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209-145
9333, 9360, 9589 & 9723 By Grace Christianson at 3:06 pm, Apr 24, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.04.24 14:42:58 - 08'00' Sean McLaughlin (4311) 325-256 JJL 4/25/25 A.Dewhurst 28APR25 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. 10-407 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.28 15:59:29 -08'00'04/28/25 RBDMS JSB 042925 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: April 24, 2025 Re: 07-23B Sundry Request Sundry approval is requested to set a whipstock in the 07-23B wellbore as part of the drilling and completion of the proposed 07-23C CTD lateral. Proposed plan: 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" 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 07-23C 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" whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in the Ivishak Zone 4 and lands in Zone 2. The lateral will continue in Zone 4, 3 and 2 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr 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 May 2025) 1. Slickline : DGLVs, MITs, Dummy WS drift 2. Fullbore : MIT-IA and/or MIT-T to 2500 psi 3. E-Line : Set 4-1/2" Whipstock* at 9,330’ MD at 0 degrees ROHS 4. Coil : Mill XN nipple (at 9,009' MD) and Window (if window not possible, mill with rig). – see attached procedure 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove well house and level pad. Rig Work: x Reference 07-23C Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,387 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, ~168' (28 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2,327' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 33.8 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Alternate plug placement variance request per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : LGLVs, contingent LTP* 3. Service Coil : Post rig RPM and perforate (~30’) Trevor Hyatt CC: Well File Drilling Engineer Joe Lastufka 907-223-3087 9,303' 9,303' 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 07-23B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-145 50-029-21635-02-00 9967 Conductor Surface Intermediate Liner Liner 9257 79 2460 5739 3604 948 9630 20" 13-3/8" 9-5/8" 7" 4-1/2" 8678 30 - 109 29 - 2489 27 - 5766 5600 - 9204 9017 - 9965 30 - 109 29 - 2489 27 - 5325 5195 - 8531 8356 - 9255 none 470 1950 4760 5410 8540 9333 , 9360 , 9589 , ~ 9723 1490 3450 6870 7240 9020 9210 - 9738 4-1/2" 12.6# 13Cr85 25 - 9021 8537 - 9038 Structural 4-1/2" Baker S-3 Perm , 8903 , 8248 No SSSV 8903 8248 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com 907.564.5280 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 0028309 25 - 8360 438 506 46093 49997 1 13 0 0 1850 1195 N/A 13b. Pools active after work:PRUDHOE OIL 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 11:41 am, May 01, 2024 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.04.30 15:13:20 - 08'00' Eric Dickerman (4002) RBDMS JSB 051324 DSR-5/1/24WCB 7-30-2024 ACTIVITYDATE SUMMARY 4/1/2024 *** WELL S/I ON ARRIVAL*** JOB SCOPE: (NS CIBP & PERFORATE 7' OF 3 1/8'' GEO RAZOR 6 spf 60 DEG PHASE) RIG UP YJ ELINE. WAITING ON NON MOBILE TO BRING EQUIPMENT *** JOB CONTINUED ON 4-2-2024*** 4/2/2024 ***JOB CONTINUED FROM 4-1-2024*** PT PCE 300 PSI LOW /3000 PSI HIGH RIH WITH CH/2.75'' GR-CCL/ 7' OF 3.125'' GEO RAZOR GUNTO PERFORATE INTERVAL 9320'-9327' CCL TO TOP SHOT 12.3' CCL STOP DEPTH 9307.7' MD GR-CCL CORRELATE TO BAKER HUGHES RESERVOIR PROFORMANCE MONITOR PNC 3D DATED 31-MAR-2017 RIH WITH CH/2.75'' GR-CCL/ NS CIBP TO SET AT DEPTH 9333' CCL TO MD ELEMENT 12.6' CCL STOP DEPTH 9320.4' ***JOB COMPLETE*** *** WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU 07-23B RIH WITH CH/2.75'' GR-CCL/ NS CIBP TO SET AT DEPTH 9333' PERFORATE INTERVAL 9320'-9327' CIBP and adperfs are correctly shown on the new WBS, below. -WCB 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 07-23B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-145 50-029-21635-02-00 9967 Conductor Surface Intermediate Liner Liner 9257 79 2460 5739 3604 948 9630 20" 13-3/8" 9-5/8" 7" 4-1/2" 8678 30 - 109 29 - 2489 27 - 5766 5600 - 9204 9017 - 9965 30 - 109 29 - 2489 27 - 5325 5195 - 8531 8356 - 9255 none 470 1950 4760 5410 8540 9360 , 9589 , ~9723 1490 3450 6870 7240 9020 9210 - 9738 4-1/2" 12.6# 13Cr85 25 - 9021 8537 - 9038 Structural 4-1/2" Baker S-3 Perm , 8903 , 8248 No SSSV 8903 8248 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com 907.564.5280 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 0028309 25 - 8360 492 742 47172 57591 0 5 0 0 1979 1259 N/A 13b. Pools active after work:PRUDHOE OIL 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 1:52 pm, Aug 22, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.08.22 09:53:33 -08'00' RBDMS JSB 081923 DSR-8/23/23WCB 3-11-2024 ACTIVITYDATE SUMMARY 7/25/2023 ***WELL FLOWING ON ARRIVAL*** DRIFT TBG TO CIBP @ 9589' MD w/ 10' x 3.66" DMY GUN (no issues) ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** 7/27/2023 *** WELL SI ON ARRIVAL *** INITIAL T/I/O = 2500/550/0 LOAD HOLE WITH 150 BBLS OF CRUDE STAB ON LUBRICATOR WITH PLUG GUN COMBO. PT TO 300 LOW / 3000 HIGH RIH TO SET CIBP AT 9360 AND PERFORATE 9338 - 9348 FT. W/ 3-1/8" 6 SPF, 60 DEG, GEO BASIX XDP, 0.43 IN HOLE, 35.80 IN PENETRATION CORRELATED TIE IN TO BAKER RPM PNC3D LOG DATED 31-MAR-2017 CIBP TAGGED AFTER SETTING, ALL SHOTS FIRED. FINAL T/I/O = 1250/600/0 *** WELL SI ON DEPARTURE, DSO NOTIFIED *** 7/27/2023 T/I/O Assist E-line (Profile Modification) Pumped 1 bbl 50/50 methanol, followed by 150 bbls crude down TBG to load. IA and OA = OTG. Well in E-line control upon LRS departure. Daily Report of Well Operations PBU 07-23B RIH TO SET CIBP AT 9360 AND PERFORATE 9338 - 9348 FT. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 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. Set CIBP 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number 209-145 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 1 Slratigraphic ❑ Service ❑ 1 6. API Number. 50-029-21635-02-00 7. Property Designation (Lease Number): ADL 028309 e. Well Name and Number: PBU 07-23B 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: �.r7^ . Yam ti's®" Total Depth: measured 9967 feet Plugs measured 9589, 9723 feet true vertical 9257 feet Junk measured None feet JUL. 0 1 2019 Effective Depth. measured 9589 feet Packer measured 8903 rest true vertical 8896 feet Packer true vertical 8248 feet rr AOGC Casing: Length: Size. MD: TVD: Burst: Collapse: Structural Conductor 79 20" 30-109 30-109 1490 470 Surface 2460 13-3/8" 29-2489 29-2489 3450/5380 1950 / 2670 Intermediate 5739 9-5/8" 27-5766 27-5325 6870 4760 Liner 3604 7" 5600-9204 5195-8531 7240 5410 Liner 948 4-1/2" 9017-9965 8356-9255 9020 8540 Perforation Depth: Measured depth: 9210-9738 feet True vertical depth: 8537-9038 feet Tubing (size, grace, measured and true vertical depth) 4-1/2" 12.6# 13Cr85 25-9021 25-8360 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 8903 8248 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-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 336 34074 561 0 1041 Subsequent to operation: 157 6632 4 0 850 14. Attachments: (evuimd per 20 MC 25070.25.071,325.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ SVatigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ 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: WA Authorized Name: Thompson, Ryan Contact Name: Thompson, Ryan Authorized Tide: Interventions Engineer. Contact Email: RYAN.THOMPSONAbp.com Authorized Signature: Date. 6 /Z /' Contact Phone: +1 907 564 4535 Form 10404 Revived 04/2017 �� GulDl�.'� RBDMS�N/jUL 022019 Submit Original Only Daily Report of Well Operations PBU 07-23B Ar.TIVITVnnTF ***WELL S/I ON ARRIVAL*** (profile mod) DRIFTED TO CIBP @ 9,723' SLM w/ 10' x 2.25" BLR. (CIBP appears to have moved downhole). USING +10 CORRECTION FROM BELOW PUTS CIBP AT 9733'MD. DRIFTED TO XN-NIP @ 9,009' MD w/ 3.80" G -RING FOR C/F OF +10'. 6/23/2019 ***WSR CONTINUED ON 6/24/19*** ***WSR CONTINUED FROM 6123/19*** (Profile Modification) DRIFTED TO CIBP @ 9,723' SLM w/ 3.625" G -RING. SET 4-1/2" WFD CIBP 9,589' MD. 6/24/2019 B MPLETE, WELL LEFTS I*** TFd£= CMV WELLHEAD= MCB/OY ACTUATOR= BAK62C KB. ELEV = 5T BF. HEV = Opn/Sgz KOP= 3050 Max Ante = 39' @ 5796' Dalen LD= 954T DatunTVD= 880066 CSG, 724, L-80, D = Minimum ID = 3.725" @ 9009' 4-112" HES X NIPPLE 19-58• WHPSTO 02/31/09) H 5756' 1 9-5/8' SAFETY NOTES: """412' CHROM E TBG & LKR ""' ORIG & EP�aA H �°® WHIPSTOCK 07-23B NOlTSFMLGw ON PEW TABLE'' 2073' 412' HES X NP, D = 3.813' 6242' PERFORATION SLANWRV FtEF LOG: MAUAFiC'/ADN on 01/10/10 ANGLEATTOP PH6=: 19'@9219 Note: P --fu to Rodu:lion OB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 2-12" 6 9210-9232 O 0781/18 3-3/8" 6 9655-9660 C 05103!17 3-38" 6 "9680-9690 C 03/28/10 3-38' 6 "9700 - 9718 C 0282/10 3-38' 6 '9718 - 9738 C 0128110 DATA DEPTH SHFT® TO MATCH FML LOG SCILLABF32GE2 MWS1 ARCAND LAST RW ON 01/10/10 412' TBG, 12.6#. 13CR-85 VAM TOP, .0152 bpf, D = 3.958' 902V GAS LFT MANDRELS ST LD TVD I DEVI TYPE VLV LATCH PORE DATE 4 3747 3709 26 KBG2 DOME BK 16 0325/19 3 6215 5716 20 KBG2 SO BK 22 0325/19 2 7775 7184 19 KBG2 DMY BK 0 03QW19 1 8795 8146 20 KBG2 DMY BK 0 0325/19 5600' 8-5/8' X T ZXP LTPw/SEFINC SLV, D = 6.290' 9-5/8"X 7" BKR FLS(LOCK LNR HGR, D = 6.230' 5615' H 1 7' LNR 26#, L-80 TCL .0383 bpf, D = 6276' H 9204' LNR 12.6#,13CR-85 VAM TOP, .0152 MLLOUT WINDOW (07-238( 5766' - 5783' 72' 41/2" HEi X NP, D = 3.813" X 5" F RDZXRJ LIP w/TIEBACK SLV, = 4.460' 412' WLE3i, D=3.958' rT X 5' BKR FLEXLOCK LNR HGR D = 4.450' 9589' 4- ani• sLM 9728' PHtFS D 11/06/10) PRdDHOE BAY LW WELL: 07-23B PB7MT No: 2091450 AR Ko: 50-029-21635-02-00 SEC.33,T71RM4E, 1985'RNL&219'FB. DATE REV BY COMMENTS DATE HEV BY OOMv13,fTS i 0187/87 0180NAL COMPLETION 04/16/18 KFMJM) SET EVOTPB7EPl.UG(04/15/18 1082194 RWO(SCAB LNR) 06/18/18 JFeJM) RLL®EVOPLUG(06116/18) 05127198 CTD SIDETRACK(07-23A) 07/10/18 BTWJM) SETCBP&AOFEFFS 01/1470 MFS CTDSIDETRACK(07-23B) 03/27/19 RMAD GLV C/O (03/25/19) 05/03117 MS/JM) ADPHiFS(O5/IX7/17) 0625/19 CJWJM) CEP MOVED DH(SEF NLWNCBP BP Exploration (Alaska) 08116117 GIWJM) GLV d0 (08115117) ' c ; .ten STATE OF ALASKA 5 I CJ" 'x ALASKA OIL AND GAS CONSERVATION COM N REPORT OF SUNDRY WELL OPERA SMAY 0 3 20' 1. Operations Performed Abandon 0 Plug Perforations I3 Fracture Stimulate 0 Pull Tubing 0 Operations sh d• Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing 0 Change App. :••• Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set Evo-Trieve Plug EI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number. 209-145 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21635-02-001. 7. Property Designation(Lease Number): ADL 028309 8. Well Name and Number: PBU 07-23B 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 9967 feet Plugs measured 9667 feet true vertical 9257 feet Junk measured None feet Effective Depth: measured 9667 feet Packer measured 8902 feet true vertical 8970 feet Packer true vertical 8248 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 30-109 30-109 1490 470 Surface 2460 13-3/8" 29-2489 29-2489 3450/5380 1950/2670 Intermediate 5738 9-5/8" 27-5765 27-5325 6870 4760 Liner 3604 7" 5599-9203 5194-8350 7240 5410 Liner 948 4-1/2" 9016-9964 8355-9255 9020 8540 Perforation Depth: Measured depth: 9655-9738 feet JUN )f1 True vertical depth: 8959-9038 feet scow JU Iy 3. 1 `0 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr85 25-9021 25-8359 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 8902 8248 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 DailyAverage Production or Injection Data P 9 1 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 377 30707 702 1050 321 Subsequent to operation: 305 25261 127 860 340 14.Attachments:(required per 20 AAC 25.070.25.071,a 2E283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WI NJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: Vohra,Prachi Contact Name: Vohra,Prachi Authorized Title: Production Engr p Contact Email: Prachi.Vohranbp.com Authorized Signature: Date: 5/1_/. -o $� Contact Phone: +1 9075644677 V / Form 10-404 Revised 04/2017 VVVV"`` 1- f�O`L8 ABDMS�++ MAY 0 3 2018 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 (10-404) May 1, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Plug Perforations (EVO- TRIEVE Plug) for Well PBU 07-23B, PTD #209-145. 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 • Daily Report of Well Operations PBU 07-23B ACTIVITYDATE SUMMARY 4/15/2018 SET HALLIBURTON EVO-TRIEVE AT 9670' ME.TOP OF PLUG AT 9667' ***WELL S/I ON ARRIVAL***(SLB E-LINE SET PLUG) INITIAL T/I/O=2400/1100/0 SET 4-1/2"HALLIBURTON EVO-TRIEVE AT 9670' ME.TOP OF PLUG AT 9667' ALL LOGS CORRELATED TO BAKER RPM DATED 31-MARCH-2017.. RDMO.WELL S/I ON DEPARTURE. FINAL T/I/O=2490/1140/0. 4/15/2018 ***JOB COMPLETE ON 15-APRIL-2018*** Fluids Summary Bbls Type 1 Diesel MEE= CNV ***4-1/2"CHROME TBG&UV... ANG& ACTLiA Dil= BA oC a)7�� SiSD K A"NOT SHOWN BELOW WHIPS OCK NOTE PERF DATA SHIFT®10'PER LOG NOTED BELOW KB.B_EV= 57' ON PERF TABLE*** BF.B..EV= KOP= 3050' Mix Angle 39°m 5796' ' 2073' H4_1/2-l- X NP,D=3.813" Datum MD= 954T Datum7VD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347' GAS LFT MANDRELSH 2490' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3747 3709 26 KBG2 DOME BK 16 02/18/10 3 6215 5716 20 KBG2 DOME BK 16 02/18/10 2 7775 7184 19 KBG2 DOME BK 16 02/18/10 Minimum ID =3.725" @ 900W 1 8795 8146 20 KBG2 SO BK 20 08/15/17 4-112" HESXNIPPLE 7 6600' H 9-518-X 7"ZXP LTP w/SETTING SLV,D=6.290" 5616' H9-5/8"X T BKR FLEXLOCK LNR HGR,D=6.230" i 9-5/8"VVI IPSTOCK(12/31/09) H 6766' OUT VW'DOW(07-23B) 5766'-5783' I 9-5/8"CSG,47#,L-80,D=8.681" --I 9850' I--. 8872' H4-1/2"FES X NP,D=3.813" 7"LNR,26#,L-80 HC XO TO L-80 TCI H 6242' 8903' Hr X 4-1/2"BKR s-3 FxR D=3.870" PERFORATION SUMMARY �\ REF LOG:FMVLYARC/AI N on 01/10/10 `� ANGLE AT TOP PERF:17°tt 9655' i ` 8937' H4-1/2"Hes X NP,D=3.813" Note:Refer to Production DB for historical perf data SIZE SPF MERVAL Opn/Sqz DATE 3-3/8" 6 9655-9660 0 05/03/17 9009' H4-1/2"1-13S XN NP,D=3.725" 3-3/8" 6 °9680-9690 C 03/28/10 3-3/8" 6 '9700-9718 C 02/02/10 901T I—7"X 5"HRD ZXRV LTP w/TIEBACK SLV, 3-3/8" 6 '9718-9738 C 01/28/10D=4.460" \ •DATA 0631H Sl FT®TO MATCH FINAL LOG y 8021' }--{41/2"VULEG,D=3.958' SCIUL E RGBR MWD/ARC AND LAST RUN ON 01110/109033' 17"X 5" FLEXLOCK LNRHGf� D=4.45050"' 4-1/2"TBG,12.6#,13CR-85 VAM TOP,.0152 bpf,D=3.958" 9021' 9043' H5*5'X 4-1/2"XQ,0=3.930" II 9667' j—4-1/2"R(OTREVE PLUG (04/15/18) T LNR 26#,L-80 TCI,.0383 bpf,D=6.276" H 9204' ` `► 9728' I--FLL-COVERS 10'OF LOWER PBRFS 1 I1 (TAGGED 11/06110) PBTD --1 9878' lt 44 1 A - 404, 4-12'LNR,12.6#,13CR-85 VAM TOP,.0152 bpf,13=3.958' H 9866' DATE REV BY COMMENTS DATE REV BY COMMENTS PFUJHOE BAY MT 01/07/87 ORIGINAL COMPLETION 05/03/17 MS/JMD ADPBRFS(05103/17) WELL: 07-238 10/02/94 RWO(SCAB LNR) 08/16/17 CJWJMD GLV CIO(08115/17) IMT No:"2091450 05127198 CTD SIDETRACK(07-23A) 04/16/18 KFMJM) SET EVOTRIEVE PLUG(04/15/18 AR No: 50-029-21635-02-0j0 01114/10 N7ES CTD SIDETRACK(07-23B) SEC.33,T11 N,R14E, 1985'RSL&219'fka 01/01/11 AW/PJC DATUM FLL CORRECTIONS 07/28/11 TAW PJC GLV CIO(07/05/11) BP Exploration(Alaska) • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 209-145 3. Address: P.O.Box 196612 Anchorage, Development I3 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21635-02-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-23B 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: RECEIVED Total Depth: measured 9967 feet Plugs measured feet true vertical 9257 feet Junk measured feet JUN 0 5 2017 Effective Depth: measured 9920 feet Packer measured 8902 feet f true vertical 9212 feet Packer true vertical 8247.59 feet AOcC C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"91.5#H-40 30-109 30-109 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 5738 9-5/8"47#L-80 27-5765 27-5325 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9655-9660 feet feet 9680-9690 feet 9700-9718 feet 9718-9738 feet True vertical depth: 8959-8963 feet feet 8983-8992 feet 9002-9019 feet 9019-9038 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr85 25-9021 25-8359 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCA1, Treatment descriptions including volumes used and final pressure: o7@s/4NNE® ? �i1 . 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 130 13172 / 439 1200 276 Subsequent to operation: Shut-In 1300 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory 0 Development I 1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: Vohra,Prachi Contact Name: Vohra,Prachi Authorized Title: Production Engr Contact Email: Prachi.Vohra@bp.com Authorized Signature: �!_—,,,= Date: (0/6/11 Contact Phone: +1 9075644677 Form 10-404 Revised 04/2017 4 in/17 VII- 6/7/I 7- R B D M S w JUN - 6 2017 Submit Original Only • • RECEIVED JUN 052017 AOGCC 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 June 5, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for adding perforations for Well 07-23B, PTD # 209-145. 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 • • a, Q o 0 0 0 0 0 0 0) • CO vNr — CA CO l� Lo lC) O N V LO CO CO U 1 0 0 0 0 0 0 0 N N Ca• M d' CO 00) 0) 0) In O LS) 0) O O CO N CO 10 LO lf) V CO 10 N CO N LC) CO 0) Cb H LO O 0) O I- 0) LO LC) CO N LO N M N 10 CO CD LO O O CO CO O CCOO N O� LU I- N 0) O N C[) 0) O) 0) V 4-1 LJ.1 a No (� o I� rn LC) cri N N Ln O N N. L0 0) ea �f) Ln a L0 O O 00 CO CO CO CO N N Ln co N co (13 V a) o o � c`i � ti N M M o) v v 0) CO CO COO CO CO O O O) C N- NI"- CO 0) N N LU CO CO J w 07 0 — 0 C Th U w w w U 0 U r Lt Z Z w LU w E O Z Z D Cn Cn z J J H • • Packers and SSV's Attachment PBU 07-23B SW Name Type MD TVD Depscription 07-23B PACKER 5610.76 5203.21 7" Baker ZXP Top Packer 07-23B TBG PACKER 8902.34 8247.59 4-1/2" Baker S-3 Perm Packer 07-23B PACKER 9027.26 8365.35 5" Baker ZXP Top Packer • • 0 0 N I J 0 (.5 ZCO (7)• O I co 0_ 0) O 11 W I N.: ❑ H O 11. 0 W W W W W Q tl) ascn p � C w O > Z w (7)i E ▪ � J ❑ -J ❑ w U Q m -3 a U Q cn O m W D g M * `n d II O 11 N * X J (n J 1� ap Z w NC) JOtl • M < w O u) " W Q. A0_ w O Ga2 (0 O H (0 co O < >+ rOMrnH 2 LL II ❑ M cIS ❑ a ❑ Er) Li Z d X - w 17-Z Q 2 ill II 2 UO I m < O Ct O OU J p H O w o ZJ O II J LL ❑ W H Q � ❑ O co H N E m U ,-. — — 'HEE= CNV 0 . SAFE, TES: 4-1/2"CHROME TBG&LIC***ORIG& WELLFEAD = MCEVOY 07-2 3 B SIDETRACK"A"NOT SHOWN BELOW WHIPSTOCK*** ACTUATOR= BAKER C NOTE PG DATA SHIFTED 10'PER LOG NOTED BELOW KB ELEV= 5T ON PEFF TABLE*** BF.H_EV= i_li L x Angle= 39'@ 579 I I 2073" —4-1/2"HES X NIPID, =3.813" I Max DatumM)= 9547" Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,E)=12.347" — 2490' ST IAD ND DEVGATYS LET MAVLWRaV LATCH PORT DATE IL 4 3747 3709 26 KBG2 DOME BK 16 02/18/10 3 6215 5716 20 KBG2 DOW BK 16 02/18/10 2 7775 7184 19 KBG2 DOME BK 16 02118/10 Minimum ID =3.725" @ 9009' 1 8795 8146 20 KBG2 SO BK 20 07/05/11 4-1/2" HES X NIPPLE --[ 6600' —9-5/8"X 7"ZXP LIP w/SETTING SO/.ID=6.290" I LE I 6616' I--9-5/8"X 7"BKR FLEXLOCK LNR HGR ID=6.230" [ 9-5/8"WHFSTOCK(12/31/09) H 5766' MLLOUT WNDOW(07-23B) 5766 -5783' 9-5/8"CSG,47#,L-80,ID=8.681" —i 9850' I 8872' —4-1/2"FES X NIP,ID=3.813" 7"LNR,26#,L-80 HC XO TO L-80 TCI — 6242' 8903' —7"X 4-1/2"BKR S-3 PKR,ID=3_870" PERFORATION SUMMARY It., s,. REF LOG:N1WDARC/AON on 01/10/10 , ANGLE AT TOP PERE:17°@ 9655' ,/.. It 8937' —4-10"FES X MR ID=3.813" Note:Refer to Production DB for historical perf data SIZE SFF INITERVAL Opn/Sqz DATE , \ 9009' —4-1/2"FES XN NIP,ID=3.725" 3-3/8" 6 9655-9660 0 05/03/17 3-3/8" 6 "9680-9690 0 03/28/10 3-3/8" 6 *9700-9718 0 02/02/10 9017' —7"X 5"HRD ZXPIN LTP w/TEBACK SLV, 3-3/8" 6 "9718-9738 0 01/28/10 ID=4.460" \ [ 9021' —4-1/2"VVLEG,ID=3.958" *DATA DEPTH S}-FTE)TO MATCH FINAL LOG SCHLIMBERGER MVVEY ARC AND LAST RUN ON 01/10/10 '1 9033' —7"X 5"BKR FLEXLOCK LNR HGR, \ 0=4.450' 14-1/2"TBG, 12.6#,13CR-85 VAM TOP, .0152 bpf,0=3,958" 1-1_ 9021' , 9043' —5"X 4-1/2"XO,ID=3.930" i 11 7"LW?,26#,L-80 TCI, .0383 bpf,I)=6.276" H 9204' lk - 9728' —FLL-COVER'S 10'OF LOWER PERES f, (TAGGED 11/06/10) PBTD H 9878' 1 !if,444 ‘..411441k 4446o* ,tbak. • 4-1/2"LW, 12.6#,13CR-85 VAM TOP,.0152 bpf,ID=3.958" — 9965' DATE REV BY COIVIVENTS DATE REV BY COMMENTS PRUDHOE BAY LUT 01/07/87 ORIGINAL COMPLETION 05/03/17 MOM) ADPERFS(05/03/17) WELL: 07-23B —10/02/94 RVVO(SCAB LW) PERNIT No:"2091450 05/27/98 CTD SIDETRACK(07-23A) API No: 50-029-21635-02-00 01/14/10 ICES CTD SIDETRACK(07-23B) SEC.33,T11N,R14E, 1985°FN..&219°FEL 01/01/11 AW/PJC DATUIVV ELL CORRECTIONS 07/28/11 TAR/PJC GLV DO(07/05/11) -- BP Exploration(Alaska) 2.O°% — \ ,5 �, RECEI\D +• 2_-6i2,2_r.!V BAKER APR 10 2017 PRINT DISTRIBUTION LIST HUGHES 'Please sign and return one copy of this transmittal form to: COMPANY B o tirlaska Inc. BP Exploration(Alaska) Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED 44/VZ-/2017 900 E. Benson Blvd. WELL NAME 07 23B ivl.K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE March 31,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizarestbakerhughes.com TODAYS DATE April 7,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO$ LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF PFIN I S - #OF COPIES #OF COPIES #OF COPIES V 4 J V V 1 4 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 1 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 mp"confidential" 6 BP Exploration(Alaska)Inc. 0 0 0 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. SCANNED MAY 0 12017 Anchorage,Alaska 99508 ,Attn:David Itter TOTALS FOR THIS PAGE: 0 3 4 0 0 TOTALS FOR ALL PAGES: 0 3 4 0 0 !' ct Well History File Cover Pa e Image Probe y g XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 020q- 14 5' Well History File Identifier Organizing (done) ❑ Two - sided fflUIIIIIHI 1111 ❑ Rescan Needed IIIULIIOfl g g RES AN DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Di kettes, No. ❑ Maps: No. ' �' Other Items Scannable by Greyscale Items: Other, No/Type: G➢ ❑ a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: ep Date: / /s/ VY1P Project Proofing 1111111111111 ll III 9 BY: Maria Date: c_.. ill/ 3 /s/ P Scanning Preparation dr x 30 = (0 0 + = TOTAL PAGES V g (Count does not include cover sheet) i/ 1 BY: Maria Date: 3 /5/ Y Production Scanning 1111111111111 11111 Stage 1 Page Count from Scanned File: b7 (Count does include cover sheet) Pa.e Count Matches Number in Scanning Preparation: YES NO BY: Date: ,}-/ 14 / 3 /s/ Mr Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning complete lete at this point unless rescanning is required. 111111111 IIII II III p ReScanned 11111E111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked III HilIlIlIlIlIll 12/22/2011 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 8/9/2012 Permit to Drill 2091450 Well Name /No. PRUDHOE BAY UNIT 07 -23B Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 21635 -02 -00 MD 9967 TVD 9257 Completion Date 2/2/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Sure DATA INFORMATION Types Electric or Other Logs Run: dir / gr / res / pwd, dir / gr / res / neu / den (data taken from Logs Portion of Master Well Data Maint Well Log Information: • Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments ED Lis 19523 Induction /Resistivity 5525 9956 Open 4/6/2010 OH GR, ROP, FET, RPX, RPS, RPM, RPD, RAM, i DRHO, NPHI Plus PDS Graphics Log / Induction /Resistivity 25 Blu 5571 9926 Open 4/6/2010 MD Vision Service Log Induction /Resistivity 25 Blu 5081 9191 Open 4/6/2010 TVD Vision Service ED �£;` Asc Directional Survey 0 9967 Open Rpt ` ."'""1 Directional Survey 0 9967 Open Log ;/' Production 5 Btu 8700 9724 Case 12/30/2010 PPL, Pres, Temp, CCL, GR, Gradio, Spin, Deft ED `�C Pds 20600 Production 8700 9724 Case 12/30/2010 PPL, Pres, Temp, CCL, GR, Gradio, Spin, Deft Log r --- - Cement Evaluation 5 Col 8950 9714 Case 12/30/2010 CBL, GR, CCL, SCMT ED "C Pds 20601 Cement Evaluation 5 8950 9714 Case 12/30/2010 CBL, GR, CCL, SCMT Ill Log l Reservoir Saturation 5 Blu 8950 9714 Case 1/26/2011 RST. GR, CCL, Sigma ED X Lis 20677 Reservoir Saturation 8929 9716 Case 1/26/2011 GR, RST Plus PDS Graphics L - - Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 8/9/2012 Permit to Drill 2091450 Well Name /No. PRUDHOE BAY UNIT 07 -23B Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 21635 -02 -00 MD 9967 TVD 9257 Completion Date 2/2/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N ADDITIONAL INFORMATION Well Cored? Y e Daily History Received? Y F ormation Tops Y / Chips Received? "r"1' 1� p Analysis Received? Comments: • Compliance Reviewed By: Date: ) Z- • OPERABLE: Producer 07 -23B (PTD #1450) Tubing Integrity Restored (COOCTED SUB... Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Keff - 7// Sent: Monday, July 04, 2011 10:53 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Lee, Timothy Cc: AK, D &C Well Integrity Coordinator; Arend, Jon (NORTHERN SOLUTIONS LLC); King, Whitney Subject: OPERABLE: Producer 07 -23B (PTD #2091450) Tubing Integrity Restored (CORRECTED SUBJECT HEADER) All, I apologize for mislabeling the previous e- mail's subject header. The corrected header is as above. Thank you, Jerry Murphy BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Monday, July 04, 2011 10:48 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Lee, Timothy Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: FW: UNDER EVALUATION: Producer 07 -23B (PTD #2091450) Sustained IA Casing Pressure Above MOASP All, Producer 07 -23B (PTD #2091450) passed a MIT -T to 3000 psi and a CMIT -TxIA to 3000 psi on 07/04/2011 after changing out the orifice valve in the tubing. The passing test confirms the presence of two competent barriers in the well. The well is reclassified as Operable. The well may be returned to production after the tubing plug is removed from the well. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Sunday, June 12, 2011 9:39 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Lee, Timothy Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J (Swift) Subject: UNDER EVALUATION: Producer 07 -23B (PTD #2091450) Sustained IA Casing Pressure Above MOASP 7/12/2011 OPERABLE: Producer 07 -23B (PTD .1450) Tubing Integrity Restored (COOECTED SUB... Page 2 of 2 All, Producer 07 -23B (PTD #2091450) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to 2490/2290/vac psi on 06/09/11. A subsequent TIFL failed the following day on IA repressurization. The well has been reclassified as Under Evaluation and may be produced under a 28 -day clock. The plan forward is as follows: 1. DHD: TIFL FAILED 2. DHD: Re -TIFL with well online 2. Slickline: (Pending failed TIFL in step 2 ) Set DGLVs 3. Pumping: (Pending failed TIFL in step 2 ) MIT -IA to 3000 psi A TIO plot and wellbore schematic have been included for your reference. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/12/2011 UNDER EVALUATION: Producer 07.8 (PTD #2091450) Sustained IA Cas.Pressure Abo... Page 1 of 1 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelIIntegrityCoordinator @bp.com] Sent: Sunday, June 12, 2011 9:39 AM 1 k � erio `7 (g It To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Lee, Timothy Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J (Swift) Subject: UNDER EVALUATION: Producer 07 -23B (PTD #2091450) Sustained IA Casing Pressure Above MOASP Attachments: Producer 07 -23B (PTD #2091450) TIO Plot.doc; Producer 07 -23B (PTD #2091450) wellbore schematic.pdf All, J Producer 07 -23B (PTD #2091450) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to 2490/2290/vac psi on 06/09/11. A subsequent TIFL failed the following day on IA repressurization. The well has been reclassified as Under Evaluation and may be produced under a 28 -day clock. The plan forward is as follows: 1. DHD: TIFL FAILED 2. DHD: Re -TIFL with well online 2. Slickline: (Pending failed TIFL in step 2 ) Set DGLVs 3. Pumping: (Pending failed TIFL in step 2 ) MIT -IA to 3000 psi A TIO plot and wellbore schematic have been included for your reference. «Producer 07 -23B (PTD #2091450) TIO Plot.doc» «Producer 07 -23B (PTD #2091450) wellbore schematic.pdf» Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 6/15/2011 PBU 07 -23B PTD #2091450 6/12/2011 TIO Pressures Plot Well: 07 -23 4,000 3,000 T Tbg —■ IA 2.L100 —�— OA OOA 000A On 1,000 03:12!11 03/19111 03/26111 04/02/11 04/09/11 04'10/11 04/23/11 04/30/11 05/07/11 05/14/11 05/21/11 05/28/11 06/04/11 06 /11 /11 TREE = I. CIW 1 = MCEVOY SAFETY NOT * *4 -112" CHROMETBG & LNR * ** ORIG & ACTUATOR = BAKER C -2 B SIDETRACK ATA SHOWN BELOW PER L LOG NPOSTT ELOW SHIFTED KB. ELEV = 57, BF.ELEV= __ ON PERF TABLE * ** KOP 3050' I ' Max Angle = 39° @ 5796' I I I 2073' H4-1/2" HES X NIP, ID = 3.813" I Datum MD = 9547' Datum TV D = 8800' SS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2490' I--A GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE IIIR 4 3747 3709 26 KBG2 DOME BK 16 02/18/10 3 6215 5716 20 KBG2 DOME BK 16 02/18/10 2 7775 7184 19 KBG2 DOME BK 16 02/18/10 Minimum ID = 3.725" @ 9009' 1 8795 8146 20 KBG2 SO BK 20 02/18/10 4 -1/2" HES X NIPPLE jil I 5600' H9-5/8" X 7" ZXP LTP w /SE! I ING SLV, ID = 6.290" I 1 5615' H9-5/8" X 7" BKR FLEXLOCK LNR HGR, ID = 6.230" I I9 -5/8" WHIPSTOCK (12 /31/09) H 5766' I MILLOUT WINDOW (07 -23B) 5766' - 5783' 9 -5/8" CSG, 474, L -80, ID = 8.681" H 9850' I-- 8872' H4 -112" HES X NIP, ID = 3.813" I 7" LNR, 26#, L -80 HC XO TO L -80 TCII H 6242' 8903' H7" X 4 -112" BKR S -3 PKR, ID = 3.870" PERFORATION SUMMARY REF LOG: MWD /ARC /ADN on 01/10/10 ,' ANGLE AT TOP PERF: 17° @ 9690' � j 1 8937' 4-1/2" HES X NIP, ID = 3.813" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 *9680 - 9690 0 03/28/10 9009' H4 -1/2" HES XN NIP, ID = 3.725" I 3 -3/8" 6 9700 - 9718 0 02/02/10 3 -3 /8" 6 '9718 - 9738 0 01/28/10 9017' I- 7" X 5" HRD ZXPN LTPw/TIEBACK SLV, ID = 4.460" - DATA DEPTH SHIFTED TO MATCH FINAL LOG \ L 9021' H4 -1/2" WLEG. ID = 3.958" SCHLUMBERGER: MVVD /ARC AND LAST RUN ON 01,'10!10 9033' - 7" X 5" BKR FLEXLOCK LNR HGR, 1 ID = 4.450" I4 -1/2" TBG, 12.64, 13CR -85 VAM TOP, .0152 bpf, ID = 3.958" I-I 9021' 9043' H5" X 4 -112" X0, ID = 3.930" I 17" LNR, 26 #, L -80 TCII, .0383 bpf, ID = 6.276" H 9204' % N A 9728' I-- FILL - COVER'S 10' OF limit LOWER PERFS il (TAGGED 11/06/10) PBTD H 9878' I �,i,l� No I4 -1/2" LNR, 12.6 #, 13CR -85 VAM TOP, .0152 bpf, ID = 3.958" H 9965' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/07/87 ORIGINAL COMPLETION 05/30/10 CSR/PJC PERF CORRECTIONS WELL: 07 -23B 10/02/94 RWO (SCAB LNR) 12/05/10 PJC PERF CORRECTIONS PERMIT No: '2091450 05/27/98 CTD SIDETRACK (07 -23A) 01/01/11 AW /PJC DATUM/ FILL CORRECTIONS API No: 50- 029 - 21635 -02 -00 01/14/10 N7ES CTD SIDETRACK (07 -23B) SEC. 33, T11 N, R14E, 1985' FNL & 219' FEL 03/29/10 RRD /PJC PERFORATIONS 05/26/10 JM/JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) OPERABLE: Producer 07 -23B (PTD ,�; 091450) TIFL Passed verifying tubingegrity Page 1 o2' Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.comj " 1 1( Sent: Wednesday, March 02, 2011 7:45 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr Cc: King, Whitney; AK, D &C Well Integrity Coordinator; Lee, Timothy Subject: OPERABLE: Producer 07 -23B (PTD #2091450) TIFL Passed verifying tubing integrity All, Producer 07 -23B (PTD #2091450) passed a TIFL on 03/02/11 verifying tubing integrity. The well has been reclassified as Operable, but will remain shut -in due to low production rates. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, February 12, 2011 11:41 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC EOC ; Lee, Timothy Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C) Subject: Producer 07 -23B (PTD #2091450) Sustained Casing Pressure Abo - MOASP All, Producer 07 -23B (PTD #2091450) has sustained casing pres re above MOASP. The wellhead pressures were tubing /IA/OA equal to 224/2050/20 on 02 /. ;/2011. The well has been reclassified as Under Evaluation. The well may remain online while wo is conducted to attempt to restore integrity. Plan forward: 1. D: TIFL 2. WIE: Evaluate for gas lift valve ch. ge out pending TIFL results. A TIO plot and wellbore schematic are included for reference. « File: Producer 07.2313 (PTD #2091450) TIO Plot.doc » 3/3/2011 P roducer 07 -23B (PTD #2091450) ` INOned Casing Pressure Above MOASP Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, February 12, 2011 11:41 AM 0/ 14' To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS.Ops Lead; AK, OPS FS3 DS Operators; Cismoski, Doug A; Engel, Harry R; AK, D &C Wire line Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC EOC TL; Lee, Timothy Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C) Subject: Producer 07 -23B (PTD #2091450) Sustained Casing Pressure Above MOASP Attachments: Producer 07 -23B (PTD #2091450) TIO Plot.doc; Producer 07 -23B (PTD #2091450) welibore schematic.pdf All, Producer 07 -23B (PTD #2091450) has sustained casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 224/2050/20 on 02/08/2011. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. D: TIFL ' 2. WIE: Evaluate for gas lift valve change out pending TIFL results. A TIO plot and wellbore schematic are included for reference. «Producer 07 -23B (PTD #2091450) TIO Plot.doc» «Producer 07 -23B (PTD #2091450) welibore schematic. pdf» Please call if you have questions. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 II 2/14/2011 PBU 07 -23B PTD #2091450 2/12/2011 TIO Pressures Plot Well: 07 -23 4,000 3,000 T bg IA 2,000 — . OA 00A - ♦- 000A I On 1 x 000 ' ! 12/18/10 12/25/10 01/01/11 01/08/11 01/15/11 01/22/11 01/29111 02/05/11 02/12/11 TREE.= CIW WEE IFIE/0). = MCEVOY 11, SAFETY S: ***4-1/2" CHROME TBG & LNR*** ORIG & ---, . A oTUA TOR = BAKER C 0 7 ®2 3 B SIDET RA "A" NOT SHOWN BELOW WHIPSTOCK **" KB. ELEV = 57• NOTE: PERF DATA SHIFTED 10' PER LOG NOTED BELOW BF. ELEV = I ON PERF TABLE KOP = 3050' Max Angle; 89°@ 57967 I I 1 I 2073' H4-1/2" HES X NIP, ID = 3.813" 1 .... Datum MD = 9547' Datum TVD = - - 6860' SS 113-3/8" CSG, 72#, L-80, D= 12.347" H 2490' 1-41 GAS LIFT IVIANDRELS ST MD 1VD DEV TYPE VLV LATCH PORT DATE Eal 4 3747 3709 26 KBG2 DOME BK 16 02/18/10 3 6215 5716 20 KBG2 DOME BK 16 02/18/10 2 7775 7184 19 KBG2 DOME BK 16 02/18/10 Minimum ID = 3.725" @ 9009' 1 8795 8146 20 KBG2 SO BK 20 02/18/10 4-1/2" HES X NIPPLE 5600' H9-518" X 7" ZXP LTP w /St I I ING SLV, ID =6.290" 1 1 5615' H9-5/8" X 7" BKR FLEXLOCK LNR HGR, D = 6.230" 1 19-5/8" WHIPSTOCK (12/31109) H 5766' I MILLOUT WINDOW (07-23B) 5766' - 5783' 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9850' I 8872' H4-1/2" HES X NIP, ID = 3.813" 1 17" LNR, 26#, L-80 HC XO TO L-80 TCII H 6242' 8903' H7" X 4-1/2" BKR S-3 PKR, ID = 3.870" I PERFORATION SUMMARY _ REF LOG: MWD/ARC/ADN on 01/10/10 4 ANGLE AT TOP PERF: 17° @ 9690' 8937' H4-1/2" HES X NIP, ID = 3.813" I 4. l k Note: Refer to Production DB for historical perf data . SIZE SPF INTERVAL Opn/Sqz DATE \ 9009' H4-1/2" HES XN NIP, ID = 3.725" 1 3-318" 6 "9680 - 9690 0 03/28/10 3-3/8" 6 "9700- 9718 0 02/02/10 3-3/8" 6 '9718 - 9738 0 01/28/10 9017' I— 7" X 5" HRD ZXPN LTP w /TIEBACK SLV, ID = 4.460" , \ L 9021' H4-1/2" WLEG. ID = 3.958" 1 DATA TA SHIFTED TO MATCH FINAL LOG S. SCHLUMBERGER: MD/ ARC AND LAS r RUN ON 01110/10 •!k '-' 9033' 7" X 5" BKR FLEXLOCK LNR HGR, iv D = 4.450" 4-1/2" TBG, 12.6#, 13CR-85 VAM TOP, .0152 bpf, ID = 3.958" H 9021' 9043' H5" X 4-1/2" XO, ID = 3.930" 1 17" LNR, 26#, L-80 TCII, .0383 bpf, ID = 6.276" H 9204' 111 9728' I— FILL - COVER'S 10' OF LOWER PERFS 4 .----;,0 (TAGGED 11/06/10) PBTD 9878' 4111110, — ‘6444:6 A 4-1/2" LNR, 12.6#, 13CR-85 VAM TOP, .0152 bpf, ID = 3.958" 1 9965' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/07/87 ORIGINAL COMPLETION 05/30/10 CSR/PJC PERF CORRECTIONS WELL: 07-23B 10/02/94 RWO (SCAB LNR) 12/05/10 PJC PERF CORRECTIONS PERMIT No: F 2091450 05/27/98 CTD SIDETRACK (07-23A) 01/01/11 AW/PJC DATUM/ FILL CORRECTIONS API No: 50-029-21635-02-00 01/14/10 N7ES CTD SIDETRACK (07-23B) SEC. 33, T11N, R14E. 1985' FNL & 219' FEL 03/29/10 RRD/PJC PERFORATIONS 05/26/10 JM/JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) 12/30/10 Itch (Merger NO. 5672 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambol! Street, Suite 400 Alaska Oil S Gas Cons Comm Anchorage, AK 95503- 28381 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 / i^ 6 Anchorage, AK 99501 Y Job # Log Description Date BL Color CD E-05 6L65 -00011 MEM DDL 12118/10 1 1 - 36 AY1M -00056 PROD PROFILE a... —/ — 11/27/10 1 ♦ .. . it 1 11 -12 BCZ2 -00033 1J:1.1.IJc1e]2I! mDLi 1rTA 1 01 -25 BG4H -00022 INJECTION PROFILE ' !rmAirtqa K�> LL. 1 04 -24 AY1M -00058 L•L- e . e ■ , . 1 P2 -16 B5JN -00077 E3 LiL r Vim. 1 A-41 BCZ2 -00030 I!. 0GJe •ili? 1 04 -08 BCRJ- 000566 3 1Yi{'frt.AllICIAaa il 1 01 -24A BBSK -00043 110114e +1a,t - 1.1014 . Frail !3aK _. U 6Ti Mil* 1 04-10 AV1H -00051 INJECTION PROFILE O — • 12/07110 1 V 1 15 -26B BD88 -00080 MEM PROD PROFIL � o/1S L' 12/12/10 1 , 1 2- 286/0 -19 BCRJ -00055 PROD PROFILE ' 11/30/10 1 1 07-23B AY1M -00056 SCMT _ � yy/ ��� jjj '"' 11/28/10 41 a A 1 1 02 -21A BBSK -00042 SCMT 6166 — 009 11/23/10 _ . 1 1 - 02 -22B BL65 -00006 SCMT / [l - 12111/10 4 ' 1 1 18 -126 BBUO -00029 SCMT ( 08/30/10 4 • 1 P2 -16 B5JN -00077 USIT I. 1 `a 11/28/10 1 05 -27B BAUJ-00049 MCNL ' d — J 09/18/10 1 I ,�. 1 16-066 BBSK -00037 RST _ It - - • 11/15/10 1 ! - ♦ . 1 B-00050 RST - R � 09 /20/10 1 � _ 1 E -34L1 -34L1 BD88-00050 MCNL -- J T 09/28/10 1 1 _ W -219 BGZ7 -00012 CH EDIT • DC- USIT ' -- ♦ " 11/22/10 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambetl Street, Suite 400 900 E. Benson Blvd Anchorage, AK 99503 -2838 0 r. a`) 01/20/11 Schhankerger NO. 5676 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambit!! Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 14-43 BGZ7-00010 CROSSFLOW CHECK j t i i•-•1 .— /4..) 11/13/10 1 . ., ag 6A5 1 NGI-14 AV1H-00052 USIT t. )7.5 / ./f- 9 12/23/10 9 1 1 L-205 BLP0-00073 MEM LDL 0 , — )53 12121110 1 ,13 1 A-42A BL65-00012 MEM PRODUCTION PROFILE ' Q(,, 0 -13 01/06/11 1 1 01-30 BM-00031 INJECTION PROFILE ) Z. i 56 - 1 II 12/03/10 1 CZ) 1 Ilit 02-20 K-11A BBSK-00040 RST / -t) 9 AY1M-00056 RST .- i B088-00073 MCNL R cl — i 11/19/1 1 1 11/03/10 9 07-23B 11/28/10 1 IL ' 1 1 11 . .l it , 1 04-24 AY1M-00058 RST ) , ?el , 12/05/10 11-12 BCZ2-00033 RST % — C . 12/07/10 1 1 2-2813/0-19 BCRJ-00055 RST ' 0 -nn 12/01/10 1 66113 1 S-128 BCZ2-00035 USIT — / ci 01/02/11 . (24,,11C 1 1 W-220 BG4H-00025 USIT in ••••) 12/27/10 L 4,6#- 1 1 S-41A 10AKA0108 OH MVVD VVD EDIT 5 --/t) i 10/15/10 2 0/16i/ l 1 S-41AL1 10AKA0108 OH MWD/LWD EDIT ' i f .) —, 10/15/10 2 Of...ierie 1 H-11 BGZ7-00014 RST ) — hje if 12/18/10 1 2 .9.0 4, /4- 1 6% .966 fil PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd Anchorage, AK 99503-2838 .411 ..., .._., 19 . „ 03/25/10 • Schlumherger .A NO. 5481 Alaska Data & Consulting Services Company: State of Alaska APR 0 9 `) 0 1 0 2525 Gambol) Street, Suite 400 Alaska Oil & Gas Cons Comm 9 ! 1 Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 4, 90$ cons, Comminion Anchorage, AK 99501 g® 04 Well Job # Log Description Date BI Color CD Anchrtmga 03 -37 09AKA0188 OH MWD/LWD EDIT .)(S 171 9 / 9 Saa 02/14/10 2 1 07 -23B 09AKA0078 OH MWD/LWD EDIT / 5 Sal 01/10/10 2 1 V -123 BBKA -00002 CH EDIT PDC (SCMT)�j - / / L S / 01/15/10 1 04-42 B14B -00099 INJECTION PROFILE W. X (ta b le 03/23/10 1 1 06 -12A AP30 -00081 PRODUCTION PROFILE q 6 A 14, () 03/21/10 1 1 X -04 BBSK -00012 LDL 1 '4-q .-- OW G BHP / 03(14/10 1 1 it 03 -28 B9RH -00017 PRODUCTION LOG S 03/19/10 1 1 ) 14 -11A B3S0 -00050 PERF RECORD & FL 1 HP --- �'a (O / '.5'{13/20/10 1 1 15-31B B -0008 b,PR f � IL 1 (� W 03/21/10 1 03 -3 - B9RH 10 89RH -0001 INJ 8 INJEC ION PROFILE um ) 1 1 14 -07 B14B -00098 P ERF RECORD & FLOWING BHP 03/22/10 1 1 03-11 "03/6/10 1 1 12 -26 26 ANHY ANHY -00121 121 PROPRODUCTICTI ON N P PROOFILE 03/11 1 6/10 1 I 1 - P2 -22 BBSK -00011 USIT CORROSION DATA 03/11/10 1 1 P2 -22 BBSK -00011 USIT CEMEN DATA J 03/11/10 1 1 03 -28 89RH -00017 CBL *L( -61- q 9 .t 03/19/10 1 1 15 -30A B5JN -00045 SCMT ' A - O `l1 505 03/22/10 1 1 MPS -08 BBUO -00009 USIT Q( _ ,a 3 ' v / 1-_ 7 03/12/10 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: • BP Exploration (Alaska) Inc. Alaska Data & Consulting Services S Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 1 . a STATE OF ALASKA RECEIVED ALASKAAIL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS APR 0 2 2010 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Time ExtensktmelA'' Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ AnChOrage 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development 0 Exploratory ❑ 209 -1450 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ API Number: Anchorage, AK 99519 -6612 50- 029 - 21635 -02 -00 8. Property Designation (Lease Number) : \ 9. Well Name and Number'\ ADLO- 028309 PBU 07 -23B 10. Field /Pool(s): PRUDHOE BAY FIEI:P7 PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9967 feet Plugs (measured) None feet true vertical 9257.19 feet Junk (measured) None feet Effective Depth measured 9920 feet Packer (measured) 8906' true vertical 9212.18 feet (true vertical) 8251' Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 SURFACE - 80 SURFACE - 80 1490 470 Surface 2490 13 -3/8" 72# L -80 SURFACE - 2490 SURFACE - 2490 5380 2670 Intermediate 5766 9 -5/8" 47# L -80 SURFACE - 5766 SURFACE - 5325 6870 4760 Production Liner 3604 7" 26# L -80 5600 - 9204 5195 - 8531 7240 5410 Liner 948 4 -1/2" 12.6# 13CR80 9017 - 9965 8356 - 9255 8430 7500 Perforation depth: Measured depth: 0 9700 - 9718 0 9718 - 9738 0 9680 - 9690 / _ _ True Vertical depth: 9001.65 - 9018.85 9018.85 - 9037.97 8983 - 8992 - _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2 "X12.6# L -80 SURFACE - 9021 SURFACE - 8360 Packers and SSSV (type, measured and true vertical depth) 7 "X4 -1/2" BKR S -3 8906' 8251' 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 -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 159 481 306 234 Subsequent to operation: 156 492 305 258 14. Attachments: 5. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El Service ❑ Daily Report of Well Operations X 6. Well Status after work: Oil El Gas ❑ WDSPL ❑ G TOR ❑ WAG ❑ GINJ ❑ WINJ ❑ 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 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature % �1% Phone 564 -4944 Date 4/2/2010 • • • _ 11 0 • 3ubniil Oiiyinal Only RBDMS APR 0 5 201 . y.s/o I 07 -23B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/26/2010' ** *WELL SHUT IN ON ARRIVAL * ** (pre adperf) MIRU SLB SLICKLINE #4516 TO DRIFT/TAG FOR ADPERFS. ** *CONT. ON 03/27/10 WSR * ** 3/27/2010 * * *CONT. FROM 03/26/10 WSR * ** (pre adperf) TAG HARD BTM AT 9711' SLM W/ 3 -3/8" DUMMY GUN, S.BLR (Sample: Form sand). NOTE: TAG DEPTH IS SLM DEPTH. PERF INTERVAL = 9710 -9748' ELM. ** *WELL LEFT SHUT IN, DSO WALK THROUGH UPON DEPARTURE * ** 3/28/2010 ** *WELL SHUT IN UPON ARRIVAL * ** (ELINE: PERFORATION) INITIAL T /1 /O: 1700/1700/0 PSI. PERFORATED INTERVAL: 9680' - 9690'. CCL TO TOP SHOT: 3.8' CCL STOP DEPTH: 9686.2' 10' 3 -3/8" HSD 3406 POWERJET, HMX CHARGES PENETRATION DEPTH: 36.5" HOLE SIZE: 0.37" TD TAGGED AT 9733'. NO PROBLEMS RIH OR POOH. FINAL T /I /O: 1750/1700/0 PSI. ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 1 METH 1 DIESEL 2 TOTAL TREE = 4-1116" 5000 • WELLHEAD = CAMERON SAFETY NOTES: Chrome Lnr & tbg. 1 ACTUATOR = DRLD DRAFT 07_23B KB. ELEV = 57' / BF. ELEV = 27.86 ' KOP = 5766' I Max Angle = 39 © 5100' I 2,073' H4 - 112" X NIP, ID = 3.813" 1 Datum MD = 8851' Datum TV D = 8800' SS 5598' I — 9- 518 "x7" BKR Flex -Lock LNR HNGR & ZXP 110.94' PBR, ID = 7.37" H 5598' I LTP, ID = 6.151" GAS LIFT MANDRELS 13 -3/8" CSG, 72 #, L -80, ID= 12.347" H 2490' I i i 0 i iiiiii i ST MD TV DEV TYPE VLV LATCH PORT DATE 4 3747 3709 26 KGB2 DOME BK 16 02/18/10 3 6215 5716 20 KGB2 DOME BK 16 02/18/10 2 7775 7184 19 KGB2 DOME BK 16 02/18/10 1 8795 8146 20 KGB2 SO BK 20 02/18/10 9 -5/8" WHIPSTOCK 5766' V/ > --I 6282' ,-! XO VAMTOP HC Box x TCII Pin 1 Minimum ID = 3.725" @ 9010' ,---I 8873' H14 -1/2" X NIP, ID = 3.813" 1 4 -1/2" HES 'XN' NIPPLE F2 g - 8906' Hi 7 "x4 -1/2" BKR S -3 PKR, ID = 3.850" 1 I I 8937' H4 -1/2" OTIS X NIP, ID = 3.813" I e: .4 ' I 9010' H4-1/2" XN NIP, ID= 3.725 ", I 01 4 4 4 4 4 4 4 4 4 4'1 4444 4444 ►4444444444444441 9016' HT X5" TIE BACK (11.6 "), ID = 5.250" 1 (9 5i$" CSG, 47 #, L -80, ID = 8.681" H 9850' ∎ ∎••∎ ∎••4•4�4•4A4A ( 9021' H4 -1/2" WLEG, ID = 3.958" 1 4 -1/2" TBG, 12.6 #, 13CR - 80 VAM TOP, H 9021' 9033' I — 7" x 5" BKR ZXP LTP & FLEX -LOCK 0152 bpf, ID = 3.958" LNR HGR, ID = 3.85" 17" LNR, 26 #, L -80, ID = 6.276" H 9204' 1 ■ PERFORATION SUMMARY REF LOG: MWD MAD PASS GR/RES ON 01/12/10 ANGLE AT TOP PERF: 17° @ 9690' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 9690 - 9700 0 03/28/10 3 -3/8" 6 9710 - 9728 0 02/02/10 3 -3/8" 6 9728 - 9748 0 01/28/10 I PBTD H 9878' 1VAN I 1 4 4 4 4 4 4 4 � 1 4 ♦a84 14 -1/2" LNR, 12.6 #, 13CR - 80, VamTop, ID= 3.958" H 9965' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/07/87 ORIGINAL COMPLETION 02/03/10 JMF /PJC PERFS (01/28- 02/02/10) WELL: 07 -23B 10/02/94 RWO (SCAB LNR) 02/27/10 BSE/PJC GLV C/O (02/18/10) PERMIT No: 198 -089 05/27/98 CTD SDTRCK 03/27/10 CJN/PJC PERF DEPTH CORRECTION AR No: 50- 029 - 21635 -02 01/14/10 N7ES SIDETRACK (07 - 23B) 03/29/10 RRD /PJC PERFORATIONS SEC33 T11 N R14E 33 2951.54 FEL 4462,7 FNL 01/30/10 TLH DRLG HO CORRECTIONS 01/30/10 RPC/TLH GLV C/O (01/26/10) BP Exploration (Alaska) milk 0 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 1 7 2010 WELL COMPLETION OR RECOMPLETION REPORT AdirklaCt cans. cony issio 1 1a. Well Status: ® Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1b. Well Class: Mg �� L:T 20AAC 25.105 2OAAC 25.110 ® Developmenn Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 02/02/2010 209 - 145 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 01/02/2010 50 029 - 21635 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 01/09/2010 PBU 07 -23B 1986' FNL, 219' FEL, SEC. 33, T11 N, R14E, UM 8. KB (ft above MSL): 55.86' 15. Field / Pool(s): Top of Productive Horizon: 724' FSL, 1227' FEL, SEC. 33, T11 N, R14E, UM GL (ft above MSL): 26.82' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 631' FSL, 1224' FEL, SEC. 33, T11N, R14E, UM 9920' 9212' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 676003 y 5948934 Zone ASP4 9967' 9257' ADL 028309 TP1: x - 675060 y 5946342 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x - 675066 Y 5946250 Zone ASP4 None 18. Directional Survey: ■4 Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIR / GR / RES / PWD, DIR / GR / RES / NEU / DEN 5766' 5325' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM ToP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 80' Surface 80' 30" 1900 # Poleset 13 -3/8" 72# L -80 Surface 2490' Surface 2490' 17 -1/2" 200 sx Coldset 111. 550 sx Coldset II 9 -5/8" 47# L -80 Surface 5766' Surface 5325' 12 -1/4" 700 sx Class 'G'. 300 sx CS 1 7" 26# L -80 5600' 9204' 5195' 8531' 8 -1/2" 293 sx LiteCrete. 174 sx Class 'G' 4-1/2" 12.6# 13Cr85 9017' 9965' 8356' 9255' 6 -1/8" 249 sx Class 'G' 24. Open to production or injection? IN Yes ❑ No 25. TUBING RECORD If Yes, list each interval open .SIZE DEPTH SET (MD) PACKER SET (MD / ND) (MD +TVD of Top & Bottom; Perforation Size and Number): 3 -3/8" Gun Diameter 6 spf 4 -1/2 ", 12.6#, 13Cr85 9021' 8903' / 8248' MD TVD MD TVD 9710' - 9728' 9011' - 9028' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9728' - 9748' 9028' - 9048' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Freeze Protected w/ 164 Bbls of Diesel 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): February 7, 2010 Flowing _ Date of Test: Hours Tested: Production For OIL - BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: 2/13/2010 8 Test Period 4 47 360 92 82 7,623 Flow Tubing Casing Press: Calculated OIL - BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 259 1,500 24 -Hour Rate ♦ 142 1,080 276 _ Not Available 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 0 AAC 250.071. CChTE7' OT\ None • 'ATE .. C 16 , �ip4 I . Form 10-407 Revised 12/2009 • Z.l6 CONTINUED ON REVERT 18 Submit Original my 171..., 29. GEOLOGIC MARKERS (List all formations and Ars encountered): 30. O RMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. West Sak 2 6248' 5747' West Sak 1 6494' 5978' None Colville Mudstone 3 6694' 6166' Coldville Mudstone 2 7260' 6699' Colville Mudstone 1 7820' 7227' Top HRZ 8300' 7681' Base HRZ 8495' 7865' LCU / Top Kingak 8508' 7878' Sag River 9208' 8535' Shublik 9243' 8578' Sadlerochit 9319' 8640' 42SB / Zone 4A 9436' 8750' Top CGL / Zone 3 9521' 8831' Base CGL / Zone 2C 9600' 8906' 23SB / Zone 2B 9648' 8952' 22TS 9711' 9012' 21 TS / Zone 2A 9752' 9051' Zone 1B 9838' 9134' TDF / Zone 1A 9885' 9179' Base Sadlerochit 9922' 9214' Formation at Total Depth (Name): Kingak 9922' 9214' 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 32. I hereby certify that the foreg�s true and correct to the best of my knowledge. ()qt /-� Signed: Terrie Hubble Title: Drilling Technologist Date: { f PBU 07 - 23B 209 - 145 Prepared By Name/Number. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Frank Roach, 564 -4373 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -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 and Ground Level elevation in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only BP EXPLORATION Page 1 of 1 Leak -Off Test Summary Legal Name: 07 -23 Common Name: 07 -23 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 1/2/2010 FIT (ft) (ft) (ppg) (psi) (psi) 11.90 (ppg) 1/3/2010 FIT 5,809.0 (ft) 5,358.0 (ft) 9.80 (ppg) 583 (psi) 3,311 (psi) 11.89 (ppg) 1/7/2010 FIT 9,235.0 (ft) 5,358.0 (ft) 8.50 (ppg) 600 (psi) 2,966 (psi) 10.66 (ppg) 1/6/2010 FIT 9,204.0 (ft) 8,532.0 (ft) 9.85 (ppg) 600 (psi) 4,966 (psi) 11.20 (ppg) 4 1, Printed: 1/25/2010 12:07:51 PM • BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: 07 -23 Common Well Name: 07 -23 Spud Date: 1/1/2010 Event Name: REENTER +COMPLETE Start: 12/26/2009 End: 1/13/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2010 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 12/26/2009 12:00 - 00:00 12.00 MOB N WAIT PRE 7ES RELEASED FROM W -56 AT 12:00. DISCONNECT PITS. MOVE PITS, SHOP, ILLAMNA CAMP TO 7 -23. WOW. 32 MPH W /GUSTS TO 41 MPH. 12/27/2009 00:00 - 13:00 13.00 MOB N WAIT PRE WOW TO LOWER DERRICK AND MOVE SUB FROM W -56 TO 7 -23. WIND 32 MPH W /GUSTS TO 41. 13:00 - 15:00 2.00 MOB P PRE LAY DERRICK OVER AND MOVE SUB OFF W -56. SECURE WELL. 15:00 - 00:00 9.00 MOB P PRE MOVE RIG 7ES SUB FROM W -56 TO 7 -23. 12/28/2009 00:00 - 06:00 6.00 MOB P PRE MOVE RIG 7ES SUB FROM W -56 TO 7 -23. 06:00 - 17:00 11.00 RIGU P PRE RU ON DS 7 -23. PLACE MATS, LD HERCULITE BERMS, BACK IN/TIE IN PITS. RAISE DERRICK. TAKE ON HEATED SEAWATER AND ACCEPT RIG AT 17:00. END OF WEATHER INDUCED EXCEPTIONAL RIG MOVE PERIOD. 17:00 - 20:30 3.50 RIGU P DECOMP RU CELLAR EQUIPMENT AND LINES. RU FLAT TANK AND HARD LINES TO TAKE DIESEL FROM FREEZE PROTECT. BREAK IBOP AND SAVER SUB ON TOP DRIVE, TUBO SCOPE INSPECT QUILL SHAFT. OK. CHANGE OUT DRILLERS SIDE TUGGER LINE. 20:30 - 21:30 1.00 WHSUR P DECOMP PJSM. HOLD PRESPUD W /ALL HANDS, TP, MUD ENGINEER, WSL. DISCUSS WELL PROGRAM. DISCUSS CURRENT DAYS PLAN FORWARD AND CARRYING HSE IMPROVEMENT FORWARD. 21:30 - 00:00 2.50 WHSUR P DECOMP TEST OA WITH DIESEL TO 2000 F /10 MINUTES. TEST IA WITH WATER TO 2000 AND HOLD FOR 10 MINUTES BOTH TEST GOOD. HOLD PRESPUD AT MIDNIGHT TOUR MEETING WITH ALL HANDS, WSL, TP, MUD MAN. 12/29/2009 00:00 - 02:00 2.00 RIGU P DECOMP RU AND TIE IN TO HARDLINE AND TEST HARDLINE TO TIGER TANK TO 2,000 PSI. VERIFY 0 PSI ON IA AND PULL BPV WITH DSM LUBRICATOR. 02:00 - 04:30 2.50 WHSUR P DECOMP REVERSE CIRCULATE 35 BBLS OF DIESEL OUT OF TUBING. SWITCH DIRECTION AND CIRCULATE 120 BBLS OF DIESEL FREEZE PROTECT OUT OF ANNULUS. CBU WITH SAFE SURF O. 04:30 - 05:30 1.00 DHB P DECOMP JNSTAI I TWC AM) TFST TO 13100 PSI FROM RFI OW_ TEST GOOD. 05:30 - 06:30 1.00 DHB N DFAL DECOMP RU AND ATTEMPTED TO TEST TWC TO 3500 PSI FROM ABOVE, BUT DID NOT GET A GOOD TEST. RE- TESTED ON IA AT 200 PSI FROM BELOW WHCIH ALSO FAILED. RIGGED DOWN TEST EQUIPMENT AND WAITED ON DSM TO ARRIVE WITH LUBRICATOR TO CHANGE TWC. 06:30 - 09:00 2.50 DHB N DFAL DECOMP PJSM W/ DSM ON RU LUBRICATOR. TESTED WITH DIESEL TO 500 PSI THEN PULLED TWC. A ROLLED SEAL WAS FOUND WHEN PULLING TWC. REBUILT TWC AND INSTALLED WITH LUBRICATOR. TESTED F/ BELOW AT 1,000 PSI FOR 10 MINUTES, AND FROM ABOVE AT 3,500 PSI FOR 10 MINUTES. GOOD TEST. RIGGED DOWN LUBRICATOR AND SUCKED OUT TREE. 09:00 - 10:30 1.50 WHSUR P DECOMP PJSM ON ND TREE. NIPPLED DOWN TREE AND ADAPTOR FLANGE, FUNCTIONED LDS & RETORQUED TO 450 FT LBS, AND INSPECTED HANGER THREADS, 13 3/4 RHT. Printed: 1/25/2010 12:07:58 PM • BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: 07 -23 Common Well Name: 07 -23 Spud Date: 1/1/2010 Event Name: REENTER +COMPLETE Start: 12/26/2009 End: 1/13/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2010 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 12/29/2009 10:30 - 14:00 3.50 BOPSUF P DECOMP PJSM AND NIPPLE UP BOP AND RIG UP TEST EQUIPMENT. 14:00 - 23:30 9.50 BOPSUF P DECOMP MIBOPE j0 3.500 PSI HIGH 250 PSI 1 nw FnR MINUTES WITH 4" AND 4.5" TEST JOINTS; CHART ALL TESTS. TEST ANNULAR TO 2,500 PSI HIGH, 250 PSI LOW WITH 4" TEST JOINT ONLY. ALL TESTS GOOD. BOPE TEST WITNESSED BY JEFF JONES WITH AOGCC AND BP WSL NEWLON AND NAD TP WURDEMAN. 23:30 - 00:00 0.50 BOPSUF P DECOMP RIG DOWN TEST EQUIPMENT. 12/30/2009 00:00 - 00:30 0.50 DHB P DECOMP RU DSM LUBRICATOR AND EXTENDER. - PRESSURE TEST TO 500 PSI; TEST GOOD. 00:30 - 01:00 0.50 DHB P DECOMP PULLED TWC AND RIGGED DOWN DSM LUBRICATOR. 01:00 - 01:30 0.50 PULL P DECOMP MU CROSS OVER TO JOINT OF DP. - MU TO TBG HANGER AND BACK OUT LOCKDOWN SCREWS. - UNSEATED TBG HANGER W/ 80K PU WT. 01:30 - 02:30 1.00 PULL P DECOMP CIRCULATE SURFACE TO SURFACE. - 502 BBLS, 500 GPM, 515 PSI. - RU SPOOLER AND DOUBLE -STACK POWER TONGS. - LD CROSSOVER AND HANGER. 02:30 - 04:30 2.00 PULL P DECOMP PJSM AND LD 4.5" NSCT, L -80, 12.6 # TBG FROM 5,862' TO 3,751'. - STOP AT SSSV. 04:30 - 05:00 0.50 PULL P DECOMP RD CONTROL LINE SPOOLER. 05:00 - 08:00 3.00 PULL P DECOMP I D 4 5" NSCT. L -80. 12.6 # TBG FROM 3,751' TO SURFACE. - RECOVERED 53 STAINLESS STEEL BANDS, 140 JTS, 1 GLM, 1 SSSV, 1 PUP JT. - CUT JT = 3.91'. 08:00 - 08:30 0.50 PULL P DECOMP RD 4.5" HANDLING TOOLS AND CLEAN AND CLEAR RIG FLOOR. 08:30 - 09:00 0.50 BOPSUF P DECOMP, RU TO TEST LOWER 2 -7/8" X 5" VBRS. 09:00 - 09:30 0.50 BOPSUF P DECOMP ATTEMPT TO TEST, BUT SEALS FAILED ON TEST PLUG. 09:30 - 11:30 2.00 BOPSUF N WAIT DECOMP WAIT ON ARRIVAL OF NEW TEST PLUG. 11:30 - 12:30 1.00 BOPSUF P DECOMP TEST LOWER 2 -7/8" X 5" VBRS WITH 4" TEST JOINT TO 250 PSI LOW, 3,500 PSI HIGH. - TEST GOOD. 12:30 - 18:30 6.00 CLEAN P DECOMP PU BHA # 1 AND RIH ON 4" DP SINGLES FROM THE PIPESHED TO 5,865'. - TAGGED UP ON 4 -1/2" TBG STUMP AT 5.865'. - 122K PU WT, 115K SO WT. - FILL EVERY 25 STANDS. 18:30 - 19:30 1.00 CLEAN P DECOMP CIRCULATE AND MONITOR WELL; WELL STATIC. - 410 BBLS, 500 GPM, 1,900 PSI. - PUMP DRY JOB. - MW = 8.5 PPG. 19:30 - 21:30 2.00 CLEAN P DECOMP POH FROM 5,865' TO 291'. 21:30 - 22:30 1.00 CLEAN P DECOMP LD BHA # 1 FROM 291'. 22:30 - 00:00 1.50 DHB P DECOMP PJSM WITH SLB AND HAL FOR E -LINE EZSV RUN AND RU E -LINE. 12/31/2009 00:00 - 01:30 1.50 DHB P DECOMP RIH WITH EZSV AND GR/CCL ON E -LINE TO 5,800'. 01:30 - 02:00 0.50 DHB P DECOMP LOG ON DEPTH AND SET EZSV AT 5,781' (WIRELINE). - SET 3' ABOVE CASING COLLAR. 02:00 - 02:30 0.50 DHB P DECOMP POH WITH GR/CCL ON E -LINE TO SURFACE. Printed: 1/25/2010 12:07:58 PM • BP EXPLORATION Page 3 of 12 Operations Summary Report Legal Well Name: 07 -23 Common Well Name: 07 -23 Spud Date: 1/1/2010 Event Name: REENTER +COMPLETE Start: 12/26/2009 End: 1/13/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2010 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 12/31/2009 02:30 - 03:00 0.50 DHB P DECOMP PRESSURE TEST 9 -5/8" CASING ABOVE EZSV TO 3,500 PSI FOR 30 CHARTED MINUTES. - FIRST 15 MINUTES 0 PSI LOSS; SECOND 15 MINUTES 0 PSI LOSS. - TEST GOOD. 03:00 - 03:30 0.50 DHB P DECOMP RD SLB E -LINE. 03:30 - 08:00 4.50 WHSUR P DECOMP ND BOP. - REMOVE CAMERON 11" TBG SPOOL AND REPLACE WITH MCELVOY 13 -5/8" TBG SPOOL. - PRESSURE TEST PACKOFF TO 3,750 PSI FOR 30 MINUTES (TEST GOOD). 08:00 - 10:30 2.50 BOPSUF P DECOMP NU BOP. 10:30 - 12:00 1.50 WHSUR N SFAL DECOMP PRESSURE TEST BREAK BETWEEN BOP, TBG SPOOL, AND KILL LINE. - 250 LOW PSI / 3,500 HIGH PSI. - LEAK BETWEEN TBG SPOOL AND BOP. 12:00 - 14:30 2.50 BOPSUF N SFAL DECOMP UNSUCCESSFUL TEST AFTER MAKING ADJUSTMENTS BETWEEN TBG SPOOL AND BOP. -ND BOP. - CLEANED FLANGE SURFACE AND RING GROOVE. - REPLACED API RING. 14:30 - 16:00 1.50 BOPSUF N SFAL DECOMP NU BOP. 16:00 - 16:30 0.50 WHSUR N SFAL DECOMP SET TEST PLUG AND RU TEST EQUIPMENT. 16:30 - 17:00 0.50 WHSUR N SFAL DECOMP PRESSURE TEST BREAK BETWEEN BOP, TBG SPOOL, AND KILL LINE. - 250 LOW PSI / 3,500 HIGH PSI. 17:00 - 17:30 0.50 WHSUR P DECOMP RD TEST EQUIPMENT AND SET WEAR RING. 17:30 - 20:00 2.50 STWHIP P WEXIT PJSM AND PU WHIPSTOCK BHA # 2 TO 383'. 20:00 - 23:00 3.00 STWHIP P WEXIT RIH TO 5,655'. - PU WT 125K, SO WT 117K. 23:00 - 00:00 1.00 STWHIP P WEXIT SET WHIPSTOCK AT 5,788'. - ORIENT 80 DEGREE LEFT. - TAG AT 5,788'. - SO 20K AND SHEAR ANCHOR. - OVERPULL 15K TO CONFIRM SET. - SO 55K AND SHEARED BOLT (GOOD INDICATION OF SHEAR). - TOW AT 5.766'. - BOW AT 5,783'. 1/1/2010 00:00 - 01:00 1.00 STWHIP P WEXIT DISPLACED 8.5 PPG SEAWATER WITH 9.8 PPG LSND. - 475 BBL, 500 GPM, 1,460 PSI. 01:00 - 07:00 6.00 P WEXIT MILL WINDOW IN 9 -5/8" CASING FROM 5 786' TO 5 783' AND CONTINUE IN OPEN HOLE TO 5,796'. - 400 GPM, 1,075 PSI. - 90 RPM, 15K WOM. - TO 5K. - PU WT 125K, SO WT 117K, RT WT 122K. - TOW, 5,766'; BOW, 5,783'. - MW 9.8 PPG. 07:00 - 07:30 0.50 P WEXIT CBU TO CONDITION WELL FOR PHASE THREE WEATHER CONDITION WORK STOPPAGE. - WORK WINDOW. - POH TO INSIDE 9 -5/8" CASING TO 5,763'. Printed: 1/25/2010 12:07:58 PM • . BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: 07 -23 Common Well Name: 07 -23 Spud Date: 1/1/2010 Event Name: REENTER +COMPLETE Start: 12/26/2009 End: 1/13/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2010 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 1/1/2010 07:00 - 07:30 0.50 P WEXIT - CBU, 334 BBLS, 240 GPM, 500 PSI. 07:30 - 00:00 16.50 N WAIT WEXIT PHASE THREE WEATHER CONDITIONS IN GREATER PRUDHOE BAY. - WAIT ON WEATHER. - CIRCULATE AT 19 GPM, 200 PSI. 1/2/2010 00:00 - 09:00 9.00 N WAIT WEXIT PHASE THREE WEATHER CONDITIONS IN GREATER PRUDHOE BAY. - WAIT ON WEATHER. - CIRCULATE AT 19 GPM, 200 PSI. 09:00 - 18:00 9.00 N WAIT WEXIT PHASE TWO WEATHER CONDITIONS IN GREATER PRUDHOE BAY ON MAJOR ROADS ONLY. - LEVEL THREE ON ACCESS ROADS AND PADS. - INCIDENT MANAGEMENT TEAM (IMT) DECIDED TO WAIT UNTIL 1800 HRS TO RESUME DRILLING OPERATIONS SO THAT ROADS COULD BE CLEARED. - CIRCULATE AT 19 GPM, 200 PSI. 18:00 - 18:30 0.50 N FLUD WEXIT CIRCULATE AND CONDITION MUD FOR RESUMPTION OF DRILLING OPERATIONS. - 330 BBLS, 400 GPM, 1,080 PSI. 18:30 - 00:00 5.50 P WEXIT DRILL AHEAD IN 8 -1/2" INTERMEDIATE HOLE SECTION FROM 5,796' TO 5,809'. - WOB 15 -20K. - TO 5K ON, 2.5K OFF. - 90 RPM. - 400 GPM, 1,085 PSI. - PU WT 135K, SO WT 110K, ROT WT 120K. - MW 9.8 PPG. 1/3/2010 00:00 - 01:00 1.00 P WEXIT CIRCULATE SURFACE TO SURFACE AND PUMP HI -VIS SWEEP TO CLEAN METAL CUTTINGS OUT OF HOLE. - 218 # OF METAL CUTTINGS RETRIEVED. - 411 BBLS, 400 GPM, 1,080 PSI. 01:00 - 02:00 1.00 P WEXIT POH FROM 5,809' TO 5,716 TO POSITION WHIPSTOCK/MILLING BHA INSIDE 9 -5/8" CASING WINDOW. PERFORM FIT TO 11.9 PPG EMW. MW = 9.8 PPG, TVD = 5,358', SURFACE PRESSURE = 583 PSI. CHARTED TEST FOR 10 MINUTES WITH INITIAL PRESSURE OF 583 PSI AND FINAL PRESSURE OF 380 PSI. 02:00 - 04:00 2.00 P WEXIT POH WHIPSTOCK/MILLING BHA FROM 5,716' TO 910'. - PUWT 120K, SOW 115K. - MW 9.8 PPG IN / OUT. 04:00 - 05:30 1.50 P WEXIT LD WHIPSTOCK/MILLING BHA FROM 419' TO SURFACE. - UPPER MILL IN GAUGE. 05:30 - 06:00 0.50 P WEXIT RU BOP JETTING TOOL & FLUSH STACK. 06:00 - 08:30 2.50 P WEXIT MU BHA # 3 WITH NEW 8 -1/2" HYCALOG DTX619M PDC BIT, 1.83 DEG BEND ON MUD MOTOR, ARC, AND MWD. RIH ON SINGLES TO 805'. 08:30 - 13:00 4.50 P WEXIT RIH ON SINGLES FROM PIPE SHED F/ 805' TO 5,571'. - SHALLOW TEST MWD (500 GPM, 935 PSI). - ORIENT 90 LEFT. - PUWT 118K, SOW 110K. 13:00 - 14:00 1.00 P WEXIT CUT AND SLIP 84' OF DRILLING LINE, INSPECT DRAW WORKS, SERVICE TOP DRIVE AND CROWN. Printed: 1/25/2010 12:07:58 PM • BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Name: 07 -23 Common Well Name: 07 -23 Spud Date: 1/1/2010 Event Name: REENTER +COMPLETE Start: 12/26/2009 End: 1/13/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2010 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 1/3/2010 14:00 - 15:00 1.00 P WEXIT MAD PASS FROM 5,571' TO 5,783'. - 300 FT /HR, NO PUMPS OR ROTATION. - WASHED FROM 5,783' TO 5,809' (NO FILL). 15:00 - 00:00 9.00 DRILL P INT1 DRILL AHEAD IN 8 -1/2" INTERMEDIATE HOLE FROM 5,809' TO 6,239'. - 8 -10K WOB. - 500 GPM. - 2,185 PSI ON, 2,070 PSI OFF. - 6K TQ ON, 5K TQ OFF. - 130K PU WT, 112K SO WT, 120K ROT WT. - 45 RPM. - CALC ECD 10.21 PPG, ACT ECD 10.56 PPG. - ART 1.15, AST 3.77, ADT 4.90. 1/4/2010 00:00 - 12:00 12.00 DRILL • P INT1 DRILL AHEAD IN 8 -1/2" INTERMEDIATE HOLE FROM 6,239', TO 7,764'. - 15 -25K WOB. - 500 GPM. - 3,130 PSI ON, 2,759 PSI OFF. - 9K TQ ON, 7K TQ OFF. - 155K PU WT, 130K SO WT, 140K ROT WT. - 80 RPM. - MW 10 PPG IN / OUT. - CALC ECD 10.21 PPG, ACT ECD 10.56 PPG. - ART 6.97, AST 1.43, ADT 8.40. 12:00 - 00:00 12.00 DRILL P INT1 DRILL AHEAD IN 8 -1/2" INTERMEDIATE HOLE FROM 7,764' TO 8,369'. - 15 -25K WOB. - 530 GPM. - 3,270 PSI ON, 2,880 PSI OFF. - 10K TQ ON, 6.5K TQ OFF. - 173K PU WT, 137K SO WT, 145K ROT WT. - 60 RPM. - MW 10 PPG IN / OUT. - CALC ECD 10.37 PPG, ACT ECD 11.03 PPG. - ART 1.95, AST 5.87, ADT 7.82. 1/5/2010 00:00 - 12:00 12.00 DRILL P INT1 DRILLED AHEAD IN 8 -1/2" INTERMEDIATE HOLE FROM 8,369' TO 9,195'. - 5 -15K WOB. - 515 GPM. - 3,342 PSI ON, 3,077 PSI OFF. - 9K TQ ON, 7K TQ OFF. - 185K PU WT, 145K SO WT, 155K ROT WT. - 80 RPM. - MW 10 PPG IN / OUT. - CALC ECD 10.35 PPG, ACT ECD 11.12 PPG. - ART 2.63, AST 4.15 ADT 6.78. 12:00 - 13:00 1.00 DRILL P INT1 DRILL AHEAD IN 8 -1/2" INTERMEDIATE HOLE FROM 9,195' TO 9,205'. - 5 -15K WOB. -515 GPM. - 3,339 PSI ON, 3,080 PSI OFF. - 9K TO ON, 7K TQ OFF. - 190K PU WT, 145K SO WT, 162K ROT WT. Printed: 1/25/2010 12:07:58 PM • • BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: 07 -23 Common Well Name: 07 -23 Spud Date: 1/1/2010 Event Name: REENTER +COMPLETE Start: 12/26/2009 End: 1/13/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2010 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 1/5/2010 12:00 - 13:00 1.00 DRILL P INT1 - 60 RPM. - MW 10 PPG IN / OUT. - CALC ECD 10.32 PPG, ACT ECD 10.79 PPG. - ART .09, ADT .09 13:00 - 14:00 1.00 DRILL P INT1 CIRCULATE FOR SAMPLES IN ORDER TO VERIFY INTERMEDIATE CASING POINT. 14:00 - 17:00 3.00 DRILL P INT1 SHORT TRIPPED TO 7,441' (GHOST REAMER DEPTH). EXPERIENCED 25K OVERPULL AND INTERMITTENT SWABBING AT DEPTHS 8,792' - 8,760', 8,710, 8,638' - 8,591'. - PUMPED OUT F/ 8,300' TO 7,441' - 150 GPM, 620 PSI. - PUWT 167, SOWT 125K. 17:00 - 18:00 1.00 DRILL P INT1 RIH FROM 7,441' TO 9,205' AND WASHED TO BOTTOM (NO FILL). 18:00 - 20:00 2.00 DRILL P INT1 CIRCULATING THREE BU, ECD (10.6) AND CUTTINGS RETURN INDICATED SUFFICIENT HOLE CLEANING TO POH FOR 7" LINER RUN. - 525 GPM, 3,135 PSI. 20:00 - 23:30 3.50 DRILL P INT1 POH FROM 9,205 TO 5,674'. ENCOUNTERED 25K OVERPULL FROM 6,538' - 6,512', AND 50K OVERPULL AT 6,314' AND 6,173', WHILE HWDP AND JARS WERE CROSSING WINDOW. 23:30 - 00:00 0.50 DRILL P INT1 CHANGE OIL IN TOP DRIVE. 1/6/2010 00:00 - 00:30 0.50 DRILL P INT1 CHANGE OIL IN TOP DRIVE. 00:30 - 02:30 2.00 DRILL P INT1 POH FROM 5,674' TO 210' RACKING BACK DP & HWDP. 02:30 - 04:00 1.50 DRILL P INT1 UD 8 -1/2" INTERMEDIATE BHA FROM 210' TO SURFACE. 04:00 - 04:30 0.50 BOPSUF P LNR1 CLEAN AND CLEAR FLOOR. 04:30 - 06:00 1.50 BOPSUF P LNR1 CHANGE TOP RAMS TO 7" CASING AND TEST TO 250 PSI LOW / 3500 PSI HIGH (GOOD TEST). 06:00 - 08:00 2.00 CASE P LNR1 RIG UP CASING HANDLING TOOLS TO RUN 7" LINER. 08:00 - 15:30 7.50 CASE P LNR1 MU AND BAKER LOK 7" BTC -M SHOE TRACK, CHECKED FLOATS (CHECKED GOOD), AND RIH TO 3,617' WITH 2,799' OF 7" 26# L -80 TC II AND 617' OF 7" 26# C -90 VAM TOP HC LINER. - USED JET LUBE SEAL GUARD DOPE. - TORQUE TURNED ALL CONNECTIONS. - MU TQ TC II = 10,100 FT /LBS. - MU TQ VAM TOP HC = 13,750 FT /LBS. 15:30 - 16:30 1.00 CASE P LNR1 CIRCULATE 1.5 LINER VOLUMES (207 BBL) AND STAGE PUMPS TO 6 BPM (DISP RATE). - 252 GPM, 415 PSI. - PUWT 102K, 93K. 16:30 - 18:00 1.50 CASE P LNR1 RIH WITH LINER ON DP TO 5,754' FILLING PIPE AND BREAKING CIRCULATION EVERY 10 STDS. 18:00 - 18:30 0.50 CASE P LNR1 CIRCULATE AND CONDITION 1 LINER VOLUME AT WINDOW PRIOR TO ENTERING OPENHOLE. - STG TO 5 BPM, 450 PSI, 138 BBL. 18:30 - 20:30 2.00 CASE P LNR1 RIH WITH LINER ON DP FROM 5,754' TO 8,228' FILLING PIPE AND BREAKING CIRCULATION EVERY 10 STDS. - PUWT 195K, SOW 135K. 20:30 - 22:00 1.50 CASE P LNR1 CIRCULATE BU PRIOR TO ENTERING THRZ. - STG TO 6 BPM, 780 PSI, 356 BBL. 22:00 - 23:00 1.00 CASE P LNR1 RIH WITH LINER ON DP FROM 8,228' TO 9,183'. TOOK 25K Printed: 1/25/2010 12:07:58 PM �► • BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: 07 -23 Common Well Name: 07 -23 Spud Date: 1/1/2010 Event Name: REENTER +COMPLETE Start: 12/26/2009 End: 1/13/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2010 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 1/6/2010 22:00 - 23:00 1.00 CASE P LNR1 TO WORK PIPE FROM 8,872' TO 9,087'. - PUWT 250K, SOW 130K. 23:00 - 00:00 1.00 CASE P LNR1 RIGGED UP BAKER CEMENT HEAD AND WASH TO 9,205. - ENCOUNTERED 7' OF FILL. 1/7/2010 00:00 - 01:00 1.00 CEMT P LNR1 CIRCULATE AND CONDITION PRIOR TO CEMENTING 7" LINER. -STG TO 6 BPM, CBUX2. 01:00 - 03:30 2.50 CEMT P LNR1 PJSM FOR 7" INTERMEDIATE LINER CEMENT JOB. - PUMPED 30 BBLS OF 10.4 PPG MUDPUSH II. - PT LINES TO 4,500 PSI; TESTED GOOD. - Pl1MPED 96 BBLS OF 11 PPG LITE CRETE CEMENT STARTING AT 0200 HRS; PUMPED © 5.5 BPM, 923 PSI. - PIIMPFD 38 RBI OF 15.8 PPG CLASS G CEMENT STARTING AT 0221 HRS; PUMPED © 6 BPM, 526 PSI. - DROPPED DRILL PIPE WIPER DART. - PUMPED 5 BBL FRESH WATER TO RINSE LINES AND BEGIN DISPLACEMENT. - SWITCHED TO RIG PUMPS FOR DISPLACEMENT. - DISPLACED WITH 189 BBLS AT 6 BPM, 1813 PSI UNTIL 5 BBLS BEFORE BUMPING THE PLUG. SLOWED THE PUMP TO 2.5 BPM, 1288 PSI IN PREPARATION FOR BUMPING PLUG. BUMPED PLUG AT 3190 STKS, 189 BBL AND PRESSURED UP TO 3100 PSI TO SET HANGER. - SET DOWN 50K TO VERIFY HANGER SET. - PRESSURED UP 4058 PSI TO RELEASE RUNNING TOOL. - PICK UP TO EXPOSE DOGS. - SET DOWN 55K AND HAD GOOD INDICATION OF DOG SHEAR AT 40K. - BLED OFF PRESSURE AND CHECKED FLOATS; FLOATS HELD. - PRESSURED UP TO 1000 PSI TO STING OUT OF LINER TOP PACKER. - FULL RETURNS THROUGHOUT JOB. - TOTAL CEMENT PUMPED: LITE CRETE SLURRY, 11 PPG Ag - -96 BBLS, 292.9 SKS, 1.84 CU FT /SK, TAIL SLURRY, 15.8 PPG - -36 BBLS, 174 SKS, 1.16 CU FT /SK. ** *CEMENT IN PLACE AT 0305 HRS. * ** 03:30 - 04:30 1.00 CEMT P LNR1 CIRCULATE EXCESS CEMENT TO SURFACE. - 30 BBLS MUDPUSH II RETURNS AT SURFACE; 30 BBL CEMENT RETURNS AT SURFACE. - 570 GPM, 1900 PSI. 04:30 - 07:00 2.50 CEMT P LNR1 UD LINER CEMENT HEAD, POH FROM 5,600 TO SURFACE, AND UD LINER RUNNING TOOL. 07:00 - 09:00 2.00 BOPSUF P LNR1 NIPPLE DOWN BOP AND CHANGE UPPER RAMS TO 3 -1/2" X 6" AND TEST TO 250 PSI LOW / 3500 PSI HIGH. 09:00 - 09:30 0.50 BOPSUF P LNR1 INSTALL WEAR BUSHING. 09:30 - 12:00 2.50 DRILL P PROD1 PJSM. PU 6 -1/8" DRILLING BHA #4 WITH XR2ODOD1GVPD SMITH BIT, 1.15 MOTOR W/ FLOAT, NM STAB, NM FLEX 10' LC, IMPULSE MWD, ADN4 (RA SOURCE), NM STAB, 3X NM FLEX DC, AND HYD JARS. RIH THE HOLE FROM SURFACE TO 829'. 12:00 - 15:30 3.50 DRILL P PROD1 RIH FROM 829' TO 9,022' FILLING DP EVERY 30 STDS. - PUWT 195K, SOWT 125K. Printed: 1/25/2010 12:07:58 PM • • BP EXPLORATION Page 8 of 12 Operations Summary Report Legal Well Name: 07 -23 Common Well Name: 07 -23 Spud Date: 1/1/2010 Event Name: REENTER +COMPLETE Start: 12/26/2009 End: 1/13/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2010 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 1/7/2010 15:30 - 17:00 1.50 CASE P PROD1 PRESSURE TEST CASING TO 3,500 PSI FOR 30 MINS (GOOD TEST). -FIRST 15 MINS 32 PSI LOSS / SECOND 15 MINS 15 PSI LOSS. 17:00 - 19:00 2.00 DRILL P PROD1 RIH AND TAG CEMENT AT 9,097', WASH DOWN (170 GPM, 1,300 PSI) AND TAG LC AT 9,121'. DRILLED LC, FC, AND CEMENT TO 9,199'. - 250 GPM, 2,095 PSI, 60 RPM, 8.5K TQ. - PUWT 195K, SOWT 125K, ROT 152K. 19:00 - 21:00 2.00 DRILL P PROD1 DISPLACE TO 8.5 PPG FLO PRO SF. - PUMPED 75 BBL WATER. - 50 BBL HIGH VISCOSITY SPACER. - 494 BBL FLO PRO SF. - 10, 730 STK, 250 GPM, 1500 PSI. 21:00 - 21:15 0.25 DRILL P PROD1 DRILLED REMAINDER OF SHOE TRACK FROM 9,199' TO 9,204'. - 250 GPM, 2,095 PSI, 60 RPM, 8.5K TQ. 21:15 - 22:00 0.75 DRILL P PROD1 DRILLED NEW FORMATION FROM 9,205' TO 9,225'. ENCOUNTERED LOSSES (APPROXIMATELY 16 BBL) AND AS PER DISCUSSION WITH TOWN DRILLED AN ADDITIONAL 10' TO 9,235'. LOSSES DID NOT SUBSIDE AND CONTINUED AT A RATE OF 18 -24 BBLS /HR. 22:00 - 00:00 2.00 LCR N DPRB PROD1 BUILDING 25 BBL SEEPAGE LOSS PILL BASED ON MI SWACO RECOMMENDATION. - G -SEAL PLUS, 10 PPB. - MIX II M, 15 PPB. - SAFE CARB 40, 10 PPB. - NUTPLUG F, 5 PPB. !\ - MAGMA FIBER, 5 PPB. 1/8/2010 00:00 - 02:00 2.00 LCR N DPRB PROD1 CONT. MIXING 25 BBLS SEEPAGE LOSS PILL AND AT 9,235'. 02:00 - 02:30 0.50 LCR N DPRB PROD1 POH FROM 9,235' TO 8,300'. 02:30 - 03:00 0.50 LCR N DPRB PROD1 CIRCULATED AT 8,300' WHILE MONITORING LOSSES. NO LOSSES WERE RECORDED FOR LAST 15 MINS. 03:00 - 05:00 2.00 LCR N DPRB PROD1 ATTEMPTED TO PERFORM FIT TO 10.5 PPG EMW., REACHED A PRESSURE OF 756 PSI (10.2 PPG EMW) AND SHUT IN. PRESSURE BLED OFF TO 0 PSI IN 7 MINUTES. CONTACTED ENGINEER TO DETERMINE NEXT STEP. DECIDED TO GIVE HOLE TIME TO HEAL AND RE- ATTEMPT FIT. 05:00 - 06:00 1.00 DRILL P PROD1 PERFORMED SECOND FIT TO 600 PSI (9.85 PPG EMW). 06:00 - 07:00 1.00 DRILL P PROD1 MONITOR WELL TO ESTABLISH STATIC LOSS RATE (30 BBL / HR). 07:00 - 07:30 0.50 DRILL P PROD1 RIH FROM 8,300' TO 9,235'. 07:30 - 10:30 3.00 DRILL N DFAL PROD1 UNABLE TO COMMUNICATE WITH MWD. PULLED INTO THE SHOE AT 9,204' AND ATTEMPTED TO RE- ESTABLISH CONNECTION. DECISION WAS MADE TO DRILL AHEAD TO SEE IF DISTANCE FROM THE CASING WOULD ELIMINATE PROBLEM WITH MWD. RIH TO TD TO RESUME DRILLING. 10:30 - 12:00 1.50 DRILL P PROD1 DIRECTIONAL DRILLED FROM 9,235' TO 9,266'. - 12K WOB, 80 RPM. - TO ON 5K, TQ OFF 4K. Printed: 1/25/2010 12:07:58 PM • • • BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Name: 07 -23 Common Well Name: 07 -23 Spud Date: 1/1/2010 Event Name: REENTER +COMPLETE Start: 12/26/2009 End: 1/13/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2010 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 1/8/2010 10:30 - 12:00 1.50 DRILL P PROD1 - 250 GPM, 1535 PSI ON, 1415 PSI OFF. - PUWT 180K, SOWT 150K, ROT 170K. - ART 1.86. 12:00 - 17:00 5.00 DRILL P PROD1 DIRECTIONAL DRILLED FROM 9,266' TO 9,498'. - 12K WOB, 80 RPM. - TQ ON 3K, TO OFF 3K. - 250 GPM, 1550 PSI ON, 1380 PSI OFF. - PUWT 180K, SOWT 150K, ROT 157K. - REGAINED COMMUNICATION WITH INTERMITTENT OUTAGES, BUT STILL NO RESITIVITY. - ART 3.25, AST 0, ADT 3.25. 17:00 - 19:00 2.00 DRILL N DPRB PROD1 COMMUNICATION WITH MWD COULD NOT BE RESTORED. A TRIP WAS NECESSARY TO CHANGE OUT MWD. PRIOR TO PULLING OFF BOTTOM PUMPED A 50 BBL PARTIAL LOSS PILL WITH 80 PPB LCM TO HELP WITH LOSSES. DROPPED 1.76" BALL TO OPEN CCV W/ 2100 PSI. DROPPED 1.693" BALL TO REDIRECT FLOW FROM BHA. 19:00 - 20:30 1.50 DRILL N DFAL PROD1 POH FROM 9,498' TO 7,874' (INSIDE 7" LINER). 20:30 - 22:00 1.50 DRILL N DFAL PROD1 CIRCULATE BOTTOMS UP WHILE MONITORING THE WELL FOR LOSSES. NO FLUID LOST TO FORMATION, BUT NOTED SOME FLUID LOSS OVER THE SHAKERS. / \� -228 GPM, 423 PSI. �`( 22:00 - 00:00 2.00 DRILL N DFAL PROD1 POH FROM 7,874' TO 4,921'. - 8.5 MW IN / OUT. -TOTAL LOSSES FOR THE DAY 697 BBL. 1/9/2010 00:00 - 01:30 1.50 DRILL N DFAL PROD1 POH FROM 4,921' TO 230'. 01:30 - 03:30 2.00 DRILL N DFAL PROD1 L/D BHA FROM 230' TO SURFACE. BIT WAS IN GAUGE AND UNDAMAGED (RE -RUN). 03:30 - 05:30 2.00 DRILL N DFAL PROD1 CIO MWD, MU 6 -1/8" PRODUCTION BHA, AND RIH TO 230'. - DOWNLOADED MWD AND ADN. 05:30 - 12:00 6.50 DRILL N DFAL PROD1 RIH FROM 230' TO 9,498' FILLING DP EVERY 30 STDS. 12:00 - 14:30 2.50 DRILL P PROD1 CIRCULATED 1 BOTTOMS UP STAGING FLOW RATE UP TO 250 GPM AS NEW MUD WARMING UP AND SHEARING. SHAKERS RUNNING OVER LIMITED PUMP RATE. FSTIMATFD I OSSFS TO FORMATION AT 10 -15 BPI - 14:30 - 00:00 9.50 DRILL P PROD1 DIRECTIONALLY DRILLED FROM 9,498' TO 9,967' MD (TD). LOSSES DURING DRILLING AT 10 -15 BPH. - 14K WOB, 60 RPM, 4K TQ ON, 3K TO OFF. - 250 GPM, 1,550 PSI ON, 1,393 PSI OFF - PU - 184K, SO - 154K, RTW - 165K. - MW - 8.5 PPG IN /OUT - TOTAL LOSSES FOR THE DAY 153 BBL. - ART - 7.46 HRS, AST - 0.00 HRS, ADT - 6.46 HRS. 1/10/2010 00:00 - 04:30 4.50 DRILL P PROD1 BACK REAM FROM 9,967' TO 9,204' AT 300 FT /HR WHILE PERFORMING MAD PASS IN OPEN HOLE INTERVAL. STOPPED ROTATION AT 9,350' (STABALIZER 95' ABOVE BIT) TO AVOID POSSIBLY AGITATING LOSS ZONE AT 9,220' - 9,250'. FLOW RATE = 250GPM @ 1,375 PSI 04:30 - 05:30 1.00 DRILL P PROD1 CBU AT 9,204' VIA OPEN CCV. - OPENED CCV W/ 2100 PSI. - CIRCULATED @ 500 GPM, 1,500 PSI FOR 1 CBU. Pnnted: 1/25/2010 12:07:58 PM • • BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: 07 -23 Common Well Name: 07 -23 Spud Date: 1/1/2010 Event Name: REENTER +COMPLETE Start: 12/26/2009 End: 1/13/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2010 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 1/10/2010 05:30 - 08:00 2.50 DRILL P PROD1 CLOSED CCV W/ 2,100 PSI. MAD PASS CASED HOLE FROM 9,204' TO 8,500' MD AT 500 FT /HR WITHOUT ROTATION. FLOW RATE = 180 GPM @ 1,029 PSI 08:00 - 09:30 1.50 DRILL P PROD1 POOH TO LINER TOP @ 5,615' MD 09:30 - 10:30 1.00 DRILL P PROD1 JET LINER TOP WITH CCV FOR 2 CBU FLOWING AT 525 GPM @ 1,060 PSI, ROTATING AT 60RPM FROM 5,682' TO 5,600' MD. (BIT DEPTH FROM 5,875' TO 5,794') SAW LCM RETURNS AFTER 1 BU, LCM RETURNS TAPPERED OFF 90% BEFORE 2ND BU. 10:30 - 12:30 2.00 DRILL P PROD1 POOH FROM 5,600' TO TOP OF BHA @ 830' CLOSE CCV W/ 1,820 PSI 12:30 - 17:00 4.50 DRILL P PROD1 LD HWDP, LD DRILLING BHA #5, LD JARS BREAK CCV AND CATCHER TOOL, REMOVED 4 BALLS REMOVE RA SOURCE, DOWNLOAD LWD WHILE ON RIG FLOOR, LD MOTOR & BIT BIT GRADING 1- 2- BT- G- E- I -ER -TD SHALLOW RESISTIVITY SENSOR FAILED ON LWD TOOL 17:00 - 17:30 0.50 DRILL P PROD1 CLEAR AND CLEAN RIG FLOOR 17:30 - 20:30 3.00 CASE P RUNPRD RIG UP NABORS CASING SERVICE TONGS, TORQUE TURN EQUIPMENT, AND COMPENSATOR TO RIH 4 -1/2" 12.60 # VAM TOP 13CR -85 PRODUCTION LINER. 20:30 - 23:00 2.50 CASE P RUNPRD PU SHOE TRACK AND RIH W/ 22 JTS OF 4-1/2" LINER TO 916' MD FILLING EVERY TENTH JOINT. UTILIZE TORQUETURN EQUIPMENT TO TORQUE TUBING TO 4,440 FT /LBS AND RECORD. JET LUBE SEAL GUARD DOPE. BAKER LOCKED SHOE TRACK CONNECTIONS - LOSSES AT 7 BBUHR WHILE RIH. 23:00 - 23:15 0.25 CASE P RUNPRD PRE JOB SAFETY MEETING WITH GUESS'S CREW AND CHECK 6. 23:15 - 23:30 0.25 CASE P RUNPRD RU BAKER FLEX -LOCK LINER HANGER. RUN 4 -1/2" LINER TO 947' MD. 23:30 - 00:00 0.50 CASE P RUNPRD RD 4 -1/2" TONGS, ELEVATORS, AND TORQUE TURN EQUIPMENT, C/O BAILS FOR HANDLING 4" DP. 1/11/2010 00:00 - 01:00 1.00 CASE P RUNPRD RD 4 -1/2" TONGS, ELEVATORS, AND TORQUE TURN EQUIPMENT, C/O BAILS FOR HANDLING 4" DP. 01:00 - 01:30 0.50 CASE P RUNPRD CIRCULATED 1.5 LINER VOLUME (25 BBL, 433 STK, 170 GPM, 60 PSI). 01:30 - 07:00 5.50 CASE P RUNPRD RIH WITH 4 -1/2" LINER FROM 947' TO 9,204' MD. - PUWT 108K, SOWT 135K. 07:00 - 08:00 1.00 CASE P RUNPRD CIRCULATE 150 BBL PRIOR TO RUNNING INTO OPEN HOLE. -126 GPM, 380 PSI. 08:00 - 09:00 1.00 CASE P RUNPRD RIH WITH 4 -1/2" LINER FROM 9,204' TO 9,941'. - MU 1 -JT DP AND BAKER CMT HEAD. - TAG BOTTOM AT 9,967' (26' IN ON SINGLE). - PU 170K, SO 150K. 09:00 - 10:30 1.50 CEMT P RUNPRD PJSM WITH SCHLUMBERGER CEMENTERS. - RU CEMENTING EQUIPMENT. - CIRCULATE @ 3 BPM, 480 PSI, WHILE RIGGING UP. - LOSING 15 -20 BBUHR. 10:30 - 12:00 1.50 CEMT P RUNPRD 4 -1/2" PRODUCTION LINER CEMENT JOB. Printed: 1/25/2010 12:07:58 PM • w • BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: 07 -23 Common Well Name: 07 -23 Spud Date: 1/1/2010 Event Name: REENTER +COMPLETE Start: 12/26/2009 End: 1/13/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2010 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 1/11/2010 10:30 - 12:00 1.50 CEMT P RUNPRD - PUMPED 25 BBLS OF 12 PPG MUDPUSH II. - PT LINES TO 4,500 PSI; TESTED GOOD. - PUMPED 51 BBLS OF 15.8 PPG GAS BLOC TAIL CEMENT STARTING AT 10:41 HRS; PUMPED @ 3.8 BPM, 165 PSI. - DROPPED DRILL PIPE WIPER DART. - SWITCHED TO RIG PUMPS FOR DISPLACEMENT, NO CEMENT ON TOP OF PLUG. - DISPLACED WITH 102.79 BBLS OF 8.5 PPG FLO PRO AT 3 BPM, 170 PSI. BUMPED PLUG AT 1739 STKS, 102.79 BBL AND PRESSURED UP TO 3400 AND HELD 2 MINS TO SET HANGER. - SET DOWN 80K TO VERIFY HANGER SET. - PRESSURED UP 4300 PSI TO RELEASE RUNNING TOOL. - PICK UP TO EXPOSE DOGS. - SET DOWN 120K AND HAD GOOD INDICATION OF DOG SHEAR. - PU TO 160K AND REPEAT SLACK OFF TO 75K (NO SHEAR), AND ROTATED DOWN TO 105K (NO SHEAR). - BLED OFF PRESSURE AND CHECKED FLOATS; FLOATS HELD. - PRESSURED UP TO 1000 PSI TO STING OUT OF LINER TOP PACKER. - SLIGHT LOSSES DURING CEMENT JOB. FROM PLUG BUMP TO PACKER SET FLUID FELL 30' FOR 10 BBL LOSS. - TOTAL CEMENT PUMPED: TAIL SLURRY GAS BLOC, 15.8 PPG - -51.8 BBLS, 266 SKS, 1.17 CU FT/SK. ** *CEMENT IN PLACE AT 11:28 HRS. * ** 12:00 - 12:30 0.50 CEMT P RUNPRD CIRCULATE EXCESS CEMENT TO SURFACE. - 1.2 BU - 17 BBL OF CEMENT. / -530 GPM, 1,500 PSI. 12:30 - 13:00 0.50 CEMT P RUNPRD UD BAKER CMT HEAD. 13:00 - 14:30 1.50 CEMT P RUNPRD RU AND PRESSURE TEST 4 -1/2" LINER TO 3532 PSI FOR �l" 30 MINS (soon TFST)__ �,� - FIRST 15 MINS LOST 14 PSI (3518 PSI). SECOND 15 MINS GAINED 12 PSI (3530 PSI). 14:30 - 15:30 1.00 CONDHL P RUNPRD DISPLACE 8.5 PPG FLOW PRO SF WITH 8.5 PPG SEAWATER. - 516 GPM, 2,150 PSI. - PU 160K , SO 140K. 15:30 - 23:30 8.00 CONDHL P RUNPRD POH UD DP FROM 9,006' TO SURFACE. - UD RUNNING TOOL. - BAKER REP CONFIRMED DOG SUB SHEARED. 23:30 - 00:00 0.50 WHSUR P RUNPRD REMOVE WEAR BUSHING. 1/12/2010 00:00 - 00:30 0.50 RUNCOMP RUNCMP MAKE DUMMY RUN WITH 13" TBG HANGER. 00:30 - 02:30 2.00 RUNCOMP RUNCMP RU TBG HANDLING EQUIPMENT. COMPENSATOR, TORQUE -TURN EQUIPMENT AND TONGS 02:30 - 12:00 9.50 RUNCOMP RUNCMP MU TAILPIPE AND BAKERLOK ASSY, "X" NIPPLE ASSY #1, FULL JOINT, "X" NIPPLE ASSY #2, AND GLM ASSY #1, AND RIH WITH 4 -1/2" 12.6# VAM TOP 13CR TBG TO 6028' MD. AVERAGE M/U TORQ = 4440 FT /LBS 12:00 - 16:30 4.50 RUNCOMP RUNCMP CONTIUNE TO RIH WITH 4 -1/2" VAM TOP 13CR COMPLETION TBG FROM 6028' MD TO 9028' MD AND TAG Printed: 1/25/2010 12:07:58 PM • • BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: 07 -23 Common Well Name: 07 -23 Spud Date: 1/1/2010 Event Name: REENTER +COMPLETE Start: 12/26/2009 End: 1/13/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2010 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 1/12/2010 12:00 - 16:30 4.50 RUNCOMP RUNCMP UP ON NO GO IN PBR AT 9028' MD. 16:30 - 18:00 1.50 RUNCOMP RUNCMP SPACE OUT WITH 209 JTS AND 29.71' AND 5.83' PUP BETWEEN JTS 209 AND 208. WLEG AT 9021' MD WITH LINER TOP AT 9016' MD 18:00 - 21:00 3.00 RUNCOMP RUNCMP REVERSE CIRCULATE 137 BBLS CLEAN SEAWATER, 162 BBLS CORROSION INHIBITED SEAWATER AND 201 BBLS OF CLEAN SEAWATER AT 3 BPM AND 190 PSI. 21:00 - 23:00 2.00 RUNCOMP RUNCMP PICK 11P 4 -1/2" I ANnINC .IT AND M/U TO HANGER. ,DROP BALL AND ROD. LAYDOWN LANDING JT AND CLOSE BLIND RAMS. PRESSURE UP TUBING TO 3500 PSI AND SET PACKER. PRESSURE TEST TUBING TO 3500 PSI FOR 30 MIN. LOST 0 PSI IN 30 MIN. BLEED OFF TUBING PRESSURE TO 1500 PSI. PRESSURE TEST IA TO 3500 PSI FOR 30 MIN. LOST 10 PSI IN THE FIRST 15 MIN AND 0 PSI IN THE SECOND 15 MIN. BLEED IA, THEN TUBING TO 0 PSI. PRESSURE UP IA TO 3000 PSI TO SHEAR DCK IN GLM #4. CIRCULATE 2 BBLS EACH WAY TO CONFIRM VALVE SHEARED. 23:00 - 00:00 1.00 RUNCOMP RUNCMP BLOW DOWN LINES. DRYROD IN TWC. 1/13/2010 00:00 - 00:30 0.50 RUNCOMP RUNCMP FINISH INSTALLING TWC. PRESSURE TEST FROM ABOVE AND BELOW TO 1000 PSI FOR 5 MIN. 00:30 - 01:30 1.00 WHSUR P RUNCMP BLOW DOWN LINES. ND BOPE STACK AND SECURE TO PEDESTAL. 01:30 - 05:00 3.50 WHSUR P RUNCMP NU ADAPTER FLANGE AND 4- 1/16" TREE., TEST ADAPTER FLANGE AND TUBING HANGER TO 5000 PSI FOR 30 MIN. FINISH NU TREE AND TEST TO 5000 PSI FOR 5 MIN. 05:00 - 06:30 1.50 WHSUR P RUNCMP RU DSM LUBRICATOR AND TEST. PULL TWC. RD LUBRICATOR. 06:30 - 10:30 4.00 WHSUR P RUNCMP PJSM, RU LITTLE RED HOT OIL. PRESSURE TEST LINES TO 3000 PSI. REVERSE CIRCULATE IN 164 BBLS OF DIESEL. ALLOW DIESEL TO U -TUBE INTO TUBING. RD LRHOS LINES. INSTALL BPV AND TEST FROM BELOW TO 1000 PSI. 10:30 - 12:00 1.50 WHSUR P RUNCMP CLEAN AND CLEAR RIG FLOOR. INSTALL ALL FLANGES AND GAUGES. SECURE TREE. RIG RELEASED FROM 07 -23B AT 12:00 1/13/2009 TO 17 -09A Printed: 1/25/2010 12:07:58 PM • 07 -23B, Well History (Post Rig Sidetrack) Date Summary 1/26/2010 WELL SI ON ARRIVAL. PULL B &R FROM 8988' SLM, PULL ST.3 BK -DGLV @ 6201' SLM / 6221' MD. PULL ST.4 BEK -DCK @ 3731' SLM / 3753' MD, SET ST.4 BK -LGLV @ 3731' SLM / 3753' MD. SET ST.3 BK -OGLV 6201' SLM / 6221' MD, PULL RHC FROM 8991' SLM / 9010' MD. DRIFT 3 3/8" DMY GUN UNABLE TO PASS 9720' SLM, VERY STICKY (NO SAMPLE). RAN 3.00" x 10' PUMP BAILER TO 9734' SLM WORK IT TO 9772' SLM RECOVER - 2 gal DRILLING MUD. RIH W/ 3 -1/2 "x 10' PUMP BAILER. 1/27/2010 RAN 3 -1/2" x 10' PUMP BAILER TO 9808' SLM WORKED TO 9822' SLM. RECOVERED 2 -1/2 gal of DRILLING MUD. DRIFT 3 -3/8" X 10' DMY GUN TO 9816' SLM. LEFT WELL SI, TURNED OVER TO DSO. 1/27/2010 WELL SHUT IN UPON ARRIVAL. ARRIVE ON LOCATION, SPOT EQUIPMENT, AND BEGIN RU ELINE. 1/28/2010 INITIAL T /I /O: 200/0/0 PSI. PERFORATE 9728' - 9748'. CCL TO TOP SHOT: 4.2' CCL STOP DEPTH: 9723.8'. API DATA: PENETRATION DEPTH: 36.5 ", HOLE SIZE: 0.37 ". SECOND GUN RUN POSTPONED DUE TO WIND. FINAL T /I /O: 200/0/0 PSI. 2/2/2010 WELL SHUT -IN ON ARRIVAL. INITIAL T /I /O = 0/0/0 PSI. PERFORATE 9710' - 9728' WITH 3 -3/8" PJ HSD 6 SPF, 60 DEG PHASING GUN. DEPLOYED WITH SCHLUMBERGER 0.44" SLIC CABLE WIRE. FINAL T /I /O = 0/0/0. JOB COMPLETED, WELL LEFT SHUT -IN. Page 1 of 1 by 4) DS07 -23B Survey Report Schlumberger Report Date: January 13, 2010 Survey 1 DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 221.160 Field: Prudhoe Bay Unit - EOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: DS -07 / 07 -23 TVD Reference Datum: Rotary Table Well: 07 -23 TVD Reference Elevation: 55.86 ft relative to MSL Borehole: 07 -23B Sea Bed I Ground Level Elevation: 26.80 ft relative to MSL UWIIAPI #: 500292163502 Magnetic Declination: 22.402 Survey Name I Date: 07 -23B / January 5, 2010 Total Field Strength: 57680.250 nT Tort I AHD I DDI I ERD ratio: 127.170° / 2944.39 ft 1 5.605 / 0.318 Magnetic Dip: 80.922 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: January 05, 2010 Location LaULong: N 70.26609159, W 148.57681591 Magnetic Declination Model: BGGM 2009 Location Grid NIE YIX: N 5948934.440 ftUS, E 676002.660 ftUS North Reference: True North Grid Convergence Angle: +1.33963322 Total Corr Mag North -> True North: +22.402° Grid Scale Factor: 0.99993519 Local Coordinates Referenced To: Well Head • Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub -Sea TVD TVD Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North I (ft ) (deg) (deg) (ft) (ft) (ft ) (ft) I (ft) (ft ) (ft ) (deg!f00ft ) (ftUS) (ftUS) Projected -Up 0.00 0.00 0.00 -55.86 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5948934.44 676002.66 N 70.26609159 W 148.57681591 WRP 29.06 0.00 0.00 -26.80 29.06 0.00 0.00 0.00 0.00 0.00 0.00 5948934.44 676002.66 N 70.26609159 W 148.57681591 Gyrodata Gyro 98.76 0.06 188.22 42.90 98.76 0.03 0.04 0.04 -0.04 -0.01 0.09 5948934.40 676002.66 N 70.26609150 W 148.57681596 10/30/09 198.66 0.06 248.62 142.80 198.66 0.12 0.13 0.12 -0.11 -0.06 0.06 5948934.33 676002.60 N 70.26609130 W 148.57681641 298.76 0.12 251.65 242.90 298.76 0.26 0.28 0.26 -0.16 -0.21 0.06 5948934.28 676002.45 N 70.26609116 W 148.57681761 398.46 0.25 236.29 342.60 398.46 0.56 0.60 0.58 -0.31 -0.49 0.14 5948934.12 676002.18 N 70.26609074 W 148.57681987 498.66 0.19 202.78 442.80 498.66 0.93 0.98 0.94 -0.59 -0.74 0.14 5948933.84 676001.94 N 70.26608999 W 148.57682186 598.66 0.21 170.27 542.80 598.66 1.20 1.32 1.20 -0.92 -0.77 0.11 5948933.50 676001.91 N 70.26608908 W 148.57682213 698.26 0.22 112.03 642.40 698.26 1.25 1.66 1.30 -1.17 -0.56 0.21 5948933.26 676002.13 N 70.26608839 W 148.57682045 797.76 0.17 175.34 741.90 797.76 1.29 1.97 1.44 -1.39 -0.37 0.21 5948933.04 676002.32 N 70.26608779 W 148.57681892 899.16 0.17 101.96 843.30 899.16 1.32 2.23 1.59 -1.57 -0.21 0.20 5948932.86 676002.48 N 70.26608730 W 148.57681763 997.86 0.05 110.06 942.00 997.86 1.24 2.42 1.62 -1.62 -0.03 0.12 5948932.82 676002.67 N 70.26608718 W 148.57681615 1098.06 0.24 158.52 1042.20 1098.06 1.32 2.66 1.83 -1.83 0.09 0.21 5948932.62 676002.79 N 70.26608660 W 148.57681519 1197.96 0.17 158.20 1142.10 1197.96 1.48 3.02 2.17 -2.16 0.22 0.07 5948932.29 676002.93 N 70.26608569 W 148.573 1298.66 0.42 165.92 1242.79 1298.65 1.76 3.54 2.68 -2.66 0.37 0.25 5948931.79 676003.09 N 70.26608434 W 148.57 5 1397.96 0.49 138.63 1342.09 1397.95 2.02 4.31 3.41 -3.33 0.74 0.23 5948931.13 676003.47 N 70.26608250 W 148.57680997 1497.06 0.41 150.18 1441.19 1497.05 2.19 5.09 4.13 -3.95 1.19 0.12 5948930.52 676003.94 N 70.26608079 W 148.57680628 1598.76 0.62 155.19 1542.88 1598.74 2.54 6.00 5.03 -4.77 1.60 0.21 5948929.71 676004.37 N 70.26607857 W 148.57680295 1698.36 0.58 137.93 1642.48 1698.34 2.81 7.04 6.03 -5.63 2.17 0.19 5948928.86 676004.96 N 70.26607621 W 148.57679839 1797.76 0.65 152.12 1741.87 1797.73 3.08 8.10 7.07 -6.50 2.77 0.17 5948928.00 676005.58 N 70.26607382 W 148.57679353 1897.66 0.97 148.74 1841.76 1897.62 3.53 9.51 8.47 -7.73 3.47 0.32 5948926.80 676006.31 N 70.26607048 W 148.57678784 1997.66 0.77 148.48 1941.75 1997.61 3.99 11.03 9.98 -9.02 4.26 0.20 5948925.52 676007.13 N 70.26606694 W 148.57678145 2097.26 0.84 146.23 2041.34 2097.20 4.38 12.43 _ 11.37 -10.20 5.02 0.08 5948924.36 676007.91 N 70.26606372 W 148.57677534 2197.46 1.19 113.41 2141.53 2197.39 4.25 14.15 12.91 -11.23 6.38 0.66 5948923.37 676009.30 N 70.26606093 W 148.57676432 2297.86 1.08 107.55 2241.91 2297.77 3.55 16.14 14.50 -11.93 8.24 0.16 5948922.71 676011.18 N 70.26605902 W 148.57674930 2397.76 1.30 96.73 2341.78 2397.64 2.54 18.21 16.05 -12.34 10.26 0.31 5948922.34 676013.21 N 70.26605788 W 148.57673294 9 -5/8" Csg 2488.86 1.66 106.27 2432.85 2488.71 1.40 20.55 17.95 -12.83 12.55 0.47 5948921.91 676015.51 N 70.26605654 W 148.57671443 2497.36 1.69 106.95 2441.35 2497.21 1.30 20.80 18.17 -12.90 12.79 0.47 5948921.84 676015.75 N 70.26605635 W 148.57671251 2597.46 3.38 141.22 2541.35 2597.21 1.21 25.11 22.41 -15.63 16.05 2.20 5948919.19 676019.07 N 70.26604888 W 148.57668615 SurveyEditor Ver SP 2.1 Bld( users) 07- 23 \07- 23 \07- 23B \07 -23B Generated 2/17/2010 10:51 AM Page 1 of 5 Measured Azimuth Vertical Along Hole NS EW 1 Comments Inclination Sub-Sea TVD TVD Closure DLS Northing Easting Latitude Longitude ' Depth True Section Departure True North True North de (ftl (deg) (deg) I (ft) (ft) (ft) (k) lkl (ft) ( ft ) ( 9l 100 ft ) ( ftUS ) ( ftUS ) 2697.56 5.01 163.21 2641.19 2697.05 4.04 32.35 29.26 -22.12 19.16 2.26 5948912.78 676022.33 N 70.26603117 W 148.57666100 2797.26 5.12 177.00 2740.50 2796.36 9.54 41.11 37.02 -30.73 20.65 1.22 5948904.20 676024.02 N 70.26600764 W 148.57664895 2897.46 6.60 195.20 2840.19 2896.05 17.93 51.25 45.12 -40.75 19.38 2.35 5948894.15 676022.98 N 70.26598026 W 148.57665926 2998.26 9.02 205.98 2940.05 2995.91 30.77 64.91 55.35 -53.45 14.40 2.80 5948881.35 676018.30 N 70.26594557 W 148.57669953 3097.16 11.68 201.60 3037.33 3093.19 47.68 82.67 70.11 -69.73 7.31 2.80 5948864.91 676011.60 N 70.26590110 W 148.57675680 3197.06 13.25 205.13 3134.88 3190.74 68.22 104.23 89.51 -89.50 -1.27 1.75 5948844.94 676003.48 N 70.26584709 W 148.57682620 3298.86 14.73 204.92 3233.65 3289.51 91.86 128.83 112.41 - 111.80 -11.68 1.45 5948822.41 675993.60 N 70.26578617 W 148.57691035 3323.86 15.48 205.82 3257.79 3313.65 98.13 135.35 118.57 - 117.68 -14.47 3.14 5948816.46 675990.94 N 70.26577009 W 148.57693292 3348.86 15.95 206.25 3281.85 3337.71 104.66 142.12 124.99 - 123.77 -17.45 1.94 5948810.31 675988.11 N 70.26575347 W 148.57695695 3373.86 16.70 206.62 3305.85 3361.71 111.46 149.15 131.68 - 130.06 -20.57 3.03 5948803.94 675985.13 N 70.26573628 W 148.57698225 3398.86 17.37 206.51 3329.75 3385.61 118.55 156.47 138.68 - 136.61 -23.85 2.68 5948797.32 675982.01 N 70.26571838 W 148.57700873 3423.86 17.69 206.94 3353.59 3409.45 125.84 164.00 145.90 - 143.34 -27.24 1.38 5948790.52 675978.78 N 70.26570001 W 148.57703611 3448.86 18.37 207.44 3377.36 3433.22 133.35 171.74 153.34 - 150.22 -30.77 2.79 5948783.55 675975.41 N 70.26568121 W 148.577 9 3473.86 18.91 207.81 3401.05 3456.91 141.12 179.73 161.03 - 157.30 -34.48 2.21 5948776.39 675971.87 N 70.26566187 W 148.57 5 3498.86 19.54 208.06 3424.66 3480.52 149.13 187.96 168.98 - 164.57 -38.33 2.54 5948769.03 675968.19 N 70.26564200 W 148.577 83 3523.86 20.36 208.31 3448.15 3504.01 157.44 196.49 177.23 - 172.09 -42.36 3.30 5948761.42 675964.33 N 70.26562146 W 148.57715840 3548.86 20.89 208.40 3471.55 3527.41 166.03 205.30 185.76 - 179.84 -46.55 2.12 5948753.57 675960.33 N 70.26560029 W 148.57719221 3573.86 21.45 208.29 3494.87 3550.73 174.83 214.33 194.54 - 187.78 -50.83 2.25 5948745.53 675956.23 N 70.26557858 W 148.57722687 3598.86 22.04 208.08 3518.09 3573.95 183.86 223.59 203.58 - 195.95 -55.21 2.38 5948737.27 675952.05 N 70.26555628 W 148.57726223 3623.86 22.60 208.31 3541.21 3597.07 193.11 233.08 212.86 - 204.32 -59.69 2.27 5948728.80 675947.76 N 70.26553341 W 148.57729850 3648.86 23.57 208.32 3564.21 3620.07 202.67 242.88 222.45 - 212.95 -64.34 3.88 5948720.06 675943.32 N 70.26550984 W 148.57733609 3673.86 24.11 208.32 3587.08 3642.94 212.52 252.99 232.36 - 221.84 -69.14 2.16 5948711.06 675938.73 N 70.26548554 W 148.57737484 3698.86 24.93 208.44 3609.82 3665.68 222.64 263.36 242.55 - 230.97 -74.07 3.29 5948701.82 675934.02 N 70.26546060 W 148.57741471 3723.86 25.71 208.45 3632.42 3688.28 233.07 274.06 253.07 - 240.37 -79.16 3.12 5948692.30 675929.15 N 70.26543492 W 148.57745588 3748.86 26.32 208.46 3654.89 3710.75 243.77 285.02 263.87 - 250.01 -84.38 2.44 5948682.54 675924.15 N 70.26540858 W 148.57749811 3773.86 27.33 208.50 3677.20 3733.06 254.77 296.30 274.99 - 259.93 -89.76 4.04 5948672.50 675919.00 N 70.26538149 W 148.57754160 3798.86 27.99 208.37 3699.34 3755.20 266.09 307.91 286.45 - 270.13 -95.29 2.65 5948662.17 675913.72 N 70.26535361 W 148.57758628 3823.86 28.83 208.38 3721.33 3777.19 277.69 319.80 298.20 - 280.60 - 100.94 3.36 5948651.58 675908.31 N 70.26532502 W 148.57763198 3848.86 29.71 208.41 3743.14 3799.00 289.61 332.03 310.29 - 291.35 - 106.76 3.52 5948640.69 675902.75 N 70.26529564 W 148.57767897 3873.86 30.45 208.57 3764.77 3820.63 301.84 344.56 322.69 - 302.36 - 112.73 2.98 5948629.55 675897.03 N 70.26526556 W 148.57772729 3898.86 31.34 208.81 3786.22 3842.08 314.37 357.39 335.40 - 313.62 - 118.90 3.59 5948618.14 675891.14 N 70.26523479 W 148.57777711 3923.86 31.79 208.85 3807.52 3863.38 327.16 370.48 348.37 - 325.09 - 125.21 1.80 5948606.54 675885.10 N 70.26520347 W 148.572 3948.86 32.75 209.08 3828.66 3884.52 340.20 383.83 361.59 - 336.77 - 131.67 3.87 5948594.71 675878.91 N 70.26517157 W 148.577 8 3973.86 33.37 209.20 3849.61 3905.47 353.54 397.46 375.11 - 348.68 - 138.31 2.49 5948582.65 675872.55 N 70.26513903 W 148.57793406 3998.86 33.99 209.29 3870.42 3926.28 367.11 411.33 388.85 - 360.77 - 145.08 2.49 5948570.40 675866.06 N 70.26510598 W 148.57798882 4023.86 34.73 209.30 3891.06 3946.92 380.91 425.44 402.85 - 373.08 - 151.99 2.96 5948557.94 675859.44 N 70.26507236 W 148.57804463 4048.86 35.63 209.17 3911.49 3967.35 395.01 439.84 417.15 - 385.65 - 159.02 3.61 5948545.21 675852.71 N 70.26503803 W 148.57810150 4073.86 36.37 208.89 3931.71 3987.57 409.37 454.54 431.75 - 398.50 - 166.15 3.03 5948532.20 675845.88 N 70.26500292 W 148.57815914 4098.86 36.55 208.94 3951.82 4007.68 423.89 469.39 446.52 - 411.50 - 173.34 0.73 5948519.03 675839.00 N 70.26496740 W 148.57821721 4123.86 36.81 208.83 3971.87 4027.73 438.48 484.33 461.37 - 424.58 - 180.55 1.07 5948505.79 675832.10 N 70.26493167 W 148.57827552 4148.86 37.01 208.85 3991.86 4047.72 453.15 499.34 476.31 - 437.73 - 187.79 0.80 5948492.47 675825.16 N 70.26489574 W 148.57833407 4173.86 37.15 208.85 4011.80 4067.66 467.88 514.41 491.31 - 450.93 - 195.07 0.56 5948479.10 675818.20 N 70.26485967 W 148.57839286 4198.86 37.33 208.83 4031.71 4087.57 482.66 529.54 506.38 - 464.18 - 202.36 0.72 5948465.68 675811.22 N 70.26482347 W 148.57845186 4223.86 37.46 208.78 4051.57 4107.43 497.49 544.72 521.50 - 477.49 - 209.68 0.53 5948452.21 675804.21 N 70.26478712 W 148.57851099 4248.86 37.36 208.76 4071.43 4127.29 512.33 559.91 536.63 - 490.80 - 216.99 0.40 5948438.73 675797.22 N 70.26475075 W 148.57857008 4273.86 37.51 208.79 4091.28 4147.14 527.17 575.11 551.77 - 504.12 - 224.30 0.60 5948425.25 675790.22 N 70.26471436 W 148.57862922 SurveyEditor Ver SP 2.1 Bld( users) 07- 23 \07- 23 \07- 23B \07 -23B Generated 2/17/2010 10:51 AM Page 2 of 5 Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub-Sea TVD TVD Closure DLS Northing Easting Latitude Longitude • Depth True Section Departure True North True North (ft) (deg) I (deg) I (ft) (ft) _ (ft) (ft) I (ft) (ft) (ft ) I (deg/100ft ) (ftUS) (ftUS) 4298.86 37.53 208.78 4111.11 4166.97 542.04 590.34 566.94 - 517.46 - 231.64 0.08 5948411.74 675783.20 N 70.26467790 W 148.57868848 4323.86 37.49 208.80 4130.94 4186.80 556.91 605.56 582.12 - 530.81 - 238.97 0.17 5948398.23 675776.18 N 70.26464146 W 148.57874775 4348.86 37.63 208.83 4150.76 4206.62 571.80 620.80 597.31 - 544.16 - 246.31 0.56 5948384.71 675769.15 N 70.26460498 W 148.57880712 4373.86 37.61 208.78 4170.56 4226.42 586.70 636.06 612.52 - 557.53 - 253.66 0.15 5948371.17 675762.11 N 70.26456844 W 148.57886656 4398.86 37.80 208.80 4190.34 4246.20 601.64 651.35 627.77 - 570.93 - 261.03 0.76 5948357.60 675755.07 N 70.26453184 W 148.57892609 4423.86 37.93 208.84 4210.07 4265.93 616.63 666.69 643.08 - 584.38 - 268.43 0.53 5948343.99 675747.99 N 70.26449511 W 148.57898588 4448.86 37.96 208.77 4229.79 4285.65 631.65 682.07 658.41 - 597.85 - 275.83 0.21 5948330.35 675740.90 N 70.26445831 W 148.57904576 4473.86 38.04 208.77 4249.49 4305.35 646.68 697.46 673.76 - 611.34 - 283.24 0.32 5948316.69 675733.81 N 70.26442145 W 148.57910564 4498.86 37.76 208.73 4269.22 4325.08 661.68 712.81 689.09 - 624.80 - 290.63 1.12 5948303.06 675726.74 N 70.26438466 W 148.57916535 4523.86 37.93 208.75 4288.96 4344.82 676.66 728.15 704.39 - 638.25 - 298.00 0.68 5948289.44 675719.68 N 70.26434792 W 148.57922496 4548.86 38.12 208.71 4308.65 4364.51 691.70 743.55 719.76 - 651.75 - 305.41 0.77 5948275.77 675712.60 N 70.26431103 W 148.57928480 4573.86 37.91 208.75 4328.35 4384.21 706.73 758.95 735.13 - 665.26 - 312.81 0.85 5948262.10 675705.51 N 70.26427414 W 148.57934463 4598.86 37.77 208.65 4348.09 4403.95 721.71 774.29 750.44 - 678.71 - 320.17 0.61 5948248.48 675698.46 N 70.26423739 W 148.57940416 4623.86 37.89 208.62 4367.84 4423.70 736.67 789.62 765.74 - 692.17 - 327.52 0.49 5948234.85 675691.43 N 70.26420062 W 148.579 6 4648.86 37.55 208.51 4387.61 4443.47 751.60 804.91 781.01 - 705.60 - 334.83 1.39 5948221.25 675684.44 N 70.26416392 W 148.57 7 4673.86 37.31 208.36 4407.46 4463.32 766.42 820.11 796.19 - 718.96 - 342.07 1.03 5948207.73 675677.52 N 70.26412742 W 148.57958116 4698.86 37.49 208.33 4427.32 4483.18 781.23 835.29 811.35 - 732.32 - 349.28 0.72 5948194.20 675670.62 N 70.26409091 W 148.57963943 4723.86 37.58 208.36 4447.15 4503.01 796.08 850.52 826.57 - 745.73 - 356.51 0.37 5948180.63 675663.71 N 70.26405429 W 148.57969788 4748.86 37.27 208.48 4467.00 4522.86 810.90 865.72 841.74 - 759.09 - 363.74 1.27 5948167.10 675656.79 N 70.26401778 W 148.57975633 4773.86 37.48 208.45 4486.87 4542.73 825.70 880.89 856.90 - 772.43 - 370.97 0.84 5948153.60 675649.87 N 70.26398133 W 148.57981480 4798.86 37.66 208.47 4506.68 4562.54 840.58 896.14 872.12 - 785.83 - 378.24 0.72 5948140.03 675642.92 N 70.26394472 W 148.57987351 4823.86 37.69 208.51 4526.47 4582.33 855.48 911.42 887.38 - 799.26 - 385.52 0.15 5948126.44 675635.95 N 70.26390803 W 148.57993243 4848.86 37.67 208.51 4546.26 4602.12 870.39 926.70 902.65 - 812.69 - 392.82 0.08 5948112.84 675628.97 N 70.26387135 W 148.57999138 4873.86 37.67 208.52 4566.05 4621.91 885.30 941.97 917.91 - 826.12 - 400.11 0.02 5948099.25 675622.00 N 70.26383467 W 148.58005034 4898.86 37.54 208.51 4585.85 4641.71 900.19 957.23 933.15 - 839.52 - 407.39 0.52 5948085.68 675615.03 N 70.26379805 W 148.58010920 4923.86 37.50 208.52 4605.68 4661.54 915.04 972.46 948.36 - 852.90 - 414.66 0.16 5948072.14 675608.08 N 70.26376150 W 148.58016796 4948.86 37.46 208.55 4625.52 4681.38 929.89 987.67 963.55 - 866.26 - 421.93 0.18 5948058.61 675601.12 N 70.26372499 W 148.58022669 4973.86 37.49 208.60 4645.36 4701.22 944.73 1002.88 978.75 - 879.62 - 429.21 0.17 5948045.08 675594.16 N 70.26368849 W 148.58028550 4998.86 37.58 208.67 4665.19 4721.05 959.60 1018.11 993.96 - 892.99 - 436.50 0.40 5948031.55 675587.18 N 70.26365197 W 148.58034450 5023.86 37.83 208.71 4684.96 4740.82 974.53 1033.40 1009.24 - 906.40 - 443.84 1.00 5948017.97 675580.16 N 70.26361533 W 148.58040383 5048.86 38.13 209.21 4704.67 4760.53 989.57 1048.78 1024.60 - 919.86 - 451.29 1.72 5948004.34 675573.02 N 70.26357855 W 148.58046404 5073.86 38.47 209.82 4724.29 4780.15 1004.74 1064.28 1040.07 - 933.35 - 458.93 2.03 5947990.68 675565.71 N 70.26354172 W 148.584 5098.86 38.74 209.90 4743.83 4799.69 1020.04 1079.88 1055.64 - 946.87 - 466.69 1.10 5947976.98 675558.26 N 70.26350476 W 148.58 1 5123.86 38.86 209.96 4763.31 4819.17 1035.40 1095.54 1071.27 - 960.45 - 474.51 0.50 5947963.22 675550.76 N 70.26346767 W 148.580 9 5148.86 38.82 210.19 4782.78 4838.64 1050.79 1111.22 1086.92 - 974.02 - 482.37 0.60 5947949.48 675543.23 N 70.26343060 W 148.58071519 5173.86 38.71 210.40 4802.28 4858.14 1066.16 1126.87 1102.53 - 987.53 - 490.26 0.69 5947935.78 675535.65 N 70.26339367 W 148.58077902 5198.86 38.67 210.63 4821.79 4877.65 1081.52 1142.50 1118.12 - 1001.00 - 498.20 0.60 5947922.14 675528.03 N 70.26335689 W 148.58084315 5223.86 38.73 210.82 4841.30 4897.16 1096.89 1158.13 1133.71 - 1014.43 - 506.18 0.53 5947908.52 675520.36 N 70.26332018 W 148.58090770 5248.86 38.41 211.31 4860.85 4916.71 1112.24 1173.72 1149.25 - 1027.78 - 514.23 1.77 5947894.98 675512.63 N 70.26328371 W 148.58097271 5273.86 38.40 211.50 4880.44 4936.30 1127.54 1189.25 1164.72 - 1041.04 - 522.32 0.47 5947881.54 675504.85 N 70.26324749 W 148.58103812 5298.86 38.49 211.60 4900.02 4955.88 1142.87 1204.79 1180.21 - 1054.29 - 530.45 0.44 5947868.11 675497.03 N 70.26321130 W 148.58110386 5323.86 37.94 211.74 4919.66 4975.52 1158.12 1220.26 1195.62 - 1067.45 - 538.57 2.23 5947854.76 675489.22 N 70.26317534 W 148.58116949 5348.86 37.77 211.66 4939.40 4995.26 1173.26 1235.60 1210.91 - 1080.50 - 546.63 0.71 5947841.53 675481.47 N 70.26313968 W 148.58123465 5373.86 37.32 211.58 4959.22 5015.08 1188.28 1250.84 1226.09 - 1093.47 - 554.62 1.81 5947828.37 675473.79 N 70.26310424 W 148.58129920 5398.86 37.10 211.61 4979.13 5034.99 1203.19 1265.95 1241.16 - 1106.35 - 562.54 0.88 5947815.31 675466.17 N 70.26306906 W 148.58136322 5423.86 37.16 211.69 4999.06 5054.92 1218.07 1281.04 1256.20 - 1119.20 - 570.46 0.31 5947802.29 675458.56 N 70.26303396 W 148.58142722 5448.86 37.18 211.65 5018.98 5074.84 1232.97 1296.15 1271.25 - 1132.05 - 578.39 0.13 5947789.25 675450.93 N 70.26299884 W 148.58149132 SurveyEditor Ver SP 2.1 Bid( users) 07- 23 \07- 23 \07- 23B \07 -23B Generated 2/17/2010 10:51 AM Page 3 of 5 Measured Azimuth Vertical Along Hole NS EW Comments Depth Inclination True Sub-Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude ' (ft ) (deg) (deg) (ft) (ft ) (ft ) (ft) (ft) (ft) (ft) (deg1100ft) (ftUS) (ftUS) 5473.86 37.34 211.71 5038.88 5094.74 1247.90 1311.29 1286.34 - 1144.93 - 586.34 0.66 5947776.19 675443.28 N 70.26296365 W 148.58155557 5498.86 37.34 211.79 5058.76 5114.62 1262.86 1326.45 1301.45 - 1157.83 - 594.32 0.19 5947763.11 675435.61 N 70.26292842 W 148.58162006 5523.86 37.36 211.93 5078.63 5134.49 1277.83 1341.62 1316.57 - 1170.71 - 602.33 0.35 5947750.05 675427.91 N 70.26289322 W 148.58168477 5548.86 37.52 212.00 5098.48 5154.34 1292.83 1356.81 1331.72 - 1183.60 - 610.37 0.66 5947736.97 675420.17 N 70.26285800 W 148.58174980 5573.86 37.81 211.99 5118.27 5174.13 1307.91 1372.09 1346.94 - 1196.56 - 618.47 1.16 5947723.83 675412.38 N 70.26282260 W 148.58181521 5598.86 38.07 211.99 5137.99 5193.85 1323.09 1387.46 1362.26 - 1209.60 - 626.61 1.04 5947710.61 675404.54 N 70.26278699 W 148.58188103 5623.86 38.32 211.98 5157.63 5213.49 1338.35 1402.92 1377.67 - 1222.71 - 634.80 1.00 5947697.31 675396.66 N 70.26275116 W 148.58194721 5648.86 38.52 212.18 5177.22 5233.08 1353.69 1418.45 1393.16 - 1235.87 - 643.05 0.94 5947683.96 675388.72 N 70.26271520 W 148.58201390 5673.86 38.57 212.44 5196.77 5252.63 1369.08 1434.03 1408.68 - 1249.04 - 651.37 0.68 5947670.60 675380.71 N 70.26267923 W 148.58208119 5698.86 38.30 213.00 5216.36 5272.22 1384.45 1449.57 1424.16 - 1262.11 - 659.77 1.76 5947657.33 675372.61 N 70.26264351 W 148.58214908 5723.86 38.12 213.28 5236.00 5291.86 1399.76 1465.04 1439.55 - 1275.06 - 668.23 1.00 5947644.19 675364.47 N 70.26260813 W 148.58221741 Tie -In Survey 5748.86 37.96 213.47 5255.69 5311.55 1415.03 1480.44 1454.88 - 1287.92 - 676.70 0.79 5947631.13 675356.30 N 70.26257298 W 148.58228590 TOW (Blind) 5766.00 37.85 213.50 5269.21 5325.07 1425.46 1490.97 1465.36 - 1296.71 - 682.51 0.65 5947622.22 675350.69 N 70.26254899 W 148.58233286 BOW (Blind) 5783.00 38.25 210.24 5282.60 5338.46 1435.80 1501.45 1475.81 - 1305.60 - 688.04 12.05 5947613.20 675345.37 N 70.26252468 W 148.585 Inc +Trend 5796.15 38.96 209.86 5292.88 5348.74 1443.85 1509.65 1484.00 - 1312.71 - 692.15 5.69 5947606.00 675341.43 N 70.26250528 W 148.582 5 5891.36 33.91 207.07 5369.46 5425.32 1499.00 1566.17 1540.51 - 1362.35 - 719.16 5.58 5947555.74 675315.59 N 70.26236965 W 148.58262903 5987.32 27.70 204.26 5451.84 5507.70 1546.35 1615.29 1589.59 - 1406.56 - 740.53 6.64 5947511.04 675295.27 N 70.26224885 W 148.58280171 MWD +GMAG 6018.85 27.86 203.34 5479.74 5535.60 1560.38 1629.98 1604.25 - 1420.01 - 746.46 1.45 5947497.46 675289.65 N 70.26221212 W 148.58284963 6082.77 23.98 203.99 5537.22 5593.08 1587.02 1657.92 1632.12 - 1445.60 - 757.66 6.09 5947471.62 675279.05 N 70.26214221 W 148.58294016 6177.09 20.37 208.96 5624.56 5680.42 1621.39 1693.49 1667.67 - 1477.49 - 773.41 4.31 5947439.38 675264.06 N 70.26205509 W 148.58306743 6274.16 20.09 208.52 5715.64 5771.50 1654.17 1727.06 1701.23 - 1506.92 - 789.55 0.33 5947409.58 675248.61 N 70.26197468 W 148.58319787 6369.00 20.58 207.49 5804.57 5860.43 1686.26 1760.01 1734.19 - 1536.02 - 805.02 0.64 5947380.13 675233.82 N 70.26189518 W 148.58332290 6464.17 20.12 205.85 5893.80 5949.66 1718.30 1793.11 1767.27 - 1565.59 - 819.88 0.77 5947350.22 675219.66 N 70.26181439 W 148.58344297 6561.00 19.95 205.13 5984.77 6040.63 1750.24 1826.28 1800.42 - 1595.53 - 834.15 0.31 5947319.95 675206.09 N 70.26173259 W 148.58355834 6653.73 19.69 205.74 6072.01 6127.87 1780.51 1857.72 1831.84 - 1623.92 - 847.66 0.36 5947291.25 675193.26 N 70.26165501 W 148.58366746 6749.21 20.47 211.15 6161.69 6217.55 1812.46 1890.48 1864.59 - 1652.70 - 863.28 2.11 5947262.12 675178.31 N 70.26157638 W 148.58379372 6844.31 20.14 210.85 6250.88 6306.74 1844.94 1923.48 1897.53 - 1680.99 - 880.28 0.36 5947233.44 675161.98 N 70.26149910 W 148.58393108 6938.18 19.68 210.27 6339.14 6395.00 1876.36 1955.45 1929.45 - 1708.52 - 896.53 0.53 5947205.55 675146.37 N 70.26142389 W 148.58406244 7033.81 19.53 206.43 6429.23 6485.09 1907.64 1987.52 1961.52 - 1736.74 - 911.76 1.36 5947176.98 675131.81 N 70.26134679 W 148.58418553 7130.43 19.22 204.80 6520.38 6576.24 1938.51 2019.58 1993.55 - 1765.64 - 925.62 0.65 5947147.77 675118.63 N 70.26126783 W 148.58429752 7225.28 18.20 204.06 6610.21 6666.07 1967.65 2050.00 2023.93 - 1793.34 - 938.21 1.10 5947119.78 675106.69 N 70.26119216 W 148.58439924 7321.39 18.94 206.85 6701.32 6757.18 1997.11 2080.60 2054.51 - 1820.96 - 951.37 1.20 5947091.86 675094.18 N 70.26111669 W 148.584 1 7416.29 19.59 209.05 6790.91 6846.77 2027.59 2111.91 2085.81 - 1848.61 - 966.06 1.03 5947063.88 675080.15 N 70.26104115 W 148.58 5 7511.69 21.27 211.19 6880.30 6936.16 2060.28 2145.21 2119.07 - 1877.39 - 982.78 1.93 5947034.71 675064.10 N 70.26096250 W 148.58475943 7607.50 19.79 210.36 6970.03 7025.89 2093.32 2178.81 2152.62 - 1906.26 - 999.98 1.57 5947005.46 675047.58 N 70.26088364 W 148.58489841 7702.33 18.63 210.07 7059.58 7115.44 2123.96 2210.01 2183.79 - 1933.22 - 1015.69 1.23 5946978.14 675032.51 N 70.26080998 W 148.58502531 7797.94 18.85 200.74 7150.14 7206.00 2153.43 2240.66 2214.39 - 1960.88 - 1028.81 3.14 5946950.17 675020.04 N 70.26073439 W 148.58513136 7893.84 18.13 186.41 7241.13 7296.99 2180.22 2270.93 2243.70 - 1990.22 - 1035.97 4.79 5946920.68 675013.57 N 70.26065426 W 148.58518917 7989.85 18.50 178.36 7332.30 7388.16 2203.67 2301.06 2270.98 - 2020.29 - 1037.20 2.66 5946890.59 675013.04 N 70.26057209 W 148.58519909 8085.32 20.50 175.23 7422.29 7478.15 2226.42 2332.92 2298.50 - 2052.10 - 1035.38 2.36 5946858.84 675015.61 N 70.26048521 W 148.58518432 8180.79 19.08 176.02 7512.12 7567.98 2249.05 2365.24 2326.22 - 2084.32 - 1032.90 1.51 5946826.68 675018.83 N 70.26039716 W 148.58516429 8276.79 18.60 180.71 7602.98 7658.84 2271.77 2396.23 2353.61 - 2115.29 - 1032.00 1.65 5946795.75 675020.46 N 70.26031257 W 148.58515699 8371.57 17.99 180.74 7692.97 7748.83 2294.42 2425.98 2380.54 - 2145.04 - 1032.38 0.64 5946766.00 675020.78 N 70.26023130 W 148.58515999 8466.73 19.89 180.56 7782.97 7838.83 2317.90 2456.87 2408.56 - 2175.92 - 1032.73 2.00 5946735.12 675021.15 N 70.26014693 W 148.58516277 8563.11 21.46 176.78 7873.14 7929.00 2342.95 2490.88 2438.97 - 2209.92 - 1031.90 2.14 5946701.15 675022.78 N 70.26005404 W 148.58515603 8657.77 19.63 174.98 7961.78 8017.64 2366.34 2524.10 2468.04 - 2243.05 - 1029.53 2.04 5946668.08 675025.91 N 70.25996353 W 148.58513688 8753.92 20.95 176.24 8051.96 8107.82 2389.69 2557.44 2497.24 - 2276.29 - 1026.99 1.45 5946634.91 675029.23 N 70.25987272 W 148.58511631 SurveyEditor Ver SP 2.1 Bld( users) 07- 23 \07- 23 \07- 23B \07 -23B Generated 2/17/2010 10:51 AM Page 4 of 5 I Comments Measured Azimuth Vertical Along Hole NS EW Inclination Sub -Sea TVD TVD Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North (ft ) (deg) I (deg) (ft) Ik) (ft) (ft ) (ft ) (ft ) (ft ) (deg /100ft ) (ftUS) (ftUS) 8848.60 19.10 174.75 8140.92 8196.78 2412.36 2589.86 2525.71 - 2308.61 - 1024.47 2.03 5946602.66 675032.51 N 70.25978442 W 148.58509584 8943.52 18.75 173.30 8230.71 8286.57 2433.30 2620.64 2552.44 - 2339.23 - 1021.26 0.62 5946572.13 675036.43 N 70.25970078 W 148.58506994 9039.30 21.15 174.69 8320.73 8376.59 2455.54 2653.32 2580.92 - 2371.73 - 1017.87 2.55 5946539.72 675040.58 N 70.25961200 W 148.58504246 9134.63 20.56 175.32 8409.82 8465.68 2479.04 2687.25 2610.87 - 2405.53 - 1014.91 0.66 5946506.00 675044.33 N 70.25951964 W 148.58501852 7" Csg 9203.00 19.40 175.12 8474.07 8529.93 2495.29 2710.62 2631.59 - 2428.82 - 1012.96 1.70 5946482.77 675046.82 N 70.25945604 W 148.58500276 9210.85 19.27 175.09 8481.48 8537.34 2497.09 2713.22 2633.89 - 2431.41 - 1012.74 1.70 5946480.19 675047.10 N 70.25944896 W 148.58500097 9260.17 19.21 174.56 8528.04 8583.90 2508.32 2729.47 2648.28 - 2447.59 - 1011.28 0.37 5946464.04 675048.95 N 70.25940474 W 148.58498910 9358.78 18.65 175.78 8621.32 8677.18 2530.54 2761.46 2676.75 - 2479.47 - 1008.58 0.70 5946432.24 675052.39 N 70.25931767 W 148.58496726 9454.26 18.31 176.63 8711.88 8767.74 2551.95 2791.72 2704.00 - 2509.66 - 1006.57 0.45 5946402.10 675055.10 N 70.25923517 W 148.58495102 9546.25 18.07 176.21 8799.27 8855.13 2572.35 2820.44 2729.96 - 2538.32 - 1004.78 0.30 5946373.49 675057.56 N 70.25915687 W 148.58493651 9641.67 17.55 176.45 8890.11 8945.97 2593.05 2849.62 2756.38 - 2567.45 - 1002.91 0.55 5946344.42 675060.11 N 70.25907730 W 148.58492137 9736.55 16.94 177.51 8980.73 9036.59 2613.22 2877.75 2782.03 - 2595.54 - 1001.43 0.72 5946316.38 675062.25 N 70.25900057 W 148.58490933 9831.26 16.84 177.40 9071.35 9127.21 2633.11 2905.27 2807.25 - 2623.03 - 1000.20 0.11 5946288.92 675064.12 N 70.25892547 W 148.584 42 Last Survey 9920.81 16.71 179.15 9157.09 9212.95 2652.04 2931.11 2831.13 - 2648.86 - 999.42 0.58 5946263.12 675065.50 N 70.25885491 W 148.58 9 4 -1/2" Lnr 9965.00 16.71 179.15 9199.42 9255.28 2661.48 2943.82 2842.95 - 2661.56 - 999.24 0.00 5946250.42 675065.98 N 70.25882020 W 148.584 6 TD (Projected) 9967.00 16.71 179.15 9201.33 9257.19 2661.91 2944.39 2843.49 - 2662.14 - 999.23 0.00 5946249.85 675066.01 N 70.25881863 W 148.58489149 Survey Error Model: SLB ISCWSA version 24 * ** 3 -D 95.00% Confidence 2.7955 sigma Surveying Prog: MD From ( ft 1 MD To ( ft) EOU Freq Survey Tool Type Borehole -> Survey 0.00 29.06 Act -Stns SLB_ZERO -Depth Only 07 -23 -> 07 -23 29.06 29.86 Act -Stns SLB_CNSG +CASING -Depth Only 07 -23 -> 07 -23 29.86 5748.86 Act -Stns SLB_CNSG +CASING 07 -23 -> 07 -23 5748.86 5783.00 Act -Stns SLB_BLIND 07 -23B -> 07 -23B 5783.00 5987.32 Act -Stns SLB_INC +TREND 07 -23B -> 07 -23B 5987.32 9134.63 Act -Stns SLB_MWD +GMAG^^1 07 -23B -> 07 -23B 9134.63 9920.81 Act -Stns SLB_MWD +GMAG^ ^2 07 -23B -> 07 -23B 9920.81 9967.00 Act -Stns SLB_BLIND^^2 07 -23B -> 07 -23B Legal Description: Northing (Y) IftUS1 Easting (X) (ftUSI Surface : 3294 FSL 219 FEL S33 T11N R14E UM 5948934.44 676002.66 BHL : 631 FSL 1224 FEL S33 T11N R14E UM 5946249.85 675066.01 *Italicized stations are NOT used in position calculations. • SurveyEditor Ver SP 2.1 Bld( users) 07- 23 \07- 23 \07- 23B \07 -23B Generated 2/17/2010 10:51 AM Page 5 of 5 TREE= w 4- 1/16" 5000 • •SAFETY NOTES: Chrome Lnr & tbg. I WELLHEAD = CAMERON A%TUA TOR = DRLG DRAFT 07 -23B KB. ELEV = 57' BF. ELEV = 27.86 KOP = 5766' Max Angle = 39 @ 5100' Datum MD = 8851' ' I 2,073' H 4 -1/2" X NIP, ID = 3.813" Datum TVD = 8800' SS 5598' I- 9- 5/8 "x7" BKR Flex -Lock LNR HNGR & ZXP 110.94' PBR, ID = 7.37" 5598' ) LTP, ID = 6.151" 0 g GAS LIFT MANDRELS I13 -3/8" CSG, 72 #, L -80, ID= 12.347" 2490' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3747 3709 26 KGB2 DOME BK 16 01/26/10 3 6215 5716 20 KGB2 SO BK 20 01/26/10 2 7775 7184 19 KGB2 DMY BK 0 01/12/10 1 8795 8146 20 KGB2 DMY BK 0 01/12/10 ITOP OF WHIPSTOCK 5761 - ;' .:44--•••=,;.,:: L'. - y , \ Z-1- 6282' I-I XO VAMTOP HC Box x TCII Pin Mg 1:4 Minimum ID = 3.725" @ 9010' N 4 -1/2" HES 'XN' NIPPLE 11 8873' H 4 -1/2" X NIP, ID= 3.813° i i 8906' 1-1 7 "x4 -1/2" BKR S -3 PKR, ID = 3.850"1 :::J -1 4 -1/2" OTIS NIID = 313 4 -1/2" XN NIP, ID = 3.725" I I X111111. 111111111 9021' L 4 -1/2" TBG, 12.6 #, 13Cr -80, Vam Top, 11111111 ••••••••1 ID = 3.958" 11 r�1/111111 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 9021' H WLEG I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9850' •���������• 9016' H 11.16' TBR ID = 5.250" ID I 9033' 7 "x5" BKR Flex -Lock LNR HNGR 7" LNR, 26 #, L -80 ID = 6.276" H 9204' I & ZXP LTP, ID = 3.85" DRIFT PERFORATION SUMMARY REF LOG: MWD MAD PASS GR/RES ON 01/12/10 ANGLE AT TOP PERF: 17° @ 9710' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 9710 - 9728c 0 02/02/10 3 -3/8" 6 9728 - 9748 0 01/28/10 I PBTD I—I 9878' 1 /•t•t•v• / 1 1 1 1 1 1 1 1 1 1 1 4 -1/2" LNR, 12.6 #, 13Cr -80, Vam Top, ID = 3.958" H 9965' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/07/87 ORIGINAL COMPLETION 08/23/06 JCM/PAG GLV C/O WELL: 07 -23B 10/02/94 RWO (SCAB LNR) 01/14/10 N7ES SIDETRACK (07 -23B) PERMIT No: 198 -089 05/27/98 CTD SDTRCK 01/30/10 TLH DRLG HO CORRECTIONS API No: 50- 029 - 21635 -02 09/26/01 RN/TP CORRECTIONS 01/30/10 RPC/TLH GLV C/O (01/26/10) SEC33 T11 N R14E 33 2951.54 FEL 4462.7 FNL 07/05/05 DRS /TLH 1994 SCAB LNR CORRECTION 02/03/10 JMF /PJC PERFS (01/28- 02/02/10) 05/30/06 DTM WELLHEAD CORRECTION BP Exploration (Alaska) 07 -23B (209 -145) - BOP Test Ext nsion Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, January 12, 2010 9:00 AM To: 'Mallery, Joshua' Subject: RE: 07 -23B (209 -145) - BOP Test Extension Joshua, Your request makes operational sense. Since the wellbore is isolated from the formation and has been pressure tested the BOP test can be postponed. You are granted an extension from BOP testing to finish running the tubing completion as per our conversation this morning. Regards, Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Mallery, Joshua [mailto:Joshua.Mallery@BP.com] Sent: Tuesday, January 12, 2010 8:52 AM To: Schwartz, Guy L (DOA) Subject: 07 -23B (209 -145) - BOP Test Extension Guy, The status of 07 -23B sidetrack is that the 7" liner and 4.5" liner have both been set and tested to 3500 psi. The well is isolated from open hole and is intended to be perforated post rig. The rig is currently running 4.5" tubing and forecasts to nipple down the BOPs 1/13/10 at 00:30. The rig is due to commence a BOP test prior to 1/12/10 at 23:59. Due to the fact that the well has a passing MIT test to 3500 psi, BP requests a 24 hour extension on the BOP test. This extension will allow the rig to nipple down the BOPs and move off of the well before the test is due. Thanks, Joshua Mallery BPX (Alaska) Drilling Engineer 907.564.5545 (Office) 907.244.4351 (Cell) Joshua.Mallery@bp.com 1/12/2010 • 9 �} t4 t si �E p SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMDIISSIONT 1 ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Mr. Greg Hobbs Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07 -23B BP Exploration (Alaska) Inc. Permit No: 209 -145 Surface Location: 1986' FNL, 219' FEL, SEC. 33, T11N, R14E, UM Bottomhole Location: 612' FSL, 1230' FEL, SEC. 33, T11N, R14E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). incerely, Daniel T. Seamount, Jr. Chair DATED this 17 day of November, 2009 cc: Department of Fish 85 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALA IL AND GAS CONSERVATION COMM RECEIVED � STATE OF ALASKA S ON //- 6-0 PERMIT TO DRILL NOV 1 3 1009 20 AAC 25.005 Oiip k§ it t�Cons. cot n issior - 1 a. Type of work: 1 b. Proposed Well Class: ® Development Oil ❑ Service - Winj ❑ Single Zone p a 1 we I is prop se or: ❑ Drill ®Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed M i t t s Hydrates ❑ Re -Entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU 07 -23B 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 9966' TVD 9251' Prudhoe Bay Field / Prudhoe 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): Bay Oil Pool Surface: ADL 028309 1986' FNL, 219' FEL, SEC. 33, T11N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 804' FSL, 1240' FEL, SEC. 33, T11N, R14E, UM December 15, 2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 612' FSL, 1230' FEL, SEC. 33, T11N, R14E, UM 2560 22065' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 57' feet 15. Distance to Nearest Well Open Surface: x- 676003 y- 5948934 Zone- ASP4 GL Elevation above MSL: 26.82' feet to Same Pool: 920' 16. Deviated Wells: Kickoff Depth: 5700 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 38.61 degrees Downhole: 3240 Suffice: 2360 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8 -1/2" 7" 26# L -80 TC- III BTC -M 3679' 5550' 5160' 9229' 8559' 294 sx LiteCrete. 157 sx Class 'G' ' 6 - 1/8" 4 - 1/2" 12.6# 13Cr - Vam Top 887' 9097' 8418' 9966' 9251' 119 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 10664' 9050' 9253' 9253' 8217' None Casing Length Size Cement Volume MD TVD Conductor / Structural 80' 20" 1900# Poleset 80' 80' • Surface 2490' 13 -3/8" 200 sx CS III, 550 sx CS II 2490' 2490' ' Intermediate 9852' 9 -5/8" 700 sx Class 'G'. 300 sx CSI 9852' 8646' Production Liner 1117' 2 - 7/8" 48 sx Class 'G' w/ Latex 9547' - 10664' 8417' - 9050' Scab Liner 344' 7 - 5/8" Uncemented 5902' - 6246' 5430' - 5704' Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments: ❑ Property Plat ❑ BOP Sketch -! Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report Drilling Fluid Program ® 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing ' true and correct. Contact Frank Roach, 564 -4373 Printed Name Greg �- Title Eng ineering Team Leader J / Prepared By Name /Number Signature , / Phone 564 -4191 Date /'j / /. /O S ondra Stewman, 564 -4750 / Commission Use Only Permit To Drill f API Number: Permit ovall at See cover letter for Number: ,c 50- 029 - 21635 -02 -00 fle 7 / 0 41 other requirements coal h Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce co methane, gas hydrates, or g as contained shales: Er e 3 500 P is.: The Other. r kSi- Samples Req'd: Oyes 110 No Mud Log Req'd: ❑yes �No 4k 25 . An....1.,. ✓ -7-.54 ( ,4) HA Measures: kff Yes ❑ No Directional Survey Req'd: (Yes ❑ No APPROVED BY THE COMMISSION se: 1//17Y Date , COMMISSIONER Form 10-401 Revised 07 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit In Duplicate • To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Frank Roach - ODE Date: November 10, 2009 0 b p Re: PBU 07 -23B Permit to Drill Approval is requested for the drilling of the 07 -23B Ivishak sidetrack. For the planned drilling of this well, an 8 -1/2" intermediate hole will then be drilled from a KOP in the 9 -5/8" casing at -5700' MD into the top of the Sag River formation -9,230' MD where a 7 ", 26.0# intermediate drilling liner will run and fully cemented. A 6 -W production hole will then be drilled targeting Zone 2 sands which will be drilled to the final well TD at -9,966' MD where a 4 -'/2 ", 12.6 #, chrome production liner will be run and fully cemented. The planned completion for this well will include a 4 -'/2 ", 12.6 #, chrome tubing string with 4 gas lift mandrels and a permanent production packer. This well is currently scheduled for Doyon 14 beginning -12/15/09. Please refer to the additional data within this request for specific well details and do not hesitate to call if additional information is required. Frank Roach - ODE Office - 564 -4373 Cell - 244 -1674 04 -33A Sidetrack Page 1 07'23B Planned Well Summmv Well 07 -23B T ype Sidetrack Objective ve Ivishak API Number: 50- 029 - 21635 -02 1 Current Status Shut -In Estimated Start Date: 15- Dec -2009 Time to Complete: 14.7 Days Surface Northing Easting Offsets TRS Location 5,948,934 676,003 3294' FSL / 219' FEL 11N, 14E, 33 Northing Easting TVDss Offsets TRS TSAD 5,946,422 675,045 -8658 804' FSL / 1241' FEL 11N, 14E, 33 Bottom Northing Easting TVDss Offsets TRS Location 5,946,230 675,060 -9190 612' FSL / 1230' FEL 11N, 14E, 33 Planned KOP: 5700'MD / 5213'TVDss Planned TD: 9,965'MD / 9,190' TVDss Rig: 1 Doyon 14 GL: 26.8' RTE: 61.1' Directional — Halliburton (Sperry) WPO4A KOP: 1 5700' MD Maximum Hole Angle: -38 in the 8 -1/2" intermediate section -19 in the 6 -1/8" production section Close Approach Wells: No anti - collision issues with this directional plan. Survey Program: Standard MWD +IIFR +MS Nearest Property Line: 22,065' to Southern IPA Boundary Nearest Well within Pool: 920' to 07 -11 V III 04 -33A Sidetrack Page 2 • Current Well Information 1 Well Name: 07 -23A API Number: 50- 029 - 21635 -01 PTD: 1980890 Well Type: Producer Current Status: Shut in BHP: 3240 psi @ 8800' TVDss (7.1 ppg) BHT: 210° F @ 8800' TVDss Mechanical Condition: Tubing: See current schematic for detail. Tubing of interest is 4 -1/2 ", 12.6 #, L -80, NSCT to 9480' (pre -rig tubing cut at -5862' MD.) " TD / PBTD: 10,664' MD / P &A to -9,253' MD during pre -rig P &A work Max Dogleg (to P &A): 4.8 °/100' @ 3000' MD Max Angle (to P &A): 49° @ 9400' MD Wellhead Equipment: Cameron Gen 4 Starting Head: 13 -5/8" 5000 psi with 2-1/16" outlet valve Tbg. Spool: 13 -5/8" 5000 psi x 11" 5000 psi Tbg. Hanger: 11" x 5 -1/2" NFBB w/5 -1/2" LTC lifting threads Csg. Hanger: 9 -5/8" set on emergency slips Tbg. Head Adapter: 11" 5K x 5 -1/8" 5K Tree: Cameron 5 -1/8" bore x 7- 1/16" flange w/7" tree cap BPV Profile: Cameron 5" Type H Completion Equipment: SSSV Landing Nipple: 4 -1/2" Camco TRDP -4A SSSV Control line: 1 - .25" Stainless Gas Lift Mandrels: See current schematic Control line bands /clamps: 50 SS Bands Casing Equipment: Surface Casing: 13 -3/8 ", 72 #, L -80 to 2490' MD 13 -3/8" Cement: cement to surface Intermediate Casing: 9 -5/8 ", 47 #, L -80 to 9,850' MD (CTD sidetrack window) 9 -5/8" Cement: Pumped 193 bbls of Class G cmt (-3355' of gauged hole = TOC at 7,199' MD) Tubing Fluids: seawater w /2000' diesel cap IA Fluids seawater w /2000' diesel cap OA Freeze Protection 13 -3/8" x 9 -5/8" pumped 115 bbls of Arctic Pack down annulus - 50 bbls "Cold Set I" downsqueezed ahead of the Arctic Pack (TOC at 1979' MD) Perforations: P &A'ed w /cement tested to 3500 psi (TOC tagged @ 9253' SLM) Pre -Rig MIT Data: MIT -OA PASS 2000 psi CMIT -TxIA PASS 1000 psi (Post -jet cut) PPPOT -T PASS 5000 psi PPPOT -IC PASS 3500 psi 04 -33A Sidetrack Page 3 Formation Markers 07B (Based on SOR) Commercial Th th.ac on Est Formation Zaps Uncertainty .inty Baring, Est Pore Press. Formation tl i �s ,, set,+ _ t2 Vo, (Psi) NOTE: All formation tops are required from 1000' above proposed !OP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells UG4 -4382 40' No UG3 4625 -i0' No 1:G1 -5034 40' No KOP @5770 MD WS2 -5695 40' No WS1 -5905 40' Na 0113 -5100 4D° CM2 -6626 40' No C3,11 - 40' No THRZ -7635 4D` No BHRZ '79 40' Na LCL: - 40' No TJD -7955 S0` tie TJC -8159 40' No TJB -8303 40' No TJA -S405 40' No -839S ISGR 30' Yes TSHC -8525 30' Yes TSAD -3605 30' Yes 42SB -8 3D` Yes TCGL -r92 3D' Yes 324 psi BCGL -8361 30' 23SB -3915 30' Yes PGOC -S920 30' 22TS -8975 30' Yes HOT -8980 30' :ITS -9029 3D' Yes TZ1B -9102 30' Yes TDF -9141 30' Yes BS - AD - 9185 30' No Casing/Tubing Program Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg (psi) (psi) MD/TVD MD/TVD O.D. 8 - 7" 26# L -80 TC -II 7,240 5,410 1,450' 5,550' / 7,000' / 5160' 6,461' 7,000' / 9,229' / 7" 26# L -80 BTC -M 7240 5,410 2,229' ,. 8,461' 8,559' 6 -1/8" 4 12.6# 13Cr -80 Vam Top 8,430 7,500 887' 9079' / 9,966' / 8,418' 9,251' Tubing 4 12.6# 13Cr -80 Vam Top 8,430 7,500 9,079' surface 9,079' / 8,418 04 -33A Sidetrack Page 4 Mud Program Intermediate Mud Properties: LSND 1 8 -1/2" hole section Depth Interval Density (ppg) PV YP API FL HTHP FL MBT PH KOP — THRZ 9.8 10-18 18 - 28 < 6 N/C <18 9 —10 THRZ- 8 -1/2" 10.0 ' 12 -22 18 -28 4 -6 <10.0 <20 9 -10 TD Production Mud Properties: FLOPRO SF Reservoir Drill -in Fluid 1 6 -1/8" hole section Depth Interval Density (ppg) PV YP LSVR API Fl pH MBT 8 -1/2" TD — 8.4 — 8.5 6 -12 22 -28 >20,000 6.0 -8.0 9.0 -9.5 < 3 6 -1/8" TD Logging Program 8 -1/2" Intermediate: Sample Catchers — as required by Geology Drilling: Dir /GR/Res w /PWD Open Hole: None Cased Hole: CCL f /9 -%" whipstock set 6 -1/8" Production: Sample Catchers — as required by Geology Drilling: Drilling BHA — Dir /GR /Res /Neu /Density Open Hole: None Cased Hole: None Cement Program Casing Size: 7" 26 #, L -80 Intermediate Liner Lead: 2679' of open hole x 7" liner volume plus 40% from 1000' above the shoe back to the Basis: window + 150' of 9 -5/8" x 7" annulus + 200' of 9 -5/8" x 4" annulus. Tail: 1,000' of 7" x 8 -1/2" open hole with 30% excess, plus 80' shoe track. Total Cement Spacer 30 bbls of Viscosified Spacer weighted to 10.4 ppg (Mud Push 11) Volume: Lead 96.2 bbls, 294 sxs 11.0 ppq Litecrete cement - 1.84 cf /sk Tail _ 32.4 bbls, 157 sxs 15.8 lb/qal Class G + adds —1.16 cuft/sk Temp _ BHST = 203° F, BHCT TBD by Schlumberger Casing Size: 4 -1/2" Production Liner Basis: Lead: NONE Tail: 6 -1/8" x 4 -1/2" open hole volume (737' + plus 40% excess) + 80' of 4 -1/2" shoe track + 150' of 7" x 4 -1/2" annulus + 200' of 7" x 4" annulus. Total Cement Spacer None Volume: Lead None Tail -.24.6 bbls, 119 sxs 15.8 lb/gal Class G + gas block + other adds —1.16 cuft/sk Temp BHST = 210° F, BHCT TBD by Schlumberger 04 -33A Sidetrack Page 5 Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind /shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for 07 -23B will be 14 days during drilling phase and 7 days during decompletion work. Intermediate Interval Maximum anticipated BHP 2628 psi @ 5270' TVDss — UG1 (9.6 ppg EMW) Maximum surface pressure 2101 psi (.10 psi /ft gas gradient to surface) Planned BOP test pressure Rams test to 3,500 psi /250 psi. Annular test to 2,500 psi /250 psi 9 -s /e" Casing Test / 7" 3500 psi surface pressure Casing FIT to 11.9 ppg after drilling 20' from mid - window to satisfy ECD Integrity Test — 8- hole management concerns, however, a minimum 10.8 ppg FIT provides 79.2 bbls kick tolerance w /10.0 ppg mud in the hole. 7" Casing The VBR's will be changed to 7" rams to accommodate the 7" liner. Production Interval Maximum anticipated BHP 3240 psi @ 8800' TVDss — TSAD (7.1 ppg EMW) Maximum surface pressure 2360 psi (.10 psi /ft gas gradient to surface) Planned BOP test pressure Rams test to 3,500 psi /250 psi. Annular test to 2,500 psi /250 psi 7" Liner / 4 -1/2" Liner Test 3500 psi surface pressure Integrity Test — 6 -' /a" hole FIT to 10.5 ppg after drilling 20' of new hole to satisfy ECD management concerns, however, 8.8 ppg mud in the hole will provide an "infinite" kick tolerance. Planned completion fluids 8.5 ppg Seawater / 6.8 ppg Diesel 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 Class I waste to DS -04 and /or Pad 3 for disposal / Contact the GPB Environmental Advisors (659 -5893) f /guidance. Fault Prognosis There is one planned fault crossing in Zone 4 at —9475' MD (-8730' TVD). Expected losses associated with this fault are minimal. 04 -33A Sidetrack Page 6 • 07 -23B Operations Sulary Pre -rip prep work: W 1 Function tubing and casing LDS. Repair /replace as required. Perform PPPOT -IC to 3500psi and PPPOT -T to 5000psi. DONE 09/08/09 (IC failed again. Retested 9/11/09, re- energized secondary. IC packoff passed.) S 2 Run flapper checker to confirm SSSV is open. Drift tubing to top of liner at 9,547'. DONE 9/19/09 F 3 Confirm injectivity into the open perfs as required for P &A to follow. If injectivity is sufficient for fulibore P &A, proceed with step 4a, option 1. If not, contact ODE and proceed with step 4b. DONE 10/03/09. 5 bpm c 1200 psi. Good to go with fulibore P &A. F 4a "bullhead" 18.3bbl (10bb1 excess), 15.8ppg G cement to plug and abandon the current well perforations: Liner Size 6.5# 2 -7/8" (.00579 bpf) from 9,550' to 10,664' MD 9.3# 3 -1/2" (.00870 bpf) from 9,547' to 9,550' MD Tubing size (Lnr to XO) 17.0# 5 -1/2" (.02332 bpf) from 9,481' to 9,547' MD Tubing size (XO to TOC) 12.6# 4 -1/2" (.01520 bpf) from 9,450' to 9,481' MD Bottom of plug 10,631' MD Top of plug 9,450' MD Total Footage 1,181' ( -8.3 bbls) Top Perf 10,526' MD Bottom Perf 10,605' MD SBHP: 3240 psi SBHT: 210 °F DONE 10/10/09 (Est TOC -9450' MD) S 5 WOC. Drift to TOC. DONE 10/13/09 F 6 CMIT -TxIA to 3,500 psi. Pressure test is required for competent barrier for rig operations. If test fails, contact ODE. Freeze Protect as necessary. DONE 10/17/09 (PASS) E 7 Gyro well to 6000' MD. DONE 10/19/09 E/F 8 Punch tubing above 4 -1/2" x 5 -1/2" crossover at -9,480' MD (or as close to TOC as possible) (DONE 10/19/09) and circulate tubing and IA to clean seawater. DONE 10/20/09 Power Jet cut 4 -1/2" tubing at -5,850' MD (try to get cut -2' below a coupling to help with standoff from the intermediate casing). Establish circulation from the T to the IA. DONE 10/25/09 F 9 CMIT TxIA to 3,500 psi. DONE 10/26/09 (1000 psi) MIT -OA to 2,000 psi. DONE 10/20/09 If combo fails, contact ODE. D 10 Bleed casing and annulus pressures to zero. DONE 10/26/09 ✓ 11 Set a BPV. Remove well house and flow line. Level pad as necessary. Proposed Drilling Rig Operations: 1. MI /RU. 2. CMIT -TxIA to 2000 psi and MIT -OA to 2000 psi to confirm barriers (10 minute tests - expect both test to pass). 3. Pull BPV w /tested lubricator and circulate out diesel freeze protection and displace the well to seawater. 4. Set and re -test TWC to 1000 psi from below and 3500 psi from above for 10 minutes. 5. As there is path - forward wellhead work to be completed, begin the OA monitoring process (RU to bleeder tank). 6. Nipple down tree. Nipple up and test BOPE to 3500psi. Pull TWC w /tested lubricator. 7. R/U & pull 4'/2" tubing from the cut depth at 5850' MD. 8. Test lower set of rams if required. 9. PU drill -pipe and make bit and scraper run to the top of the tubing stub and test well to 3500 psi f /30 min and chart. (NOTE: If well does not test to 3500 psi, an RTTS will be RIH to isolate /locate the leak.) 10. Assuming a good pressure test in the previous step, RU E -line and RIH w /EZSV and CCL and set the EZSV at -5781' MD given the location of the nearest casing collar and re -test well to 3500 psi for 10 minutes. 11. Split stack and replace existing tubing spool with McEvoy SSH. 12. NU Wellhead /BOPE test breaks to 3500 psi. 04 -33A Sidetrack Page 7 13. P/U and RIH with 9 -%" r bottom -trip anchor whip stock assemblibrient whip stock and set on EZSV bridge plug at -5781' MD. Shear off of whip stock. 14. Displace the well to LSND based milling fluid per mud program. (End Work Under Sundry Approval #309 -319 / Begin Work Under PTD #xxx -xxx) 15. Mill window in 9 -%" casing at -5770' MD, plus approximately 30' of new hole beyond middle of window and circulate well -bore clean. 16. Pull up into 9 -%" casing and conduct a FIT. POOH. 17. M/U 8 -1" Dir /GR/Res /PWD assembly. RIH, kick off and drill the 8 -'h" intermediate section to the top Sag River target at -9,200' MD, per directional plan. 18. Circulate, short trip and POOH to run the 7" drilling liner (manage drill -pipe as required). 19. Run and cement a 7 ", 26.0 #, L -80, TC -I1 intermediate drilling liner (fully cemented liner w / -150' liner lap to 5,620' MD TOL). 20. After cement has reached a minimum 500 psi compressive strength, test the 9 -%" casing X 7" liner to 3,500psi for 30 minutes and record the test. 21. M/U 6 -W motor assembly w /Dir /GR/Res /Neu /Den + insert bit to drill -out the shoe track, displace to the well to the planned drill -in fluid, drill 20' of new hole and run FIT. 22. Drill ahead per the directional plan to TD at -9960' MD. 23. Circulate, short trip, spot liner running pill. POOH to run the production liner. 24. Run and fully cement a 4 -'h ", 12.6 #, Vam Top, chrome production liner. 25. After cement has reached a compressive strength of 500 psi, test the well to 3500 psi f /30 minutes and chart. 26. POOH L/D all drill pipe. 27. R/U and run 4-1/2", 12.6 #, 13 Cr -80, VamTop completion tubing. 28. Land the tubing RILDS. 29. Reverse the well to clean seawater to include inhibited seawater to the production packer depth per the plan. 30. Drop ball & rod and set packer and individually test the tubing and annulus to 3,500psi 30 minutes and record each test. 31. Shear the DCK valve and pump each way to confirm shear. 32. Set a TWC and test to 1000 psi from above and below. 33. Nipple down the BOPE. Nipple up the tree and test to 5,000psi with diesel (new adapter flange required). 34. Pull TWC w /lubricator. 35. Freeze protect the well to 2,200' TVD with diesel. 36. Install BPV and secure the well. 37. Rig down and move off. Post -Rig Operations: (S -Riser Modification will be Required) 1. MI / RU slick line. 2. Pull the ball and rod / RHC plug from landing nipple below the production packer. 3. MIRU E -line and perforate production interval zone of interest. 4. Install gas lift valves. 5. Install well house and instrumentation. 04 -33A Sidetrack Page 8 Drillin Hazards and Contingincies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. With the KOP for the 8 -1/2" hole in the UG1 and an un- cemented annuls behind the existing 9 -5/8" casing, injection pressures up to 9.6 ppg may be encountered (planned minimum mud weight = 9.8 ppg = -60 psi over - balance). B. For the production interval of the well, the pore pressure of the Ivishak should be in the 7.1 ppg range (planed minimum mud weight = 8.5 ppg) II. Lost Circulation/Breathing A. For the 8 -1/2" intermediate hole, the lost circulation /breathing potential should be minimized due to the relative low mud weight which will be used to drill this interval of the well (10.1 ppg f /top HRZ). However, as there may be no cement behind the 9 -5/8" casing at the KOP and given the potential for a "weak" zone within the Colville to be present below the KOP, lost circulation /breathing problems must be considered a possibility. B. As for the production interval of the well, lost circulation in the Ivishak formation is usually fault related and as there are no planned faults through this interval of the well, the lost circulation potential while drilling this interval of the well has been rated "low ". Please refer to the MI mud program for details as they relate to dealing with lost circulation problems while drilling this interval of the well. III. Kick Tolerance/Integrity Testing Test Point Test Depth Test type EMW (Ib/gal) 9 -%" window 20 -ft minimum from the 9 -%" window FIT 10.8 ppg min f /KT 11.9 ppq max f /ECD Mqt 7" shoe 20 -ft minimum from the 7" shoe FIT Infinite w/ 8.8ppg mud 10.5 ppq max f /ECD Mqt IV. Stuck Pipe A. For the 8 -1/2" intermediate interval of the well, insufficient/poor hole cleaning support resulting in stuck pipe will be of primary concern. B. For the 6 -1/8" production interval of the well, both differential sticking and sticking as associated with insufficient/poor hole cleaning should be of primary concern. VI. Hydrogen Sulfide With H2S levels below the 100 ppm threshold (with the exception of one reading noted on 07 -13A), DS -07 is not considered an H2S pad (see below). Follow all RP recommendations as required for working within this environment. Date of Well Name H2S Level Reading #1 Closest SHL Well H2S Level 07 -24 22 ppm 6/2/2008 #2 Closest SHL Well H2S Level 07 -25A 20 ppm 10/1/2008 #1 Closest BHL Well H2S Level 07 -22 20 ppm 8/25/2008 #2 Closest BHL Well H2S Level 07 -11A 14 ppm 5/29/2008 Max. Recorded H2S on Pad/Facility 07 -13A 150 ppm 7/21/1993 Other Relevant H2S Data DS 7 is not a H2S pad; levels are generally <30 ppm (H2S alarms from rigs, etc.) VII. Faults There are no visible fault crossings associated with this wellplan/directional plan. VIII. Anti - Collision Issues There are no anti - collision issues associated with the directional plan for this well as all near -by wells pass Major risk. CONSULT THE DS -04 DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 04 -33A Sidetrack Page 9 Project: Prudhoe Bay bp COMPANY DETAILS: BP - Alaska REFERENCE INFORMATION Site: PB DS 07 HALLIBURTON NORTH AMERICA Co-ordinate (N /E) Reference: Well 07 -23, True North Well: 07 -23 ALASKA Vertical (TVD) Reference: 07 -23B D -14 @ 61.1ft Wellbore: Plan 07 -23B Sperry Drilling Services Measured Depth Reference: 07-23B D -14 @ 61.tft calculation Method: Minimum Curvature Calculation Method: Minimum Curvature Plan: 07 -23B Wp04a (07- 23/Plan 07 -23B) Error System: ISCWSA Scan Method: Tray. Cylinder Nort 1p WELL DETAILS: 07 -23 Error Surface: Elliptical Conic Ground Level: 26.8 CASING DETAILS Waming Method: Rules Based +N / -S +E / -W Northing Easting Latittude Longitude Slot DDI = 6.14 TVD MD Name Size 0.0 0.0 5948934.44 676002.6670"1557.9301848"3436.537W 2494.0 2494.1 13 3/8" 13 -3/8 ERD = 0.32 5274.2 5700.0 9 5/8" 9 -5/8 WELLBORE TARGET DETAILS (MAP CO-ORDINATES) 8559.1 9229.5 7" 7 Name Northing 9251.0 9965.5 4 -1/2" 4-1/2 TVD +N / -S +E/ -W g Easting Shape 07 -23B Tgt Sag 8559.1 - 2431.4 - 1019.8 5946480.00 675040.00 Rectangle (Sides: L40.0 W40.0) 07 -23B Flt 1 8730ss 8791.1 - 1566.0 - 1239.7 5947340.00 674800.00 Polygon -640 - 07 -23B Flt 2 8845ss 8906.1 - 1734.5 - 1518.7 5947165.00 674525.00 Polygon - 07 -23B F1t3 9090ss 9151.1 - 2063.1 -941.2 5946850.00 675110.00 Polygon 07 -23B Tgt Poly 9251.1 - 2681.8 - 1005.7 5946230.00 675060.00 Polygon -800 - 450 SURVEY PROGRAM - Date: 2009.11- 09700:00:00 Validated: Yes Version: -960 - Depth From Depth To Survey /Plan Tool 104.0 5679.1 Gyro (07 -23) GYD -CT -CMS 5679.1 9164.5 07 -23B Wp04a (Plan 07 -23B) MWD +IFR +MS -1120 _ 9 5/8" 50 0 0 Tie -In Survey 9164.5 9965.6 07 -236 Wp04a (Plan 07-23B) MWD +IFR +MS - 1280 - ° = _ _ _ - KOP 85 LFT Start DLS 12.00 TFO -85.00 SS c 0 Start Dir 12° /100' : 5700' MD, 5274.2'TVD - 1440 - 0 w - 07 -23B Flt 1 8730ss I _ Start Dir 4° /100' : 5720' MD, 5289.9'TVD o -1600 T 6 00 0 - _ + - 1 End Dir : 6193.6' MD, 5701.6' TVD 1 -1760 - 07 -23B Flt 2 8845ss."- t 1 1 63- 00 1 t 1 o -1920- 1 1 S tart Dir 4° /100' :7767.1' MD, 7183.4'TVD 1 1 1 End Dir : 8029.5' MD, 7430.9' TVD 1 t 2 • 080 1 1 7 1 1 - 1 1 07 -23B F1t3 9090ss -2240 1 t 1 1 8000 - 1 -2400- \\ \ 7 t 07 -23B Tgt Sag .,,,8500 - - - - - -2560 95% cont - - - - - -- 1 ' � SECTION DETAILS - 4 -1/2" ■ -2720. � Total Depth : 9965.6' MD, 9251.1' TVD Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target 07 -23B Tgt Poly \ - -' 1 5679.1 38.57 212.44 5257.9 - 1249.0 -651.4 0.00 0.00 1398.2 - 07 - 23/07 - 23A . 2 5700.0 38.34 212.91 5274.2 - 1260.0 -658.4 1.78 128.38 1410.9 3 5720.0 38.61 209.08 5289.9 - 1270.6 -664.8 12.00 -85.00 1423.2 2860 - -- Q'J 31 �7 07- 23/07 -23B Wp a 4 6193.6 19.67 208.09 5701.6 - 1472.0 -775.2 4.00 - 178.98 1650.4 l i i I j I F l � l , � i F 1 ill r r 1 1;11 I ji I I r 1 5 7767.1 19.67 208.09 7183.4 - 1939.3 - 1024.6 0.00 0.00 2175.6 -1760 -1600 -1440 -1280 -1120 -960 -800 -640 -480 -320 -160 6 8029.5 19.92 176.77 7430.9 - 2023.2 - 1042.9 4.00 - 103.47 2260.5 -1920 7 9229.5 19.92 176.77 8559.1 - 2431.4 - 1019.8 0.00 0.00 2634.7 07 -23B Tgt Sag West( - )/East( +) (400 ft/in) 8 9965.6 19.92 176.77 9251.1 - 2681.8 - 1005.7 0.00 0.00 2864.2 07 -23B Tgt Poly Project: Prudhoe Bay bp SURVEY PROGRAM Site: PB DS 07 CI HALLIBURTON Date: 2009-11-09T00:00:00 Validated: Yes Version: Well: 07 -23 Depth From Depth To Survey /Plan Tool Wel!bore: Plan 07 -23B Sperry Drilling Services 104.0 5679.1 Gyro (07 -23) GYD -CT -CMS Plan: 07 -23B Wp04a (07 -23 /Plan 07 -23B) 5679.1 9164.5 07 -238 Wp04a (Plan 07 -23B) MWD +IFR +MS 9164.5 9965.6 07 -23B Wp04a (Plan 07 -23B) MWD +IFR +MS REFERENCE INFORMATION SECTION DETAILS DDI = 6 Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target - Co- ordinate (N /E) Reference: Well 07 -23, True North 1 5679.1 38.57 212.44 5257.9 - 1249.0 -651.4 0.00 0.00 1398.2 ERD = 0.32 Vertical (TVD) Reference: 07 -23B D -14 @ 61 tft 2 5700.0 38.34 212.91 5274.2 - 1260.0 -658.4 1.78 128.38 1410.9 3500- Measured Depth Reference: 07 -23B D -14 @ 61.1ft 3 5720.0 38.61 209.08 5289.9 - 1270.6 -664.8 12.00 -85.00 1423.2 Calculation Method: Minimum Curvature 4 6193.6 19.67 208.09 5701.6 - 1472.0 -775.2 4.00 - 178.98 1650.4 - 5 7767.1 19.67 208.09 7183.4 - 1939.3 - 1024.6 0.00 0.00 2175.6 - CASING DETAILS 6 8029.5 19.92 176.77 7430.9 - 2023.2 - 1042.9 4.00 - 103.47 2260.5 7 9229.5 19.92 176.77 8559.1 - 2431.4 - 1019.8 0.00 0.00 2634.7 07 -23B Tgt Sag 4000 TVD MD Name Size 8 9965.6 19.92 176.77 9251.1 - 2681.8 - 1005.7 0.00 0.00, 2864.2 07 -23B Tgt Pcly 2494.0 2494.1 13 3/8" 13 -3/8 - 5274.2 5700.0 9 5/8" 9 -5/8 WELLBORE TARGET DETAILS (MAP CO- ORDINATES) 8559.1 9229.5 7" 7 - 9251.0 9965.5 4 -1/2" 4 -1/2 Name TVD +N / -S +E / -W Northing Easting Shape 4500- Tie -In Survey 07 -23B Tgt Sag 8559.1 - 2431.4 - 1019.8 5946480.00 675040.00 Rectangle (Sides: L40.0 W 07 -23B Flt 1 8730ss 8791.1 - 1566.0 - 1239.7 5947340.00 674800.00 Polygon - 07 -23B Flt 2 8845ss 8906.1 - 1734.5 - 1518.7 5947165.00 674525.00 Polygon • 07 -23B F1t3 9090ss 9151.1 - 2063.1 -941.2 5946850.00 675110.00 Polygon 9 5/8" 07 -23B Tgt Poly 9251.1 - 2681.8 - 1005.7 5946230.00 675060.00 Polygon 5000- - _ \ / - KOP 85 LFT Start DLS 12.00 TFO -85.00 - D ___------- WELL DETAILS: 07 -23 - - - 5500- - - - Start Dir 12 °/100' : 5700' MD, 5274.2'TVD _ Ground Level: 26.8 - - - - - - +N / -S +E/ -W Northing Easting Latittude Longitude Slot 7 _ _ - Start Dir 4 °/100' : 5720' MD, 5289.9'TVD 0.0 0.0 5948934.44 676002.6670 15' 57.930 N48° 34' 36.537 W 06000 WS1 - - COMPANY DETAILS: BP - Alaska FORMATION TOP DETAILS o - End Dir :6193.6' MD, 5701.6' TVD NORTH AMERICA TVDPattivlDPath Formation - - - ALASKA 5756.1 6251.4 WS2 t - CM3 _ 5966.1 6474.4 WS1 a 6161.1 Method: Minimum Curvature 6161.1 6681.5 CM3 0 6500- CM2 Error System: ISCWSA 6687.1 7240.1 CM2 - Scan Method: Tray. Cylinder North 7225.1 7811.4 CM1 v _ Error Su (6 ' - - Surface: Elliptical Conic 7696.1 8311.6 THRZ C - CM 1 Warning Method: Rules Based 7858.1 8483.9 BHRZ Start Dir 4 °/100' : 7767.1' MD, 7183.4'TVD 7885.1 8512.6 LCU > 7000- _ 8016.1 8652.0 TJD N THRZ RZ - - ' - 8220.1 8868.9 TJC ` I- - _ _ _- 8364.1 9022.1 TJB BHRZ End Dir : 8029.5' MD, 7430.9' TVD 8559.1 9229.5 TSGR - - - 8586.1 9258.2 TS 7500- 8666.1 9343.3 TS - TJD _ _ LCU _ _ - 8776.1 9460.3 42 - - - - - - 8853.1 9542.2 TCGL - -. - TJB_ TJC_ _ - - - -__ `_ - - -_ 8922.1 9615.6 BCGL - _ 07 -23B Tgt Sag 8979.1 9676.3 23SB _ - 8000 - - - - - _ - - - - 8981.1 9678.4 PGOC - - - TSGR_ _ TJA_ _ - - 9041.1 9742.2 HOT - - TSAD _ _ TSHU - - - - - - - - - - 7 9163.1 9872.0 9090.1 9794.3 TZ1B TZ1 B 9202.1 9913.5 TDF 8500 _ _ 4256 -_____ - - - -___ , - TCGL- _ _ - - - _ _ _ t 07- 23/07 -23A 9246.1 9960.3 BSAD - - BCGL - - - - -- - - - - - - 95/8" PGOC - - - - - - - - 9000- 23SB- 4 -1/2" - - - 22TS 07 23/07 - 23 HOT ___ �` - / 21T8 ___ - -- -- _ - - - - _ _ _ - - - - - - - _ 7 - 7 - _ 07 -23B Tgt Poly - TZ1 B - TDF -- BSAD 0 7- 23/07 -23B W 04, 9500 P Total Depth : 9965.6' MD, 9251.1' TVD I: I I i I I I I I l 1 1 1 [ - - - - r_I l 1 I T - ,. - 1 _.i -1 7 - - i I T - L - -_ -.. -.I -I -r-r -__- I �I I ! r 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 Vertical Section at 200.56° (1000 ft/in) HALLIBURTON • Hallibur Proposal R port Database: .Sperry EDM .16 PRD Local Co -ordinate Reference: Well 07 -23 Company: BP - Alaska TVD Reference: 07 -23B D -14 @ 61.1ft Project: Prudhoe Bay MD Reference: 07 -23B D -14 @ 61.1ft Site: PB DS 07 North Reference: True Well: 07 -23 Survey Calculation Method: Minimum Curvature Wel!bore: Plan 07 -23B Design: 07 -23B Wp04a Project Prudhoe Bay, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 07, TR -11 -14 Site Position: Northing: 5,948,144.78ft Latitude: 70° 15' 49.847 N From: Map Easting: 677,382.28ft Longitude: 148° 33' 56.934 W Position Uncertainty: 0.0 ft Slot Radius: 0" Grid Convergence: 1.35 ° f Well 07 -23, 07 -23 Well Position +N / -S 0.0 ft Northing: 5,948,934.44 ft Latitude: 70° 15' 57.930 N +E / -W 0.0 ft Easting: 676,002.66 ft Longitude: 148° 34' 36.537 W 1 Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 26.8ft - - - - - -- - --- - -- -- - -- - - - -- Wellbore Plan 07 -23B Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) ( (nT) BGGM2009 10/23/2009 22.50 80.92 57,675 Design 07 -23B Wp04a Audit Notes: Version: Phase: PLAN Tie On Depth: 5,679.1 Vertical Section: Depth From (TVD) +N!-S +E/-W Direction (ft) (ft) (ft) ( 34.3 0.0 0.0 200.56 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/ -W Rate Rate Rate Tool Face (ft) ( (°) (ft) ft (ft) (ft) ( /100ft) (°/100 t) ( ° /100ft) (°) 5,679.1 38.57 212.44 5,257.9 5,196.8 - 1,249.0 -651.4 0.00 0.00 0.00 0.00 5,700.0 38.34 212.91 5,274.2 5,213.1 - 1,260.0 -658.4 1.78 -1.10 2.25 128.38 5,720.0 38.61 209.08 5,289.9 5,228.8 - 1,270.6 -664.8 12.00 1.36 -19.17 -85.00 6,193.6 19.67 208.09 5,701.6 5,640.5 - 1,472.0 -775.2 4.00 -4.00 -0.21 - 178.98 7,767.1 19.67 208.09 7,183.4 7,122.3 - 1,939.3 - 1,024.6 0.00 0.00 0.00 0.00 8,029.5 19.92 176.77 7,430.9 7,369.8 - 2,023.2 - 1,042.9 4.00 0.09 -11.94 - 103.47 9,229.5 19.92 176.77 8,559.1 8,498.0 - 2,431.4 - 1,019.8 0.00 0.00 0.00 0.00 9,965.6 19.92 176.77 9,251.1 9,190.0 - 2,681.8 - 1,005.7 0.00 0.00 0.00 0.00 11/9/2009 12:23:26PM Page 2 COMPASS 2003.16 Build 71 • . HALLIBURTOA H Sta � ndard Propo Report Database: .Sperry EDM .16 PRD Local Co- ordinate Reference: Well 07 -23 Company: BP - Alaska TVD Reference: 07 -23B D -14 @ 61.1ft Project: Prudhoe Bay MD Reference: 07 -23B D -14 @ 61.1ft Site: PB DS 07 North Reference: True Well: 07 -23 Survey Calculation Method: Minimum Curvature Wel[bore: Plan 07 -23B Design: 07 -23B Wp04a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /-S +E/ -W Northing Easting DLS Vert Section (ft) r) ( °) (ft) ft (ft) (ft) (ft) (ft) - 5,196.77 I 5,679.1 38.57 212.44 5,257.9 - 5,196.8 - 1,249.0 -651.4 5,947,670.60 675,380.71 0.00 1,398.22 Tie -In Survey 5,698.3 38.36 212.87 5,272.9 - 5,211.8 - 1,259.1 -657.8 5,947,660.40 675,374.50 1.78 1,409.90 KOP 85 LFT Start DLS 12.00 TFO -85.00 5,700.0 38.34 212.91 5,274.2 - 5,213.1 - 1,260.0 -658.4 5,947,659.50 675,373.95 1.78 1,410.93 I Start Dir 12°/100' : 5700' MD, 5274.2'TVD - 9 5/8" 5,720.0 38.61 209.08 5,289.9 - 5,228.8 - 1,270.6 -664.8 5,947,648.69 675,367.79 12.00 1,423.16 Start Dir 4 °1100' : 5720' MD, 5289.91VD 5,800.0 35.41 208.98 5,353.8 - 5,292.7 - 1,312.7 -688.2 5,947,606.05 675,345.42 4.00 1,470.79 5,900.0 31.41 208.83 5,437.2 - 5,376.1 - 1,360.9 -714.8 5,947,557.25 675,319.94 4.00 1,525.26 I 6,000.0 27.41 208.64 5,524.3 - 5,463.2 - 1,404.0 -738.4 5,947,513.66 675,297.34 4.00 1,573.86 � 6,100.0 23.42 208.40 5,614.6 - 5,553.5 - 1,441.7 -758.9 5,947,475.50 675,277.74 4.00 1,616.36 6,193.6 19.67 208.09 5,701.7 - 5,640.6 - 1,472.0 -775.2 5,947,444.86 675,262.18 4.00 1,650.41 End Dir : 6193.6' MD, 5701.6' TVD 6,200.0 19.67 208.09 5,707.7 - 5,646.6 - 1,473.9 -776.2 5,947,442.93 675,261.21 0.00 1,652.55 I 6,251.4 19.67 208.09 5,756.1 - 5,695.0 - 1,489.1 -784.3 5,947,427.48 675,253.42 0.00 1,669.71 WS2 6,300.0 19.67 208.09 5,801.9 - 5,740.8 - 1,503.6 -792.0 5,947,412.87 675,246.06 0.00 1,685.93 6,400.0 19.67 208.09 5,896.0 - 5,834.9 - 1,533.3 -807.9 5,947,382.81 675,230.91 0.00 1,719.30 6,474.4 19.67 208.09 5,966.1 - 5,905.0 - 1,555.4 -819.7 5,947,360.44 675,219.63 0.00 1,744.14 WS1 6,500.0 19.67 208.09 5,990.2 - 5,929.1 - 1,563.0 -823.7 5,947,352.75 675,215.75 0.00 1,752.68 6,600.0 19.67 208.09 6,084.3 - 6,023.2 - 1,592.7 -839.6 5,947,322.69 675,200.60 0.00 1,786.06 6,681.5 19.67 208.09 6,161.1 - 6,100.0 - 1,616.9 -852.5 5,947,298.18 675,188.25 0.00 1,813.26 CM3 6,700.0 19.67 208.09 6,178.5 - 6,117.4 - 1,622.4 -855.4 5,947,292.62 675,185.45 0.00 1,819.43 6,800.0 19.67 208.09 6,272.7 - 6,211.6 - 1,652.1 -871.3 5,947,262.56 675,170.30 0.00 1,852.81 6,900.0 19.67 208.09 6,366.8 - 6,305.7 - 1,681.8 -887.1 5,947,232.50 675,155.14 0.00 1,886.19 7,000.0 19.67 208.09 6,461.0 - 6,399.9 - 1,711.5 -903.0 5,947,202.44 675,139.99 0.00 1,919.56 7,100.0 19.67 208.09 6,555.2 - 6,494.1 - 1,741.2 -918.8 5,947,172.37 675,124.84 0.00 1,952.94 7,200.0 19.67 208.09 6,649.3 - 6,588.2 - 1,770.9 -934.7 5,947,142.31 675,109.69 0.00 1,986.32 ' 7,240.1 19.67 208.09 6,687.1 - 6,626.0 - 1,782.8 -941.0 5,947,130.25 675,103.61 0.00 1,999.71 CM2 7,300.0 19.67 208.09 6,743.5 - 6,682.4 - 1,800.6 -950.5 5,947,112.25 675,094.54 0.00 2,019.69 7,400.0 19.67 208.09 6,837.6 - 6,776.5 - 1,830.3 -966.4 5,947,082.19 675,079.38 0.00 2,053.07 7,500.0 19.67 208.09 6,931.8 - 6,870.7 - 1,860.0 -982.2 5,947,052.12 675,064.23 0.00 2,086.45 7,600.0 19.67 208.09 7,026.0 - 6,964.9 - 1,889.7 -998.1 5,947,022.06 675,049.08 0.00 2,119.82 7,700.0 19.67 208.09 7,120.1 - 7,059.0 - 1,919.4 - 1,013.9 5,946,992.00 675,033.93 0.00 2,153.20 7,767.1 19.67 208.09 7,183.3 - 7,122.2 - 1,939.3 - 1,024.6 5,946,971.83 675,023.76 0.00 2,175.59 Start Dir 4 %100' : 7767.1' MD, 7183.41 7,800.0 19.41 204.24 7,214.3 - 7,153.2 - 1,949.2 - 1,029.4 5,946,961.85 675,019.14 4.00 2,186.54 7,811.4 19.34 202.88 7,225.1 - 7,164.0 - 1,952.7 - 1,031.0 5,946,958.34 675,017.71 4.00 2,190.33 CM1 7,900.0 19.12 192.13 7,308.8 - 7,247.7 - 1,980.4 - 1,039.7 5,946,930.44 675,009.61 4.00 2,219.33 8,000.0 19.63 180.15 7,403.1 - 7,342.0 - 2,013.2 - 1,043.2 5,946,897.55 675,006.89 4.00 2,251.29 11/9/2009 12:23:26PM Page 3 COMPASS 2003.16 Build 71 . HALLIBURT0R • H Sta l ndard Proposal Report Database: .Sperry EDM .16 PRD Local Co- ordinate Reference: Well 07 -23 Company: BP - Alaska TVD Reference: 07 -23B D -14 @ 61.1ft Project: Prudhoe Bay MD Reference: 07 -23B D -14 @ 61.1ft Site: PB DS 07 North Reference: True Well: 07 -23 Survey Calculation Method: Minimum Curvature Welibore: Plan 07 -23B Design: 07 -23B Wp04a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/ -W Northing Easting DLS Vert Section 4 (ft) (°) ( °) (ft) ft (ft) (ft) (ft) (ft) - 7,369.79 8,029.5 19.92 176.77 7,430.9 - 7,369.8 - 2,023.2 - 1,042.9 5,946,887.59 675,007.39 4.00 2,260.53 End Dir : 8029.5' MD, 7430.9' TVD 8,100.0 19.92 176.77 7,497.2 - 7,436.1 - 2,047.1 - 1,041.6 5,946,863.64 675,009.31 0.00 2,282.51 8,200.0 19.92 176.77 7,591.2 - 7,530.1 - 2,081.2 - 1,039.6 5,946,829.68 675,012.03 0.00 2,313.69 8,300.0 19.92 176.77 7,685.2 - 7,624.1 - 2,115.2 - 1,037.7 5,946,795.71 675,014.74 0.00 2,344.87 I 8,311.6 19.92 176.77 7,696.1 - 7,635.0 - 2,119.1 - 1,037.5 5,946,791.78 675,015.06 0.00 2,348.49 I THRZ 8,400.0 19.92 176.77 7,779.2 - 7,718.1 - 2,149.2 - 1,035.8 5,946,761.75 675,017.46 0.00 2,376.05 8,483.9 19.92 176.77 7,858.1 - 7,797.0 - 2,177.7 - 1,034.2 5,946,733.25 675,019.74 0.00 2,402.21 BHRZ 8,500.0 19.92 176.77 7,873.2 - 7,812.1 - 2,183.2 - 1,033.9 5,946,727.78 675,020.18 0.00 2,407.23 8,512.6 19.92 176.77 7,885.1 - 7,824.0 - 2,187.5 - 1,033.6 5,946,723.50 675,020.52 0.00 2,411.17 LCU 8,600.0 19.92 176.77 7,967.2 - 7,906.1 - 2,217.2 - 1,031.9 5,946,693.82 675,022.89 0.00 2,438.41 1 8,652.0 19.92 176.77 8,016.1 - 7,955.0 - 2,234.9 - 1,030.9 5,946,676.17 675,024.31 0.00 2,454.62 TJD 8,700.0 19.92 176.77 8,061.3 - 8,000.2 - 2,251.3 - 1,030.0 5,946,659.85 675,025.61 0.00 2,469.59 8,800.0 19.92 176.77 8,155.3 - 8,094.2 - 2,285.3 - 1,028.1 5,946,625.89 675,028.33 0.00 2,500.77 8,868.9 19.92 176.77 8,220.1 - 8,159.0 - 2,308.7 - 1,026.8 5,946,602.47 675,030.20 0.00 2,522.27 TJC 8,900.0 19.92 176.77 8,249.3 - 8,188.2 - 2,319.3 - 1,026.2 5,946,591.92 675,031.05 0.00 2,531.95 I 9,000.0 19.92 176.77 8,343.3 - 8,282.2 - 2,353.3 - 1,024.3 5,946,557.96 675,033.76 0.00 2,563.13 9,022.1 19.92 176.77 8,364.1 - 8,303.0 - 2,360.9 - 1,023.8 5,946,550.45 675,034.36 0.00 2,570.03 TJB 9,100.0 19.92 176.77 8,437.3 - 8,376.2 - 2,387.4 - 1,022.3 5,946,523.99 675,036.48 0.00 2,594.32 9,130.6 19.92 176.77 8,466.1 - 8,405.0 - 2,397.8 - 1,021.7 5,946,513.60 675,037.31 0.00 2,603.86 TJA 9,200.0 19.92 176.77 8,531.3 - 8,470.2 - 2,421.4 - 1,020.4 5,946,490.03 675,039.20 0.00 2,625.50 9,229.5 19.92 176.77 8,559.1 - 8,498.0 - 2,431.4 - 1,019.8 5,946,480.00 675,040.00 0.00 2,634.70 1 TSGR - 7" - 07 -23B Tgt Sag 9,258.2 19.92 176.77 8,586.1 - 8,525.0 - 2,441.2 - 1,019.3 5,946,470.25 675,040.78 0.00 2,643.66 TSHU 9,300.0 19.92 176.77 8,625.4 - 8,564.3 - 2,455.4 - 1,018.5 5,946,456.06 675,041.91 0.00 2,656.68 9,343.3 19.92 176.77 8,666.1 - 8,605.0 - 2,470.1 - 1,017.7 5,946,441.34 675,043.09 0.00 2,670.19 TSAD 9,400.0 19.92 176.77 8,719.4 - 8,658.3 - 2,489.4 - 1,016.6 5,946,422.10 675,044.63 0.00 2,687.86 9,460.3 19.92 176.77 8,776.1 - 8,715.0 - 2,509.9 - 1,015.4 5,946,401.60 675,046.27 0.00 2,706.67 42SB 9,500.0 19.92 176.77 8,813.4 - 8,752.3 - 2,523.4 - 1,014.6 5,946,388.13 675,047.35 0.00 2,719.04 9,542.2 19.92 176.77 8,853.1 - 8,792.0 - 2,537.8 - 1,013.8 5,946,373.79 675,048.50 0.00 2,732.21 TCGL 9,600.0 19.92 176.77 8,907.4 - 8,846.3 - 2,557.5 - 1,012.7 5,946,354.17 675,050.07 0.00 2,750.22 9,615.6 19.92 176.77 8,922.1 - 8,861.0 - 2,562.8 - 1,012.4 5,946,348.86 675,050.49 0.00 2,755.09 1 BCGL 9,676.3 19.92 176.77 8,979.1 - 8,918.0 - 2,583.4 - 1,011.3 5,946,328.27 675,052.14 0.00 2,774.00 23SB 11/9/2009 12:23 :26PM Page 4 COMPASS 2003.16 Build 71 HALLIBURTON 41, Halliburton Company Standard Proposal Report Database: .Sperry EDM .16 PRD Local Co- ordinate Reference: Well 07 -23 Company: BP - Alaska TVD Reference: 07 -23B D -14 @ 61.1ft Project: Prudhoe Bay MD Reference: 07 -23B D -14 @ 61.1ft Site: PB DS 07 North Reference: True Well: 07 -23 Survey Calculation Method: Minimum Curvature Welibore: Plan 07 -23B Design: 07 -23B Wp04a Planned Survey j Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /-S +E/ -W Northing Easting DLS Vert Section 1 (ft) ( ( (ft) ft (ft) (ft) (ft) (ft) 4,920.00 9,678.4 19.92 176.77 8,981.1 - 8,920.0 - 2,584.1 - 1,011.2 5,946,327.54 675,052.20 0.00 2,774.66 PGOC 9,700.0 19.92 176.77 9,001.4 - 8,940.3 - 2,591.5 - 1,010.8 5,946,320.20 675,052.78 0.00 2,781.40 9,736.9 19.92 176.77 9,036.1 - 8,975.0 - 2,604.0 - 1,010.1 5,946,307.67 675,053.79 0.00 2,792.90 22TS 9,742.2 19.92 176.77 9,041.1 - 8,980.0 - 2,605.8 - 1,010.0 5,946,305.87 675,053.93 0.00 2,794.56 1 HOT 1 9,794.3 19.92 176.77 9,090.1 - 9,029.0 - 2,623.6 - 1,009.0 5,946,288.16 675,055.35 0.00 2,810.81 21 TS 9,800.0 19.92 176.77 9,095.4 - 9,034.3 - 2,625.5 - 1,008.9 5,946,286.24 675,055.50 0.00 2,812.58 9,872.0 19.92 176.77 9,163.1 - 9,102.0 - 2,650.0 - 1,007.5 5,946,261.79 675,057.46 0.00 2,835.02 TZ1B 9,900.0 19.92 176.77 9,189.4 - 9,128.3 - 2,659.5 - 1,007.0 5,946,252.27 675,058.22 0.00 2,843.76 9,913.5 19.92 176.77 9,202.1 - 9,141.0 - 2,664.1 - 1,006.7 5,946,247.70 675,058.58 0.00 2,847.95 TDF 9,960.3 19.92 176.77 9,246.1 - 9,185.0 - 2,680.0 - 1,005.8 5,946,231.81 675,059.86 0.00 2,862.55 BSAD 9,965.5 19.92 176.77 9,251.0 - 9,189.9 - 2,681.8 - 1,005.7 5,946,230.03 675,060.00 0.00 2,864.18 Total Depth : 9965.6' MD, 9251.1' TVD - 4 -1/2" 9,965.6 19.92 176.77 9,251.1 - 9,190.0 - 2,681.8 - 1,005.7 5,946,230.00 675,060.00 0.00 2,864.20 07 -23B Tgt Poly 11/9/2009 12:23:26PM Page 5 COMPASS 2003.16 Build 71 . HALLIBURTO • H Sta l ndard Proposal Report Database: .Sperry EDM .16 PRD Local Co- ordinate Reference: - Well 07 -23 Company: BP - Alaska TVD Reference: 07 -23B D -14 @ 61.1ft Project: Prudhoe Bay MD Reference: 07 -23B D -14 @ 61.1ft Site: PB DS 07 North Reference: True Well: 07 -23 Survey Calculation Method: Minimum Curvature Wellbore: Plan 07 -23B Design: 07 -23B Wp04a Targets Target Name Dip Angle Dip Dir. TVD +NI-S +EI-W Northing Easting - Shape ( °) ( (ft) (ft) (ft) (ft) (ft) 07 -23B Flt 2 8845ss 0.00 0.00 8,906.1 - 1,734.5 - 1,518.7 5,947,165.00 674,525.00 - Polygon I Point 1 8,906.1 - 1,734.5 - 1,518.7 5,947,165.00 674,525.00 Point 2 8,906.1 - 2,277.2 - 1,411.4 5,946,625.00 674,645.00 Point 3 8,906.1 - 2,558.1 - 1,162.9 5,946,350.00 674,900.00 Point 4 8,906.1 - 2,277.2 - 1,411.4 5,946,625.00 674,645.00 07 -23B F1t3 9090ss 0.00 0.00 9,151.1 - 2,063.1 -941.2 5,946,850.00 675,110.00 - Polygon I Point 1 9,151.1 - 2,063.1 -941.2 5,946,850.00 675,110.00 Point 2 9,151.1 - 2,468.0 -740.6 5,946,450.00 675,320.00 j Point 3 9,151.1 - 2,987.9 -537.7 5,945,935.00 675,535.00 Point 4 9,151.1 - 2,468.0 -740.6 5,946,450.00 675,320.00 07 -23B Fit 1 8730ss 0.00 0.00 8,791.1 - 1,566.0 - 1,239.7 5,947,340.00 674,800.00 - Polygon Point 1 8,791.1 - 1,566.0 - 1,239.7 5,947,340.00 674,800.00 I . Point 2 8,791.1 - 2,200.2 - 1,069.5 5,946,710.00 674,985.00 Point 3 8,791.1 - 2,511.5 - 1,016.7 5,946,400.00 675,045.00 Point 4 8,791.1 - 2,747.1 -997.2 5,946,165.00 675,070.00 Point 5 8,791.1 - 2,511.5 - 1,016.7 5,946,400.00 675,045.00 Point 6 8,791.1 - 2,200.2 - 1,069.5 5,946,710.00 674,985.00 07 -23B Tgt Poly 0.00 0.00 9,251.1 - 2,681.8 - 1,005.7 5,946,230.00 675,060.00 - Polygon Point 1 9,251.1 - 2,549.2 -945.6 5,946,364.00 675,117.00 Point2 9,251.1 - 2,629.9 - 1,129.5 5,946,279.00 674,935.00 Point 3 9,251.1 - 2,812.8 - 1,050.8 5,946,098.00 675,018.00 ' Point4 9,251.1 - 2,735.1 -867.9 5,946,180.00 675,199.00 07 -23B Tgt Sag 0.00 0.00 8,559.1 - 2,431.4 - 1,019.8 5,946,480.00 675,040.00 - Rectangle (sides W40.0 H40.0 D0.0) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (') ( 9,229.5 8,559.1 7" 7 8 -1/2 2,494.1 2,494.0 13 3/8" 13 -3/8 17 -1/2 9,965.5 9,251.0 4 -1/2" 4 -1/2 6 -1/8 5,700.0 5,274.2 9 5/8" 9 -5/8 12 -1/4 i I 11/9/2009 12:23:26PM Page 6 COMPASS 2003.16 Build 71 • . HALLIBURTOR H Sta ' ndard Proposal Report Database: .Sperry EDM .16 PRD Local Co- ordinate Reference: Well 07 -23 Company: BP - Alaska TVD Reference: 07 -23B D -14 @ 61.1ft Project: Prudhoe Bay MD Reference: 07 -23B D -14 @ 61.1ft Site: PB DS 07 North Reference: True Well: 07 -23 Survey Calculation Method: Minimum Curvature Wellbore: Plan 07 -23B Design: 07 -23B Wp04a r Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) 1 8,512.6 7,885.1 LCU I 9,678.4 8,981.1 PGOC 9,676.3 8,979.1 23SB 6,251.4 5,756.1 WS2 0.00 8,652.0 8,016.1 TJD 9,960.3 9,246.1 BSAD 9,794.3 9,090.1 21TS 6,474.4 5,966.1 WS1 9,343.3 8,666.1 TSAD 9,229.5 8,559.1 TSGR 9,460.3 8,776.1 42SB 7,240.1 6,687.1 CM2 9,872.0 9,163.1 TZ1B 9,258.2 8,586.1 TSHU 1 6,681.5 6,161.1 CM3 9,022.1 8,364.1 TJB 8,311.6 7,696.1 THRZ 8,868.9 8,220.1 TJC 9,615.6 8,922.1 BCGL 1 7,811.4 7,225.1 CM1 I 9,742.2 9,041.1 HOT 1 9,130.6 8,466.1 TJA 9,736.9 9,036.1 22TS 8,483.9 7,858.1 BHRZ 0.00 9,913.5 9,202.1 TDF 9,542.2 8,853.1 TCGL Plan Annotations Measured Vertical Local Coordinates Depth Depth +N /$ +E/ -W (ft) (ft) (ft) (ft) Comment 5,679.1 5,257.9 - 1,249.0 -651.4 Tie -In Survey 5,698.3 5,272.9 - 1,259.1 -657.8 KOP 85 LFT Start DLS 12.00 TFO -85.00 5,700.0 5,274.2 - 1,260.0 -658.4 Start Dir 12 °/100' : 5700' MD, 5274.2'TVD 5,720.0 5,289.9 - 1,270.6 -664.8 Start Dir 4 °/100' : 5720' MD, 5289.9'TVD 6,193.6 5,701.7 - 1,472.0 -775.2 End Dir : 6193.6' MD, 5701.6' TVD 7,767.1 7,183.3 - 1,939.3 - 1,024.6 Start Dir 4 °/100' : 7767.1' MD, 7183.4'TVD 8,029.5 7,430.9 - 2,023.2 - 1,042.9 End Dir : 8029.5' MD, 7430.9' TVD 9,965.5 9,251.0 - 2,681.8 - 1,005.7 Total Depth : 9965.6' MD, 9251.1' TVD 11/9/2009 12:23:26PM Page 7 COMPASS 2003.16 Build 71 SURVEY PROGRAM BP - Alaska ANTI - COLLISION SETTINGS Date: 2009-11-09T00:00:00 Validated: Yes Version: NORTH AMERICA Interpolation Method: MD, interval: 25.0 • ALASKA Depth Range From: 5679.0 To 9965.6 Depth From Depth To Survey /Plan Tool Results Limited By: Centre Distance: 1193.1 104.0 5679.1 Gyro (07 -23) GYD -CT -CMS Calculation Method: Minimum Curvature Reference: Plan: 07 -23B Wp04a (07 -23 /Plan 07 -23B) 5679.1 9164.5 07 -23B Wp04a (Plan 07 -23B) MWD+IFR +MS Error System: ISCWSA 9164.5 9965.6 07 -23B Wp04a (Plan 07 -23B) MWD+IFR +MS Scan Method: Tray. Cylinder North NAD 27 ASP Zone 4 : WELL DETAILS: 07 - 23 Error Surface: Elliptical Conic Warning Method: Rules Based Ground Level: 26.8 +NI.S +E/ -W Northing Easting Latittude Longitude Slot REFERENCE INFORMATION CASING DETAILS 0.0 0.0 5948934.44 676002.66 70° 15' 57.930 N 148° 34' 36.537 W Co ordinate (NIE) Reference: Well 07 -23, True North TVD MD Name Size Vertical (TVD) Reference: 07 -23B D -14 @ 61.1ft 2494.0 2494.1 13 3/8" 13 - 3/8 Section (VS) Reference: Slot - (0.ON, 0.0E) 5274.2 5700.0 9 5/8" 9 - 5/8 Measured Depth Reference: 07-23B 13-14 @ 61.1ft 8559.1 9229.5 7" 7 Calculation Method: Minimum Curvature 9251.0 9965.5 4 -1/2" 4 -1/2 0 330 30 • __ 0 300 11r 330 30 From Color To MD 270 vir Il 90 300 60 240 II 07 -23t L - - - - -- - 120 107-2Z 20 270 90 210 150 AL.,- 180 • Travelling Cylinder Azimuth (TFO +AZI) 1 vs Centre to Centre Separation 120 ft/inl 5 120 SECTION DETAILS 240 _ - - - - -1 Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target 07 -24 1 5679.1 38.57 212.44 5257.9 - 1249.0 -651.4 0.00 0.00 1398.2 107 - 2 5700.0 38.34 212.91 5274.2 - 1260.0 -658.4 1.78 128.38 1410.9 3 5720.0 38.61 209.08 5289.9 - 1270.6 -664.8 12.00 -85.00 1423.2 4 6193.6 19.67 208.09 5701.6 - 1472.0 -775.2 4.00 - 178.98 1650.4 5 7767.1 19.67 208.09 7183.4 - 1939.3 - 1024.6 0.00 0.00 2175.6 210 150 6 8029.5 19.92 176.77 7430.9 - 2023.2 - 1042.9 4.00 - 103.47 2260.5 7 9229.5 19.92 176.77 8559.1 - 2431.4 - 1019.8 0.00 0.00 2634.7 07 -23B Tgt Sag 100 8 9965.6 19.92 176.77 9251.1 - 2681.8 - 1005.7 0.00 0.00 2864.2 07 -23B Tgt Poly 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation 150 ft/inl HALLIBURTON Halliburton Company • look Anticollision Report Sperry Drilling Services Company: BP - Alaska Local Co- ordinate Reference: Well 07 -23 Project: Prudhoe Bay TVD Reference: 07 -23B D -14 @ 61.1ft Reference Site: PB DS 07 MD Reference: 07 -23B D -14 @ 61.1ft Site Error: 0.0ft North Reference: True Reference Well: 07 -23 Survey Calculation Method: Minimum Curvature Well Error: 0.0ft Output errors are at 1.00 sigma Reference Wellbore Plan 07 -23B Database: .Sperry EDM .16 PRD Reference Design: 07 -23B Wp04a Offset TVD Reference: Offset Datum Reference 07 -23B Wp04a Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.0ft Error Model: ISCWSA Depth Range: 5,679.0 to 9,965.6ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center - center distance of 1,193.1ft Error Surface: Elliptical Conic Survey Tool Program Date 11/9/2009 From To (ft) (ft) Survey (Wei[bore) Tool Name Description 104.0 5,679.1 Gyro (07 -23) GYD -CT -CMS Gyrodata cont.casing m/s 5,679.1 9,164.5 07 -23B Wp04a (Plan 07 -23B) MWD +IFR +MS MWD + IFR + Multi Station 1 9,164.5 9,965.6 07 -23B Wp04a (Plan 07 -23B) MWD +IFR +MS MWD + IFR + Multi Station Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) PB DS 07 07 -01 - 07 -01 - 07 -01 Out of range 07 -01 - 07-01A - 07-01A Out of range 07 -01 - 07- 01APB1 - 07- 01APB1 Out of range 07 -01 - 07-01B - 07-01B Out of range 07 -02 - 07 -02 - 07 -02 Out of range 07 -02 - 07 -02A - 07 -02A Out of range 07 -02 - 07 -02B - 07 -02B Out of range 07 -03 - 07 -03 - 07 -03 Out of range 07 -03 - 07-03A - 07 -03A Out of range 07 -03 - 07- 03APB1 - 07- 03APB1 Out of range 07 -04 - 07 -04 - 07 -04 Out of range 07 -04A - 07 -04A - 07 -04A Out of range 07 -05 - 07-05 - 07 -05 Out of range 07 -11 - 07 -11 - 07 -11 8,659.2 9,225.0 720.2 508.22 299.2 Pass - Major Risk 07 -11A - 07 -11A - 07 -11A 8,864.1 9,450.0 718.9 490.22 277.1 Pass - Major Risk 07 -22 - 07 -22 - 07 -22 9,965.1 10,025.0 1,188.3 573.77 660.2 Pass - Major Risk 07 -23 - 07 -23 - 07 -23 5,704.1 5,700.0 0.0 1.57 -1.5 FAIL - Major Risk 07 -23 - 07 -23A - 07 -23A 5,704.1 5,700.0 0.0 1.29 -1.3 FAIL - Major Risk 07 -23A - 07 -23A - 07 -23A 5,777.1 5,775.0 12.3 244.21 -228.1 FAIL - Major Risk 07 -24 - 07 -24 - 07 -24 Out of range 07 -25 - 07 -25 - 07 -25 5,696.5 5,925.0 1,092.8 188.68 910.5 Pass - Major Risk 07 -25 - 07 -25A - 07 -25A 5,696.5 5,925.0 1,092.8 188.68 910.5 Pass - Major Risk 07 -25 - 07 -25A - Plan #5x 5,696.5 5,925.0 1,092.8 188.68 910.5 Pass - Major Risk 07 -26 - 07 -26 - 07 -26 Out of range 11/9/2009 3:11:27PM Page 2 of 3 COMPASS 2003.16 Build 71 HALLIBURTON • Halliburton Company i Anticollision Report � ; Sperry Drilling Services '1,01' Company: BP - Alaska Local Co- ordinate Reference: Well 07 -23 Project: Prudhoe Bay TVD Reference: 07 -23B D -14 @ 61.1ft Reference Site: PB DS 07 MD Reference: 07 -23B D -14 @ 61.1ft Site Error: 0.Oft North Reference: True Reference Well: 07 -23 Survey Calculation Method: Minimum Curvature Well Error: 0.0ft Output errors are at 1.00 sigma Reference Wellbore Plan 07 -23B Database: .Sperry EDM .16 PRD Reference Design: 07 -23B Wp04a Offset TVD Reference: Offset Datum Reference Depths are relative to 07 -23B D -14 @ 61.1ft Coordinates are relative to: 07 -23 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 Central Meridian is 150° 0' 0.000 W ° Grid Convergence at Surface is: 1.34° Ladder Plot 1200 ` I I I t I 1 I I I .0 1 I'1 1 1 1 I 1 1 I I I 111 1 1 1 I I I RJ I I 1 VI I C 1 I I 1 N 1 I 4 - - • 900 [A O 1 1 1 1 1 g; o 1 1 1 kil E,# C I I I 1 0 ! p _ J J J _ ___J_ _ _ FD - fYFJ __ _ J _ I I 1 1 0 I 03 I I 1 �. P • • -- I ct, i 1 1 1 ► .. r 1 1 y 1 1 1 1 Fe 1 I co 600 1 al I I I I r.4 1 I I I I 1 I I C I 1 1 1 re 1 1 a) 1 1 1 1 Fe 1 I U J _ _ _ _ J _ _ _ _ _ _1 _ _ _ _ J _ _ _ J - _ _ _ J -- o 1 1 1 1 r l 1 I a) I 1 I 1 re I I I 1 I I I I c 1 1 1 f/ 1 I a' 1 1 300 <_) 1 1 1 r41 1 I I I I r1 1 I 1 1 I I I 1 1 I -___J J J _ ra __1 _ J J _ I I I 1 1 I 1 1 I d 1 1 I 1 I 1 1 1 1 i 1 1 1 1 0 - 1 0 2000 4000 6000 8000 1 000 0 1 200 0 M easured Depth (2000ft/in) I LEGEND -4- 07- 23,07 - 23,07 -23 V1 44- 07. 03.07. 03,07 - 031# •t 07- 23A07- 23A07 -23AV1 -A- 07- 23,07- 23A,07.23AV0 07.03,07.03A07.03AV1 07- 24,07 - 24,07.24 VI .94.- 07- 01,07 - 01,07 -01 V1 -0- 07- 03, 07- 03 AP B1 , 07- 03AP B 1 VI 07- 25,07- 25,07 -2512 -- 07 -01 .07- 01A,07 -01AV2 07. 04.07. 04.07 -04 V1 $ 07- 25 .07- 25A.07 -25A 5 -e- 07 -01 ,07 -01 AP 61, 07 -01 APB 1 V1 07 -04A 07.04A.07 -04AV1 -X- 07- 25.07 -25A Plan M5x VI -4- 07- 01.07 - 018,07 -01B V4 07- 05,07 - 05,07 -05 VI -e- 07- 26.07- 26.07 -26 VI -El- 07- 02,07 - 02,07 -02 V1 07- 11.07. 11,07 -11 VI $ 0 7 -23 B Wp04a - X- 07- 02.07- 02A,07 -02AV1 07- 11A.07- 11A,07 -11AV3 11/9/2009 3:11:27PM Page 3 of 3 COMPASS 2003.16 Build 71 TREE =, CIWGEN4 07 -23A WELLHEAD = CAMERON SAFETY NOTES: TIGHT SPOT NOTED ON ACTUATOR = AXELSON TOP OF LNR ON HO FORM. KB.ELEV= 57' Pre -Rig BF.ELEV= - KOP = 3050' Max Angle = 65 @ 9992' Datum MD = 10278' 2112' H4-1/2" CAMCO TRDP -4A SSSV NIP, ID = 3.812" I Datum TVD = 8800' SS 0 GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID= 12.347" H 2490' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 -1/2" TUBING c . H — 5z1�;� r� 1 4111 4017 37 KBMG -M DMY BK 0 08/23/06 2 7105 6396 35 KBMG -M DMY BK 0 08/23/06 7 -5/8" SCAB LNR, 29.7 #, L -80, ID = 6.75" 1 5903' - 6246' L 3 9401 8317 49 KBMG -M DMY BK 0 08/23/06 1 H -9253' I ���2999 I 9469' H 4 -1/2" OTIS XN NIP, ID= 3.725" I 1 TOP OF 5-1/2" TBG 1 9501' 1-- 1 9480' 1-I 4-1/2" X 5-1/2" XO I 1 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 9501' 1 / 11 I 9501' -I 5 -1/2" BAKER SEAL ASSY 1 M C 9502' 1-1 9 -5/8" X 5 -1/2" BAKER SB -3 PKR 1 Minimum ID = 2.372 @ 9551' 2 -7/8" PUP JOINT TOP OF 3 -1/2" LNR H 9547' 1 0 9547' H 3 -1/2" BAKER SETTING SLV, ID = 2.935" I 3 -1/2" LNR, 9.3 #, L -80, .0087 bpf, ID = 2.992" 1 9550' ■ / 9550' 1- 3 -1/2" X 2 -7/8 " X01 TOP OF 2 -7/8" LNR H 9550' 9551' H 2 -7/8 PUP JOINT, ID = 2.372" 1 TOP OF CEMENT H 9570' 1 41 ,', 9610' 1 1 5-1/2" XN NIP, ID = 4.455" 41/1 r, P.' (BEHIND LNR) 3.75" MILLED OUT O. 1.1 � 9624' H5-1/2" BAKER SHEA ROUT SUB (BEHIND LNR) 1 1 5 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" H 9625' ; # '• ' I •• j 9625' I-I 5 -1/2 TUBING TAIL (BEHIND LNR) 1 ,...' 1.�.�. 9607' I-I ELMD TT LOGGED 01/24/87 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9850' •• k � I /, 4 . 40 MILLOUT WINDOW W.W., 9852' PERFORATION SUMMARY '����������������0 REF LOG: BHCS ON 09/01/86 lAvevav��Av����ev��C ANGLE AT TOP PERF: 60 © 10526' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/8" 4 10526 - 10536 0 06/24/98 2 -1/8" 8 10580 - 10605 0 06/24/98 TD 1 10664' 1 PBTD H 10631' -. ��� • 1 2 -7/8" LNR, 6.5 #, L -80, .00579 bpf , ID = 2.441" 1 10662' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/07/87 ORIGINAL COMPLETION 08/23/06 JCMIPAG GLV C/O WELL: 07 -23A 10/02/94 RWO (SCAB LNR) PERMIT No: 98 -0890 05/27/98 CTD SDTRCK API No: 50- 029 - 21635 -01 09/26/01 RN/TP CORRECTIONS SEC33 T11 N R14E 33 2951.54 FEL 4462.7 FNL 07/05/05 DRS/TLH 1994 SCAB LNR CORRECTION 05/30/06 DTM WELLHEAD CORRECTION BP Exploration (Alaska) TREE = CIW GEN 4 • 07-23B I I WELLHEAD = CAMERON S AFETY NOTES: Chrome Lnr & tbg. +I .ACTUATOR = AXELSON KB. ELEV = 57' PROPOSED BF. ELEV = KOP = 5700' Max Angle = 39 @ 5100' Datum MD= 10278' 1 1 2100' I-J : -1/2" OTIS X NIP- j.813" I Datum TVD = 8800' SS .A ? 5550' 1-1 BKR Flex -Lock LNR HNGR & ZXP LTP, ID = 6.290" I-- 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2490' , 0 g G:" "? LIFT MANDRELS ST MD TVD DEV 'PE VLV LATCH PORT DATE 4 3793 3750 3 6263 5756 2 7792 7200 1 8851 8200_ MILLOUT W 5700' 1 y 7100' H 7" LNR, 26 #, L -80, BTC -M, ID = 6.276" I Minimum ID = 3.725" @ 9030' 1 4 -1/2" HES 'XN' NIPPLE 8952' - 4-1 IS X NIP, ID =R e $g$2' - x1/ BKR S3 PKR, ID = 3.870" _ � _ 9006' - 4-1/2" OTIS X NIP, ID = 3.813" I �� �� 9061' - 4-1/2" OTIS XN NIP, ID = 3.725" I )079' I- 4 -1/2" TBG, 12.6 #, 13Cr -80, Vam Top, 0 = 4.958" 9079' - TBR ID = 5.250" I II II - 9079' 7 "x5" BKR Flex -Lock LNR HNGR & ZXP LTP, ID = 4.440" PA rei � ' � „ '1 / 9229' H 7" LNR, 26 #, L -80, TC-II, ID = 6.276" I 1 411 ∎1 I*** 0 11 1 1 1 * *11 *01 PERFORATION SUMMARY 1 ,� 41 REF LOG: BHCS ON XX/XX /XX 1 � 1 � 1 1 ANGLE AT TOP PERF: XX @ XX,XXX' 100 1 1 1 Note: Refer to Production DB for historical perf data 1 1 1 1�1�1 1 .�1 1 4 \' SIZE SPF INTERVAL Opn /Sqz DATE 1 1�1�1�1�1 1 1����, \ , I 9886' I-1 PBTD I • k.--I 9966' I 4 -1/2" LNR, 12.6 #, 13Cr -80, Vam Top, 1 ID = 4.958" '�� 1 , ` `:∎i DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/07/87 ORIGINAL COMPLETION 08/23/06 JCM/PAG GLV C/O WELL: 07 -23B 10/02/94 RWO (SCAB LNR) 08/24/09 f-V R RST PROP(' PERMIT No: 198 -089 05/27/98 CTD SDTRCK API No: 50- 029 - 21635 -02 09/26/01 RN/TP CORRECTIONS SEC33 T11 N R14E 33 2951.54 FEL 4462.7 FNL 07/05/05 DRS /TLH 1994 SCAB LNR CORRECTION 05/30/06 DTM WELLHEAD CORRECTION BP Exploration (Alaska) EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 - AEO 2 6000000 1 ___ H • / Mt AEO 1 5950000 H DS 7 -23B 5900000 40 CFR 147.102 (b)(3) 0 5850000 400000 500000 600000 700000 800000 Alaska Department of Natural sources Land Administration System Page 1 of/ 1 Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources r Alaska DNR Case Summary File Type: ADL File Number: 28309 Printable Case File Summary See Township, Range, Section and Acreage? New Search 0 Yes 0 No LAS Menu I Case Abstract 1 Case Detail I Land Abstract File: ADL 28309 ~_ - Search for Status Plat Updates As of 11/16/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: 011N Range: 014E Section: 27 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 014E Section: 28 Section Acres: 640 Meridian: U Township: O11N Range: 014E Section: 33 Section Acres: 640 Meridian: U Township: 011N Range: 014E Section: 34 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14-130 11N 14E UM 27,28,33,34 2560.00 U- 3- 7 12 -01 -1986 * * *LISBURNE PARTICIPATING AREA * ** T. 11N.,R. 14E., U.M. SECTION 27: ALL 640 ACRES http://dnr.alaska.gov/projects/las/Case Summary.cfin?FileType=AD L&FileNumber=2 8 3 ... 11 /1 6/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME / � /3l/ 07-.0-73 PTD# Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: P.G'4/1)4 )99/ POOL: # 2)1Y D/G Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 ' -, ' . Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 07 -23B Program DEV Well bore seg ❑ PTD#: 2091450 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11650 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 1 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2560 acres. 1 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes - 10 Operator has appropriate bond in force Yes Blanket Bond # 6194193. 111 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes X 13 Can permit be approved before 15 -day wait Yes ACS 11/16/2009 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre - production less than 3 months (For service well only) NA 1 17 Nonconven. gas conforms to AS31.05.030(y1.A),(j.2.A -D) NA_ - 18 Conductor string provided NA Surface conductor set in 7 -23A Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 7 -23A 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented to GL 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in 7 -23A 22 CMT will cover all known productive horizons Yes cemented 4.5 inch liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 1 25 If are- drill, has a 10 -403 for abandonment been approved Yes 309 -319 P & A sundry 26 Adequate wellbore separation proposed Yes Proximity analysis performed. No issues. Closest wellbore is 7 -23A and paths diverge. 1 27 Ifdiverter required, does it meet regulations NA Well head in place.. BOP stack installed. Appr Date 128 Drilling fluid program schematic & equip list adequate Yes Max Formation pressure =2628 Psi @ 5270' TVD (UG1) at 9.6 ppg EMW.. Will drill with 10 ppg mud GLS 11/16/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP =2101 psi .. Will test BOP to 3500 psi 31 Choke manifold complies w/API RP -53 (May 84) Yes '32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S reported on DS 7 . Rig has sensors and monitors . 34 Mechanical condition of wells within AOR verified (For service well only) NA 1 1 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S 150ppm on well 07 -13A. Geology 1 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 11/16/2009 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Date: Date Date Commissioner: nx: ,.. 17... C Commissioner
