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Home My WebLink About209-0527. 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 C-15A Tubing Swap RWO Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-052 50-029-20427-01-00 11066 Conductor Surface Intermediate Scab Liner / Liner Liner 9011 80 2641 8873 4943 2041 10856 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 9022 32 - 112 31 - 2673 29 - 8902 4498 - 9441 9025 - 11066 32 - 112 31 - 2673 29 - 8262 4417 - 8747 8371 - 9011 10855 2670 4760 7020 10530 None 5380 6870 8160 10160 9052 - 10840 4-1/2" 12.6# 13cr, L-80 27 - 9053 8395 - 9022 Structural 4-1/2" HES TNT Packer 8990, 8340 8828, 8990 8197, 8340 Torin Roschinger Operations Manager Leif Knatterud leif.knatterud@hilcorp.com 907-564-4667 PRUDHOE BAY 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 0028285, 0028305 27 - 8396 N/A N/A 530 629 42351 43320 0 0 1670 0 1200 1140 325-369 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker S3 Packer 8828, 8197 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 No SSSV Installed By Grace Christianson at 3:33 pm, Aug 07, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.07 14:56:10 - 08'00' Torin Roschinger (4662) RBDMS JSB 080825 DSR-9/10/25JJL 9/5/25 ACTIVITY DATE SUMMARY 6/20/2025 ***WELL S/I ON ARRIVAL*** ** CONDUCTED MAN DOWN/WELL CONTROL DRILL w/ WSS ** SET 4-1/2" JUNK CATCHER (114" oal) ON PX @ 9013' MD PULLED BK-DGLV FROM STA #1 @ 8278' MD *** WSR CONT ON 6/21 *** 6/21/2025 POLLARD 63 RIG DOWN 6/21/2025 T/I/O=300/200/0 Temp=S/I (TFS unit 1 perform Circ out) Pumped 285 bbls of 1% KCL down the TBG and up the IA taking returns down C-13 FL for Circ out. Pumped a further 98 bbls of Deep Clean before letting it soak for 30 minutes. ******WSR Continued on 6-22-2025****** 6/22/2025 *****WSR Continued from 6-21-2025****** Let DeepClean soak for 30 minutes before pumping 319 bbls of 9.8 Brine down the TBG and up the IA taking returns down C-13 FL. Pumped a further 3 bbls of 50/50 and 10 bbls of DSL before isolating C-15 from C- 13 FL in order to allow C-15 TBG and IA to Youtube for FP. Pumped 1.5 bbls of 50/50 down hardline from choke trailer to C-13 FL to flush hardline. Final WHPS 250/150/0 6/24/2025 ***WELL SHUT IN ON ARRIVAL*** RIG UP AK E-LINE (CUT TUBING) PRESSURE TEST 250L 3000H RIH WITH RS, WELLTEC MECHANICAL CUTTER. OAL=24' MAX OD=3.13 TIED INTO TUBING TALLY CUT TUBING @ 8921 CCL STOP DEPTH=8902.7 (CCL-CUTTER=18.3) WELLTEC TATTLE TAIL=4.64" JOB COMPLETE RIG DOWN SECURE WELL. ***WELL SHUT IN ON DEPARTURE*** 6/25/2025 T/I/O=25/0/0. Pre RWO, Set 4" "H" TWC #436 , TWC LTT Passed. PT tree cap to 500 psi. Pass. ***Job Complete*** Final WHP's TWC/0/0. 6/26/2025 T/I/O=TWC/0/0. Pre RWO. RD 4" CIW upper tree and install 4" Tree cap assembly on MV. Torqued flange to spec. PT tree cap against MV to 300/5000 psi. Pass. ***Job Complete*** Final WHP's TWC/0/0. 7/4/2025 ***RWO Scope*** RDMO E-09C Trasnport all mods to C-Pad Spot Sub over well and continue putting rig together ***Cont. WSR on 7-5-25*** 7/5/2025 T/I/O=0/0/0 Pull 4" CIW H TWC, stand by for rock out diesel, set TWC, nipple down THA,SBMS stayed in THA, clean void, ring groove, make up 4-1/2" TC-II test sub to tubing hanger lift threads, test 3500 psi/5 min., good test, bleed off, rig down, function upper lock down screws to 3-1/2", all functioned as should, but several gland nuts were verhy tight, cleaned & lubed alll of them, several still very tight, but functioned & sealed, install new BX-160, stand by for BOP nipple up & test, pull TWC, make up landing joint, back out lock down screws, POOH, stand by for tubing swap. Final T/I/O=0/0/0 Daily Report of Well Operations PBU C-15A Daily Report of Well Operations PBU C-15A 7/5/2025 ***Cont. WSR from 7-4-25*** Spot gen mod and R/U power Scope up derrick Work on rig acceptance check list accepting rig at 06:00 hrs Circ 9.8 brine STS N/D Tree and N/U BOPE PT BOPE as per sundry 2500/3500 psi with 4-1/2" test and tested all PVT/gas alarms. Test was witnessed by AOGCC rep Guy Cook. R/U TRS and pull hanger to rig floor ***Cont. WSR on 7-6-27*** 7/6/2025 ***Cont. WSR From 7-5-25*** POOH and L/D 4-1/2" TBG F/8921' R/U TRS torque turn equipment RIH with 4-1/2" JFE Bear completion tagging No-go at 8932.67' ***Cont. WSR on 7-7-25*** 7/7/2025 ***Cont. WSR From 7-6-25*** Land hanger w/81K on hanger. RILDS and L/D landing jt. R/U and reverse in 290 bbls CI-brine Set packer at max pressure 4300psi for 10 min. Perform MIT-T and MIT-IA, Failed MIT-I/A R/U E-line and perform leak detection (GLM #2 at 7193') R/U slick line and change out dummy valve in GLM #2. Pressure up on TBG T/3700 PSI ***Cont. WSR on 7-8-25*** 7/7/2025 T/I/O=0/0/0 Make up hanger to tubing string, run in hole, land on RKB mark, verify landed looking through IA valve, run in lock down screws, torque to 500 ft/lbs, tighten gland nuts, stand by for drop ball & rod, test, etc. Final T/I/O=0/0/0 7/7/2025 **WELL S/I ON ARRIVAL*** (LEAK DETECTION LOG) RIG UP YJ E-LINE OPEN ENDED AT RIG FLOOR PERFORM LEAK DETECTION LOG BASELINE TEMPERATURE PASS FROM SURFACE TO PACKER AT 8840' INITIAL TUBING PRESSURE= 0 PSI, IA PRESSURE 0 PSI, PRESSURIZED IA WITH RIG PUMP ~0.4 - 0.8 BPM, MAX IA PRESSURE 1620 PSI SPINNER MOVING SUGGESTS GLM ASSY #2 LEAKING LEAK SIGNATURE AT 7196' ' NOT OTHER REMARKABLE LEAK SIGNATURE FOUND ON SPINNER OR TEMPERATURE SENSORS. RDMO YJOS ELINE. *** JOB COMPLETE *** 7/7/2025 ***POLLARD #61 ASSIST I-RIG*** SET 4-1/2" WHIDDON ON B&R AT 8,857' MD PULLED BK-DGLV AT ST# 2 (7,194' md) SET BK-DGLV AT ST# 2 (7,194' md) PULLED 4-1/2" WHIDDON AT 8,857' MD (empty) ***JOB COMPLETE ON DEPARTURE*** Daily Report of Well Operations PBU C-15A 7/8/2025 T/I/O=0/0/0 Set 4" H CTS BPV, stand by for BOP nipple down, clean void, install CTS plug & new BX-160, grease hange rneck, inspect THA ID, SBMS stil in from nipple down, make up THA, torque w/ Sweeny, test void 500/5000 5min./10 min., good tests witnessed by driller Eric, bleed off test psi, stand by for rig to test tree, monitored SBMS port during tree test, no leak, good tree test, bleed off, pull CTS plug & BPV for freeze protect, RDMO Final T/I/O=0/0/0 7/8/2025 ***Cont. WSR From 7-7-25*** Perform MIT-T & MIT-I/A holding for 30 min. MIT-T passed to 3610 psi. MIT-IA passed to 2669 psi Shear SOV in GLM #4 Install TWC and N/D BOPE N/U tree and PT void/tree to 500/5000 psi. R/U LRS and FP well. R/D and realese rig at 12:00 hrs. ***Final WSR Wrok Complete*** 7/8/2025 Assist I-Rig (RWO EXPENSE) Pumped 151 bbls Diesel down IA taking returns up TBG to Rig cuttings box. RDMO 7/9/2025 ***WELL S/I ON ARRIVAL*** SET 4-1/2'' BAIT SUB w/2.00'' GUTTED JD ON B&R @ 8856' MD PULLED BK-DGLV FROM ST# 3 @ 5534' MD ***WSR CONT. ON 07-10-2025*** 7/9/2025 T/I/O=0/0/0. Post RWO. RU CIW lubricator and Set 4" "H" TWC #710 @85". Removed 4" dryhole tree and installed 4" CIW tree assembly. Torqued flanges to spec. PT Tree against TWC to 300/5000 psi. Passed. Pulled 4" TWC #710 @145". RD lubricator and installed tree work platfroms, production piping and set floor and wellhouse. ***Job Complee*** Final WHP's 0/0/0. 7/10/2025 ***WSR CONT. FROM 07-09-2025*** PULLED BEK-SOV FROM ST# 4 @ 3233' MD SET BK-LGLV(16/64'' Port, 1500 tro) IN ST# 4 @ 3233' MD SET BK-OGLV(20/64'' Port) IN ST# 3 @ 5534' MD PULLED 4-1/2" BAITSUB, 2.00" GUTTED JD FROM TOP OF BALL & ROD @ 8856' MD PULLED BALL & ROD FROM RHC BODY @ 8856' MD PULLED 4-1/2" RHC BODY FROM X-NIP @ 8856' MD RAN 4-1/2'' GR TO JUNK CATCHER @ 9013' MD (Unable to latch) RAN 10' x 2.50'' P. BAILER(msfb) TO JUNK CATCHER @ 9013' MD PULLED JUNK CATCHER @ 9013' MD PULLED P-PRONG FROM PX PLUG @ 9013' MD ***WSR CONT. ON 07-11-2025*** 7/11/2025 ***WSR CONT. FROM 07-10-2025*** PULLED 4-1/2" PX PLUG FROM X-NIP @ 9013' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT C-15A JBR 08/07/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 4 1/2" test joint used for testing. Operator dropped their third ram due to clearance issues nippling up so #3 Rams is N/A. Both the HCR Kill and the HCR Choke failed initial testing. Both were serviced and passed the retests. Test Results TEST DATA Rig Rep:M. Vanhoose/M. LawsoOperator:Hilcorp North Slope, LLC Operator Rep:C. Montague/C. Yearout Rig Owner/Rig No.:Hilcorp Innovation PTD#:2090520 DATE:7/5/2025 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopGDC250706104324 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6.5 MASP: 2520 Sundry No: 325-369 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8"x 5.5" P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 FP Kill Line Valves 2 3 1/8" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3100 Pressure After Closure P1750 200 PSI Attained P12 Full Pressure Attained P67 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2316 ACC Misc NA P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P16 #1 Rams P4 #2 Rams P4 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1       7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU C-15A Tubing Swap RWO Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-052 50-029-20427-01-00 341J ADL 0028285, 0028305 11066 Conductor Surface Intermediate Scab Liner / Liner Liner 9011 80 2641 8873 4943 2041 9013 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 8361 32 - 112 31 - 2673 29 - 8902 4498 - 9441 9025 - 11066 2520 32 - 112 31 - 2673 29 - 8262 4417 - 8747 8371 - 9011 10855 2670 4760 7020 10530 9013 5380 6870 8160 10160 9052 - 10840 4-1/2" 12.6# L-80 27 - 90538395 - 9022 Structural 4-1/2" Baker S3 Packer No SSSV Installed 8990, 8340 Date: Torin Roschinger Operations Manager Leif Knatterud leif.knatterud@hilcorp.com (907) 564-4667 PRUDHOE BAY 7/1/2025 Current Pools: Prudhoe Oil Proposed Pools: Prudhoe Oil Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:49 am, Jun 18, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.06.18 06:45:53 - 08'00' Torin Roschinger (4662) 325-369 JJL 6/18/25 AOGCC witnessed BOP test to 3500 psi and annular test to 2500 psi. X DSR-6/18/25 10-404 A.Dewhurst 23JUN25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.24 05:59:35 -08'00'06/24/25 RBDMS JSB 062425 RWO C-15A PTD:209-052 Well Name:C-15A API Number:50-029-20427-01 Current Status:Not Operable Rig:Hilcorp Innovation Estimated Start Date:7/1/25 Estimated Duration:5days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:209-052 First Call Engineer:Leif Knatterud (907) 564-4667 (o)(432) 227-4342 (m) Second Call Engineer:Finn Oestgaard (907) 564-5026 (o)(907) 350-8420 (m) Current Bottom Hole Pressure:3250 psi @ 8,800’ TVD 7.1 PPGE | (Estimated) Maximum Expected BHP:3400 psi @ 8,800’ TVD 7.5 PPGE | (Highest Ivishak BHP) Max. Anticipated Surface Pressure:2520psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2,238 psi (Taken on 04/24/2025) Min ID:2.377” @ 10,200’ 3-3/16” X 2-7/8” XO Max Angle:96 Deg @ 11,019’ Brief Well Summary: C-15A was CTD sidetracked in June 2009. The heel of the well landed in Zone 1A and then dropped into Zone 1B before toeing up just into Zone 2A at the toe. Initially, 405’ of Zone 1B was perforated. In January of 2010, 25’ of Zone 2A was perforated which added ~1000 bopd and 8mm gas. In May of 2024, a PPROF showed most of the flow coming from the 50’ of perfs in Z2A. On 5/14/14, 30’ of perfs were added from 9,850’-9,880’. New PPROF showed majority of flow from newest perfs (9,850’-9,880’). In June 2017, a WFD CIBP was set at 9,769’ and Sag perforations were added from 9,052’-9,082’. The gas rates didn’t change, and the assumption was that the CIBP did not hold. In June 2021, an Alpha Extended Range Bridge Plug was stacked and held @ 9,735’. The well has produced Sag only since then showing initially 11 mm formation gas and ~250 bopd. Gas rates increased to ~18 mm and oil rates remained constant. Prior to the CTD sidetrack in 2009 GLM #2 developed a leak that extended packing would not mitigate. A patch was set to repair the TxIA communication, and it remained Operable until June 2023 when TxIA was observed. An LDL showed that additional tubing leaks were identified at 5,639’, 5,698’, and 6,332’. On 3/9/2025, 2 CIBPs were milled and 220’ was perforated. The well was pop’d under evaluation to justify RWO. Passed CMIT-TxIA on 5/4/2025. Objective: Cut and replace compromised 4-1/2” L-80 tubing with 4-1/2” 13CR Pre RWO work: DHD: Complete 1. CMIT-TxIA - 2750psi (5/04/25) 2. Cycle LDS’s (5/23/25) 3. PPPOT-T - 5,000psi, PPPOT-IC – 3,500psi (5/23/25) Slickline/Fullbore: 1. Set Junk basket above PX Plug at 9,013’. 2. Pull DMY GLV @ 8,278’. 3. Circ out wellbore with 9.8ppg brine and Diesel cap. E-line: 1. Cut tubing with Welltec cutter at 8,921’ (2’ below collar of first full joint of tubing above pup). RWO C-15A PTD:209-052 Valve Shop 1. Set and test TWC. 2. Pull wellhouse and flow line. RWO Procedure: 1. MIRU Workover Rig. 2. Nipple down tree and tubing head adaptor. Inspect landing threads. 3. NU BOPE configuration top down: Annular, 2-7/8”x 5” VBRs, blind/shear rams and integral flow cross. 4. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). a. Record accumulator pre-charge pressures and chart tests. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 2-7/8”x 5” VBRs with 4-1/2” test joint. e. Test the annular with 4-1/2” test joint. f. Submit a completed 10-424 form to the AOGCC within 5 days of BOPE test. 5. RU and pull TWC. RU lubricator if pressure is expected. 6. Rock out diesel freeze-protect. 7. MU landing joint or spear, BOLDS and pull hanger to the floor. a. Expected PU weight in 8.4ppg = 95k-lbs calculated. 8. Pull 4-1/2” tubing to floor, circulate bottoms up. 9. Lay down 4-1/2” completion. Tubing hanger and tubing will not be salvaged. 10. On surface, confirm overshot compatibility with cut joint. 11. Run 4-1/2” gas lifted tubing string with stacker packer completion as detailed on draft tally attached. a. Torque turn connections. 12. Land Hanger and reverse in corrosion inhibited 8.4 ppg KCl or seawater. 13. Drop ball and rod and set packer. 14. Perform MIT-T to 3,500 psi. 15. Bleed off tubing pressure to 1000 psi and MIT-IA to 2,500 psi for 30 charted minutes. 16. Bleed tubing pressure down to shear the shear out valve in the top GLM. FP Tubing and IA with diesel to 2200’ MD. 17. Set TWC. 18. ND BOPE 19. NU tree and tubing head adapter. 20. Test both tree and tubing hanger void to 500psi low/5,000psi high. 21. RDMO Workover Rig. Post-rig Work: Valve shop: 1. Pull TWC. Slickline: 2. Pull Shear-out valve, run KO GLV. 3. Pull Ball and rod and RHC profile. 4. Pull junk basket and PX Plug. RWO C-15A PTD:209-052 Attachments: x Wellbore Schematic x Proposed Wellbore Schematic x BOP Drawing x Proposed Tally x MOC form RWO C-15A PTD:209-052 Wellbore Schematic: RWO C-15A PTD:209-052 Proposed Wellbore Schematic: RWO C-15A PTD:209-052 Innovation Rig BOPs: Innovation Rig Choke Manifold RWO C-15A PTD:209-052 Proposed Tally: Well: C-15A Approx Depth Description 4-1/2” Tbg Hanger XO 13Cr Pup Joint to 4-1/2" JFE BEAR Full Joint - 4-1/2" 13Cr JFE BEAR b x p, 40’ 13 Cr Spaceout Pups (As Needed): 2 ft, 4ft, 6ft, 8ft etc. 4-1/2” 13Cr JFE BEAR Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ X Nip (ID=3.813”), 4-1/2” 13Cr JFE BEAR b x p 2200' MD Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ 4-1/2” 13Cr JFE BEAR Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ 4-1/2" MO-2 MMG style GLM w 1.5" SOV , 13Cr JFE BEAR 3244' MD Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ 4-1/2” 13Cr JFE BEAR Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ 4-1/2" MO-2 MMG style GLM w 1.5" DGLV , 13Cr JFE BEAR 5538' MD Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ 4-1/2” 13Cr JFE BEAR Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ 4-1/2" MO-2 MMG style GLM w 1.5" DGLV , 13Cr JFE BEAR 7180' MD Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ 4-1/2” 13Cr JFE BEAR Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ 4-1/2" MO-2 MMG style GLM w 1.5" DGLV , 13Cr JFE BEAR 8757' MD Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ Full Joint - 4-1/2" 13Cr JFE BEAR b x p, 40’ Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ X Nip (ID=3.813”), 4-1/2” 13Cr JFE BEAR b x p 8817' MD Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ XO: 4-1/2" 12.6 13CR JFE BEAR BOX X VAM TOP PIN ~2' 7”x4-1/2” 13Cr HES TNT Packer Vam Top bxp 8839' MD XO: 4-1/2" 12.6 13CR VAM TOP BOX X JFE BEAR PIN ~2' Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ X Nip (ID=3.813”), 4-1/2” 13Cr JFE BEAR b x p (with RHC Installed)8861' MD Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ Full Joint - 4-1/2" 13Cr JFE BEAR b x p, 40’ Pup Joint - 4-1/2” 13Cr JFE BEAR b x p, ~10’ Northern Solutions 13Cr 7" x 4-1/2" Overshot 8921' MD RWO C-15A PTD:209-052 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 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 C-15A Pull Patch, Mill CIBPs, Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-052 50-029-20427-01-00 11066 Conductor Surface Intermediate Scab Liner / Liner Liner 9011 80 2641 8873 4943 2041 9013 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 8361 32 - 112 31 - 2673 29 - 8902 4498 - 9441 9025 - 11066 32 - 112 31 - 2673 29 - 8262 4417 - 8747 8371 - 9011 10855 2670 4760 7020 10530 9013 5380 6870 8160 10160 9052 - 10840 4-1/2" 12.6# L-80 27 - 9053 8395 - 9022 Structural 4-1/2" Baker S-3 Perm Packer 8990 8340 Torin Roschinger Operations Manager Leif Knatterud leif.knatterud@hilcorp.com 907-564-4667 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 0028285, 0028305 27 - 8396 N/A N/A 214 796 18913 26498 0 184 100 1600 210 1150 324-713 13b. Pools active after work:Prudhoe Oil No SSSV Installed 8990, 8340 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 1:17 pm, May 06, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.05.06 12:00:21 - 08'00' Torin Roschinger (4662) RBDMS JSB 050825 DSR-5/6/25JJL 5/8/25 ACTIVITY DATE SUMMARY 2/9/2025 ***WELL S/I ON ARRIVAL*** RIG UP POL UNIT 59 ***CONT WSR ON 2-10-25*** 2/10/2025 ***WELL S/I ON ARRIVAL*** SET 4-1/2" WHIDDON (wcs 42) ON BAKER 45 KB PATCH @ 7171' MD PULLED BK-DGLV FROM ST #3 @ 5538' MD PULLED RK-DGLV FROM ST #4 @ 3244' MD SET RK-LGLV IN ST #4 @ 3,244' MD SET BK-OGLV IN ST #3 @ 5,538' MD PULLED EMPTY CATCHER FROM 7,171' MD PULLED 2-7/8" XX PLUG FROM NIPPLE REDUCER @ 9,013' MD DRIFTED W/ 2.30" SWAGE TO CIBP @ 9,735' MD. NO ISSUES ***WELL LEFT S/I ON DEPARTURE*** 2/26/2025 ***WELL S/I ON ARRIVAL*** R/U .160 ***CONTINUED ON 2-27-25*** 2/27/2025 ***CONTINUED FROM 2-26-25*** JARRED ON 45KB SINGLE TRIP PATCH @ 7,171'MD FOR 5-1/2 HOURS PULLED 45KB PATCH FROM 7,171' MD (MISSING 1 TOP ELEMENT & 1 BOTTOM ELEMENT) RAN 4-1/2" BLB, 3-1/2" BLB, 3.50" WIRE GRAB S/D @ 8,992' SLM (RECOVERED 1 ELEMENT) Well Control Drill w/ WSL (leak below wlv) ***CONTINUE 2/28/25*** 2/28/2025 ***CONTINUE FROM 2/27/25*** RAN 3.80" CENT. 4-1/2" BLB, S/D @ 8,992' SLM (RECOVERED SEVERAL SMALL PIECES OF ELEMENT) RAN 4-1/2" GS, S/D @ 9,013' MD, PULL 4-1/2" NIPPLE REDUCER (RECOVERED SMALL PIECES OF ELEMENT) ***WELL LEFT S/I*** *****1 MISSING ELEMENT***** 3/6/2025 LRS CTU #1, 1.5" CT. Job Scope: Mill Deployment Sleeve, Mill CIBP's (x2), Extended Adperf Travel to C-pad. MIRU and make up 2-1/8" Yellowjacket milling BHA with 2.80" round nose mill and 2.79" diamond string mill. RIH and tag the deployment sleeve at ~ 9020' CTM / 9025' MD. Mill through and reciprocate across the area to clean up. Dry drift to 9050' CTM (clean). POOH and make up 2.62" venturi junk basket with 2.76" burn shoe (1.51" ID). RBIH and tag the 3-3/16" CIBP at 9131' CTM / 9135' MD. Start milling. ***Job in progress*** Daily Report of Well Operations PBU C-15A Daily Report of Well Operations PBU C-15A 3/7/2025 LRS CTU #1, 1.5" CT. Job Scope: Mill Deployment Sleeve, Mill CIBP's (x2), Extended Adperf Continue milling the 3-3/16" CIBP at 9131' CTM. Mill through the plug and push down to the 2nd CIBP at 9769' MD. POOH to check tools. Recover parts of the plug core, elements, and a spring. RBIH with 2.62" venturi junk basket and 2.76" burn shoe (1.51" ID). Attempted to mill for 4 hours, with good motorwork and occasional stalls for the first couple hours but started spinning with 4-5k down and very little motorwork. POOH, no overpull or MW increase and deployment sleeve bushing. FP CT with diesel. L/D tools at surface and had 6 larger metal chunks (slips, nose cone and other plug parts) apx 1.5" in size, six chunks 1" or smaller and 1/2 cup small debris. Burn shoe measured 2.71" OD. L/D remaining tools. Perform weekly BOP test. Make up and RIH with 2-1/8" Yellowjacking milling BHA with 2.62" venturi junk basket and 2.76" burn shoe. Mill the 3-3/16" plug at 9769' and push it down to the crossover at 10200'. Start to POOH. ***Job in Progress*** 3/8/2025 LRS CTU #1, 1.5" CT. Job Scope: Mill Deployment Sleeve, Mill CIBP's (x2), Extended Adperf Continue to POOH with 2.76" venturi burn shoe (recover 1 slip and a 4" chunk of plug core). Take off 2-1/8" BHA and make up 1-11/16" Yellowjacket milling BHA with 2.35" 4-blade reverse clutch junk mill. RIH and milled the second CIBP at 9769'. Push plug remnants down to PBTD at 10855' MD. Dry drift the entire liner (clean). POOH and freeze protect the coil. Lay down YJ milling BHA (mill gauged 2.36"). Make up HES GR/CCL logging toolstring in 2.20" carrier with 2.50" JSN. Log from 10192' to 8900' at 50 FPM. Painted a tie-in flag at 9799'. POOH while killing the well with 180 BBL's of 1% KCL at max rate. Confirm good data (+3' correction). Perform 10 minute no-flow test and establish a leak off rate to the well of ~ 0.2 BPM. Perform PJSM and well control kick while tripping drill with the crew. Deploy 220' of 2" GeoRazor, 6 SPF, 60 degree phase guns. Start to RIH. Bump test H2S/LEL monitors, PT TIW/Safety Joint. Tag stripper with the coil connector. Perform kick while tripping drill with the night crew. Verify safety joint crossover makes up to perf gun threads. ***Job in Progress*** 3/9/2025 LRS CTU #1, 1.5" CT. Job Scope: Mill Deployment Sleeve, Mill CIBP's (x2), Extended Adperf Continue RIH with 2.00" x 220' HES GeoRazor, 6 SPF, 60 degree phase guns. Perforate 9880' - 10100'. Good indication of shot, POOH pumping KCL down the CTB to keep the well dead. Perform PJSM and well control kick will tripping drill with the crew. Shots all fired properly. Ball recovered. Un-deploy all guns. FP well with 30bbls 60/40 and 8 bbls diesel. 38 bbls total FP cap. RDMO ***Job Complete*** 4/24/2025 T/I/O= 2238/1800/341 (PROFILE MODIFICATION). Pumped 267 bbls crude into IA to load. Pumped 152 bbls crude into TBG to load. ***Job continued to 4-25-25*** 4/24/2025 ***WELL FLOWING ON ARRIVAL*** LRS LOADED IA W/ 267 BBLS CRUDE LRS LOADED TUBING W/ 152 BBLS CRUDE SET 4-1/2" PX PLUG BODY @ 9,013' MD SET P-PRONG @ 9,013' MD ***CONTINUE 4/25/25*** Daily Report of Well Operations PBU C-15A 4/25/2025 ***Job continued from 4-24-25***(PROFILE MODIFICATION) Pumped 36 bbls crude amd 13 bbls DSL down TBG to pressure up TBG and IA to 2750 Psi, TBG lost 66 Psi and IA lost 74 Psi in 15 min, TBG lost 53 Psi and IA lost 57 Psi in 30 min, TBG lost 48 Psi total, IA lost 43 Psi Lost in 45 min, TBG lost 167 Psi total, IA lost 174 Psi total (Test 1 Failed), FP FL with 9 bbls 60/40 and 138 bbls crude, Well left in Slicklines controll, DSO notfied upon departure, FWHP= 1100/900/100 4/25/2025 ***CONTINUE FROM 4/24/25*** LRS PERFORMED FAILING COMBO CMIT T X IA BLEEDING GAS FROM IA LRS FREEZE PROTECT FLOW LINE 115 BBLS CRUDE BLEED IA & TUBING BACK TO STARTING PSI (500PSI) ***WELL LEFT S/I*** 5/4/2025 T/I/O=392/389/50 (CMIT-TxIA) TFS U4. Pumped 25 bbls of crude down the TBG and IA to attempt and pressure up for a CMIT-TxIA MAP @ 2750 psi. Reached test pressure @ 2746 psi TBG and 2750 psi IA. First 15 minutes TBG lost 110 psi, IA lost 103 psi. Second 15 minutes TBG lost 37 psi, IA lost 37 psi. ***CMIT-TxIA PASSED*** Bled back 9 bbls to bring both strings down to ~600 psi. Flags and tags hung, PO notified of passing test upon departure FWHPS= 605/608/50 SV/WV/SSV=C MV=O I/O=OTG CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:Finn Oestgaard - (C) Cc:AOGCC Records (CED sponsored) Subject:RE: C-15A Sundry 324-713 flow extension request Date:Thursday, April 3, 2025 5:09:35 PM Attachments:image001.png image002.png Hi Finn, You are approved to flow UE for an additional 15 days, for 45 days total, per your request below. Please continue to monitor the OA. Thanks, JAck From: Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com> Sent: Thursday, April 3, 2025 4:56 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: C-15A Sundry 324-713 flow extension request Hi Jack, Question for you on well C-15A sundry 324-713. This was a mill plug, extended adperf and flow with known TxI communication for economic evaluation. We finished up the work on 3/09 & POP’d on 3/10. It initially came on @ 53,500 GOR, in 3 weeks of ontime it’s halved the gap to our typical GOR marginal of 90,000ish where wells are SI for high GOR, testing @ a GOR of 73,600 yesterday. There’s still a decent amount of uncertainty if that GOR will keep increasing @ that rate or start to taper out. If it keeps increasing at this rate we’re struggling to justify a RWO, if it flattens out which is what we expect, it’s just a matter of where does that GOR turn the corner, we plan to proceed with the RWO and start working the submission of a new Sundry. This is a request to flow the well for a total of 45 day under economic evaluation, currently we have permission to flow for 30 days. The current rate of increase in GOR leaves enough uncertainty at this point in time, hence this request. The IA has been behaving nicely while online, no bleeds necessary. The OA has been @ 250 -300 psi over the past 3 weeks. Let me know if you have any questions/concerns and if this is or is not approved. Thanks, Finn Finn Oestgaard GBP GC1 & GC3 Operations Engineer A,B,C,D,E,F,G,K,P,X,Y pads 907-564-5026 office 907-350-8420 mobile The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you arehereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly andpermanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. Noresponsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Gluyas, Gavin R (OGC) From:Lau, Jack J (OGC) Sent:Friday, February 28, 2025 11:25 AM To:Finn Oestgaard - (C) Subject:RE: C-15A (2090520) Revision/approval request Finn, Your plan below is approved. Please ensure the OA is periodically monitored for indications of IAxOA for the duration of flow. Jack From: Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com> Sent: Thursday, February 27, 2025 4:15 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: C-15A Revision/approval request Hi Jack Following up on our conversaƟon regarding C-15A (Sundry 324-713). IniƟally our plan was to mill the two CIBPs slightly under gauged due to the tubing patch and deployment sleeve ID. Due to the increased operaƟonal risks and complicaƟons of milling under gauged, I would like to revise the steps to include the following prior to milling the CIBP’s. 1. Pull tubing patch (SL or Coil) 2. Pull Nipple Reducer(SL or Coil) 3. Mill deployment sleeve bushing to 2.80” (Coil) This will allow us to mill the plugs with a full gauge mill assembly reducing the likelihood of complica Ɵons associated with under gauge milling bridge plugs. Please let me know if you have any quesƟons or concerns, Thank you, Finn You don't often get email from finn.oestgaard@hilcorp.com. Learn why this is important CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU C-15A Mill CIBPs, Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-052 50-029-20427-01-00 341J ADL 0028285, 0028305 11066 Conductor Surface Intermediate Liner Liner 9011 80 2641 8873 4943 2041 9735 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 8965 32 - 112 31 - 2673 29 - 8902 4498 - 9441 9025 - 11066 2430 32 - 112 31 - 2673 29 - 8262 4417 - 8747 8371 - 9011 None 2670 4760 7020 10530 9735, 9763 5380 6870 8160 10160 9052 - 10840 4-1/2" 12.6# L-80 27 - 90538395 - 9022 Structural 4-1/2" Baker S-3 Perm Packer No SSSV Installed 8990, 8340 Date: Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907-903-5990 PRUDHOE BAY 2/6/2025 Current Pools: PRUDHOE OIL Proposed Pools: Prudhoe Oil Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:51 pm, Jan 24, 2025 324-713 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.01.24 08:32:15 - 09'00' Torin Roschinger (4662) Perforating gun BHA not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders. Approved for POP Under Eval w/ TxIA comm for 30 days with IA < MOASP. JJL 1/24/25 Perforate SFD 1/24/2025 10-404 DSR-2/3/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.03 15:52:19 -09'00'02/03/25 RBDMS JSB 050825 Mill Plugs and Ext Perf C-15A PTD:209-052 Well Name: C-15A API Number: 50-029-20427-01 Current Status: SI Not Operable - TxIA Rig: SL, CTU Estimated Start Date: 2/06/25 Estimated Duration: 4 days Reg.Approval Req’std? 10-403 Date Reg. Approval Rec’vd: Check status Regulatory Contact: Abbie Barker First Call Engineer: Finn Oestgaard (907) 350-8420 Current Bottom Hole Pressure:3310 psi @ 8,800’ TVD 7.3 PPGE | (Average Ivishak BHP) Maximum Expected BHP:3310 psi @ 8,800 TVD 7.3 PPGE | (Average Ivishak BHP) Max. Anticipated Surface Pressure:2430psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2111 psi (Taken on 1/26/23) Min ID:2.30” Bushing @ 9,034’ MD Max Angle:96 Deg @ 11,019’ MD, 70 Deg at 9,750’ MD Brief Well Summary: C-15A was CTD sidetracked in June 2009. The heel of the well landed in Zone 1A and then dropped into Zone 1B before toeing up just into Zone 2A at the toe. Initially 405’ of Zone 1B was perforated. In January of 2010 25’ of Zone 2A was perforated which added ~1000 bopd and 8mm gas. In May of 2024 a PPROF showed most of the flow coming from the 50’ of perfs in Z2A. On 5/14/14 30’ of perfs were added from 9,850’-9,880’. New PPROF showed majority of flow from newest perfs (9,850’-9,880’). In June 2017 a WFD CIBP was set at 9,769’ and Sag perforations were added from 9,052’-9,082’. The gas rates didn’t change and the assumption was that the CIBP did not hold. In June 2021 a Alpha Extended Range Bridge Plug was stacked and held @ 9,735’. The well has produced Sag only since then showing initially showing 11 mm formation gas and ~250 bopd. Gas rates increased to ~18 mm and oil rates remained constant. Prior to the CTD sidetrack in 2009 GLM #2 developed a leak that extended packing would not mitigate. A patch was set to repair the TxIA communication and it remained Operable until June 2023 when TxIA was observed. An LDL showed that additional tubing leaks were identified at 5,639’, 5,698’, and 6,332’. On 10/31/24 a CMIT-TxIA was performed and passed to 2,385 psi proving a tested and competent barrier. A profile modification is planned in the liner including milling 2 CIBPs and 220’ of extended perforating. The well in it’s current condition does not economically support a RWO, this profile modification will assist in justifying spend on a tubing replacement extending the life of the well. Request to POP Under Eval with TxIA Hilcorp Alaska requests a 45-day POP under evaluation (with a possible extension if approved by the AOGCC) to evaluate the economics for a RWO tubing swap. The IAP will be maintained below MOASP and the well will be resecured at the end of the under eval period. If Objective:Utilize CTU to mill 2x CIBPs and shoot extended perforations in Z2A. POP under-eval and collect production data to determine if a tubing swap is economic. Mill Plugs and Ext Perf C-15A PTD:209-052 Procedure Slickline 1. Set GL kickoff design in top 2 stations 2. Pull TTP 3. D&T w/ 2.25” OD, attempt 2.30” drift if possible 4. Caliper from deviation to surface with 24 Arm Caliper. Coiled Tubing Mill 2x CIBPs 1. MU venturi, motor and 2.20” burn shoe BHA, measure & confirm OD of burn shoe prior to RIH & record in AWGRs. NOTE: history has shown 2.25” tools can pass the LTP without issue. SL will attempt a 2.30” drift to see if that size venturi will be possible. 2. Mill CIBP @ 9,735’. Once plug breaks loose, push downhole to 2 nd plug @ 9,769’ & lightly tag. PUH and note pickup weight. Set trips to 5k lbs above pickup weight & begin POOH 3. Once @ 8,984’ (50’ below deployment sleeve bushing) slow down to 5 fpm and proceed to POOH through deployment sleeve. - This is a precaution after G-11 & G-29 getting BHA’s stuck while POOH. a. If no restriction is observed, POOH to surface, measure OD of burn shoe and record in AWGRs. b. If BHA hangs up in the liner top, push back down into liner & contact OE for plan forward.We do not want to swedge BHA into the liner top. Potential path forward: disconnect, POOH, make up a motor & 2.40” mill (passes through 2.45” ID of patch & mills out 2.30” restrictions), RIH & mill nipple reducer & liner top to 2.40”, & recover BHA. 4. MU venturi motor & and 2.20” burn shoe BHA, measure & confirm OD of burn shoe prior to RIH & record in AWGRs. 5. Mill 2 nd CIBP @ 9,769’ & push to minimum target depth of 10,840’ (beyond deepest perf, PBTD @ 10,856’.) 6. Once plug is beyond target depth or unable to make it any deeper, PUH and note pickup weight. Set trips to 5k lbs above pickup weight & begin POOH. Once @ 8,984’ (50’ below deployment sleeve bushing) slow down to 5 fpm and proceed to POOH through deployment sleeve. a. If no restriction is observed, POOH to surface, measure OD of 2 nd burn shoe and record in AWGRs. b. If BHA hangs up in the liner top, push back down into liner & contact OE for plan forward.We do not want to swedge BHA into the liner top. Potential path forward: disconnect, POOH, make up a motor & 2.40” mill (passes through 2.45” ID of patch & mills out 2.30” restrictions), RIH & mill nipple reducer & liner top to 2.40”, & recover BHA. Correlate with attached log information. c. Correct flag and send to Corey Ramstad and OE for confirmation. Coil – Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. Mill Plugs and Ext Perf C-15A PTD:209-052 2. Bullhead 1.2x wellbore volume ~180 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 150 bbls b. 4-1/2” tubing/liner – 9025’ X .0152 bpf = 137 bbls c. 3-3/16” Liner – 1175’ X .0076 bpf = 9 bbls d. 2-7/8” Liner – 640’ X .0058 bpf = 4 bbls 3. At surface, prepare for deployment of TCP guns. 4. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 5.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. e.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 6.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 2” Millenium guns or similar Perf Interval (tie-in depths) Lengths Total Gun Length Weight of Gun (lbs) Run #1 9,880’ – 10,100’ – gun 220’ - loaded 220’~1,232 lbs (5.6 ppf) 7. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 8. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 9. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 10. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 11. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 12. RDMO CTU. 13. Turn well over to Operations POP. Slickline and Fullbore – Secure at the end of POP Under-Eval 1. Near the end of the 45 UE clock consider requesting an extension from the AOGCC to extend the POP U/E period. At the end of the POP U/E period MIRU SL and Fullbore prior to shutting in the well. 2. Load the IA with dead-crude to prevent breaking MOASP 3. Secure well - Dependent on results of prior coil steps if nipple reducer was milled out to 2.40” or not. a. Nipple not milled - set plug in nipple reducer OR Mill Plugs and Ext Perf C-15A PTD:209-052 b. Nipple previously milled out to 2.40” - Pull tubing patch & nipple reducer and set plug in 4-1/2” X nipple @ 9,013’ 4. Load remainder of tubing and IA with dead crude. Attachments: x Wellbore Schematic x Proposed Schematic x Tie-In Log x BOPE Schematic x Standing Orders x Equipment Layout x Sundry Change Form Mill Plugs and Ext Perf C-15A PTD:209-052 Current Wellbore Schematic Mill Plugs and Ext Perf C-15A PTD:209-052 Proposed Wellbore Schematic New Perforations O O O O O O O 9,880’-10,100’ Mill Plugs and Ext Perf C-15A PTD:209-052 Tie-in Log Mill Plugs and Ext Perf C-15A PTD:209-052 Perf Interval – 9,880’ – 10,100’ Mill Plugs and Ext Perf C-15A PTD:209-052 BOP Schematic Mill Plugs and Ext Perf C-15A PTD:209-052 Mill Plugs and Ext Perf C-15A PTD:209-052 Mill Plugs and Ext Perf C-15A PTD:209-052 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from oliver.sternicki@hilcorp.com. Learn why this is important From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: C-15A (PTD# 209052) request to POP under evaluation for up to 90 days Date:Tuesday, December 17, 2024 2:43:16 PM From: Lau, Jack J (OGC) Sent: Tuesday, December 17, 2024 2:43 PM To: 'Oliver Sternicki' <Oliver.Sternicki@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: C-15A (PTD# 209052) request to POP under evaluation for up to 90 days Oliver – Approved for 45 days with opportunity to extend if justified by Hilcorp and agreed by AOGCC. Jack From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, December 10, 2024 12:48 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: C-15A (PTD# 209052) request to POP under evaluation for up to 90 days Jack, Mel, C-15A (PTD# 209052) is a natural flow producer that is currently not operable due to a failed MIT-T on 6/17/2023. Prior to a CTD sidetrack in 2009, GLM #2 developed a leak and a tubing patch was set from 7173’-7208’ MD. After a failing TIFL on 6/3/2023 and the failing MIT-T on 6/17/2023, an LDL identified tubing leaks at 5,639’, 5,698’, and 6,332’ MD (LLR= 0.6 bpm at 1300 psi). The well passed a CMIT-TxIA to 2385 psi on 10/31/2024 with a plug set at 9013’ MD, proving the well has a competent secondary barrier. Work is being planned to mill the two CIBPs in the 3-3/16” liner and shoot extended perforations in Z2A, but it is unknown if the well will be productive enough to economically support a tubing swap to repair the TxIA communication. Hilcorp requests permission to POP C-15A under evaluation for up to 90 days post plug mill/ extended perforating work to evaluate well economics for justification of a tubing swap for continued well production. A longer than typical evaluation period is being requested for this well to ensure that stabilized production rates beyond the initial flush production period is achieved. Gas lift may be required to flow the well. IA pressure will be maintained below MOASP of 2100 psi. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:209-052 6.50-029-20427-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11066 9735 8965 8990 None 9735, 9769 8340 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 32 - 112 32 - 112 Surface 2641 13-3/8" 31 - 2673 31 - 2673 5380 2670 Intermediate 8875 9-5/8" 29 - 8902 29 - 8262 6870 4760 Production 4943 7" 4498 - 9441 4417 - 8747 8160 7020 Perforation Depth: Measured depth: 9052 - 10840 feet True vertical depth:8395 - 9022 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 27 - 9046 27 - 8390 8990 8340Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 2041 9025 - 11066 8371 - 9011 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 306 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Wyatt Rivard wrivard@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.777.8547 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9011 Sundry Number or N/A if C.O. Exempt: N/A Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028285, 0028305 PBU C-15A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 3-1/2" x 3-3/16" x 2-7/8" No SSSV Installed 365 40205 64 910 116 11146 24 570 700 By Samantha Carlisle at 1:30 pm, Jul 06, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.07.06 13:06:00 -08'00' Stan Golis (880) MGR29JUL2021 SFD 7/6/2021DSR-7/6/21 RBDMS HEW 7/8/2021 ACTIVITY DATE SUMMARY 6/18/2021 ***WELL FLOWING ON ARRIVAL***(profile mod) DRIFTED LINER W/ BAITED 5' x 2.25" DRIVE DOWN BAILER, TOOLS S/D @ 9757' SLM.(no sample) SET 3-3/16" ALPHA EXT RANGE CIBP @ 9735' MD. ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU C-15A STATE OF ALASKA • LASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations H 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 ❑ Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other:5C f- L°/'/) Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 209-052 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20427-01-00 7. Property Designation(Lease Number): ADL 0028305 8. Well Name and Number. PBU C-15A 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 11066 feet Plugs measured 9769 feet true vertical 9011 feet Junk measured feet AUG 17 2017 Effective Depth: measured 9769 feet Packer measured 8996 feet true vertical 8978 feet Packer true vertical 8345 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 32-112 32-112 Surface 2642 13-3/8"72#L-80 31-2672 31-2672 4930 2670 Intermediate 8875 9-5/8"47#L-80 29-8904 29-8264 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9052-9082 feet feet 9850-9880 feet 10100-10125 feet 10310-10380 feet 10430-10460 feet 10470-10520 feet 10540-10600 feet 10630-10775 feet 10790-10840 feet True vertical depth: 8395-8422 feet feet 8993-8994 feet 8998-8999 feet 9008-9013 feet 9015-9016 feet 9016-9017 feet 9018-9019 feet 9020-9022 feet 9022-9022 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 27-9053 27-8396 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 8996 8345 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED NOV 0 7 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 445 35529 64 600 911 Subsequent to operation: 678 38384 98 110 931 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development p Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ® Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 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: Glasheen,Brian PContact Name: Glasheen,Brian P Authorized Title: Production E .f• --r Contact Email: Brian.Glasheen©bp.com Authorized Signature: Date: V7 /7 Contact Phone: +1 907 564 5905 1 Form 10-404 Revised 04/2017 555777 /// L y RBDMS D Y � = gij Z J 2 017( 7 Submit Original Only • • RECEIVED AUG 17 2017 ` 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 August 8, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug and Adding of Perforations for Well C-15A, PTD # 209-052. 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 • • • co NCOO N Lo 00 N V N-O ° Ce) N U 00 OS ,n0 M ti 0 M • O) Oo o m CO CO ,..... 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Q1 a � X m U • g E 0 Q 2WF- Qm_ o 0 w = E m O 00wi H OW N m � (f) �° v) W a Q ° oo ° WI_ Zo < c� L' Q u) 1-- 0 0 aco 30Qza_ .- 0 X « a g __ 0 P tN ° W MZ N . * 7, W Z LL W m J LLCL >- 0 N N V E a Z 0 = N _1 � f�? a' a II pZN D t m 4= 00 a ~ 2 F— OZ -1 = d 0 d 0_� Jaw U ° o6 ~ O 0 W > o D 2 N a >, __I f-- CO 1Zc3 2 o a > z < z _ x0 XJOu. 9 � * 0 00W0O00Z a) MWWN ZW Q Q ° Z N O Q w II ° ° S Z w J z > z ~ nWw w � zz ° oa _• 0 — ' 0 < i- .ct%zz 22 cn0cncn - w_ 0 W00000 ° 0 J ~ JJJ O = �jOO Q O u" Q �41= 2 � Tu o � -' OQaU00 co 0 : : zFcNiaE.0 : : a ? a : 0 w F- Q N. I. N- a a 0 r 0 0 0 CO I- (0 rn 0 5_ N N M m H co co co 0 a TREE= " 4-1/16 CNN 4V�LHEAD= WA-01C-1 1 S NOTES; WELL ANGLE 70°@—9750" ACTUATOR= AXELSON1 1 OKB.ELEV= 62 7' BF aEV= 34.2 KOP= 3500'} J L Max Angle= 96"@ 11019'? I 2202' H4-112"Hl X NP,D=3.813" Datum P.O= 9573' !Datum TVD= 8800'SSI 113-3/8"CSG,72#,L-80,D=12.34r H 2673' I-- GAS LFT MANDRELS ST MD 1 ND DEV TY FE VLV LATCH FORT DATE 1 4 3244 3243 6 MMS DMR Y K 0 02/03/11; 7"T!W TRACK w/HNGR(02/02/0) H 4498' 3 5538 5303 33 KBG-2 DBK 0 02/03/111 , M'"2 7180 6688 28 KBG-2 ""DMY BK 0 108/14/07, -' $ 11 82781 7693 22 KBG-2 DMY BK 0 02/14/06; ;Minimum ID =2.30" @ 9034' ► 0 ST#2 HAS MAY w/EXT PKG&COVERED BY PATCH ti 13.70 DEPLOY SLV BUSHING, MILLED I #1 17171'-7213" —14-1/2"BKR45 KB PATCH(07/27/09),D=2.45" ► d1► dal ► 6 7"SCAB LHR,26#L145? —I 8408" 1.0371 bpf,0=6 184" 8408' —7"SEAL ASSY w/NO GO(02/02/90) TOP OF 7"LTC — 8409' 1 9-5/8"CSG,47#,L-80.D=8.681" H 8902' ' , , I 8969' —14-1/2"HES X NP,D=3.813" 1 S 8990' H 7"X 4-1/2"BKR S-3 PKR l 9013' --i 4-1/2"HES X NP,D=3.813" 9013' --4-1/2"X 2-7/8"NP Rte,D=2313'(7/7/09) 9025' H 3.70"BKR DEPLOY SLV w/4"GS PROFILE,ID=2.30" I4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958" E-1 9046' I 9034' -OY SLV BUSHING,(1 LED D=2.30" j `, II 9034' —4-1/2"HES XN NF',MLLED 3-1/2"LNR,9.2#,L-80 STL, 0087 bpf,D=2.992" —I 9076' D=3.80"(05/26/09)(BB1SND PIPE) 3.625"BKR WHIPSTOCK(05/21/09) H 9435' 9046' —14-1/2"WLEG,ID=3.958"(694ND PIPE) w/3 RIP TAGS @ 9445' 9076' —13-1/2"X 3-3/16"XO,0=2.786" E 7"LNR,29#,L-80,.0371 bpf,D=6.184" — 9900' 4**, `•,449250' H TOP OF CEMENT(06/25/09) PERFORATION SUMMARY '`'PERFORATION •4.44, 1 MLLOUT WIDOW(C-15A) 9442'-9449' 4.REF LOG.'977?ON XX/XX/XX I mo=o=!=e i i 9769' H3-3/16"WFD CEP(06/29/17) ANGLE AT TOP Fid 27a @ 9052o'er•-•:4,9111 Note;Refer to Production DB for histoncai perf data i die `` 10200' H3-3/16"X 2-7/8"XO,ID=2.377" SIZE!SFE E INTERVAL Opn/Sgz SHOT SQZ 2" i 6 1 9052-9082 0 06/29/17 4% 2" I 6 I 9850-9880 C 05/14/14 / 2" I 6 110100-10125 C 01/28/10 j 3-3/16"LN 62#,L-80 TCS, —1 10200' FgTD —I 10856' 2" 6 110310-10380 C 06/26/09 I .0076 bpf,D=2.80" 2" 1 6 110430-10460 C 06/26/09 2" I 6 (10470- 10520 C 06/26/09 2" ! 6 10540- 10600 C 06/26/09 2" I 6 110630- 10775 C 06/26/09 2-7/8"LNR 6.16#,L-80 STL, 0058 bpf,D=2.441" — 110W N. 2" 1 6 10790- 10840 C 06/26/09 I I DATE REV BY j COMMENTS DATE REV BY COMMENTSI PRUDHOE BAY LNT 103/09/80 !ORIGINAL COMPLETION 05/19/14 LB/JMD ADPERFS(05/14/14) WELL: G15A 102/05/90 !I2WO 07/03/17 MS/JMD SET CBP&ADFERFS PERMT No "2090520 07/08/03 DAV/KK IM _ I AFI No 50-029-20427-01 106/27/09 NORDIC2I CTD SIDETRACK(C-15A) SEC 19,T11 N,R14E,226'FNL&1219'FE. 102/13/11 PJC +GLV CORRECTIONS f 05/01/14 (07/07/09)'SET i BP Exploration(Alaska) Image Project Well History File Cover Page 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. ~~~ - ~' j ~ Well History File Identifier Organizing (done) ^ Two-sided III 111111 II II I II III ^ Rescan Needed RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: (Maria ~ ____ Date: ~ / ~ / /n /s~ ~ 1 Project Proofing BY: Maria Date: I ~ /s/ / Scannin Pre aration ~ x 30 = ~ + ~. =TOTAL PAGES__~~ (Count does not include cover sheet) in/~ g Iri BY: Maria _ Date: ~ ~ ~ j ~ ~ /s~ Production Scanning //~~.-.,, 1111111114 ""' Stage 1 Page Count from Scanned File: ~J~ (Count does include cov sheet) Pa a Count Matches Number in Scannin Preparation: YES NO 9 g BY: Maria Date: ~~~ ~ ~ /s~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II ( II'I II (II II I I III ReScanned BY: Maria Date: ~s~ Comments about this file: Quality Checked III II~III III IIII II 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 F,s c f; ; RECE1V G Mr. Tom Ata31 2.(111 Alaska Oil and Gas Conservation Commission ,as ;hl Gas Cjg 333 West 7 Avenue Anchorage, Alaska 99501 AI1C 9rI Q$ Subject: Corrosion Inhibitor Treatments of GPB C -Pad ca, ( 7 - 0 49" Dear Mr. Maunder, C.-15A Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -178 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C-41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 OPERABLE: Producer C -15A (PTD #2 520) Passed TIFL verifying tubing in rity Page 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] 1/2s-Il Sent: Tuesday, January 18, 2011 2:32 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC1 OSM; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, OPS Prod Controllers; AK, RES GPB West Wells Opt Engr Cc: Holt, Ryan P (ASRC); AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Robertson, Daniel B (Alaska) Subject: OPERABLE: Producer C -15A (PTD #2090520) Passed TIFL verifying tubing integrity All, Producer C -15A (PTD # 2090520) was classified as Not Operable during the shut down due to sustained casing pressure. The well passed a TIFL on 01/17/11 verifying tubin integrity. Therefore, the well has been reclassified as OperabTe and may be placed on production when convenient for operations. Please be careful of fluid expansion when placing the well on production as the OA is fluid packed. Thank you, Torin Roschinger (alt. Jerry Murphy) _- , FEB 7 2011 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: Friday, January 14, 2011 10:34 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (D• )'; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C ■ reline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM• K, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Fac' & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops ead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS Well Pa • • FT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB hest Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney :ommarito, Olivia 0; Robertson, Daniel B (Alaska); Ramsay, Gavin; Stone, Christopher; Kirchn: , Carolyn J; Longden, Kaity; Phillips, Patti J; Sayed, Mohamed; Holt, Ryan P (ASRC) Subject: Producers with sustained casing pres re on IA and OA due to proration All, The following producers were found o have sustained casing pressure on the IA during the proration January 12 -14. The immediate a• ion is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the -ells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 11 -05A (PTD #1961572 C -15A (PTD #22'0520) E -17A (PT■ #2042040) E -27A_ (PTD #1990590) 1/25/2011 • • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Friday, January 14, 2011 10:34 PM J ' e To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS Well Pad DFT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Bommarito, Olivia 0; Robertson, Daniel B (Alaska); Ramsay, Gavin; Stone, Christopher; Kirchner, Carolyn J; Longden, Kaity; Phillips, Patti J; Sayed, Mohamed; Holt, Ryan P (ASRC) Subject: Producers with sustained casing pressure on IA and OA due to proration All, The following producers were found to have sustained casing pressure on the IA during the proration January 12 -14. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. • • , PM #1961570 L/C (PTD #2090520 E -1 ' D • 142040) E -27A (PTD #1990590) F -04B (PTD #2100870) W -01A (PTD #2031760) W -16A (PTD #2031000) W -21A (PTD #2011110) W -25A (PTD #2091020) W -38A (PTD #2021910) The following producers were found to have sustained casing pressure on the OA during the proration January 12 -14. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. 09 -34A (PTD #1932010) M -21A (PTD #1930750) N -22B (PTD #2061610) All the wells listed above will be classified as Not Operable until start -up operations commence and are stable or the well passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. 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 1/24/2011 DATA SUBMITTAL COMPLIANCE REPORT 8/27/2010 Permit to Drill 2090520 Well Name/No. PRUDHOE BAY UNIT C-15A Operator BP EXPLORATION (ALASFC~ INC MD 11066 TVD 9011 Completion Date 6/26/2009 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-20427-01-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Tye Med/Frmt Number Name Scale Media No Start Stop CH Received Comments og Neutron 25 Blu 7331 10761 Case 9/1/2009 MCNL, GGL, GR, CNL 52 €D C Lis 18474 ~tron 8200 10768 Case 9/1/2009 Jun-2009 LIS Veri, GR, CNT Plus Ili Graphics !, Rpt LIS Verification 9150 11066 Open 9/1/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS ED C Lis 18485 ~duction/Resistivity 9150 11066 Open 9/1/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS Plus Graphics og Induction/Resistivity 25 Col 9442 11066 Open 9/2/2009 MD MPR, GR og Induction/Resistivity 5 Col 9442 11066 Open 9/2/2009 TVD MPR, GR og Gamma Ray 25 Col 9442 11066 Open 9/2/2009 MD GR o Gamma Ray 5 CoI 9140 11070 Open 9/2/2009 Depth Shift Monitor Plot L//og Neutron 25 Blu 9400 10834 Case 4/26/2010 MCNL, Lee CCL, GR, CNL ,J~ED C Lis 19584 Neutron 9389 10820 Case 4/26/2010 LIS Veri, GR, CNT Plus II Graphics Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 8/27/2010 Permit to Drill 2090520 Well Name/No. PRUDHOE BAY UNIT C-15A MD 11066 ND 9011 ADDITIONAL INFORMI~,T.(ON Well Cored? Y / Chips Received? ,,~C1.~L_ Analysis ~Q~ Received? Operator BP EXPLORATION (ALASI(a INC Completion Status 1-OIL Current Status 1-OIL Daily History Received? Y N Formation Tops >~N API No. 50-029-20427-01-00 UIC N Completion Date 6/26/2009 Comments: Compliance Reviewed By: Date: ~,~ ~~ ~pu ,. ~~ ~~ f1 B-`) ~:\ L~ ~ ~ 1,1 0 ~ 04,2,,, ~ Schlumb~rger NO. 5511 ~~yyyy~~ g` ,r~:, 'r .y,- Y ~- Alaska Data & Consulting Services Company: State of Alaska ~'~~~'~ 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99603-2836 Attn: Christine Mahnken ANN: Bath 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 8 Log Description Date BL Color CD F-30 12-14AL1 12-15 BBUO-00014 AVKP-00079 83S0.00049 PRODUCTION PROFILE PRODUCTION PROFILE - PRODUCTION PROFILE 03/17/10 03/18/10 - 03/78/10 1 1 1 ~ 1 1 17-11 17-OS J-23A 07-18 83S0-00053 B3S0-00052 BCUE-00010 BC72.00006 PRODUCTION PROFILE PRODUCTION PROFILE ~ MEM PRODUCTION PROFIL ~ .~ FL DETERMINATIOWPERF 03/30/10 03/29/10 04!14/10 04/17/10 1 i 1 1 1 1 1 1 LE 04/14/10 1 1 aa/17/10 1 1 P2-31 A 83S0-00046 _ CH EDIT PDC JUNK BASKET - 02/27/20 1 Cd5A AWJI-00068 MCNL - L 01/27/10 1 1 K-07E B2NJ-00054 MCNL 02/18/10 1 1 01-28A BAUJ-00004 MCNL - 12/18/09 1 1 PLEASE ACKNOWLEDGE aec Flar Rv cu•.utrJ r. eun ncrr~orJ~ur-_ nue ~..o~ ~...., r,.. BP Exploration (Alaska) Inc. Petrolechnicat Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 6 p~ STATE OF ALASKA ALAS AND GAS CONSERVATION COMMIS ~ . REPORT OF SUNDRY WELL OPERATIONS RECEIVED FFR 4 9 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Ext~~(>j~j~ ~ 68$ CIS. Comml! Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^~ Exploratory ^ 209-0520 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20427-01-00 8. Property Designation (Lease tuber) : .Well Name and Number: ADLO-028305 C-15A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11066 feet Plugs (measured) None feet true vertical 9011.25 feet Junk (measured) None feet Effective Depth measured 10856 feet Packer (measured) 8990 true vertical 9021.83 feet (true vertical) 8340 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2673 13-3/8" 72# L-80 31 - 2673 31 - 2673 4930 2670 Intermediate 8902 9-5/8" 47# L-80 27 - 8902 27 - 8262 6870 4760 Production 4943 7" 29# L-80 4498 -9441 4417 - 8747 8160 7020 Liner 2041 3-1/2"X3-3/16"X2-7/8" 9025 - 11066 831 - 9011 Liner 9.2/6.2/6.16# L-80 ~ Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# LL-80 SURFACE - 9046 SURFACE - 8390 Packers and SSSV (type, measured and true vertical depth) 7"X4-1/2" BKR S-3 PKR 8990 8340 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: Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ 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 Pre Title Data Management Engineer Signature Phone 564-4944 Date 2/9/2010 ion unn iu-ty~ iycvi~cu ~i~uva + svvq~4i {~ ~ ~, r":, vuvinn ~v~iyn~ai vn~y O LlJ ~ ~'~~' ~~ .%~~!(~ C-15A 209-052 PERF i4TT~4CHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C-15A 6/26/09 PER 10,310. 10,380. 9,008.4 9,013.17 C-15A 6/26/09 PER 10,430. 10,460. 9,014.79 9,015.74 C-15A 6/26/09 PER 10,470. 10,520. 9,015.98 9,017.03 C-15A 6/26/09 PER 10,540. 10,600. 9,017.56 9,018.86 C-15A 6/26/09 PER 10,630. 10,775. 9,019.61 9,022.3 C-15A 6/26/09 PER 10,790. 10,840. 9,022.45 9,022.33 C-15A 1/28/10 APF 10,100. 10,125. 8,998.08 8,999.41 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • i • C-15A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY [ 1/27/2010 CTU #9 w / 1.75"ct Job scope: Log with SLB MCNL & Perforate. «< Inter ACT publishing »> MORU CT. RIH w/Sch GR/CCL/MCNL in carrier. Tag bottom j@ 10,854'. Log up to 9400' x 3 passes. Painted flag @ 10,0150'. POOH. =Good data. Continued on WSR 01/28/2009. 1/28/2010CTU #9 w/1.75" OD CT. Job scope -Perforate. «< InterACT publishing »> Continued from WSR 01/27/2010. MU Sch 2" PJ2006 HMX x 25' pert gun. RIH ~. Perforate 10,100' - 10,125'. POOH. Confirmed holes, recovered ball. RDMO CT. Job complete. FLUIDS PUMPED BBLS 44 60/40 METH 44 Total TREE= 4-1/16 CMJ ',WELLHEAD = FMC 'ACTUATOR= AXELSON KB. ELEV = 54.39' BF. ELEV = 34.21' KOP = 3500' Max Angle = 96 @ 11019' 'Datum MD = 9573' Datum TV D = 8800' SS SA .,, TES: W ELL ANGLE 70° @ 9750' C-~15A 13-3/8" CSC, 72#, L-80, ID = 12.347" 11 2673' 1- Minimum ID = 2.30" @ 9034' 3.70 DEPLOY SLV BUSHING, MILLED 7" TIEBACK LNR, 26#, IJ45?, .0371 bpf, ID = 6.184"? ~~ TOP OF 7" LNR $409' 9-518" CSC, 47#, L-80, ID = 8.681" $902' 2202' ~ 4-1 /2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3244 3243 6 MMG DOME RK 16 07/10/09 3 5538 5303 33 KBG-2 SO BK 20 07/10/09 **2 7180 6688 28 KBG-2 ""DMY BK 0 08/14/07 1 8278 7693 22 KBG-2 DMY BK 0 02(14(06 *"ST #2 HAS DMY w/IXTENDED PACKING & COVERED BY PATCH 44g$' 7" TNV TIEBACK w /HNGR (02/02190} 449$' TOP OF CEMENT (0211990} 7171'-7213' 4-1/2" BKR 45 KB PATCH (07/27!09), ID = 2.45" $40$' 1-17" SEAL ASSY w/NO GO (02102/90) $969' I-~4-1(2" HES X NIP, ID = 3.813" $990' 7" X 4-1/2" BKR S-3 PKR 9013' 4-1/2'~,~uHES~~~X~~~~~N~~~~P~~ ~D~,g~ (4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9046' 3-1/2" LNR, 9.2#, L-80 STL, .0087 bpf, ID = 2.992" 9076' 3.625" BKR WHIPSTOCK (05!21/09) 1-) 9435' 3 RIP TAGS (05/21/09) 9445' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1-I 9900' PERFORATION SUMMARY REF LOG: ????? ON XX1XX/XX ANGLE RT TOP PERF: 84 @ 10310' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10310 - 10380 O 06!26/09 2" 6 10430 - 10460 O 06/26/09 2" 6 10470 - 10520 O 06/26/09 2" 6 10540 - 10600 O 06/26/09 2" 6 10630 - 10775 O 06/26/09 2" 6 10790 - 10840 O 06!26/09 9025' 3.70" BKR DEPLOY SLV w /4" GS PROFILE, ID = 2.30" 9034' DEPLOY SLV BUSHING, MILLED ID = 2.30" 9034' 4-1/2" HES XN NIP, MILLED 1 ID = 3.80" (05!26109} (BEHIND PIPE) ( 9046' 4-112" WLEG, ID = 3.958" {BEHIND PIPE} 9076' 3-1/2" X 3-3/16" XO, ID = 2.786" 9250' TOP OF CEMENT (06/25/09) MILLOUT WINDOW (C-15A} 9442' - 9449' 10200' 3-3/16" X 2-718" XO, ID = 2.377" 3-3/16" LNR, 6.2#, L-80 TCN, -, 10200' .0076 bpf, ID = 2.80" PBTD 10$56' 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, iD = 2.441" 11066' DATE REV BY COMMENTS DATE REV BY COMMENTS 03!09180 ORIGINAL COMPLETION 08/25/09 AKlTLH DRLG DRAFT CORRECTIONS 02/05!90 RWO 07/08/03 DAV/KK RWO 06127/09 NORDIC2 CTD SIDETRACK (C-15A} 07(16/09 TFA/SV GLV C/O (07/10!09} 07(27109 RRDITCH PATCH SET PRUDHOE BAY UNR WELL: G15A PERMIT No: 2090520 API No: 50-029-20427-01 SEC 19, T11N, R14E, 226' SNL & 1219' WEL BP Exploration (Alaska} // ~~ BAKER NV~sF~ES CUMYANY WELL NAME FIELD Barer Atlas PRINT DISTRIBUTION LIST BY EXYLURA'f1UN (ALASKA)1NC CUUN7'Y NUK'1'H SLUY;/ BUKUUUH C-15A STATE ALASKA PRUDHOE BAY UNIT THIS DISTRIBUTION LIST AUTHORIZED BY: DATE 8/31/2009 CATRINA GUIDRY SO #: 2658386 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2-I Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE AK 99508 ANCHORAGE. AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE. AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield. Houston. Texas 77073 This Distribution List Completed Bk ~ ,? €' ,g:-rt SEP U 2 2~~g Alaska Oii ~ Gas Cons. Come~ri~sinri Anchorage ~ gyp, Asa Page I of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7~h Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: C-15A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) ~~ 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2658386 Sent by: Catrina G , i Date: 08/ Received by Date: SEP 0 1 2009 PLEASE ACKNOWLEDGE RECEIPT BY ~ S~ETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ ~~(~~~ 7260 Homer Drive /~ e~II~MES Anchorage, Alaska 99518 /1 Direct: (907) 267-6612 INTEQ ~ FAX: (907) 267-6623 ~~~ ~ ~ ~~ ~ ~ ~~ F, S~C~~~ SEA n 1 2009 ~.~~ ail t~~ Goea~. ~~~~ttis~l~rb Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~ ~ r :, "' .,f ~ ~~,~; ~~nCh~faq~ Anchorage, AK 99503-2838 „ ',_:., '~ ~ ••_ ~ ~ ~ + `~ ATYN: Beth Well Job # Log Description Date 08/27/09 N0.5336 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Color CD 14-12 AYTU-00048 USIT ~- ~ 07/26/09 1 1 L2-06 ANHY-00101 PRODUCTION PROFILE C ~G 07/23/09 1 1 03-20A AYKP-00034 CROSSFLOW CHECK <' 07/16/09 1 1 M-06A AZCM-00034 PRODUCTION LOG - 07/13/09 1 1 P1-11 AYS4-00086 PRODUCTION PROFILE (o L 07/21/09 1 1 02-11A AYS4-00084 LDL - ~ 07/20/09 1 1 W-212 63S0-00011 INJ PROFILE W/WFL - 07/20/09 1 1 W-215 AYKP-00036 INJ PROFILE W/RST-WFL ~ - 07/25/09 1 1 W-207 AYKP-00035 INJ PROFILE W/RST-WFL -(SC L 07/24/09 1 1 H-29A AYOO-00027 RST 'b~ 05/19/09 1 03-28 B14B-00067 RST j - C.( 07/17/09 1 1 B-27A AXBD-00029 MCNL ~ 06/12/09 1 1 C-15A AWJI-00038 MCNL - 06/25/09 1 1 O-04A B1JJ-00023 MCNL ~ 05/28/09 1 1 V-05 08AKA0024 OH MWD/LWD T 10/13/08 1 1 07-066 AWJI-00042 MCNL .07/21/09 1 1 02-336 09AKA0149 OH MWD/LWD EDIT 06/03/09 1 1 14-23A 09AKA0035 OH MWD/LWD EDIT 05/12/09 1 1 H-19B B2WY-00004 MCNL (REPLACEMENT) - L 05/07/09 1 r~twst w~nnuw~tutat ttt~tiri esr siurvmta wrvu rtt~urtninta unt purr twin Iu: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 s ~~ STATE OF ALASKA ALASKA AND GAS CONSERVATION COM ~~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECENE :ro9 JUL 2 7 2009 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1 b. 8S OnS. OfTtfIIISS zoAACZS.~os zoAACZS.»o ®Developme~tlC~1'~~gloratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aban 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/2'2009 209-052 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 6/20/2009 - 50-029-20427-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 6/23/2009 ' PBU C-15A FEL, SEC. 19, T11 N, R14E, UM 226 FNL, 1219 Top of Productive Horizon: 8. KB (ft above MSL): 62.7' 15. Field /Pool(s): 734' FNL, 4026' FEL, SEC. 19, T11 N, R14E, UM Ground (ft MSL): 32.76' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Oil Pool 81' FSL, 110' FEL, SEC. 13, T11 N, R13E, UM 10856' 9022' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 664132 y- 5960988 Zone- ASP4 11066' 9011' ADL 028305 & 028285 TPI: x- 661338 y- 5960420 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: - 5961212 Zone- ASP4 Total De th: x- 660284 None y p 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): ' Submit el ctronic and rinted information er 20 AA 25. N/A ft MSL (Approx.) 1900 21. Logs Obtained (List all logs here and submit electronic and pri ted information per 0 AAC 25.071): MWD DIR / GR / 9~~/;~J ~,~8~a ~TYQ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 12.9 cu ds Permafrost 1 - /8" 72# L-80 1' 7 ' 1' 2673' 17-1/2" 720 cu ft r i II 4 c A II 9-5/ " 47# L-80 27' 8902' 27' 8262' 12-1/4" 121 c Class'G' 130 cu ft AS I 7" 29# L-80 4498' 4417' 8747' 8-1/2" 425 cu CI ss'G' & 667 'G' s-vz° x 3-3/16" g.2# / 6.2# L-8 11 71' 11' 4-1 / " 11 cu I x za/e" / 6.16# 23. Open to production or inject ion? ®Yes ^ No 24. Tui3iluG RECORD If Yes, list each i (MD+TVD of To & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD p 2" Gun Diameter 6 spf 4-1/2", 12.6#, L-80 9046' 8990' , MD TVD MD TVD 3-1/2", 9.3#, L-80 9520' - 9720' 9717' 10310' - 10380' 9008' - 9013' 10430' - 10460' 9015' - 9016' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10470' - 10520' 9016' - 9017' DEPTH INTERVAL MD AMOUNT Sc KIND OF MATERIAL USED 10540' - 10600' 9018' - 9019' 10630' 10775' 9020' 9022' 2050' Freeze Protect w/ 38 Bbls McOH - - 10790' - 10840' 9022' - 9022' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): July 24, 2009 Flowing Date Of Test: HOUrS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 7/22/2009 6 TEST PERIOD 300 67 18 94 225 Flow Tubing Casing PreSS: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): Press. 800 1,650 24-HOURi4ATE~ 1,1 99 269 72 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^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 20_AAC 250.071. COIVIFLETION N l one -~. QR Form 10-407 ReVISed 02/2007 CONTINUED ON REVERSE SIDE ~,~Eil~ ~,- e ~j~~~ - ~ ~JG ~ ~ 2D09 ~~ ~ T, 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND M S ENCOUNTERED): 29. FORMATION 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. 23S6 /Zone 2B 9498' 8798' None 22TS 9582' 8870' 21 TS /Zone 2A 9632' 8907' Formation at Total Depth (Name): 21TS /Zone 2A 9632' 8907' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the forego'ng is true and correct to the best of my knowledge. ~ ~~ ~~~ Signed Terrie Hubble Title Drilling Technologist Date PBU C-15A 209-052 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Charles Reynolds, 564-5480 INSTRUCTIONS GeNew-~: 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. IreM 1a: 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. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: 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. IreM 29: 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 02/2007 Submit Original Only BP EXPLORATION Operations Summary Report Page 1 of 10 Legal Well Name: C-15 Common Well Name: C-15 Spud Date: 2/17/1980 Event Name: REENTER+COMPLETE Start: 6/18/2009 End: 6/27/2009 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2009 Rig Name: NORDIC 2 Rig Number: Date ,From - To I Hours Task Code NPT Phase ~', Description of Operations 6/18/2009 ~ 14:00 - 00:00 10.00 I MOB P PRE I Scope down derrick. I ~~\ 6/19/2009 00:00 - 00:25 0.42 BOPSU P PRE 00:25 - 04:00 3.58 BOPSU P PRE 04:00 - 05:00 1.00 BOPSU P PRE 05:00 - 12:00 7.00 BOPSU P PRE 12:00 - 14:00 2.00 STWHIP P 14:00 - 18:45 4.75 STWHIP P 18:45 - 20:45 I 2.001 STWHIPI P y `'d~ 120:45 - 22:35 22:35 - 23:05 23:05 - 00:00 6/20/2009 00:00 - 00:40 00:40 - 00:55 00:55 - 01:05 1.83 STWHIP P 0.50 STWHIP P 0.92 STWHIP P 0.67 STWHIP P 0.25 .STWHIP P 0.17 STWHIP P 01:05 - 06:00 - ~ °~-> 06:00 - 06:30 0.50 STWHIP P 06:30 - 11:00 4.50 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Move off H Pad to C Pad Move onto C Pad Scope up Derrick Pull over Well C-15 Accept rig C~ Midnight PJSM for NU of BOPE NU BOPE Fill stack. Shell test BOPs. Pressure test BOPE as per AOGCC Regulations, BP policy, and well plan and drilling permit requirements. Test inner reel valve and packoffs. Witness waived by AOGCC representative. Test data transmitted to AOGCC via a-mail by R. Holmes, Nordic 2 toolpusher. Reverse a-line slack in coil. Cut 360' pipe. MU a-coil head with SLB & Inteq. Leaked during pressure test. Re-head and test connector. MU nozzle assembly and RIH to displace FP and sea water to clean BIO. Tag TOC / TOW ~ 9,452.8 ft uncorrected. POOH PJSM for LD / PU of BHA's Tag up flow check well. Stand back injector, and LD nozzle. PU window milling BHA with 3.8" DSM window mill and 3.79" string mill. Stab on and test tools. RIH pumping min rate 5858 ft at midnight. Continue to RIH with window milling BHA ~ min rate. Log for GR TIE IN from 9,250 ft to 9,282 ft Made -6 ft correction. Continue to RIH and Taa TOC /TOW C~ 9444 ft Dry PU and start pumps Tag C~ 9443 ft with sharp stall. Time mill window following schedual and practices. FS=1670 psi ~ 2.62 bpm Slowly RIH to 9441.8 ft got small rise in pressure and DH WOB, start with 0.1 ft per 10 min. After advancing to 9442 ft continue with 0.1 ft per 6 min. 9443.3 ft initial exit of window mill. -Increase DH WOB, still 300-400 psi of MW 9443.9 wait 19 min for MW and weight to mill off before advancing then back to schedule. Milled to 9445.2 ft Crew Change and walk arounds Continue to mill window from 9445.2' 1800 psi fs at 2.58 bpm in/out. 100-200 psi mtr work. 2-3k# dhwob. ia/oa/PVT: 5 psi / 54 psi / 273 bbls. BHP/ECDlTVD: 4005 psi / 8.95 ppg / 8705 ' Time mill at 6 minute per 1/10 ft. Slower as required to maintain WOB. Drill off indicates out of csg at 9448.5'. ~__ Printed: 7/16/2009 4:49:33 PM BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: C-15 Common Well Name: C-15 Spud Date: 2/17/1980 Event Name: REENTER+COMPLETE Start: 6/18/2009 End: 6/27/2009 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2009 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task Code ~i, NPT I, Phase Description of Operations 6/20/2009 11:00 - 13:00 2.00 STWHIP P WEXIT Continue to time mill ahead until string reamer is out of casg. dhwob: 0.5 - 1.Ok# at 6 min per 0.1 ft. Drill formation to 9457'. '~ Displace well to used geovis mud. 13:00 - 14:00 1.00 STWHIP P WEXIT Back ream through window three passes. Dry drift with mill. Wondow smooth. 14:00 - 16:00 2.00 STWHIP P WEXIT Circulate out of hole. 16:00 - 16:45 0.75 STWHIP P WEXIT Get off well. Unstab coil. LD milling BHA tools. Mill 16:45 - 17:30 0.75 DRILL P PROD1 MU drillin build BHA with resistivi 1.3 AKO with new, Hycalog trex 4-1/4" bicenter. Stab coil. Test tools. Get on well. 17:30 - 19:00 1.50 DRILL P PROD1 Run in hole. Circ at min rate. Check SPM filter in reel house. 19:00 - 19:15 0.25 DRILL P PROD1 Log for GR tie in from 9200 ft to 9229 ft Made -9 ft correction 19:15 - 22:10 2.92 DRILL P PROD1 FS=3150 ~ 2.55 bpm Ta bottom ~ 9457 ft and drill ahea . @9460 ft Op=3380 psi ~ 2.56 bpm DH W06=1200#'s CT WT=23600#'s Vibrations=5 (tried reduced rate still 5's) ROP=43 FPH NBI=22.9 deg C~ 9443 ft Ratty drilling that continues to roll the BHA around and frequent stalling. ~ 9525 ft slowed to 30 FPH drilling rate to be able to hold desired toolface and not keep stalling, however Vibrations are still 5 to 6. Op=2.62 bpm ~ 3400 psi DH WOB=610#'s Drilled to 9558.8 ft. Previous toolface problems require POOH for motor adjustment. 22:10 - 22:15 0.08 DRILL P PROD1 Wiper to window 22:15 - 00:00 1.75 DRILL N DFAL PROD1 POOH for AKO adjustment to increase DLS to 20's. Previous drilling conditions lead to problems holding tool face therefore not getting enough build to land on target. Open EDC, and POOH with Op=4.0 bbls ~ 4120 psi. (IA=7 OA=160 psi) PVT=272 bbls During POOH tested HOT by rotating toolface to the stops. Tool amped out and stop approximately 180 deg from stops, then when turned the opposite direction it rotated through the stops and amped out about 180 deg out again. This is a new tool from town and was the first run in the hole. PJSM while POOH on LD of BHA 6/21/2009 00:00 - 00:50 0.83 DRILL N DFAL PROD1 Tag up, flow check well. Stand back injector, LD BHA Bit came out 2 - 1 with broken cutters on nose and gauge of nose. Also changed out shaker screens and changed out HP filter in reel house that was washing out. 00:50 - 01:00 0.17 DRILL N DFAL PROD1 PJSM - on MU and PU of new build BHA. 01:00 - 01:35 0.58 DRILL N DFAL PROD1 PU BHA #4 with 2.4 AKO, rebuilt HCC bicenter bit, and new HOT. Stab on and test tools. Printed: 7/16/2009 4:49:33 PM • BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: C-15 Common Well Name: C-15 Spud Date: 2/17/1980 Event Name: REENTER+COMPLETE Start: 6/18/2009 End: 6/27/2009 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2009 Rig Name: NORDIC 2 Rig Number: Date j From - To Hours ' Task Code NPT Phase ~ Description of Operations 6/21/2009 01:35 - 02:55 1.33 DRILL N DFAL PROD1 RIH at min rate. 02:55 - 04:20 1.42 DRILL P PROD1 Log for GR Tie in from 9205 ft to 9233 ft Made -10 ft correction. Continue to log down from 9233 ft continuously for Whipstock RA tie in per well plan to 9490 ft Puts RA marker C~ 9446 ft 04:20 - 06:00 1.67 DRILL P PRODi FS=3040 psi ~ 2.55 Still really ratty conditions with stalling and rolling the BHA. Slowly drilling using controlled rate to help with vibrations and stalling. 9585 ft Op=3850 psi ~ 2.56 bpm DH W0B=1320#'s ROP=22 FPH Vibrations 3 to 4 ECD=9.98 ppg 06:00 - 08:00 2.00 DRILL P PROD1 Drill ahead from 9600'. OA increasing, IA pressure is not. Known hole in tbg at +/-7130'. Replace IA transducer, double check gauge and IA valve position in cellar. There is a slight blow of gas when IA is opened to atmosphere. Numerous stalls at 9657'. Noted rubber on shaker earlier. Motor appears to be shot. 08:00 - 10:00 2.00 DRILL P PROD1 Wiper to window. Circulate out of hole. 10:00 - 11:00 1.00 DRILL P PROD1 At surface. Get off well. Stand back BHA. Bit was 7-3 with chipped cutters on nose. Adjust AKO to 1.8 deg. MU Hycalog re-run razor bicenter. Check SPM screen in reel house. Some paint chips and minor metal pices only. 11:00 - 12:30 1.50 DRILL P PROD1 Stab coil. Get on well. Run in hole. Circ at min rate 1223 psi at 0.21 bpm in. 12:30 - 12:45 0.25 DRILL P PROD1 Log GR tie in from 9190'. Subtract 10.5' correction. Run in hole 12:45 - 15:30 2.75 DRILL P PROD1 Drill ahead from 9657'. 3080 psi fs at 2.57 bpm in/out. 200-300 psi tutor work 1-2k# dhwob. BHP/ECDlfVD: 4572 psi / 9.98 ppg / 8828 ft IA/OA/PVT: 17 psi / 51 psi / 278 bbls. ROP: 50-80 fph. Drill to 9800'. 15:30 - 16:00 0.50 DRILL P PROD1 Wiper trip to window. Hole smooth. 16:00 - 19:00 3.00 DRILL P PROD1 Drill ahead from 9800'. 30100 psi fs at 2.53 bpm in /out. Land build/turn at 9870'. Continue to drill ahead. Drilled to 9942.7 ft and appears that bit has given out as we keep stacking and no ROP 19:00 - 21:25 2.42 DRILL P PROD1 POOH for bit and to adjust down the AKO. Q=2.8 bpm on wiper out of hole 0=4.0 bpm in cased hole. On POOH having problems again with power to hydraulic Printed: 7/16/2009 4:49:33 PM ~ ~ BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: C-15 Common Well Name: C-15 Spud Date: 2/17/1980 Event Name: REENTER+COMPLETE Start: 6/18/2009 End: 6/27/2009 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2009 Rig Name: NORDIC 2 Rig Number: Date From - To ' Hours Task Code NPT Phase Description of Operations 6/21/2009 19:00 - 21:25 2.42 DRILL P PROD1 power pack and mud pumps. Power is "back feeding" to Hydraulic power pack while on assignment 4, change to assignment 2 got worse, went back to 4. Still POOH ~ 3.4 bpm. Nordic electrician is on the way to help trouble shoot. PJSM while POOH for LD of BHA. 21:25 - 22:30 1.08 DRILL P PROD1 Tag up and flow check well. Unstab and stand back injector. Blow down BHA and stand back in derrick. Bit was 4-1 and was ringing out. Change bit to new Trex Bi Center and adjust motor to 1.2 AKO. Stab on and test tools. 22:30 - 00:00 1.50 DRILL P PROD1 RIH with EDC closed at min rate. 6/22/2009 00:00 - 00:20 0.33 DRILL P PROD1 Log for GR tie in from 9190 ft to 9221 ft made -10 ft correction. 00:20 - 00:45 0.42 DRILL P PROD1 Continue to RIH Wiper in through open hole C~3 2.6 bpm 00:45 - 03:00 2.25 DRILL P PROD1 FS=3120 psi ~ 2.6 bpm Ta bottom r~ 9943 ft and stalled PU and "feather in". ~ ft O „=2.59 bpm ~ 3350 psi DH W0B=780#'s CT WT=23,300#'s ROP=106 FPH Den=8.72/8.78 ppg (both centrifuges on) ECD=10.08 ppg Vibrations=4 NBI=89.85 deg WH/IA/OA=77/20/262 psi PVT=267 bbls ROP's increased to 120 FPH with DH WOB=870 #'s and about 200-300 psi MW Drilled to 10,100 ft 03:00 - 03:55 0.92 DRILL P PROD1 Wiper to window Op=2.82/2.68 bpm ~ 3430 psi on trip to window. Qp=2.6 bpm ~ 3150 psi while RIH. 03:55 - 05:15 1.33 DRILL P PROD1 FS=3130 psi ~ 2.6 bpm Drill ahead from 10,100 ft fast. Qp=2.63 bpm r~ 3350 psi (drilling with 200 to 500 psi MW) DH W06=1220#'s ROP=125 FPH (still running on old H-13a mud with 700+ ft this well) Vibrations=5 Still running into hard spots but there short lived. Hard s ots ettin worse and ~ 10 186 ft GEO advised to dro an le. 05:15 - 07:30 2.25 DRILL P PROD1 Drilling conditions are slow and ratty again as were trying to dive back into formation. with TF=165 RT Back reamed to 10,150 ft and then back to bottom. Good wt transfer just bad drilling with slow ROP. ROP continues to deteriorate. Note tar in sample, which should not be there. 07:30 - 09:00 1.50 DRILL P PROD1 Make wiper trip to window. 3142 psi fs at 2.55 bpm in/out. Hole smooth. 09:00 - 10:00 1.00 DRILL P PROD1 Drill ahead to 10,252'. Drilling parameters indicate the bit is worn out. 10:00 - 12:30 2.50 DRILL P PROD1 Wiper trip to window. Open EDC. Circulate out of hole. Hold PJSM. Printed: 7/16/2009 4:49:33 PM ~ ~ BP EXPLORATION Operations Summary Report Page 5 of 10 ~ (Legal Well Name: C-15 Common Well Name: C-15 Spud Date: 2/17/1980 Event Name: REENTER+COMPLETE Start: 6/18/2009 End: 6/27/2009 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2009 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ~I Code ~; NPT Phase Description of Operations 6/22/2009 12:30 - 13:30 1.00 DRILL P PROD1 Get off well. Ustab coil. Change out bit from Hyc t-rex 4.25" bicent (1-1-) to used Hyc t-rex 3.75" DS49 style. Bit pulled was very balled up with several partially clogged ports. Stab coil. Test tools. Get on well. 13:30 - 15:15 1.75 DRILL P PROD1 Run in hole. Circ at min rate. 15:15 - 15:45 0.50 DRILL P PROD1 Log gr tie in from 9169'. Subtract 10' correction. Wiper to btm. 15:45 - 18:45 3.00 DRILL P PROD1 Drill ahead from 10,252'. 3032 psi fs at 2.50 in/out. 200-300 psi mtr work. New mud around. ROP: 50-70 fph. Drill to 10,331 ft Make a BHA Wiper -pulling tight @ 10,304 ft. Made 2 more BHA wipers (~3 10 fpm -clean. Drilled to 10,396 ft 18:45 - 20:15 1.50 DRILL P PROD1 Wiper to window ~ 2.8 bpm. Wiper was clean. 20:15 - 21:45 1.50 DRILL P PROD1 FS=2915 psi (~ 2.62 bpm Drill ahead from 10,396 ft. Drilling C~3 10,500 ft Op=2.62 bpm @ 3050 psi DH W0B=800#'s ROP=133 FPH Vibrations=l ECD=9.96 ppg Drilled to 10,552 ft 21:45 - 23:05 1.33 DRILL P PROD1 Wiper to window ~ 2.8 bpm 23:05 - 23:55 0.83 DRILL P PROD1 FS=2750 psi C~ 2.55 bpm Drill ahead from 10,552 ft ~ 10,577 ft Op=2.55 bpm ~ 29870 psi DH WOB=3000#'s ROP=149 FPH (been fast drilling with occasional hard spots) Den=8.62/8.69 ppg ECD=9.91 ppg Getting more hard spots and ratty drilling - GEO thinks we maybe out the top again. Drilled to 10,622 ft. 23:55 - 00:00 0.08 DRILL P PROD1 Slowly back ream C~3 5 min from 10,622 ft 6/23/2009 00:00 - 00:15 0.25 DRILL P PROD1 Continue slow back ream up to 10,560 ft and then slow wiper back to 10,622 ft 00:15 - 01:00 0.75 DRILL P PROD1 Drill ahead from 10,622 ft FS=2800 psi ~ 2.63 bpm Drilling with 200 to 300 psi MW and 100 to 125 FPH ROP's Started stacking out, Drilled to 10,700 ft 01:00 - 02:20 1.33 DRILL P PROD1 Wiper to tubing tail 0=2.8 bpm in open hole Qin7"=3.7bpm 02:20 - 02:35 0.25 DRILL P PROD1 Log for GR tie in ~ Whipstock RA Made +5 ft correction 02:35 - 03:25 0.83 DRILL P PROD1 Continue wiper to bottom ~ 2.5 bpm 03:25 - 04:40 1.25 DRILL P PROD1 Drill ahead from 10,704 ft FS=2840 psi C~? 2.6 bpm ~ 10,770 ft Op=3300 psi ~ 2.61 bpm DH W0B=2570#'s CT WT=17,300#'s Printed: 7/16/2009 4:49:33 PM i ~ BP EXPLORATION Operations Summary Report Page 6 of 10 Legal Well Name: C-15 Common Well Name: C-15 Spud Date: 2/17/1980 Event Name: REENTER+COMPLETE Start: 6/18/2009 End: 6/27/2009 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2009 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code'. NPT Phase Description of Operations 6/23/2009 03:25 - 04:40 1.25 DRILL P PROD1 ROP=151 FPH Vibrations = 0 Den=8.66/8.72 ppg PVT=384 bbls Drilled to 10,850 ft 04:40 - 06:05 1.42 DRILL P PROD1 Wiper to window C~ 2.8 bpm 10K over pull ~ 10,302 ft with a little MW and smaller OP ~ 10,228 ft on wiper out of hole. 06:05 - 09:15 3.17 DRILL P PROD1 Drill ahead from 10,850 ft. - FS=2880 ~ 2.6 bpm Drill in to 14N shale. ROP has slowed way down. 8-10K# overpulls. Call for additional kla-gard. 09:15 - 11:30 2.25 DRILL P PRODi Make wiper trip to window. 3087 psi fs at 2.69 bpm in/out. Hole smooth. 11:30 - 13:25 1.92 DRILL P PRODi Drill ahead from 10,995'. - 3050 psi fs at 2.60 bpm in/out. Bad ratt drillin - N14 shale TD called ~ 11 070 ft - 13:25 - 15:45 2.33 DRILL P PROD1 Wiper to 4-1/2" tubing Open EDC in 7" and jet out slowly 15:45 - 16:50 1.08 DRILL P PROD1 wait for N-14 shales to react. 16:50 - 17:10 0.33 DRILL P PROD1 The guys can't possibaly sit still and wait anymore! Log for GR tie in at RA marker ~ 9,446 ft. +3.5 ft correction 17:10 - 20:30 3.33 DRILL P PROD1 Continue to wait on shales. Close EDC, RIH thru window 20:30 - 21:20 0.83 DRILL P PROD1 Wiper to TD 2.65/3030 was clean until set down at 10930'. 41 k, 23k Work three times w/ 10k OP's w/ MW and get to 10945' 21:20 - 00:00 2.67 DRILL P PROD1 Ream shale 2.1/2800 from 10900' while taking 5-20' bites. Backream to 10700' 2.6/3080 while moving solids up the hole. 5-10k OP's common, 35k max OP. Cleanout to 11034' by midnite 6/24/2009 00:00 - 01:25 1.42 DRILL P PROD1 Finish CO wellbore to TD to ed at 11064' CTD 01:25 - 02:25 1.00 DRILL P PROD1 Wiper back to window 2.76/3500 was clean except for one OP at 10311' 02:25 - 02:35 0.17 DRILL P PROD1 Log tie-in to RA pip down from 9465', add 5.5' 02:35 - 03:25 0.83 DRILL P PROD1 Wiper to TD was clean and was tagged at 11066' 03:25 - 04:15 0.83 DRILL P PROD1 Wiper back to window was clean 04:15 - 06:00 1.75 DRILL P PROD1 POOH circ thru EDC 3.65/3900 Flag at 9000' EOP 06:00 - 07:30 1.50 DRILL P PROD1 LD drilling BHA and crew change 07:30 - 08:30 1.00 CASE RUNPRD Cut off SLB CTC and terminate E line 08:30 - 09:00 0.50 CASE P RUNPRD Pump slack out of reel over bung hole -Cut 310 ft of E line 09:00 - 09:30 0.50 CASE P RUNPRD Make up BTT CTC PT to 3500 psi Pull test to 35 K 09:30 - 10:00 0.50 CASE P RUNPRD RU to run liner while waiting of circulating sub to be machined and delivere . 10:00 - 10:30 0.50 CASE N WAIT RUNPRD Wait on machine shop and part to be delivered. 10:30 - 11:15 0.75 CASE P RUNPRD PJSM on running liner and Safety meeting with crews and Pat Archey 11:15 - 16:20 5.08 CASE P RUNPRD Make up liner assembly with 26 It's of 2-7/8" L-80 STL liner and 35 jt's 3-3/16" L-80 TC Printed: 7/16/2009 4:49:33 PM • ~ BP EXPLORATION From - To Hours Legal Well Name: C-15 Common Well Name: C-15 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date 6/24/2009 Operations Summary Report Start: 6/18/2009 Rig Release: 6/27/2009 Rig Number: Page 7 of 10 Spud Date: 2/17/1980 End: 6/27/2009 Task Code NPT Phase Description of Operations 11:15 - 16:20 5.08 ~ CASE ~ P 16:20 - 16:30 0.17 CASE P 16:30 - 16:45 0.25 CASE N 16:45 - 17:25 I 0.671 CASE I N 17:25 - 18:50 ~ 1.42 i CASE ~ P 18:50 - 19:05 ~ 0.25 ~ CASE ~ P 19:05 - 19:30 0.421 CASE P RUNPRD liner PU injector and stab on RUNPRD RIH with pumps off -Baker choke open. HMAN RUNPRD After crew change CT Driller advised that if the spread sheet was done right there could be 110 ft of a line left in the coil. POOH to PU 2 more jt's 2 3/8" PH-6 for worst case scenario. PJSM for adding PH-6 to BHA HMAN RUNPRD Stand back injector and PU 2 jnt's of PH-6 Tried to pump slack out and still only 2 or 3 ft left. Stab on injector. RUNPRD RIH with liner at min rate MIRU SWS cementers RUNPRD 9400' 0.21/1730 19'/min 42k, 26k RIH thru window until set down at 9682'. PUH 60' w/ 10k over until clean DLS is only 33 deg max, no TF changes RUNPRD RIH to set down at 9694'. Work to 9699'. PUH w/ 10-15k over until clean 9:30 - 19:35 19:35 - 20:00 .08 0.42 ASE CASE P P UNPRD RUNPRD RIH w/ wt loss at 9682', then work to 9711'. PUH w/ 20k over until clean at 9670' PUH thru window w/ shoe, clean. PUH to 9400' 9400' 0.23/1700 Wt chk 20'/min 42.2k, 24k-same as before RIH thru window, clean RIH 100'/min to wt loss at 9676', then 9711' and get to 9733'. PUH to 9660' w/ only 5k OP's at known set downs. RIH 80'/min and major wt loss at 9744'. Continue RIH 80'/min. Looks like we 'ust had to wi a out a led eat -9640' w/ the cementralizers. Wt loss at 10296', 10353'. No set downs in shale from 10900', but a little rough. RIH to TD tagged at 11076' CTD. Did not recip 20:00 - 20:45 0.75 CASE P RUNPRD Circ w/full returns at 0.2/1750. Stage up pump to 1.50/2520 w/ full returns. Remove mud from pits Safety mtg re: drop ball to release Move to ball drop position at 11068', 40k. Load and launch 5/8" steel ball w/ 1500 psi 20:45 - 21:30 0.75 CASE P RUNPRD Circ ball 1.85/2800 and heard it rolling for 14 bbls, but reel holds -20 bbls. Slow rate to 0.82/2160 about 10 bbls 64 seating. Circ 5 bbls past calc displ and ball did not seat. Deviation at SELRT is 8 deg 21:30 - 22:10 0.67 CASE N SFAL RUNPRD Recip pipe to 44k, circ 1.70/2640 another volume + 5 bbls w/o ball seating 22:10 - 22:50 0.67 CASE N SFAL RUNPRD Close inner reel valve. Pressure to 2000 psi. Open to CT and surge w/ 2.8 bpm Circ another volume 1.57/2530 w/o seating 22:50 - 00:00 1.17 CASE N SFAL RUNPRD Move to ball drop postion at 11067.6' w/ 41 k. Load and launch second 5/8" steel ball X) w/ 1500 psi. Circ ball 2.19/2980 and ~ heard it rolling (actually heard two balls rolling). Got one over the gooseneck after -5 bbls, second at 18.4 bbls. Circ first ball to seat 1.0/2190, but had no press incr. Incr rate 1.52/2530, cycle pump and attempt to get a ball on seat 6/25/2009 00:00 - 00:30 0.50 CASE N SFAL RUNPRD Recip CT. Continue to circ 1.5/2500 close to two volumes and a ball finally seated. Pressure up to 4370 psi and blow out ball Printed: 7/16/2009 4:49:33 PM ~ ~ BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: C-15 Common Well Name: C-15 Spud Date: 2/17/1980 Event Name: REENTER+COMPLETE Start: 6/18/2009 End: 6/27/2009 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2009 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task !, Code NPT Phase Description of Operations 6/25/2009 00:00 - 00:30 0.50 CASE N SFAL RUNPRD seat. PUH and verified released. Left TOL at 9025' ELMD 00:30 - 01:55 1.42 CEMT P RUNPRD Swap to 2% KCI w/ FR 2.65/3380 at start, 2.85/1910 at end Safety mtg re: cement Cementers batch up. Cement to wt at 0150 hrs. Swap to biozan 1.50/640 and pump to reel 01:55 - 02:25 0.50 CEMT P RUNPRD PT cement line thru MM at 4000, thru bypass at 6500 psi SWS load reel w/ 22.0 bbls 15.8# G cement w/ latex at 86F at 2.11/1370, 2.11/2600 Wash up cement line 02:25 - 03:15 0.83 CEMT P RUNPRD Dis lace cement with 60 bbls 2 ppb biozan 2.07/750 followed by KCI. Zero out MM w/ cement at ported sub. SD pump w/ 2 bbls of cement left above SELRT 2.0/1500. PUH 39.5k 13' above up wt. Circ 5.0 bbls at 1.5/950 while exhausting 2 bbls of cement followed by 3 bbls of biozan. Open Baker choke. RBIH and sting in from 11064.0' and stack wt back to 11074'. Close choke, pressure up w/ 0.3 bbls and sheared LWP at 1370 psi. Incr rate and displace LWP at 1.62/1500 and landed near calc disp of 12.7 bbls. CIP 0305 hrs. Had full returns thru-out. Est TOC at 9250'. Pressure up to 2500 psi and held. Open choke and no flow back 03:15 - 05:05 1.83 CEMT P RUNPRD Pressure up CT to 710 psi and unsting. PUH 38.Ok, clean POOH replacing voidage w/ biozan 05:05 - 06:00 0.92 CEMT P RUNPRD LD 4 jts CSH. LD SELRT tool. Recovered both balls. Also found several strands of a-line armor wire in ball catcher 06:00 - 06:20 0.33 CEMT P RUNPRD Crew change, walk arounds, spill champ, and PJSM. 06:20 - 06:40 0.33 CEMT P RUNPRD RD from liner run and cement job Send out SELRT tools. 06:40 - 07:30 0.83 EVAL P LOWERi RU to run millin to in BHA. 07:30 - 10:20 2.83 EVAL P LOWERI PU clean out /logging assembly with 60 jt's of 1-1/4" CSH and 4 Jt's 2-3/8 PH6. Stab on injector and connect up the SLB memory logging depth recorder 10:20 - 11:50 1.50 EVAL P LOWERI RIH @ min rate WT check C~3 8900 35K up wt, R WT=21,700#'s FS=1930 psi ~ 1.5 bpm trip set ~ 2200 psi Pumps off tag ~ 9039 ft uncorrected depth 11:50 - 12:40 0.83 EVAL P LOW ER1 PUH and 0=1.44 bpm ~ 1840 psi Trip reset to 2200 psi Ease back to profile eing any pressure cnange- ana weignr mii a time and then wait until the weight mills ~ 9041.3 ft take the brake off and no indication of MW Ta bottom ~ 10,861 ft. PUH and to a 0,8 uncorrected de th. Check memory logging depths to Coil depths 13:45 - 14:45 1.00 EVAL P LOWERI Log up C~3 60 ft/min to 8,000 ft. 14:45 - 16:25 1.67 EVAL P LOWERI Log down ~ 30 ft/min to PBTD. 16:25 - 18:15 1.83 EVAL P LOWERi POOH laying in high vis FloPro pert pill._ advance to 9052 ft PUH to 9029 ft clean. Dry drift profile was clean. 12:40 - 13:45 1.08 EVAL P LOWERI Clean out liner to PBTD ~ 1.44 bpm -Clean. ain 1 61 ft EOP flag ~ 8300 ft (tied in with memory log) Printed: 7/16/2009 4:49:33 PM BP EXPLORATION Operations Summary Report Page 9 of 10 Legal Well Name: C-15 Common Well Name: C-15 Spud Date: 2/17/1980 j Event Name: REENTER+COMPLETE Start: 6/18/2009 End: 6/27/2009 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2009 Rig Name: NORDIC 2 Rig Number: Date ~i From - To Hours Task Code ~ NPT ! Phase Description of Operations 6/25/2009 18:15 - 18:45 0.50 EVAL P LOW ER1 Break off injector, drop ball Crew change/safety mtg Found more a-line wire strands in upper MHA chks 18:45 - 22:00 3.25 EVAL P LOWERI Unable to get ball on seat POOH standback CSH (wet) LD 10 jts CSH. Found more wire in MHA above circ ball seat. Ball was on seat LD MCNL tool. LD mill and motor. No wear on mill 22:00 - 23:00 1.00 EVAL P LOWERI Fill hole w/ 3 bbls Initial conditions WHP=O, IA =17, OA=18 PT wellbore (liner lap) w/ 1.4 bbls of 2% KCI to 2096 psi for 30 minutes Final conditions WHP=2036, IA 20, OA 18 Good liner lao test (and aood PxA cement iob!1 23:00 - 00:00 1.00 PERFOB P 6/26/2009 00:00 - 01:00 1.00 (EVAL ~ P 01:00 - 01:15 0.25 PERFOB~ P 01:15 - 02:30 1.25 PERFO P 02:30 - 02:40 0.17 PERFO~ P 02:40 - 04:20 1.67 PERFO P 04:20 - 06:45 2.42 PERFO P 06:45 - 07:10 0.42 PERFOB~ P 07:10 - 07:30 0.33 PERFO P 07:30 - 09:30 2.001 PERFOB~ P 09:30 - 10:45 1.25 PERFO P 10:45 - 11:00 0.25 PERFO P 11:00 - 12:50 1.83 PERFO P 12:50 - 13:35 0.75 PERFO P 13:35 - 14:00 0.42 WHSUR P 14:00 - 14:20 0.33 WHSUR P 14:20 - 14:45 0.42 WHSUR P 14:45 - 14:55 0.17 WHSUR P 14:55 - 15:15 0.33 WHSUR P 15:15 - 15:40 0.42 WHSUR P 15:40 - 16:20 0.67 WHSUR P 16:20 - 16:25 0.08 WHSUR P 16:25 - 16:35 0.17 WHSUR P 16:35 - 16:40 I 0.081 WHSUR I P LOWERI Load pert guns in pipeshed Circ CT to bunghole 3.0/1290 1.5 volumes to remove any additional wire. Found one 3" piece LOWERI WO CNL log data and send to town TOL ~ 9022' PBD ~ 10852' ELMD measured on down as Layout pert guns in pipeshed LOWERI Safety mtg re: MU pert guns LOWERI MU 27 pert guns and blanks Install firing head and MHA LOWERI Safety mtg re: MU CSH LOW ER1 RIH w/ 25 stds of CSH + 2 jts of PH6 LOWERI RIH circ 0.30/125 Tag bottom ~ 10,861.9 ft uncorrected. LOWERi PUH and practice firing sequence for a fire guns LOWERI RIH to (~ 10,861.1 ft PU to B/O wt (~ 10859 ft Correct to 10,848 ft (ELMD of corrected PBTD from memory logging in up pass) PU 6 ft to 10 842 ft and start firin se uence. . PUH slowly C~ 1 fpm Good indications of fire on de th of 10 840 ft for bottom shot LOWERI POOH circulating across the top. PJSM for LD of BHA while POOH LOWERI Stand back 25 stands of CSH and LD the rest of BHA. LOWERI PJSM for LD of pert guns LOWERI LD 27 erf uns LOWERI RD from pulling pert guns. POST PU nozzle BHA for FP. Stab on injector POST RIH with nozzle to 2050 ft. POST Wait on LRHOS POST PJSM with LR HOS on loading McOH into reel. POST RU LRHOS and PT to 3500 psi POST Load reel with 38 bbls of McOH and circulate to the nozzle. POST POOH displacing KCL with 60/40 McOH. Left 280 ft void in 4-1/2 tubing. POST Tag up close swab, and PJSM POST Unstab injector, and stand back. LD nozzle assembly Install night cap POST Open Swab valve and flow check well. Printetl: 7/16/2009 4:49:33 PM BP EXPLORATION Operations Summary Report Legal Well Name: C-15 Common Well Name: C-15 Event Name: REENTER+COMPLETE Start: 6/18/2009 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2009 Rig Name: NORDIC 2 Rig Number: Page 10 of 10 ~ Spud Date: 2/17/1980 End: 6/27/2009 Date ', From - To Hours Task Code NPT i Phase Description of Operations 6/26/2009 16:35 - 16:40 0.08 WHSUR P POST WHP= -15 psi, it's on a vac. 16:40 - 17:00 0.33 WHSUR P POST Dry rod in BPV. and clean up rig floor. 17:00 - 20:00 3.00 RIGD N SFAL POST RU and cut coil to try and find damaged E line. Cut off 300' 20:00 - 22:30 2.501 RIGD N SFAL POST 22:30 - 00:00 1.50 RIGD N SFAL POST 6/27/2009 00:00 - 00:20 0.33 BOPSU P POST 00:20 - 03:00 2.67 BOPSU P POST and found no birdnest Remove hardline in reel and look for strands-none. Assume source of stranding is in CT about 14 bbls from reel end based on 1st ball stopping in that area (when trying to release from liner) Nordic 3rd party crane inspector on location MIRU SWS N2. Start cool down and charge pump had a leak. RDMO N2 unit. WO second pumper to RD off of service CT job and mob to location. RU N2 pumper. PT C~ 4000. Displace CT w/ N2 while taking KCI returns to tiger tank. Bleed off CT. Safety mtg to pull back Pull CT out of injector and back to reel and secure Set injector on legs in prep for rig move Safety mtg re: ND BOPE ND BOPE. NU tree cap SWS fin remove hardline in reel house RREL ~ 0300 hrs Future operations will be found under B-14 Printed: 7/16/2009 4:49:33 PM • r~,~r BAILER NU~NE~ INTEQ North America -ALASKA - BP Prudhoe Bay PB C Pad C-15 -Slot 15 C-15A Survey: MWD Survey Report -Geographic 24 June, 2009 by ~,ar `~ s INTEQ Survey Repoli -Geographic Company: North America -ALASKA - BP <iocal Co-ordinate Reference: :Project: Prudhoe Bay TVD Reference: Site: PB C Pad MD Reference: WeII: C-15 North Reference: Weilbore: C-15A Survey Calculation Method: Design: C-15A Database: Well G15 -Slot 15 Mean Sea Level 17:15 2/17/1980 00:00 @ 62.70ft (generic drillinc True Minimum Curvature EDM .16 - Anc Prod - WH24P *roject Prudhoe Bay, North Slope,. UNITED STATES Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level 3eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor .Site PB C Pad, TR-11-14 Site Position: Northing: 5,957,218.72ft Latitude: 70° 17' 22.367 N From: Map Easting: 662,550.03ft Longitude: 148° 41' 2.797 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.24 ° Wel C-15 API No 500292042700 Well Position +N/-S 0.00 ft Northing: 5,960,988.00 ft Latitude: 70° 17' 59.094 N +EI-W 0.00 ft Easting: 664,132.00 ft Longitude: 148° 40' 14.310 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Welibore C-15A API No 500292042701 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2008 4/20/2009 22.76 80.92 57,707 - - Design - C-15A - - - _- Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,400.00 Vertical Section: Depth From (TVD) +N/-S +EI-W Direction (f4) (ft) ? (ft) (°) -33.00 0.00 0.00 274.58 Survey Program Date: 6/24/2009 From To (ft) (ft) Survey (Wellbore) Tool'Name Description 100.00 9,400.00 1 : Sperry-Sun BOSS gyro multi (C-15) BOSS-GYRO Sperry-Sun BOSS gyro multishot 9,436.00 11,066.00 MWD (C-15A) MWD MWD -Standard 6/24/2009 12:31:19PM Page 2 COMPASS 2003.16 Build 70 BAIQR ^ • ~or~s INTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB C Pad Well: C-15 Wellbore: C-15A Resign; C-15A Survey Survey Report -Geographic ~ bP Local Co-ordinate Reference: Well G15 -Slot 15 TVD Reference:.. Mean Sea Level MD Reference: 17:15 2/17/1980 00:00 @ 62.70tt (generic drillinc North Reference: True Survey Calculation Method: Minimum Curvature batabase: EDM .16 - Anc Prod - WH24P Measured TVD Below Depth Inclination Azimuth System +N/~ 9 400.00 24.32 274.90 8 646.69 -511.93 TIP 9,436.00 24.07 275.29 8,679.52 KOP ~ 9,456.82 25.58 274.00 8,698.42 9,484.98 27.28 272.00 8,723.64 9,515.52 28.22 270.00 8,750.66 9,545.35 29.99 266.50 8,776.73 9,559.79 31.92 265.50 8,789.11 j 9,581.77 36.16 267.36 8,807.32 9,609.03 42.84 276.87 8,828.36 9,638.29 48.25 281.93 8,848.85 9,672.67 53.51 289.84 8,870.56 9,707.55 60.01 292.77 8,889.67 9,736.04 65.17 294.00 8,902.78 9,770.78 71.60 294.64 8,915.57 9,797.28 76.63 294.55 8,922.82 ~! 9,824.18 82.00 294.48 8,927.81 ~I 9,855.41 88.46 295.01 8,930.40 i, 9,886.43 88.62 291.12 8,931.20 ~ 9,916.01 89.94 286.73 8,931.57 9,948.46 90.12 282.70 8,931.55 ~ 9,981.26 89.66 279.51 8,931.61 10,016.16 IC 89.51 276.54 8,931.87 I 10,051.79 87.82 274.83 8,932.70 10,082.35 86.31 279.79 8,934.26 j 10,106.47 86.49 283.14 8,935.78 10,138.34 88.65 287.35 8,937.13 10,171.36 90.64 294.48 8,937.33 10,207.74 89.20 299.67 8,937.38 10,237.23 85.73 301.33 8,938.69 10,268.21 84.47 303.30 8,941.33 !i 10,304.61 83.60 308.13 8,945.12 '~ 10,332.28 85.27 311.16 8,947.80 10,360.54 87.17 314.72 8,949.67 10,391.16 88.59 320.19 8,950.80 10,421.41 87.76 324.27 8,951.76 10,451.03 88.28 326.51 8,952.79 10,481.37 88.99 322.78 8,953.51 10,515.92 88.62 317.71 8,954.23 10,545.44 88.34 314.60 8,955.02 10,575.36 89.08 311.03 8,955.69 10,611.59 88.53 306.40 8,956.45 10,649.95 88.56 301.86 8,957.42 10,680.77 89.57 306.52 8,957.92 10,714.98 88.68 311.76 8,958.45 10,743.00 88.74 316.26 8,959.08 10,771.10 89.32 320.10 8,959.55 10,800.09 89.54 324.39 8,959.84 10,837.21 90.95 329.96 8,959.68 10,863.13 92.98 334.03 8,958.79 10,893.91 90.09 337.61 8,957.97 ~, 10,928.96 89.94 342.24 8,957.96 ~ 10,958.60 90.71 345.27 8,957.79 10,989.52 95.17 349.01 8,956.21 +EI_W (~) -2,688.15 Map Map Northing Fasting (ft) (ft) Latitude 5,960,417.51 661,455.86 70° 17' 54.054 N Longitude 148° 41' 32.672 W j -510.62 -2,702.84 5,960,418.50 661,441.14 70° 1T 54.067 N 148° 41' 33.100 W' -509.92 -2,711.55 5,960,419.02 661,432.42 70° 17' 54.074 N 148° 41' 33.354 W -509.27 -2,724.07 5,960,419.39 661,419.89 70° 17' 54.080 N 148° 41' 33.719 W -509.02 -2,738.29 5,960,419.33 661,405.67 70° 17' 54.083 N 148° 41' 34.133 W -509.48 -2,752.78 5,960,418.55 661,391.19 70° 17' 54.078 N 148° 41' 34.556 W -510.00 -2,760.19 5,960,417.87 661,383.80 70° 17' 54.073 N 148° 41' 34.772 W -510.75 -2,772.47 5,960,416.85 661,371.54 70° 17' 54.065 N 148° 41' 35.130 W -510.01 -2,789.74 5,960,417.21 661,354.26 70° 17' 54.073 N 148° 41' 35.633 W -506.56 -2,810.31 5,960,420.21 661,333.61 70° 17' 54.106 N 148° 41' 36.233 W -499.21 -2,835.90 5,960,427.00 661,307.87 70° 17' 54.179 N 148° 41' 36.979 W -488.59 -2,863.05 5,960,437.03 661,280.50 70° 17' 54.283 N 148° 41' 37.771 W -478.55 -2,886.26 5,960,446.56 661,257.08 70° 17' 54.382 N 148° 41' 38.447 W -465.25 -2,915.67 5,960,459.21 661,227.39 70° 17' 54.512 N 148° 41' 39.305 W -454.65 -2,938.84 5,960,469.30 661,203.99 70° 17' 54.617 N 148° 41' 39.980 W -443.69 -2,962.88 5,960,479.74 661,179.72 70° 17' 54.724 N 148° 41' 40.681 W -430.67 -2,991.13 5,960,492.14 661,151.20 70° 17' 54.852 N 148° 41' 41.505 W -418.52 -3,019.66 5,960,503.66 661,122.41 70° 17' 54.972 N 148° 41' 42.336 W -408.93 -3,047.63 5,960,512.63 661,094.24 70° 17' 55.066 N 148° 41' 43.152 W -400.69 -3,079.01 5,960,520.19 661,062.69 70° 17' 55.147 N 148° 41' 44.067 W -394.37 -3,111.19 5,960,525.80 661,030.38 70° 17' 55.209 N 148° 41' 45.005 W -389.50 -3,145.74 5,960,529.91 660,995.73 70° 17' 55.256 N 148° 41' 46.012 W -385.97 -3,181.18 5,960,532.67 660,960.23 70° 17' 55.291 N 148° 41' 47.046 W -382.09 -3,211.45 5,960,535.89 660,929.89 70° 17' 55.329 N 148° 41' 47.928 W -377.31 -3,235.03 5,960,540.15 660,906.20 70° 17' 55.376 N 148° 41' 48.616 W -368.93 -3,265.75 5,960,547.85 660,875.32 70° 17' 55.458 N 148° 41' 49.511 W -357.16 -3,296.57 5,960,558.95 660,844.25 70° 17' 55.574 N 148° 41' 50.410 W -340.60 -3,328.95 5,960,574.79 660,811.51 70° 17' 55.737 N 148° 41' 51.354 W -325.65 -3,354.33 5,960,589.18 660,785.82 70° 17' 55.883 N 148° 41' 52.094 W -309.15 -3,380.41 5,960,605.11 660,759.38 70° 17' 56.046 N 148° 41' 52.854 W -288.03 -3,409.80 5,960,625.59 660,729.54 70° 17' 56.253 N 148° 41' 53.711 W -270.46 -3,431.00 5,960,642.69 660,707.96 70° 17' 56.426 N 148° 41' 54.330 W -251.25 -3,451.64 5,960,661.44 660,686.91 70° 17' 56.615 N 148° 41' 54.932 W -228.72 -3,472.32 5,960,683.51 660,665.74 70° 17' 56.836 N 148° 41' 55.535 W -204.82 -3,490.84 5,960,707.00 660,646.71 70° 17' 57.071 N 148° 41' 56.075 W -180.46 -3,507.65 5,960,730.98 660,629.37 70° 17' 57.311 N 148° 41' 56.565 W -155.73 -3,525.20 5,960,755.33 660,611.29 70° 17' 57.554 N 148° 41' 57.077 W -129.18 -3,547.28 5,960,781.38 660,588.63 70° 17' 57.815 N 148° 41' 57.721 W -107.90 -3,567.72 5,960,802.21 660,567.74 70° 17' 58.024 N 148° 41' 58.317 W -87.57 -3,589.66 5,960,822.05 660,545.36 70° 17' 58.224 N 148° 41' 58.957 W -64.93 -3,617.91 5,960,844.07 660,516.62 70° 17' 58.447 N 148° 41' 59.781 W -43.42 -3,649.65 5,960,864.89 660,484.42 70° 17' 58.658 N 148° 42' 0.707 W -26.10 -3,675.13 5,960,881.63 660,458.57 70° 17' 58.828 N 148° 42' 1.450 W -4.52 -3,701.65 5,960,902.63 660,431.59 70° 17' 59.040 N 148° 42' 2.223 W 14.94 -3,721.79. 5,960,921.64 660,411.03 70° 17' 59.231 N 148° 42' 2.811 W 35.87 -3,740.52 5,960,942.16 660,391.84 70° 17' 59.437 N 148° 42' 3.357 W 58.79 -3,758.27 5,960,964.68 660,373.60 70° 17' 59.663 N 148° 42' 3.875 W 89.97 -3,778.38 5,960,995.41 660,352.82 70° 17' 59.969 N 148° 42' 4.462 W 112.83 -3,790.54 5,961,018.01 660,340.16 70° 18' 0.194 N 148° 42' 4.816 W 140.89 -3,803.14 5,961,045.78 660,326.95 70° 18' 0.470 N 148° 42' 5.184 W 173.80 -3,815.17 5,961,078.42 660,314.21 70° 18' 0.793 N 148° 42' 5.535 W 202.26 -3,823.46 5,961,106.69 660,305.30 70° 18' 1.073 N 148° 42' 5.777 W 232.35 -3,830.33 5,961,136.62 660,297.77 70° 18' 1.369 N 148° 42' 5.978 W 6/24/2009 12:31:19PM Page 3 COMPASS 2003.16 Build 70 ~%/ swtaas INTEQ Company: Project: Site: Well: Wellbore: Design: Survey • Survey Report -Geographic ~ bP North America -ALASKA - BP 'Local Co-ordinate Reference: Well G15 -Slot 15 Prudhoe Bay 'TVD Reference: Mean Sea Level PB C Pad MD Reference: ' 17:15 2/17/1980 00:00 @ 62.70ft (generic drillinc `; C-15 North Reference:: True C-15A Survey Calculation Method: Minimum Curvature C-15A Database: EDM .16 - Anc Prod - WH24P Measured TVD Belovu: Map Map Depth Inclination Azimuth System +N/~ +E/_yy Northing Fasting (ft) (°} (°} (ft} (ft) (ft) (ft) (ft) Latitude Longitude 11,019.01 95.88 351.42 8,953.37 261.27 -3,835.32 5,961,165.42 660,292.15 70° 18' 1.654 N 148° 42' 6.124 W 11,066.00 95.88 351.42 8,948.55 307.49 -3,842.29 5,961,211.48 660,284.17 70° 18' 2.108 N 148° 42' 6.328 W TD 6/24/2009 12:31:19PM Page 4 COMPASS 2003. i 6 Build 70 ~.r ss • Survey Report -Geographic ~~. ~ ~.~ by .Company: North America -ALASKA - BP Local,Co-ordinate Reference: Well G15 -Slot 15 Project: Prudhoe Bay TVD Reference: Mean Sea Level -Site: PB C Pad MD Reference: 17:15 2/17/1980 00:00 @ 62.70ft (generic drillinc Well:: C-15 North Reference: True Wellbore: C-15A Survey Calculation Method: Minimum Curvature Design: C-15A Database: EDM .16 - Anc Prod - WH24P Targets Target Name - hiUmiss target Dip Angle Dip Dir. TVD +N/S +E/-W ':Northing Easting -Shape (°) (°) (ft) (ft) (fty (ft) (ft) Latitude Longitude C-15A Fault 3 0.00 0.00 0.00 531.31 -4,081.65 5,961,430.00 660,040.00 70° 18' 4.308 N 148° 42' 13.310 W - survey misses target center by 8820.17ft at 9400.OOft MD (8646.69 TVD, -511.93 N, -2688.15 E) - Polygon Point 1 0.00 531.31 -4,081.65 5,961,430.00 660,040.00 Point 2 0.00 685.71 -3,823.20 5,961,590.00 660,295.00 C-15A Target 2 0.00 0.00 8,940.00 -346.56 -3,275.58 5,960,570.00 660,865.00 70° 17' 55.678 N 148° 41' 49.798 W - survey misses target center by 18.09ft at 10155.54ft MD (8937. 38 TVD, -363.28 N, -3281.98 E ) - Paint C-15A Target 1 0.00 0.00 8,935.00 -430.59 -3,092.36 5,960,490.00 661,050.00 70° 17' 54.853 N 148° 41' 44.456 W - surrey misses target center by 32.26ft at 9955.81ft MD (8931.54 TVD, -399. 12 N, -3086.18 E) - Point C-15A Fault 2 0.00 0.00 0.00 30.12 -3,347.37 5,960,945.00 660,785.00 70° 17' 59.383 N 148° 41' 51.896 W - survey misses target center by 8688.70ft at 9400.OOft MD (8646.69 TVD, -511.93 N, -2688.15 E) - Polygon Point 1 0.00 30.12 -3,347.37 5,960,945.00 660,785.00 Point 2 0.00 193.34 -3,263.78 5,961,110.00 660,865.00 C-15A Target 3 0.00 0.00 8,947.00 -222.11 -3,477.92 5,960,690.00 660,660.00 70° 17' 56.901 N 148° 41' 55.698 W - survey misses target center by 4.03ft at 10399.69ft MD (8951.0 3 TVD, -222. 11 N, -3477.72 E) - Point C-15A Fault 1 0.00 0.00 0.00 -548.85 -2,944.89 5,960,375.00 661,200.00 70° 17' 53.690 N 148° 41' 40.156 W -survey misses target center by 8650.57ft at 9400.OOft MD (8646.69 TVD, -511.93 N, -2688.15 E) - Polygon Point 1 0.00 -548.85 -2,944.89 5,960,375.00 661,200.00 Point 2 0.00 -491.70 -2,813.60 5,960,435.00 661,330.00 Point 3 0.00 -215.27 -2,417.44 5,960,720.00 661,720.00 Point4 0.00 -491.70 -2,813.60 5,960,435.00 661,330.00 C-15A Target 4 0.00 0.00 8,952.00 415.21 -3,804.10 5,961,320.00 660,320.00 70° 18' 3.168 N 148° 42' 5.216 W - survey misses target center by 114.34ft at 11066.OOft MD (8948.55 TVD, 307.49 N, -3842.29 E) - Point C-15A Polygon 0.00 0.00 0.00 -264.86 -3,123.75 5,960,655.00 661,015.00 70° 17' 56.482 N 148° 41' 45.373 W - survey misses target center by 8661.18ft at 9400.OOft MD (8646.69 TVD, -5 11.93 N, -2688.15 E) - Polygon Point 1 0.00 -264.86 -3,123.75 5,960,655.00 661,015.00 Point 2 0.00 -57.69 -3,449.33 5,960,855.00 660,685.00 Point 3 0.00 502.35 -3,672.16 5,961,410.00 660,450.00 Point 4 0.00 320.25 -4,036.25 5,961,220.00 660,090.00 Point 5 0.00 -199.36 -3,832.54 5,960,705.00 660,305.00 Point 6 0.00 -565.33 -3,335.38 5,960,350.00 660,810.00 Casing Points Measured Vertical C asing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 11,066.00 8,948.55 2.875" 2.875 4.125 6/24x1009 12:31:19PM Page 5 COMPASS 2003.16 Build 70 BA ~R ^s FR/isl~ ~ Survey Report -Geographic • bP 1NTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Site:. PB C Pad Well: C-15 Wellbore: C-i5A Design: C-15A Local Co-ordinate Reference: ' Well G15 -Slot 15 ND Reference: Mean Sea Level MD Reference: 17:15 2/17/1980 00:00 @ 62.70ft (generic drillinc North Reference: True Survey Calculation Method:- Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Targets Target Name - hit/miss target Dip Angle Dip'Dir, iTVD +N/~ +EI-W Northing Easting -Shape (°) (°) (ttj (ft) (ft) (ft) (ft) Latitude Longitude C-15A Fault 3 0.00 0.00 0.00 531.31 -4,081.65 5,961,430.00 660,040.00 70° 18' 4.308 N 148° 42' 13.310 W - survey misses target center by 8820.17ft at 9400.OOft MD (8646.69 TVD, -5 11.93 N, -2688.15 E) - Polygon Point 1 0.00 531.31 -4,081.65 5,961,430.00 660,040.00 Point 2 0.00 685.71 -3,823.20 5,961,590.00 660,295.00 C-15A Target 2 0.00 0.00 8,940.00 -346.56 -3,275.58 5,960,570.00 660,865.00 70° 17' 55.678 N 148° 41' 49.798 W - survey misses target center by 18.09ft at 10155.54ft MD (8937. 38 TVD, -363.28 N, -3281.98 E) - Point C-15A Target 1 0.00 0.00 8,935.00 -430.59 -3,092.36 5,960,490.00 661,050.00 70° 17' 54.853 N 148° 41' 44.456 W - survey misses target center by 32.26ft at 9955.81ft MD (8931.54 TVD, -399. 12 N, -3086.18 E) - Point C-15A Fault 2 0.00 0.00 0.00 30.12 -3,347.37 5,960,945.00 660,785.00 70° 17' 59.383 N 148° 41' 51.896 W - survey misses target center by 8688.70ft at 9400.OOft MD (8646.69 TVD, -5 11.93 N, -2688.15 E) - Polygon Point 1 0.00 30.12 -3,347.37 5,960,945.00 660,785.00 Point 2 0.00 193.34 -3,263.78 5,961,110.00 660,865.00 C-15A Target 3 0.00 0.00 8,947.00 -222.11 -3,477.92 5,960,690.00 660,660.00 70° 17' 56.901 N 148° 41' 55.698 W - survey misses target center by 4.03ft at 10399.69ft MD (8951.0 3 TVD, -222 .11 N, -3477.72 E) - Point C-15A Fault 1 0.00 0.00 0.00 -548.85 -2,944.89 5,960,375.00 661,200.00 70° 17' 53.690 N 148° 41' 40.156 W -survey misses target center by 8650.57ft at 9400.OOft MD (8646.69 TVD, -5 11.93 N, -2688.15 E) - Polygon Point 1 0.00 -548.85 -2,944.89 5,960,375.00 661,200.00 Point 2 0.00 -491.70 -2,813.60 5,960,435.00 661,330.00 Point 3 0.00 -215.27 -2,417.44 5,960,720.00 661,720.00 Point 4 0.00 -491.70 -2,813.60 5,960,435.00 661,330.00 C-15A Target 4 0.00 0.00 8,952.00 415.21 -3,804.10 5,961,320.00 660,320.00 70° 18' 3.168 N 148° 42' 5.216 W -survey misses target center by 114.34ft at 11066.OOft MD (8948.55 TVD, 307.49 N, -3842.29 E ) - Point C-15A Polygon 0.00 0.00 0.00 -264.86 -3,123.75 5,960,655.00 661,015.00 70° 17' 56.482 N 148° 41' 45.373 W -survey misses target center by 8661.18ft at 9400.OOft MD (8646.69 TVD, -5 11.93 N, -2688.15 E) - Polygon Point 1 0.00 -264.86 -3,123.75 5,960,655.00 661,015.00 Point 2 0.00 -57.69 -3,449.33 5,960,855.00 660,685.00 Point 3 0.00 502.35 -3,672.16 5,961,410.00 660,450.00 Point 4 0.00 320.25 -4,036.25 5,961,220.00 660,090.00 Point 5 0.00 -199.36 -3,832.54 5,960,705.00 660,305.00 Point 6 0.00 -565.33 -3,335.38 5,960,350.00 660,810.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name.. (in) (~n) 11,066.00 8,948.55 2.875" 2.875 4.125 Survey Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,400.00 8,646.69 -511.93 -2,688.15 TIP 9,436.00 8,679.52 -510.62 -2,702.84 KOP __ _ 6/24/2009 12:31:19PM Page 6 COMPASS 2003.16 Build 70 ~~~ ~i~t! ~ Survey Report -Geographic • bP INTEQ Company: North America -ALASKA - BP ..Local Co-ordinate Reference: Well C-15 -Slot 15 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB C Pad MD Reference; 17:15 2/17/1980 00:00 @ 62.70ft (generic drillinc Well: C-15 North Reference: True Wellbore: C-15A Survey Calculation Method: Minimum Curvature Design: C-15A batabase: EDM .16 - Anc Prod - WH24P Targets Target Name - hit/miss target. Dip Angle .Dip Dir. `TVD +N/-S +El-W Northing Easting -Shape (°) (°) ({{) (ft) ($) (~) (ft) C-15A Fault 3 0.00 0.00 0.00 531.31 -4,081.65 5,961,430.00 660,040.00 - survey misses target center by 8820.17ft at 9400.OOft MD (8646.69 TVD, -511.93 N, -2688.15 E) - Polygon Point 1 0.00 531.31 -4,081.65 5,961,430.00 660,040.00 Point 2 0.00 685.71 -3,823.20 5,961,590.00 660,295.00 C-15A Target 2 0.00 0.00 8,940.00 -346.56 -3,275.58 5,960,570.00 660,865.00 - survey misses target center by 18.09ft at 10155.54ft MD (8937.38 TVD, -363.28 N, -3281.98 E) - Point C-15A Target 1 0.00 0.00 8,935.00 -430.59 -3,092.36 5,960,490.00 661,050.00 - survey misses target center by 32.26ft at 9955.81ft MD (8931.54 TVD, -399. 12 N, -3086.18 E) - Point C-15A Fault 2 0.00 0.00 0.00 30.12 -3,347.37 5,960,945.00 660,785.00 -survey misses target center by 8688.70ft at 9400.OOft MD (8646.69 TVD, -511.93 N, -2688.15 E) - Polygon Point 1 0.00 30.12 -3,347.37 5,960,945.00 660,785.00 Point 2 0.00 193.34 -3,263.78 5,961,110.00 660,865.00 C-15A Target 3 0.00 0.00 8,947.00 -222.11 -3,477.92 5,960,690.00 660,660.00 -survey misses target center by 4.03ft at 10399.69ft MD (8951.03 TVD, -222. 11 N, -3477.72 E) - Point C-15A Fault 1 0.00 0.00 0.00 -548.85 -2,944.89 5,960,375.00 661,200.00 -survey misses target center by 8650.57ft at 9400.OOft MD (8646.69 TVD, -5 11.93 N, -2688.15 E) - Polygon Point 1 0.00 -548.85 -2,944.89 5,960,375.00 661,200.00 Point 2 0.00 -491.70 -2,813.60 5,960,435.00 661,330.00 Point 3 0.00 -215.27 -2,417.44 5,960,720.00 661,720.00 Point 4 0.00 -491.70 -2,813.60 5,960,435.00 661,330.00 C-15A Target 4 0.00 0.00 8,952.00 415.21 -3,804.10 5,961,320.00 660,320.00 - survey misses target center by 114.34ft at 11066.OOft MD (8948.55 TVD, 307.49 N, -3842.29 E ) - Point C-15A Polygon 0.00 0.00 0.00 -264.86 -3,123.75 5,960,655.00 661,015.00 - survey misses target center by 8661.18ft at 9400.OOft MD (8646.69 TVD, -5 11.93 N, -2688.15 E) - Polygon Point 1 0.00 -264.86 -3,123.75 5,960,655.00 661,015.00 Point 2 0.00 -57.69 -3,449.33 5,960,855.00 660,685.00 Point 3 0.00 502.35 -3,672.16 5,961,410.00 660,450.00 Point 4 0.00 320.25 -4,036.25 5,961,220.00 660,090.00 Point 5 0.00 -199.36 -3,832.54 5,960,705.00 660,305.00 Point 6 0.00 -565.33 -3,335.38 5,960,350.00 660,810.00 Casing Points Latitude Longitude 70° 18' 4.308 N 148° 42' 13.310 W 70° 17' 55.678 N 148° 41' 49.798 W 70° 17' 54.853 N 148° 41' 44.456 W 70° 17' 59.383 N 148° 41' 51.896 W 70° 17' 56.901 N 148° 41' 55.698 W 70° 17' 53.690 N 148° 41' 40.156 W 70° 18' 3.168 N 148° 42' 5.216 W 70° 17' 56.482 N 148° 41' 45.373 W Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 11,066.00 8,948.55 2.875" 2.875 4.125 11,066.00 8,948.55 307.49 -3,842.29 TD Checked By: Approved By: Date: 6/24/2009 12:31:19PM Page 7 COMPASS 2003.16 Build 70 TREE= ~ 4-1/16 CNV WELLHEAD = : FMC .....~ ACTUATOR = AXELSON KB. ELEV = 54.39' BF. ELEV = 34.21' KOP = 3500' Max Angle= 96 @ 11019' Datum MD = 9573' Datum TV D = 8800' SS i 13-3/8" CSC, 72#, L-80, ID = 12.347" ~~ 2673' Minimum ID = 2.30" @ 9034' 3.70 DEPLOY SLV BUSHING, MILLED 7" TIEBACK LNR, 26#, iJ45?, .0371 bpf, ID = 6.184"? ~-j 8408' TOP OF 7" LNR 8409' 9-5/8" CSC, 47#, L-80, ID = 8.681" 8902' S OTES: 700 @ -9750' C-15A 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3244 3243 6 MMG DOME RK 16 07/10/09 3 5538 5303 33 KBG-2 SO BK 20 07/10/09 2 7180 6688 28 KBG-2 *DMY BK 0 08/14!07 1 8278 7693 22 KBG-2 DMY BK 0 02/14/06 *STATION #2 HAS DM Y w/EXTENDED PACKING 449$' 7" TNV TIEBACK w /HNGR (02/02/90) 8408' ~-~7" SEAL ASSY w/NO GO (02/02/90) 8969' -j 4-1 /2" HES X NIP, ID = 3.813" 8990' 7" X 4-1/2" BKR S-3 PKR 9013' 4-1/2" HES X NIP, ID = 3.813" I4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9046' 3-1/2" LNR, 9.2#, L-80 STL, .0087 bpf, ID = 2.992" 9076' 3.625" BKR WHIPSTOCK (05/21/09) I 9435' 3 RIP TAGS (05/21/09) 9445' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~-{ 9900' PERFORATION SUMMARY REF LOG: ????? ON XX/XXtXX ANGLEAT TOP PERF: 84 @ 10310' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10310 - 10380 O 06/26/09 2" 6 10430 - 10460 O 06/26/09 2" 6 10470 - 10520 O 06/26/09 2" 6 10540 - 10600 O 06/26/09 2" 6 10630 - 10775 O 06/26/09 2" 6 10790 - 10840 O 06/26/09 9025' 3.70" BKR DEPLOY SLV w /4" GS PROFILE, ID = 2.30" 9034' DEPLOY SLV BUSHING, MILLED ID = 2.30" 9034' 4-1/2" HES XN NIP, MILLED ID = 3.80" (05/26/09) (BEHIND PIPS 9046' 4-1/2" WLEG, ID = 3.958" (BEHIND PIPE) 9076' 3-1/2" X 3-3/16" XO, ID = 2.786" 9250' TOP OF CEMENT (06/25/09) TOP OF WINDOW (C-15A) 9441' _ 10~ 00' ~ 3-3/16" X 2-7/8" XO, ID = 2.377" 3-3/16" LNR, 6.2#, L-80 TCII, I 10200' .0076 bpf, ID = 2.80" PBTD ~ 10856' r 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 11066' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/09/80 ORIGINAL COMPLETION 02/05/90 RWO 07/08/03 DAV/KK RWO 06/27/09 NORDIC2 CTD SIDETRACK (C-15A) 07/02/09 AK/TLH DRLG DRAFT CORRECTIONS 07/16/09 TFA/SV GLV C/O (07/10/09) PRUDHOE BAY UNIT WELL: G15A PERMff No: 2090520 API No: 50-029-20427-01 SEC 19, T11 N, R14E, 226' SNL & 1219' WEL BP Exploration (Alaska) 4 ~ I ~ S 1 ; ALASKA OIL A1~TI) GA5 COI~TSERQATIOIQ CO1~II~IISSIOI~T John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Pool, C-15A Well BP Exploration (Alaska) Inc. Permit No: 209-052 Surface Location: 226' FNL, 1219' FEL, SEC. 19, T 11 N, R 14E, UM Bottomhole Location: 1.85' FSL, 75' FEL, SEC. 1.3, T 11 N, R 13 E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill 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). Sincerely, Cathy oerster .} Commissioner DATED this ~ s day of May, 2009 cc: Department of Fish ~ Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. STATE OF ALASKA ~KA OIL AND GAS CONSERVATION C ISSION s~~ PERMIT TO DRILL 20 AAC 25.005 '~ ~ ~~~t~ ~~~'~ ~ 2009 y~~~~ f~~e~ ~~,s, ~nrnmission .~tR~ ::SUB 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU C-15A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11130' TVD 8952'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028305 & 028285 Oil Pool FEL, SEC. 19, T11 N, R14E, UM FNL, 1219 226 Top of Productive Horizon: R14E UM 3774' FEL SEC. 19 T11N 749' FNL 8. Land Use Permit: 13. Approximate Spud Date: June 1, 2009 , , , , , Total Depth: 185' FSL, 75' FEL, SEC. 13, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 23,560' 4b. Location of Well (State Base Plane Coordinates): Surface: x-664132 y-5960988 Zone-ASP4 10. KB Elevation (Height above GL): 62.7' feet 15. Distance to Nearest well Within Pool: 850' 16. Deviated Wells: Kickoff Depth: 8455 feet Maximum Hole An le: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3187 Surface: 2307 P m: n - in _ g .f. Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4_1/ ~~ ~-in^xsans" 9.3#/ .2# L-8 STL/TCII 211 2 ' 304's 11130' 1 6c Cla ' x z-~re° / 6.16# 1 g, PRESE NT WELL CONDITION S UMMARY (To be.completed forRedrill and Re-entry Operations) Total Depth MD (ft): 9900 Total Depth TVD (ft): 171 Plugs (measured): 9699' Effective Depth MD (ft): 9850 Effective Depth TVD (ft): 9124 Junk (measured): 9762' asing° Len th Size Cement Volume MD- TVD Conductor /Structural 11 rm r n 1 1 ' Surface 2642' 13-3/8" 3720 cu ft Ar i II 14 c ft Arctics II 267 ' 2 73' Intermediate 87 ' 9-5/8" 121 u ft I 'G' 130 AS I 8 2' 262' P in Liner 14 1' 7" 4 5 u I 409' - 9900' 7814' - 171' A ii n I T 'n -1/2" r N/ - 7 1 '- ' Perforation Depth MD (ft): 9700' - 9765' Perforation Depth TVD (ft): 8985' - 9045' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ 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 is true and correct. Contact Charles Reynolds, 564-5480 Printed Name Jo tuU Title Engineering Team Leader Prepared By NamelNumber Si nature ~ Phone 564-4711 Date l C~ Terrie Hubble, 56a-a628 Commission Use Onl Permit To Dnll N m r: v?090~50~ API Number: 50-029-20427-01-00 Permit Approval See cover letter for p ~ S/ii/o h r r m Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ~./ 7JSOaQS\ rO~~s~ `` Samples Req'd: Yes [1~No Mud Log Req'd: ,,^/Yes pp No a.SC~~~sl h\~\'MV'MV.t~t~J~Ca~~ST' HZS Measures: Yes ^ No Directional Survey Req'd: L10 Yes ^ No Other: APPR VED BY THE COMMISSION Date 5 ~ ~ ~ COMMISSIONER Form 10-401 Revised 12/2005 ~ suomrc m uupncate by BPXA Prudhoe Bay C-15A CTD Sidetrack Apri121, 2009 CTD Sidetrack Summary Pre-Rig Work: (Scheduled to begin on April 30, 2009) 1. MIT-IA - to 3000psi 2. MIT-OA - to 2000 psi 3. PT Master & Swab valve to 4500 psi. Drawdown test MV and SV to 0 psi 4. PPPOT-T, Function LDS 5. Pull Baker KB Straddle Packer from 4-1/2" tubing C~ 7,160'. 6. Drift well for whipstock to 9,520' which is top 3-1/2" tubing stub. 7. Set Whipstock with top at 9,435'. 8. Mill XN nipple to 3.80" using Left Handed Motor. 9. Downsqueeze cement past whipstock (This will P&A the existing perforations.) 10. Bleed IA, gas lift and production flowlines down to zero and blind flange. 11. Remove S-Riser, Remove wellhouse, level pad. 305- ~ ~ ~ Rig P&A and Sidetrack Operations: (Scheduled to begin on June 1, 2009 using Nordic rig 2) ' 1. MIRU Nordic Rig 2 2. NU 7-1/16" CT Drillin BOPE and test. i win ow t roug t e 7 4. Drill turn and. lateral section to 11,130'. 5. Run and cement a 3-3/16" x 2-7/8" L-80 liner string to 9,020'. 6. Make a cleanout run with mill and motor and SWS MGR-MCNL 7. Perforate well. ` 8. FP well to 2000' with McOH. Z'h'~ s ,pe~r~.`'C 9. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. `` 10. RDMO Nordic 2. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run gas lift design. 4. POP Well Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • AlI Class I wastes will go to Pad 3 for disposal. Hole size: 4.125" (bi-center bits used) Casing Program: fully cemented liner • 3-1/2", L-80 9.3# STL 9,020' - 9,050' and • 3-3/16", L-80 6.2# TCII 9,050' and - 10,000' and • 2-7/8", L-80 6.16# STL 10,000'md -11,130' and • A minimum of 24.3 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9,235' Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 90 deg at 9,946'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line - 23,560ft. • Distance to nearest well within pool - 850ft. (C-35B @ 9,846') Logging • MWD directional and Gamma Ray will be run over all of the open hole section. Hazards • The maximum recorded H2S level on C Pad was 25 ppm on well C-39A. • No planned fault crossings, calculated risk of lost circulation low. Reservoir Pressure • The reservoir pressure on C-15A is expected to be 3,187 psi at 8,800' TVDSS. (6.96 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,307 psi. C.R.Reynolds CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble E _ 6" CIW t+l£LLHEAD = . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .FMC . 14~TUATOR-= .... ................. ~. ELEV = . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54.39' . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . EF. ELEV = 34.21' KOP = 3500' Max Ankle = .. .... _ 34 ~ 6100' ~ Datum MD .................................. 9567' ......... Datum TVD = 8800' SS • ~ ~~ 13-3l8" CSG, 72*, L-80, ID = 12.347" Minimum ID ~ 2.37" 7160' 4-1a*2" KB STRADDLE PKR TOP OF 7" L.NR 9.518" CSG, 47#, L-80, ID = $.681" ~~ $902' 1 t2" TBG,12.s#, L-8D, .0152 bpf, ID = 3.958" ~ 90d6' TOP OF 3-112" TBG 951' PERFORATION SUMMARY REF LOG: SWS BHCS ON 03ro5180 ANGLE AT TOP PERF: 23 (~ 9618' Nate: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn1SgZ DATE 3-118" 4 9618 -964$ S 11 M 4189 3-118" 4 9658 - 97D8 S 11 M 4189 s° 4 s7oo - s71 o c oaro419o 2-118" 4 9728 - 97s2 C 02/90 2-11'8" 4 9752 - 9765 C 02191 3-112" TBG, 9.3~, L-80 EUE 8RD, .OOS7 bpf, ID = 2.992" P8 TD 7" LNR, 29*, L-80, .03"!1 bpf, ID = 6.184' FGSFi - E4iR 5" X 36' TBG CONVEYED PERF GUN (LIED). SHEAR RELEASED AND PUSHED TO BTM ON 2121 P90. DATE REV BY COMFITS DATE REV BY C0^NTS 93A98180 ORIGINAL CON~LETION 09ro1 roT TEL/SV ET PATCH 08!24„07 S f12~3P90 R~ IAPORKOHER 09M 1 ro7 JCMiPJC _ SET UPPER P,e~TCH ASSY /T~1~3 iDAYA(K RWO 12M 1 rob AKIPJC DRAWING CORRECTIONS 07123ro3 JCMlI'LH GLV C10 12M 3ro8 GJFISV SLUGGITS 06/27103 02116ro6 KSBIPAG GLV CAO !CORRECTIONS 08116107 KSB~JC GLV C10 (08M 4ro7 PRUDHOE BAY L~qT WELL: C-15 PERMIT No: 1791090 API No: 50-029-20427-~ 19, T11 N, R14E, 226' SNL 81219' iBP Espiontiai (Ah~ca) SAFETY MOTES: 2202' ~41l2" HES K Nom, ~ = 3.813" C;~LC I IFT MAM110RF1_S ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3244 3242 6 MMG DMY RK D 02M4ro6 5538 5303 33 kBG-2 DMY BK D 02M4ro6 2 7180 6688 28 KI3G-2 'DMY BK 0 08M4ro7 1 8278 7s93 22 KBG-2 DMY BK 0 02114ro6 " EXTENDED PACKNUG ( STRAFE PKR} 7160'-7246' 4102" BKR KB STRADDLE PKR, 10 = 2.37" $~9' 412" HES X Nom, ~ = 3.813 -~ 7" X4112" BKR S-3 PKR X13' 412" HES X N~, ID = 3.$13" L ~"~`' I 4112" HES XN NIP. ID = 3.725" 9046' 4112" UULEG, ~ = 3.958" 9582' -~3-1!2" OTIS XA SLR SLV, ID = 2.750" 9602' R/A LOCATOR SUB, ID= 2.992" 9603' - 9711' 4102" BLAST JOMITS ~~' DUMP SLUGGITS (08!27!03) 9712' .7" X 4102" BOT-3H PERM PKR, ID = 3 977T 412" X 3-112" X, ID = 2.992" . 9717' 3-12" 0715 X NIP, ID = 2.7'30" 9717' 3-12" XX PLUG (08l11l~~ 9720' 3-112" TUBING TAIL 9720' ELMD TT LOGGED 03f10/~ TREE _ 6" CNV ~JSELLHEAD = . . . . FMC .. ...................... .............. ...... .......... . .. ACTUATOR = ..................................... .. ..... OTIS ............................... KB. ELEV = ..................................... 54.39' ............................... BF. ELEV = ..................................... 34.21' ............................... KCP = ................................. 3500' ............................... . Max Angle = ..................................... 34 ~ 6100' ............................... Daium MD = 9567' Daum TVD = 8800' SS 13-3P8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.37" 7164' 4-1l2" KB STRAQDLE PKR TOP OF 7" LNR 9.518" CSG, 47#, L-80, ID = 8.881" ~-1 Proposed CT ~~ SAFETY ROTES: D Sidetrack 2202' i~4102" HES X NIP, ID = 3.813" 8409' 8902' I TOP3.102"X3.3M8"X2.718"LNRI ~41C2" TBG, 12.8#, L-80, .0152 bpf, ID = 3.958" TOC I whipstock I ITop3.102"stub I 9435' 2~ PERFORATION SUMMARY REF LOG: SWS BRCS ON 03105J80 ANGLE AT TOP PERF: 23 ~ 9618' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn!5gz DATE 3-118" 4 9618 - 9648 S 11 M 4189 3-115" 4 9658 - 9708 S 11 M 4189 5" 4 9700 - 9710 C 02f04/90 2-118" 4 9728 - 9752 C 02190 2-1 J'8" 4 9752 - 9765 C 02191 3-1 I2" TBG, 9.3#, L-80 EUE 8RD, 9720' .0087 bpf, ID = 2.992" PBTD 9831' 7" LNR, 29#, L•80, .0371 bpf, ID = 8.184" 9900' j3.12" XX PLUG (08/11P98) I 3.112" TUBING TAIL FISH -BKR 5" h 36' TBG CONb'EYEG FERF rLIP~I (UNFIRED). SHEAR RELE,~.SED AI'Jp FIJ'c~HED TO BThA Ohl 2 ~1 !'.30. DATE REV BY COMMENTS DATE REV BY COMMENTS 03!09180 ORIGINAL COMPLETION 09101!07 TEL!5V SET PATCH 8024!07 02105MJ0 RIG WORICOVER 09M 1!07 JCM!PJC SET UPPER PATCH ASSY 07/08!103 DAVIKK RWO 12M 1108 AKfPJC DRAVNNG CORRECTIONS 07!23!03 JCMITLH GLV C!O 12M 3!08 GJFISV SLUGGITS (OGl27!03) 02M 6!06 KSB!PAG GLV CIO !CORRECTIONS 03M 0!09 MSE PROPOSED CTD SIDETRACK 08M 6!07 KSB!FJr: GL''•:` ~=:it~ i i ~~ ~i 1 :},~t=i?'! 1 _ PRUDHOE BAY UNIT WELL: C-15A PERMIT No: API No: 50-029-20427-01 BP Exploration (Alaska) GAS LIFT MANDRELS ST MD TVD DEW TYPE VLV LATCH PORT DATE 4 3244 3242 6 MMG DMY RK 0 02M4106 5538 5303 33 K8G-2 DMY BK 0 02M4/06 2 7180 6688 28 KBG-2 "DMY BK 0 08M4!07 1 8278 7693 22 I~G-2 DMY BK 0 02M4106 E}CTENDED PACKING rjBBI1ND STRADDLE PKR) 7760'-7246' 4102" BKR KB STRADDLE PKR, ID = 2.37" to b? pull?d _< r?nm 8969' 412" HES X NIP, ID = 3.813" - 8990'X4102" BKR S-3 PKR 9073' 412" HES X NIP, ID = 3.813" 9030' 3-112" X NIPPLE ID = 2.813' 9034' 4112" HES XN NIP, ID mill?d to = 3.80" - 9046' 4102" W LEG, ID = 3.958" TSGR 9047` 311 B x 3-3M6" x 2-1A8" cmt'd and perf'ri I~ 11130' 9699• ~ DUM' SLUGGITS (08027/03) I 9712' 7"X4102" BOT-3H PERM PKR, ID = 3.25U' BP CTD BOP Stackup 2 3/8" Coil b ~ Welt: C-15A Rig: Nordic 2 Rig Floor to Top of Bag: 9.23' 7 1/16" H rill Annular, 5000 si (9.23') 7 1/16" 5000 si, RX-46 Blind Shears TOT 12.65' tt . K. 2 3/6" Combi's TOT 13.56' ,,.~;;, 7 1/16" 5000 si, RX-46 !Cil! f. ine 'hoke ~-~ Mud Cross 14.89' 2 1/16" 5000 si, RX-24 2 3/6" x 3 1!2' Variable Ram 16.10' 2 3/6" Combi TOT 18.66' ~ 7 1116" 5000 si, RX-46 7 1/16" x 3 1/6" Flan ed Ada ter Tree Size: 4 1/16" Swab Valve 20.04') O Flow Line (~ SSV 22.88' Master Valve 24.86' .~ Lock Down Screws 26.68' Ground level 31.00' .~ ~~ BAKER I~tiNES INTEL North America -ALASKA - BP Prudhoe Bay PB C Pad C-15 -Slot 15 Plan 3, C-15A Plan: Plan #3 Baker Hughes INTEQ Planning Report 20 April, 2009 by ~~~~ BP Exploration Alaska b Baker Hughes INTEQ Planning Report P INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well G15 -Slot 15 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB C Pad MD Reference: 17:15 2/17/1980 00:00 @ 62.70ft (generic drillinc Well: C-15 North Reference: True Wellbore: Plan 3, C-15A Survey Calculation Method: Minimum Curvature Design: Plan #3 Database: EDM .16 - Anc Prod - WH24P 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 C Pad, TR-11-14 - - - ~- I~ Site Position: Northing: 5,957,218.72 ft Latitude: 70° 1T 22.367 N From: Map Easting: 662,550.03 ft Longitude: 148° 41' 2.797 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Conve rgence: 1.24 ° Nell C-15 -Slot 15, C-15 Nell Position +N/S 0.00 ft Northing: 5,960,988.00 ft Latitude: 70° 17' 59.094 N +E/-W 0.00 ft Easting: 664,132.00 ft Longitude: 148° 40' 14.310 W position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore Plan 3, C-15A _ ' ~ Magnetics Model Name Sampl® Date Declination Dip Angle Field Strength BGGM2008 4/20/2009 22.76 80.92 57,707 Design Plan #3 _ i Audit Notes: _ __ ;Version: i Phase: PLAN Tie On Depth: 9,400.00 Vertical Section: Depth From (TVD) +NI-S +E/-W D€rectton (ft) (ft) (ft) (°) I -33.00 0.00 0.00 300.00 4/20/2009 3:59:33PM Page 2 COMPASS 2003.16 Build 70 ~~~ BP Exploration Alaska $ Baker Hughes INTEQ Planning Report by INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well G15 -Slot 15 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB C Pad MD Reference: 17:15 2/17/1980 00:00 @ 62.70ft (generic drillinc Well: C-15 North Reference: True Wellbore: Plan 3, C-15A Survey Calculat ion Method: Minimum Curvature Design: Plan #3 Database: EDM .16 - Anc Prod - WH24P Survey Tool Program Date 4/20/2009 From To (ft) (ft) Survey (Well bore) Tool Name Description 100.00 9,400.00 1 : Sperry-Su n BOSS gyro multi (C-15) BOSS-GYRO Sperry-S un BOSS gyro multishot 9,400.00 11,130.00 Plan #3 (Plan 3, C-15A) MWD MWD -Standard Planned Survey - _ _ -- MD Inc Azi TVDSS N/S E/W Northing Easting OLeg V. Sec TFace lft) (°) (°) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) (°) 9,400.00 24.32 274.90 8,646.69 -511.93 -2,688.15 5,960,417.51 661,455.86 0.00 2,072.04 0.00 TIP 9,435.00 24.07 275.28 8,678.61 -510.66 -2,702.44 5,960,418.47 661,441.55 0.84 2,085.05 148.25 KOP 9,455.00 25.84 276.00 8,696.74 -509.83 -2,710.83 5,960,419.12 661,433.14 9.00 2,092.74 10.00 End of 9 Deg1100' DLS 9,500.00 32.07 278.05 8,736.10 -507.13 -2,732.44 5,960,421.35 661,411.48 14.00 2,112.80 10.00 9,600.00 45.96 280.80 8,813.61 -496.62 -2,794.33 5,960,430.50 661,349.37 14.00 2,171.66 8.20 9,700.00 59.90 282.49 8,873.75 -480.44 -2,872.26 5,960,444.97 661,271.12 14.00 2,247.23 6.0 9,745.00 66.17 283.09 8,894.14 -471.56 -2,911.35 5,960,453.00 661,231.84 14.00 2,285.52 5.0 End of 14 Deg1100' DLS 9,800.00 72.68 284.29 8,913.46 -459.37 -2,961.35 5,960,464.09 661,181.59 12.00 2,334.92 10.00 9,900.00 84.52 286.28 8,933.19 -433.54 -3,055.73 5,960,487.85 661,086.68 12.00 2,429.57 9.58 9,946.26 90.00 287.17 8,935.40 -420.25 -3,099.96 5,960,500.18 661,042.17 12.00 2,474.52 9.18 5 10,000.00 89.10 293.55 8,935.82 -401.56 -3,150.32 5,960,517.76 660,991.42 12.00 2,527.48 98.00 10,096.26 87.54 305.00 8,938.66 -354.59 -3,234.10 5,960,562.89 660,906.64 12.00 2,623.52 97.95 6 10,100.00 87.54 304.55 8,938.82 -352.45 -3,237.17 5,960,564.95 660,903.52 12.00 2,627.25 -90.00 10,146.26 87.55 299.00 8,940.80 -328.13 -3,276.45 5,960,588.41 660,863.73 12.00 2,673.42 -89.98 7 10,196.26 87.56 292.99 8,942.94 -306.24 -3,321.33 5,960,609.31 660,818.38 12.00 2,723.23 -90.00 8 4/20/2009 3:59:33PM Page 3 COMPASS 2003.16 Build 70 //~'~ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB C Pad Well: C-15 Wellbore: Plan 3, C-15A Design: Plan #3 Planned Survey MD (ft) 10,200.00 10,296.26 9 10,300.00 10,386.26 10 10,400.00 10,500.00 10,600.00 10,686.26 11 10,700.00 10,800.00 10,900.00 10,936.26 12 11,000.00 11,100.00 11,130.00 TD at 11130.00 BP Exploration Alaska Baker Hughes INTEQ Planning Report bP Local Co-ordinate Reference: Well G15 -Slot 15 TVD Reference: Mean Sea Level MD Reference: 17:15 2/17/1980 00:00 @ 62.70ft (generic drillinc` North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Inc Azi TVDSS N/S E/W Northing Easting DLeg V. Sec (°) (°) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 87.60 293.44 8,943.09 -304.77 -3,324.76 5,960,610.71 660,814.92 12.00 2,726.94 88.65 304.95 8,946.25 -257.92 -3,408.60 5,960,655.71 660,730.08 12.00 2,822.98 88.69 304.50 8,946.34 -255.79 -3,411.68 5,960,657.78 660,726.96 12.00 2,826.71 89.61 294.19 8,947.62 -213.58 -3,486.76 5,960,698.33 660,650.98 12.00 2,912.83 89.61 295.84 8,947.71 -207.77 -3,499.21 5,960,703.87 660,638.41 12.00 2,926.52 89.62 307.84 8,948.38 -155.11 -3,584.00 5,960,754.66 660,552.49 12.00 3,026.28 89.65 319.84 8,949.01 -85.97 -3,656.00 5,960,822.20 660,479.00 12.00 3,123.20 89.69 330.19 8,949.51 -15.40 -3,705.39 5,960,891.68 660,428.09 12.00 3,201.26 89.69 331.84 8,949.59 -3.38 -3,712.05 5,960,903.55 660,421.17 12.00 3,213.04 89.70 343.84 8,950.13 89.06 -3,749.70 5,960,995.14 660,381.51 12.00 3,291.86 89.72 355.84 8,950.64 187.32 -3,767.30 5,961,092.98 660,361.77 12.00 3,356.24 89.73 0.19 8,950.82 223.54 -3,768.56 5,961,129.16 660,359.72 12.00 3,375.44 89.60 352.54 8,951.19 287.11 -3,772.59 5,961,192.62 660,354.30 12.00 3,410.72 89.41 340.54 8,952.07 384.18 -3,795.82 5,961,289.16 660,328.96 12.00 3,479.37 89.36 336.94 8,952.39 412.13 -3,806.69 5,961,316.86 660,317.48 12.00 3,502.76 TFace ' (°) 85.00 84.98 -85.00 -84.99 90.00 89.99 89.91 89.83 90.00 89.99 89.93 -91.00 -90.95 -90.85 4/20/2009 3:59:33PM Page 4 COMPASS 2003.16 Build 70 s BP Exploration Alaska Baker Hughes INTEQ Planning Report INTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB C Pad Well: C-15 Wellbore: Plan 3, C-15A Design: Plan #3 by Local Co-ordinate Reference: Well G15 -Slot 15 ND Reference: Mean Sea Level MD Reference: 17:15 2/17/1980 00:00 @ 62.70ft (generic drillinc North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Targets Target Name - hit/miss target Dip Angle Dip Dir. ND +N!-S +E/-W -Shape (°) (°) (ft) (ft) (ft) C-15A Fault 3 0.00 0.00 0.00 531.31 -4,081.65 - plan misses target center by 8820.17ft at 9400.OOft MD (8646.69 ND, -511.93 N, -2688.15 E) - Polygon Point 1 0.00 531.31 -4,081.65 Point 2 0.00 685.71 -3,823.20 C-15A Target 2 0.00 0.00 8,940.00 -346.56 -3,275.58 - plan misses target center by 15.61ft at 10135.78ft MD (8940.35 ND, -333.30 N, -3267.35 E) - Point C-15A Target 1 0.00 0.00 8,935.00 -430.59 -3,092.36 - plan misses target center by 7.66ft at 9935.99ft MD (8935.29 TVD, -423.26 N, -3090.14 E) - Point C-15A Fault 2 0.00 0.00 0.00 30.12 -3,347.37 - plan misses target center by 8688.70ft at 9400.OOft MD (8646.69 ND, -511.93 N, -2688.15 E) - Polygon Point 1 0.00 30.12 -3,347.37 Point 2 0.00 193.34 -3,263.78 C-15A Target 3 0.00 0.00 8,947.00 -222.11 -3,477.92 - plan misses target center by 4.06ft at 10374.35ft MD (8947.52 ND, -218.59 N, -3475.96 E) - Point C-15A Fault 1 0.00 0.00 0.00 -548.85 -2,944.89 - plan misses target center by 8650.57ft at 9400.OOft MD (8646.69 ND, -511.93 N, -2688.15 E) - Polygon Point 1 0.00 -548.85 -2,944.89 Point 2 0.00 -491.70 -2,813.60 Point 3 0.00 -215.27 -2,417.44 Point 4 0.00 -491.70 -2,813.60 C-15A Target 4 0.00 0.00 8,952.00 415.21 -3,804.10 - plan misses target center by 4.04ft at 11130.OOft MD (8952.39 ND, 412.13 N, -3806.69 E) - Point C-15A Polygon 0.00 0.00 0.00 -264.86 -3,123.75 - plan misses target center by 8661.18ft at 9400.OOft MD (8646.69 ND, -511.93 N, -2688.15 E) - Polygon Point 1 0.00 -264.86 -3,123.75 Northing Easting (ft) (ft) Latitude Longitude 5,961,430.00 660,040.00 70° 18' 4.308 N 148° 42' 13.310 W 5,961,430.00 660,040.00 5,961,590.00 660,295.00 5,960,570.00 660,865.00 70° 17' 55.678 N 148° 41' 49.798 W 5,960,490.00 661,050.00 70° 17' 54.853 N 148° 41' 44.456 W 5,960,945.00 660,785.00 70° 17' 59.383 N 148° 41' 51.896 W 5,960,945.00 660,785.00 5,961,110.00 660,865.00 5,960,690.00 660,660.00 70° 17' 56.901 N 148° 41' 55.698 W 5,960,375.00 661,200.00 70° 17' 53.690 N 148° 41' 40.156 W 5,960,375.00 661,200.00 5,960,435.00 661,330.00 5,960,720.00 661,720.00 5,960,435.00 661,330.00 5,961,320.00 660,320.00 70° 18' 3.168 N 148° 42' 5.216 W 5,960,655.00 661,015.00 70° 17' 56.482 N 148° 41' 45.373 W 5,960,655.00 661,015.00 4/20/2009 3:59:33PM Page 5 COMPASS 2003.16 Build 70 N.t~ s'~ieir~s INTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB C Pad Well: C-15 Wellbore: Plan 3, C-15A Design: Plan #3 Point 2 Point 3 Point 4 i Point 5 Point 6 Casing Points Measured Depth (ft) 11,130.00 Vertical Depth (ft) 8,952.39 .875" Plan Annotations Measured Depth (ft) 9,400.00 9,435.00 9,455.00 9,745.00 9,946.26 10,096.26 10,146.26 10,196.26 10,296.26 10,386.26 10,686.26 10,936.26 11,130.00 Vertical Depth (ft) 8,646.69 8,678.61 8,696.74 8,894.14 8,935.40 8,938.66 8,940.80 8,942.94 8,946.25 8,947.62 8,949.51 8,950.82 8,952.39 BP Exploration Alaska Baker Hughes INTEQ Planning Report by 0.00 -57.69 -3,449.33 0.00 502.35 -3,672.16 0.00 320.25 -4,036.25 0.00 -199.36 -3,832.54 0.00 -565.33 -3,335.38 Local Co-ordinate Reference: Well G15 -Slot 15 TVD Reference: Mean Sea Level MD Reference: 17:15 2/17/1980 00:00 @ 62.70ft (generic drillinc' North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P __ 5,960,855.00 660,685.00 5,961,410.00 660,450.00 5,961,220.00 660,090.00 5,960,705.00 660,305.00 5,960 350.00 660,810.00 Casing Hole Diameter Diameter Name (in) (in) 2.875 4.125 Local Coordinates +NI-S +FJ-W (ft) ~ft) -511.93 -2,688.15 -510.66 -2,702.44 -509.83 -2,710.83 -471.56 -2,911.35 -420.25 -3,099.96 -354.59 -3,234.10 -328.13 -3,276.45 -306.24 -3,321.33 -257.92 -3,408.60 -213.58 -3,486.76 -15.40 -3,705.39 223.54 -3,768.56 412.13 -3,806.69 Comment TIP KOP End of 9 Deg/100' DLS End of 14 Deg/100' DLS 5 6 7 8 9 10 11 12 TD at 11130.00 Checked By: Approved By: Date: 4/20/2009 3:59:33PM Page 6 COMPASS 2003.16 Build 70 by Pro'ett: Prudhoe Ba 1 Y MmuNa m True NoM agn¢Ik Noun: n 7e WELLBORE DETAILS: Plan 3, G15A REFERENCE INFORMATION Slte: PB C Pad . MagneGC F u Parent Wellfwfe: C-15 CooNinale (NIE) Reference; Well C-15 -Slot 15, Tru Well: C-75 SUengm: snossan Tie On MD: 9400 00 Vertical (TVD) Reference. Mean Sea Level Wellbore: Plan 3, C-15A Du Angle: 80.92 . Section (VS) Reference: Slot -15(O OON, O.OOE) Plan• Plan #3 C-15IPIan 3, C-75A • ( ) Dale: <2a2oo Model: eccMZoo Meawred Depth Reference: 17: 15 211Th 990 00:00 Calalation Method: Minimum Curvature WELL DETAILS: C-15 Ground Level. 0.00 +N/-S +EI-W Northing Easting Latiltude Longdutle Slot 0.00 0.00 5960996.00 664132 00 70" 17' S9 094 N 148" 40' 14.310 W 15 SECTION DETAILS ANNOTATIONS Sec MD Inc Azi ssND +N/-S +EI-W DLeg TFace VSec Target Annotatwn 1 9400.00 24.32 274.90 8646.69 -511.93 •2688.15 0.00 0.00 2072.04 TIP 2 9435.00 24.07 275.28 8678.61 -510.66 -2702.44 0.84 148.25 2085.05 KOP 3 9455.00 25.84 276.00 8696.74 -509.83 -2710.83 9.00 10.00 2092.74 End of 9 DegI100' DLS 4 9745.00 66.17 283.09 8894.14 -471.56 -2911.35 14.00 10.00 2265.52 End of 14 Deg1100' DLS 5 9946.26 90.00 287.17 8935.40 -020.25 -3099.96 12.00 10.00 2474.52 5 6 10096.26 87.54 305.00 8938.66 -354.59 -3234.10 12.00 98.00 2623.52 6 7 10146.26 87.55 299.00 8940.80 -328.13 -3276.45 12.00 270.00 2673.42 7 8 10196.26 87.56 292.99 8942.94 -306.24 -3321.33 12.00 270.00 2723.23 8 9 10296.26 88.65 304.95 8946.25 -257.92 -3408.60 12.00 85.00 2822.98 9 10 10386.26 89.61 294.19 8947.62 -213.58 -3486.76 12.00 275.00 2912.83 10 11 10686.26 89.69 330.19 8949.51 -15.40 -3705.39 12.00 90.00 3201.26 11 12 10936.26 89.73 0.19 8950.82 223.54 -3768.56 12.00 90.00 3375.44 12 13 11130.00 89.36 336.94 8952.39 412.13 -3806.69 12.00 269.00 3502.76 TD at 11130.00 8 a a O 8 ~_ ~ 8 ¢. ~ ~ ~ 8 Q ~ d U rn N -~ ~ ~ 5 ~ S H S S S K w, rn 0 0 .3~~. North BAKER Hu~NEs a 62.7011 (generic ddoirg rigs al ~ a . •.~ I I I .5 ' - _ . " ~TIP ._ _ ___ ~ ! _ _I-KOP_ ' 0 , ~~ of 9 De~100' D ----__....--- ~.S 5 - - { r~ ~ - i 10 ~ i nd of 14 00' LS S ' G15 Target l ',.. _ GlSA Target 2 ~ ' i0 . .. _ - _ ., . Ta of 3 _ ~C-ISA ~' i, ~ C-3n' Targe6..4 -~ ~ 1] 12 to IS - - -_ , - -- - r I i 0 L___-- I J . !00 L _ _-__ -_ C IYVU IYJ1/ LUUU LUJU LIUV GIJV LLW ILJV L}VV L}JU L4W L4JU GJUU LJJU LOW LOJU L/UU L/JU L6UU L6JU LYUV LYJU }VUU }UJU }IUU }IJU }LUU JLJU JJUU }}JU }4UU }4JU }]UU }JJU }ODU }bJU S/UU }/]U }6UU 16]11 Vertical Section at 300.00° (50 ft/in) -0180 -4085 -3990 -3895 -3800 -3705 -3610 -3515 -3420 -3325 -3230 -3135 -3040 -2945 -2850 -2755 -2660 -2565 -2470 ~xro~t7 vc.,~di~ 7oc w7:.,~ by 9001-~ c w 7O C i 7 O Means Project: Prudhoe Bay ~ M,gnauc Norm: iz.7e WELLBORE DETAILS: Plan 3, C-15A REFERENCE INFORMATION Site: PB C Pad Magnadc Fiep Parent Wellbore: C-15 CooNinate (NIE) Reference: Well C-15 -Slot 15, True North WEII: C-15 Strengm. 577066vn Tie on MD: 9400 00 Vertical (ND) Reference. Mean Sea Level Wellbore: Plan 3, C-15A Gy Mgle. eo.gz . Section (v5) Reference. Sbi - i5(O.OON, O.OOE) Plan: Plan #3 (C-15/Plan 3, C-15A) MbdeI~BG2GM200 Measured DepN Reference. 17:15 211711980 00.00 Q 62 70X (generk ddPing rg) Calwlation Melhod'. Minimum Curvature ri.~ BAKER Nua~s 1NTEQ szs 750 _ - i _. _ -_-- 307 . _ 370 L --- 675 - 600 . _ -- i i I 525 - __ i '_ C-t /Pla 3, C l5A 7 r 7 . i 450 375 - - - __... -. $9 --- 52.. ---- 300 -- J i / zzs - C- 5/C- 56 1so I 75 _ _ _. . D- _.. 30/D-30A - -- D .o I50 , . ___ _.. ~.. . 225 - - D- U~D- OA - -- 300 - 375 -__ -____ - - __ - - _. - 450 52S ~, -- _, --- - _ - ._ _ ._t ~ 00 o` _ . 0 h . ~.- - - M _. ~ _ 600 . _ i _ o o v, ~ o o0 o I I 675 --~ - --- 750 - r - 825 - 900 - 975 ' - OS - Level - ----- - ~- ', ._..-... J '. i - --- - - - - -~~-- -- -.- _. -- -- -- -1 -~ -4800 -4725 -4650 -4575 -4500 -4425 -4350 -4275 -4200 -4125 -4050 -3975 -3900 -3825 -3750 -3675 -3600 -3525 -3450 -3375 -3300 -3225 -3150 -3075 -3000 -2925 -2850 -2775 -2700 -2625 -2550 -2475 -2400 -2325 -2250 -2175 -2100 -2025 West(-)/East(+) (75 ft/in) a PfojeCt: Pfudhoa Bay ANTI-COLLISION SETTINGS couvANr o6TAas. N•M Am•nw ~ ALASKA - av ~~~^ h Up Slte: PB C Pad Well: C-15 Interyolation Methotl: MD, interval: 50.00 Depth Range From: 9400.00 To 11130.00 NORAHAAMERiLA ~` L•I•Wmm M•mm. Minm•m cw,l~.. BAKER N~lGFIES Results Limited By: Centre Distance: 1310.03 Error sya.n, iscwsA Walll743re: Plan 3, C-15A Reference: Plan: Plan #3 (G15IPIan 3, G15A) sc.n M•n•a 7rer u,b•, Ndl6 Er,•. s•,Ma anvo ~c•oK Plan: Plan #3 (C-15/Plan 3, C-15A) w•e.•9 M•rw4 R•M• e..•4 1NTEQ WELL DETAILS: C-15 Ground Lew:l: 0.00 +NI-S +EI•W Northing Easting Latittude Longitude Slot 0.00 0.00 5960988.00 664132.00 70° 17' 59.094 N 149° 40' 14.310 W 15 SECTION DETAILS Sec MD Inc Azi TVD •W-S +EI-W DLe9 TFace VSec Target 1 2 9400.00 9435 00 24.32 24.07 274.90 275.28 8646.69 86]8.61 -51193 -510.66 -2688.15 0.00 0.00 20]2.04 -2702.44 0.84 148 25 2085 OS 3 9455 00 25.84 276.00 8696.74 -509.83 -271083 9.00 10.00 2092 74 4 974500 66.17 2B3.W 8890.14 371.56 -2911.35 14.00 10.00 220552 5 9946.26 90.00 287.17 8935.40 320.25 -309996 12.00 10.00 24]4.52 6 10096.26 87.54 305.00 8938.66 -354.59 -3234.10 12.00 9B 00 2623 52 7 10146.26 87.55 299.00 8900.80 -328.13 -3276.45 12.00 270.00 26]342 8 10196.26 87.56 292.99 8942.94 -306.24 3321.33 12.00 270.00 272323 9 10296.26 88.65 304.95 8906.25 -257.92 300860 12.00 85.00 282298 10 10386.26 89.61 289.19 8907.62 -213.58 -3486.76 12.00 275.00 2912 B3 11 10686.26 &9.69 330.19 8949.51 -15 40 -3705.39 12.00 90.00 3201.26 12 10936.2fi 89.73 0.19 895082 223.54 -3768.56 12.00 90.00 3375.44 13 11130.00 89.36 336.99 8952.39 412.13 -380669 12 00 269.00 3502.76 SURVEY PROGRAM Date: 2009-04-20700:00:00 Validated: Yes Version: Depth Fmm Depth To SurveylPlan Tool 100.00 9400.00 1 : SperrySun BOSS gyro multB~b'6)GVRO 9400.00 11130.00 Plan #3 (Plan 3, G15A) MWD /C-15 LEGEND • A •~•5 vt 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation (16 ft/in] r .~ ~~ ~~~~ INTEQ North America -ALASKA - BP Prudhoe Bay PB C Pad C-15 Plan 3, C-15A Plan #3 Travelling Cylinder Report 20 April, 2009 by 1NTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Reference Site: PB C Pad Site Error: O.OOft Reference Well: C-15 tNeli Error. O.OOft Reference Wellbore Plan 3, C-15A Reference Design: Plan #3 BP Exploration Alaska Travelling Cylinder Report bP Local Co-ordinate Reference: Well G15 -Slot 15 TVD Reference: Mean Sea Level MD Reference: 17:15 2/17/1980 00:00 @ 62.70ft (generic drilling rig) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM .16 - Anc Prod - WH24P Offset TVD Reference: Offset Datum Reference Plan#3 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refers Interpolation Method: MD Interval 25.OOft En•or Model: ISCWSA Depth Range: 9,400.00 to 11,130.OOft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,310.03ft Error Surface: Elliptical Conic Survey Tool Program Date 4/2.0/2009 ~ From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 9,400.00 1 : Sperry-Sun BOSS gyro multi (C-15) BOSS-GYRO Sperry-Sun BOSS gyro multishot 9,400.00 11,130.00 Plan #3 (Plan 3, C-15A) ---- --- MWD MWD -Standard - -~ Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 11,130.00 8,952.39 2.875" 2.875 4.125 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 C Pad C-15 - C-15 - C-15 9,450.00 9,450.00 0.19 5.14 -2.70 FAIL -Major Risk C-35 - C-35B - C-35B 9,846.72 11,300.00 854.69 588.63 266.48 Pass -Major Risk PB D Pad D-30 - D-30 - D-30 Out of range D-30 - D-30A - D-30A 10,825.00 11,935.00 830.29 152.79 677.39 Pass -Major Risk D-30 - D-30A -Plan #2 10,850.00 11,925.00 821.98 150.80 671.12 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/20/2009 3:56:38PM Page 2 of 7 COMPASS 2003.16 Build 70 . sw~aR ~ Iliilllr~es INTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Reference Site: PB C Pad Site Error: O.OOft Reference Well: C-15 Well Error: O.OOft Reference Wellbore Plan 3, C-15A Reference Design: Plan #3 BP Exploration Alaska . Travelling Cylinder Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well G15 -Slot 15 Mean Sea Level 17:15 2/17/1980 00:00 @ 62.70ft (generic drilling rig) >' True Minimum Curvature 1.00 sigma EOM .16 - Anc Prod - WH24P Offset Datum Offset Design PB C Pad - C-15 - C-15 - C-15 offset site Error: o.oo ft Survey Program: 100-BOSS-GYRO Rule Assigned: Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface + Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +NIS +El-W Hole Size Centre Distance Deviation (ff) (n) Iff1 (ff) (ft) lftl (°) (ft) (ft) Iff) lft) (k) Iffl 9,400.00 8,646.69 9,400.00 8,646.69 0.00 0.00 -85.10 -511.93 -2,688.15 0.29 0.00 0.29 -0.29 FAIL -Major Risk, CC 9,425.00 8,669.48 9,425.00 8,669.48 0.27 0.52 -95.13 -511.03 -2,698.37 0.29 0.00 2.91 -1.55 FAIL -Major Risk 9,450.00 8,692.23 9,450.00 8,692.31 0.37 1.05 102.21 -510.09 -2,708.52 0.29 0.19 5.14 -2.70 FAIL -Major Risk, ES, SF 9,474.92 8,714.45 9,475.00 8,715.17 0.37 1.57 102.76 -509.11 -2,718.59 0.29 1.51 7.20 -2.65 FAIL -Major Risk 9,499.57 8,735.74 9,500.00 8,738.06 0.37 2.09 103.30 -508.08 -2,728.59 0.29 4.40 9.30 -1.06 FAIL -Major Risk 9,523.79 8,755.88 9,525.00 8,760.98 0.37 2.60 103.73 -507.03 -2,738.52 0.29 8.84 11.35 2.12 Pass -Major Risk 9,547.40 8,774.74 9,550.00 8,783.93 0.38 3.11 104.11 -505.96 -2,748.38 0.29 14.76 13.38 6.84 Pass -Major Risk 9,570.27 8,792.19 9,575.00 8,806.90 0.38 3.62 104.43 -504.89 -2,758.17 0.29 22.13 15.38 13.06 Pass -Major Risk 9,592.28 8,808.19 9,600.00 8,829.91 0.38 4.12 104.69 -503.81 -2,767.90 0.29 30.85 17.33 20.70 Pass -Major Risk 9,613.35 8,822.74 9,625.00 8,852.94 0.38 4.62 104.92 -502.71 -2,777.57 0.29 40.85 19.23 29.71 Pass -Major Risk 9,633.43 8,835.85 9,650.00 8,875.99 0.39 5.12 105.12 -501.60 -2,787.19 0.29 52.03 21.10 39.97 Pass -Major Risk 9,652.50 8,847.61 9,675.00 8,899.06 0.39 5.61 105.29 -500.48 -2,796.75 0.29 64.31 22.93 51.41 Pass -Major Risk 9,670.55 8,858.08 9,700.00 8,922.15 0.40 6.11 105.45 499.34 -2,806.27 0.29 77.61 24.74 63.93 Pass -Major Risk 9,687.56 8,867.35 9,725.00 8,945.27 0.40 6.59 105.59 X98.18 -2,815.70 0.29 91.87 26.47 77.49 Pass -Major Risk 9,703.56 8,875.52 9,750.00 8,968.44 0.41 7.07 105.70 -497.00 -2,825.02 0.29 107.03 28.16 92.02 Pass -Major Risk 9,718.57 8,882.69 9,775.00 8,991.65 0.42 7.55 105.80 -095.81 -2,834.24 0.29 123.02 29.83 107.44 Pass -Major Risk 9,732.63 8,888.97 9,800.00 9,014.90 0.42 8.03 105.89 -494.59 -2,843.34 0.29 139.76 31.47 123.67 Pass -Major Risk 9,745.85 8,894.48 9,825.00 9,038.17 0.43 8.50 105.98 -493.37 -2,852.39 0.29 157.15 33.05 140.60 Pass -Major Risk 9,758.82 8,899.54 9,850.00 9,061.44 0.43 8.98 106.16 -492.14 -2,861.44 0.29 175.05 34.63 158.08 Pass -Major Risk 9,771.10 8,904.04 9,875.00 9,084.71 0.44 9.45 106.35 -490.92 -2,870.50 0.29 193.41 36.18 176.04 Pass -Major Risk 9,782.71 8,908.02 9,900.00 9,107.98 0.45 9.92 106.54 -489.69 -2,879.55 0.29 212.18 37.71 194.45 Pass -Major Risk 9,793.71 8,911.55 9,925.00 9,131.26 0.45 10.40 106.74 -488.47 -2,888.60 0.29 231.34 39.23 213.26 Pass -Major Risk 9,800.00 8,913.46 9,950.00 9,154.53 0.46 10.87 106.87 -487.24 -2,897.65 0.29 250.90 40.68 232.53 Pass -Major Risk 9,813.99 8,917.43 9,975.00 9,177.80 0.47 11.35 107.12 -486.01 -2,906.70 0.29 270.68 42.23 251.97 Pass -Major Risk 9,825.00 8,920.28 10,000.00 9,201.07 0.47 11.83 107.33 -484.79 -2,915.75 0.29 290.82 43.73 271.82 Pass -Major Risk 9,832.23 8,922.02 10,025.00 9,224.34 0.48 12.31 107.49 -483.56 -2,924.81 0.29 311.22 45.17 291.97 Pass -Major Risk 9,840.6(1 8,923.92 10,050.00 9,247.61 0.48 12.78 107.66 -482.34 -2,933.86 0.29 331.89 46.62 312.40 Pass -Major Risk 9,850.00 8,925.86 10,075.00 9,270.89 0.49 13.26 107.85 -481.11 -2,942.91 0.29 352.80 48.09 333.08 Pass -Major Risk 9,856.28 8,927.06 10,100.00 9,294.16 0.49 13.74 108.00 X79.89 -2,951.96 0.29 373.92 49.55 353.99 Pass -Major Risk I 9,863.53 8,928.34 10,125.00 9,317.43 0.50 14.22 108.16 -478.66 -2,961.01 0.29 395.25 51.02 375.13 Pass -Major Risk 9,875.00 8,930.16 10,150.00 9,340.70 0.51 14.69 108.39 -477.44 -2,970.06 0.29 416.82 52.54 396.52 Pass -Major Risk 9,875.00 8,930.16 10,175.00 9,363.97 0.51 15.17 108.43 -076.21 -2,979.11 0.29 438.47 53.91 417.99 Pass -Major Risk 9,883.26 8,931.31 10,200.00 9,387.24 0.51 15.65 108.60 -474.99 -2,988.17 0.29 460.32 55.39 439.69 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/20/2009 3:56:38PM Page 3 of 7 COMPASS 2003. f6 Build 70 ~R ^ . BP Exploration Alaska • $ Travelling Cylinder Report Company: North America -ALASKA - BP Local Co-ordinate Reference: Project: Prudhoe Bay TVD Reference: Reference Site: PB C Pad MD Reference: Site Error: O.OOft North Reference: Reference Well: C-15 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Wellbore Plan 3, C-15A Database: Reference Design: Plan #3 Offset ND Reference: by Well G15 -Slot 15 Mean Sea Level 17:15 2/17/1980 00:00 @ 62.70ft (generic drilling rig) True Minimum Curvature 1.00 sigma EDM .16 - Anc Prod - WH24P Offset Datum Offset Design PB C Pad - C-35 - C-35B - C-356 ofrsel site Error: o.oo e Survey Program: 100-BOSS-GYRO, 8871-MWD Rule Assigned: Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface + Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/S +El_yy Hole Size Centre Distance Deviation (ff) (ft) (ff) lft) (ff) fill (°) (ft) (ft) (ff) (ff) (ftl (ff) 9,405.03 8,651.27 10,425.00 8,946.29 121.45 79.23 43.39 332.30 -1,960.71 0.29 1,153.97 571.14 664.87 Pass-MajorRisk 9,413.81 8,659.27 10,450.00 8,945.81 121.54 79.24 43.21 317.88 -1,981.12 0.29 1,130.39 571.74 640.02 Pass -Major Risk 9,422.26 8,666.99 10,475.00 8,945.31 121.63 79.25 43.05 302.85 -2,001.09 0.29 1,106.65 572.31 615.16 Pass -Major Risk 9,430.92 8,674.89 10,500.00 8,944.90 121.72 79.26 42.87 288.26 -2,021.38 0.29 1,083.05 572.89 590.28Pass-MajorRisk 9,435.00 8,678.61 10,525.00 8,944.57 121.76 79.27 42.58 275.07 -2,042.61 0.29 1,059.94 573.34 565.57 Pass -Major Risk 9,442.46 8,685.40 10,550.00 8,944.57 121.76 79.29 42.21 263.67 -2,064.85 0.29 1,037.66 573.70 541.40 Pass -Major Risk 9,448.10 8,690.52 10,575.00 8,945.11 121.76 79.32 41.75 253.80 -2,087.81 0.29 1,016.31 574.08 517.72 Pass -Major Risk 9,455.00 8,696.74 10,600.00 8,945.93 121.76 79.35 41.20 245.42 -2,111.34 0.29 995.94 574.52 494.61 Pass -Major Risk 9,455.00 8,696.74 10,625.00 8,947.00 121.76 79.38 40.56 238.25 -2,135.27 0.29 976.49 574.96 471.98 Pass -Major Risk 9,465.77 8,706.37 10,650.00 8,948.09 121.76 79.42 39.91 232.05 -2,159.46 0.29 957.78 575.45 450.11 Pass -Major Risk 9,475.00 8,714.52 10,675.00 8,948.41 121.76 79.46 39.15 227.30 -2,184.00 0.29 940.08 575.99 428.72 Pass -Major Risk 9,475.00 8,714.52 10,700.00 8,948.46 121.76 79.51 38.25 223.92 -2,208.76 0.29 923.51 576.50 407.97 Pass -Major Risk 9,484.46 8,722.78 10,725.00 8,948.48 121.76 79.57 37.32 221.83 -2,233.67 0.29 908.20 577.05 388.39 Pass -Major Risk 9,491.40 8,728.76 10,750.00 8,948.31 121.76 79.62 36.31 220.95 -2,258.66 0.29 894.13 577.82 369.80 Pass -Major Risk 9,500.00 8,736.10 10,775.00 8,947.75 121.76 79.69 35.22 221.46 -2,283.64 0.29 881.51 578.22 352.45 Pass -Major Risk 9,506.33 8,741.44 10,800.00 8,947.22 121.76 79.76 34.04 223.84 -2,308.51 0.29 870.94 578.81 336.97 Pass -Major Risk 9,514.78 8,748.48 10,825.00 8,947.11 121.76 79.83 32.83 227.59 -2,333.23 0.29 862.18 579.41 323.35 Pass -Major Risk 9,525.00 8,756.87 10,850.00 8,947.37 121.76 79.92 31.61 232.79 -2,357.68 0.29 855.38 580.04 311.77 Pass -Major Risk 9,533.71 8,763.90 10,875.00 8,947.66 121.76 80.00 30.35 239.46 -2,381.76 0.29 850.54 580.65 302.24 Pass -Major Risk 9,543.84 8,771.95 10,900.00 8,947.62 121.76 80.09 29.07 247.63 -2,405.39 0.29 847.69 581.25 294.84 Pass -Major Risk 9,554.36 8,780.14 10,925.00 8,947.32 121.77 80.19 27.78 257.52 -2,428.34 0.29 847.14 581.87 289.94 Pass -Major Risk 9,565.48 8,788.60 10,950.00 8,947.17 121.77 80.29 26.52 269.02 -2,450.53 0.29 848.90 582.46 287.65 Pass -Major Risk 9,575.00 8,795.70 10,975.00 8,946.86 121.77 80.39 25.28 282.01 -2,471.88 0.29 852.82 583.04 287.82 Pass -Major Risk 9,588.96 8,805.83 11,000.00 8,946.29 121.77 80.50 24.09 295.87 -2,492.68 0.29 858.18 583.58 289.76 Pass-Major Risk 9,600.00 8,813.61 11,025.00 8,945.81 121.77 80.61 22.94 309.47 -2,513.65 0.29 863.73 584.14 292.22 Pass -Major Risk 9,616.05 8,824.54 11,050.00 8,945.37 121.77 80.72 21.88 322.03 -2,535.26 0.29 868.54 584.69 294.23 Pass -Major Risk 9,631.58 8,834.68 11,075.00 8,945.07 121.78 80.84 20.87 333.30 -2,557.57 0.29 872.33 585.26 295.51 Pass -Major Risk 9,648.55 8,845.23 11,100.00 8,944.87 121.78 80.95 19.93 343.13 -2,580.55 0.29 874.94 585.82 295.88 Pass -Major Risk 9,666.87 8,856.00 11,125.00 8,944.57 121.78 81.06 19.06 351.34 -2,604.15 0.29 876.13 586.38 295.08 Pass -Major Risk 9,686.41 8,866.74 11,150.00 8,943.98 121.79 81.17 18.26 358.31 -2,628.15 0.29 876.26 586.91 293.45 Pass -Major Risk 9,707.33 8,877.37 11,175.00 8,943.41 121.80 81.27 17.55 364.06 -2,652.47 0.29 875.38 587.42 291.03 Pass -Major Risk 9,729.75 8,887.72 11,200.00 8,943.30 121.81 81.38 16.96 368.35 -2,677.10 0.29 873.22 587.90 287.59 Pass-Major Risk 9,755.20 8,898.16 11,225.00 8,943.64 121.82 81.48 16.57 371.23 -2,701.93 0.29 869.78 588.28 283.13 Pass -Major Risk 9,784.82 8,908.71 11,250.00 8,943.79 121.83 81.58 16.43 373.19 -2,726.85 0.29 865.39 588.48 278.03 Pass -Major Risk 9,815.27 8,917.77 11,275.00 8,943.57 121.85 81.68 16.39 374.29 -2,751.82 0.29 860.01 588.60 272.13 Pass -Major Risk 9,846.72 8,925.20 11,300.00 8,943.21 121.86 81.78 16.48 375.60 -2,776.78 0.29 854.69 588.63 266.48 Pass -Major Risk, ES, SF 10,125.00 8,939.89 11,325.00 8,942.84 122.08 81.88 31.79 376.92 -2,801.75 0.29 848.87 553.74 295.19 Pass -Major Risk 10,125.00 8,939.89 11,330.00 8,942.77 122.08 81.90 31.77 377.18 -2,806.74 0.29 846.42 553.84 292.63 Pass -Major Risk, CC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/20/2009 3:56:38PM Page 4 of 7 COMPASS 2003.16 Build 70 I/.~~ i BP Exploration Alaska Travelling Cylinder Report by LNTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Project: Prudhoe Bay ND Reference: Reference Site: PB C Pad MD Reference: Site Error: O.OOft North Reference: Reference Well: C-15 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Wellbore Plan 3, C-15A Database: Reference Design: Plan #3 Offset TVD Reference: Well G15 -Slot 15 Mean Sea Level 17:15 2/17/1980 00:00 @ 62.70ft (generic drilling rig) True Minimum Curvature 1.00 sigma EDM .16 - Anc Prod - WH24P Offset Datum -_ Offset Design PB D Pad - D-30 - D-30A - D-30A ofrget site Error: o.oon Survey Program: 21 4-MW D, 10487-MWD Rule Assigned: Major Risk Offset Well Error: O.OOft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N!-S +E!-W Hole Size Centre Distance Deviation In) (n) (ft) (ft) (ft) Ift> (°I (ftj (ft) (n) (n) (nl (H) 10,825.00 8,950.26 11,675.00 8,960.21 122.76 70.50 -103.68 -110.87 -4,817.62 0.29 1,085.04 152.25 932.74 Pass -Major Risk 10,825.00 8,950.26 11,700.00 8,960.45 122.76 70.78 -103.71 -114.63 -4,792.91 0.29 1,061.69 152.33 909.29 Pass -Major Risk 10,825.00 8,950.26 11,725.00 8,960.82 122.76 71.07 -103.74 -116.71 -4,768.00 0.29 1,037.84 152.42 885.35 Pass -Major Risk ~~~ 10,825.00 8,950.26 1 Y,750.00 8,961.43 122.76 71.36 -103.79 -117.45 -4,743.03 0.29 1,013.67 152.50 861.09 Pass -Major Risk ~, 10,825.00 8,950.26 11,775.00 8,961.57 122.76 71.65 -103.82 -116.73 -4,718.04 0.29 989.19 152.57 836.54 Pass -Major Risk '. 10,825.00 8,950.26 11,800.00 8,961.43 122.76 71.95 -103.83 -114.58 -4,693.14 0.29 964.48 152.63 811.76 Pass -Major Risk 10,825.00 8,950.26 11,825.00 8,961.65 122.76 72.25 -103.86 -111.15 -4,668.38 0.29 939.62 152.67 786.85 Pass -Major Risk 10,825.00 8,950.26 11,850.00 8,962.22 122.76 72.55 -103.91 -106.57 -4,643.81 0.29 914.68 152.72 761.86 Pass -Major Risk 10,825.00 8,950.26 11,875.00 8,962.55 122.76 72.85 -103.95 -100.31 -4,619.62 0.29 889.69 152.75 736.84 Pass -Major Risk 10,825.00 8,950.26 11,900.00 8,962.98 122.76 73.14 -104.01 -91.95 -4,596.07 0.29 864.84 152.77 711.96 Pass -Major Risk 10,825.00 8,950.26 11,925.00 8,963.58 122.76 73.44 -104.07 -82.40 -4,572.97 0.29 840.16 152.78 687.26 Pass -Major Risk 10,825.00 8,950.26 11,935.00 8,963.82 122.76 73.55 -104.10 -78.58 -4,563.73 0.29 830.29 152.79 677.39 Pass -Major Risk, CC, ES, 10,835.20 8,950.32 11,650.00 8,960.01 122.76 70.23 -102.44 -105.97 -4,842.13 0.29 1,107.90 150.41 957.42 Pass -Major Risk 10,837.86 8,950.33 11,625.00 8,959.67 122.76 69.95 -102.09 -102.02 4,866.81 0.29 1,131.25 150.15 981.04 Pass -Major Risk 10,839.97 8,950.34 11,600.00 8,959.11 122.76 69.68 -101.80 -99.77 4,891.70 0.29 1,155.19 150.02 1,005.11 Pass-Major Risk 10,850.00 8,950.39 11,450.00 8,960.32 122.76 67.97 -100.60 -119.30 -5,039.35 0.29 1,303.90 150.20 1,153.66 Pass-Major Risk 10,850.00 8,950.39 11,475.00 8,959.98 122.76 68.25 -100.59 -111.67 -5,015.55 0.29 1,279.06 150.25 1,128.77 Pass-Major Risk 10,850.00 8,950.39 11,500.00 8,959.90 122.76 68.54 -100.60 -105.79 4,991.26 0.29 1,254.09 150.29 1,103.75 Pass-Major Risk '~, 10,850.00 8,950.39 11,525.00 8,959.86 122.76 68.82 -100.61 -101.76 -4,966.59 0.29 1,229.11 150.32 1,078.74 Pass-Major Risk I, 10,850.00 8,950.39 11,550.00 8,959.28 122.76 69.11 -100.59 -99.90 -4,941.67 0.29 1,204.31 150.34 1,053.93 Pass -Major Risk 10,850.00 8,950.39 11,575.00 8,958.90 122.76 69.39 -100.58 -99.20 -4,916.69 0.29 1,179.68 150.35 1,029.29 Pass-Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/20/2009 3:56:38PM Page 5 of 7 COMPASS 2003.16 Build 70 ~s • BP Exploration Alaska Travelling Cylinder Report Company: North America -ALASKA - BP Local Co-ordinate Reference: Project: Prudhoe Bay TVD Reference: Reference Site: PB C Pad MD Reference: Site Error: O.OOft North Reference: Reference Well: C-15 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Wellbore Plan 3, C-15A Database: Reference Design: Plan #3 Offset TVD Reference: by Well G15 -Slot 15 Mean Sea Level 17:15 2/17/1980 00:00 @ 62.70ft (generic drilling rig) , True Minimum Curvature 1.00 sigma EDM .16 - Anc Prod - WH24P Offset Datum Offset Design PB D Pad - D-30 - D-30A -Plan #2 offset sce Error: o.oon Survey Program: 21 4-MWD, 10431-MWD Rule Assigned: Major Risk Offset Well Error: O.OOft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/S +E/-W Hole Size Centre Distance Deviation (hl (ff) (ff) (ff) (h) lff) (°) (h) (ft) (ft) (ffl (ff) (ff) 10,825.00 8,950.26 11,725.00 8,961.13 122.76 71.28 -103.76 -93.70 -4,752.86 0.29 1,018.15 152.21 865.88 Pass -Major Risk 10,825.00 8,950.26 11,750.00 8,960.94 122.76 71.58 -103.77 -89.36 -4,728.25 0.29 993.17 152.26 840.83 Pass -Major Risk 10,825.00 8,950.26 11,775.00 8,960.76 122.76 71.88 -103.77 -83.74 -4,703.89 0.29 968.18 152.29 815.81 Pass -Major Risk 10,833.50 8,950.31 11,800.00 8,960.58 122.76 72.17 -102.76 -76.84 -4,679.86 0.29 943.14 150.74 792.32 Pass -Major Risk 10,833.85 8,950.31 11,700.00 8,961.31 122.76 70.98 -102.70 -96.75 -4,777.67 0.29 1,042.95 150.56 892.31 Pass -Major Risk 10,834.52 8,950.31 11,825.00 8,960.40 122.76 72.47 -102.65 -68.71 -4,656.23 0.29 918.32 150.64 767.60 Pass -Major Risk 10,834.93 8,950.31 11,675.00 8,961.50 122.76 70.69 -102.57 -98.50 -4,802.61 0.29 1,067.70 150.40 917.23 Pass -Major Risk 10,836.03 8,950.32 11,850.00 8,960.23 122.76 72.76 -102.47 -59.34 -4,633.05 0.29 893.71 150.51 743.12 Pass -Major Risk 10,836.38 8,950.32 11,650.00 8,961.70 122.76 70.40 -102.39 -98.93 -4,827.60 0.29 1,092.25 150.22 941.96 Pass -Major Risk 10,838.05 8,950.33 11,875.00 8,960.07 122.76 73.05 -102.24 -48.77 -4,610.40 0.29 869.38 150.39 718.91 Pass-Major Risk 10,838.17 8,950.33 11,625.00 8,961.89 122.76 70.11 -102.17 -98.06 -4,852.58 0.29 1,116.54 150.05 966.41 Pass-Major Risk 10,840.27 8,950.34 11,600.00 8,962.08 122.76 69.83 -101.92 -95.90 -4,877.48 0.29 1,140.51 149.93 990.51 Pass -Major Risk 10,840.60 8,950.34 11,900.00 8,959.91 122.76 73.34 -101.94 -37.04 -4,588.33 0.29 845.42 150.33 695.02 Pass -Major Risk 10,850.00 8,950.39 11,450.00 8,963.32 122.76 68.11 -100.74 -104.20 -5,026.63 0.29 1,288.54 150.20 1,138.28 Pass-Major Risk 10,850.00 8,950.39 11,475.00 8,963.10 122.76 68.39 -100.74 -99.57 -5,002.07 0.29 1,263.54 150.24 1,113.25 Pass-Major Risk 10,850.00 8,950.39 11,500.00 8,962.89 122.76 68.68 -100.74 -96.22 -4,977.30 0.29 1,238.59 150.26 1,088.27 Pass-Major Risk 10,850.00 8,950.39 11,525.00 8,962.68 122.76 68.97 -100.74 -94.18 -4,952.39 0.29 1,213.74 150.28 1,063.41 Pass-Major Risk 10,850.00 8,950.39 11,550.00 8,962.48 122.76 69.26 -100.75 -93.45 -4,927.40 0.29 1,189.08 150.28 1,038.74 Pass • Major Risk 10,850.00 8,950.39 11,575.00 8,962.28 122.76 69.54 -100.75 -94.02 -4,902.41 0.29 1,164.69 150.28 1,014.35 Pass -Major Risk 10,850.00 8,950.39 11,925.00 8,959.75 122.76 73.62 -100.82 -24.16 -4,566.90 0.29 821.98 150.80 671.12 Pass -Major Risk, CC, ES, f CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/20/2009 3:56:38PM Page 6 of 7 COMPASS 2003.16 Build 70 ' BAKER ^ IlilltlGll~s • INTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Reference Site: PB C Pad Site Error: O.OOft Reference Well: C-15 Well Error: O.OOft Reference Wellbore Plan 3, C-15A Reference Design: Plan #3 BP Exploration Alaska • Travelling Cylinder Report by Local Co-ordinate Reference: Well G15 -Slot 15 TVD Reference: Mean Sea Level MD Reference: 17:15 2/17/1980 00:00 @ 62.70ft (generic drilling rig) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM .16 - Anc Prod - WH24P Offset TVD Reference: Offset Datum teference Depths are relative to 17:15 2/17/1980 00:00 @ 62.70ft (geCoordinates are relative to: C-15 -Slot 15 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: 1.25° Ladder Plot 1400 ~ 1050 O .~ f0 Q Q1 UJ d ~ i a 700 U O 41 C U 350 0 0 2000 40 00 6000 80 00 10000 12000 Measured Depth LEGEND -~- C-15,C-15,C-15 V1 0-30,0-3DA,D-30AV2 -$- C-35,C-35 B,C-35BV3 -~- D-30,0-30A,PIan M2 V3 I 1 I I _ _ J _ _ _ I I 1 I I I I I _ _ J _ _ _ I I I I I I I I _ .. J _ _ . I I I I I I I I - .. J _ _ I I I I I I I I _ _ J _ .. I 1 1 I I I I I _ _ J _ _ I I I I _ I I I I _ .. J _ _ I I I I I I I I _ .. J _ .. I I I I I I I I - .. J _ _ _ I I I I I I I I _ .. J - .. _ 1 i I I I I I 1 I _ .. J - I I I I I I ~ ~ I _ _ .. J _ .. I I I I I I I I . _ _ J _ _ _ I I ~ I I I I I _ .. J _ .. I I 1 I I I 1 I _ .. J _ .. I I 1 I I I I I _ _ _ J _ - .. I I I I I I I I _ .. J _ _ I I I I I I I I _ _ J _ _ _ . I I I I _ I I I I _ _ _ J _ _ _ I I I I I I I I _ _ _ _ J _ _ .. I I I I I I I I _ _ _ J _ .. I I I I I I I I _ - .. J _ .. i I I 1 I I I I _ _ J _ I I I I I I I I _ _ .. J _ _ - I I 1 I _ CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/20/2009 3:56:38PM Page 7 of 7 COMPASS 2003.16 Build 70 Alaska Department of Ni~al Resources Land Administration Sy~ Page 1 of~ ~ ';Alaska Mapper Land RecordslStatus Plats Recorder's Search State Cabins Natural ResoUrceS ~T ~~- Alaska DNR Case Summary File Type: ADL File Number: 2$2$5 ~ Prntable Case Fle.Summary See Township, Range, Section and Acreage? ~ New Search ~' Yes ~_.;= No LAS Menu I Case Abstract I Case Detail ~ Land Abstract _~, File: ADL 282$5 `~{"~ Search for Status. Plat_Updates As of 04/28/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 1 966 1 2/900 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: 011 N Range: 013E Section: 13 Section Acres: 640 Search Plats Meridian: tJ Township: 011 N Range: 0 l 3 E Section: 14 Section Acres: 640 Meridian: U Township: O11N Range: 013E Section: 23 Section Acres: 640 Meridian: U Township: 01 1 N Range: 013E Section: 24 Section Acres: 640 Legal De scription 0~-28-196 * * *SALE NOTICE LEGAL DESCRIPTION* Cld-96 TIIN-RISE-UM 13,1~t,23,2~12,560.00 LISBURNE PARTICIPATING AREA DESCRIPTION T. I1., R. 13 E., U.M. SECTION 13: ALL 610 ACRES CONTAINING 6~0 ACRES. MORE OR LESS. httn://dnr.alaska.gov/oroiects/las/Case Summarv.cfm?FileType=ADL&FileNumber=2828... 4/28/2009 Alaska Department of N~•al Resources Land Administration Sy~n Page 1 of~ j ' .Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Na#ura~ Resources ~,.~a~.ry~. 4 Alaska DNR Case Summary File Type: ADL File Number: 28305 ~ Printable Case File Summary See Township, Range, Section and Acreage? Yes t? No New Search LAS. Menu. I Case Abstract I Case Detail I Land Abstract File: ADL 28305 '~~ ~ Search for Status Plat Updates As of 04/28/2009 Customer.• 000107377 BP EXPLORATION (ALASKA) [NC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 0[L & GAS LEASE COMP DNR Unit: 780 0[L AND GAS File Location: DOG D[V OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2480.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV 0[L AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED ridian: U Township: O 1 1 N Range: 014E Section: 17 Section Acres: 640 Search. Plats Meridian: U Township: O11N Range: 014E Section: 18 .Section Acres: 599 Meridian: U Township: O 1 1 N Range: 014E Section: 19 Section Acres: 601 Meridian: U Township: O1 1N Range: 014E Section: 20 Section Acres: 640 Legal Description Me OS-28-196 * * * SALE NOTICE LEGAL DESCRIPTION* C1-1-126 IIN 1=1E UM 17,18,19,20 2-180.00 U- 3- 7 End of Case Summary Last updated on 04128/2009. httn://dnr.alaska.~ov/nroiects/las/Case Summarv.cfm?FileTvne=ADL&FileNumber=2830... 4/28/2009 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME _ ,~,~'~ ~ f~'~ PTD# o?09OS~ / Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: _,~.~IJDf/D~' / ~y POOL: _ P.P~D.yDGr'1S A ~/G Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing wel I (If last two digits in , API number are Permit No. __~ ApI No. 50- - _ between 60-b9) Production should continue to be reported as a function of the original API number stated above. PLOT 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 / in'lect 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 C i SAMPLE omm ssion must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Well Ptease note the following special condition of this permit: production or production testing of coal bed methane is not allowed for name of well until after (Comaany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _t'Comuanv Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: l/1 I/2008 WELL REKNIT CHECKLIST Field 8 Paol PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT C-15A Program DEV Well bore seg ^ PTD#:2090520 Company BP EXPLORATION~ALASKA) INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11650 OnlOff Shore ~ Annular Disposal ^ Administratlon 1 Permit_feeatkached-- -- ------ -- -- -- - NA ----- ----- ------ - ------ -- -- -- -- --- ----- -- 2 J_easenumberappropriate----- ------ -- --- -- -- - --- ----- YeS- ------ - -- - - --- -------- -- - -- - - -- ----------- 3 Uni-quewell_riameandnumbet-- --------- - --- --- - --- -- Yes - -- -- --- --- ----- - -- --------------------------------- 4 Well locatedin,a-definedp9ol______________________________________ Yes- ------------------------- ------------------------------------------------ 5 Well located proper distance from drilling unit boundary_ - _ _ - - _ _ . _ - - _ - _ - _ Yes - - - - - - - - - - - - - - - ------------------------------------------------------------ 6 Well located Droperdlstattcefromotherwells_,--------------------------- Yes- ---------------------------------------------------------------_---- 7 Ss~fficientecreageayailableindrillingunit________________________________ Yes_ _-____2569 acres._____--_-_-----_- 8 If deviated,is_wellboreplatincluded------- -- -- ~- - -- - ----- Yes- - -- -- -- --- -- - ---------- - - - - - --- 9 Operaioronlyaffecigdparty -- _ -... - -..-_ Yes - - -- --- -- ~--- - - ----- --- ---------- -- -- -- -- - 10 Operatothas_approprlate_bondinforce___________________.-_.__________ Yes_ ---_--BlanketBond#6194.193._-__.--_____---_------_---_--_---_.-_.-_.._____.____ 11 P®tmikcanbeissuedwithoutconsentali4nQrder---------------------------- Yes- -------------_.-------_----------------------_------------------------ Appr Date 12 Pem1ft_canbeissuedwithoutadminisirative_approval_________________________ Yes_ ________--_-_-___-_____________-_ ------------------------------------- 13 Can permit be approved before 14-day wait- - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - ACS 4!2612009 - - - - - - - - - - - - 14 Well located withinare>~andstrataauihcrizedby-InjQGiionOtder#(put_IQ#in_comments)_(FQr- NA-- -------------------------------------------------------------------------- 15 AJlwelJs.withip114_mileareaofreyiewidentlfied(Forse[vicewellpnly)_--_____-__--_ NA__ __--____________________________._--_---_- 1 16 Pre-prcducedinjector. duration of pre production less-than3months_(Forservice well Qnly)-_ NA-_ --__--.____-_------_-----------------_-__-----..---_----_----_--.---_ 17 Nooconven,gascQnformsJoAS31,04.030Q.1,A)~(12.A-p)----- -- -- -- -- - ~ - - - - ------- -- -- ----- - --------- -- - -- -- ------ -- 18 Conductofstring_Rrovided----------------------------------------- NA-- ------CQnductorset_ioC-1$1179.19@).----------------_------.__.----.--.----.---- Engineerin9 19 Surface-casing-protects all known lJSDWS------------------------------- NA__ _____AquiferseXPemptAE01.-_------------------„--------- --- ------------------ 20 CMT_voladequate_to cir-culete an conds~ctor& surf-csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - _ _ _ _ _ Surface casing set in C-15. - - - - _ - - - _ - ------------------------------------------ 21 C-MT_voladeguateagtie-inlongstrit~gtosurfcsg________________________-._ _KA._ _.____Produc#ion-casing set inC-15.--______________--_---___-__--____------____ 22 CMTwillcoyeraJlkDOwnproductiyehori~ons____-____-__.____--___-_ Yes- --------------- 23 CasingdesynsadequatefQ[C,_T,B&_petmafrost-------------------------- Yes- ------------------------------------------------------------------------ 24 Adequate tankage_or teserye p~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - - _ - -Rig equipped w~h steel piss, No reserve pit planned._ Allwaste-io approved disposal well(s), _ _ - _ _ _ _ - _ _ - _ 1 25 Jfa_rQ-drill,has-a10r403 for abandonment been approved---------------------- Yes- ---_--309.15~_________-__-_-__---_---___---.-.-------------.------ 26 Adequate weUbore separationptoposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - _ _ - - Pro>rimity analysts perfomled.- Nearest segment is P$A por#ion_of C-15 apd peths_divetge, _ _ _ _ _ _ _ _ - _ _ _ _ _ 27 Ifdiverterrequired,doesitmeetregulati9ns--__-------------------------- NA__ _____-BQPStack_will already-be in place. ____-__.___.._-__-____-_____-__-_______--____ Appr Date 28 Drilling fluid_program schematic & equip list adequate _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . _ . _ - .Maximum expected f9rmaiion pressure J,0_FMW._ MW planned $.$ ppg, - - - - - - - - - - _ - - - _ - - - - - _ _ _ _ _ TEM 5!20!2009 29 BQPES,dotheymeet_regulatipn_________________-_----------____-- Yes- ------------------------------.---------------------------------- _-- 30 6013E-press rating appropriate; test tc_(pul psig in comments)_ - - - - _ - - _ _ YeS _ - _ - _ - - MASP calculated at 2307 psi, 3500_pis-BQP testplanned- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 31 Choke-manifold complieswlAPl_RP-53(May$4)_____---------------------- Yes- ---------------------------------------------------------------- _-- 32 Work will9ccurwithputoperationshutdown------------------------------- Yes- ---------------------------.------------------------------------ 33 Is presence_of H2S gas_ probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ - - - H2S is reported_at Cpad. _ Mudsh9uld preclude_H2S onrig._ Rig has sensors and alarms. _ _ _ . _ _ _ _ - _ _ _ _ _ X34 .Meehan!calc9nditlonofyrellswi3hinAQRyerfied(Forservicewelionly)__.-_______-- NA_ ___-..,-__-_________________________-__- 35 Per-miteanbe issuedwlohydrogen_sulfidem8asures_________________________ No_- --_---Maxlev_eIH2$on_Cpad-v1as25gpmfotwellC-39A,_-__-__-.--_--_----__-__,___-__,__ Geology 36 Deta_presented on-potential 9verpressure zones - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ _ _ _ _ _ _ _ _ _ - - Appr Date 37 Selsmicanalysls-of shallowgas_z9nes--- -- -- -- -- -- --- ------- J~'-- -- --- -- -- - - - ----------- - - - - - - ----- ACS 412812009 38 Seabad_condiiionsurvey_(ifoff-shore)--------------------------------- -tyA- ------------------------------------- ----------------------------------- 39 Contactnam8lphonefotweekly_proglessreporls_[exploratoryonly~---------------_ Yes_ ______CharlesReynolds-_564.5480,__________-_______-___--_________--__-________._-_ Geologic Engineering Public ner: Com is s~~ Date: Commissioner: Date Commissioner Daie , RR ~~t~r ~ `gyp ~9 Well- History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify Minding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • tapescan.txt '~*'~* REEL HEADER **** MWD 09/08/31 BHI O1 LIS Customer Format Tape **** TAPE HEADER **'~* MWD 09/06/24 2658386 O1 3" CTK ~"~* LIS COMMENT RECORD ~** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las i version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 9150.5000: Starting Depth STOP.FT 11066.5000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: C-15A FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 59.094"N 148 deg 40' 14.310"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 24 Jun 2009 API API NUMBER: 500292042701 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 19 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 62.7 DMF DF EKB .F 0 EDF .F 62.7 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth other Services Line 1 (1) All depths are Measured Depths <MD) unless otherwise noted. <2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. Page 1 '~D9 , USA ~ ~ ~~~' S' • tapescan.txt (5) Baker Hughes INTEQ utilized coilTrak downhole tools and the Advantage surface system to lob this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic orienting sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by schlumberger GR CNL dated 25 gun 2009 per Adam van Holland with BP Exploration (Alaska), Inc. <8) The sidetrack was drilled from C-15A through a milled window in a 7 inch liner. Top of window 9442 ft.MD (8684.8 ft.TVDSS) Bottom of window 9449 ft.MD (8690.9 ft.TVDSS) (9) Tied to C-15 at 9400 feet MD (8646.7 feet TVDSS). (10) Baker Hughes INTEQ run 1 was a nozzle run to displace the well. No logging tools were used. (11) The interval from 11036 feet to 11066 feet MD (8951.6 feet to 8948.6 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) RoP~vG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHZ-COmpens,ated Borehole Corrected (OHMM) RACHX -> ResiSt'lVlty (AT)(LS)2MHZ-Compensated BOrehOle Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHZ-Compensated Borehole corrected <oHMM) RPCHX -> Resistivity (PD)(LS)2MHZ-Compensated Borehole Corrected (OHMM) Tvoss -> True vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9152.65, 9153.36, ! 0.705078 9155.83, 9156.18, ! 0.352539 9158.65, 9157.41, ! -1.23438 9159.88, 9158.83, ! -1.05859 9161.65, 9161.12, ! -0.529297 9164.65, 9164.12, ! -0.529297 9169.41, 9168, ! -1.41113 9172.76, 9170.99, ! -1.76357 9177.34, 9175.76, ! -1.58691 9193.75, 9192.51, ! -1.23535 9199.92, 9199.21, ! -0.706055 9214.2, 9214.2, ! 0 9241.21, 9240.5, ! -0.705078 9245.26, 9244.56, ! -0.706055 9252.49, 9252.14, ! -0.352539 9256.2, 9256.37, ! 0.175781 9261.66, 9261.31, ! -0.352539 9273.34, 9274.4, ! 1.05859 9284.8, 9284.1, ! -0.705078 9296.44, 9296.27, ! -0.176758 9304.2, 9303.85, ! -0.352539 9311.08, 9310.2, ! -0.881836 9349.27, 9349.44, ! 0.176758 9356.32, 9355.44, ! -0.881836 9367.45, 9366.92, ! -0.529297 9372.04, 9371.33, ! -0.706055 9389.32, 9388.44, ! -0.881836 9395.67, 9395.14, ! -0.529297. 9406.57, 9406.04, ! -0.529297 9412.74, 9412.39, C -0.352539 9444.57, 9444.4, ! -0.175781 9446.34, 9445.99, ! -0.352539 9448.81, 9447.93, ! -0.881836 9483.16, 9481.22, ! -1.94043 9486.51, 9484.4, ! -2.11621 9489.87, 9489.69, ! -0.175781 9491.81, 9492.33, ! 0.529297 9496.92, 9496.74, ! -0.175781 9498.51, 9497.98,. ! -0.529297 9504.5, 9503.8, ! -0.705078 9510.32, 9509.79, ! -0.529297 9513.32, 9513.67, ! 0.352539 Page 2 C~ tapescan.txt 9516.5, 9516.67, ! 0.176758 9522.33, 9522.33, ! 0 - 9525.51, 9525.86, ! 0.352539 9527.1, 9527.45, ! 0.352539 9531.15, 9531.51, ! 0.352539 9533.62, 9533.45, ! -0.175781 9536.8, 9536.44, ! -0.352539 9550.52, 9545.76, ! -4.76172 9554.05, 9549.81, ! -4.2334 9555.81, 9551.58, ! -4.2334 9564.8, 9563.22, ! -1.58691 9575.21, 9574.5, ! -0.706055 9580.15, 9579.79, ! -0.352539 9586.85, 9585.62, ! -1.23438 9589.67, 9588.61, ! -1.05859 9596.11, 9595.76, ! -0.352539 9605.1, 9604.75, ! -0.352539 9610.04, 9609.51, ! -0.529297 9615.33, 9615.51, ! 0.176758 9624.86, 9624.5, ! -0.352539 9627.5, 9627.15, ! -0.352539 9632.09, 9631.91, ! -0.176758 9634.03, 9634.03, ! 0 9636.32, 9636.5, ! 0.176758 9645.76, 9645.05, ! -0.706055 9649.11, 9648.4, ! -0.705078 9661.63, 9661.28, ! -0.352539 9686.5, 9685.09, ! -1.41113 9702.9, 9702.55, ! -0.353516 9712.51, 9712.51, ! 0 9722.56, 9721.15, ! -1.41113 9724.86, 9724.33, ! -0.52832 9729.27, 9728.91, ! -0.352539 9738.08, 9737.56, ! -0.52832 9748.23, 9746.99, ! -1.23438 9752.28, 9753.34, ! 1.05762 9761.1, 9761.63, ! 0.52832 9765.16, 9764.63, ! -0.52832 9767.63, 9767.1, ! -0.529297 9771.68, 9770.98, ! -0.706055 9775.56, .9775.92, ! 0.352539 9778.91, 9779.44, ! 0.529297 9785.97, 9786.32, ! 0.352539 9789.85, 9790.2, ! 0.352539 9793.9, 9793.38, ! -0.529297 9802.63, 9800.69, ! -1.94043 9804.93, 9804.22, ! -0.706055 9808.63, 9808.98, ! 0.352539 9815.33, 9815.69, ! 0.352539 9822.04, 9822.21, ! 0.175781 9832.62, 9832.26, ! -0.352539 9835.79, 9835.97, ! 0.175781 9891.68, 9892.21, ! 0.52832 9941.68, 9941.51, ! -0.176758 9948.03, 9946.27, ! -1.76367 9951.38, 9950.85, ! -0.529297 9957.2, 9957.38, ! 0.176758 9963.2, 9964.08, ! 0.881836 9981.93, 9980.69, ! -1.23535 10010.5, 10010.3, ! -0.176758 10016.1, 10015.4, ! -0.706055 10023.4, 10022.8, ! -0.529297 10026.5, 10024.4, ! -2.11621 10031.5, 10028.5, ! -2.99805 10104.3, 10104.7, ! 0.352539 10106.3, 10106.6, ! 0.353516 10119.5, 10121.6, ! 2.11621 10125.7, 10126.4, ! 0.706055 10128, 10129.9, ! 1.94043 10138.4, 10139.4, ! 1.05859 Page 3 n • i 10143.7, 10144.6., 10149.1, 10151.4, 10151.5, 10153.6, 10155.4, 10157.9, 10159.6, 10161.4, 10161.4, 10164.4, 10166.5, 10169, 10168.5, 10170.9, 10170.4, 10173.6, 10172.7, 10176.4, 10178, 10181.5, 10183.1, 10186.6, 10186.4, 10189.3, 10189.3, 10191.6, 10194, 10196, 10198.1, 10198.6, 10199.2, 10201, 10202.2, 10204.3, 10206.3, 10207.5, 10208.2, 10210.7, 10210.3, 10212.6, 10211.6, 10214, 10212.1, 10215.5, 10217.7, 10218.6, 10220, 10220, 10222.2, 10221.8, 10227.3, 10225.9, 10230.6, 10229.2, 10234.9, 10232.6, 10237.5, 10235.8, 10249.2, 10247.6, 10256.7, 10254.6, 10263.3, 10266.4, 10267.9, 10270.3, 10284.6, 10286.4, 10287.1, 10288.8, 10301.6, 10300.9, 10304.6, 10305.1, 10313.1, 10313.5, 10316.5, 10315.2, 10325.1, 10323.7, 10332.3, 10330.6, 10352.3, 10354.2, 10401.6, 10402.8, 10417.4, 10420.1, 10426.6, 10427.2, 10431.8, 10431.8, 10437.1, 10439.6, 10439.9, 10442.4, 10450, 10450.5, 10456.5, 10457.6, 10460.9, 10461.1, 10465.8, 10466.3, 10475.5, 10475.9, 10481.2, 10481.2, 10500.6, 10501.8, 10507.4, 10508.3, 10512.7, 10513.8, 10522.3, 10523.6, 10524.5, 10526, 10533.8, 10536.4, 10538, 10540.7, 10570.8, 10573.4, 10584, 10584.4, 10587.7, 10588.2, 10601.6, 10603.5, 10610:2, 10612, 10615.3, 10616.7, 10616.9, 10618.7, 10626.4, 10627.1, tapescan.txt ! 0.881836 ! 2.29297 ! 2.11621 ! 2.46973 ! 1.76367 ! 2.99805 ! 2.46875 ! 2.46875 ! 3.1748 ! 3.7041 ! 3.52734 ! 3.52734 ! 2.82129 ! 2.29297 1.93945 ! 0.529297 1.76367. ! 2.11621 ! 1.23535 ! 2.46875 ! 2.29297 ! 2.46973 ! 3.35059 ! 0.881836 ! -0.352539 ! -1.41113 ! -1.41113 ! -2.29199 ! -1.76367 ! -1.58789 ! -2.11719 ! 3.1748 ! 2.46973 ! 1.76367 ! 1.76367 ! -0.705078 ! 0.529297 ! 0.353516 ! -1.23438 ! -1.41113 ! -1.76367 ! 1.93945 ! 1.23438 ! 2.64551 ! 0.529297 ! 0 ! 2.46875 ! 2.46973 ! 0.52832 ! 1.05762 ! 0.175781 ! 0.52832 ! 0.353516 ! 0 ! 1.23438 ! 0.881836 ! 1.05762 1.23438 ! 1.58691 ! 2.64551 ! 2.64551 ! 2.64551 ! 0.353516 ! 0.529297 ! 1.94043 ! 1.76367 ! 1.41016 ! 1.76367 ! 0.706055 Page 4 tapescan.txt EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 258 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 25 Tun 2009 per Adam van Holland with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logyin direction is down (value= 255) Optical Loy Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 107 Tape File Start De th = 9150.500000 Tape File End Depth = 11066.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER "*** Tape Subfile: 2 120 records... Page 5 tapescan.txt Minimum record length: 54 bytes Maximum record length: 4124 bytes ***'~ FILE HEADER ~`*** MWD .001 1024 '`** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) Optical Lod Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 curves: Name Tool Code Samples units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 -- ---24 Total Data Records: 213 Tape File Start Depth = 9150.000000 Tape File End Depth = 11066.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet ~*** FILE TRAILER **** Tape subfile: 3 226 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes tx:r~r TAPE TRAILER **** MWD 09/06/24 Page 6 2658386 O1 *'~*'~ REEL TRAILER **** MWD 09/08/31 BHI Ol tapescan.txt Tape Subfile: 4 2 records.:. Minimum record length: 132 bytes Maximum record length: 132 bytes D Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP RA0 RAS RPD RPS 9150.5000 48.6000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9151.0000 46.2835 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9200.0000 23.6428 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9300.0000 26.9552 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9400.0000 18.8545 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 53.9088 ~ 54.9051 17.4270 16.8163 13.5608 11.7482 9600.0000 20.8101 31.4000 16.2843 21.7924 17.1746 15.4219 9700.0000 43.5277 91.2149 17.0607 21.6752 17.6238 16.0710 9800.0000 47.7937 38.3532 15.9911 22.0553 19.0612 17.7583 9900.0000 28.2036 116.7482 11.9188 15.6576 14.7774 15.2921 10000.0000 33.9658 126.5877 13.0918 17.7609 15.9196 15.7308 10100.0000 38.2856. 106.2806 11.5622 15.0023 14.3921 15.0656 Page 7 tapescan.txt 10200.0000 95.0109 80.8453 10.9833 14.7124 16.4080 21.3958 10300.0000 128.7126 71.4827 16.1864 25.0112 22.1480 23.4300 10400.0000 67.7762 122.3735 18.4930 28.7100 23.9070 22.7700 10500.0000 44.1712 136.7899 17.7326 20.2859 18.1180 16.9403 10600.0000 48.9757 106.1998 15.2706 20.6620 18.7410 17.9680 10700.0000 33.5227 147.0000 13.6427 17.3626 16.9650 17.1903 10800.0000 45.7023 153.9203 16:0700 21.0310 19.0871 18.6560 10900.0000 177:6836 104.7406 9.7372 9.2171 9.1575 8.9541 11000.0000 182.7258 32.7000 11:2679 11.3694 13.0325 14.4798 11066.5000 -999.2500 81.9547 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9150.500000 Tape File End Depth = 11066.500000 Tape File revel Spacing = 0.500000 Tape File Depth units = feet D Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9150.0000 48.6000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9150.2500 47.6000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9200.0000 27.6000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9300.0000 28.2000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9400.0000 18.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 75.1000 48.2000 17.9860 16.8110 11.5700 9.0660 9600.0000 20.6000 31.4000 16.4300 22.1460 17.5030 15.8000 9700.0000 40.2000 91.9000 17.0840 21.3730 17.3050 15.5170 9800.0000 44.0000 83.7000 16.1530 21.8700 18.5030 17.0700 9900.0000 27.7000 117.0000 11.9490 15.5460 14.6540 15.0000 Page 8 tapescan.txt 10000.0000 32.7000 127.3000 13.0830 15.8990 15.5260 10100.0000 38.4000 112.0000 11.5370 14.3650 15.0000 10200.0000 114.6000 87.2000 10.9140 16.2360 20.9240 10300.0000 135.2000 85.3000 16.0530 21.4580 22.6400 10400.0000 69.3000 123.7000 18.5840 23.9070 22.7700 10500.0000 41.0000 139.8000 17.7170 18.1180 16.9010 10600.0000 72.3000 111.3000 15.1590 18.9560 18.3600 10700.0000 31.4000 144.2000 13.6680 16.7840 17.1070 10800.0000 41.5000 152.9000 16.0170 19.1740 18.6560 10900.0000 181.0000 105.2000 9.6220 9.0540 8.8390 11000.0000 180.6000 32.7000 11.2780 13.0560. 14.5260 11066.0000 -999.2500 101.0000 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9150.000000 Tape File End Depth = 11066.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet D Tape Subfile 4 is type: LIS 17.7140 14.9710 14.6880 24.3200 28.7810 20.1700 20.8380 17.2000 20.9700 9.1860 11.4510 -999.2500 Page 9