4311) 325-307 JJL 6/2/25 10-407 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parentwell contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. A.Dewhurst 02JUN25 DSR-6/3/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.04 08:54:37 -08'00' 06/04/25 RBDMS JSB 060525 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: May 15, 2025 Re:F-06B Sundry Request Sundry approval is requested to set a whipstock in the F-06A wellbore as part of the drilling and completion of the proposed F-06B CTD lateral. Proposed plan for F-06B Producer: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line or coil will mill the XN- nipple. E-line will set a 4-1/2" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or mill the window pre-rig, the rig will perform that work. See F-06B PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to pre-rig, the rig will set the 4-1/2" packer whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in the Shublik and lands in Ivishak Zone 4. The lateral will continue in Zone 4 and up through the Shublik and into the Sag to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” L-80 solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in June 2025) 1. Slickline : Dummy WS drift 2. E-Line : Set 4-1/2" Packer Whipstock* at 10,390’ MD at 325 degrees ROHS 3. Fullbore : MIT-IA and/or MIT-T to 2,500 psi (min) 4. Coil : Mill 3.80" XN nipple (at 10,130' MD) and 3.80" Window (if window not possible, mill with rig). - see attached procedure 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: x Reference F-06B Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,364 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not done pre-rig). 3. Drill build section: 4.25" OH, ~388' (32 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2,595' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2"x3-1/4” x 2-7/8” L-80 solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job*: 34.7 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP*. 7. Perforate Liner with rig (~1500') - will perforate with service coil under this PTD if needed 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Liner Lap Test, set LTP* (if necessary). Set live GLVs. 3. Testing : Portable test separator flowback. * Alternate plug placement variance request per 20 AAC 25.112(i) Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3"or 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU F-06A Patch Perforations Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 203-149 50-029-20097-01-00 10981 Surface Intermediate/Scab Tieback Liner 9147 2287 8810 10282 842 10726 18-5/8" 13-3/8" x 9-5/8" 7" 4-1/2" 8996 30 - 2317 29 - 8839 27 - 10309 10138 - 10980 30 - 2317 29 - 7801 27 - 8742 8634 - 9146 10726 870 1950 5410 7500 10726 930 3450 7240 8430 10530 - 10745 4-1/2" 12.6# 13Cr80 25 - 10142 8877 - 9008 Conductor 80 30" 31 - 111 31 - 111 4-1/2" Baker S-3 Packer 10083, 8598 10083 8958 Torin Roschinger Area Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028277, 0028280 25 - 8637 N/A N/A 351 870 56668 37348 29 478 1450 1300 1112 1257 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:05 am, Jul 18, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.07.18 06:03:37 -08'00' Torin Roschinger (4662) WCB 3-4-2024 RBDMS JSB 071823 DSR-7/19/23 ACTIVITYDATE SUMMARY 6/21/2023 ***WELL S/I ON ARRIVAL*** PT PCE 250LP-3000HP CORRELATE TO SLB PERF RECORD DATED 11-OCT-2003. (+9' FROM REFERENCE LOG) SET 45 KB 1 TRIP PATCH ELEMENT TO ELEMENT=10661' - 10696' MD (10652'- 10687' REFERENCE DEPTHS) CCL TO TOP ELEMENT=12.3', CCL STOP DEPTH=10648.7' MD. LIH OAL=41.1', MAX OD=3.70" ***CONTINUED ON 22-JUN-2023 WSR*** 6/22/2023 ***CONTINUED FROM 6-21-2022 WSR*** PT PCE 250LP-3000HP CORRELATE TO AKES PLUG AND PERF RECORD DATED 8-DEC-2021 (+11' FROM REFERENCE LOG) SET 45K KB 1 TRIP PATCH ELEMENT TO ELEMENT=10536' - 10557' MD (10525' - 10546' REFERENCE LOG DEPTHS) CCL TO TOP ELEMENT=12.3, CCL STOP DEPTH=10523.7' MD. LIH LENGTH=28.66', MAX OD=3.70" ***WELL LEFT S/I, PAD OP NOTIFIED*** Daily Report of Well Operations PBU F-06A 10652'- 10687' REFERENCE DEPTHS 10525' - 10546' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU F-06A Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 203-149 50-029-20097-01-00 10980 Surface Intermediate/Scab Tieback Liner 9146 2287 8810 10282 842 10726 18-5/8" 13-3/8" x 9-5/8" 7" 4-1/2" 8996 30 - 2317 29 - 8839 27 - 10309 10138 - 10980 30 - 2317 29 - 7801 27 - 8742 8634 - 9146 10726 870 1950 5410 7500 10726 930 3450 7240 8430 10530 - 10745 4-1/2" 12.6# 13Cr80 25 - 10142 8877 - 9008 Conductor 80 30" 31 - 111 31 - 111 4-1/2" Baker S-3 Packer 10083, 8598 10083 8958 Torin Roschinger Area Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028277, 0028280 25 - 8637 N/A N/A 351 Well Not Online 56668 29 1450 1200 1112 600 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 4:04 pm, Jun 21, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.21 14:37:36 -08'00' Torin Roschinger (4662) RBDMS JSB 071223 DSR-6/21/23WCB 1-9-2024 ACTIVITY DATE SUMMARY 6/1/2023 CTU #6 1.75" 0.156". Job Scope: Mill CIBP MIRU CTU 6. MU YJ milling assembly w/ 3.67" Venturi/Burnshoe. RIH. Tag CIBP @ 10603' CTM / 10620' MD. Milll CIBP. Push CIBP fish down to bottom CIBP @ 10710' CTM / 10620' MD. POOH. FP coil and well with diesel. ***Job in Progress*** 6/2/2023 CTU #6 1.75" 0.156". Job Scope: Mill CIBP LD 2-7/8" milling assembly w/ 3.67" Venturi burn shoe. Recovered CIBP parts. RDMO. ***Job Complete*** Daily Report of Well Operations PBU F-06A The 10620' is a mistype. The fish is at 10,726' MD. -WCB POOH. MIRU CTU 6. MU YJ milling assembly w/ 3.67" Venturi/Burnshoe. RIH. Tag CIBP @ gy g@ 10603' CTM / 10620' MD. Milll CIBP. 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Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Pull AICD Patch Set New Patch 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ® Exploratory ❑ t to Drill Number: 203-149 3. Address: P.O. Box 196612 Anchorage, F6API AK 9 951 9-6 612 Stratigraphic ❑ Service umber: 50-029-20097-01-00 7 Property Designation (Lease Number): ADL 028277 8. Well Name and Number: PBU F -06A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field,IPools: �Oy PRUDHOE BAY, PRUDHOE OILf 5i ,a" 11. Present Well Condition Summary: Total Depth: measured 10960 feet Plugs 06 2019 measured 10726 feet true vertical 9146 feet Junk measured None feet Effective Depth: measured 10726 feet Packer OGCC measured 10081 feet true vertical 8996 feet Packer true vertical 8598 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 30" 31 - 111 31 - 111 Surface 2287 18-5/8" 30-2317 30-2317 930 670 Intermediate 8810 13-3/8" x 9-5/8" 29-8839 29-7800 3450/6870 1950/4760 Liner 10284 7' 27-10311 27-8743 7240 5410 Liner 842 4-1/2" 10136 - 10980 8634-9146 6430 7500 Perforation Depth: Measured depth: 10656 - 10745 feet True vertical depth: 8954-9008 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 25-10140 25-8636 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Hydro Set Packer 10081 8598 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Md Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 212 22835 270 0 336 Subsequent to operation: 374 16266 284 0 304 14. Attachments: (required per 20enc25.070.25.071.&25.283) 15. Well Class after work: Daily Report of Well Operations 9 Exploratory ❑ Development p Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil RI Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Haffener, Jordan Contact Name: Haffener, Jordan Authorized Title: Petroleum Engineer Contact Email: Jordan. Haffener@bp.com Authorized Signature:>� Date: �� 5 Zbf Contact Phone: +1 9075645383 Form 10404 Revised 04/2017 4' (11-7':7/u, tx&RZ6A"11BDMSLgVN0V 0 8 2019 Submit Original Only Daily Report of Well Operations PBU F -06A ArTI V ITV RATP �, ,.......,. ***WELL S/I UPON ARRIVAL*** (profile modification) RAN 45KB UPPER, 20' x 2 7/8" SPACER PIPE, 45KB LOWER DRIFT TO TOP OF PATCH @ 10,644' MD PULLED UPPER 45KB & AICD FROM 10,644' MD (missing 1 element) RAN 4 1/2" BRUSH, 3.50" 3 PRONG WIRE GRAB TO 10,653' SLM (recovered 3/4 element) PULLED 13 1/2' BLAST JOINT FROM 10,653' SLM PULLED AICD FROM 10,669' SLM 8/5/2019 ***CONT WSR ON 8/6/19*** ***CONT WSR FROM 8/5/19*** (profile modification) PULLED 13' BLAST JOINT FROM HIGHER IN TUBING @ 8,928' SLM PULLED LOWER 45KB PACKER FROM 10,684' SLM (missing 1 element) RAN 4 1/2" BRUSH, 3.50" WIRE GRAB TO TOP OF CIBP @ 10,722' SLM (recovered 1 element) 8/6/2019 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** ***WELL SHUT IN ON ARRIVAL***(ELINE SET LOWER PATCH ASSEMBLY) INITAL T/1/0=2500/200/0 SET 45 BAKER FLO-GUARD LOWER PATCH ASSEMBLY AT 10686', MIN ID = 2.45", CCL TO MID ELEMENT=8.83', CCL STOP DEPTH=10677.17' LOGS CORRELATED TO SLB PATCH SETTING RECORD DATED 19 -SEPT -2019 10/10/2019 ***JOB COMPLETE, PAD OP NOTIFIED*** ***WELL S/I ON ARRIVAL*** (Profile modification) TAGGED BAKER 45KB FLO-GUARD ANCHOR PACKER W/ 3.50" L.I.B. AT 10,689' SLM. 10/23/2019 ***JOB IN PROGRESS, CONTINUED ON 10/24/19 WSR*** ***CONTINUED FROM 10/23/19 WSR*** (Profile modification) SET AND PULL TESTED 13.11' BLAST JOINT INTO LOWER ANCHOR AT 10,689' SLM SET AND PULL TESTED 5.56' SPACER JOINT INTO TOP OF 1st BLAST JOINT AT 10,678' SLM SET AND PULL TESTED 14.05' BLAST JOINT INTO TOP OF SPACER JOINT AT 10,670' SLM SET BAKER 45KB FLO-GUARD PKR W/ 2-7/8" CMD SLEEVE INTO BLAST JOINT AT 10,661' SLM TOP OF BAKER PKR ATt0,642' MD / BAKER CMD SLEEVE W/ 2.31"X -NIPPLE AT 10,649' MD (Sleeve is closed) ***TIGHT SPOTS FROM 8800' TO 9300' ENCOUNTERED RIH W/ BLAST JOINTS*** 10/24/2019 ***CONT WSR ON 10/25/19*** ***CONT WSR FROM 10/24/19*** (profile modification) RD SWCP 4518 SLICKLINE UNIT 10/25/2019 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** TREE= 4" CAN 13-918- CS(3, 68#, K-55, D = 12.415" 2269' 9-5/8" SCAB LNR ID = 8.887" 2266' 18-5/8" CSG, 96.5#, K-55, D = 17.655" 2306' Minimum ID = 2.31" @ 10649' BKR CMD SLV IN 46 KB UPPER PKR 7" CSG, 26#, L-80, D = 6.276" 8661' 1 8839' 1 9-5/8" CSG, 47#, N-80, SEALLOCK, D= 8.681^ I McEVOY R= BAKER FOLD= H.EV = 55.60' Note: Refer to Production DB for historical perf data 36.61' KOP= 2862' Max Angle = 54' @ 10915' Datum MD= 10517 Datum TVD= 8800'SS 13-918- CS(3, 68#, K-55, D = 12.415" 2269' 9-5/8" SCAB LNR ID = 8.887" 2266' 18-5/8" CSG, 96.5#, K-55, D = 17.655" 2306' Minimum ID = 2.31" @ 10649' BKR CMD SLV IN 46 KB UPPER PKR 7" CSG, 26#, L-80, D = 6.276" 8661' 1 8839' 1 9-5/8" CSG, 47#, N-80, SEALLOCK, D= 8.681^ I 4-12' TBG, 12.6#, 73CR-80 VAM TOP, .0152 bpf, D= 3.958" 7" LNR 26#, L-80, .0382 bpf, D = 6 276" I PBTD I 12.6#, L-80..0382 F-0 6 A SAFETY NOTES:' "4-1 /2" CHROME TBQ "' LNR TOP TCR, D = 8.575" IES X NIP, ID =3.813^ GAS LIFE M WRELS ST PERFORATION SUMMARY I TVD REF LOG: SP ERRY MAD ON 09/25/03 ANGLEAT TOP PERF: 53" @ 10659 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT TSOZ 2-718" 6 10656 - 10666 O 10/11/03 3964 2-7/8' 6 10674 - 10682 O 10/11/03 3-3/8" 6 10693 -10711 O 09/03/09 BK 20 2-718" 6 10693 - 10711 O 10/11/03 2-7/8" 6 10735 - 10745 C 10/11/03 8055 4-12' TBG, 12.6#, 73CR-80 VAM TOP, .0152 bpf, D= 3.958" 7" LNR 26#, L-80, .0382 bpf, D = 6 276" I PBTD I 12.6#, L-80..0382 F-0 6 A SAFETY NOTES:' "4-1 /2" CHROME TBQ "' LNR TOP TCR, D = 8.575" IES X NIP, ID =3.813^ GAS LIFE M WRELS ST ND I TVD OEVgI VLV LATCH Fi7RT DATE 5 3051 3045 14 012422WN2ES RWO DMY BK 0 09/25/03 4 4040 3964 31 BP Exploration (Alaska) DOME BK 160330/183 6247 5545 32 So BK 20 03/30/182 7657 6600 25 OM1' BK 0 03/30/18 1 9237 8055 53 DMY BK 0 03130/18 NO_LODUF WPi70W: 8839'- 8855' 10069' -14-12" HES x NP, D = 10083' l --q 7" X 4-1/2" BKR S-3 PKR D = 3.875" 14-1/2" IES X NP, ID = 3.813" 1 10130' (-14-12" HES XN NP. D = 3.725" 10138'J--7^X4-12^BKRLTP, D=4.40^ 1 ivr i� 4-1/2' WLEG, D=3.958" 10147' aMD TT LOG 0/N xx/xxncx 10642' 1 45 KB UPPER FLOGUARD PKR, D =2.45- (102511 10649'2-7/r BKRCMDSLEEVEw/2.31^XNP,D=231^ 10654'-10666' 2-78' BLAST JOINT, D = 2.441" 110672'406827--2-7m- BLAST JONT, D = 2.441" 10684' 45 KB BKR LOWER FLOGUARD PKR, D =2.45^ (10 PRUDHOE BAY UNIT WELL: F -06A PERMrr No:'2031490 API No: 50-029-20097-01 SEC 2, T11 N, R73E, 2508' FSL&2401'FWL REV BY COMMENTS DATE REV BY COMMENTS INITUIL COMPLETION 11/13/18 KFM/JMD SET LOWER STRADDLE PKR RWO 11/13/18 KFM/JMD SETUPPERSTRADDLE PKR 012422WN2ES RWO 0821/19 LG/JMD PULLED PKR W/AICD EOUFLOW 4E5 RWOSUSPENDED10/16/19 NXW/JMD SET LOWERSTRADOLE PKR DACMK RWO1029119 CJN/JMD SETSTRADDLDACrfLH BP Exploration (Alaska) SIDETRACK (FARM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Y'Br—UL.—ill V lir LO 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program Plug for Rednll ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: Pull and Set Patches 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number 203-149 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50429-20097-01-00 7. Property Designation (Lease Number): ADL 028277 8. Well Name and Number: PBU F -06A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10980 feet Plugs measured 10726 feet true vertical 9146 feet Junk measured None feet Effective Depth: measured 10726 feet Packer measured 10081 feet true vertical 8996 feet Packer true vertical 8597 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 30" 31 -111 31-111 Surface 2287 18-5/8" 30-2317 30-2317 930 870 Intermediate 8810 13-3/8" x 9-5/8" 29-8839 29-7800 3450/6870 1950 / 4760 Intermediate 10284 7" 27-10311 27-8743 7240 5410 Production Liner 842 4-1/2" 10138 - 10980 8634-9146 8430 7500 Perforation Depth: Measured depth: 10656 - 10745 feet True vertical depth: 8954-9008 feet Tubing (size, grade, measured and We vertical depth) 4-1/2"12.6# 13Cr80 25-10140 25-8636 Packers and SSSV (type, measured and 4-1/2" Backer S-3 Hydra Set Packer 10081 8597 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mct Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 108 179 180 200 200 Subsequent to operation: No Test Available 200 80 14. Attachments: (muses per20MC 25 070.25071. &25283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stretigmphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ fy regoin is true and r:ofrect to the best of m knowledge, 17. 1 herebycertify that the foregoing y g Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Haffener, Jordan Contact Name: Haffener, Jordan Authorized Title: Production Engineer Contact Email: Jordan.HaffenerLMbp.com Authorized Signature: ffi§te: j Contact Phone. +1 9075645383 Form 10-404 Revised 04/2017 'Oe(/1%!� BDMDEC 17 2018 Submit On8lnalOny Daily Report of Well Operations PBU F -06A ACTIVITvnATF CI IMAAADV '**WELL S/I ON ARRIVAL' (profile mod) R/U SWCP 4521 DRIFT 20'x 3.70" DUMMY WHIP STOCK & 3.50" LIB TO 10,275' SLM (impression of fn) PULL TOP 45 KB STRADLE PACKER FROM 10,275' SLM PULL SECTION 2 OF STRADLE PACKER FROM 10,640' SLM ***JOB IN PROGRESS, CONTINUED ON 09-23-18 WSR*** 9/22/2018 ***CONTINUE WSR FROM 9/22/18 SWCP 4521*** (profile mod) R/U SWCP 4521 PULL BOTTOM 2 SECTIONS OF MULTI -TRIP AICD STRADDLE PACKER FROM 10,654 TO 10,659' SLM PULL 45 KB BOTTOM ANCHOR FROM 10,670' SLM DRIFT 20'x 3.70" DUMMY WHIPSTOCK TO 10,703'SLM/10,726' MD, TAG CIBP 9/23/2018 ***JOB IN PROGRESS, CONTINUED ON 09-24-18 WSR**' ***CONTINUE WSR FROM 9/23/18 SWCP 4521*** (profile mod) RAN SBHPS TO 10,676' MD PER PROGRAM (GOOD DATA) RAN 40 ARM PDS CALIPER FROM 10,700' TO SURFACE (good data). 9/24/2018 'WELL S/I ON DEPARTURE**' '**JOB STARTED 22 -OCT -2018*'* (SLB ELINE SET LOWER PATCH ASSEMBLY) WELL SHUT IN ON ARRIVAL INITIAL T/I/O = 2400/200/0/0 RU. PT. RUN 1: RIH W/4.5" BAKER LOWER PATCH ASSEMBLY **'JOB CONTINUED ON 23 -OCT -2018*'* 10/22/2018 ***JOB CONTINUED FROM 22 -OCT -2018*** (SLB ELINE SET LOWER PATCH ASSEMBLY) CONTINUE RUN 1. SET BAKER 4.5" LOWER PATCH ASSEMBLYAT 10686. TOP OF PATCH AT 10684' ALL LOGS CORRELATED TO SLB 4.5" PATCH SETTING RECORD DATED 19 -SEP -2017 WELL SHUT IN ON DEPARTURE FINAL T/I/O = 2430/200/0/0 10/23/2018 ***JOB COMPLETE'** ***WELL S/I ON ARRIVAL' (Profile Mod) RAN 3.50" LIB TO 10,684' SLM... IMPRESSION OF BAKER 45 KB LOWER STRADDLE PKR SET BLAST JOINT JUNCTION # 1 IN BAKER 45 KB LOWER STRADDLE PKR @ 10,684' SLM SET HES LOWER AICD #1 IN BLAST JOINT JUNCTION #1 @ 10,672' SLM 11/7/2018 *'*CONT. ON 11/08/2018 WSR"* ***CONT. FROM 11/07/2018 WSR*** (Profile Mod) SET BLAST JOINT JUNCTION #2 IN HES LOWER AICD #1 @ 10,666' SLM SET UPPER HES AICD & 45 KB PACKER @ 10,644' MD ***WELL S/I ON DEPARTURE, PAD OP NOTIFIED**' 11/8/2018 **'*TIGHT SPOTS @ 8830' & 8945' SLM W/ LONG ASSEMBLIES***** TREE= 4'CMV WELLHEAD= WEVOY ACTUATOR= BAKE2C NIDAL KB. B -EV = 55.60' BE HEV = 36.61' KOP= 2862' Max Angle = Datum Am= Datum TVD= 54' @ 10915' 10512' 88W'SS F -06A 113-318' CSG. 68#. K-55. D = 12.415' 1 Minimum ID =1.93" @ 10650' HES AICD EQUIFLOW DEVICE IN PKR 17" CSG, 26#. L-80. D = 6.276' 1 9-5/8- NSG, 4-1/2' TBG, 12.6#, 13CR-80 VA M TOP, .0152 bpf, D = 3.958' PBTD H 10893' SAFETY NOTES: "'4-112" CHROME TBG"' LNR TOP RO2, D = B.: HESX NP. D=3.813' GAS LFT MANDRELS ST MD PERFORATION SUMMARY DEV TYPE REF LOG: SPERRY /AND ON 09125103 LATCH ANGLE AT TOP FEW 53°@ 1065V Note: Refer to Production DB for historical pert data S¢E SPF MHZVAL Opn/Sgz SHOT SOZ 2-718'B 09/25/03 10656 - 10666 O 10111/03 2-718' 6 10674 -10682 0 10111103 3-318' 6 110693-10711 O 09/03/09 2-718' 6 110693-10711 O 10/11103 2-7/8' 6 110735-10745 C 10/11103 4-1/2' TBG, 12.6#, 13CR-80 VA M TOP, .0152 bpf, D = 3.958' PBTD H 10893' SAFETY NOTES: "'4-112" CHROME TBG"' LNR TOP RO2, D = B.: HESX NP. D=3.813' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3051 3045 14 KBG-2 DM1Y BK 0 09/25/03 4 4040 3964 31 KBG-2 DOME BK 16 03/30/18 3 6247 5545 32 KBG-2 SO BK 20 03/30/18 2 7657 SSW 25 KBG-2 DW BK 0 03/30/18 1 9237 8(155 53 KBG-2 DW BK 0 03/30118 8966' H9-5/8' X T BKR LNR TOP RJR, MLLOUT WI DOW: 8839' - 8855' 10109• H4-1/2-H84XNP,1D=3.613• 1014THELmDTrLD`GONxx'xx/;Zfl 10'� 1� 7' X 4-1/2' XO. D = 390' KB BKR UPPER STRADDLE PKR (11/J i AICD EOUIFLOW DEV ICE. ID = 1.93' > A ICD EOUIFLO W DEV ICE. ID = 1.93' KB BKR LOWER STRADDLE PKR SNAP LATCH & MULE SHOE, D = 2.44' FR(DFDE BAY tM WELL: F -06A PERMIT No: 02031490 API No: 50029.2DO97-01 SBC 2, T11 N, R13E, 2509 FSL & 2401' FAL DATE REV BY COMMENTS DATE FEV BY COMMENTS 06105171 INITIAL COMPLETION 12/02/12 PJC REFORMATM 06107193 lwM 08106118 LHJMD ADO®AICDD 12MM WES RIND 09127/18 JM1u/JMD FUZED STRADDLE PKR w IDEVI 12/02102 4EIS RING SUSPENDED 11113118 KFlu1'JMD SET LOA'B2 STRADDLE RJR 02/11103 DAC/KK RIND 11113118 KF WJMD SET LFP92 STRADDLE RJR BP Etploratlon(Alaska) 09/27103 DACITLH SIDETRACK (F -06A) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, March 18, 2018 1:44 PM To: AK, OPS EOC Specialists;AK, OPS GC1 Facility OTL;AK, OPS GC1 Field O&M IL;AK, OPS GC1 OSM;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad DG;AK, OPS Well Pad EKG;AK, OPS Well Pad YP;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Landi, Nancy A;Cerveny, Philip F; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer F-06 (PTD 2031490) Sustained inner annulus casing pressure above NOL Attachments: F-06A.pdf All, Producer F-06 (PTD 2031490)was reported to have sustained inner annulus casing pressure above NOL on 3/17/18. The pressures were confirmed to be T/I/O/O0= 2400/2050/0/Opsi. The high inner annulus pressure is an indication of a potential loss of one or more well barriers. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. SL-perform GLV change out 2. DHD-TIFL and Monitor Satit453 Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO IOWA•••••«w..«.. 1 • S Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, March 4, 2018 1:38 PM To: AK, OPS EOC Specialists;AK, OPS GC1 Facility OIL;AK, OPS GC1 Field O&M IL;AK, OPS GC1 OSM;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad DG;AK, OPS Well Pad EKG;AK, OPS Well Pad YP;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL;Cerveny, Philip F; Haffener,Jordan; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A;Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer F-06A(PTD#2031490) Passed warm TIFL external-email: 0 All, Producer F-06A(PTD#2031490)was put Under Evaluation on 02/18/18 for having sustained inner annulus casing pressure above NOL. On 03/04/18 DHD performed a passing warm TIFL.The passing TIFL indicates two competent well barriers.The well is now classified as OPERABLE. Plan Forward/Work Completed: b z l 1. Operations—POP Well-Complete SCANNED . 2. DHD—Warm TIFL-Complete 3. Slickline (Contingent)—GLV Change out-Cancelled 4. DHD(Contingent)—Warm TIFL-Cancelled 5. Well Integrity Engineer—Additional diagnostics as needed-Cancelled Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 From: AK, G • -II Integrity Engineer 9 9 Sent: Sunday, February :, -18 10:34 AM To: AK, OPS EOC Specialists; AK, •• - 1 Facility OTL; AK, OPS GC1 Field O&M TL; AK, OPS GC1 OSM; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, • ' od Controllers; AK, OPS Well Pad DG; AK, OPS Well Pad EKG; AK, OPS Well Pad YP; Ak, Ops West Area TL; AK, RES GPB Ea -IIs Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Haffener, Jordan; 'Regg, James B (DOA) egg@alaska.gov)' Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integr • •K, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well 0. •mp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Mon s.eery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel, Joshu•, orthington, Aras 3; 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, February 18, 2018 10:34 AM To: AK, OPS EOC Specialists;AK, OPS GC1 Facility OIL;AK, OPS GC1 Field O&M TL;AK, OPS GC1 OSM;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad DG;AK, OPS Well Pad EKG;AK, OPS Well Pad VP;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Haffener,Jordan; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer F-06A(PTD#2031490) Sustained inner annulus casing pressure above NOL Attachments: F-06A.pdf All, Producer F-06A(PTD#2031490)was reported to have inner annulus casing pressure above NOL on 2/17/2018. The pressures were confirmed to be T/I/O/OO=2410/2280/0/Opsi. A subsequent cold TIFL failed indicating a potential loss of one or more well barriers. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. Operations—POP Well 2. DHD—Warm TIFL 3. Slickline (Contingent)—GLV Change out 4. DHD(Contingent)—Warm TIFL 5. Well Integrity Engineer—Additional diagnostics as needed Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 * }" .Whig......,..":•• 1 STATE OF ALASKA SLASKA OIL AND GAS CONSERVATION COMMIS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations I3 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set Perf Straddle Patch I? 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 203-149 3. Address: P.O.Box 196612 Anchorage, Development IBJ Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20097-01-00 7. Property Designation(Lease Number): ADL 0028277 8. Well Name and Number: PBU F-06A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL RECEIVED 11.Present Well Condition Summary: Total Depth: measured 10980 feet Plugs measured 10726 feet NOV 0 `9 n 2017 true vertical 9146 feet Junk measured feet Effective Depth: measured 10726 feet Packer measured 10081 feet true vertical 8996 feet Packer true vertical 8597 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 90 30"Conductor 32-122 32-122 Surface 2287 18-5/8"96.5#K-55 30-2317 30-2317 930 870 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment • Perforation Depth: Measured depth: 10656-10657 feet 10657-10666 feet 10674-10682 feet 10693-10711 feet 10735-10745 feet True vertical depth: 8954-8955 feet feet 8955-8960 feet 8965-8970 feet 8977-8987 feet 9002-9008 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 25-10140 25-8636 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): j� DEC2 Treatment descriptions including volumes used and final pressure: SCA NEu DEC 2 201 e{�j, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 736 53845 160 20 983 Subsequent to operation: Shut-In 20 120 14.Attachments:(required per 20 AAC 25.070.25.071,s 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 121 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I1 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG ❑ 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: N/A Authorized Name: Haffener,Jordan Contact Name: Haffener,Jordan Authorized Title: Production Engineer Contact Email: Jordan.HaffenerI bp.com Authorized Signature: E' .. Date: 11/9/1,017 Contact Phone: +1 9075645383 Form 10-404 Revised 04/ '17 17'77- `7i ``-7- "t1',#7 RBD NIS L' VOV _ 9 2017 Submit Original Only • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary November 7, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for pulling and setting a new Straddle Patch to isolate the upper three perforation intervals from 10656' to 10682' for well F-06A, PTD # 203-149. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 s • C, C) 0 0 0 0 0 0 00 0 � � toLC) COON— OL0O - 0 � 0) 0) � � � LLO O LO LOr� � � v `� 0 0 0 0 0 0 0 0 0 i O V Ln LO I� r N M O CO • N V c0 00 N .c CO CO CO CO co N- 00 c) co I- O CO 00 N N CO CO O N— L) Ln O t N- CO CO CO O N CO N N- O) CO N N N N 00 07 CO CO I I I I N V c0 co O N O 0) tY O LC) M LO LO CO CO N N O N O) CO CO C)) N N N f� 00 CO N. co CO c0 N N V O M O O N CO N O O O N CO N N CO N e- C) p O CO Q▪ CO N O N- O V' N r L Lo co co N N O N O) CO O N N N '— CO �▪ �• MM O LO O Q. O 00 in in 000 c 00 � Cj a) cOYYZ _Li 00 -1coco • d -0 - J op It *k CC) �$ ▪y N *k O CO V *k N N CO • U - N 0\O 0\O N O N - , NCO _ CO 0 M L CO COO 00 N N NCO M N CO = O) (N CO O M 1 O CO CO J N CO N N O M O W W W W Q Q Q Q CM cW� ❑ ❑ ❑ ❑ ' U W W W W ❑ Q C7 U ❑ r Z ZWWWWWWWWm O DZZZZJ U coZ Z Z Z J J J H • • • a) L U a) (a d ca 0_ J L L C '^ 'N^ Y Y Q VJ — Q. a) O U d d .L CYJ -0 N Q Q L 0.(/) . 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 03 - ~ 4£f Well History File Identifier D Two-sided 1111111111111111111 Organizing (done) D Rescan Needed 1111111111111111111 RE~N 1;z{éolor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, Norrype: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: Date: ð" ìòj05" D Other:: BY: ~ /s/ vY\p 1111111111111111111 vYlP Project Proofing BY: ~ Date ~~ /3j05" a x 30 = faro + JCb = TOTAL PAGES -¡q n J . (Count does not include cover ste~t) \1\.11. ý) Date: I ~ '3 05 /s/ V ' t r 11111111111111 ,,11\ /s/ Scanning Preparation BY: ~ Production Scanning Stage 1 Page Count from Scanned File: 7 c¡ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES ~ Date fð--' 13/05"" Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: /s/ NO VV1P YES NO BY: Maria Date: /s/ 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111111I BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page. doc RECEIVED STATE OF ALASKA AS OIL AND GAS CONSERVATION COMMON JAN 2 2 2013 REPORT OF SUNDRY WELL OPE�I2ATIONS AOGCC 1. Operations Abandon L] Repair Well U Plug Perforations l Perforate U Other LJ Performed: Alter Casing ❑ Pull TubingJ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory ❑ .� 203 -149 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 - 6612 50- 029 - 20097 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028277 - PBU F -06A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): r To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10980 feet Plugs measured 10736 feet true vertical 9146.2 feet Junk measured None feet Effective Depth measured 10736 feet Packer measured See Attachment feet true vertical 9002.44 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 81 30" Conductor 30 - 111 30 - 111 0 0 Surface 2288 18 -5/8" 96.5# K -55 29 - 2317 29 - 2316.94 930 870 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 842 4 -1/2" 12.6# L -80 10140 - 10982 8635.56 - 9147.37 8430 7500 Perforation depth Measured depth 10666 - 10676 feet 10684 - 10692 feet 10703 - 10721 feet 10745 - 10755 feet True Vertical depth 8960.42 - 8966.45 feet 8971.27 - 8976.08 feet 8982.69 - 8993.48 feet 9007.81 - 9013.77 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 26 - 10143 26 - 8637.51 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: MAR 2013 Intervals treated (measured): SCANNED p� tYY�IAR Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 635 49632 165 0 972 Subsequent to operation: 916 5036 207 0 1213 14. Attachments: 15. Well Class after work: ,,,, Copies of Logs and Surveys Run ExploratorLj Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil .. ig Gas U WDSPUJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG0 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: N/A Contact Nita Summerhays Email Nita.Summerh Printed Name Nita Summerhays Title Petrotechnical Data Technician `/ Signatur- y o� �J ; 1)11//- Phone 564 -4035 Date 1/21/2013 RBDMS JAN 2 P M41 3 3 Form 10 -404 Revised 10 /2012 Submit Original Only • • Daily Report of Well Operations ADL0028277 " ** WELL SMUT IN ON ARRIVAL *** (ELINE: PACKER) INITIAL T /I /O = 0/0/500 RIH. HEAD / ERS/ 2X WB/ UPCT/ BAKER #10 / PATCH. FN: 1.38" LENGTH: 35' WEIGHT: 560 LBS. OD: 3.7" SET LOWER PACKER ASSEMBLY MID - ELEMENT AT 10680'. TOP OF PACKER ASSEMBLY = 10678'. CCL TO M.E. = 9.9'. CCL STOP = 10670.1' FINAL T /I /O = 0/0/450 WELL SHUT IN ON DEPARTURE. * ** JOB COMPLETED ON 21 -NOV -2012 * ** 11/21/2012 ** *WELL S/I ON ARRIVAL ** *(patch- tubing /liner) TAG BKR KB LOWER STRADDLE @ 10644 SLM W/3.50" LIB, IMPRESSION OF FN. RAN DPU, BKR KB UPPER PACKER S/D @ 8825' SLM WORK TO 8863' SLM UNABLE TO WORK PAST. SET BKR KB UPPER PACKER AT 2600' SLM DUE TO TIME LIMITATIONS ON DPU. 12/9/2012 ** *CONT ON 12/10/12 WSR * ** ** *CONT FROM 12/10/12 WSR * ** (patch - tubing /liner) PULL BKR KB UPPER PACKER @2595' SLM. DRIFT W/ 4 -1/2" BLB, 3.70" GAUGE TAG BKR KB LOWER PACKER @10644' SLM. 12/11/2012 ** *CONT ON 12/12/12 WSR * ** ** *CONT FROM 12/11/12 WSR ** *(patch - tubing /liner) DRIFTED W /BKR DMY KB PATCH TO 10,551' SLM VERFIED ABILITY TO ENGAGE SNAP LATCH TO LOWER STRADDLE 12/12/2012 ** *WELL S/I ON DEPARTURE, PAD OP NOTIFIED * ** ** *WELL S/I UPON ARRIVAL * ** (patch - tubing /liner) RU SWCP 4516 12/21/2012 ** *CONT WSR ON 12/22/12 * ** * * *CONT WSR FROM 12/21/12 * ** (patch - tubing /liner) SET SNAP LATCH SPACER ASSEMBLY (14.54' oal, 2.36" min id, 3.68" od) SET 45 KB UPPER PACKER ASSEMBLY W/ SNAP LATCH ON HALLIBURTON DPU (8.0' oal, 2.36" min id, 3.70" od) TOP OF UPPER PACKER ASSEMBLY = 10,657' MD. ** *WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL 12/22/2012 STATUS * ** FLUIDS PUMPED BBLS 5 DIESEL 5 TOTAL Casing / Tubing Attachment ADLOO28277 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 30" Conductor 30 - 111 30 - 111 INTERMEDIATE 2242 13 -3/8" 68# K -55 28 - 2270 28 - 2269.94 3450 1950 INTERMEDIATE 6569 9 -5/8" 47# N -80 2270 - 8839 2269.94 - 7800.58 6870 4760 LINER 842 4 -1/2" 12.6# L -80 10140 - 10982 8635.56 - 9147.37 8430 7500 PRODUCTION 8624 7" 26# L -80 27 - 8651 27 - 7654.84 7240 5410 PRODUCTION 1660 7" 26# L -80 8651 - 10311 7654.84 - 8742.73 7240 5410 SURFACE 2288 18 -5/8" 96.5# K -55 29 - 2317 29 - 2316.94 930 870 • TUBING 10117 4 -1/2" 12.6# 13Cr80 26 - 10143 26 - 8637.51 8430 7500 • • • Packers and SSV's Attachment ADL0028277 SW Name Type MD TVD Depscription F -06A PACKER 1927 1860.34 9 -5/8" Top Packer F -06A PACKER 8657 7592.98 7" Top Packer F -06A PACKER 10084 8532.35 4 -1/2" Baker S -3 Hydro Set Packer F -06A PACKER 10138 8567.64 4 -1/2" Top Packer F -06A PACKER 10657 8888.37 4 -1/2" Top Packer F -06A PACKER 10684 8904.66 4 -1/2" Top Packer TREE= 4" CIW W V B . L F E A D = McEVOY F-06A S/ NOTES: ***4-1/2" CHROME 1 G*** 1 ACTUATOR = BAKER C NTIAL KB. ELEV = 55.60' BF. E.EV = 36.61' KOP= 2867 I ' I 1927' H9-5/8" LNR TOP PKR, 0 = 8.575" I Max Angle = 54° @ 10915' I 2195' �— {H4-1/2" HES X NP, D = 3,813" Datum MD = 10512' Datum TVD = 8800' SS 113 -3/8' CSG, 68#, K-55, D = 12A15" H 2259' i I 2259' H13-3/8' X 9-5/8" XO I I9 -5/8" SCAB LNR, D = 8.681" I 22 - 66' , 118 -5/8" CSG, 96.5#, K-55, D = 17.655' H 2306' I.-- GAS LFT MANDRELS L ST MD TVD DEV TYPE VLV LATCH FORT DATE 5 3051 3045 14 KBG-2 DMY BK 0 09/25103 Minimum ID = 3.725" @ 10130' 4 4040 3964 31 KBG-2 DOME BK 16 10/10/03 4-1/2" HES XN NIPPLE 3 6247 5545 32 KBG-2 DOI* BK 16 10/10/03 2 7657 6800 25 KBG-2 DOME BK 16 10/10/03 1 9237 8055 53 KBG-2 SO BK 24 1 I7" CSG, 26#, L80, D = 6276" 1--I 8651' I 86 —{9 5/8"X7" BKR LNR TOP PKR D I I9 -5/8" 1m-us-rock H 8839' I9 -5/8" CSG, 47#, N-80, SEALLOCK, D = 8.681" H --8839 I MB.LOUT WPDOW: 8839 ' - 8855' 1 PERFORATION SUMMARY REF LOG: SPERRY MWD ON 09/25/03 ANGLEAT TOP PERF: 53° 7 10666' I 10059' I- 14 -1/2" HES X NP, D= 3.813" I Note: Refer to Ptoduction DB for historical pert data SIZE SPF WIERVAL Opn/Sqz SHOT SQZ 2 -7/8" 6 10666 -10676 C 10/11/03 = ■ 10083' H 7" x 41/2" BKR S-3 PKR, 13= 3.875" I 2 -7/8" 6 10684 - 10692 0 10/11/03 3 3/8" 6 10703 -10721 0 09/03/09 10109' J- 141/2" HES X NP, D = 3.813" I 2 -7/8" 6 10703 - 10721 0 10/11/03 2 -7/8" 6 10745 -10755 C 10/11/03 10130' J- 141/2" FES XN NP, D= 3.725" I 10138' H7"X4-1/2" BKR LTP,D =4.40' I 41/2" TBG, 12.6#, 13CR -80 VAM TOP, --I 10140' 10142' . 1- 14102' VVL EG D = 3.958" .0152 bpf, D = 3.958' I 10147' I—I ELMD TT LOG ON JWXX(XX I 10159' Hr x 4-112" XO, D= 3.90 I 17" UM , 26#, L -80, .0382 bpf, D = 6276' H 10309' / I 1 10657' - 10684' I 4-1/2' BKR STRADDLE PACKER D = 2.3 8" 12/22/12) II ili 10736' --1C CEP (09/01/09) I I MID H 10893' I I I :1:, 1 4-1/2" LNR, 12.6#, L -80, .0382 bpf, D= 3.958' H 10978' r A DATE REV BY COMVENTS DATE REV BY COMMENTS PRUD DE BAY LINT 06/05171 IMTIAL CCWIPLETION 12/02/12 PJC REFOR AAT#IG WH.L: F-06A 06/07/83 RWO 12/26/12 A M PJC SET LITER KB PKR (12/22/12) PBS.IT No: "2031490 12122/94 N2ES ' RWO API No: 50-029-20097-01 12/02/02 4E5 RVYO SUSPENDED SEC 2, T11 N, R13E, 2508' FSL & 2401' FW.. 02111/03 DAC/KK RWO 09/27/03 D1AC/TLH SIDETRACK (F -06A) 8P Exploration (Alaska) i DATE: S -Nov12 Stephanie Pacillo TRANS #: 6192 Data Delivery Services Technician _ z Bender Schlumherger Oilfield Services -1. \ .. Natural Resources Technician II WIRELIKE . WIR Gambell St, Ste. 400 Alaska Oi� & Gas Conservation Commission 332 . . .�,>• , 'i ?Ave, =.,�� _life ICJ r..rc.- <c- - f.. r.; :;'-i=--7.)-1 ; Anchorage, AK 99503 _ W: Office: (907) 273 -1770 :: t. 1 E gA "V S EAMK . T 0H . ' R,ESERV CNL I►/IECH ' LOG DESCRIPTION . DATE 8/W COLOR CD`S .' NAME ORDER # DIST DIST . DIST DM LOGGED PRIM PRINTS Z -34 BTJ0.00034 X USIT MSIP 8-Sep-12 1 1 CD H -02B C4W7-00035 X PPROF 24- Aug -12 1 1 CD G -29B C1UB -00030 X LEAK DETECTION LOG 13- Sep -12 1 1 CD D -27A C2JC -00056 X LDL W/ WATERFLOW 5- Sep -12 1 1 CD L -100 C3NA -00041 IIIIIIIIIIIIIIEIIIIIIIIIIIIIII SFRT CH FORMATION RESIST!) 15- Oct -12 1 1 CD 06-03A C4W7.00036 CEMENT BOND LOG 15-Sep-12 1 1 CD MPL -08 C600-00036 MEMORY INJECTION PROFILE 10- Aug -12 1 1 CD 15.048 C600-00045 MEMORY PPROF 7- Sep -12 1 1 CD r F -06A C3NA -00038 PPROF W DEFT & GHOST 16-Sep-12 1 1 CD C -20C BCRC -00212 Mill MEMORY PPROF 1- Oct -12 1 1 CD 14-27 C3NA -00039 LEAK DETECTION LOG 17- Sep -12 1 1 CD V -221 BBSK -00135 1111 !PROF W/ WFL 22- Aug -12 1 1 CD MPC-42 C600-00057 _.. MEMORY !PROF 9- Oct -12 1 1 CD MPC -28A 0600.00056 MEMORY IPROF 9- Oct -12 1 1 CD MPL -16A CSXI-00033 MEMORY IPROF 13- Sep -12 1 1 CD C -18B 0600.00053 X MEMORY PPROF 3- Oct -12 1 1 CD NK -22A BYS4-00052 X LEAK DETECTION LOG 4-Sep-12 1 1 CD • MPG-01 C2JC -00054 X RST WATERFLOW LOG 31- Aug -12 1 1 CD 13 -36 BYS4.00053 X LEAK DETECTION LOG 12- Sep -12 1 1 CD X ig44E--- 0 Please return a signed copy to: Please return a signed c y to: BP PDC LR2 -1 SCANNED APR 0 5 2D13 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 ' 1 v i DATE: 17- May -12 Stephanie Pacillo TRANS#: 5958 Pv akanaK Bender Data Delivery Services Technician 4, Schiumherger Oilfield Services . , 4 ,; . w-: a P es, .1 'E S ,.` `' j,l` � : r. II Data & Consulting Services r 2525 Gambell St, Ste. 400 - Anchorage, AK 99503 "_ ilt: Office: (907) 273 -1770 WELL SERVICE OH RESERV CNL MECH LOG DESCRIPTION DATE B/W COLOR CD's NAME # � I T . y WOW , PRINTS PRINTS C - 32C BLPO - 00117 X LDWG EDIT OF MCNL 6- Jul -11 1 1 CD • GC -2E BYS4 -00011 X LDWG EDIT OF RST/WFL 6- Dec -11 1 1 CD F -06A BSM4 -00011 X LDWG EDIT OF RST 2-Jul-11 1 1 CD 03 -30 BINC -00081 X LDWG EDIT RST 16- Nov -11 1 1 CD F -45B BUTT -00013 X LDWG EDIT OF MCNL 29- Aug -11 1 1 CD A-43 BG4H -00086 X LDWG EDIT OF RST 10-Sep-11 1 1 CD N -16 BCRD -00032 X LDWG EDIT OF RST 5- Jul -10 1 1 CD MPI -18 BG4H -00107 X LDWG EDIT OF IBC 25- Dec -11 1 1 CD MPB -50 BCRJ -00096 X LDWG EDIT OF RST/WFL 16- Jul -11 1 1 CD 1- 21/K -25 BG4H -00113 X LDWG EDIT OF RST 18- Feb -12 1 1 CD P -01A BD88 -00193 X LDWG EDIT OF PDC -GR - - 15- Jan -12 1 1 CD Y -19 BINC -00091 X LDWG EDIT OF PDC -GR 9- Jan -12 1 1 CD S X X Please return a signed copy to: Please return a signed copy to: BP PDC LR2 -1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd SCANNED APR 0 5 2013 Anchorage AK 99503 Anchorage AK 99508 i CIS W 04- I _D • • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) 41■31k-t PT 7 -0 - 5 - l4-1 Sent: Wednesday, April 13, 2011 10:46 AM To: 'Engel, Harry R' Cc: Crawford, Gary R; Wyatt, Chris; Cismoski, Doug A; Daniel, Ryan; Hjelmaas, Thor Subject: RE: AOGCC request for information PBU F -06A SVS Response by April 26, 2011 is acceptable. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 � APP 4 907 - 793 -1236 Q + +� From: Engel, Harry R [mailto:Harry.Engel @bp.com] Sent: Wednesday, April 13, 2011 10:43 AM To: Regg, James B (DOA) Cc: Crawford, Gary R; Wyatt, Chris; Cismoski, Doug A; Daniel, Ryan; Hjelmaas, Thor; Engel, Harry R Subject: AOGCC request for information PBU F -06A SVS Jim - This is a follow up to our telephone conversation this morning regarding the above subject. The subject request for information dated March 24, 2011 was addressed to Mr. Thor A Hjelmaas. Mr. Hjelmaas is relocating to an assignment in the United Kingdom. Consequently the request was received by our Operations team approximately April 12, 2011. As we discussed, BP will respond to the subject request by close of business on April 26, 2011. Sincerely, Harry Engel 4/13/2011 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ,~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ Performed: Alter Casing ~ Puli Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ PerForate Q Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~lopment ~ Exploratory ~ 203-1490 ~ 3. Address: P.O. Box 196612 Stratigraphic ~` Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20097-01-00 / 7. KB Elevation (ft): 9. Well Name and Number: 66.61 KB PBU F-06A v 8. Property Designation: 10. Field/Pool(s): ADLO-028277 / PRUDHOE BAY Field/ PRUDHOE OIL Pool ~ 11. Present Well Condition Summary: Total Depth measured 10893 ~ feet Plugs (measured) None true vertical 9095 feet Junk (measured) None Effective Depth measured 10893 feet true vertical 9095 feet Casing Length Size MD ND Burst Coilapse Conductor 87 30" Conductor 30 - 111 30 - 111 Intermediate 2242 13-3/8" 68# K-55 28 - 2270 28 - 2269 3450 1950 Intermediate 6569 9-5/8" 47# N-80 2270 - 8839 2270 - 7801 6870 4760 Liner 842 4-1/2" 12.6# L-80 10140 - 10982 8636 - 9147 8430 7500 Production 8624 7" 26# L-80 29 - 8653 29 - 7656 7240 5410 Liner 1665 7" 26# L-80 8646 - 10311 7651 - 8743 7240 5410 Surface 2288 18-5/8" 96.5# K-55 29 - 2317 29 - 2317 930 870 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 27 - 10143 0 0 - Packers and SSSV (type and measured depth) 7" Top Packer 8657 4-1/2" Baker S-3 Hydro Set Packer 10084 4-1/2" Top Packer 10148 0 0 12. Stimulation or cement squeeze summary: . ,a~ ~ r. ~ ~~,~ Intervals treated (measured): . ~ ~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1191 44808 3385 1153 Subsequent to operation: 1584 46698 4400 1150 14. Attachments: 15. Well Class after qroposed work: Copies of Logs and Surveys Run EXpIOP2tOry ~ D@Vi210pmellt ~': S@t1AC@ ~ Daily Report of Weil Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG I~ GINJ ~ WWJ (~ 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: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 9/11/2009 - _~ ~:~ ~. ~- s ~ ~/ ~ ~;.!L~ ~Z _"~i ~ ~~-~ F-06A 203-149 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base F-06A 10/12/03 PER 10,666. 10,676. 8,960.42 8,966.45 F-06A 10/12/03 PER 10,684. 10,692. 8,971.27 8,976.08 F-06A 10/12/03 PER 10,703. 10,721. 8,982.69 8,993.48 F-06A 10/12/03 PER 10,745. 10,755. 9,007.81 9,013.77 F-06A 9/3/09 APF 10,703. 10,721. 8,982.69 8,993.48 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • # • F-06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL ~ • ~_ ti~.~.- - 11 ~ ~ 111 ~ ~~ 03~0~ zoos DO NOT PLACE _~ ~~,~ °~ ANY NEW MATERIAL UNDER THIS PAGE F:~L.aserFiche\CvrPgs_Inserts\Microfilm Marlcer.doc 7s Scbhnburg8P Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, At( 99503-2838 ATTN: Beth 04/05/07 NO. 4210 :JD3 -[Lie>¡ Jf 145~MED þ..?R 1 () 'L007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 WII J b# 'f e 0 og escnptlon ae o or W-25 10980555 RST (REDO) 05/02/05 1 N··07A 11296715 RST 09/11/06 1 1 F-06A 11258688 RST 03/03/06 1 1 18-16B 11588702 MCNL 12/27/06 1 1 011-09 11320999 RST 08/02/06 1 1 X-15A 10928631 MCNL 05/11/05 1 1 011-09 11223132 RST 08/02/06 1 1 3-17F/K-30 10728392 MCNL 03/12/04 1 1 L D PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. :~g~t~~~~i~:~ ~~~~center LR2-1 R E C E.I VE 0 Anchorage. Alélska 99508 Date Delivered: APR 0 6 7007 f\laska Oil & Gaí; Coos. commission AnchoragE: Field: Prudhoe Bay D t CI CD BL . . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 "'''''''0'0. AK ""'U ATTN: Beth ê. Received by:... ~ Schlum~erger SCANNED SEP 14 2DUo Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth ;}ð3 -/¿f9 NO. 3941 Company: ~: r-- .,,-.. ..... . '\, ) t\¡-- " '" .~~~j J.::; ,~uô 08/28/06 ~ CiI & Gas Cens. CcrrdT1iW:n Anchorage State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 WI! D BL Field: Prudhoe Bay CD e 0 og escnptlon ate o or C-11A 11225983 LDL 07/02/06 1 B-25 11217247 LDL 05/11/06 1 F-06A 11258688 PROD PROFILE W/DEFT 03/20/06 1 G-18A 11209612 MEM INJECTION PROFILE 07/19/06 1 P-24 11216206 MEM INJECTION PROFILE 07/06/06 1 B-28 11221590 LDL 07/04/06 1 B-01 11211508 PROD LOG W/DEFT 06/23/06 1 W-39A 11216197 MEM PROD PROFILE OS/29/06 1 Z-02A 11212856 INJECTION PROFILE 05/02/06 1 G-03A 11211493 LDL OS/24/06 1 C-26A 11225979 LDL 06/07/06 1 F-26B N/A MEM PROD & INJECTION 06/06/06 1 F-26B N/A MEM BORAX LOG 06/06/06 1 W-39A 11216197 MEM BORAX LOG OS/29/06 1 F-04A 11221602 SCMT 08/18/06 1 Y -OBA 11221604 SCMT 08/20/06 1 C-06B 11212883 USIT 08/15/06 1 X-27 11217274 USIT 08/26/06 1 K-07D 10942217 MEMORY SCMT 06/15/05 1 Y-10A 11209611 MEM INJECTION PROFILE 07/18/06 1 F-12 11225984 LDL 07/02/06 1 K-07D 11058256 SBHP SURVEY 11/28/05 1 X-04 10919925 PROD PROFILE W/DEFT 12/15/04 1 A-30A 11054295 CH EDIT OF PDC LOG W/GR 04/06/05 1 17-04B 40010183 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 03/09/04 1 1 Z-30A 40010092 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 01/27/04 1 1 17-04B PB1 40010183 OH EDIT OF MWD/LWD 03/08/04 2 1 L D J b # Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 CI . . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth e e WELL LOG TRANSMITTAL eJ03-/4Q To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 I :3 Cø31 RE: MWD Formation Evaluation Logs F-06A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 F -06A: LAS Data & Digital Log hnages: 50-029-20097-01 1 CD Rom ~ J{ al/o¿ DATA SUBMITTAL eOMPLIANeE REPORT 12/13/2005 Permit to Drill 2031490 Well Name/No. PRUDHOE BAY UNIT F-06A Operator BP EXPLORATION (ALASKA) INC ~ I ~ 1¡f .tè-~j API No. 50-029-20097-01-00 MD 10981"" TVD 9147" Completion Date 10/11/2003 r- Completion Status 1-01L Current Status 1-01L UIC N Mud Log No Samples No Directional ç Yes ~ ) REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: DIR, GR, RES, DEN, NEU (data taken from Logs Portion of Master Well Data Maint Log/ Data Type I Electr Digital Dataset Med/Frmt Number Name Log Log Scale Media Run No Interval OH / Start Stop CH Received Comments . .....I3PV Directional Survey 8761 10980 1 0/1 0/2003 ¡;,Ø D 12464 I nd uction/Resistivity 2-5 8629 10922 3/18/2004 GR, EWR4, CNP, SLD, ROP RPt/ LIS Verification 2-5 8629 10922 3/18/2004 GR, EWR4, CNP, SLD, ROP ED D Lis 12464 Neutron 2-5 8629 10922 3/18/2004 GR, EWR4, CNP, SLD, I ROP ED D Lis 12464 Density 2-5 8629 10922 3/18/2004 GR, EWR4, CNP, SLD, ROP . ED D Lis 12464 Rate of Penetration 2-5 8629 10922 3/18/2004 GR, EWR4, CNP, SLD, . ROP Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments Permit to Drill 2031490 MD 10981 TVD 9147 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? v I f\ Analysis Received? ~V / N Comments: Compliance Reviewed By: ~_ DATA SUBMITTAL eOMPLIANeE REPORT 12/13/2005 Well NamelNo. PRUDHOE BAY UNIT F-06A Operator BP EXPLORATION (ALASKA) INC Completion Date 10/11/2003 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? ® 6N Formation Tops u c Date: API No. 50-029-20097-01-00 ,~DFc~~'Or . . . 803 -I Lfer . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7tlJ. Avenue, Suite 100 Anchorage, Alaska March 09, 2004 RE: MWD Fonnation Evaluation Logs F-06A, AK-MW-2661658 1 LDWG fonnatted Disc with verification listing. / t} J.../ w LI PùPI#: 50-029-20097-01 -\ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~N\~ JY'\.~'-~\. RECEIVED p .", A¡ 0 1)004 1'~/-",,~_< U Lu . . . '1'1 ¡¡ n .... /",,, ' . p~~5Ka 19h!;1( uë5lJOOS. wmm~n Ainl"hM'°9'" f ~.~~~5~~ug ç; RBDMS RD MAR ~ n ?OOIf A STATE OF ALASKA . ALAS~IL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter CasingD Change Approved Program D 2. Operator SuspendD RepairWellD Pull TubingD Operation ShutdownD Plug PerforationsD Perforate New Pool 0 4. Current Well Class: Perforate Œ] WaiverO Stimulate D Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 203-1490 Name: BP Exploration (Alaska), Inc. Development 00 ExploratoryD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Stratigraphic 0 ServiceD 9. Well Name and Number: F-06A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 66.61 8. Property Designation: ADL-028277 11. Present Well Condition Summary: Total Depth measured 10983 feet true vertical 9148.0 feet Plugs (measured) Effective Depth measured 10895 feet Junk (measured) true vertical 9096.4 feet Casing Length Size MD TVD Conductor 81 30" Conductor 30 111 30.0 111.0 Intermediate 2242 13-3/8" 68# K-55 28 - 2270 28.0 2269.9 Intermediate 6569 9-5/8" 47# N-80 2270 - 8839 2269.9 7800.6 Liner 842 4-1/2" 12.6# L-80 10140 - 10982 8635.6 9147.4 Production 8624 7" 26# L-80 29 - 8653 29.0 7656.4 Liner 1665 7" 26# L-80 8646 - 10311 7650.9 8742.7 Surface 2288 18-5/8" 96.5# K-55 29 - 2317 29.0 2316.9 Perforation deDth: Measured depth: 10666 -10676,10684 -10692,10703 -10721,10745 -10755 True vertical depth: 8960.42 - 8966.45,8971.27 - 8976.08,8982.69 - 8993.48,9007.81 - 9013.77 Tubing ( size, grade, and measured depth): 4-112" 12.6# 13Cr80 @ 27 10143 @ 10084 @ 10148 @ 8657 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Hydro Set Packer 4-1/2" Liner Top Packer 7" Liner Top Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 OtherD 6. API Number 50-029-20097-01-00 None None Burst Collapse 3450 1950 6870 4760 8430 7500 7240 5410 7240 5410 930 870 RECEIVED FEe 7 92004 Alasks ON 8: Ct1 r . ~ VOOs. ('-m . . An,.., V\I. ml1Ji;'IQI' "'"(;'1'&"'1''' .c "" ' d 4~5,-,) Oil-Bbl ReDresentative Daily Averaoe Production or Iniection Data Gas-Me! I Water-Bbl I Casing Pressure I Tubing Pressure New Well - No Prior Production Prior to well operation: Subsequent to operation: 1326 3.86 972 14. Attachments: 15. Well Class after proposed work: ExploratoryD o 265 Development ŒI Service 0 16. Well Status after proposed work: Operational Shutdown D Oil 00 GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Copies of Logs and Surveys run_ Daily Report of Well Operations _ ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron 111 Gi:wt.. Form 1 0-404 Revised 12/2003 Phone 564-4657 Production Technical Assistant 2/13/04 Title Signature IfØJM~ ~fL ftH GJ Z~U~ Date . . F-06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/11/03 RST LOG THREE PASSES FROM 10836'-10300'. JEWELRY LOG FROM 10836'-8300'. PERFORATED 10666'-10676', 10684'-10692', 10703'-10721' AND 10745'-10755' WITH 2 7/8" POWERJET, 6 SPF, PENE 27.7", EH 0.36",15 GMS. TAG TD STICKY AT 10836'. FLUIDS PUMPED BBLS o I TOTAL No Fluids Pumped Page 1 '" / TREE = 4"OW . WELU-EA D = McEV OY ACTUATOR = BAKER KB. ELBI = 62.06' BF. ELBI = 36.61' KOP = 2862' ~xAngle= 54@ 10915' Datum IIÐ = 10279' Datum lVD = 8800' Ss 113-3/8" CSG, 68#, K-55, ID = 12.415" H 19-518" SCAB LNR, ID = 8.681" H 2259' 2266' 118-518" CSG, 96.5#, K-55, ID = 17.655" H 2306' Minimum ID = 3.725" @ 10130' 4-1/2" HES XN NIPPLE 17" CSG, 26#, L-80, ID = 6.276" H 8651' I TOP OF WHPSTOO< H 8839' ÆRFORA TON SUMlt1ARY REF LOG: SPERRY MND ON 09/25iV3 ANGLE AT TOP PERF: 53 @ 10666' Note: Refer to Production DB for historical perf data SIZE SA' INìERVAL Opn/Sqz DATE 2-7/8" 6 10666-10676 0 10/11/03 2-7/8" 6 10684 - 10692 0 10/11/03 2-7/8" 6 10703-10721 0 10/11/03 2-7/8" 6 10745- 10755 0 10/11/03 (TOP OF 7' LNR H 9202' I ... . 19-518" CSG, 47#, N-80, SEAL LOCK, ID = 8.681" H 9703' ------ ~ 17" LNR, 29#, N-80, SEALLOCK, ID = 6.184" H 10684' ( 14-1/2" lBG, 12.6#, 13CR-80, .0152 bpf, ID= 3.958" H 10140' I IT' LNR, 26#, L-80, .0382 bpf, ID = 6.276" H 10309' [)6. TE RBI BY COMlt1ENTS 08107f72 INITIAL COMPLETION 06107/83 RWO 12/22/94 MDO RWO COMPLETION 12102102 DDN/KK RWO SUSPEtÐED 02/11103 DAC/KK 2ND RWO 09/27103 DACITLH SIŒTRACK (F-06A) F-06A ~ I SAF~Y NOTES: ***4-1/2" CHROME TBG*** d r--1 192T H9-5I8" LNR TOP A<R, ID = 8.575" -r 1 2195' H4-1/2" HES X NIP, ID = 3.813" I < ~ 2259' H 13-318" X 9-5/8" XO 1 ~ ~ GAS LIFT MlINDRB.S ST MD TVD DBI TYÆ VLV LATCH FDRT DATE L 5 3051 3045 14 KBG-2 DMY BK 0 09/25103 - 4 4040 3964 31 KBG-2 DOME BK 16 10/10/03 3 6247 5544 32 KBG-2 DOME BK 16 10/10/03 2 7657 6799 25 KBG-2 DOME BK 16 10/10/03 1 9237 8054 53 KBG-2 SO BK 24 10/10/03 , , 8656' H 9-518" X 7" BKR LNR TOP PKR, ID = 6.280" 1 I MILLOUT WIf\ÐOW: 8839 ' - 8855' 11: 10059' H4-1/2"HEBXNIP,ID=3.813" 1 0083' H 7" X 4-1/'Z' BKR S-3 PKR, ID = 3.875" 1 10109' H4-1/2" HEB X NIP, ID= 3.813" I 10130' H4-1/2" I-ESXNNIP, ID= 3.725" 1 10138' HT' X 4-.1/'Z' BKRLNR I TOP FKR, ID = 4.40" 10142' H4-1/2"WLEG, ID =3.958" 1 ( 10147' HELMDTTLOG I I NOT AVAILABLE 10159' Hr X4-1/2" XO, ID = 3.90" I IPBTD H 10893' 14-1/2" LNR, 12.6#. L-80, .0382 bpf, ID = 3.958" H 10978' DA ìE REV BY COMIvENTS 10/10103 JCM/lLH GLV C/O 10/12/03 CJS/TI.H INITIAL PERFS PRLÐI-OE BAY lJ'-JIT WELL: F-06A PERMrr f\b: 2031490 AA f\b: 50-029-20097-01 SEC 2, T11N, R13E, 277'Z FN... & 2879' FEL BP Exploration (Alaska) . STATEOFALASKA a ALASKA. AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 30" Surface 100' 36" 18-5/8" 96.5# K-55 Surface 2306' 24" 13-3/8" x 9-5/8" 68#/47# K-55/L-80/N-80 Surface 8839' 17-1/2" 9-5/8" 47# L-80 1927' 2270' Scab Lnr 7" 26# L-80 25' 10309' 8-1/2" 4-1/2" 12.6# L-80 10138' 10980' 6-1/8" 23. Perforations open to Production (MD + rvD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-7/8" Gun Diameter, 6 spf MD rvD 10666' - 10676' 8960' - 8966' 10684' - 10692' 8971' - 8976' 10703' - 10721' 8983' - 8993' 10745' - 10755' 9008' - 9014' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2772' SNL, 2879' WEL, SEC. 02, T11 N, R13E, UM Top of Productive Horizon: 1225' NSL, 3539' WEL, SEC. 35, T12N, R13E, UM Total Depth: 1550' NSL, 3339' WEL, SEC. 35, T12N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 651961 y- 5974028 Zone- ASP4 TPI: x- 651215 y- 5978011 Zone- ASP4 Total Depth: x- 651408 y- 5978339 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: DIR, GR, RES, DEN, NEU MD 26. Date First Production: October 16, 2003 Date of Test Hours Tested PRODUCTION FOR 10/22/2003 4 TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ....... Press. 216 24-HoUR RATE""'" 27. One Other 5. Date Comp., Susp., or Aband. 10/11/2003 6. Date Spudded 9/18/2003 7. Date T.o. Reached 9/24/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 66.61' 9. Plug Back Depth (MD+ rvD) 10893 + 9095 Ft 10. Total Depth (MD+ rvD) 10981 + 9147 Ft 11. Depth where SSSV set (Nipple) 2195' MD 19. Water depth, if offshore N/A MSL 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-149 13. API Number 50- 029-20097-01-00 14. Well Number PBU F-06A 15. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028277 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 300 sx Permafrost II 5200 sx Permafrost II 1700 sx Class 'G', 1550 sx PF II 144 sx Class 'G' 315 sx Class 'G', 136 sx Class 'G' 117 sx Class 'G' SIZE 4-1/2", 12.6#, 13Cr80 TVD DEPTH SET (MD) 10142' PACKER SET (MD) 10083' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 75 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-Bsl 1,296 Oll-Bsl 7,776 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach &ê)itaié sheøt, ifneçessary). Submit core chips; if none, state "none"r-;:11r;¡;-r.:-~¡;;;;¡ .. v,.',"" L~ i '·IJ¡<.J i r . ~ . i .~.,ø~)9.,J . - ~ED None Form 10-407 Revised 2/2003 GAs-McF 3,785 GAs-McF 22,710 W A TER-Bsl 1,324 W A TER-Bsl 7,944 ORIGINAL CONTINUED ON REVERSE SIDE ts> f RBDMS BfL OCT 2 I, 200~ CHOKE SIZE I GAS-Oil RATIO 96° 2,920 Oil GRAVITY-API (CORR) 25.8 o 'ii': 28. GEOLOGIC MARKERS. NAME MD Sag River 10312' Shublik 10381 ' Sadlerochit 10505' Top CGL 10696' Base CGL 10783' 29. .RMATJON TESTS TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 8743' None 8786' 8862' 8978' 9030' :) 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~QAr\;(J ~ Title Technical Assistant PBU F-06A Well Number Date '°f a3/'03 203-149 Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Jim Smith, 564-5773 Permit No. / Approval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 (JR\G\\\J¡\L t Page 1 of 1 EMW 12.01 (ppg) 9.66 (ppg) t BP EXPLORATION Leak-Off Test Summary Leak Off Pressure (BHP) 4,890 (psi) 4,393 (psi Surface Pressure 290 (psi 550 (psi AMW .._.._.......... ..__ ·_"w__..__ 11.30 (ppg) 8.45 (ppg) Test Depth (TVD) 7,836.0 (ft) 8,755.0 (ft) M.·.._........._.. Test Depth (TMD) 8,871.0 (ft) 0,329.0 (ft) Legal Name: F-06 Common Name: F -06A .--.-.....---.- ....--.....-- Test Date Test Type .- ·_·_..·....·.··__n 9/17/2003 FIT 9/22/2003 FIT Printed: 9/29/2003 9:07:07 AM ,., .. Page 1 of 10' BP EXPLORATION Operªtions Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/9/2003 9/10/2003 9/11/2003 F-06 F-06A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES I . FrOin - To I Hours Task .~ ! . 00:00 - 03:00 ~.~~e I NPT P PRE Phase 3.00 MOB 03:00 - 21 :00 18.00 RIGU P PRE 21 :00 - 21 :30 0.50 RIGU P PRE 21 :30 - 00:00 2.50 CLEAN P DECOMP 00:00 - 01 :30 1.50 CLEAN P DECOMP 01 :30 - 02:30 1.00 CLEAN P DECOMP 02:30 - 05:00 2.50 CLEAN P DECOMP 05:00 - 07:30 2.50 WHSUR P DECOMP 07:30 - 10:30 3.00 BOPSURP DECOMP 10:30 - 17:00 6.50 BOPSUR P DECOMP 17:00 - 18:30 1.50 PULL P DECOMP 18:30 - 19:00 0.50 PULL P DECOMP 19:00 - 19:30 0.50 PULL P DECOMP 19:30 - 22:00 2.50 PULL P DECOMP 22:00 - 22:30 0.50 PULL P DECOMP 22:30 - 23:30 1.00 BOPSURP DECOMP 23:30 - 00:00 0.50 DHEQP P DECOMP 00:00 - 01 :30 1.50 DHEQP P DECOMP 01 :30 - 03:00 1.50 DHEQP P DECOMP 03:00 - 05:30 2.50 DHEQP P DECOMP 05:30 - 06:30 1.00 DHEQP P DECOMP 06:30 - 08:00 1.50 DHEQP P DECOMP 08:00 - 09:00 1.00 DHEQP P DECOMP 09:00 - 09:30 0.50 DHEQP P DECOMP 09:30 - 10:30 1.00 DHEQP P DECOMP 10:30-11:00 0.50 DHEQP P DECOMP 11 :00 - 12:30 1.50 DHEQP P DECOMP 12:30 - 13:00 0.50 DHEQP P DECOMP 13:00 - 14:30 1.50 DHEQP P DECOMP Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: 2ES Spud Date: 5/1/1997 End: Description of Operations "._ ".h____..·_ ._... ._._ Hold Pre-Job Safety Meeting. Disconnect utilities between sub base and pit complex. Rig Down Can Rig top drive. Bridal up derrick and dress out derrick to layover. Layover derrick. Jack up sub base and move off well. Hold Pre-Job Meeting with GPB Security, Tool Service Personal and, Nabors 2ES Rig team regarding move to F-06A. Move sub base from Drill Site 02-14A to F-06A. Leave location with sub base at 03:15 Hours. Layout matting boards and Herculite. Position rig over well. Position pump and pit complex. Spot truck shop and welding shop. Position camp. Hook up utalities and lines between modules. Accept rig for work at 21 :00 hrs. Hold pre-spud meeting with all personnel. Receive sea water. Rig up lines to circulate and kill well. Tubing pressure 0 psi. Casing pressure 0 psi. Install secondary valve on annulus. Rig up circulating lines to well head. Rig up lubricator and pull BPV from tubing hanger. 0 psi on tubing. Circulate out freeze protect diesel with sea water at 4.5 bpm with 220 psi. Install TWC and test same from below. Nipple down tree and remove from cellar. Check threads on tubing hanger. Nipple up BOP. Adjust riser to fit lower well head in cellar. Install test plug. Test BOP, 250 psi low and 3500 psi high. Test witnessed by AOGCC Lou Grimaldi. Rig up lubricator and pull TWC. Unseat tubing hanger and pull to floor. Rig up tongs and 4 1/2" handling equipment Lay down tubing hanger. POH and lay down 51 Its 4 1/2" 12.6# L-80 IBT-M tubing. Rig down 4 1/2" handling equipment and tongs. Install test plug and test lower pipe rams to 250 psi low and 3500 psi high. Pick up clean out milling assembly. Pick up milling clean out BHA. 8 1/2" junk mill, 11 1/2" string mill, drill collars and HWDP. Pick up 5" drill pipe and RIH to top of 95/8" casing at 2270'. Indication of passing through FO cementer at 2017'. Circulate and pump high vis pill around at 12 BPM with 600 psi. POH to BHA Stand back BHA. Lay down mills. Clear floor. Pick up BHA with 12 1/4" bit and 13 3/8" casing scraper. RIH to 1975'. Circulate at 12 BPM with 600 psi. Test casing to 500 psi for 10 minutes. Noted a pressure increase on the outer annulus to 650 psi. POH to BHA Stand back BHA Lay down bit and scraper and jars. Clear rig floor. Make up 13 3/8" RTTS packer. RIH with RTTS on 5" drill pipe to 1967'. Printed: 9/29/2003 9:07:23 AM .,. .. BP EXPLORATION "'Operations Summary Report Page 2qf 10 Circulate with 100 deg sea water at 3 bpm with 40 psi. Set RTTS at 1963'. Test casing with 2400 psi for 30 minutes. Rig up hot oil unit and test lines. Apply 1500 psi on 5" drill pipe X 13 3/8" annulus. Pump 290 bbl100 deg diesel down drill pipe and up 13 3/8" x 18 5/8" annulus at 2.5 BPM with 150 psi. Displace diesel in drill pipe to sea water. Rig down hot oil unit. POH to BHA Stand back BHA and lay down RTTS. Rig up to run 9 5/8" liner. Rig up to run 9 5/8" liner. Hold PJSM with crew. Make up floats and check same. Run 8 joints 9 5/8" 47# L-80 NSCC liner. Make up HMC 13 3/8" x 9 5/8" liner hanger. Check up and down weights. Circulate 1.5 liner volume. RIH with 9 5/8" liner to 2240' on 5" drill pipe from derrick. Pick up 16 joints 5" drill pipe from pipe shed. Rig up cementing head and lines. Run in and tag up on top of 95/8" cross over at 2270'. Circulate. Hold PJSM with drilling crew, cementers and truck drivers. Drop ball and set liner hanger. 8.525 OD guide at 2270', float colar with baffle at 2230' and landing collar at 2185'. Top of 9 5/8" liner at 1906' DECOMP Pump 5 bbl fresh water. Test lines to 4500 psi. Pump 5 bbl CW100. Pump15 bb111.5 ppg Mudpush II. Mix and pump 30 bbl (144 sx) 15.8 ppg cement. Drop pipe wiper dart and displace with 54 bbl viscous sea water at 5 bpm. Bump plug. Pressure up to 4200 psi to set ZXP liner top packer. Cement in place at 07:36 hrs. Unsting from liner hanger. Circulate at 12 bpm with 1800 psi. Return 2 bbls of contaminated cement on bottoms up. Rig down cement head and lines. POH. Lay down 5" drill pipe. Lay down liner running tools. Change out saver sub on top drive from 4 1/2" IF to 4" HT-40. Service top drive. Make up 81/2" bit and RIH with BHA Change out handling equipment to 4". RIH with 8 1/2" drilling BHA to 1920'. Pick up 4" drill pipe from the pipe shed. Drill pack off bushing in liner hanger. Run in to 2185'. Drill float equipment and firm cement to 2420'. Circulate around 30 bbl high vis sweep at 12 bpm with 1200 psi. Pick up to next tool joint. Make up Storm packer and set at 35'. Bit depth 2380'. Test packer to 500 psi. Nipple down BOP. Nipple down 20" 3000 X 13 5/8" 5000 spool. Nipple down 20" 3000 X 13 5/8" 5000 spool. Remove old packing, seals and plates. Clean 13 3/8" casing packing and seal area. Install new packing and plates. Torque down seal plates. Install new 20" 3000 X 13 5/8" 5000 spool. Fill void Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-06 F-06A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES I Date From.:To Hours Task Code NPT Phase 9/11/2003 14:30 - 16:30 2.00 DHEQP P DECOMP 16:30 - 17:30 1.00 DHEQP P DECOMP 17:30 - 18:00 0.50 DHEQP P DECOMP 18:00 - 21 :00 3.00 DHEQP P DECOMP 21 :00 - 21 :30 0.50 DHEQP P DECOMP 21 :30 - 22:30 1.00 DHEQP P DECOMP 22:30 - 23:30 1.00 DHEQP P DECOMP 23:30 - 00:00 0.50 DHEQP P DECOMP 9/12/2003 00:00 - 01 :30 1.50 DHEQP P DECOMP 01 :30 - 03:00 1.50 DHEQP P DECOMP 03:00 - 03:30 0.50 DHEQP P DECOMP 03:30 - 04:00 0.50 DHEQP P DECOMP 04:00 - 05:00 1.00 DHEQP P DECOMP 05:00 - 05:30 0.50 REMCM-P DECOMP 05:30 - 07:00 1.50 REMCM-P DECOMP 07:00 - 08:00 1.00 REMCM-P 08:00 - 09:00 1.00 REMCM-P DECOMP 09:00 - 10:30 1.50 DHEQP P DECOMP 10:30-11:30 1.00 DHEQP P DECOMP 11 :30 - 12:00 0.50 DHEQP P DECOMP 12:00 - 13:00 1.00 DHEQP P DECOMP 13:00 - 13:30 0.50 DHEQP P DECOMP 13:30 - 15:30 2.00 DHEQP P DECOMP 15:30 - 20:00 4.50 DHEQP P DECOMP 20:00 - 21 :00 1.00 DHEQP P DECOMP 21 :00 - 22:00 1.00 DHEQP P DECOMP 22:00 - 23:30 1.50 DHEQP P DECOMP 23:30 - 00:00 0.50 DHEQP P DECOMP 9/13/2003 00:00 - 13:30 13.50 WHSUR P DECOMP Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: 2ES Spud Date: 5/1/1997 End: Description of Operätions _ __.___._._" _,,__ ~..n___ Printed, 9/29/2003 9,07:23 AM . . Page 3'Òf 10 BPEXPLORATION Operations SUrn'märy Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-06 F-06A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task! Code NPT Pha~ë 9/13/2003 00:00 - 13:30 13.50 WHSUR P 13:30 - 14:00 0.50 WHSUR P 14:00 - 15:30 1.50 DHEQP P 15:30 - 16:00 0.50 DHEOP P 16:00 - 22:30 6.50 DHEQP P 22:30 - 00:00 1.50 DHEQP P 00:00 - 00:30 0.50 DHEOP P 00:30 - 01 :00 0.50 DHEQP P 01 :00 - 03:30 2.50 DHEQP P 03:30 - 08:00 4.50 DHEQP P 08:00 - 10:30 2.50 DHEQP P 10:30 - 13:00 2.50 DHEQP P 13:00 - 14:30 1.50 DHEQP P 14:30 - 15:00 0.50 DHEQP P 15:00 - 16:30 1.50 DHEQP P 16:30 - 19:00 2.50 DHEQP P 9/14/2003 19:00 - 20:30 1.50 DHEQP P 20:30 - 21 :30 1.00 DHEQP P 21 :30 - 22:00 0.50 DHEQP P 22:00 - 00:00 2.00 DHEQP P 9/15/2003 00:00 - 01 :00 1.00 DHEQP P 01 :00 - 02:30 1.50 DHEQP P 02:30 - 03:00 0.50 DHEOP P 03:00 - 05:30 2.50 DHEQP P 05:30 - 06:30 1.00 DHEQP P 06:30 - 08:30 2.00 STWHIP P 08:30 - 09:30 1.00 STWHIP P 09:30 - 11 :30 2.00 STWHIP N 11 :30 - 12:00 12:00 - 15:00 0.50 STWHIP N 3.00 FISH N 15:00 -16:00 1.00 FISH N DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP WEXIT WEXIT DPRB WEXIT Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: 2ES Spud Date: 5/1/1997 End: Description of Operatioos",: between flanges with plastic sealer and test to 1200 psi for 15 minutes. Nipple up BOP while filling void with sealer. Test 20" 3000 flange to 250 psi low and 3500 psi high. Release storm packer, retrieve and lay down same. Pressure test casing to 2400 psi for 15 minutes. RIH to 2420'. Drill hard cement from 2420' to 2525'. Drill EZSV bridge plug from 2525' to 2527'. Circulate out trapped gas from below packer at 12 bpm with 950 psi. Drill EZSV packer from 2527' to 2528'. Run in the hole to 2550' Circulate bottoms up at 12 bpm with 950 psi. Gas to surface. Circulate out trapped gas at 12 bpm with 950 psi. RIH. Pick up 4" drill pipe from pipe shed. Tag up at 9025' PBTD. Ciruclate around 30 bbl high vis sweep. Gas on bottoms up. Circulate out gas at 12 bpm with 1800 psi. POH to BHA. Stand back BHA. Clean junk subs. Recovered pieces of EZSV and aluminum guide from junk subs. Install wear bushing. Run BHA with bit and full guage mill 8.51" OD. RIH to 8994'. Clear obstruction at pack off bushing in liner hanger, make wiper pass through 9 5/8" float equipment depth. Circulate around 30 bbl high vis sweep at 13 bpm with 2750 psi. Slip and cut drilling line 80'. Service top drive. POH to 2369' POH to BHA. Stand back BHA. Lay down bit, junk subs and mill. Recover pieces of aluminum guide from junk subs. Clear floor. PJSM with rig crew, Schlumberger and Halliburton. Rig up Schlumberger E-line unit. Run and set 9 5/8" EZSV pridge plug at 8875'. POH E-line tools and rig down unit. Test casing to 2400 psi for 30 minutes. Make up mills and Whipstock with MWD BHA. PJSM. RIH with BHA from derrick. Shallow test MWD tools. Tools plugged. Check surface equipment. POH. Stand back drill collars and HWDP. The bumper sub snagged on the bottom of the wear bushing causing the string to jump. This jarring action caused the 45,000 Ibs shear bolt on the starter mill to part allowing the Whipstock slide to fall down the hole. DPRB WEXIT Lay down mills and MWD tools. DPRB WEXIT Difficulty pulling wear bushing. Flush stack. Pick up bumper sub and pull wear bushing. Bevel inner lip of wear bushing and reinstall. DPRB WEXIT Make up Whipstock retrieving hook on drill collars and HWDP and RIH. Printed: 9/29/2003 9:07:23 AM .... ... BP EXPLORATION Operations Summary Report Page 4 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-06 F-06A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 9/7/1003 Rig Release: 9/26/2003 Rig Number: 2ES Spud Date: 5/1/1997 End: Date From - To Hours Task Code. NPT Phase Description of Operations 9/15/2003 16:00 - 16:30 0.50 FISH N DPRB WEXIT RIH with retrieving hook and tag up at 1916'. 16:30 - 18:00 1.50 FISH N DPRB WEXIT Attempt to engage Whipstock slide with retrieving hook. 18:00 - 18:30 0.50 FISH N DPRB WEXIT POH to BHA. 18:30 - 19:30 1.00 FISH N DPRB WEXIT Stand back BHA and Whipstock retrieving hook. 19:30 - 20:00 0.50 FISH N DPRB WEXIT Pull wear bushing. 20:00 - 21 :00 1.00 FISH N DPRB WEXIT Make up fishing BHA with 8 3/8" OD box tap. 21 :00 - 21 :30 0.50 FISH N DPRB WEXIT RIH with fishing BHA to 1907'. 21 :30 - 22:30 1.00 FISH N DPRB WEXIT Work box tap over fish. Work fish. Max over pull 35,000 Ibs. 22:30 - 23:00 0.50 FISH N DPRB WEXIT POH to BHA. 23:00 - 00:00 1.00 FISH N DPRB WEXIT Stand back BHA. No recovery. No indications of engaging the fish on inside of box tap. 9/16/2003 00:00 - 01 :30 1.50 FISH N DPRB WEXIT Make up Whipstock retrieving hook on BHA. (use 4" DP vs 5" HWDP for flexibilty) 01 :30 - 02:00 0.50 FISH N DPRB WEXIT RIH to top of fish at 1907'. 02:00 - 03:30 1.50 FISH N DPRB WEXIT Work retrieving hook over Whipstock slide. Rotating 360 deg trying to engage fish. Max over pull 35,000 Ibs. Fish shifted down hole 2' and drag increased slightly. PIU weight 88K, S/O weight 88K. 03:30 - 04:00 0.50 FISH N DPRB WEXIT POOH to 895'. 04:00 - 05:30 1.50 FISH N DPRB WEXIT Stand back BHA from 895' to 62'. No recovery. UD J-hook. Clear floor. 05:30 - 09:30 4.00 FISH N DPRB WEXIT Dress 9 5/8" overshot RJU false table. PIU and MIU overshot RIH with BHA to 864'. CIO elevators. 09:30 - 10:00 0.50 FISH N DPRB WEXIT RIH with drill pipe from 864'. 10:00 - 12:00 2.00 FISH N DPRB WEXIT Engage fish at 1,900'. Swallow to 1,907'. Maximum overpull 70K. POOH with drill pipe from 1,907' to 864'. CIO elevators. Standback BHA from 864' to 31'. Recovered whipstock. 12:00 - 15:00 3.00 FISH N DPRB WEXIT Pull fish to floor and release. Break down Overshot assembly. Clear floor. 15:00 -16:00 1.00 FISH N DPRB WEXIT MIU mills. MIU BHA to 987'. 16:00 - 18:30 2.50 FISH N DPRB WEXIT RIH with drill pipe from 897' to 8,863'. Tag EZSV. 18:30 - 21 :30 3.00 FISH P WEXIT Displace well to 11.4 ppg milling fluid. SPR's. 21 :30 - 00:00 2.50 FISH N DPRB WEXIT POOH from 8,863' to 2,766'. 9/17/2003 00:00 - 02:00 2.00 FISH N DPRB WEXIT POOH from 2,766' to 897'. Stand back BHA from 897'. Caliper mills. 02:00 - 03:00 1.00 STWHIP N DPRB WEXIT PJSM. M/U MWD, upload, and shallow flow test 03:00 - 04:00 1.00 STWHIP N DPRB WEXIT MIU and orient whipstock. 04:00 - 10:00 6.00 STWHIP P WEXIT RIH with BHA to 957'. CIO elevators. Continue in hole with drill pipe from 957' to 8,705'. Fill pipe every 3,000 feet Install blower hose. 10:00 - 11 :00 1.00 STWHIP P WEXIT Orient WIS to 64 degrees RHS. Tag EZSV at 8,863'. PIU weight 195K, SIO weight 150K. Set bottom trip anchor with 18K down weight P/U weight 205K. Shear bolt with 37K down weight SPR's. TOW at 8,839', BOW at 8,855'. 11 :00 - 19:00 8.00 STWHIP P WEXIT Mill 8 1/2" window from 8,839' to 8,855'. (5 hours) P/U weight 195K, SIO weight 150K, Rot weight 173K. Torque on 8 - 9K, Torque off 6 - 7K. Drill/MiII8 1/2" hole from 8,855' to 8,871'. (3 hours) 19:00 - 20:30 1.50 STWHIP P WEXIT Work window. Circulate sweep around at 500 gpm and 2,000 psi. Approximately 97 Ibs cuttings recovered. 20:30 - 21 :00 0.50 STWHIP P WEXIT Perform FIT at 8,871' (7,836' tvd) with 11.3 ppg mud and 290 Printed: 9/29/2003 9:07:23 AM ..... .. BP EXPLORATION Ope'rations Summiil)',Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-06 F-06A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES bate From~To Hours task Code NPT Phase ----... .._--"- 9/17/2003 20:30 - 21 :00 0.50 STWHIP P WEXIT 21 :00 - 23:30 2.50 STWHIP P WEXIT 23:30 - 00:00 0.50 STWHIP P WEXIT 9/18/2003 00:00 - 01 :00 1.00 STWHIP P WEXIT 01 :00 - 03:00 2.00 BOPSUR P INT1 03:00 - 06:00 3.00 BOPSUR P INT1 06:00 - 06:30 0.50 WHSUR P INT1 06:30 - 07:30 1.00 DRILL P INT1 07:30 - 08:30 1.00 DRILL P INT1 08:30 - 10:30 2.00 DRILL P INT1 10:30 - 11 :30 1.00 DRILL P INT1 11 :30 - 12:00 0.50 DRILL P INT1 12:00 - 13:00 1.00 DRILL P INT1 13:00 - 13:30 0.50 DRILL P INT1 13:30 - 14:00 0.50 DRILL P INT1 14:00 - 00:00 10.00 DRILL P INT1 9/19/2003 00:00 - 15:30 15.50 DRILL P INT1 15:30 - 17:00 1.50 DRILL P INT1 Page 5 of 10 Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: 2ES Spud Date: 5/1/1997 End: Description of Operations psi surface pressure. EMW 12.0 ppg. POOH from 8,871' to 933'. Handle BHA. Stand back BHA from 400' to 124'. UD BHA, MWD, and mills. Upper mill in gauge. Clear rig floor. Flush stack, clear floor, and blow down surface equipment. CIO upper rams from 3 1/2" X 6" VBR to 7". RlU test joint. Test BOPE and all related valves to 250 psi low and 3,500 psi high. Witness of test waived by Chuck Sheve of the AOGCC. Pull test plug. Set wear bushing. RID test Joint. PJSM. MIU BHA to 80'. Orient. Shallow test MWD tools. RIH with BHA from 80' to 1,028'. PIU 4" drill pipe from 1,028' to 3,840'. Fill pipe at 2,900'. RIH with drill pipe from 3,840' to 6,641'. Fill pipe at 5,710'. Service top drive. RIH with drill pipe from 6,641' to 8,601'. MAD pass with MWD from 8,601' to 8,787'. Orient and slide through window, no problems. Ream undergauge hole from 8,864' to 8,871'. Directional drill from 8,871' to 9,349'. ART = 0.80 hrs, AST = 6.50 hrs, ADT = 7.30 hrs PIU weight 200K, SIO weight 145K, Rot weight 175K. Slide I Rotate 478' (8,871' - 9,349') Slide at TF 75 to 120 RHS to initiate RH turn and build Flow rate 525 gpm, on btm 3,600 psi, off btm 3,400 psi. WOB 8 - 12 K, ROP 60-80 fph Rotate at 30 RPM Flow rate 525 gpm, on btm 3,550 psi, off btm 3,250 psi. Torque on btm 9,000; Torque off btm 8,000 WOB 10 -12K, ROP 80 - 120 fph Directional drill from 9,349' to 10,309'. ART = 6.66 hrs, AST = 2.81 hrs, ADT = 9.47 hrs PIU weight 205K, S/O weight 145K, Rot weight 172K. Slide I Rotate 960' (9,349' - 10,309') Slide at TF 10 LHS to 20 RHS, as needed, to maintain inclination. Flow rate 520 gpm, on btm 3,850 psi, off btm 3,650 psi. WOB 8 - 10 K, ROP 60-80 fph Rotate at 90 RPM FJow rate 520 gpm, on btm 3,850 psi, off btm 3,650 psi. Torque on btm 10 - 12,000; Torque off btm 9 - 10,000 WOB 10 - 12K, ROP 100 - 200 fph Pump sweep, CBU at 515 gpm and 3,900 psi. Monitor well. Printed: 9/29/2003 9:07:23 AM .., - BP EXPLORATION Qperation$.S.þmrt1!äry Report p¡:¡ge 6 öf 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-06 F-06A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: 2ES Spud Date: 5/1/1997 End: Date From - To Hours Task Code NPT Phase Descriptiön 'öf Operations ----------- ..--.- ---.--.-.--- ..-..------ 9/19/2003 15:30 - 17:00 1.50 DRILL P INT1 Static. 17:00 - 18:00 1.00 DRILL P INT1 POOH with drill pipe from 10,309' to 8,839'. 30K over pull at 10,169'. 18:00 - 18:30 0.50 DRILL P INT1 Service top drive. 18:30 - 19:30 1.00 DRILL P INT1 RIH with drill pipe from 8,839' to 10,309'. No problems. 19:30 - 21:30 2.00 DRILL P INT1 Pump sweep and CBU. Spot liner running pill. Monitor well. Drop SSDS ESS with 2.25" rabbit. 21 :30 - 22:30 1.00 DRILL P INT1 POOH with drill pipe from 10,309' to 8,839'. No problems. Blow down surface equipment. 22:30 - 00:00 1.50 DRILL P INT1 POOH with drill pipe from 8,839' to 5,149'. 9/20/2003 00:00 - 02:00 2.00 DRILL P INT1 POOH with drill pipe from 5,149' to 1,028'. 02:00 - 05:30 3.50 DRILL P INT1 CIO handling equipment. UD BHA from 1,028'. Discovered ESS jammed in jars. Download MWD. Clear rig floor. 05:30 - 06:30 1.00 CASE P LNR1 RIU 7" casing equipment. 06:30 - 07:30 1.00 CASE P LNR1 PJSM. MIU float equipment, check floats. 07:30 - 09:00 1.50 CASE P LNR1 MIU 7", 26#, L-80, BTC-M liner to 1,640'. 09:00 - 10:00 1.00 CASE P LNR1 CIO handling equipment. M/U Baker HMC hanger I ZXP liner top packer and 1 stand drill pipe. Circulate a liner volume at 6 bpm and 140 psi. 10:00 - 14:00 4.00 CASE P LNR1 RIH with 7" liner on drill pipe from 1,674' to 8,839'. 14:00 - 14:30 0.50 CASE P LNR1 Circulate one liner and drill pipe volume at 5 bpm and 810 psi. 14:30 - 15:00 0.50 CASE P LNR1 RIH with drill pipe from 8,839' to 10,293'. No problems. 15:00 - 15:30 0.50 CASE P LNR1 MIU cement head, manifold, and circulating lines. 15:30 - 16:30 1.00 CASE P LNR1 Break circulation. Tag bottom at 10,309'. Stage pump rate up to 6 bpm and 1,370 psi. 16:30 - 18:00 1.50 CEMT P LNR1 PJSM. Pump 5 bbl water and test lines to 4,500 psi. Pump 25 bb112.0 ppg MudPUSH, 63 bb115.8 ppg class 'G' cement slurry. Wash lines, drop plug. Displace with Dowell at 5 bpm. Bump plug at 142.8 bbl displacement. Bump to 3,600 psi. CIP at 17:50 hrs. Verify hanger set with 60K down weight. Check floats. O.K. 18:00 - 19:30 1.50 CEMT P LNR1 Rotate 20 RHT to release from hanger. Increase pump pressure to 1,000 psi. Sting out, circulate 500 strokes at 185 spm. Reduce rate to 55 spm, slack off to set liner top packer. Good surface indication of shear. Circulate bottoms up at 12.5 bpm and 3,950 psi. Trace of cement strung out in returns. 19:30 - 20:00 0.50 EVAL P LNR1 Pressure test liner top packer to 2,400 psi for 10 minutes. 20:00 - 22:00 2.00 CASE P LNR1 Displace well to seawater at 12 bpm and 3,250 psi. 22:00 - 22:30 0.50 CASE P LNR1 UD rotary cement head, manifold, and lines. 22:30 - 00:00 1.50 CASE P LNR1 PJSM. Slip and cut 1,500' drilling line. 9/21/2003 00:00 - 02:00 2.00 CASE P LNR1 Continue slip 1,500' new drilling line. Inspect brakes, service top drive. 02:00 - 07:00 5.00 CASE P LNR1 POOH with drill pipe from 8,630'. Service break and UD running tool. Clear rig floor. Pull wear bushing. 07:00 - 08:00 1.00 CASE P LNR1 RIU 7" casing equipment. 08:00 - 16:30 8.50 CASE P LNR1 PJSM. MIU seal assembly and 7", 26#, L-80, BTC-M casing to 8,644'. Total of 210 joints. Average MIU torque 7,900 ft Ibs. 16:30 - 17:30 1.00 CASE P LNR1 C/O bales. MIU cement head and adapter. 17:30 - 18:00 0.50 CASE P LNR1 Space out. No-Go seal assembly at 8,654'. Increase pump pressure to 1,000 psi to test seal assembly. Bleed to 500 psi. Sting out and PIU to expose circulating orifices in seal Printed: 9/29/2003 9:07:23 AM ... .. Page 7 of 10 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-06 F-06A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 'Task I ¡Phase Date From - To Hours I Code NPT I 9/21/2003 17:30 - 18:00 0.50 CASE P LNR1 18:00 - 21 :00 3.00 CEMT P LNR1 21 :00 - 21 :30 21 :30 - 00:00 0.50 CEMT P 2.50 BOPSURP LNR1 LNR1 9/22/2003 00:00 - 01 :00 1.00 BOPSURP LNR1 01 :00 - 05:30 4.50 BOPSURP LNR1 05:30 - 06:30 1.00 BOPSURP LNR1 06:30 - 10:00 3.50 DRILL P PROD1 10:00 - 13:00 3.00 DRILL P PROD1 13:00 - 14:00 1.00 DRILL P PROD1 14:00 - 14:30 0.50 DRILL P PROD1 14:30 - 15:30 1.00 DRILL P PROD1 15:30 - 16:30 1.00 DRILL P PROD1 16:30 - 17:00 0.50 EVAL P PROD1 17:00 - 18:30 1.50 DRILL P PROD1 18:30-21:00 2.50 DRILL P PROD1 21 :00 - 22:00 1.00 DRILL P PROD1 22:00 - 22:30 0.50 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: 2ES Spud Date: 5/1/1997 End: DescriptiOn. of Opërations assembly. Break circulation. PJSM. Pump 40 bbl Hi-Vis spacer. Pump 5 bbl water and test lines to 4,500. Pump 290 bbl diesel. Drop bottom plug, pump 10 bbl 12.0 ppg MudPUSH and 28 bbl of 15.8 ppg class 'G' cement. Drop top plug. Rig pumps displace with 331 bbl seawater at 230 spm and 1,100 psi. Bump plug on calculated strokes to 1,000 psi. CIP at 20:30 hours. First indication of diesel in returns at 292 bbls of 331 bbls pumped during displacement. Estimate 8 - 10 bbls diesel in returns. Slack off 60K to insert seal assembly. RID cement head and lines. Drain stack and landing joint. Split the stack. Set casing on slips/packoff with 140K on weight indicator. RILDS. Cut casing and pull cut joint (7.37' cut off). Set back BOP stack. Dress 7" casing stub. Install new tubing spool. NIU spool. Energize pack-off and test seals to 5,000 psi. Move secondary annulus valve. NIU BOPE stack. CIO upper rams to 31/2" X 6" VBR. Test rams to 250 psi low and 3,500 psi high. Install wear bushing. Pressure test 7" casing to 3,500 psi. MIU 61/8" BHA to 936'. Upload MWD and surface test at 102 spm and 820 psi. Install RAS. CIO handling equipment. RIH from 936' to 8,415'. SLM drill pipe. Fill pipe at 3,270' and 6,084'. Service top drive. Install blower hose. RIH with drill pipe from 8,415' to 8,550'. Wash down from 8,550' to 8,620'. Drill cement stringers from 8,620' to FIe at 8,634'. Drill FIC and plugs at 8,634'. RIH with drill pipe from 8,635' to 10,097'. Wash from 10,097' to UC at 10,224'. Pressure test casing to 3,500 psi for 30 minutes. Record on chart. Drill UC and shoe tract from 10,224' to FIC at 10,264'. Difficulties due to pipe drag. Displace well to 8.4+ ppg Flo-Pro mud. Clean cement from under shakers. Drill FIe at 10,264'; shoe at 10,309'. Drill 20' new formation to 10,329'. Pull up into shoe. Perform FIT at 10,329' md (8,755' tvd) with 8.4+ ppg mud to 550 psi, (9.6 ppg EMW) Drill ahead from 10,329' to 10,392'. ART = 1.50 hrs, AST = 0.00 hrs, ADT = 1.50 hrs PIU weight 178K, SIO weight 140K, Rot weight 160K. Rotate at 40 - 60 RPM Flow rate 265 gpm, on btm 2,050 psi, off btm 1,850 psi. Torque on btm 6,000; Torque off btm 5,000 WOB 20K, ROP 50 - 75 fph Printed: 9/29/2003 9:07:23 AM ...... .. Page 8 of 10 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-06 F-06A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date , . i 1: From - To ! Hours i TaSk Code NPT Phase , ! ¥""-..-. 9/23/2003 00:00 - 10:30 10.50 DRILL P Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: 2ES Spud Date: 5/1/1997 End: Description of Operations ----.-- PROD1 Drill ahead from 10,392' to 10,733'. ART = 8.44 hrs, AST = 0.00 hrs, ADT = 8.44 hrs Torque became erratic, spiking to 10K. ROP slowed to 25 fph. Decided to pull bit. CBU at 112 spm and 2,000 psi. POOH from 10,733' to 10,003', Drop dart to open circ sub. Slup pipe at 10,003'. BID surface equipment. Remove blower hose, POOH with drill pipe from 10,003' to 936', CIO elevators. POH with BHA from 936' to 101'. PJSM. Shallow test MWDtools at 101', Remove RAS. CIO bit. Install RAS. RIH with BHA to 937'. CIO elevators. RIH with drill pipe from 937' to 10,309', Cut and slip drilling line. Service top drive. Install blower hose. Fill pipe. RIH with drill pipe from 10,309' to 10,469'. Wash and ream hole from 10,469' to 10,733' at 260 gpm and 1,950 psi. Ream at 60 rpm, torque 4,500 ft-Ibs . No hole problems. Check shot survey at 10,655'. PROD1 Drill ahead from 10,733' to 10,790'. Rotate at 65 RPM Flow rate 265 gpm, on btm 2,050 psi, off btm 1,850 psi. Torque on btm 5 - 7,000; Torque off btm 4 - 5,000 WOB 20K, ROP 50 - 90 fph PROD1 Drill ahead from 10,790' to 10,981'. ART = 4.75 hrs, AST = 0.00 hrs, ADT = 4.75 hrs P/U weight 185K, SIO weight 140K, Rot weight 165K. 10:30-11:30 1.00 DRILL P PROD1 11 :30 - 12:00 0.50 DRILL P PROD1 12:00 - 12:30 0.50 DRILL P PROD1 12:30 - 15:00 2.50 DRILL P PROD1 15:00 - 15:30 0.50 DRILL P PROD1 15:30 - 16:30 1.00 DRILL P PROD1 16:30 - 17:00 0.50 DRILL P PROD1 17:00 - 20:00 3.00 DRILL P PROD1 20:00 - 21 :30 1.50 DRILL P PROD1 21 :30 - 22:30 1.00 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P 9/24/2003 00:00 - 06:00 6.00 DRILL P 06:00 - 07:00 1.00 DRILL P PROD1 CBU at 108 spm and 2,000 psi. Spot liner running pill in open hole. Monitor well. PIU weight 180K, SID weight 145K, Rot weight 165K. Rotate at 60 - 70 RPM Flow rate 265 gpm, on btm 2,050 psi, off btm 1,850 psi. Torque on btm 6,000; Torque off btm 5,000 WOB 20K, ROP 50 - 90 fph ART = 1.40 hrs, AST = 0,00 hrs, ADT = 1.40 hrs PIU weight 185K, SIO weight 140K, Rot weight 165K. Rotate at 65 RPM Flow rate 265 gpm, on btm 2,050 psi, off btm 1,850 psi. Torque on btm 5 - 7,000; Torque off btm 4 - 5,000 WOB 20K, ROP 40 - 100 fph On site geologist called TD at 10,981' based upon sufficient rathole below OWC. Printed: 9/29/2003 9:07:23 AM ..... .. Page 9 of 10 BP EXPLORATION ... Operati9l1s>Summary ~eport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-06 F-06A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES . . I Date From - To ¡Hours Ta$k Code NPT Phase ~.._--_....._._- 9/24/2003 07:00 - 10:30 3.50 DRILL P PROD1 10:30 - 11 :00 0.50 DRILL P PROD1 11 :00 - 14:30 3.50 DRILL P PROD1 14:30 - 16:00 1.50 DRILL P PROD1 16:00 - 17:00 1.00 DRILL P PROD1 17:00 - 18:00 1.00 CASE P COMP 18:00 - 19:00 1.00 CASE P COMP 19:00 - 19:30 0.50 CASE P COMP 19:30 - 20:00 0.50 CASE P COMP 20:00 - 00:00 4.00 CASE P COMP 9/25/2003 00:00 - 01 :30 1.50 CASE P COMP 01 :30 - 03:00 1.50 CASE P COMP 03:30 - 04:00 0.50 CEMT P COMP 04:00 - 05:00 1.00 CEMT P COMP 05:00 - 06:00 06:00 - 13:00 1.00 CASE P 7.00 CASE P COMP COMP Start: Rig Release: Rig Number: Spud Date: 5/1/1997 End: 9/7/2003 9/26/2003 2ES Description of Operations MAD pass with MWD from 10,981' to 10,330', at 200 fph. POOH to 10,282'. Drop dart, open circ sub, pump dry job. Drop 2 3/8" rabbit. POOH from 10,282' to 937'. C/O elevators. UD BHA from 937' to 132'. Flush MWD with water. PJSM. Pull RAS and download MWD. UD BHA from 132'. Clear rig floor. PJSM. RJU 4 1/2" liner equipment. PIU and M/U float equipment. Check floats. MIU 41/2", 12.6#, L-80, IBT-M liner to 815'. Average M/U torque 3,800 ft-Ibs. Ran a total of 19 joints. Used Best-O-Life 2000 thread compound. MIU Baker HMC hanger and ZXP packer to 848'. C/O handling equipment. P/U 1 stand drill pipe and circulate one liner volume. Liner weight Up 40K, Dn 40K. RIH with liner on drill pipe from 942' to 10,287'. Fill pipe every 10 stands. Run in open hole with 4 1/2" liner. No problems. MIU rotary cement head. Tag bottom at 10,981'. PIU 180K, SIO 145K Circulate and stage rate up to 7 bpm and 1,350 psi. Batch mix cement. PJSM. Pump 5 bbl water and test lines to 4,500 psi. Pump 10 bbl 8.35 ppg CW100 at 4 bpm and 1,050 psi. Pump 30 bb110.0 ppg MudPUSH at 4 bpm and 900 psi. Pump 25 bb115.8 ppg 'G' cement slurry at 4 bpm and 900- 600 psi. Wash lines with perf pill through tee. Release plug, displace with 40 bbl perf pill and mud at 6 bpm and 1,250 psi with Dowell. Reduce rate to 4 bpm prior to latch dart. Continue displacement at 4 bpm. Bump plug on schedule at 3 bpm. CIP at 04:00. Total displacement at plug bump 114.8 bbls. Reciprocate pipe 10ft intervals, throughout displacement, until after latching dart. Spot liner on depth just prior to bumping plug. Increase pressure to 4,000 psi to set hanger. Set down 40K. Bleed off and check floats. Rotate off hanger with 20 RH rotations. Increase pressure to 1,000 psi, sting out, circulate at 200 spm and 2,600 psi for 600 strokes. Reduce rate to 50 spm and SIO 35K down weight to set packer. Good surface indication of shear and set. Increase rate to 12 bpm and 2,800 psi. CBU. Estimate -7 bbl cement returned to surface. Rotate down on packer with 40K weight and confirm packer set. 4 1/2" liner shoe at 10,980', ZXP packer at 10,146' with top of TBS at 10,138'. Displace to sea water at 12 bpm and 3,000 psi. Pump dry job. UD rotary cement head. P/U weight 175K, 8/0 weight 155K. POOH UD drill pipe 1 X 1. Printed: 9/29/2003 9:07:23 AM ..,. . Þage 100f 10 BP EXPLORATION Operations Sum,l1lary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/25/2003 9/26/2003 F-06 F-06A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From - To . Hours Task ; Code NPT· Phase 13:00 - 13:30 0.50 CASE P COMP 13:30 - 14:30 1.00 CASE P COMP 14:30 - 16:30 2.00 RUNCOI\IP COMP 16:30 - 17:00 0.50 RUNCOI\IP COMP 17:00 - 17:30 0.50 RUNCOI\IP COMP 17:30 - 00:00 6.50 RUNCOI\IP COMP 00:00 - 05:00 5.00 RUNCOI\IP COMP 05:00 - 06:30 1.50 RUNCOI\IP COMP 06:30 - 07:00 0.50 RUNCOI\IP COMP 07:00 - 07:30 0.50 RUNCOI\IP COMP 07:30 - 09:30 2.00 RUNCOI\IP COMP 09:30 - 10:30 1.00 RUNCOI\IP COMP 10:30 -11 :30 1.00 BOPSURP COMP 11 :30 - 13:00 1.50 BOPSURP COMP 13:00 - 15:30 2.50 WHSUR P COMP 15:30 - 16:00 0.50 WHSUR P COMP 16:00 - 17:00 1.00 WHSUR P COMP 17:00 - 19:00 2.00 WHSUR P COMP 19:00 - 20:00 1.00 WHSUR P COMP 20:00 - 20:30 0.50 WHSUR P COMP Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: 2ES Spud Date: 5/1/1997 End: Description of Operations UD running tool. Clear rig floor. M/U muleshoe. RIH with drill pipe to 840'. POH UD drill pipe 1 X 1. Pull wear bushing. Remove top drive saver sub. RlU 4 1/2" tubing handling equipment with compensator. Pressure test casing to 3,500 psi for 30 minutes. Record on chart. P/U tail pipe assembly and packer. Baker-Lock tailpipe and packer. Run 41/2", 12.6#, 13Cr-80, VAM TOP tubing to 6,236'. Utilize Jet-Lube thread compound. Average MIU torque 4,440 ft-Ibs. Run 41/2",12.6#, 13Cr-80, VAM TOP tubing to 10,145'. Tag No-Go. Rotate pipe, work pipe up and down to transfer rotation down hole. Confirm tag. Space out tubing with 15.68' of pup joints. Spacing places WLEG at 10,141.7', -4' into TBS. M/U tubing hanger. Land hanger. RILDS. RlU circulating lines and test to 4,000 psi. Reverse circulate sea water and corrosion inhibitor at 3 bpm and 250 psi. Drop ball/rod. Pump down tubing and set packer at 10082' wI 3,500 psi. Test tubing to 3,500 psi for 30 minutes and record. Bleed tubing to 1,500 psi and pump down annulus to 3,500 psi. Test annulus to 3,500 psi for 30 minutes and record. Bleed tubing to shear DCK valve. Set TWC and test from below to 1,000 psi. Blow down all surface equipment. NJD BOPE. NIU tree and adapter. Test tree and adapter to 5,000 psi. Pull TWC with DSM and lubricator. PJSM. RlU LRHOS. Pressure test lines to 3,500 psi. Pump 75 bbl diesel freeze protect down annulus at 2 bpm and 2,450 psi. Allow to U-tube. Install BPV (Cameron). Test from below to 1,000 psi. RID LRHOS. Remove secondary annulus valve. Secure well. RELEASE Rig at 20:30 hours. Printed: 9/29/2003 9:07:23 AM . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well F-06A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,761.01' MD 8,839.00' MD 10,980.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager AUachment( s) ~..~~. ~ ~ 'C:I\.) \\\ 0 &03 -- }~q 06-0ct-03 Sperry-Sun Drilling Services North Slope Alaska BPXA PBU WOA F Pad F-06A Job No. AKZZ2661658, Surveyed: 24 September, 2003 Survey Report 6 October, 2003 Your Ref: API 500292009701 Surface Coordinates: 5974027.91 N, 651960.65 E (70020' 09.8413" N, 148046' 01.3873" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974027.91 N, 151960.65 E (Grid) Surface Coordinates relative to Structure Reference: 1478.94 N, 1030.96 E (True) Kelly Bushing: 66. 61ft above Mean Sea Level Elevation relative to Project V Reference: 66.61ft Elevation relative to Structure Reference: 66.61ft SpE!r"r",:/-SUi! ORiLLING seRVices A Halliburton Company DEFINITIVE . . Survey Ref: svy4106 Sperry-Sun Drilling Services Survey Report for PBU_WOA F Pad - F-06A Your Ref: API 500292009701 Job No. AKZZ2661658, Surveyed: 24 September, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8761.01 39.000 353.000 7674.55 7741.16 2835.37 N 1242.73 W 5976837.51 N 650660.72 E 2239.33 Tie On Point AK-6 BP _IFR-AK 8839.00 41 .720 354.580 7733.98 7800.59 2885.57 N 1248.17 W 5976887.60 N 650654.26 E 3.726 2284.65 Window Point 8884.50 44.580 358.200 7767.17 7833.78 2916.61 N 1250.11 W 5976918.59 N 650651.70 E 8.312 2313.16 8915.12 46.410 0.380 7788.64 7855.25 2938.45 N 1250.37 W 5976940.42 N 650650.99 E 7.842 2333.58 . 8948.14 48.570 2.730 7810.95 7877.56 2962.77 N 1249.70 W 5976964.75 N 650651.17 E 8.385 2356.67 8977.82 50.440 4.670 7830.22 7896.83 2985.29 N 1248.24 W 5976987.30 N 650652.18 E 8.025 2378.33 9009.17 52.090 6.630 7849.84 7916.45 3009.63 N 1245.83 W 5977011.67 N 650654.09 E 7.175 2402.02 9039.28 53.050 8.440 7868.14 7934.75 3033.33 N 1242.69 W 5977035.43 N 650656.75 E 5.740 2425.37 9071.56 52.920 6.610 7887.58 7954.19 3058.88 N 1239.31 W 5977061.05 N 650659.61 E 4.544 2450.53 9102.37 52.900 8.640 7906.16 7972.77 3083.24 N 1236.05 W 5977085.47 N 650662.37 E 5.256 2474.54 9134.82 52.340 13.990 7925.87 7992.48 3108.50 N 1231.00W 5977110.83 N 650666.91 E 13.212 2500.01 9167.15 52.360 16.250 7945.62 8012.23 3133.21 N 1224.33 W 5977135.67 N 650673.09 E 5.535 2525.51 9195.91 52.730 18.300 7963.11 8029.72 3155.01 N 1217.55 W 5977157.60 N 650679.42 E 5.803 2548.32 9229.91 53.130 20.680 7983.60 8050.21 3180.58 N 1208.49 W 5977183.35 N 650687.96 E 5.708 2575.44 9261.86 52.880 22.880 8002.83 8069.44 3204.28 N 1199.03W 5977207.23 N 650696.94 E 5.555 2600.94 9290.60 52.680 25.180 8020.22 8086.83 3225.18 N 1189.71W 5977228.32 N 650705.83 E 6.410 2623.77 9324.77 52.330 28.670 8041.02 8107.63 3249.34 N 1177.44 W 5977252.73 N 650717.61 E 8.168 2650.68 9355.66 52.260 29.480 8059.91 8126.52 3270.70 N 1165.56 W 5977274.32 N 650729.05 E 2.087 2674.81 9384.05 51.770 30.630 8077.39 8144.00 3290.07 N 1154.36 W 5977293.91 N 650739.86 E 3.629 2696.84 9418.39 51.190 31.770 8098.77 8165.38 3313.05 N 1140.44 W 5977317.17 N 650753.31 E 3.098 2723.20 9449.31 50.950 32.190 8118.20 8184.81 3333.45 N 1127.70 W 5977337.83 N 650765.63 E 1.311 2746.72 . 9476.06 50.570 32.620 8135.12 8201.73 3350.94 N 1116.60W 5977355.54 N 650776.38 E 1.889 2766.96 9510.00 50.070 33.820 8156.79 8223.40 3372.80 N 1102.29 W 5977377.68 N 650790.24 E 3.094 2792.39 9571.71 49.580 34.160 8196.61 8263.22 3411.89 N 1075.93 W 5977417.30 N 650815.80 E 0.899 2838.14 9665.40 48.580 33.590 8257.97 8324.58 3470.67 N 1036.47 W 5977476.86 N 650854.07 E 1.162 2906.87 9757.14 47.860 34.960 8319.10 8385.71 3527.20 N 997.95 W 5977534.16 N 650891.43 E 1.362 2973.16 9788.56 48.180 35.070 8340.11 8406.72 3546.33 N 984.55 W 5977553.56 N 650904.45 E 1.051 2995.72 9850.54 48.190 35.570 8381.44 8448.05 3584.02 N 957.84 W 5977591.78 N 650930.38 E 0.601 3040.27 9944.34 50.610 35.750 8442.47 8509.08 3641.88 N 916.32 W 5977650.47 N 650970.72 E 2.584 3108.84 10037.59 49.690 35.860 8502.23 8568.84 3699.94 N 874.44 W 5977709.37 N 651011.42 E 0.991 3177.73 6 October, 2003 - 7:43 Page 2 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA F Pad - F-06A Your Ref: API 500292009701 Job No. AKZZ2661658, Surveyed: 24 September, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10130.89 49.030 35.920 8562.99 8629.60 3757.29 N 832.94 W 5977767.55 N 651051.75 E 0.709 3245.82 10221.83 51.890 35.290 8620.88 8687 A9 3814.31 N 792.12 W 5977825.39 N 651091 AO E 3.190 3313.36 10251.58 51.640 35.120 8639.29 8705.90 3833A 1 N 778.65 W 5977844.75 N 651104A9 E 0.953 3335.91 10311.96 51.750 34.880 8676.72 8743.33 3872.22 N 751 A7 W 5977884.11 N 651130.87 E 0.361 3381.68 10404.85 52.840 33.910 8733.53 8800.14 3932.86 N 709.96 W 5977945.58 N 651171.14 E 1A35 3452.86 10497A5 51.420 35.250 8790.38 8856.99 3993.05 N 668A8 W 5978006.59 N 651211.39 E 1.912 3523.60 . 10590.20 52.230 34.030 8847.70 8914.31 4053.04 N 627.04 W 5978067A1 N 651251.61 E 1.353 3594.15 10685.36 53.000 33.080 8905A8 8972.09 4116.05 N 585.25 W 5978131.25 N 651292.11 E 1.133 3667.65 10778A6 53.650 30.740 8961.09 9027.70 4179A3 N 545.79 W 5978195A2 N 651330.28 E 2.133 3740.71 10870.87 54.050 29.130 9015.61 9082.22 4244.09 N 508.56 W 5978260.82 N 651366.19 E 1A72 3814.20 10915.77 54.120 29.010 9041.94 9108.55 4275.87 N 490.89 W 5978292.96 N 651383.22 E 0.267 3850.11 10980.00 54.120 29.010 9079.59 9146.20 4321.39 N 465.65 W 5978338.97 N 651407.53 E 0.000 3901.51 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 20.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10980.00ft., The Bottom Hole Displacement is 4346.40ft., in the Direction of 353.850° (True). . 6 October, 2003· 7:43 Page 3 of 4 DríllQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA F Pad - F-06A Your Ref: API 500292009701 Job No. AKZZ2661658, Surveyed: 24 September, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8761.01 8839.00 10980.00 7741.16 7800.59 9146.20 2835.37 N 2885.57 N 4321.39 N 1242.73 W 1248.17W 465.65 W Tie On Point Window Point Projected Survey . Survey tool program for F-06A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8761.01 0.00 8761.01 7741.16 10980.00 7741.16 BP High Accuracy Gyro (F-06) 9146.20 AK-6 BP _IFR-AK (F-06A) . 6 October, 2003 - 7:43 Page 4 of4 DrillQuest 3.03.02.005 · AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ~03-J1C¡ 06-0ct-03 Re: Distribution of Survey Data for Well F-06A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,761.01' MD 8,839.00' MD 10,980.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager Attachment( s) <"~~~~'Y\ ~ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU WOA F Pad F-06A MWD . Job No. AKMW2661658, Surveyed: 24 September, 2003 Survey Report 6 October, 2003 Your Ref: API 500292009701 Surface Coordinates: 5974027.91 N, 651960.65 E (70· 20'09.8413" N, 148· 46' 01.3873" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 974027.91 N, 151960.65 E (Grid) Surface Coordinates relative to Structure Reference: 1478.94 N, 1030.96 E (True) Kelly Bushing: 66.61ft above Mean Sea Level Elevation relative to Project V Reference: 66.61ft Elevation relative to Structure Reference: 66.61ft 51=JE!!!!ï'ï"V-5U1'1 õFtîLLING seRvices A Halliburton Company Survey Ref: svy4107 Sperry-Sun Drilling Services Survey Report for PBU_WOA F Pad· F-06A MWD Your Ref: API 500292009701 Job No. AKMW2661658, Surveyed: 24 September, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8761.01 39.000 353.000 7674.55 7741.16 2835.37 N 1242.73 W 5976837.51 N 650660.72 E 2239.33 Tie On Point MWD Magnetic 8839.00 41.720 354.580 7733.98 7800.59 2885.57 N 1248.17 W 5976887.60 N 650654.26 E 3.726 2284.65 Window Point 8884.50 44.580 358.200 7767.17 7833.78 2916.61 N 1250.11 W 5976918.59 N 650651.70 E 8.312 2313.16 8915.12 46.410 0.380 7788.64 7855.25 2938.45 N 1250.37 W 5976940.42 N 650650.99 E 7.842 2333.58 . 8948.14 48.570 2.730 7810.95 7877.56 2962.77 N 1249.70 W 5976964.75 N 650651.17 E 8.385 2356.67 8977.82 50.440 4.670 7830.22 7896.83 2985.29 N 1248.24 W 5976987.30 N 650652.18 E 8.025 2378.33 9009.17 52.090 6.630 7849.84 7916.45 3009.63 N 1245.83 W 5977011.67 N 650654.09 E 7.175 2402.02 9039.28 53.050 8.440 7868.14 7934.75 3033.33 N 1242.69 W 5977035.43 N 650656.75 E 5.740 2425.37 9071.56 52.920 6.610 7887.58 7954.19 3058.88 N 1239.31 W 5977061.05 N 650659.61 E 4.544 2450.53 9102.37 52.900 8.640 7906.16 7972.77 3083.24 N 1236.05 W 5977085.47 N 650662.37 E 5.256 2474.54 9134.82 52.340 13.990 7925.87 7992.48 3108.50 N 1231.00 W 5977110.83 N 650666.91 E 13.212 2500.01 9167.15 52.360 16.250 7945.62 8012.23 3133.21 N 1224.33 W 5977135.67 N 650673.09 E 5.535 2525.51 9195.91 52.730 18.300 7963.11 8029.72 3155.01 N 1217.55 W 5977157.60 N 650679.42 E 5.803 2548.32 9229.91 53.130 20.680 7983.60 8050.21 3180.58 N 1208.49 W 5977183.35 N 650687.96 E 5.708 2575.44 9261.86 52.880 22.880 8002.83 8069.44 3204.28 N 1199.03W 5977207.23 N 650696.94 E 5.555 2600.94 9290.60 52.680 26.800 8020.22 8086.83 3225.04 N 1189.42W 5977228.19 N 650706.13 E 10.883 2623.74 9324.77 52.330 29.790 8041.02 8107.63 3248.91 N 1176.57 W 5977252.31 N 650718.49 E 7.017 2650.56 9355.66 52.260 31.080 8059.91 8126.52 3269.98 N 1164.19 W 5977273.63 N 650730.44 E 3.312 2674.60 9384.05 51.770 31.180 8077.39 8144.00 3289.13 N 1152.62W 5977293.01 N 650741.61 E 1.748 2696.55 9418.39 51.190 32.120 8098.77 8165.38 3312.00 N 1138.53 W 5977316.16 N 650755.25 E 2.728 2722.86 9449.31 50.950 32.790 8118.20 8184.81 3332.30 N 1125.62 W 5977336.72 N 650767.74 E 1.856 2746.35 . 9476.06 50.570 33.060 8135.13 8201.74 3349.69 N 1114.36W 5977354.33 N 650778.65 E 1.621 2766.54 9510.00 50.070 34.000 8156.80 8223.41 3371.46 N 1099.93 W 5977376.39 N 650792.63 E 2.591 2791.94 9571.71 49.580 34.900 8196.61 8263.22 3410.34 N 1073.26 W 5977415.81 N 650818.51 E 1.368 2837.60 9665.40 48.580 33.930 8257.97 8324.58 3468.74 N 1033.25 W 5977475.00 N 650857.33 E 1.323 2906.16 9757.14 47.860 34.640 8319.10 8385.71 3525.27 N 994.71 W 5977532.30 N 650894.71 E 0.974 2972.46 9788.56 48.180 34.610 8340.11 8406.72 3544.49 N 981.44 W 5977551.78 N 650907.59 E 1.021 2995.06 9850.54 48.190 35.580 8381.44 8448.05 3582.28 N 954.88 W 5977590.11 N 650933.38 E 1.167 3039.66 9944.34 50.610 35.720 8442.48 8509.09 3640.15 N 913.38 W 5977648.81 N 650973.70 E 2.582 3108.23 10037.59 49.690 36.210 8502.23 8568.84 3698.09 N 871.33 W 5977707.59 N 651014.56 E 1.066 3177.06 6 October, 2003 - 7:48 Page 2 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA F Pad - F-06A MWD Your Ref: API 500292009701 Job No. AKMW2661658, Surveyed: 24 September, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10130.89 49.030 36.540 8563.00 8629.61 3755.10 N 829.35 W 5977765.43 N 651055.38 E 0.757 3244.98 10221.83 51.890 35.550 8620.88 8687.49 3811.80 N 788.10 W 5977822.96 N 651095.48 E 3.255 3312.38 10251.58 51.640 35.520 8639.30 8705.91 3830.82 N 774.51 W 5977842.25 N 651108.67 E 0.844 3334.89 10311.96 51.750 35.770 8676.72 8743.33 3869.32 N 746.90 W 5977881.30 N 651135.50 E 0.372 3380.52 10404.85 52.840 34.860 8733.53 8800.14 3929.29 N 704.42 W 5977942.12 N 651176.75 E 1 .406 3451.40 . 10497.45 51.420 35.700 8790.38 8856.99 3988.96 N 662.21 W 5978002.64 N 651217.75 E 1.692 3521.91 10590.20 52.230 33.300 8847.71 8914.32 4049.05 N 620.92 W 5978063.55 N 651257.81 E 2.214 3592.50 10685.36 53.000 33.840 8905.49 8972.10 4112.05 N 579.11 W 5978127.38 N 651298.33 E 0.926 3665.99 10778.46 53.650 31.970 8961.09 9027.70 4174.74 N 538.56 W 5978190.88 N 651337.61 E 1.756 3738.77 10870.87 54.050 28.980 9015.62 9082.23 4239.04 N 500.72 W 5978255.93 N 651374.13 E 2.648 3812.14 10915.77 54.120 28.040 9041.95 9108.56 4270.99 N 483.37 W 5978288.23 N 651390.84 E 1.703 3848.10 10980.00 54.120 28.040 9079.60 9146.21 4316.93 N 458.90 W 5978334.65 N 651414.37 E 0.000 3899.63 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 20.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10980.00ft., The Bottom Hole Displacement is 4341.25ft., in the Direction of 353.932° (True). . 6 October, 2003 - 7:48 Page 3 of 4 Dril/Quest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA F Pad - F-06A MWD Your Ref: API 500292009701 Job No. AKMW2661658, Surveyed: 24 September, 2003 '" BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8761.01 8839.00 10980.00 7741.16 7800.59 9146.21 2835.37 N 2885.57 N 4316.93 N 1242.73 W 1248.17 W 458.90 W Tie On Point Window Point Projected Survey . Survey tool program for F-06A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8761.01 0.00 8761.01 7741.16 10980.00 7741.16 BP High Accuracy Gyro (F-06) 9146.21 MWD Magnetic (F-06A MWD) . 6 October, 2003 - 7:48 Page 4 of4 Dril/Quest 3.03.02.005 . rrPf till -' . .-- '1 ~\ ~ - « L/~ Ln.-,~_ÛJU FRANK H. MURKOWSKI, GOVERNOR ~I#ASIiA. OILAlQ) GAS CONSERVATION COMMISSION Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe bay Unit F-06A BP Exploration (Alaska), Inc. Permit No: 203-149 Surface Location: 2772' SNL, 2879' WEL, Sec. 02, T11N, Rl3E, UM Bottomho1e Location: 1473' NSL, 3375' WEL, Sec. 35, T12N, R13E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ tê--<--~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this ~, day of August, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section . STATE OF ALASKA . ALASKA, . AND GAS CONSERVATION CO .ISSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: IBI Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: ./ MD 10875' TVD 9089' 7. Property Designation: ADL 028277 , o Drill B Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2772' SNL, 2879' WEL, SEC. 02, T11N, R13E, UM Top of Productive Horizon: 1338' NSL, 3464' WEL, SEC. 35, T12N, R13E, UM Total Depth: ' 1473' NSL, 3375' WEL, SEC. 35, T12N, R13E,UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-651961 y-5974028 Zone-ASP4 16. Deviated Wells: Kickoff Depth 18; ·CasingPrôgråm Size CasinQ 9-5/8" Hole N/A 8-1/2" 6-1/8" 8850 ft Maximum Hole Angle Specifications Grade CouplinQ L-80 I NSCC L-80 BTC-M L-80 IBT-M 7" Weight 47# 26# 12.6# 4-1/2" í¡...J G A- g, 2..7ll.00J B Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU F-06A ./ 12. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 8. Land Use Permit: 13. Approximate Spud Date: 09/08/03 r' 14. Distance to Nearest Property: -5200' (Approx.) 9. Acres in Property: ,; .'1 2560' 52° 10. KB Elevation Plan KBE 15. Distance to Nearest Well Within Pool (Height above GL): = 65.1' feet F-32 is 914' away at 8857' ./ 17. Anticipated pressure (see 20 MC 25.035) ./ Max. Downhole Pressure: 3252 psig. Max. Surface Pressure: 2371 psig Setting Dêpth>' ... Quäntity'ofCêmêht Top Bottom (c.f. or sacks) MD TVD MD TVD (includinQ staQe data) 1983' 1983' 2259' 2259' 111 sx Class 'G' -' Surface Surface 10350' 8769' 247 sx Class 'G', 117 sx Class 'G' ,/ 10200' 8677' 10875' 9089' 116 sx Class 'G' ,/ LenQth 2259' 10350' 675' ~,,;;.,. ',:,:0. >.':.:. ,:",.:,:, ';",:.' ',' .:.:. i:' .. ".. ...>:.:,:-,,:,":':" ... PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD Plugs (measured): Effective Depth MD (ft): Effective Depth TVD 10700' 9188' 2420',2520',9945' 2420' 2420' Structural Conductor 100' 30" 300 sx Permafrost II 100' 100' Surface 2306' 18-5/8" 5200 sx Permafrost II 2306' 2306' Intermediate 9703' 13-3/8" x 9-5/8" 1700 sx Class 'G', 1550 sx PF II 9703' 8415' Production Liner 1482' 7" 400 sx Class 'G' 9202' - 10684' 8054' - 9176' Perforation Depth MD (ft): Below Sand: 10120' - 10396' 20. Attachments IBI Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8731' - 8948' IBI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report IBI Drilling Fluid Program IBI 20 MC 25.050 Requirements Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name BiIIlsaacson Title Senior Drilling Engineer SiQnature 7^-' lL \. '",¡.v, Permit To Drill I API Number: Number: 2(B -/"'71/, 50-029-20097-01-00 Conditions of Approval: Samples Required Hydrogen Sulfide Measures Other: T.es t goy E fø ~SOO fçl. Approved Bv: ~~ Form 10-401 Revised 3/2003 Contact Jim Smith, 564-5773 Rob Tirpack, 564-4166 Prepared By Name/Number: Terrie Hubble, 564-4628 Date 81z. fel oJ Phone 564-5521 Commission Use Only 1 Permit Approval Date: !S/Utl.>'] Mud Log Required Directional Survey Required I See cover letter for other requirements DYe~ ~\o S Yes []N.o DYes gNo ~Yes 0 No BY ORDER OF THE COMMISSION ¥,/ð3 ~/~ R I Gt~'^t"R Submit In Duplicate Date · e F-06A / Approval is requested for the proposed repair and sidetrack of PBU well F-06. This well is currently shut-in due to collapsed production casing and fish stuck in the hole. Fishing attempts have proved unsuccessful. The wellbore is providing no production or value to the field. The well currently has a bridge plug with cement placed at 2420' MD F-06 was drilled in May 1971 as a conventional Ivishak producer. It remained a strong producer until 1983, when a RWO was required to repair collapsed 13-3/8" casing. After the successful RWO, F-06 continued production until 1999 when it was shut-in due to collapsed tubing. In November 2002, a RWO was initiated to replace the collapsed tubing. It was at this time when an additional collapsed section of 13-3/8" casing was discovered. Operations were halted to develop an appropriate plan forward. A rig returned to F-06 in January 2003 to repair the collapsed 13-3/8" casing, replace the collapsed production tubing and return the well to production. After three weeks of milling and fishing with limited success, rig operations were once again suspended. Multiple fish are now located on top of a deep tubing stub and the collapsed 13-3/8" casing remains un-repaired. The F-06A sidetrack is currently scheduled for Nabors rig 2ES, beginning around September 25, 2003, /' after the completion of summer rig maintenance. The pre-rig work for this sidetrack is planned to begin as soon as possible in preparation for the sidetrack. Following is a summary of the proposed well repair and sidetrack operations in support of this drilling permit application. F-06A Permit to Drill Page 1 · e IWell Name: I F-06A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer ./ Surface Location: Estimated Target Location: Ivishak Zone 2A Bottom Hole Location: x = 651,961 Y = 5,974,028 2772' FNL, 2879' FEL / Sec. 2, T11N, R13E Umiat X = 651,288 Y = 5,978,125 TVDss 8900' 1338' FSL, 3464' FEL /' Sec. 35, T12N, R13E Umiat X = 651 ,374 Y = 5,978,262 TVDss 9024' 1473' FSL, 3375' FEL /' Sec. 35, T12N, R13E Umiat I AFE Number: 1 PBD4P2092 1 I Estimated Start Date: 19/08/03 I MD: 110,875' I I TVD: 19089' 1 I Rig: I Nabors 2ES ,/ I Operating days to complete: 120 I GL: 134.8' ./' I KB: 165.1' 1 I KBE: 165.1' I Well Design (conventional, slim hole, etc.): 1 High angle Sidetrack I Objective: 1 Ivishak Zone 4A Formation Markers Formation Tops (wp04c) MD TVD TVDss Comments Kingak N/A N/A 7,366' Kingak JF 8,796' 7,768' 7,703' Kick-off Point 8,850' 7,808' 7,743' Kingak JE 9,023' 7,935' 7,870' Kingak JD 9,356' 8,161' 8,096' No Hydrocarbons Kingak JC 9,784' 8,423' 8,358' No Hydrocarbons Kingak JB 10,015' 8,564' 8,499' Sag River 10,331' 8,757' 8,692' Shublik 10,397' 8,797' 8,732' TSAD - Zone 4 10,523' 8,874' 8,809' SAD - Zone 3 . 10,711' 8,898' 8,924' SAD - Zone 2C 10,793' 9,039' 8,974' SAD - Zone 2Bu 10,863' 9,082' 9,017' SAD - Zone 2BI N/A N/A N/A TD 10,875' 9,089' 9,024' TD Criteria: Based on 200' below OWC, may extend approx. 50' based on deeper OWC. F-06A Permit to Drill Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW ~.(p Page 2 · Directional KOP: 18,850' MD Maximum Hole Angle: Close Approach Well: e _520 in 8-1/2" hole There are no close approach issues. The nearest well bore is the F-32 well which is 914' away at 8857'MD on the F-06A (at the kick off point). MWD only The nearest lease boundary is -5200' to the north-northeast Survey Program: Lease boundaries: Casing/Tubing Program Hole Size CsglTbg O.D. WtlFt Grade 11.5"mill 9-5/8" -Scab string 7" -casing 4-1/2" 4-1/2" 47# L-80 &NT95 L-80 L-80 13-Cr 8-1/2" 6-1/8" Tubing 26# 12.6# 12.6# Mud Program Window Millin¡ Mud Properties: LSND Density (ppg) Viscosity I PV 10.5 40 - 60 14-18 Intermediate Mud Properties: LSND Density (p~) 1 10-Sec Gel I PV 11 .4 40 - 60 12-14 Production Mud Properties: Quickdril Density (ppg) I TauO I PV 8.3 - 8.6 3-7 7 - 11 Logging Program 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GRlRes- Real time Open Hole: None Cased Hole: None Conn Length Top Btm MDITVD MDITVD NSCC 276' 1983'/1983' 2,259'/2,259' BTC-M 10,350' GL 10,350'/8,769' IBT-M 675' 10,200'/8,677' 10,875'/9,089' VAMACE 10,200' GL 10,200'/8,677' Whip Stock Window 9 5/8" YP 110 sec gel MBT PH IAP~ FII 40+ 15-20 6-8 9.0- 9.5 8-1/2" hole section YP 110 sec gel MBT PH A:I:I 15-21 15-20 6-8 9.0 - 9.5 1 6-1/8" hole section YP 1 LSYP I MBT pH APIFI 30 - 35 8-14 <6 9.0 - 9.5 4-6 6-1/8" Production: Drilling: Open Hole: Cased Hole: Sample Catchers - over entire interval, samples described and discarded. MWD Dir/GRlRes - Real time; DenlNeu - recorded mode None None Cement Program I Casing Size 9-5/8" 47#, L-80/NT95 Scab casing string Basis: Lead: None Tail: 276' of 9-518" x 13-3/8" casing annulus (2,259' to 1,983' MD) plus shoe track Tail TOC: 1,983' TotaICementVolume: Tail 23bbls, 129ft3, 111 sksClassG @ 15.8ppg, 1.16ft3/sack /' F-06A Permit to Drill Page 3 · e I Casing Size 17" 26#, L-80 Casing, first stage I Basis: Lead: None Tail: Based on 80' shoe track, 1500' of 7" X 8-1/2" open hole with 30% excess, 150' 7" X 9-5/8" Liner Lap. Tail TOC: 8700' MD (150' above window) I Total Cement Volume: I Lead I None Tail 51 bbls, 286 ft3, 247 sacks Class G @ 15.8 ppg, 1.16 ft3/sack- 17" 26#, L=80 Casing, second stage Basis: Lead: None Tail: 1000' of 7" X 9-5/8" casing with 0% excess. Tail TOC: 7700' MD I Total Cement Volume: Casing Size I Lead I None Tail 24 bbls, 136 ft3, 117 sacks Class G @ 15.8 ppg, 1.16 ft3/sack -- I Casing Size 14.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: Based on 80' shoe track, 525' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X 7" Liner Lap, and 200' of 7" excess. Tail TOC: 10200' MD 1TOL) I Total Cement Volume: Lead None . Tail 124 bbls, 135 ft3, 116 sacks Class G @ 15.8 ppg, 1.16 ft3/sack /' Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear 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 the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingn" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids F-06A Permit to Drill 3209 psi (7.1 ppg @ 8692' TV D) 2340 psi (.10 psi/ft gas gradient to surface) Infinite with a 12.0 ppg FIT ..,., Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi 3500 psi surface pressure ,/ FIT after drilling 20' outside window 3252 psi (7.1 ppg @ 8809' TVD) 2371 psi (.10 psi/ft gas gradient to surface) Infinite with 9.6ppg FIT ./ Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi 3500 psi surface pressure / 9.6 ppg EMW FIT 8.4 ppg Seawater / 6.8 ppg Diesel Page 4 . e Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. .Sidetrack and Complete Procedure Summary Pre-Riq Work: 1. Function all Lock Down screws, repair or replace as needed. 2. Bleed casing and annulus pressure to zero. 3. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. Riq Operations: / 1. MIRU N2es. 2. Pull BPV. Circulate out freeze protection and displace well to seawater. 3. Pressure test against abandonment plug at 2420', 9-5/8" casing, 13-3/8" casing and outer 18-5/8" /' casing exposed through collapse section of 13-3/8" to 500 psi. (Note: watch for pressure increase on 13-3/8 by 18-5/8" annulus indicating communication). Set TWC. 4. Nipple up and test BOPE. Pull TWC. 5. Pull 4-1/2" 12.6#, L-80, IBT-Mod tubing kill string (mule shoe is at 1997'). 6. PU 8-1/2" mill and 11-3/4" OD tapered mill plus BHA. RIH. 7. Work 8-1/2" mill in upper part of 9-5/8" casing, tag 13-3/8" by 9-5/8" crossover at approx. 2261' with 11-3/4" mill. POOH. 8. RU casing crew and run 9-5/8" scab liner with nose guide to stab into crossover at approximately /' 2261', 9-5/8" casing will shoulder on the crossover. 9. Set 13-3/8" X 9-5/8" liner hanger at - 1983' MD, cement in place, set 13-3/8" X 9-5/8" ZXP liner top packer. 10. PU 8-1/2" bit and BHA to clean out down to the abandonment plug and EZSV at 2420'. 11. Pressure test 9-5/8" against abandonment plug to 3500 psi for 30 minutes. POOH. ../ 12. ND BOPE. Add additional spool to wellhead. A future 7" casing string will land in the original wellhead where the tubing was landed. The new spool will be used to land the tubing string. 13. NU BOPE. Test BOPE and spool to 3500 psi for 30 mins. ./ 14. PU and RIH with 8-1/2" bit and clean out assembly. Drill up abandonment plug and EZSV, push any junk to bottom (top of existing fish at 9028'MD). 15. Displace out seawater with milling fluid. POOH. 16. RU e-line and run GR/JB to 8880'MD (approximate bridge plug setting depth). 17. Make up bridge plug on e-line with CCL. RIH to setting depth near 8875'MD. Set bridge plug to avoid ,/ cutting a collar with the whipstock mills. RD e-line. 18. Pressure test casing to 3500 psi for 30 minutes. / 19. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 20. Mill window in 9-5/8" casing at -8850' MD. Perform FIT to 12.0ppg EMW. POOH 21. MU 8-1/2" drilling assembly with Dir/GR/Res and RIH. Kick off and drill the 8-1/2" intermediate interval, building and turning at 5°/100' to a 52° hold angle. ,...- 22. Drill ahead to casing point at Top Sag River to an estimated depth of 10,331'-10,350' MD. 23. Run and cement a 7" full string throughout the 8-1/2" hole. Cement the 8-1/2" hole and back into the ../ 9-5/8" casing to 8700' MD with first stage cement, Drop the bomb to open the stage collar placed at 8700'MD and circulate out excess cement. Then pump diesel freeze protection followed by spacer and cement to provide 1000' of cement in the 9-5/8" x 7" annulus. Close stage collar. Displace cement with mud. 24. MU 6-1/8" BHA with Dir/GR/Res/Den/Neu and RIH to the stage collar landing collar. Drill that collar and perform a brief pressure test to ensure the stage collar is closed. RIH to landing collar. 25. Pressure test casing to 3500 psi for 30 minutes. / F-06A Permit to Drill Page 5 · It 26. Drill shoe track. Swap to 8.6 ppg mud and drill 20' of new formation. Perform FIT to 9.6ppg EMW. /' 27. Drill the 6-1/8" production interval holding 52° angle to the estimated TD of 10,875' MD 28. Run and cement a 4-1/2" solid liner throughout the 6-1/8" wellbore and back into the 7" casing to ~ about 10,200' MD (150' of liner lap). Displace cement with perf pill and clean seawater, after pulling running tool from the liner, displace the remainder of the wellbore to clean seawater. 29. Run 4-1/2", 12.6#, Chrome completion tying into the 4-1/2" liner top. ,/ 30. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 31. Set and test TWC. 32. ND BOPE. NU and test the tree to 5000 psi. 33. Freeze protect the well to -2200' and secure the well. 34. RDMO Post-Riq Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from landing nipple below the new production packer. 2. Perforate and install gas lift valves. 3. Install well house and flowlines. The flowline will need to be re-fitted. / F-06A Drilling Program Job 1: MIRU Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto F-06A. The closest neighboring wells are spaced as follows: F-43 at -67' and F-5 at -100'. Care should be taken while moving onto the well. Spotters and ~munications will be used at all times. ~ F-Pad is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: The maximum levels of recorded of H2S on the pad was 140 ppm on F-47 and 100 ppm / was reported from F-24 in 2002. Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies ~ F-06 has been temporarily abandoned from an attempted workover in January, 2003. The existing perforations are isolated below a bridge plug set at 2520'MD with cement above the plug to 2420'. The well should be considered open to the reservoir once these plugs have been drilled out although the perforations have been sanded back. ~ The 13-3/8" protective casing (tapered string; 13-3/8" to 2259' and 9-5/8" below that), has collapsed and been milled open to 11.5" inside diameter down to the crossover at 2261'. It may be necessary to accomplish additional milling to retain the 11.5" inside diameter. ~ There are known holes in the 13-3/8" protective casing near 2083'MD, there is an outer casing string of 18-5/8" that appears intact. ~ The 13-3/8" by 18-5/8" annulus was last loaded with ArcticPak, no loss of this freeze protection has been noted but with the milling and damage to 13-3/8" casing the integrity of the annular freeze protection is suspect. F-06A Permit to Drill Page 6 · e ).> NORM test all retrieved well head and completion equipment. ).> Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP Job 3: Scab tieback Hazards and Contingencies ).> Passage of 9-5/8" scab tieback through the damaged 13-3/8" collapse area will retain risk even after the passage of an 11-3/4" taper mill. Use a nose guide for passage below the damage area. ~ Alignment of the new 9-5/8" casing tieback with the existing 9-5/8" casing below the crossover at 2261' must be close enough that bit/BHA passage is unrestricted. A nose guide on the new casing will assure alignment. ~ Welding in the cellar will be necessary for placement of the new Gen 5 FMC wellhead. Fire danger must be mitigated with fire watch personnel and fire protection equipment. Job 4: Window Mill Hazards and Contingencies ).> Position bridge plug to avoid cutting a casing collar while milling the window. ).> Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies ).> The intermediate section will kick off in the Kingak 'F' interval and TD at the top of Sag River. Since F-06A will be at _520 inclination at a 330 azimuth, maintain mud weight at minimum 11.4 ppg to interval TD. Follow all shale drilling practices to minimize potential problems. ).> There is a fault crossing in the intermediate section in the Kingak near 10, 165'MD/8,655'TVD and a fault tip near 9,616'MD/8,320'TVD in the Kingak. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ).> There are no close approach issues while drilling the intermediate hole section. ).> KICK TOLERANCE: In the worst-case scenario of 9.5 ppg pore pressure at the Sag River depth, a fracture gradient of 12.0 ppg at the 9-5/8" casing window, and 11.5 ppg mud in the hole, the /" kick tolerance is Infinite. Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" F-06A Permit to Drill Page 7 · e "·n.~")i."",,. '-;~·__.E1I'i'i'ln·-·"} Job 6: Install 7" Intermediate and Tieback Liners Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ The 7" full string will be run with a stage collar above the sidetrack depth. Cement volume calculations will need to be accurate and delay in opening the stage collar could lead to premature cement set and resultant failure to freeze protect the 7" by 9-5/8" annulus. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP ~~-~" ¡;;;;;",.....--~-~,-=... Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ A pump out sub will be run in the BHA to aid in placing LCM material. ~ KICK TOLERANCE: In the worst-case scenario of 8.8 ppg pore pressure in the Ivishak, a fracture gradient of 9.6 ppg at the 7" casing shoe, and 8.6 ppg mud in the hole, the kick .,/ tolerance is Infinite. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP ;--!.1-,-,-~~=-,:'-!¡fæ=~_·,-_·J)i·______ Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is always a concern but is minimized for the F-06A due to lower hole angle at 52 degrees. The 8.6ppg mud will be -750psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ? Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate casing. ? Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. -< -,.- F-06A Permit to Drill Page 8 · e Job 12: Run Completion Hazards and Contingencies >- Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. >- 4-1/2" Chrome tubing will be run and additional Chrome handling procedures will be needed. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NUlRelease Riq Hazards and Contingencies >- No wells will require well house removal or shut-in for the rig move onto F-06A. The closest neighboring wells are spaced as follows: F-43 at -67' and F-5 at -100'. Care should be taken while moving onto the well. Spotters will be used at all times. Reference RP .:. "Freeze Protecting an Inner Annulus" RP F-06A Permit to Drill Page 9 . e F-06A Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Hole Section: · There are no close approach issues. · Differential sticking has been experienced in the past. Keep pipe moving at all times. · Lost circulation while drilling has not been problematic at F-Pad. In the event of lost circulation, consult the LCM Decision Tree. · There have been reports of tight hole, torque and packing off in the Kingak. · The intermediate hole section will be drilled with a recommended mud weight of 11.4 ppg to ensure shale stability in the Kingak. · Kick tolerance is Infinite with a 12.0 ppg LOT. · There is one fault crossing expected in the intermediate hole sectionnear 10,165'MD. Production Hole Section: · There are no fault crossings expected in the production hole section. Lost circulation risk is low. Use LCM Decision Tree in the event of losses. · There is indication of faulting outside the target polygon to the north and south. The wellbore must remain within the target polygon. · Kick tolerance is Infinite. HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. Recent tests indicate / a very low concentration of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE F-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION F-06A Permit to Drill Page 10 F-06 olla 2033' 2216' 2259' 2306' 2420' 2520' 4742' 9028' ed 13-3/8 chematic 13-3/8" 72# N-80 Buttress Casing - Good 13-3/8" Baash-Ross Casing Patch - Full bore 13-3/8" 68# K-55 Seal Lock Casing - Good 13-3/8" 68# K-55 Seal Lock Casing - Collapsed Last mill to pass through was 8.5" Largest mill to pass was 11.5" 13-3/8" 68# K-55 Seal Lock Casing - Good 13-3/8" DV Tool 13-3/8" X 9-5/8" Crossover 18-5/8" 96.5# K-55 Buttress Surface Casing - Good Top of Cement Plug 9-5/8" EZSV Bridge Plug 9-5/8" 47# N-80 Seal Lock Casing - Good 9-5/8" DV Tool 4-1/2" Tubing Stub with junk beside 1983' 2033' . 2159' 2259' - 2306' 2420' 2520' 4742' 9028' F-06 PI ab Liner Forward - 9-5/ 13-3/8" X 9-518" BOT Liner Hanger with ZXP Packer Milled out casing collapse zone Base of LinerlTop of Sand 18-5/8" 96.5# K-55 Buttress Surface Casing - Good Top of Cement Plug 9-5/8" EZSV Bridge Plug 9-5/8" 47# N-80 Seal Lock Casing - Good 9-5/8" DV Tool 4-1/2" Tubing Stub with junk beside F-06 PI Forward.. 7" 1983' t 13-3/8" X 9-5/8" BOT 2033' MUledoutcasing ooUapsezone 2159' 2306' Seal Lock Casing 7700' 8700' 7" stage Collar 8850' 8880' 9028' 10,331' F-ota Proposed Com~tion 1983' 2159' 2259' 2306' .. 9-5/8",47#, l-80, BTC-M Casing Patch 13-3/8",68#, K-55, Seal lock ~ 18-5/8", 96.5#, K-55 , Buttress TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = 4" CPN McEVOY BAKER 64.81' 36.61' 2862' 48 @ 5235' 10279' 8800' SS I. ~ 7", 26#, l-80, BTC-M Tie Back Liner GlM Design: #5 - 3265' TVD - 4-1/2" X 1"-KBG2-DV #4 - 3965' TVD - 4-1/2" X 1 "-KBG2-DCK Shear #3 - 5565' TVD - 4-1/2" X 1 "-KBG2-DV #2 - 6815' TVD - 4-1/2" X 1"-KBG2-DV #1 - 8065' TVD - 4-1/2" X 1"-KBG2-DV /4-1/2", 12.6#, 13Cr80, VAM ACE Tubing 8850' KOP Tubing Tail: -10' Pup Joint -X Nipple (3.813") -10' Pup Joint -Packer -20' Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG 8700' 8880' 9028' -,- 9050' g 7" X 4-1/2" S-3 Packer @ 10131' ( 9112' g X 9-5/8" 3H BOT packer 9202' . ,. TOl ~ ¡ 7",26#, l-80, BTC-M @ 10,331' 9242' 9703' ~ 4-1/2", 12.6#, l-80, Seallock ~ 9-5/8",47#, N-80, Seallock ~ 10684' ... 7",29#, N-80, Seallock / 4-1/2", 12.6#, l-80, IBT-M @ 10,875' Date 05-07-03 Rev By Comments RBT Proposed Completion - wp03 PRUDHOE BAY UNIT WELL: 18-03B API NO: Permit NO: GPB Rotary Drilling COMPANY DETAILS DP Arnow REFERENCE INFORMATION CASING DETAILS No. TVD MD Name Size 8757.II 1033!.!0 7" 7.000 9089.22 10875.03 4 II2" 4.500 o 0 7800 F RMA T! N TOP DETAILS ~ No. TVDPatI1 MDPath Forn1ation ~ 1 ~ ~ Start Dir 12fJOO': 8850' MD, 7808.38'TVD 2 3 ig Start Dir 51100' :3870' MD,7823J8'fVD 4 . 5 JB 6 7 ~:m - 8 ~ 9 - 10 - II ,. - . rD EndDir : 9414.97' MD,3197.76' TVD , ~ . I , - - I ; I . . . , ; ; , 'lmm¡ ~1] tGm1 - - . . . I . ' I - , I I . . . I ' I , I, I , 4 , ; , ,. . , ¡ - . - . .. ., - .. I '.' I +r~1 . . _. ~. . - . I , . . . I ! . . ¡ , ¡ , I ¡ ¡ j , , , , , , , , , I I ¡ , , I I , I 8100 " ;j§ 8400 g ::1 "" 15, " Ci '" " 'X: ~ " ¡¡ ¡.- 8700 9000 9300 3000 3300 4200 Vertical Section at 353.27' [300ftlin] SURVEY PROGRAM J)q:tth Fm Deptll To SurveylPlan 8850.00 10815.04 Ph:rnned: F-OM wp03 V6 Name +-Nl-S +-EPN " Plan: F~06A wp03 (F-06/Plan f,.{}6A) Too' Cn.'1lte-d By: Ken AHen Cheçked: Date: 5/6/2003 MWD Date Reviewed: Date Northing WELL DETAILS Easting Longitude Slot Laiiruœ F..(}6 14&0.19 1030-03 5974021.80 651960J56 70"20'09.ß40N 148Q4{i'01.387W 06 TARGET DETAILS N"", TVD +N/>$ ~Ei"W Northing Basting Shape f.j)6A TI E 8967.11 4113.25- "587.48 5978128.00 651290.00 Polygon SECTION DETAILS See MD Inc Azi TVD +NI-S +EI-W DLeg TFace VSee Till'get 7808.38 2893,89 ·1248.94 0.00 7823,18 2907.33 -1249.74 85,00 3 8197,76 3278.6 I ·1134.51 81.50 4 8967.11 4113,25 ·587.48 tWO F-06A T1 E 5 9089,22 4245.73 -500.66 0,00 112" (F..06) ø ,I I' I' ¡p' ; ,I ¡P ,I .I ,I ,II COMPANY DETAILS BP Amooo REFERENCE INFORMATION CASING DETAILS No. TVD MD 1033UO 7" 10875.03 4 II2" - - - - - 4800-- - - - - - 4400-- _,~__.c . . ,,,ou-,,, ~~4 ;~i~tr _ = 1] J '.. ..:' 1 . ¡, 1i E , '" :¡¡¡ 4000 g - ::!, i· - +' f ~ .¡; " " '" - - - - , " )0 3600 -R~I . . , - . ;.. _H .. .. - w . 3200 , / : i , 1 , , J ; ,., 10' , ., I. - . , . .. - . !4:il 1.. . 2800 , . - . . : : : ! , , I I ¡ I I , , , , , , , I ' , , , , , , I ' , -1200 -800 -400 0 We>1(-)/East(+) [400ftJin] SURVEY PROGRAM o..)th Fm Depth To $urveyIPhm 8850JJO Hlli75.04 Planned; F.Q6A wp03 V6 Plan: Fw06A wp03 {Fw06/Plun fw06A) Tool Created By: Ken Allen Checked: D¡\te; 5/6/2001 MWO Date Reviewed: Date Name WELL DETAILS Nillœ +Nf-S Northing &is/ing Latitude: Loo.gituœ Slot F-06 14&0.19 1030.03 5974027.80 651%0.66 7ff20'09.!MON 14S"46'01381W û6 TARGET DETAJLS ""'" TV" +NfwS '~Ef~W Nmibing EasÜng Shape f~0:6.'\ T1 E 8961.1J 4JO.25- -587.48 5978128.1JO 651290.00 Pulygon SECTION DETAILS Sec MD Inc Azi TVD +NJ-S +EJ-W DLeg naec I 8850.00 7808.38 -1248.94 0.00 0.00 2 8870.00 7823. I 8 -1249.74 12.00 85.00 3 9414.97 8197.76 ·II34.51 5.00 8L50 4 10675.04 8967. ¡¡ ·587.48 0.00 0.00 5 10875.04 9089.22 -500.66 0.00 0.00 F-06A TJ E Size 7.000 4.500 VSec T¡µget o FORMATION TOP DETAILS No. TVDPath MOPatn Formalion I 2 3 4 5 6 7 8 9 !O II 8796.46 9023.50 9355.99 9784.06 10015.00 10331. 10 10396.61 10522.72 10711.07 10792.96 10863.39 ,I I ¡P I I I -I ,I ; II ,,1 ~ '/Q2 ~ V . BP KW A Planning Report MAP Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB F Pad F-06 Plan F-06A Date: 51612003 Time: 14:39:20 Page: 1 Co-ordinate(NE) Reference: Well: F-06, True North Vertical (TVD) Reference: 65.11' 65.1 Section (VS) Reference: Well (0.00N,O.00E,353.27Azi) Survey Calculation Method: Minimum Curvature Db: Oracle -.--.----- Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB F Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5972527.29 ft 650960.70 ft Latitude: 70 19 Longitude: 148 46 North Reference: Grid Convergence: . Alaska, Zone 4 Well Centre BGGM2002 55.283 N 31.468 W True 1.15 deg Well: F-06 Slot Name: 06 F-06 Well Position: +N/-S 1480.19 ft Northing: 5974027.80 ft Latitude: 70 20 9.840 N +E/-W 1030.03 ft Easting : 651960.66 ft Longitude: 148 46 1.387 W Position Uncertainty: 0.00 ft Wellpath: Plan F-06A Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 65.11' 4/15/2003 57540 nT Depth From (TVD) ft 0.00 Height 65.11 ft +N/-S ft 0.00 Plan: F-06A wp03 Date Composed: Version: Tied-to: Principal: Yes Casing Points F-06 8850.00 ft Mean Sea Level 25.86 deg 80.84 deg Direction deg 353.27 5/5/2003 6 From: Definitive Path MD TVD Diameter Hole Size Name ft ft in in 10331.10 8757.11 7.000 8.500 7" 10875.03 9089.22 4.500 6.125 41/2" Formations MD TVD J?ol"mations ft ft 8796.46 7768.11 TJF 0.00 0.00 9023.50 7935.11 TJE 0.00 0.00 9355.99 8161.11 TJD 0.00 0.00 9784.06 8423.11 TJC 0.00 0.00 10015.00 8564.11 TJB 0.00 0.00 10331.10 8757.11 Sag 0.00 0.00 10396.61 8797.11 Shu 0.00 0.00 10522.72 8874.11 TSADITZ4 0.00 0.00 10711.07 8989.11 TCGLlTZ3 0.00 0.00 10792.96 9039.11 BCGLlTZ2C 0.00 0.00 10863.39 9082.11 23SBITZ2Bu/25N 0.00 0.00 Targets !\f¡P Map Name !)eseription TVD +N/~S +E/"W Nol'thing Easting Dip. Dir. ft ft ft ft ft F-06A T1 E 8967.11 4113.25 -587.48 5978128.00 651290.00 70 20 50.293 N 148 46 18.553 W -Polygon 1 8967.11 5026.08 -368.93 5979045.00 651490.00 70 20 59.271 N 148 4612.169 W -Polygon 2 8967.11 4489.16 -774.92 5978500.00 651095.00 70 20 53.990 N 148 46 24.032 W -Polygon 3 8967.11 3879.54 -802.28 5977890.00 651080.00 70 20 47.995 N 148 46 24.829 W -Polygon 4 8967.11 3867.18 -192.36 5977890.00 651690.00 70 2047.873 N 148 46 7.008 W . \ Company: Field: Site: WeD: WeDpath: Targets BP Amoco Prudhoe Bay PB F Pad F-06 Plan F-06A . . BP KW A Planning Report MAP Name Description TVD Dip. Dir. ft -Polygon 5 8967.11 -Plan hit target Plan Section Information MD ft 8850.00 8870.00 9414.97 10675.04 10875.04 Survey MD ft 8796.46 8850.00 8870.00 8900.00 9000.00 9023.50 9100.00 9200.00 9300.00 9355.99 9400.00 9414.97 9500.00 9600.00 9700.00 9784.06 9800.00 9900.00 10000.00 10015.00 10100.00 10200.00 10300.00 10331.10 10396.61 10400.00 10500.00 10522.72 10600.00 10675.04 10700.00 10711.07 10792.96 10800.00 10863.39 Incl deg 42.17 42.43 52.37 52.37 52.37 Incl deg 40.29 42.17 42.43 42.67 43.77 44.10 45.30 47.20 49.44 50.82 51.97 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 52.37 Azim deg 354.82 358.37 33.24 33.24 33.24 Azim deg 353.77 354.82 358.37 0.56 7.68 9.31 14.47 20.87 26.86 30.04 32.44 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 33.24 10875.04 52.37 33.24 TVD ft 7808.38 7823.18 8197.76 8967.11 9089.22 TVD ft 7768.11 7808.38 7823.18 7845.28 7918.19 7935.11 7989.51 8058.69 8125.22 8161.11 8188.57 8197.76 8249.67 8310.73 8371.78 8423.11 8432.84 8493.90 8554.95 8564.11 8616.01 8677.07 8738.12 8757.11 8797.11 8799.18 8860.24 8874.11 8921.29 8967.11 8982.35 8989.11 9039.11 9043.41 9082.11 +N/-S ft 2893.89 2907.33 3278.61 4113.25 4245.73 Sys 7703.00 7743.27 7758.07 7780.17 7853.08 7870.00 7924.40 7993.58 8060.11 8096.00 8123.46 8132.65 8184.56 8245.62 8306.67 8358.00 8367.73 8428.79 8489.84 8499.00 8550.90 8611.96 8673.01 8692.00 8732.00 8734.07 8795.13 8809.00 8856.18 8902.00 8917.24 8924.00 8974.00 8978.30 9017.00 Date: 5/6/2003 Time: 14:39:20 Page: 2 Co-ordinate(NE) Reference: Well: F-06, True North Vertical (fVD) Reference: 65.11' 65.1 Section (VS) Reference: Well (0.00N,0.00E,353.27Azi) Survey Calculation Method: Minimum Curvature Db: Oracle +N/-S ft 4658.16 +E/-W ft 263.80 +EI~W ft -1248.94 -1249.74 -1134.51 -587.48 -500.66 Map'\{ ft 5976860.55 5976895.58 5976908.99 5976929.27 5976997.56 5977013.73 5977066.55 5977135.71 5977204.52 5977242.69 5977272.44 5977282.51 5977339.56 5977406.66 5977473.76 5977530.16 5977540.86 5977607.96 5977675.05 5977685.12 5977742.15 5977809.25 5977876.35 5977897.22 5977941.18 5977943.45 5978010.55 5978025.80 5978077.65 5978128.00 5978144.75 5978152.18 5978207.13 5978211.85 5978254.38 9089.22 9024.11 5978262.20 Map Map Northing Easting ft ft 5978690.00 652130.00 <-- Latitude --> <- Longitude -> Deg Min See Deg Min See DLS BuDd Turn degl100ft degl100ft deg/100ft 0.00 0.00 0.00 12.00 1.32 17.72 5.00 1.82 6.40 0.00 0.00 0.00 0.00 0.00 0.00 650657.64 650653.43 650652.36 650651.76 650655.33 650657.41 650667.45 650688.02 650716.89 650736.59 650753.83 650760.04 650795.80 650837.86 650879.92 650915.27 650921.97 650964.03 651006.09 651012.40 651048.15 651090.21 651132.26 651145.34 651172.90 651174.32 651216.38 651225.94 651258.44 651290.00 651300.50 651305.15 651339.60 651342.56 651369.22 vS ft 2984.96 3020.24 3033.68 3053.84 3121.01 70 20 55.653 N 148 45 53.678 W TFO Target deg 0.00 85.00 81.50 0.00 F-06A T1 E 0.00 DLS .<TFO deg/10Oft deg 0.00 0.00 3.74 20.62 12.00 85.00 5.00 81.50 5.00 79.89 TJF MWD MWD MWD MWD 3136.73 5.00 3187.68 5.00 3253.37 5.00 3317.57 5.00 3352.68 5.00 3379.79 5.00 3388.91 5.00 3440.52 0.00 3501.22 0.00 3561.92 0.00 3612.94 0.00 3622.61 0.00 3683.31 0.00 3744.01 0.00 3753.11 0.00 3804.71 0.00 3865.41 0.00 3926.10 0.00 3944.98 0.00 3984.75 0.00 3986.80 0.00 4047.50 0.00 4061.29 0.00 4108.20 0.00 4153.75 0.00 4168.90 0.00 4175.62 0.00 4225.33 0.00 4229.60 0.00 4268.07 0.00 651374.12 4275.15 0.00 74.70 TJE 73.52 MWD 69.85 MWD 65.42 MWD 61.44 TJD 59.40 MWD 57.90 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 T JC 0.00 MWD 0.00 MWD 0.00 MWD 0.00 T JB 0.00 MWD 0.00 MWD 0.00 MWD 0.00 Sag 0.00 Shu 0.00 MWD 0.00 MWD 0.00 TSADfTZ4 0.00 MWD 0.00 F-06A T1 E 0.00 MWD 0.00 TCGLfTZ3 0.00 BCGLfTZ2C 0.00 MWD 0.00 23SBfTZ2Bu/25N 0.00 MWD . Company: Field: Reference Site: Reference Well: Reference Wellpatb: BP Amoco Prudhoe Bay PB F Pad F-06 Plan F-06A BP Anticollision Report . GLOBAL SCAN APPLIED: All wellpatbs witbin 200'+ 10011000 of reference - Tbere ar~ftells in tb"~al Plan & PLANNED PROGRAM Interpolation Metbod: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Deptb Range: 8850.00 to 10875.04 ft Scan Metbod: Trav Cylinder North Maximum Radius: 1284.65 ft Error Suñace: Ellipse + Casing Survey Program for Definitive Wellpatb Date: 4/15/2003 Validated: No Planned From To Survey ft ft 159.51 8850.00 1 : Camera based gyro multisho 8850.00 10875.04 Planned: F-06A wp03 V6 Casing Points MD TVD Diameter Hole Size Name ft ft in in 10334.37 8759.11 7.000 8.500 7" 10875.03 9089.22 4.500 6.125 41/2" Summary < Offset Wellpatb > Site Well WeUpatb PB F Pad F-06 F-06 V1 PB F Pad F-14 F-14 V1 PB F Pad F-21 F-21 V1 PB F Pad F-21PB1 F-21PB1 V1 PB F Pad F-22 F-22 V1 PB F Pad F-32 F-32 V1 PB F Pad F-37 F-37 V1 PB F Pad F-42 F-42 V1 Version: 0 Toolcode Tool Name CB-GYRO-MS MWD Camera based gyro multishot MWD - Standard Reference MD ft 8859.51 8859.87 9989.63 10657.43 8857.34 Ctr-Ctr No-Go Distance Area ft ft 0.09 0.00 Pass: NO ERRORS Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Offset MD ft 8850.00 ft 0.09 1053.26 549.10 1237.06 519.50 1176.67 429.36 914.05 883.49 8725.00 9350.00 10034.00 9100.00 820.94 913.80 927.32 30.80 Site: PB F Pad Well: F-06 Rule Assigned: NOERRORS Wellpatb: F-06 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZJ: no-USea.iog Distaaee Area Deviation l\8f!'ing ft ft ft ft ft ft deg deg in ft ft ft 8859.51 7815.42 8850.00 7805.90 145.71 145.93 356.51 0.00 9.625 0.09 0.00 0.09 Pass 8884.48 7833.85 8875.00 7824.22 144.68 145.75 278.90 279.48 9.625 1.08 0.00 1.08 Pass 8909.38 7852.17 8900.00 7842.32 143.76 145.95 281.96 280.73 9.625 2.72 0.00 2.72 Pass 8934.21 7870.36 8925.00 7860.19 142.74 146.08 284.38 281.35 9.625 4.96 0.00 4.96 Pass 8958.92 7888.40 8950.00 7877.83 141.72 146.15 286.27 281.48 9.625 7.79 0.00 7.79 Pass 8983.50 7906.25 8975.00 7895.33 140.71 146.22 287.09 280.56 9.625 11.20 0.00 11.20 Pass 9007.93 7923.91 9000.00 7912.79 139.63 146.22 286.99 278.76 9.625 15.19 0.00 15.19 Pass 9032.17 7941.33 9025.00 7930.22 138.38 146.17 286.59 276.69 9.625 19.74 0.00 19.74 Pass 9056.21 7958.51 9050.00 7947.61 137.14 146.05 286.12 274.57 9.625 24.87 0.00 24.86 Pass 9080.03 7975.42 9075.00 7964.99 135.92 145.87 285.60 272.45 9.625 30.47 0.00 30.46 Pass 9103.66 7992.08 9100.00 7982.42 134.67 145.63 285.05 270.34 9.625 36.45 0.00 36.45 Pass 9127.06 8008.46 9125.00 7999.88 133.23 145.33 284.51 268.27 9.625 42.83 0.00 42.83 Pass 9150.23 8024.56 9150.00 8017.39 131.81 144.98 284.00 266.26 9.625 49.60 0.00 49.60 Pass 9173.16 8040.36 9175.00 8034.94 130.40 144.55 283.52 264.32 9.625 56.75 0.00 56.75 Pass 9195.84 8055.86 9200.00 8052.55 129.01 144.07 283.06 262.44 9.625 64.28 0.00 64.28 Pass 9218.25 8071.05 9225.00 8070.22 127.47 143.54 282.63 260.63 9.625 72.19 0.00 72.19 Pass 9240.39 8085.91 9250.00 8087.94 125.90 142.96 282.23 258.89 9.625 80.47 0.00 80.47 Pass 9262.27 8100.46 9275.00 8105.73 124.35 142.32 281.87 257.22 9.625 89.08 0.00 89.08 Pass 9283.88 8114.70 9300.00 8123.57 122.82 141.63 281.55 255.62 9.625 97.99 0.00 97.99 Pass 9305.23 8128.61 9325.00 8141.47 121.27 140.90 281.26 254.09 9.625 107.19 0.00 107.19 Pass 9326.31 8142.21 9350.00 8159.42 119.59 140.14 281.00 252.63 9.625 116.68 0.00 116.68 Pass 9347.10 8155.48 9375.00 8177.43 117.94 139.32 280.77 251.23 9.625 126.52 0.00 126.52 Pass 9367.55 8168.39 9400.00 8195.47 116.32 138.47 280.58 249.90 9.625 136.77 0.00 136.77 Pass . BP . Anticollision Report Company: SPAmoco Da~: ... ··.·.5/6/2003 Time: Field: prudhoe Say RefereneeSite: PBEPad Refe..enee WeD: . f-06 Reference WeDpatb: Plan F-OI;ìt\ Site: PB F Pad Well: F-06 Rule Assigned: NOERRORS Wellpatb: F-06 V1 Inter-Site Error: 0.00 ft Reference OtTset Semi-Major ..ub MD TVD MD TVD Ref ØtTset TFO+AZJTFO-BS.CasiîJg ft ft ft ft ft ft deg deg in 9387.67 8180.95 9425.00 8213.54 114.72 137.59 280.41 248.64 9.625 147.43 0.00 147.43 Pass 9407.44 8193.15 9450.00 8231.66 113.11 136.68 280.28 247.44 9.625 158.48 0.00 158.48 Pass 9428.62 8206.09 9475.00 8249.78 112.48 136.92 279.94 246.70 9.625 169.85 0.00 169.85 Pass 9450.83 8219.65 9500.00 8267.89 112.49 137.88 279.52 246.28 9.625 181.27 0.00 181.27 Pass 9473.03 8233.21 9525.00 8285.98 112.50 138.84 279.15 245.91 9.625 192.69 0.00 192.69 Pass 9495.24 8246.77 9550.00 8304.05 112.51 139.80 278.84 245.60 9.625 204.12 0.00 204.12 Pass 9517.45 8260.33 9575.00 8322.10 112.52 140.77 278.56 245.32 9.625 215.55 0.00 215.55 Pass 9539.66 8273.89 9600.00 8340.16 112.53 141.74 278.31 245.06 9.625 226.99 0.00 226.99 Pass 9561.87 8287.44 9625.00 8358.22 112.53 142.72 278.08 244.84 9.625 238.43 0.00 238.43 Pass 9584.08 8301.00 9650.00 8376.28 112.54 143.70 277.87 244.63 9.625 249.88 0.00 249.88 Pass 9606.32 8314.58 9675.00 8394.37 112.55 144.66 277.67 244.43 7.000 261.26 0.00 261.26 Pass 9628.62 8328.20 9700.00 8412.52 112.56 145.63 277.47 244.23 7.000 272.52 0.00 272.52 Pass 9650.99 8341.86 9725.00 8430.72 112.57 146.60 277.27 244.03 7.000 283.64 0.00 283.64 Pass 9673.41 8355.55 9750.00 8448.97 112.58 147.57 277.07 243.82 7.000 294.64 0.00 294.64 Pass 9695.86 8369.26 9775.00 8467.32 112.59 148.50 276.85 243.61 7.000 305.58 0.00 305.58 Pass 9718.30 8382.96 9800.00 8485.80 112.61 149.43 276.61 243.37 7.000 316.54 0.00 316.53 Pass 9740.72 8396.65 9825.00 8504.41 112.62 150.36 276.36 243.12 7.000 327.50 0.00 327.50 Pass 9763.12 8410.32 9850.00 8523.14 112.63 151.30 276.09 242.85 7.000 338.49 0.00 338.49 Pass 9785.53 8424.00 9875.00 8541.98 112.64 152.19 275.81 242.57 7.000 349.45 0.00 349.45 Pass 9807.95 8437.69 9900.00 8560.91 112.66 153.08 275.53 242.29 7.000 360.37 0.00 360.37 Pass 9830.38 8451.39 9925.00 8579.93 112.67 153.97 275.24 242.00 7.000 371.25 0.00 371.25 Pass 9852.83 8465.10 9950.00 8599.04 112.68 154.86 274.94 241.70 7.000 382.07 0.00 382.07 Pass 9875.29 8478.81 9975.00 8618.23 112.70 155.72 274.64 241.40 7.000 392.86 0.00 392.86 Pass 9897.77 8492.53 10000.00 8637.51 112.71 156.58 274.34 241.10 7.000 403.60 0.00 403.60 Pass 9920.25 8506.26 10025.00 8656.88 112.73 157.44 274.03 240.79 7.000 414.30 0.00 414.30 Pass 9942.75 8520.00 10050.00 8676.34 112.74 158.30 273.72 240.48 7.000 424.97 0.00 424.97 Pass 9965.27 8533.75 10075.00 8695.83 112.76 159.16 273.41 240.17 7.000 435.59 0.00 435.59 Pass 9987.81 8547.51 10100.00 8715.30 112.77 160.02 273.12 239.88 7.000 446.15 0.00 446.15 Pass 10010.39 8561.30 10125.00 8734.75 112.79 160.87 272.85 239.61 7.000 456.67 0.00 456.67 Pass 10033.00 8575.10 10150.00 8754.19 112.80 161.73 272.59 239.35 7.000 467.13 0.00 467.12 Pass 10055.65 8588.93 10175.00 8773.65 112.82 162.58 272.34 239.10 7.000 477.51 0.00 477.51 Pass 10078.33 8602.78 10200.00 8793.18 112.84 163.44 272.08 238.84 7.000 487.79 0.00 487.79 Pass 10101.05 8616.65 10225.00 8812.78 112.85 164.29 271.81 238.57 7.000 497.98 0.00 497.98 Pass 10123.80 8630.54 10250.00 8832.45 112.87 165.15 271.54 238.30 7.000 508.07 0.00 508.07 Pass 10146.55 8644.43 10275.00 8852.18 112.89 165.98 271.27 238.03 7.000 518.16 0.00 518.16 Pass 10169.25 8658.29 10300.00 8871.95 112.91 166.81 271.01 237.77 7.000 528.33 0.00 528.33 Pass 10191.92 8672.13 10325.00 8891.78 112.93 167.64 270.74 237.50 7.000 538.58 0.00 538.58 Pass 10214.55 8685.95 10350.00 8911.65 112.95 168.47 270.48 237.24 7.000 548.92 0.00 548.92 Pass 10237.16 8699.75 10375.00 8931.55 112.97 169.30 270.23 236.99 7.000 559.31 0.00 559.31 Pass 10259.76 8713.56 10400.00 8951.45 112.99 170.13 269.99 236.75 7.000 569.71 0.00 569.71 Pass 10282.37 8727.36 10425.00 8971.35 113.01 170.96 269.75 236.51 7.000 580.12 0.00 580.11 Pass 10304.98 8741.16 10450.00 8991.25 113.03 171.79 269.52 236.28 7.000 590.53 0.00 590.53 Pass 10327.59 8754.97 10475.00 9011.14 113.05 172.63 269.31 236.07 7.000 600.95 0.00 600.95 Pass 10350.21 8768.78 10500.00 9030.99 113.07 173.48 269.10 235.86 7.000 611.37 0.00 611.37 Pass 10372.85 8782.60 10525.00 9050.81 113.09 174.33 268.91 235.67 7.000 621.79 0.00 621.79 Pass 10395.49 8796.42 10550.00 9070.59 113.11 175.17 268.73 235.49 7.000 632.20 0.00 632.20 Pass 10418.13 8810.25 10575.00 9090.33 113.14 176.04 268.56 235.32 7.000 642.64 0.00 642.64 Pass 10440.75 8824.06 10600.00 9110.01 113.16 176.91 268.41 235.17 7.000 653.14 0.00 653.14 Pass 10463.36 8837.86 10625.00 9129.63 113.18 177.78 268.27 235.03 7.000 663.69 0.00 663.69 Pass 10485.95 8851.66 10650.00 9149.20 113.21 178.65 268.14 234.90 674.28 No Reference Casings 10508.55 8865.45 10675.00 9168.76 113.23 179.54 268.02 234.78 684.89 No Reference Casings . BP . Anticollision Report Cømpltny: BPAmoco Date: 5/612003 Time: 14:17:20 Field: Prudh~Bay Reference Site: PB FPad C...øl'dinate~)Reference: Well:F.,Q6. True North Reference WeD: F-06 "ertical (TVJ»Reference: 65;11~ 65.1 Reference WeDpltth: Plan F-Q6A Oracle Site: PB F Pad WeD: F-06 Rule Assigned: NOERRORS Wellpath: F-06 V1 Inter-Site Errør: 0.00 ft Reference Offset Seøti-Majør ADs Ctr'-Cti' ·.NO'GO AIIøwåble MD TV» MD TV» Ref Offset TFO+AZI TFO-6SCltsing I)isfltnceÁreIt DeViation Wltnqúg ft ft ft ft ft døg deg in ft ft ft 10531.14 8879.25 10700.00 9188.33 113.25 180.42 267.90 234.66 695.49 No Reference Casings Site: PB F Pad Well: F-21 Rule Assigned: Major Risk Well path: F-21 V1 Inter-Site Errør: 0.00 ft Reference Offset Semi-MaWJ\ùs Ctr-CtrNO'GO AIIowltble MD TV» MD TV» Ref Offset TFO+AZI· TFO-HSCasing Distltnce Are. DeVi.tiôn ft ft ft ft ft ft deg deg in ft ft ft 8859.87 7815.69 8725.00 7108.46 145.70 26.68 358.12 1.54 1053.26 549.10 820.94 Pass 8889.35 7837.44 8750.00 7125.09 144.51 26.41 358.56 358.78 1054.69 546.08 825.56 Pass 8916.56 7857.44 8775.00 7141.82 143.47 26.26 358.65 356.89 1055.98 542.94 830.25 Pass 8943.35 7877.05 8800.00 7158.62 142.36 26.10 358.71 355.03 1057.18 539.20 834.99 Pass 8969.71 7896.25 8825.00 7175.45 141.28 25.93 358.73 353.18 1058.32 535.20 839.66 Pass 8995.61 7915.02 8850.00 7192.34 140.22 25.75 358.72 351.35 1059.41 530.96 844.24 Pass 9021.03 7933.34 8875.00 7209.27 138.95 25.57 358.67 349.54 1060.46 526.79 849.24 Pass 9045.97 7951.20 8900.00 7226.24 137.67 25.39 358.59 347.75 1061.52 523.23 854.24 Pass 9070.40 7968.60 8925.00 7243.23 136.41 25.21 358.48 345.98 1062.59 519.47 859.18 Pass 9094.32 7985.51 8950.00 7260.25 135.18 25.03 358.33 344.23 1063.70 515.56 864.05 Pass 9117.73 8001.95 8975.00 7277.31 133.80 24.84 358.15 342.51 1064.85 510.99 869.28 Pass 9140.63 8017.90 9000.00 7294.42 132.40 24.66 357.94 340.82 1066.05 506.14 874.55 Pass 9163.01 8033.39 9025.00 7311.57 131.02 24.47 357.70 339.14 1067.30 501.21 879.73 Pass 9184.89 8048.40 9050.00 7328.79 129.68 24.28 357.43 337.49 1068.61 496.23 884.81 Pass 9206.26 8062.94 9075.00 7346.08 128.31 24.10 357.13 335.87 1069.97 491.18 889.88 Pass 9227.15 8077.04 9100.00 7363.46 126.84 23.92 356.80 334.26 1071.39 486.80 895.08 Pass 9247.55 8090.69 9125.00 7380.93 125.39 23.75 356.45 332.68 1072.86 482.37 900.12 Pass 9267.46 8103.90 9150.00 7398.48 123.99 23.58 356.08 331.12 1074.42 477.92 905.01 Pass 9286.91 8116.68 9175.00 7416.09 122.61 23.41 355.68 329.58 1076.10 473.45 909.77 Pass 9305.87 8129.03 9200.00 7433.77 121.22 23.26 355.26 328.06 1077.91 468.79 914.52 Pass 9324.37 8140.97 9225.00 7451.49 119.75 23.11 354.82 326.56 1079.91 463.84 919.29 Pass 9342.41 8152.50 9250.00 7469.24 118.31 22.98 354.35 325.07 1082.10 458.93 923.94 Pass 9360.01 8163.65 9275.00 7487.02 116.92 22.85 353.87 323.61 1084.51 454.05 928.47 Pass 9377.17 8174.41 9300.00 7504.82 115.55 22.74 353.37 322.16 1087.15 449.25 932.85 Pass 9393.90 8184.81 9325.00 7522.61 114.22 22.66 352.85 320.74 1090.08 444.52 937.13 Pass 9410.19 8194.83 9350.00 7540.36 112.88 22.60 352.31 319.33 1093.36 439.75 941.32 Pass 9427.75 8205.56 9375.00 7558.03 112.48 22.67 351.54 318.30 1097.03 438.55 945.63 Pass 9445.95 8216.67 9400.00 7575.62 112.49 22.79 350.67 317.43 1101.07 438.93 949.88 Pass 9464.14 8227.78 9425.00 7593.13 112.50 22.91 349.81 316.57 1105.48 439.30 954.04 Pass 9482.33 8238.88 9450.00 7610.54 112.50 23.04 348.96 315.72 1110.26 439.68 958.13 Pass 9500.52 8249.99 9475.00 7627.87 112.51 23.16 348.11 314.87 1115.40 440.02 962.19 Pass 9518.70 8261.09 9500.00 7645.12 112.52 23.28 347.28 314.04 1120.89 440.41 966.18 Pass 9536.87 8272.18 9525.00 7662.27 112.52 23.41 346.46 313.22 1126.74 440.80 970.18 Pass 9555.02 8283.26 9550.00 7679.31 112.53 23.53 345.65 312.40 1132.96 441.19 974.24 Pass 9573.14 8294.33 9575.00 7696.26 112.54 23.66 344.84 311.60 1139.54 441.58 978.39 Pass 9591.24 8305.38 9600.00 7713.11 112.55 23.79 344.05 310.81 1146.46 441.98 982.66 Pass 9609.32 8316.42 9625.00 7729.88 112.55 23.92 343.27 310.03 1153.70 442.35 987.09 Pass 9627.38 8327.44 9650.00 7746.59 112.56 24.05 342.50 309.26 1161.24 442.76 991.62 Pass 9645.41 8338.45 9675.00 7763.24 112.57 24.18 341.74 308.50 1169.06 443.17 996.32 Pass 9663.43 8349.45 9700.00 7779.82 112.58 24.31 340.99 307.75 1177.17 443.57 1001.20 Pass 9681.44 8360.45 9725.00 7796.33 112.59 24.44 340.26 307.02 1185.56 443.98 1006.29 Pass 9699.45 8371.45 9750.00 7812.77 112.60 24.57 339.53 306.29 1194.22 444.39 1011.62 Pass 9717.45 8382.44 9775.00 7829.15 112.61 24.71 338.82 305.58 1203.15 444.76 1017.19 Pass 9735.46 8393.43 9800.00 7845.48 112.62 24.84 338.12 304.88 1212.31 445.17 1022.94 Pass . BP . Anticollision Report Company: BP .Amoco Date: 5/612003 Time: 14:11:20 Field: Prudhoe Bay Reference Site: PB F Pad Cö-ørdinatt1(NE)R~ere..ce: Well;F~06;True North Reference Well: F-06 Yertk:aJ (TVD)Reference: 65.11'65.1 Reference WeIlpath: Plan F-06A Site: PB F Pad Well: F-21 Rule Assigned: Major Risk Wellpath: F-21 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Çtr.ç..,No-.Go MD TVD MD TVD Ref Offset 1'FOtAZI TFo-ØS Casing DistlJnce· Area ft ft ft ft ft ft dég deg in ft ft 9753.46 8404.42 9825.00 7861.76 112.63 24.97 337.44 304.20 1221.71 445.59 1028.93 Pass 9771.45 8415.41 9850.00 7877.99 112.64 25.11 336.76 303.52 1231.35 446.00 1035.15 Pass 9789.44 8426.39 9875.00 7894.14 112.64 25.24 336.10 302.86 1241.24 446.42 1041.63 Pass 9807.41 8437.37 9900.00 7910.23 112.66 25.38 335.45 302.21 1251.37 446.81 1048.40 Pass 9825.38 8448.34 9925.00 7926.28 112.67 25.51 334.81 301.57 1261.70 447.22 1055.38 Pass 9843.37 8459.32 9950.00 7942.31 112.68 25.63 334.19 300.95 1272.20 447.62 1062.59 Pass 9861.39 8470.32 9975.00 7958.39 112.69 25.73 333.57 300.33 1282.78 447.97 1070.02 Pass Site: PB F Pad Well: F-21PB1 Rule Assigned: Major Risk Wellpath: F-21PB1 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-~jor ~ Ctr-Ctr NO-Go MD TVD MD TVD Ref Offset TFO+AZI.· TFO-HS Casing Distance Area ft ft ft ft ft ft deg (leg ft ft 9839.39 8456.89 9150.00 7444.25 112.67 44.26 31.70 358.46 1280.53 513.45 926.28 Pass 9858.13 8468.33 9175.00 7461.12 112.69 44.47 31.02 357.78 1274.17 514.19 923.49 Pass 9876.88 8479.78 9200.00 7477.95 112.70 44.68 30.33 357.08 1268.06 514.92 921.05 Pass 9895.64 8491.23 9225.00 7494.73 112.71 44.89 29.63 356.38 1262.20 515.66 918.95 Pass 9914.41 8502.70 9250.00 7511.46 112.72 45.09 28.92 355.68 1256.61 516.43 917.20 Pass 9933.20 8514.17 9275.00 7528.15 112.73 45.30 28.21 354.96 1251.28 517.17 915.79 Pass 9952.00 8525.64 9300.00 7544.78 112.75 45.51 27.49 354.25 1246.22 517.91 914.74 Pass 9970.81 8537.13 9325.00 7561.35 112.76 45.73 26.76 353.52 1241.45 518.69 914.04 Pass 9989.63 8548.62 9350.00 7577.79 112.77 45.96 26.03 352.79 1237.06 519.50 913.80 Pass 10008.46 8560.12 9375.00 7594.09 112.79 46.19 25.29 352.05 1233.07 520.34 914.04 Pass 10027.30 8571.62 9400.00 7610.26 112.80 46.42 24.54 351.30 1229.47 521.15 914.75 Pass 10046.15 8583.13 9425.00 7626.28 112.81 46.65 23.79 350.55 1226.27 521.96 915.93 Pass 10065.01 8594.65 9450.00 7642.17 112.83 46.88 23.03 349.79 1223.47 522.77 917.58 Pass 10083.88 8606.17 9475.00 7657.92 112.84 47.10 22.27 349.03 1221.07 523.57 919.70 Pass 10102.75 8617.69 9500.00 7673.52 112.86 47.33 21.51 348.27 1219.08 524.42 922.29 Pass 10121.62 8629.21 9525.00 7688.98 112.87 47.56 20.74 347.50 1217.49 525.23 925.33 Pass 10140.50 8640.74 9550.00 7704.30 112.89 47.79 19.97 346.73 1216.32 526.05 928.83 Pass 10159.38 8652.27 9575.00 7719.50 112.90 48.03 19.20 345.96 1215.53 526.88 932.74 Pass 10178.26 8663.79 9600.00 7734.66 112.92 48.27 18.43 345.19 1215.01 527.73 936.94 Pass 10197.13 8675.31 9625.00 7749.80 112.93 48.51 17.65 344.41 1214.73 528.58 941.41 Pass 10215.99 8686.83 9650.00 7764.91 112.95 48.75 16.88 343.64 1214.70 529.47 946.17 Pass 10234.85 8698.34 9675.00 7780.01 112.97 48.99 16.11 342.87 1214.92 530.32 951.17 Pass 10253.70 8709.86 9700.00 7795.08 112.98 49.23 15.33 342.09 1215.39 531.17 956.43 Pass 10272.55 8721.36 9725.00 7810.13 113.00 49.47 14.56 341.32 1216.10 532.02 961.93 Pass 10291.39 8732.87 9750.00 7825.15 113.02 49.71 13.79 340.55 1217.07 532.88 967.68 Pass 10310.23 8744.37 9775.00 7840.16 113.03 49.95 13.01 339.77 1218.28 533.77 973.68 Pass 10329.06 8755.87 9800.00 7855.14 113.05 50.19 12.25 339.00 1219.74 534.62 979.88 Pass 10347.89 8767.36 9825.00 7870.10 113.07 50.43 11.48 338.24 1221.45 535.48 986.30 Pass 10366.71 8778.85 9850.00 7885.03 113.09 50.67 10.71 337.47 1223.40 536.34 992.92 Pass 10385.52 8790.34 9875.00 7899.95 113.10 50.91 9.95 336.71 1225.60 537.19 999.75 Pass 10404.34 8801.83 9900.00 7914.88 113.12 51.13 9.19 335.95 1227.99 537.84 1006.94 Pass 10423.18 8813.33 9925.00 7929.86 113.14 51.36 8.43 335.19 1230.55 538.65 1014.01 Pass 10442.03 8824.84 9950.00 7944.87 113.16 51.58 7.68 334.44 1233.27 539.47 1021.16 Pass 10460.90 8836.37 9975.00 7959.93 113.18 51.81 6.93 333.69 1236.16 540.29 1028.39 Pass 10479.79 8847.90 10000.00 7975.03 113.20 52.03 6.18 332.94 1239.20 541.10 1035.67 Pass 10498.69 8859.44 10025.00 7990.18 113.22 52.26 5.44 332.20 1242.40 541.92 1043.01 Pass 10517.60 8870.98 10050.00 8005.36 113.24 52.48 4.71 331.46 1245.76 542.78 1050.40 Pass . BP Anticollision Report Company: Field: Reference Site: Reference Well: Reference Wellpath: BPAmoco Prudhoe Bay PB F Pad F-06 Plan F-06A Co-ordinate(NE) Reference: Well: F-06, Vertical (TVD) Reference: 65.11' 65.1 . Date: 5/6/2003 Time: 14:17:20 Site: PB F Pad Well: F-21PB1 Wellpath: F-21PB1 V1 Reference MD TVD ft ft 10536.53 8882.54 10555.48 8894.11 10574.44 8905.69 Offset MD TVD ft 8020.59 8035.85 8051.16 10075.00 10100.00 10125.00 113.26 113.28 113.30 52.71 52.93 53.16 3.97 330.73 3.25 330.00 2.52 329.28 10593.42 8917.27 10150.00 8066.51 113.32 53.38 1.80 328.56 10612.41 8928.87 10175.00 8081.91 113.34 53.61 1.09 327.85 10631.41 8940.47 10200.00 8097.34 113.37 53.82 0.38 327.14 10650.42 8952.08 10225.00 8112.81 113.39 54.03 -0.32 326.44 10669.44 8963.69 10250.00 8128.32 113.41 54.24 358.98 325.74 10688.47 8975.31 10275.00 8143.86 113.43 54.45 358.28 325.04 Rule Assigned: Inter-Site Error: Major Risk 0.00 ft 1249.28 543.60 1057.80 Pass 1252.94 544.42 1065.20 Pass 1256.76 545.24 1072.61 Pass 1260.72 546.06 1080.00 Pass 1264.83 546.91 1087.37 Pass 1269.09 547.71 1094.70 Pass 1273.49 548.49 1101.97 Pass 1278.03 549.26 1109.18 Pass 1282.72 550.05 1116.31 Pass Site: PB F Pad Well: F-22 Rule Assigned: Major Risk Wellpath: F-22 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-M!,jor Axis Ctr-Ctr No-GCI Allowable MD TVD MD TVD Ref Offset ]1?<>;tAZlTFO-HS Casing Distance Area Deviation \Vål'ning ft ft ft ft ft ft dE!9 dag in ft ft ft 10395.30 8796.31 9725.00 9038.71 113.11 15.91 137.11 103.87 1280.06 423.82 1008.59 Pass 10416.50 8809.25 9750.00 9057.64 113.14 16.04 137.56 104.32 1271.35 424.05 1001.70 Pass 10437.69 8822.19 9775.00 9076.55 113.16 16.18 138.01 104.77 1262.68 424.51 994.67 Pass 10458.88 8835.13 9800.00 9095.44 113.18 16.31 138.47 105.23 1254.07 424.97 987.73 Pass 10480.08 8848.07 9825.00 9114.30 113.20 16.44 138.94 105.70 1245.51 425.44 980.87 Pass 10501.28 8861.02 9850.00 9133.14 113.22 16.58 139.41 106.16 1237.00 425.87 974.09 Pass 10522.48 8873.96 9875.00 9151.94 113.25 16.71 139.88 106.64 1228.56 426.34 967.38 Pass 10543.70 8886.92 9900.00 9170.72 113.27 16.84 140.36 107.12 1220.17 426.81 960.77 Pass 10564.92 8899.87 9925.00 9189.48 113.29 16.98 140.84 107.60 1211.86 427.29 954.26 Pass 10586.14 8912.83 9950.00 9208.24 113.31 17.12 141.33 108.09 1203.64 427.76 947.87 Pass 10607.36 8925.78 9975.00 9227.00 113.34 17.25 141.83 108.59 1195.50 428.22 941.61 Pass 10628.58 8938.74 10000.00 9245.76 113.36 17.39 142.33 109.09 1187.46 428.70 935.47 Pass 10649.80 8951.70 10025.00 9264.52 113.39 17.52 142.85 109.61 1179.51 429.18 929.45 Pass 10657.43 8956.36 10034.00 9271.28 113.40 17.57 143.03 109.79 1176.67 429.36 927.32 Pass Site: PB F Pad Well: F-32 Rule Assigned: Major Risk Wellpath: F-32 V1 Inter-Site Error: 0.00 ft Reference Offset ~nW-Major Axis Ctr,Ctr ·No-Go Allowable MD TVD MD TVD Ref Offset 1'F<>;tAZI TFO-HS Casing Distance Area Deviation \V~ing ft ft ft ft ft ft deg dag in ft ft ft 8857.34 7813.82 9100.00 8022.32 145.83 141.80 246.31 250.19 914.05 883.49 30.80 Pass 8870.00 7823.18 9125.00 8040.78 145.18 141.04 246.96 248.60 925.09 878.96 46.58 Pass 8870.00 7823.18 9150.00 8059.29 145.18 141.98 247.03 248.67 936.35 881.81 54.89 Pass 8886.93 7835.66 9175.00 8077.84 144.60 141.91 247.43 247.82 947.79 880.81 68.59 Pass 8900.00 7845.28 9200.00 8096.43 144.15 142.05 247.74 247.19 959.41 880.40 81.39 Pass 8900.00 7845.28 9225.00 8115.06 144.15 142.98 247.81 247.25 971.31 883.26 90.33 Pass 8923.19 7862.30 9250.00 8133.69 143.19 142.44 248.32 246.09 983.13 879.29 107.17 Pass 8935.05 7870.98 9275.00 8152.34 142.71 142.59 248.62 245.53 995.23 878.34 120.53 Pass 8946.79 7879.56 9300.00 8171.01 142.22 142.73 248.91 244.98 1007.48 877.23 134.09 Pass 8958.40 7888.02 9325.00 8189.62 141.75 142.88 249.21 244.46 1019.93 876.08 147.78 Pass 8969.86 7896.35 9350.00 8208.11 141.27 143.03 249.51 243.95 1032.63 874.79 161.75 Pass 9000.00 7918.19 9375.00 8226.49 140.03 141.83 250.19 242.51 1045.90 866.12 183.23 Pass 9000.00 7918.19 9400.00 8244.74 140.03 142.75 250.29 242.61 1058.81 868.85 193.42 Pass 9000.00 7918.19 9425.00 8262.86 140.03 143.73 250.41 242.73 1072.19 871.81 203.85 Pass 9000.00 7918.19 9450.00 8280.84 140.03 144.71 250.53 242.85 1086.00 874.72 214.80 Pass Còmpany: BP Amoco Field: Prudhoe Bay Referenee Site: PB F Pad Referenee WeD:. F-06 Referenee Wellpath: Plan F-06A Site: PB F Pad Well: F-32 Wellpath: F-32 V1 Reference MD TVD ft ft 9024.82 7936.06 9035.33 7943.60 9045.69 7951.01 9055.89 7958.28 9065.93 7965.42 Offset MD TVD ft ft 9475.00 8298.69 9500.00 8316.40 9525.00 8333.97 9550.00 8351.39 9575.00 8368.67 . BP Anticollision Report . Rule Assigned: Inter-Site Error: Ctr-Ctr No-Go Distanee Area ft ft 1099.70 867.18 1113.81 866.69 1128.13 866.31 1142.67 865.82 1157.42 865.25 9100.00 7989.51 9600.00 8385.81 134.89 142.87 253.37 238.90 1172.88 855.08 9100.00 7989.51 9625.00 8402.80 134.89 143.93 253.55 239.08 1187.67 858.27 9100.00 7989.51 9650.00 8419.68 134.89 145.00 253.74 239.26 1202.71 861.46 9100.00 7989.51 9675.00 8436.42 134.89 146.06 253.92 239.45 1218.01 864.67 9100.00 7989.51 9700.00 8453.04 134.89 147.12 254.12 239.64 1233.55 867.86 9100.00 7989.51 9725.00 8469.54 134.89 148.25 254.31 239.84 1249.34 871.26 9132.44 8012.22 9750.00 8485.92 132.90 146.52 255.15 238.56 1264.53 859.49 9141.45 8018.47 9775.00 8502.17 132.35 146.82 255.53 238.36 1280.30 858.41 Date: 51612003 Semi-Major Axis Ref Offset D()+AZI TF6-HS ClI$lng ft ft deg <:Ièg in 138.76 143.84 251.14 241.74 138.22 144.00 251.48 241.36 137.68 144.23 251.83 241.00 137.16 144.45 252.19 240.66 136.64 144.66 252.54 240.34 Major Risk 0.00 ft 235.87 Pass 251.60 Pass 267.38 Pass 283.41 Pass 299.67 Pass 327.33 Pass 339.24 Pass 351.44 Pass 363.88 Pass 376.62 Pass 389.42 Pass 417.64 Pass 435.06 Pass Nt\m¢ +Ni-S +EJ~W Northít1g F-ú6 1481H9 1ffiOJJ3 5974027JID -128 -120 -100 -SO --60 ~40 -20 0 -20 -40 -60 -SO ~100 ~120 -128 WPLL DETAILS Eai!ting Latit:lJòe Longítude- Soot 651960.66 7Ü"2-O'û9.84ON 148"46'0ì387W 06 ANTI£OLLJSION SETTINGS .cOMPANY DETAILS BP Amo.:;o Intcw.ù: To: Retèrence: -. .-----.-:, SURVEY PROGRi\M Depth Fm Th.->pfu To SUfVJ:y!P!an 8850:00 10875.04 Pkumed: F--06A wp03 V6 Tool MWD WELLPA1H DETAILS From Colour ToMD PlanF·(}(>..-\ 0 300 F-06 300 600 8850.00 600 900 ó5.Jt' 65.!tft 900 1200 Origin Origin Starring 1200 1500 +-Nl·S ¡ÐMW From TVD 1500 2000 353.27" 0.00 MO 0.00 2000 2500 2500 3000 3000 3500 3500 4000 LEGEND 4000 4500 4500 5000 5000 6000 6000 8000 8000 9000 9000 10000 10000 12000 2000 15000 90 &c MDfuç Am . SECTION DETAILS 'fVD +Nf.s +BJ~W I)l.çg TFat¢ VS¢c Target F-06A TJ E 15 .~ fit ø 1; ¡:::¡ i1) u .9 Nwne +N!.$ F-ú6 1480J9 1030.03 WELL DETAILS Easriug Interval: 25JJO To: 10875.04 Reference: Plan: F-OIiA wp03 ANTI..cOLLlSION SETTINGS COMPANY DETAILS Interpolation Metbod:MD Depth _ge From: 8850.00 Maximum Range: 1284-.65 SURVEY PROGRAM Depth Fm Ðep¡þ 1'(1 $lUYey/PIan &'&50.00 1087:\-04 Pùumcd~ F·Q6A wp03 V6 Northing LatilUde Longitude 8M BP Anwoo 5974027110 65t960.66 70"20W,&4ON ¡48~46·-OJ.387W 06 100 80 60 40 20 o 9000 9500 10000 10500 11000 11500 12000 12500 Measured Depth [500ft/in] WELLPATH DETAILS Pbm F·06A ParcntWclJpath: Tie on MV: F,JJ6 8850.00 65.11' 65.lIft J5327~ O.i)!) LEGEND "'" M SECTION DETAIL;!!. TVD +NI,s '¡'Et~W DLeg Trace """" T_ MD "" -----------------1 T;;>01 MWD 0.00 Starting From TVD 0,00 F,,¡}6,\'fI E p055120 DATE INVOICE I CREDIT MEMO DESCRIPTION 7/14/2003 INV# PR071003J PERMIT TO DRILL FEE THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP 6XPL9RATION, (ALASKA) INC. PRUDHOE BAY UNIt PO BOX 196612. . ANCHORAGE, AK 99519-6612 PAY: ,. B :p. r: ·1·..·~1It. tIIII; ......,' : ..:_.:' :/':::-::,"'.":_"'.-.:' _,: .. _---J":--:,:,f:::~~t:f-' : .. ..~.. JIll (W" .,iT", DATE I I CHECK NO. 7/14/2003 055120 GROSS VENDOR DISCOUNT NET ¡:-: Otç, A- :NATìoNALCITV BANK Ashland, Ohio Norp·· 05512'0 ,:". -. '" ~', :" -.. ..: ': --.. -:," . cONsoLIDATED COMMÉRCIAL ACCOUNT· TO THE ORDER OF: .. ALASKA OIL & GAS CONSËRVATION COMMISSION 333 W 7TH AVËNUË SUITE 100 ANCHORÄGE,AK 99501-3539 AMOUNT . ~***~~*$1&Ö.()()i~..*i4.:1 NOT VALID ¿~:.~r:..~.~.~.~~~..............._.... .........t'....:;...:: ...: :-:":;~. .;:..\::::~:.:.::...:.:..:.:~,~;.::,. ....:.:'.':. .~.::::.~.;..::";": ':'·1 . ":'"ß~ ...".....,.... "'.' \.... ... I ;·:\:~:··:·:4~ II" '. -:":: ::-., :.'.. ::.:;>:.J .1'.,.-- .....................1 i:~::: :::.;.. : +.::':\::.. .:(::~(:\~:~::·f~:~::~~:~·~:::r·\(:·i.: J 1110 5 5 ~ 20111 I: 0... . 20 a 8 q 5 I: o. 2 78 q b 1111 H -- - e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new well bore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 ajody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PE~MIT CJ1ECKLIST Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT F-06A Program DEV Well bore seg PTD#: 2031490 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Initial Class/Type DEV I 1-01L GeoArea 890 Unit 11650 On/Off Shore ~ Annular Disposal Administration 1 Pe(miUee attache.d. . . . . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . 2 .Leasenumber .appropriate . . . . . . . . . . . . . . . . .Y.es . . . . . . . . . 3 .U.nique weltn.ame.and oumb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . . . . _ _ . . _ . _ . . . . _ . . . . . . . . . . . _ . . . . . _ . . . . . 4 WellJo.cated in a.d.efioe.dP901 . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . 5 WellJo.cated proper distance. from driJling uoitbpuod.ar:y. . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . 6 WeUJo.cated prpper .distance. from otber welJs. . . . . . . . . . . . . . . . . Yes . . . . . . . . . 7 .S.utficieotacreage.ayailable indrilliog unjt .Yes. . . . . . . . 8 Jf.deyiated,js.weJlbo.replatiocJuded. ............ ...... . .Np. ....... ...... 9 .O,µer.ator onl}' aftected party . No . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 .O,µe(ator bas.apprppriate.b.ond inJorce . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . No. . . . . _ . . . . . . . . . . . . . . _ . . . . _ . . . . . . . _ _ . . . . . . . . . _ ............... _ . . . . . . . . . . . . . . 11 Permit cao be issued witbo.ut co.nservatioo order. . No. . . . . . . . . . . . . . . . . Appr Date 12 Peunitc.aobeissuedwjtbo.utadminist(atÏ\le.apprpyaJ.................... .Yes. ........................... RPC 8/26/2003 13 Can permit be approved before 15-day wait Yes 14 WeJUo.cated withio area and.strataauthorized by.lojectioo Orde( # (puUOif: incpOlmeots).(For NA . . . . . .. ............. . . . . . . . 15 .AjlwelJs.witþin.1l4.mite.area.ofreyiewjdeotlfied(Fp(servjc.ewellooly)... _..... _..... NA............................ _......... _..... _..... _. _........... _ _ _ _....... 16 Pre-produ.ced injector; .duration of pre-.µroduGtioo tess than. 3 mOnths. (For.service welt o.nJy) . .NA . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . _ . 17 .ACMPF.indjngofCQn.sißteocy.h.as been.issued.for.tbis project. . . . . . . . . NA . . . . . . . . . . . . . . . . . 18C.onductor st(ingprQvided . . . . . . . . . . . . . . . . . . . . _ . . .NA . . . . . . . . . . . . . . . . . . . . .. ...... . . . . . . . . 19 .S.ud'ac.e .casing. protects all known USDWs . . _ . . . . . .NA . . . . . . . . . . . . . . . . _ . . 20CMTvptadequ.ate.to Circ.utate on c9nductor.& SUJf.CSg . . . . . . _ _ . . . . . . .NA . . . . . . . _ . . . . . 21 .CMT vol. adequate. to tie-inJQngstring to.sud' csg_ . . . . . . _ . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . 22 .CMT will coyeraJl koownpro.duGtiye bQri¡::Qns . .Yes. . . . . . . . . . . .. ..... _ . . . . . _ . . . . . . . 23 Casing designs adequate fp( C,T, B&permafrost . . .Yes.. . . . . . . . . . . _ . . . . . . . . . . . . . . 24 A.dequate.tankage.oJ re.serve pit . . . . . . . . . . . . . . .Yes \jabors2.ES, . . . _ . . . . . . . . . . 25 Jfa.re-d(ilt has.a 10-4.03 fo.r abandonment beeo appro.ved . . . . . . . . . .Yes. . .5/6/200.3, . . . . . . _ . . . . . . _ . . . . . . . 26 A.dequateweJlb.ore sep¡;¡ratjo_n.pro.µosed. . . . . _ . . . . _ _ _ . . _ _ _ _ _ . _ _ . _ _ . . . . _ _ _ _Yes _ _ _ _ . . . _ . . _ _ . . _ _ _ _ . _ _ . _ _ _ _ . _ _ . . _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . 27 Jf.diverter required, do.es it meet reguJa.tioos. . _ _ . _ . . . . . _ _ . .NA . Sidet(ack. _ . . _ . . _ _ . _ . . . _ . . . . _ _ . . . . . . . Appr Date 28 .Drilliog flujdprogram schematic&.eq.uipJistadequate . . . . . . _ _ _ . . . .Yes . . Mç¡xMW.t1.4_ppg.. . . _ . . . . . _ . . . . . _ . . . . _ . . . . . WGA 8/27/2003 29 BOPEs,d_o.they meetreguJatioo . . . . . _ . _ . . . . . . . . .Yes. . . . . . . . _ . . 30 .BOPE.press ratiogap.µrop(iate;testto(putpsig Ln.comOleots ). ... _Y.es.. Testto.3500psi..MS~237"1psi........... 31 .Choke.manjfold co.mpJies w/APt R~-53 (May 84) . . . . . . . . . . . . .Yes _ . . . . _ _ . . . . . _ . 32 Wo.rk will occ.U( with9utoperatjon .stll!tdown. . . . . . . . . . . . . . Yes _ . 33 Jspres.encs.o.fH2Sgas.prob.able.... ....... . No......... . 34 Meçbanicç¡l.c90djtion .of wells within J\OR yerified (forservjce wel] only) _ . . . . . . . .NA . Engineering Geology Appr RPC Date 8/26/2003 Geologic Commissioner: D/~ D - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - e - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - e - - - - - - - - - - - - - - - - - - - - - - - - - - - - - , - - -- - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - 35 Pe(mit. c.ao be issu.ed wlo. hyd(ogen s.ulfide Oleas.uœs. _ . . . . . . . . . . 36D.ata.preseoted on. pote_ntia\ pyeJpressure .zooes. . . . . _ . 37SeißOlicanç¡lysjs. o.f shaJlow gas.ZPlJes . . . _ _ . . . . . _ . 38 .Seç¡bedcooditipo survey (if off-sh.oœ) . . . . _ . . _ . . . . . . . _ . . . . . _ . 39 . Co.nta.ct nam.elpÞoneJorweekly progress reports [expIQrç¡tor:yo!lIYl . . . . . _ _ . . . . N.o. . _ . _.. .NA_ .. NA. NA .. .NA. _. - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - ~ - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - . - - - - - - ~ - - - - - -- - - - - - - -- Date: Engineering Commissioner: Date Public Commissioner Date F:f~JD ~ ~~ ?:;~ e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, infomlation 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 infonnation. Sperry-Sun Dr~ng Services LIS sca~ility . ~03 -, Lt 1 $Revision: 3 $ LisLib $Revision: 4 $ Tue Mar 09 13:43:34 2004 ~v(lt'1 Reel Header Service name....... . . . . . .LISTPE Date.................... .04/03/09 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.................... .04/03/09 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 F-06A 500292009701 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 09-MAR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002661658 T. GALVIN J. RALL / D. MWD RUN 3 MW0002661658 J. BOBBITT J. RALL / D. MWD RUN 4 MW0002661658 T. GALVIN J. RALL / D. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0002661658 T. GALVIN J. RALL / D. MAD RUN 5 MW0002661658 T. GALVIN J. RALL / D. # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 11N 13E 2772 2879 RECEIVED 66.61 30.00 f". ,I, 'ì 1 q 0¡'''~Lt .., 0 .,:1,1. i ,;-", \ 1-'J\I # WELL CASING RECORD OPEN HOLE CASING DRILLERS tilaska Oil &. Gas Cons, Commisaion .Anchorage RBDMS RD MAR 3 0 2nmJ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S. (IN) 8.500 6.125 SIZE (IN) DEPTH (FT) 9.625 8839.0 7.000 10309.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, TO POSITION THE WHIPSTOCK, THE TOP OF WHICH WAS AT 8839'MD/7801'TVD AND THE BOTTOM WAS AT 8855'MD/7812'TVD. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. TIE-IN SGRC DATA OVER THIS INTERVAL WERE ACQUIRED AFTER MWD RUN 3. THESE MAD PASS DATA WERE MERGED WITH MWD DATA FROM RUN 3. NO PROGRESS WAS MADE ON MWD RUN 1. 4. MWD RUNS 3 - 5 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 4 & 5 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) i STABILIZED LITHO-DENSITY (SLD) i AND AT-BIT INCLINATION (ABI). MAD PASS DATA OVER THE INTERVAL 10980'MD - 10340'MD (BIT DEPTHS) WERE ACQUIRED WHILE POOH AFTER REACHING FINAL TD. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 10' UPHOLE, PER E-MAIL FROM K. COONEY (SIS/BP) DATED 2 MARCH 2004. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 2 - 5 REPRESENT WELL F-06A WITH API#: 50-029-20057-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10980'MD/9146'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT RESISTIVITY (EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP BIN). I . SLIDE = NON-RO TED INTERVALS REFLECTING BIT D S. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4 PPG MUD SALINITY: 2400 PPM CHLORIDES FORMATION WATER SALINITY: 10994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPX RPS RPD RPM ROP NPHI NCNT FCNT PEF RHOB DRHO $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8629.5 8821.5 8821.5 8821.5 8821.5 8821.5 8845.0 10280.5 10280.5 10280.5 10299.5 10299.5 10299.5 STOP DEPTH 10922.0 10929.0 10929.0 10929.0 10929.0 10929.0 10970.0 10885.5 10885.5 10885.5 10900.5 10900.5 10900.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8629.5 10970.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # GR 8639.5 10980.0 BIT RUN NO 2 3 4 5 MERGE TOP 8855.0 8871.0 10309.0 10733.0 MERGE BASE 8871.0 10309.0 10733.0 10980.0 REMARKS: MERGED MAIN P~ $ . # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record... . . . . . . . . . .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNT/ 4 1 68 36 10 NCNT MWD CNT/ 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8629.5 10970 9799.75 4682 8629.5 10970 ROP MWD FT/H 0.09 260.69 82.8486 4251 8845 10970 GR MWD API 13.62 550.6 93.8526 4586 8629.5 10922 RPX MWD OHMM 0.47 1608.34 10.0622 4216 8821.5 10929 RPS MWD OHMM 0.48 1397.13 8.88876 4216 8821.5 10929 RPM MWD OHMM 0.61 1945.57 18.1757 4216 8821. 5 10929 RPD MWD OHMM 0.67 2000 45.6351 4216 8821.5 10929 FET MWD HOUR 0.16 79.3 2.6611 4216 8821.5 10929 NPHI MWD PU-S 6.05 59.39 21.2486 1211 10280.5 10885.5 FCNT MWD CNT/ 127.4 3021. 4 911.196 1211 10280.5 10885.5 NCNT MWD CNT/ 16025 52707.4 32884.6 1211 10280.5 10885.5 RHOB MWD G/CM 2.064 3.055 2.40551 1203 10299.5 10900.5 DRHO MWD G/CM -0.211 0.634 0.0613973 1203 10299.5 10900.5 PEF MWD BARN 1. 41 10.74 2.58963 1203 10299.5 10900.5 First Reading For Entire File......... .8629.5 Last Reading For Entire File.......... .10970 File Trailer Service name........... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.002 Physical EOF File Header .... Service name............ ~LIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/09 Maximum Physical Record. .65535 File Type... ............ .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI FET RPD RPM RPS RPX GR PEF DRHO RHOB RAT $ 2 . and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 10300.0 10300.0 10300.0 10300.0 10300.0 10300.0 10300.0 10300.0 10300.0 10300.5 10300.5 10300.5 10330.5 STOP DEPTH 10889.0 10889.0 10889.0 10931.0 10931.0 10931.0 10931.0 10931.0 10924.5 10903.0 10903.0 10903.0 10969.0 # MERGED DATA SOURCE PBU TOOL CODE MWD $ MAD RUN NO. MAD PASS NO. MERGE TOP 5 1 10310.0 # REMARKS: MERGED MAD PASS. $ # 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 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 NPHI MAD PU-S 4 1 68 32 9 FCNT MAD CNTS 4 1 68 36 10 NCNT MAD CNTS 4 1 68 40 11 RHOB MAD G/CM 4 1 68 44 12 DRHO MAD G/CM 4 1 68 48 13 PEF MAD BARN 4 1 68 52 14 MERGE BASE 10980.0 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10300 10969 10634.5 1339 10300 10969 RAT MAD FT/H 3 372 215.39 1278 10330.5 10969 GR MAD API 11.01 556.04 63.7437 1250 10300 10924.5 RPX MAD OHMM 0.3 132.07 15.6164 1263 10300 10931 RPS MAD OHMM 0.47 169.26 16.4705 1263 10300 10931 RPM MAD OHMM 0.49 158.68 17.5119 1263 10300 10931 RPD MAD OHMM 0.45 2000 22.4552 1263 10300 10931 FET MAD HOUR 2.41 114.86 21.9953 1263 10300 10931 NPHI MAD PU-S 7.98 44.61 21.7254 1179 10300 10889 FCNT MAD CNTS 258 2436.5 840.539 1179 10300 10889 NCNT MAD CNTS 17826 49497.9 31837.9 1179 10300 10889 RHOB MAD G/CM 2.027 3.081 2.36897 1206 10300.5 10903 DRHO MAD G/CM 0.001 0.789 0.163489 1206 10300.5 10903 PEF MAD BARN 1. 34 8.41 2.28326 1206 10300.5 10903 First Reading For Entire File..... .... .10300 Last Reading For Entire File.......... .10969 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/09 Maximum Physical Record. .65535 File Type.......... . . . . . .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 8855.0 STOP DEPTH 8871.0 # 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): 17-SEP-03 Insite 66.37 Memory 8871.0 8839.0 BOTTOM LOG INTERVAL (FT) 4IIÞ BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # 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: $ # 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 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 8871.0 41.7 41.7 TOOL NUMBER 8.500 2259.0 LSND 11.40 54.0 9.2 1850 3.4 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD020 FT/H Min 8855 0.09 Max 8871 7.68 First Reading For Entire File......... .8855 Last Reading For Entire File.......... .8871 File Trailer Service name............ .STSLIB.003 Mean 8863 5.12303 Nsam 33 33 . .0 .0 .0 .0 First Reading 8855 8855 Last Reading 8871 8871 service Sub Level Name...4It Version Number.......... .1.0.0 Date of Generation...... .04/03/09 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...... .04/03/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPX RPM RPD FET ROP $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 8639.5 8831.5 8831.5 8831.5 8831.5 8831.5 8871.5 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 10277.5 10269.5 10269.5 10269.5 10269.5 10269.5 10309.0 19-5EP-03 Insite 66.37 Memory 10309.0 8871.0 10309.0 44.6 53.1 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 124725 163840 # 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: 8.500 8855.0 LSND 11. 40 55.0 9.4 MUD CHLORIDES (PPM): 4IIÞ 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: 1800 4IIÞ 3.3 1.500 70.0 .730 151.0 1. 400 70.0 2.000 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # 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 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8639.5 10309 9474.25 3340 8639.5 10309 ROP MWD030 FT/H 2.33 260.69 97.6353 2876 8871.5 10309 GR MWD030 API 30.8 183.43 105.854 3277 8639.5 10277.5 RPX MWD030 OHMM 0.9 1608.34 3.78571 2877 8831.5 10269.5 RPS MWD030 OHMM 0.89 1397.13 4.45092 2877 8831.5 10269.5 RPM MWD030 OHMM 0.85 1751. 71 6.13778 2877 8831.5 10269.5 RPD MWD030 OHMM 0.92 2000 12.8549 2877 8831.5 10269.5 FET MWD030 HOUR 0.16 22.8 0.729249 2877 8831.5 10269.5 First Reading For Entire File......... .8639.5 Last Reading For Entire File.......... .10309 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/09 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...... .04/03/09 Maximum Physical Record. .65535 File Type........... . . . . .LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPD RPS RPX FET GR NCNT FCNT NPHI PEF DRHO RHOB ROP $ 5 . header data for each bit run in separate files. 4 .5000 START DEPTH 10270.0 10270.0 10270.0 10270.0 10270.0 10278.0 10290.5 10290.5 10290.5 10309.5 10309.5 10309.5 10309.5 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ # STOP DEPTH 10692.0 10692.0 10692.0 10692.0 10692.0 10685.0 10650.0 10650.0 10650.0 10663.5 10663.5 10663.5 10733.0 23-SEP-03 Insite 66.37 Memory 10733.0 10309.0 10733.0 33.3 36.3 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 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): TOOL NUMBER 62456 110059 100547 73634 6.125 10309.0 Flo-Pro 8.40 56.0 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: 9.2 . 2400 .0 1. 450 70.0 .840 126.0 1.600 70.0 1. 400 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10270 10733 10501.5 927 10270 10733 ROP MWD040 FT/H 0.97 145.59 53.6325 848 10309.5 10733 GR MWD040 API 15.98 550.6 85.1925 815 10278 10685 RPX MWD040 OHMM 0.47 1208.36 32.3183 845 10270 10692 RPS MWD040 OHMM 0.48 218.54 24.5362 845 10270 10692 RPM MWD040 OHMM 1. 07 1945.57 65.1151 845 10270 10692 RPD MWD040 OHMM 0.95 2000 177.616 845 10270 10692 FET MWD040 HOUR 0.45 79.3 8.85354 845 10270 10692 NPHI MWD040 PU-S 6.05 59.39 23.6361 720 10290.5 10650 FCNT MWD040 CNTS 127.4 3021. 4 781.764 720 10290.5 10650 NCNT MWD040 CNTS 16025 52707.4 31001.4 720 10290.5 10650 RHOB MWD040 G/CM 2.064 3.047 2.408 709 10309.5 10663.5 DRHO MWD040 G/CM -0.055 0.634 0.0612807 709 10309.5 10663.5 PEF MWD040 BARN 1. 41 9.73 2.80011 709 10309.5 10663.5 First Reading For Entire Fi~....... .10270 Last Reading For Entire File.......... .10733 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/09 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...... .04/03/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPX RPS ROP $ 6 . header data for each bit run in separate files. 5 .5000 START DEPTH 10650.5 10650.5 10650.5 10664.0 10664.0 10664.0 10685.5 10692.5 10692.5 10692..5 10692.5 10692.5 10733.5 # 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: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 10895.5 10895.5 10895.5 10910.5 10910.5 10910.5 10932.0 10939.0 10939.0 10939.0 10939.0 10939.0 10980.0 24-SEP-03 Insite 66.37 Memory 10980.0 10733.0 10980.0 53.0 54.1 TOOL NUMBER 62456 SLD CTN EWR4 $ ST~~ZED LITHO DEN CO~ERMAL NEUTRON Electromag Resis. 4 # 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: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 110059 100547 73634 6.125 10309.0 Flo-pro 8.50 56.0 9.2 2400 .0 1. 450 .860 1.600 1. 400 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 . 70.0 123.0 70.0 70.0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10650.5 10980 10815.3 660 10650.5 10980 ROP MWD050 FT/H 0.26 145.14 52.1074 494 10733.5 10980 GR MWD050 API 13.62 117.73 28.529 494 10685.5 10932 RPX MWD050 OHMM 0.8. 30.41 8.54593 494 .692.5 10939 RPS MWD050 OHMM 0.67 26.45 7.96879 494 692.5 10939 RPM MWD050 OHMM 0.61 25.62 7.99194 494 10692.5 10939 RPD MWD050 OHMM 0.67 880.15 10.7875 494 10692.5 10939 FET MWD050 HOUR 0.51 13 .47 3.31962 494 10692.5 10939 NPHI MWD050 PU-S 8.65 32.6 17.7476 491 10650.5 10895.5 FCNT MWD050 CNTS 408.5 2252.3 1100.99 491 10650.5 10895.5 NCNT MWD050 CNTS 25548.6 46289.4 35646 491 10650.5 10895.5 RHOB MWD050 G/CM 2.158 3.055 2.40193 494 10664 10910.5 DRHO MWD050 G/CM -0.211 0.246 0.0615648 494 10664 10910.5 PEF MWD050 BARN 1.44 10.74 2.28755 494 10664 10910.5 First Reading For Entire File......... .10650.5 Last Reading For Entire File...... ... ..10980 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/09 Maximum Physical Record. .65535 File Type...... ......... .LO Next File Name. ......... .STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE NCNT GR RPX RPS RPM RPD FET FCNT NPHI RHOB DRHO PEF RAT $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 7 for each pass of each run in separate files. header data .5000 5 1 START DEPTH 10310.0 10310.0 10310.0 10310.0 10310.0 10310.0 10310.0 10310.0 10310.0 10310.5 10310.5 10310.5 10340.5 STOP DEPTH 10899.0 10934.5 10941.0 10941.0 10941.0 10941.0 10941.0 10899.0 10899.0 10913 .0 10913.0 10913 . 0 10979.0 24-SEP-03 SURFACE SOFTWARE VERS~ DOWNHOLE SOFTWARE VER~: 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 VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # 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: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction........ ........ . Down Optical log depth units. ........ ..Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record........ ... ..Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Insite 66.37 Memory 10980.0 10340.0 10980.0 . 53.0 54.1 TOOL NUMBER 62456 110059 100547 73634 6.125 10309.0 Flo-pro 8.50 56.0 9.2 2400 .0 1. 450 .860 1.600 1. 400 70.0 123.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD051 FT/H 4 1 68 4 2 GR MAD051 API 4 1 68 8 3 RPX MAD051 OHMM 4 1 68 12 4 RPS MAD051 OHMM 4 1 68 16 5 RPM MAD051 OHMM 4 1 68 20 6 RPD MAD051 OHMM 4 1 68 24 7 FET MAD051 HOUR 4 1 68 28 8 NPHI MAD051 PU-S . 1 68 32 9 . FCNT MAD051 CNTS 1 68 36 10 NCNT MAD051 CNTS 4 1 68 40 11 RHOB MAD051 G/CM 4 1 68 44 12 DRHO MAD051 G/CM 4 1 68 48 13 PEF MAD051 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10310 10979 10644.5 1339 10310 10979 RAT MAD051 FT/H 3 372 215.39 1278 10340.5 10979 GR MAD051 API 11.01 556.04 63.7437 1250 10310 10934.5 RPX MAD051 OHMM 0.3 132.07 15.6164 1263 10310 10941 RPS MAD051 OHMM 0.47 169.26 16.4705 1263 10310 10941 RPM MAD051 OHMM 0.49 158.68 17.5119 1263 10310 10941 RPD MAD051 OHMM 0.45 2000 22.4552 1263 10310 10941 FET MAD051 HOUR 2.41 114.86 21.9953 1263 10310 10941 NPHI MAD051 PU-S 7.98 44.61 21. 7254 1179 10310 10899 FCNT MAD051 CNTS 258 2436.5 840.539 1179 10310 10899 NCNT MAD051 CNTS 17826 49497.9 31837.9 1179 10310 10899 RHOB MAD051 G/CM 2.027 3.081 2.36897 1206 10310.5 10913 DRHO MAD051 G/CM 0.001 0.789 0.163489 1206 10310.5 10913 PEF MAD051 BARN 1. 34 8.41 2.28326 1206 10310.5 10913 First Reading For Entire File......... .10310 Last Reading For Entire File.......... .10979 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.008 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .04/03/09 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name......... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.................... .04/03/09 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name...... . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF . . End Of LIS File