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Home My WebLink About211-0387. 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-42A Tubing Swap Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 211-038 50-029-22357-01-00 12552 Conductor Surface Intermediate Liner Liner 9014 80 3203 8780 1302 3118 12486 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 9016 36 - 116 35 - 3244 33 - 8819 8494 - 9796 9406 - 12524 36 - 116 35 - 3243 33 - 8472 8213 - 8983 8837 - 12524 Unknown 470 2260 4760 7020 10530 None 1490 5020 6870 8160 10160 9369 - 12460 4-1/2" 12.6# 13cr80, L-80 31 - 9437 8819 - 9016 Structural 4-1/2" HES TNT Packer 9380, 8824 8024, 9380 7815, 8824 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 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 0028305 31 - 8851 N/A N/A 174 467 9840 12187 48 180 350 300 1000 840 324-481 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker S3 Packer 8024, 7815 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 10:17 am, Oct 25, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.10.24 17:56:43 - 08'00' Torin Roschinger (4662) DSR-10/29/24 RBDMS JSB 103124 WCB 2-10-2025 ACTIVITY DATE SUMMARY 8/27/2024 T/I/O = SSV/260/170. Temp = SI. PPPOT-T & IC, function LDS (pre rig). No AL. Functioned & torqued T LDS to 450 ft/lbs. PPPOT-T: Stung into T test port (0+ psi). Bled void to 0 psi. Increased pressure to 5000 psi for 30 min test. First 15 min lost 80 psi, second 15 min lost 0 psi (PASS). Bled void to 0 psi. PPPOT-IC: Stuing into test void (0+ psi). Bled void to 0 psi. Increased pressure to 3500 psi for 30 min test. First 15 min lost 0 psi, second 15 min lost 0 psi (PASS). Bled void to 0 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 8/31/2024 ***WELL S/I ON ARRIVAL*** (Rwo expense) DRIFT w/ 3.75" GAUGE RING TO PATCH @ 7,168' MD PULLED PATCH FROM 7168' MD (2 elements missing) RAN 4 1/2" BLB, 3.68" WIRE GRAB TO PATCH @ 7519' MD (No elements recovered) PULLED PATCH FROM 7519' MD (2 elements missing) RAN 4 1/2" BLB, 4 1/2" WIRE GRAB TO LTP @ 9,350' MD (No elements recovered) RAN 3 1/2" PUMP BAILER TO LTP @ 9,350' SLM (Recovered majority of missing elements) ***CONTINUED ON 9/1/24 WSR*** 9/1/2024 ***CONTINUED FROM 8/31/24 WSR*** RAN 3 1/2" PUMP BAILER TO LTP @ 9,350' MD (Recovered more pieces of missing elements) RAN 2" PUMP BAILER TO XX PLUG @ 9,409' MD (More pieces of rubber) RAN 2" HYDROSTATIC BAILER TO XX PLUG @ 9,409' MD ( empty ) EQ'D & PULLED 2.31" XX PLUG FROM 9,409' MD BRUSHED X NIPPLE @ 9409' MD WITH 2.19" CENT, 2-7/8" BLB T-BIRD LOADED TBG w/ 160 BBLS OF CRUDE SET 2.31" PX PLUG & PRONG IN X NIPPLE @ 9409' MD (verified w/ check set) T-BIRD PERFORMED PASSING C-MIT (See t-bird log) SET 3.80" RIG JUNK CATCHER ON LTP @ 9,350' MD ***WELL S/I ON DEPARTURE*** 9/1/2024 T/I/O=64/100/100 (Assist slickline/CMIT-TxIA) Pumped 160 bbls Crude down TBG to Load. Pumped 8 bbls of crude down the TBG to pressure up to 1000 psi to verify prong is set (IA tracking). Pumped 6.5 bbls of crude down the TBG and IA to pressure up for an CMIT-TxIA @ 2750 psi MAP. Reached test pressure at 2750 TBG and 2725 IA. OA climbing with TBG and IA. Bleed OA down to 250 psi. *** CMIT-TxIA PASSED*** Bumped up TBG and IA pressure again to 2750 TBG and 2725 IA after bleeding OA. First 15 minutes TBG and IA both lost 25 psi, OA gained 20 psi (Notified WSL). Second 15 minutes TBG lost 15 psi, IA lost 10 psi, No change on OA. ***CMIT- TxIA PASSED***. Bled back 9.5 bbls to bring TBG and IA to ~100 psi. Well left in control of slickline upon departure. FWHPS=90/100/125 Daily Report of Well Operations PBU C-42A Pumped 160 bbls Crude down TBG to() Load. Pumped 8 bbls of crude down the TBG to pressure up to 1000 psi to verify prong is set (IA tracking). Pumped 6.5 bbls of crude down the TBG and IA to g( g) pressure up for an CMIT-TxIA @ 2750 psi MAP. Reached test pressure at 2750 TBG @ and 2725 IA. OA climbing with TBG and IA. Bleed OA down to 250 psi. *** CMIT-TxIA PASSED** Daily Report of Well Operations PBU C-42A 9/2/2024 ***WELL SHUT IN ON ARRIVAL*** (TUBING CUT) RIG UP AKE PCE. FUNCTION TEST WLV'S TEST WELL TECH TOOLS PT 250 L 3000 H CUT 4 1/2 TUBING @ 8170' WITH WELL TECH MECHANICAL CUTTER' CCL STOP DEPTH=8151.7' (CCL-CUTTER=18.3') WELL TECH TATTLE TAIL= 4.78" ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE 9/12/2024 T/I/O= 106/163/9 LRS Unit 76 (RWO EXPENSE) Pumped15 BBLS Diesel followed by 125 BBLS 1% KCL down the TBG taking returns up the IA to C-13 Flowline. Shutdown for 30 minutes. Pump 100 BBLS DeepKlean followed by 800 BBLS 1% KCL down the TBG taking returns up the IA down C-13 flowline. Pumped 151 BBLS Diesel down the IA taking returns ip the TBG down C-13 flowline for freeze protect. U- Tube TxIA for 1 hour. Bleed pressure to 0 PSI. . FWHP's 0/0/0 DSO notified of well status upon departure. 9/16/2024 T/I/O = vac/vac/vac. Temp = SI. Bleed WHP's to 0 psi for RWO. No AL. Wellhouse, S-riser, FL removed. Drilling tree installed. Plug set @ 9409'. Bled CL and BL to 0 psi. SV = C. MV = O. IA & OA = OTG. 10:00. 9/20/2024 T/I/O=Vac/0/0. Pre-RWO (I-Rig) , Set 4" ISA BPV #549 at 125".R/D upper tree. R/U Temp valve #35 as Dryhole SV, PT against MV to 300 /5000 psi. (Pass) *** Job Incomplete*** Final WHP's BPV/0/0. 9/23/2024 T/I/O = BPV/0/0. Temp = SI. Bleed control & balance to 0 psi (pre rig). Dry hole tree installed. No well house or scaffolding. Control line pressure <50 psi, bled to 0+ psi (gas) in 10 sec. Monitored for 10 min. Unchanged. Balance line pressure <50 psi, bled to 0+ psi (gas) in 10 sec. Monitored for 10 min. Unchanged. SV = C. MV= O. IA, OA = OTG. 13:30 9/25/2024 C-42A RWO Scope: RDMO from DS 13-24B, Moved all moduals over to C-Pad and spotted Sub over C-42A ***CONT. WSR ON 9-26-24*** 9/26/2024 PBU C-42 RWO Scope: Cont. to spot sub over well. Set rig mats and spot caddle shoot, pipe shed, mud mod and gen mod over well. Complete rig acceptance checklist. Scope derrick up and bridle down. N/D tree and adaptor and N/U BOP's. Rigging up to test BOP's. ***Cont. WSR on 9-27-24*** 9/26/2024 Bleed off TBG HGR void. Check for pressure on control lines. N/D tree. Cut and cap (2) 1/4" CCL's. Inspect TBG HGR neck and lift threads. LDS out: 4 1/2". Install 9" acme blanking plug 5 1/2 LHT, install R54. S/B for BOP N/U and test. Locate upcoming LJ @ DS13. 9/27/2024 PBU C-42A RWO Scope: Continue to R/U 4.5" test jt and testing equipment. Test BOP's as per sundry with 2 fail/pass (HCR Kill and Inside choke)- Witness waived by AOGCC rep Kam StJohn. R/D testing equipment and pull BPV. R/U landing jt and unseat hanger taking 128K to unseat. Close the annular and reverse circulate 36 BBLS out of TBG until clean returns observed. Open annular and swap over pumping 40 bbl soap pill around staging up to 5 BPM, 300 PSI. Total of 161 BBLS of diesel sent for recycle. R/U 4.5" handling equipment, Pulled hanger to floor and L/D hanger. POOH and L/D hanger 52 JT's, SSSV with 55 SS Bands. L/D 49 more jts and a GLM. ***Cont. WSR on 9-28-27*** Testjg BOP's as per sundry with 2 fail/pass (HCR Kill and Inside choke)- Witness waived by y AOGCC rep Kam StJohn. CUT 4 1/2 TUBING @ 8170' WITH WELL TECH MECHANICAL CUTTER'@ CCL STOP DEPTH=8151.7' (CCL-CUTTER=18.3') Daily Report of Well Operations PBU C-42A 9/27/2024 M/U blanking plug R/R tool..RIH, M/U to blanking plug, POOH, to rig floor. R/U tools, RIH w/ TBAR. Check for pressure under ISA plug (on vac) RIH, pull ISA plug. P/U LJ. RIH. M/U to tbg hgr 5 1/2 LHT's. BOLDS, off seat TBG HGR. S/B for circulate. Pull TBG HGR to rig floor. Cut and cap (2) 1/4" CCL'S. 9/28/2024 PBU C-42A RWO Scope: Cont. to POOH with 4.5" TBG laying down a total of 193 jts, SSSV, 2 GLM's and a cut jt of 7.81' with no flare on cut. Clear and cleaned rig floor. Sent out spooler with control line and rigged up Parker TRS torque turn equipment. RIH with 4 1/2" 12# 13Cr Vamtop completion as per tally tagging No-Go at 8177'. Performed space out and landed hanger with 82K setting on hanger. RILDS, R/U and reverse circulated 320 BBLS of CI seawater followed by 117 BBLS of seawater down I/A and up TBG. Drop ball and rod, set packer pressuring up to 3600 PSI holding for 5 Min. Performed MIT-T to 2733 PSI for 30 min loosing 29 PSI, Bled pressure down to 1500 PSI and trap. Pressured I/A up to 2658 PSI observing tubing increase to 1945. ***Cont. WSR on 9-29-24*** 9/29/2024 Pull 4" H CTS plug #4-4 through dry hole tree for I rig. 9/29/2024 PBU C-42A RWO Scope: Pressure up I/A to 2658 PSI and hold MIT-I/A for 30 min with 27 PSI drop during test. Shear out DCR valve and verify circulation at 2 BPM, 100 PSI down I/A. Set BPV and flush through surface equipment with soap pill. Drain stack and N/D BOP. N/U tree and adaptor testing hanger void and tree to 5000 PSI. Pulled BPV, Rigged up and pumped 151 BBLS of Diesel down I/A and allowed to U- tube. Scoped down derrick, processed pipe for next well. R/D hoses and secured tree/cellar. Worked on MP #2 and maint. prodjects while waiting on C-18B freeze protect and pad prep. **** Rig was released at 00:00 HRS *** 9/29/2024 LRS 72 Assist Innovation Rig with freeze protection (RWO EXPENSE). Pumped 151 bbls of 50*F diesel into the IA. 9/29/2024 M/U TBG HGR to string. RIH land at confirmed RKB. Verify landed through IA valve. RILDS, torque to 450 ft lbs. Fill stack test TBG HGR to 500 psi. pass S/B for circulate and set packer. Set 4" CTSHBPV. S/B for N/D BOP. Inspect TBG HGR neck and lift threads. Press in SBMS. Install new RX54. Install CTS plug. N/U tree. Test void to 500 psi 5 min/5,000 10 min pass/pass. Pull CTS plug. Unable to screw into BPV. 400 psi on IA w/ communication to TBG. Dispatch WWS to lubricate BPV out. 10/1/2024 ***WELL S/I ON ARRIVAL*** PULLED B&R FROM 8068' SLM. PULLED RK-DGLV FROM STA# 2 @ 5035' MD. PULLED RK-DCR FROM STA# 3 @ 3520' MD. SET RK-LGLV IN STA# 3 @ 3520' MD. SET RK-OGLV IN STA# 2 @ 5035' MD. PULLED RHC PLUG BODY FROM 8095' MD. ***CONTINUED ON 10-2-24*** 10/2/2024 ***CONTINUED FROM 10-1-24*** PULLED JUNK CATCHER FROM 9307' SLM (~1/4 GALLON OF ASSORTED DEBRIS). PULLED 2.31" PX PLUG FROM 9,409' MD ***WELL LEFT S/I ON DEPARTURE*** y Drop ball and rod, set packer pressuring up to 3600 PSI holding for 5g Min. Performed MIT-T to 2733 PSI for 30 min loosing 29 PSI gg RIH with 4 1/2" 12# 13Cr Vamtop completion as per tally tagging No-Go at 8177'. yggg Performed space out and landed hanger with 82K setting on hanger. RILDS Cont. to POOH with 4.5" TBG laying down a total of 193 jts, Pressure up I/A to 2658 PSI and hold MIT-I/A for 30 min with 27 PSI drop during test. Shear out DCR 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-42A Tubing Swap Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 211-038 50-029-22357-01-00 341J ADL 0028305 12552 Conductor Surface Intermediate Liner Liner 9014 80 3203 8780 1302 3118 12486 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 9016 36 - 116 35 - 3244 33 - 8819 8494 - 9796 9406 - 12524 2317 36 - 116 35 - 3243 33 - 8472 8213 - 8983 8837 - 12524 Unknown 470 2260 4760 7020 10530 None 1490 5020 6870 8160 10160 9369 - 12460 4-1/2" 12.6# L-80 31 - 94378819 - 9016 Structural 4-1/2" Baker S3 Packer No SSSV Installed 9380,8824 Date: Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY 9/4/2024 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 12:32 pm, Aug 21, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.21 11:10:29 - 08'00' Torin Roschinger (4662) 324-481 2317 DSR-8/21/24 10-404 MGR23AUG24 A.Dewhurst 21AUG24 * BOPE test to 3000 psi. Annular to 2500 psi. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.27 17:24:35 -08'00'08/27/24 RBDMS JSB 082824 RWO – Tbg Swap PBU C-42A PTD:211-038 Well Name:PBU C-42A API Number:50-029-22357-01 Current Status:Not-Operable; TxIA Rig:CDR2 Estimated Start Date:9/4/2024 Estimated Duration:5 days Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker First Call Engineer:Michael Hibbert 907-903-5990 (O)907-903-5990 (M) Second Call Engineer:Aras Worthington (907) 564-4763 (O)907-440-7692 (M) Current Bottom Hole Pressure:3,197 psi @ 8,700’ TVD (7.0 ppge, last SBHPS ca. 2012) Max. Anticipated Surface Pressure:2,317 psi (Based on last SBHPS) Last SI WHP:1849 psi (11/29/2023) Min ID:2.313” X-nipple@ 9,409’ MD Max Angle:95 Deg @ 10,679’ MD/ 70 deg @ 9,681’ MD Brief Well Summary: Natural flow Not Operable well that previously produced from the Ivishak. Well currently has TxIA and fails an MIT-T. The well has 2 patches in the 4- 1/2” tubing, covering leaks at 7149’ (found in 2002) and 7530’ (found in 2015), and new tubing leak below the top patch at an unknown depth. After the new leak was observed the tubing and IA were loaded and an XX plug was installed in the PTSA nipple at 9,409’. The well passed a CMIT-TxIA to 2475 psi on 10/10/23. This verifies the production casing and packer have integrity. Objective: Pull tubing patches. Pull the existing 4-1/2” tubing. Run new 13Cr 4-1/2” completion with stacker packer. Achieve a passing MIT-IA & MIT-T. Return the well to production. Well Completion Information: Wellhead: FMC Gen 4 tree, 11” x 4-1/2” tubing hanger. Existing Production Packer: 7” x 4-1/2” BKR S-3 Packer – IA also has cement from 9330’-8248’ that was placed in August 2012 Pre RWO work: Wellhead: 1. PPPOT-T to 5000 psi, PPPOT-IC to 3500 psi. Slickline & Fullbore: 2. Pull tubing patches 3. Pull XX plug. Set PX plug. 4. CMIT-TxIA to 2500 psi. 5. Set junk catcher ontop of LTP at 9350’. E-line: 6. Mechanically cut tubing @ 8170’, 8’ below collar at 8162’ on SLB SCMT log from 8/4/12. Attached below. DHD: 7. Bleed WHP to 0 psi. Valve Shop: 8. Set and test TWC RWO Procedure: 9. MIRU Workover Rig. 10. Nipple down tree and tubing head adaptor. Inspect landing threads. 11. NU BOPE configuration top down: Annular, 2-7/8”x 5” VBRs, blind/shear rams and integral flow cross. 12. 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. 13. RU and pull TWC. RU lubricator if pressure is expected. 14. Rock out diesel freeze-protect. 15. MU landing joint or spear, BOLDS and pull hanger to the floor. a. Expected PU weight in 8.4ppg = 90k-lbs calculated. 16. Pull 4-1/2” tubing to floor, circulate bottoms up. 17. Lay down 4-1/2” completion. Tubing hanger and tubing will not be salvaged. 18. Run 4-1/2” gas lifted tubing string with stacker packer completion as detailed on draft tally attached. a. Torque turn connections. 19. Land Hanger and reverse in corrosion inhibited 8.4 ppg KCl or seawater. 20. Drop ball and rod and set packer. 21. Perform MIT-T to 2,500 psi. Assure KWF fluids and in balance between IA and tubing. Consider full wellbore volume circulation- mgr RWO – Tbg Swap PBU C-42A PTD:211-038 22. Bleed off tubing pressure to 1000 psi and MIT-IA to 2,500 psi for 30 charted minutes. 23. Bleed tubing pressure down to shear the shear out valve in the top GLM. FP Tubing and IA with diesel to 2200’ MD. 24. Set TWC. 25. ND BOPE 26. NU tree and tubing head adapter. 27. Test both tree and tubing hanger void to 500psi low/5,000psi high. 28. RDMO Workover Rig. Post-rig valve shop work 29. Pull TWC. Post-rig Slickline Work 30. Pull Shear-out valve, run KO GLV. 31. Pull Ball and rod and RHC profile. 32. Pull TTP. Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. Tubing Cut Tie-in Log 4. BOP Schematic 5. Existing Tubing Tally 6. Draft Tubing Tally 7. Sundry Revision Change Form RWO – Tbg Swap PBU C-42A PTD:211-038 Current Wellbore Schematic RWO – Tbg Swap PBU C-42A PTD:211-038 Proposed Wellbore Schematic RWO – Tbg Swap PBU C-42A PTD:211-038 Tubing Cut Tie In Log RWO – Tbg Swap PBU C-42A PTD:211-038 Cut @ 8170’ RWO – Tbg Swap PBU C-42A PTD:211-038 CDR2 BOP Stack RWO – Tbg Swap PBU C-42A PTD:211-038 Existing Tbg Tally: RWO – Tbg Swap PBU C-42A PTD:211-038 Draft Tally Well: C-42A Approx Depth Description 4-1/2” Tbg Hanger XO 9Cr Pup Joint to 4-1/2" VT Full Joint - 4-1/2" 13Cr VT b x p, 40’ 13 Cr Spaceout Pups (As Needed): 2 ft, 4ft, 6ft, 8ft etc. 4-1/2” 13Cr VT Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ X Nip (ID=3.813”), 4-1/2” 13Cr VT b x p 2200' MD Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ 4-1/2” 13Cr VT Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ 4-1/2" MO-2 MMG style GLM w 1.5" SOV , 13Cr VT 3520' MD Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ 4-1/2” 13Cr VT Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ 4-1/2" MO-2 MMG style GLM w 1.5" DGLV , 13Cr VT 5030' MD Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ 4-1/2” 13Cr VT Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ 4-1/2" MO-2 MMG style GLM w 1.5" DGLV , 13Cr VT 7950' MD Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ 4-1/2” 13Cr VT Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ X Nip (ID=3.813”), 4-1/2” 13Cr VT b x p 8040' MD Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ Full Joint - 4-1/2" 13Cr VT b x p, 40’ Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ 9-5/8”x4-1/2” 13Cr HES TNT Packer Vam Top bxp 8100' MD Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ Full Joint - 4-1/2" 13Cr VT b x p, 40’ Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ X Nip (ID=3.813”), 4-1/2” 13Cr VT b x p (with RHC Installed)8120' MD Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ Full Joint - 4-1/2" 13Cr VT b x p, 40’ Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ Northern Solutions 13Cr 9-5/8" x 4-1/2" Overshot 8170' MD RWO – Tbg Swap PBU C-42A PTD:211-038 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 Hilcorp North Slope, LLC Stan Golis, PBW Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 03/24/2023 Chairman Brett Huber, Sr. Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Low Pressure Pilot (LPP) for Prudhoe well C-42A (PTD# 211-038), Hilcorp North Slope, LLC Dear Chairman Huber, Please see below for information regarding the C-42A (PTD# 211-038) safety valve system (SVS) LPP setpoint on 03/21/2023. This information is being self-reported by Hilcorp North Slope, LLC. Event Summary: Prudhoe well C-42A was originally drilled and completed on 05/07/1993 and sidetracked on 5/29/2011as a development well. On 03/21/2023 during state witnessed SVS testing, the LPP was found to be set at 225 psi with the flowing tubing pressure at 1049 psi. When tested, the LPP tripped at 181 psi, verifying that the actuation pressure was outside of the range required by 20 AAC 25.265(h)(9). The well remained shut-in after the test until the LPP was changed to 550 psi, after which the well had a waived witness SVS performance test, which it passed on 03/22/2023. Investigation /Details: Recent timeline of events leading to discovery of incorrectly set LPP on C-42A on 03/21/2023: o 10/25/2022: Miscellaneous SVS performance test passed. Flowing tubing pressure= 647 psi, LPP setpoint= 225 psi, LPP trip pressure= 199 psi. o 2/22/2023: Flowing tubing pressure increased from 640 psi to 960 psi on 02/24/2023. o 03/02/2023: Flowing tubing pressure decreased to 700 psi. o 03/06/2023: Flowing tubing pressure increased to 980 psi. o 03/21/2023: Well failed state SVS performance test due to LPP set point, well shut-in.. o 03/22/2023: LPP changed to 550 psi, well passed state SVS performance test. C-42A and C-13A are twinned producers, the 4flowline of C-42A flows into the 6flowline of well C-13A. The tubing pressures for each well are recorded daily by the Pad Operator during the well inspections. Production Control Center (PCC) operators also remotely monitor well manifold pressures as they relate to preset SCADA system (Experion) LPP values of Low, Modified Low or High depending on if the well is flowing into a high or low pressure header. In the case of C-42A, the physical pilot at the well was set to a non-standard 225 psi whereas the alarms in the SCADA system were based off of a default Modified Low pilot value of 250 psi. C-13A operates with a High LPP of 550 psi. Due to C-42A being twinned into the C-13A flowline, the manifold pressure of C-13A was being used as the C-42A value in the SCADA system to compare against the SCADA system LPP value for C-42A. Based on daily pad operator reads and C-13A manifold pressures, both C-42A and C-13A experienced an increase in flowing tubing pressure between 02/22 and 02/24/2023 due to gas rate increases in C-42A. According to the manifold pressure monitored by PCC, the pressure on C-13A came up to a maximum of 957 psi. An alarm did not notify the board operator that the pilot on C-42A was out of compliance when this occurred due to the system default pilot value of 250 psi. The pad operator did not flag that the flowing tubing pressure of C-42A had exceeded 900 psi because they were unaware of the non-standard LPP in place instead assuming that it was the typical 250 psi LPP. On 03/21/2023, during AOGCC witnessed SVS testing of C-42A, the flowing tubing pressure at the well was found to be 1049 psi and the LPP was set to 225 psi. When tested, the pilot failed to actuate the SSV above the required 25% of flowing tubing pressure. Flowing tubing pressure was artificially high on C-42A when it was tested due to C-13A being tested immediately prior and C-13A being choked back as the well was being brought back online. This resulted By Samantha Carlisle at 2:23 pm, Mar 24, 2023 in additional backpressure on C-42A when it was being tested. The well remained shut in until the LPP was changed to 550 psi after which the well passed a waived witness performance test on 03/22/2023. Timeframe the SSV was incorrectly set (flowing tubing pressure above 900 psi with LPP set at 225 psi): 02/24-03/01/2023, 03/06-3/21/2023= 22 days Root cause of the incident: SCADA system failed to alarm that the LPP was out of compliance due to the default system value (250 psi) not matching the LPP (225 psi) on the well. Field Operator failed to recognize that the flowing tubing pressure increase on 02/24/2023 on C-42A resulted in the LPP being out of compliance with SVS regulations due to non-standard modified LPP. Contributing factors of the incident: Lack of awareness of non-standard LPP on C-42A by drill-site operator due to lack of sufficient documentation and tracking when the change was made. Twinned manifold pressure on C-13A being monitored by PCC is a lower pressure than the s-riser pressure on C-42A due to flowline sizes and system backpressure. Actions to prevent recurrence: Audit WOA for non-standard LPP set points. Require MOC for use of non-standard LPP settings such that there is proper documentation, approval and awareness. If you have any questions, please call me at 907-777-8356 or Oliver Sternicki at 907-564-4891. Sincerely, Stan Golis PBW Operations Manager Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.03.24 13:27:28 -08'00' Stan Golis (880) 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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:RE: [EXTERNAL] SVS Test - PBU C-pad 9/11/2022 Date:Thursday, October 6, 2022 3:08:02 PM Correction PBU C-42A (PTD 2110380) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (OGC) Sent: Thursday, October 6, 2022 2:59 PM To: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: FW: [EXTERNAL] SVS Test - MPU C-pad 9/11/2022 MPU C-42A (PTD 2110380) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Glynn Brown <Glynn.Brown@hilcorp.com> Sent: Thursday, October 6, 2022 1:21 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: Re: [EXTERNAL] SVS Test - MPU C-pad 9/11/2022 Jim, C-42 is currently Shut in. We will retest when the well is brought back on. Glynn CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Get Outlook for iOS From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Thursday, October 6, 2022 1:11:51 PM To: Glynn Brown <glynn.brown@hilcorp.com> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: [EXTERNAL] SVS Test - MPU C-pad 9/11/2022 C-42A (PTD 2110380) was initially passed by Inspector; after further review the LPS tripped below the required trip pressure (SVS Fail Code 3). Test specifics are as follows: Separator Pressure = 158 psi Flowing Tubing Pressure = 195 psi Required trip pressure (50% of Sep pressure or 25% of FTP, whichever is greater) = 79 psi Actual LPS Trip Pressure = 74 psi C-42A must pass a retest within 24 hrs or be shut in. Notify AOGCC Inspectors for opportunity to witness the retest. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] SVS Test - MPU C-pad 9/11/2022 Date:Thursday, October 6, 2022 2:59:31 PM MPU C-42A (PTD 2110380) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Glynn Brown <Glynn.Brown@hilcorp.com> Sent: Thursday, October 6, 2022 1:21 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: Re: [EXTERNAL] SVS Test - MPU C-pad 9/11/2022 Jim, C-42 is currently Shut in. We will retest when the well is brought back on. Glynn Get Outlook for iOS From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Thursday, October 6, 2022 1:11:51 PM To: Glynn Brown <glynn.brown@hilcorp.com> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: [EXTERNAL] SVS Test - MPU C-pad 9/11/2022 C-42A (PTD 2110380) was initially passed by Inspector; after further review the LPS tripped below the required trip pressure (SVS Fail Code 3). Test specifics are as follows: Separator Pressure = 158 psi Flowing Tubing Pressure = 195 psi Required trip pressure (50% of Sep pressure or 25% of FTP, whichever is greater) = 79 psi Actual LPS Trip Pressure = 74 psi C-42A must pass a retest within 24 hrs or be shut in. Notify AOGCC Inspectors for opportunity to witness the retest. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. By Samantha Carlisle at 2:54 pm, Aug 18, 2022 Regg, James B (DOA) `ll Q3Q From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> _, �j Sent: Tuesday, November 14, 2017 7:18 AM t1� t4(1-, t / To: Cocklan-vendl, Mary E; Regg,James B (DOA); Noble, Robert C (DOA) l/ Cc: DOA AOGCC Prudhoe Bay;AK, OPS GC1 Wellpad Lead; AK, OPS GC1 Field O&M TL;AK, OPS GC1 OSM;AK, GWO Valve Shop Coordinator; AK, OPS FF Well Ops Comp Rep Subject: RE: Deficiency Report for Wing Leak on PBU C-42 This is to advise all that the wing valve on C42 was replaced and tested last night 11/13/17. Regards, Lee Hulme Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony— 7187 SCAHOED . k (Alternate: Vince Pokryfki) From: Cocklan-vendl, Mary E Sent: Thursday, November 02, 2017 7:47 AM To: Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep; Noble, Robert C (DOA) Cc: DOA AOGCC Prudhoe Bay; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 Field O&M TL; AK, OPS GC1 OSM; AK, GWO Valve Shop Coordinator Subject: RE: Deficiency Report for Wing Leak on PBU C-42 Jim, Per our conversation on the phone,the Wing Valve on C-42 has not been replaced yet. It will be replace by the end of November or we will shut the well in until such time as the wing valve is replaced. We will keep you informed on the replacement status. Please let me know if you have any additional questions. Thanks, Mary Mary E Cock/an-Vend/ Pipeline Team Lead Office Phone-Anchorage: 907-564-4766 Office Phone— North Slope: 907-670-7550 Cell Phone: 907-227-3464 e-mail: Mary.Cocklan-Vendl(abp.com From: Regg,James B (DOA) [mailto:iim.regg@alaska.gov] Sent:Wednesday, November 1, 2017 2:02 PM 1 • • ; u-,e -4ZA ,I 01/03&" e Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Thursday, October 5, 2017 10:58 AM " �, in .-, To: Noble, Robert C (DOA) I Cc: DOA AOGCC Prudhoe Bay;AK, OPS FF Well Ops Comp Rep;AK, OPS GC1 ellpad Lead; AK, OPS GC1 Field O&M TL; AK, OPS GC1 OSM;AK, GWO Valve Shop Coordinator; Cocklan-vendl, Mary E Subject: RE: Deficiency Report for Wing Leak on PBU C-42 Attachments: PBU, C-42, Wing Leak.pdf Bob, I wanted to advise that with our current field wide safety restart and existing scheduling priorities the failed wing valve on C-42 is slated to be replaced on 10/21/17. We will advise when the valve has been replaced. Regards, Lee Lee Hulme Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 SCANNED F & 0 5 211;R Cell: (907) 229-5795 Harmony— 7187 (Alternate: Vince Pokryfki) 1 • • State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: 95 1) 1/2,4 Date: 7 - 1 7 PTD: Operator: Et Type Inspection: 5 V 5 Operator Rep: /11 Inspector: 50 b e oivry al4„Th./5 Position: kead Op era,t 0 r Op. Phone: Correct by(date): Op. Email: g1 0 1) j,jJ Follow Up Req'd: Detailed Description of Deficiencies Date Corrected ti/jh Va. " od. p,'1L lo/da 1.1 v6e-ct finirve, 55v, 66 v, eiw 'Litt 1.4,0o dlopip,e Attachments: Signatures: Operator Rep p(ct1 AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 ,fit (1-4ur • • Pit Z4(o3.0 Regg, James B (DOA) From: Noble, Robert C (DOA) Sent: Monday, September 25, 2017 4:53 PM (Rel To: Regg,James B (DOA) Subject: Deficiency Report Attachments: PBU, C-42,Wing Leak.pdf Jim Matt had tested PBU C-42 and the wing leaked.Vince with BP called and ask if I would come and test it because they were going to run out of time before they got the wing changed. So I came out and tested the well against the pit valve that was about 70 feet away. Pit valve held, Pilot and SSV passed. I did this report so that we know that the wing gets changed out. • • State of Alaska Oil and Gas Conservation Commission r ' Deficiency Report Location: f25 V G Lf /�- _ Date: 7 "Z5 -- j 7 -• r PTD: ! I ,3 S I� Operator: 8 P!' Type Inspection: 5 1/ 5 Operator Rep: /I/ i)/t/Ty © e."-A./f Inspector: 0©6 Able , Position: k e 0. 1 Op mato r. Op. Phone: 65-9- e-tag / Correct by(date): Op. Email: A Kl ©©S 6 1 (AI1_ J ,040,e,Follow Up Req'd: Detailed Description of Deficiencies Date Corrected um, i !/m 1.. c. !me.k m d P r$ 1J4 /v e 'e%3 v6 el to /2r1se, 55 v. 55 r/. �'%lamF r- l° F v4,1 e. .0 w.0, .d,pPofer!y Attachments: { Operator Rep Signatures: Aler AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 STATE OF ALASKA "'ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Pro/,gram 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well IZ1 Re-enter Susp Well 0 Other:Set LTP/Patches 7 Ed 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 211-038 J 3. Address: P.O.Box 196612 Anchorage, Development El Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22357-01-00 7. Property Designation(Lease Number): ADL 0028305 8. Well Name and Number: PBU C-42A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12552 feet Plugs measured feet RECEIVED true vertical 9014 feet Junk measured feet OCT Effective Depth: measured 12486 feet Packer measured 9397 feetAOGCC 2015 true vertical 9015 feet Packer true vertical 8832.11 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20"91.5#H-40 42-118 42-118 1490 470 Surface 3203 13-3/8"68#L-80 41-3244 41 -3243 5020 2260 Intermediate 8780 9-5/8"47#NT8OS 39-8819 39-8472 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9369-9370 feet 9370-9372 feet 9372-9374 feet 11180-11510 feet 11670-12100 feet 12350-12460 True vertical depth: 8819-8819 feet 8819-8820 feet 8820-8821 feet 9026-9025 feet 9021-9023 feet 9019-9016 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 38-9454 38-8858 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: I 'L N U f t @� 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 220 22914 16 820 513 Subsequent to operation: Shut-In 100 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 1111 Exploratory ❑ Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil B Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ./,ate.,,, Ctl,(.,J� Phone +1 907 564 4424 Date 10/7/15 Form 10-404 Revised 5/2015 7,— I"/5/✓ t r/0)\ B f RDMS OLE - 7 2015 Submit Original Only • m Q.O O O O M (p O ti p co O N (D O 0 N N- N- U 0 L N O co ,_c-c) 0 O co Ca IC) CO CO , CO O M N M d O O co �I I� co co co N V O O O O CO CO 00 00 CO 0) () 00 H r V CO N CA CO O CO CO CO CO N O CO O M CO CO CO CS) G) QO 'rOOCfl � N O M O CO O 0) (7) Off) 11111111 o o ++ Q < N CO CO S Cr) N '- rnLOoCOmco 1 MLO N1-O (A O CO Co O O _ o o � o CO to = d c Z *k J N LO cd •N COO NO Cr) CO _ N CV CO c0 - U M -000 N N CO CO M �- C; CO N L r+ co C) CO CO C)CD O CO V 0) O LC) C I- N N- N LC) O Jco co �- O N C) W CY ~ C)O Q • ~ W W U U 0 Z Z EtW W W W W m QJ ' ZZZZD U Cn Z _ _ _ J J J J • • _ Packers and SSV's Attachment PBU C-42A SW Name Type MD TVD Depscription C-42A PACKER 9359 8813.72 4-1/2" Baker KB Top Packer C-42A TBG PACKER 9396.65 8832.11 4-1/2" Baker S-3 Perm Packer • • E o 4 _ m (0 O N 0 --crs Co ch J a) c C E rn w (Al (a > C O O c •� 2 E M c0 0 a) N U N E v O 2 0 cA V .4 oo N m L p 7 } a) b 0 (a N J L cf) p cn E * _j O co Q O CO >'W Q CD 0 -O cV 2 D c Q Q� O coWap 0 TIA d O O 0 D Z o � (0 (j) 'o EEJ 0 - rX E LL �`J ---.. m .< 0_N 0 J 0 0 Cl) W C-3. v( O W H U N 2 J Q b c D 'E Q -c J o tl> O o -If -10 D z W N 0 0 < 0_ o -"=. 0E m 0 E O 0 C QN- 00_ w0_ 0 -E - rn - 0_ E z o O 0_ co H OH > 0_ z 2 2 m 0 v 0 D 0 cv .< &.) 01 0 a� l� p2w -1 ci- c pcncn -- 2 mo D - '- m > Lc2 < _1 .-11-1- CC O N O J c (!) 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Q_LL « U) CCU) J4, : Z22r- _ OLL_ i H ° O w : U) : Ln ,__Ln in LU L r \- r co co co O co N N N co co co .- CO 63 • S » k C f k k \-113 % a s 2 & - 2 k/ c 2 c ■ < / J : » § / 0 \ \ ƒ G E 2 ,__ cN mC / Eo R � b > $ a R D % 7 / p c / 10 2 g < 0 R g = - 2 Q a - E / ƒ -J i = � � / � 2d / \ 0") CL / \ / 2 U \ f d d ,, a 6 ® R * + / / O 0 � A� 5 / 7 \ J2 ©cE � 2p® w Eoe (1) o - I2sm2 (6a' I- 0 fX 7 / ©O� , O / / in $ / �0b U) R m c G < c 2 A / O _1 ¢ \ O p 7 i » / z O \ _ - \ \ >, / A ƒ _0 3 m E g R 0 ©© » U 7 / 3 ± 2 2 m e± � a % ƒ / / / / E / / Cr) / _1 / u aO - m OW gw / / / ? - 2 ) w - / / 0 \ 4 I- 2 / / / \ \ / 2 / / / � / / \ 7 � � � \ G 9 % @ 6 = % & k Z % A 10 f f \ ® ~ \ � \ 7 \ � �HcoZ \ R / w / / k U 2 \ 3 2 / 0 ± 2 / \ 0 0 \ / / \ G / f f t < D I < L § < L D 2 3 D 2 W D 2 g J $ § 2 I 0 2 w o r m I : : o_ @ m E : 5 O Z rn \ d / c) / no % /oma © a a TREE -s 41!16 CIWIII C-42A -silk 1 1 WELLHEAD= 13-5/8"FMCi S NOTES: WELL ANGLE >70° 9681' ACTUATOR= BAKER C' INIT.KB. ELEV= 72.50' BF.ELEV= 35.20'1 KOP= 6231' 20"INSULATE), H 108'1 2197' —{41/2"FES 1-1X0 SSSV NP,D=3.813" Max Angle= 95' 10679' 91.5#,I-1-40, W h1SGAS LFT MANDRELS Datum MD= 9485'1 Datum TVD= 8800'SS C=19.124" ST MD TVD DEV' TYPE VLV LATCH FORT DATE I I I 13-3/8"CSG,68#,L-80 NSCC,D 2 4239 4238 0 TGPDX DONE RM 16 09/18/15 =12.415" — 3238' u 1 6875 6847 25 TGPDX SO RM 20 09/18/15 N g_i716$'-7211' -4-1/7 BKR PATCH,ID=2.45"(09/10/15) N"---------1 7519'-7554' H4-1/2"BKR PATCH,D=2.45"(09/01/15) TOP OF CMT(SCMT LOG ON 8/4/12) H 8248' r'` a r r I; . 8494' H9-5/8"X 7'BKR TEBACK SLV,D=? Minimum ID = 1.36" 9366' i* 8507 —19-518"X 7"BKR H LNR TIEBACK PKR? �� *'� ''',.*1.--18545' -19-518"X 7"INV TIEBACK SLV,D=7.37" 2-718 ORIFICE INSERT _ ,, 4r A 9-5/8"CSG,47#,L-80 NSCC,D=8.681" H 8814' J a S 9330'-9332' —TUBING PUNCH(10102/96) CAW. 9359' —4-1/2"KB LTP w/SLD SLV,2-7/8"X Imo'&PTSA, ,2-7/8"BKR SLCN LW ASSY,D=2.313"(OPEN) — 9366' t V. .',0.•2-718"OR FILE INSERT(2 EA .188 PORTS)D=1.36" —1 9366' f�'``1 .=2.313"(8/17115) (09/17/15) ' , 9370' H4-1/2"I IES X NP,D=3.813"(9390'ELM)) 2-7/8"X NP N PISA,D=2.313" — 9409' i 9406' —3.70'BKR GEN I DEPLOY SLV,D=3.00" (9381'PER SLB MCNL ON 07/12/98) 9380' —7"X 41/2"BKR S-3 PKR,ID=3.937" ' (9400'PER SLB MCNL ON 07/12/98) , - ,1 9404' —14-1/2"FES X NP,D=3.813'(BRAND LNR) ' 1 9425' H4-1/2"FES XN NP,MILL@ TO 3.80"(4/20/11) 4-1/2"TBG, 12 6#,L-80 BTC-M,.0152 bpf,ID=3.958" H 943T / \ 9437' --141/2"WLEG,D=3.958" BEHIND 9458' —IE LMD TT LOGGED 09/19/96 CT LNR 3-1/2"LNR 9.3#,L-80 STL,.0087 bpf,D=2.992" }— 94660 \ 9433' —'3-1/2"OTIS X NP,ID=2.812" TOP OF CEMENT --f 9600" ill 1 9466' —3-1/2"X 3-3/16"XO,ID=2.786" 7'x 4-112"WHPSTOC K(05/10/11) —I 9790' 7"LNR,29#,L-80 NSCC,.0371 bpf,D=6.184" H —9790 •�•� ►i•• ►,••! ►••• MLLOUT WINDOW(C-42A) 9796'-9802' PE WORAT1ON SUMMARY ►,••4 �•�• ►.: •• REF LOG: SLB GR/OCLI MM.ON 05/25/11 ►�•�. j•.:• ANGLE AT TOP PERP 60°@ 9369' ►�� " Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 2-1/2" 6 9369-9374 0 10/12/12 . 10366' H3-3/16"X 2-7/8"XO,D=2.377" 2' 6 11180-11510 0 05/23/11 10367' --I2-7/8"MARKER JOINT 2" 6 11670-12100 0 05/23/11 2" 6 12350-12460 0 05/23/11 I I 3-3/16"LNR 6.20#,L-80 TCN,.0076 bpf,ID=2.80" H 10366' I ► 12486' --IFBTD(BKR LATCH COLLAR) 2-7/8"LNR,6.4#,L-80 STL,.0058 bpf,D=2.441" — 12524' DATE REV BY COM f34TS [ATE REV BY COMMENTS PRUDHOE BAY LINT 05/07/93 D-9 INITIAL COMPLETION 09/04/15 SWCJJMC KB LW ASSY ®fTS/RESET TEM PLUI WELL: C-42A 10/06/95 D-16 RWO 09/25/15 GJB/JMD SET PATCH/INSERT/FULL PLUG PERMF No:"`2110380 05/29/11 NORDIC 1 CTD SIDETRACK(C-42A) 09/25/15 SWC/JNC GLV C/O(09118/15) AR ND: 50-029-22357-01 07/31/15 RCT/JMD SET EVOTREVE RUG(06/30/15) SEC 19,11IN,R14E 481'FPL&1220'FEL 08/31/15 JNMJMID PULL EVOTtREVEJSET KB LIP ASSY 09/02/15 CJS/AID SET BKR PATCH(09/01/15) 1 BP Exploration(Alaska) Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, April 21, 2015 7:51 AM To: 'AK, D&C Well Integrity Coordinator' Subject: RE: Permission to Flow Natural Flow Producer C-42A (PTD#2110380) For Economics Attachments: image001.png Whitney, Approved for plan forward below and the 14 days evaluation requested. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission333 West 7Avenue n Ancho age,tAK 99501 SCANNED APR 2 3 2015 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator@bp.com] Sent: Monday, April 20, 2015 9:38 PM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: Permission to Flow Natural Flow Producer C-42A (PTD #2110380) For Economics Chris, Per our conversation earlier, permission is requested to flow natural flow Producer C-42A(PTD#2110380)for economic evaluation. The well has known tubing by inner annulus communication that will be mitigated by setting patches. However, prior to performing this well work, additional diagnostic work is needed for gas shut off. BP would like to evaluate the current condition of the LTP prior to running new patches in the well. Competent production casing has been demonstrated by a passing CMIT-TxIA to 3,000 psi on February 20, 2015. Plan forward: 1. Slickline: Set TTP 2. Operations: Bring well online 4. Slickline: Change out LTP as needed 5. Operations: Perform necessary well tests 1 The current thought is that 14 days will be sufficient for evaluating the economics involved with the required wellwork that will bring this well back to operability status. Please call with any questions or concerns.As requested, an updated TIO plot is attached. Thank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GAt GotlWeis WIC Office: 907.659.5102 WIC Email: AKDCWelIIntegrityCoordinatorftBP.com 2 Producer C-42A(PTD#2110380)TIO Plot w."C- .11/30 3000 t TM f-N 2OP1 —a.–OA OOA +OOOA On 02,2T15 02]]::5 030115 03•x'+5 03?}'15 332715 0,9315 0t1335 3137:,5 c0 o c O �9 - a. a, U � Y 30.0 U > �v WuiW X O L 0 N Z v a1 t L OJ 0] 4UA 'J I- T w U _. aT• CO co LO O 'O O O co c (O T SZ Q a. c @ 0 ' u'1 1A N 1A N 1l') O N O N N O E L CO U a N Y N Q •e L C L .0 to L R d L' '- +-, N O }, y a) m d d a) a) m _c c c m LL LL LL 2 LL 2 LL LL EE Y m 2 _ 4- N 4- N 4- O O N l0 N C d v CU v Z K Oo 73 E O > CC 2 _ m 000000 ❑ ❑ ❑ ❑ +' u s - is COW�'- J J J J J J J J J J C ,- U WWWWWWWWWW W CIO O O _ LL LL LL LL LL LL LL LL W LL 'vi a1 E -p v G J J J J J J J J J J wcu O t a) [ n Q Q Q Q Q Q Q Q4 Q g c) . ZZZZZZZZZZ d v 0 ,0 ^ WWWWWWWWW LL a) r u a! ol V7 y Z• ,ll E a) al O — I"1'a -I N is a +' -0 U Rj J @ O .❑ O a1 0 It > > c O - C ra n5 -2 I- 0 Q v s > E3 T LL fn N it C ❑ ❑ ❑ ❑ ❑ 0 Q m Lf9 fl) tv 0 J J J J J J a U ❑ NO y J1=i E- J- U 0 , n 0 o W \ p C G a w - a 0 0 0 O J O J O J J 111 gS y( �] W U W W W W W W Fri F� R C7 V1 N` EEEE W 4 )_• Alp al W or m MWMMMMM 0 0 Y 0 m 0 0 0 0 0 0 C3 p 2 2 < 203 = 2 22 = ❑ ❑ Z ❑ N ❑ ❑ ❑ ❑ ❑ a) L u J L[') e I ': w WI wIIW Wire WIre I I I I I I I I I I I I I I I c 4 o a s a a a a a a T N ( y on Q �1 CSS r/P(' MO) a0 N R F- >C iii 1 in °.. a 0 C _4 0 R O NN O 0 c0 I C9 0 . 0 0 0 0 0 0 0 0 0 0 000000 0000 u co Q to in N Q' co,- co R o ❑U cu E ce U p U U U U ❑ ❑ Q Q m �' a c "' N N 0 0 0 N 0 0 N 0 V S 0 0 0 0 0 0 0 0 0 0 w N. 0 O) M F- t0 Q h N N M IIS T W 00 )f) v '7 7 O W M pp QWO0MWONWWN n _ NNN 4 0 0 M N NNNNNNNNNN I I I 01 \ '-C v1::: Q) OO) C) C) G) a) O) OO) q NNNNNNNNNN 0 0 0 0 0 0 0 0 0 0 VVCU 0 0 0 0 0 0 0 0 0 0 � Iu) )) )) 1Cf) S N47:non I 1 I I I I 1 1 w a1 Cm 00CI a0 N c Q) Q) c - CO W > au 'p jjil Y. T 0. J U J ar 2 U d z aJ rp MEI a a Q Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, February 20, 2015 10:46 AM To: AK, OPS GC3 Facility& Field OTL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS Well Pad CX; Haffener,Jordan;Wallace, Chris D (DOA); Regg,James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Pettus,Whitney Subject: NOT OPERABLE: Producer C-42A (PTD#2110380)Well secured with tested downhole plug Attachments: image001.png; image002 jpg All, Producer C-42A(PTD#2110380) has been found to have tubing by inner annulus communication with a failed MIT-IA on February 19, 2015.The well has been reclassified as Not Operable and was secured with a tubing tail plug. A passing CMIT-TxIA performed on February 20,2015 demonstrating reservoir isolation. Please call with any questions. Thank you, Laurie Climer (Alternate:Kevin Parks) CANNED iv,* ;' Orga BP Alaska-Well Integrity Coordinator GIN�1A/ aIWel ls V Organization WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrr, dinator Sent: Thursday, February 12, 2015 3: To: AK, OPS GC3 Facility & Field OTL; AK, OP • Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Servic- •aerations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells :, Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Haffener, Jordan; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coors.--tor; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA) (jim.regg@alaska.gov Subject: UNDER EVALUATION: Producer C-42A (PTD #2110380) Sustained Inner • lus Casing Pressure Above MOASP 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, February 12, 2015 3:50 PM To: AK, OPS GC3 Facility& Field OTL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers; AK, OPS Well Pad CX; Haffener,Jordan;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA) Subject: UNDER EVALUATION: Producer C-42A (PTD#2110380) Sustained Inner Annulus Casing Pressure Above MOASP Attachments: image001.png; Producer C-42A (PTD #2110380)TIO Plot.docx All, Producer C-42A(PTD#2110380)was reported to have sustained inner annulus casing pressure above MOASP on 02/10/2015. The inner annulus pressure was reported to be 2240 psi. A TIFL failed on 02/12/15. The well is reclassified as Under Evaluation and is placed on a 28 day clock. Plan forward: 1. Slickline: Dummy gas lift valves and MIT-IA SCANNED ,, �, ti)2 A copy of the TIO plot is included for reference. Thank you, Kevin Parks c7 J,e BP Alaska -Well Integrity Coordinator GWGlob&Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com 1 Producer C-42A(PTD#2110380)TIO Plot Welt C-42 ..0 11100 to zow X00 000 0000 000 - umu +mnu mizs m:ros mvns m.as oma 020,15 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. I - O3 ' Well History File Identifier Organizing(done) ❑ Two-sided II! 1111 III I III ❑ Rescan Needed II 1111111 I RE CAN DIGITAL DATA OVERSIZED (Scannable) /Color Items: ❑ Dis ettes, No. ❑ M. ,s: Greyscale Items: ther, No/Type: C7 Nb. i ■ ether Items Scannable by a Large Scanner ❑ Poor Quality Originals: 'n',6,3 " OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: AMPDate: 7J .f/ /s/ P Project Proofing II 111111 IIII 11111 BY: AIM Date: Isl u Scanning Preparation 3 x 30 = 70 + = TOTAL PAGES ci 5-` (Count does not include cover sheet) 0 BY: Maria Date: I /s/ 7p. 1 Production Scanning I IIIIIIIIIIII I Stage 1 Page Count from Scanned File: 6(.2 (Count does include co r sheet) Pa se Count Matches Number in Scanning Preparation: YES N BY: 419 Date: /s/fi 1'7'/ - Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Is/ Scanning is complete at this point unless rescanning is required. I 111111111 liii ReScanned I HIlIlIlIJI lull BY: Maria Date: /s/ Comments about this file: Quality Checked II 1111111111111 o E Uo �._. oc O o N o L N O in To _7 -_ J. N Z 1 EWU 0 ICI N V.— O> 0 W Ili a) 2 Ali, .0 L L U J U _ ii O VI CsI 4 O >- y' cL m Cl) �0� O� N 0. i ` E U L OJE LL wgza)J (n 1'ACDco E J0 0 O O o� O -v z o 0I =a o o - a)z o �o Et: Ooa 2 2 2zI- J-oa a O 'o C r a) > _ o ! 0 1I - a "m 0 0 0 0 0 0 U O O J IIID l W V N N N N N N O O N e N N LO 11) U) k N N �ll 0 O CO (D ? J n a) a o) ol co co C E y III 2 - C C C C C C a) N E N I O• VO O O O O O U 0 O� J u0 < N . N N 00O 0Li) 0) O ID OM a) d oz ZO jU N 0 1.N rr OSNNadd t e- e- co W q «C N Z OJ CL 2 r- M r- N- W N- U) c cs a co rn co o co co co co •o W X Lu J ami a � > V m o d aa)) 0 a Z 8 0 cc• Z, 0 c C 'CC y 7 1 N O � 0 O� y O O O C >` F3 o €a� NC Zs2000 a Na) H N O E a NCa RI U N 0 E Jm N N J <CO (.0 z ICC 1. Z — Cl) C�C = N , 0 Z CO U In a m N „ C CC 11 Cl)/ ui O a) t Cn x O t0 W N x Qo a 0 Q Ca Z°1 Ce Q d• U o °' ''' o Z Z z a1° V 2 co - co> m ca co is m f Q 'y d o o m m CO CO Co • Tr E E o E E E C o ° Z E E coEE a' aa) c rn H O 6 0 0 U 0 Z Z ,p z co CNI € O > .CO O J ` M Q'ow 0 . E o I- ix m ai }2z o w ' ' v N I oZmai ClON ,., Q . co .+ . y LL �. 0 0 E Z € U E E Z N O O Z a' w w O7� < J J W Z a p j' 2 LO a 1 O V C 'O N Z 'O 8 �, y2 ZCV Ww m 2 O 0 \ \ U t O O a N a)iza E E a N J _ — a T N 1� m o F- 3 -1 o I- a w w _1 - I 0 . m f) E 0. _ mI a c w l a T °' 0 (0 act w w ° J J w 3 Q v ¢ v o 9 o N N Z ii N O 5 I II O co ° II 2 ItF. ' z o = ci co '61 8, cc Z 2 O o CL LU gCe oa W w J U m o Q e to J o co 0. cmc 0 • NN ON a E coQ CNI U N CO 1 W Q N CO 1 o ° (i) o ° 0 D1 Qfr a iin"' °' Q 1 Z 0. ° E U m Z V' 0 rn CO • �j CO O 1- v 3 N - d ` d' .2 N II ° ca E E Zi") II 2 IO I1LK EIVED STATE OF ALASKA JAN 1172013 0.s( A. KA OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Tubing Patch Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development0 Exploratory ❑ 211-038-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22357-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: _ ADL0028305 PBU C-42A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): , To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 12552 feet Plugs measured None feet true vertical 9014.11 feet Junk measured None feet Effective Depth measured 12486 feet Packer measured See Attachment feet true vertical 9015.32 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 74 20"91.5#H-40 38-112 38-112 1490 470 Surface 3203 13-3/8"68#L-80 35-3238 35-3236.8 5020 2260 Intermediate None None None None None None Production 8781 9-5/8"47#L-80 33-8814 33-8468.02 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9369-9370 feet 9370-9372 feet 9372-9374 feet 11180-11510 feet 11670-12100 feet 12350-12460 feet True Vertical depth 8818.71 -8819.21 feet 8819.21-8820.19 feet 8820.19-8821.18 feet 9026.39-9025.05 feet 9020.63-9022.95 feet 9018.62-9015.64 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 32-9437 32-8850.87 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: 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: 440 6940 4 0 304 Subsequent to operation: 410 7210 4 0 283 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 ` Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil- 0 Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerha s• b•.com Printed Name Nita ummerhays Title Petrotechnical Data Technician Signatur- / /%�" �.j Phone 564-4035 Date 1/16/2013 ��ii/ ��L%ice i - RBDMS JAN 2 8 4' ;• �� 2./I 113 Form 10-404 Revised 10/2012 27(3/ Submit Original Only < o = « o \ / 2-i / f -0 C -0 7 q 55 % \ 0 % 0 2 R / E0 _ _ _ Z \ 0 \ 2 0-/ I I 2 = o _$ / \ \ a _1 0 0 0 eeon m o = / , ± k\ / ® o IG » o % / a f C N `- 2 / , 2 $ / ® / � fE H _%2 Lo CD ± 2 = o m % I \ £ 0 2 0 k - E ƒ / g \ _S \ 0 s / / E ■ 2I m _oCN 1-11 ƒ 7 I 0 o / / U 0 � ai > W0 -0 0 -0 � z ® . f 2 = & < < a e 17, <RS \ \ ¥ = 0 ƒ e g 0 o p / I a 0 £ \ \ w \ p \ / f \ 8 \ / 2z0 $ O � A HZE 0 _I / E % E / / / < / 0H X _ 0 ± = 4 < _ O .° \g = @ q = a (--) / w ° z_ I a < m = _ 0 0 E 2 >I co a ® R _ W Z 0 < / 6 \ J b / / « D . > o W \ @ 0 % O < - 2 .� o , = o = E f : 4 o t 2 < ± O G « / « = E 5 % - co ! $ -0 / w 2 / - / -to S i E z D R < / / * \ I \ / § I E . ± < g a - 0HO DO \ � � c � w _ � » LL / L < \ \ cL / . / J ƒ < O @ 2 n / \_ RS / E \ / _ / ƒ < 2 -1 ....-. 0 < t / � / / 0 > \ 0_ k\ � m ƒ / % » ui ƒ / % 77 O O t E � 2 ° Ec12 -' z # o f z •� 0 ƒ U / 2 \ - R * U) H f E Z / 0 < ID Z O Z Z \ _/ Z O 0 i 0 I- / / a -0 > / <\ .5 Z I D \ 73(D \ ' Z Z \ $ Z E / R O D 6 $ u / - 2 O 7 m °2.2 ƒ D o a r - _ a < _ D 06 _10) ® � I-0 h / \ ƒ d / \ / 0 \ @ /_ / \ / \ \ " 2 / / -J o a n / H = / Z m y 0 �� 6 k = ° ± Z ± n I 0a >- -1-7. ± -I Z ® e L I O < 6 c r7 n 5 0 % L 2 G R O -I 0) ¢ C / \ Q \ 0 n / E » o � ' ® 0 2 0 H a H < Z 0 w / R ± -1 E 3 \ ® ° 4 2 ƒ \ / ƒ CO i 7 Z R w ± < \ ƒ I / / i g % w Z / / 2 _ 0 / - / / k / } \ / f / E / - } D / : ± m C � % E 0 : - ± / @ b a m 2 : E a: C E : 0 : : \ a O : N N N N N N N / \ d CN \ \ \ 9 7 CO CO » r--- % N N N N N a N _.g E E [ \ _ H ]\ I _ i i \ // \ «' /g « 2 a. /2 � _ _ E% O _ •)• ° a \ \ / y 5 ® % 3 3 3 I- " m •0 ƒ / R < <N- \ Iw k / ( \ � � f f \ � g 0 c6 EL \ o o \ ® R „ c Co \ / 6 \ \ 26 cp 17 0 2 2 0 ^ In \ 47. O ± c 9 _Z L m 2 oci / 7 \ L . a / = 7 ;---u) « c O LU 0 < a < / O n o Z a_ � 7 % q t / \ / / E a) coyo21 1 \ _I C) 9n 0 D a / / / \ G_ N ® / \ 20 -0EI ' & w W < t0 / \ / O « R O Q 3 © , ± \ 2I0 \ \ ƒ 0 a) 7 � / ® � ® 0 / _I Ce g } G \ o \ / o $ • < = 2 \ \ / \ I mai t 'CO - G / O ƒ ƒ 7 c - • - o o e .2 2 -' I / E \ \ c < s2TZ4O � / ifa. ± b 7 / z 2 = / O / R \ 0) / $ \ I /00- 6 \ Q mQ ƒ f / \ 2 CO _ ƒ ƒ \ / I S ƒ / ( � / / w , ¢ � ? / � * � m0 : 2 / _ : m w A U _1 ± : S 2 L) H .0Rq — © C a 7 7 / / & & CAm m 0 , M (0 O O 000 O N CO CO • f' N N- V 0 0 g 0 0 0 •m co O O CD IO COC r r N 0) NN- M C3 ) CD O O CO CA co O M co O• co o) co co coCi CDco CO N C M CC Cr) M CO co N co CO co N. o) CO ,„(Ni M I� co N I' _ 0) O " CO CO O) CO in 0 • 0 2 Q M O x CO co oo O) NCO co ) () M C o � J Q 0 0 0 0 0 Q! � a�00J° p,o � _1 J CU J M 4* co CO •� r O oCA Lof CD CO oi V o F N M N O x_ 4 .c co M In un 4o- to co in oo C CN CO N co CC') O) z O cn UJ H O U M O CL0 Q O LL z v z w w w O cc m Ozzz » 0 J J J d U) Packers and SSV's Attachment ADL0028305 SW Name Type MD ' TVD Depscription C-42A PACKER 8502 8147.13 7" Baker H Packer C-42A PACKER 9380 8751.62 4-1/2" Baker S-3 Perm Packer C-42A PACKER 9388 8755.49 4-1/2" Baker KB LT Packer TREE= 4-1/16'CIW WELLHEAD= 135/8'FMC ACTUATOR= BAKER C C-42A SAFETI n,OTES: WELL ANGLE >70'@ 9681' INIT.KB.ELEV= 72.50' BF.ELEV= 35.20' KOP= 6231' I 1 Max Angle= 95°0 10675 L 2197' -14-1/2"HES 11X0 SSSV NP?D=3.813" Datum MD= 9485' Datum ND= 8800'SS hHESGAS LFT MASS ST MD ND DEV TYPE VLV LATCH FORT DATE 13-3/8'CSG,68#,L-80 NSCC,D=12.415' H 3238' liti 2 4239 4238 0 TGPDX DMY RM 0 08/23/12 1 6875 6847 25 TGPDX DMY RM., 0 08/23/12 El TEl I 716W-7201'1—{41/2"BKR PATCH,D=2A5"(12/08/12) TOP OF CMT(SCMT LOG ON 8/4/12) H $248' •♦•♦• ��_—'/ y♦. ►.♦w 8494' -19-518"X 7"BKR TACK SLV,D=? ♦ ►•4 8502' -9-5/8"X 7"BKR H LNR TEBACK RCR? • Minimum ID = 2.31"L 9365' re.• % 8545' -s-s/8'xrTIWNCH(1KSLV,D=7.32' BAKER CMD SLIDING SLEEVE ►♦� ►•4 • • •• ►4 •4 V M 9330'-9332' —{TUBING PUNCH(10/02/96) 9-5/8'CSG,47#,1-80 NSCC,D=8.681" - 8814' •� ►♦i 4 • •' ►� 9369'-9374' -TUBING PUNCH(10/12/12) • ♦i 0-4 A. I I 9370' 14-1/2"HES X NP,0=3.813' ' 9390'ELMO 4-1/2'BKR KB LW,ID=2.45'(10/23/12) -19365'SLM 9406' -3.70'BKR GEN II DEPLOY SLV,ID=3.00" (3-1/r PIN,ID=2.3r itg-9370'SLM) (9381'PER SLB MCNL ON 07112/98) BKR CMD SLD SLV w/2.31'X LOCK FLOW - 9378'SLM i Z x {^ 9380' 1-7"X 4-1/2'BKR S-3 PKR,ID=1937' INSERT WI ORIFICES INSTALLED,ID=?' (940Q'PER SLB MCNL ON 07112/98) ' ' 9404' -14-1/2"FES X NP,ID=3.813"(BBtIND LNR) I I 9425' -141/2"HES XN NP,MILLED 1D 3.80"(4/20/11) 4-1/2"TBG,12.6#,L-80 BTC-M,.0152 bpf,0=3.958" -1 943T / 943x -{4-1/2"WL6G,D=3.958' BEHIND 9458' H ELMD Tr LOGGED 09/19/96 CT LNR 3-1/2"LNR 9.3#,L-80 STL,.0087 bpf,13=2.992' H 9466' 9433' -13.1,2"OTIS X NP,ID=2.812' TOP OF CaevT -1 9600' r I 9466' -13-1/2"X 3-3116"XO,D=2.786" 7'x 41/7 WHPSTOCK(05/10/11) -1 9790' •• ►• 7'LNR,294,1-80 NSCC,.0371 bpf,D=6.184" -9790 �••• •• •••• •• ►• ►• � •• •• MILLOUT WC�OW(C-42A) 9796'-9802' PERFORATION SUMMARY ►�♦�� :♦♦:♦ REF LOG: SLB OR/CCU MCNL ON 05/25/11 j•• 0 ANGLE AT TOP PERF: 60'0 9370' Note:Refer to Production DB for trstorical pert data SIZE SPF INTERVAL OprfSqz DATE r 6 11180-11510 0 05/23/11 r 6 11670-12100 0 05/23/11 / % 10366' —3-3/16'X2-7/8')7J,D=2.377' r 6 12350-12460 O 05/23/11 1 ' 1036T --I2-7/8'MARKER JOINT i 3-3/16"LNR 6.20#,1-80 Ta,.0076 bpf,D=2.80' H 10366' ' FBTD(BKR LATCH COLLAR) H 12486' ' 2-7/8'LNR,6.4#,L-80 STL,.0058 bpf,D=2.441" H 12524' r DATE REV BY COMu9'1TS DATE REV BY CONVENTS PPo CHOEBAY UMT 05/07/93 D.9 INITIAL COMPLETION _ 09/15/12 KE/PJC PERF ETON(08/31/12) WELL: C-42A 10/06/95 D-16 RWO 09/26/12 PM/PJC LNR CORRECTIONS PERMT No:"`2110380 05129/11 NORDIC 1 CTD SIDETRACK(C-42A) 11/01/12 DLW/PJC KB PKR/SLD SLV/ORME(10/23/12) AR No: 50-029-22357-01 08/27/12 MSS/JM)GLV C/O(08/23/12) 11/01/12 PM'PJC TOC CORRECTION(SCMT 8/4/12) SEC 19,T11N,R14E,481'FM_&1220'FEL 08/27/12 MSS/A0 PULLED PATCH(LTP(08/25/12) 12/14/12 JCMWJI D SET BKR PATCH(12/08/12) 09/04/12 JCT/JMD ADPERF(08/31/12) BP Exploration(Alaska) Ferguson, Victoria L (DOA) From: Catron, Garry R(Wipro)[Garry.Catron©bp.com] Sent: Thursday, January 10, 2013 3:41 PM To: Ferguson,Victoria L(DOA) Subject: FW: PBU C-42A 10-404 (11/16/2012) 3T, Victoria, Please see the PE explanation below. Regards, Garry Catron PDC PE 907-564-4424 From: Meixueiro, Paulina Sent: Thursday, January 10, 2013 2:04 PM To: Catron, Garry R(Wipro) Cc: Dean, James A; Starck, Jennifer L Subject: RE: PBU C-42A 10-404 (11/16/2012) Gary, C-Pad does not have gas lift supply and C-42A needs gas lift to flow.This well was shut in after the allotted time for temporary gas lift installation expired. Five feet of perforations were added to provide gas lift.Then the LTP was set on top of those perforations.The LTP included an orifice port to control the amount of gas supplied for lift. It also has a sliding sleeve in it, so when no longer needed,the gas lift can be stopped by closing the sleeve with slickline. Hope this helps. Paulina Meixueiro Production Engineer GPB Gravity Drainage West (907)564-5971 From: Catron, Garry R(Wipro) Sent:Thursday,January 10, 2013 1:28 PM To: Meixueiro, Paulina Cc: Dean, James A; Starck, Jennifer L Subject: FW: PBU C-42A 10-404(11/16/2012) Paulina, Please respond to the AOGCC question below about purpose of the Perforations added to C-42A. Thanks, Garry Catron PDC PE 1 907-564-4424 From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent:Thursday,January 10, 2013 10:52 AM To: Catron, Garry R(Wipro) Cc: Schwartz, Guy L(DOA) Subject: PBU C-42A 10-404 (11/16/2012) Garry, The daily report on 10/12/12 shows perforation interval 9369'-9374'with liner top packer set at 9365'. What is the perforation for? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.fergusone,alaska.gov 2 RECEIVED STATE OF ALASKA /,_ .SKA OIL AND GAS CONSERVATION COMMISSION NOV 2 0 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate L( Other LJ Pull/Reset LTP Performed: Alter Casing 0 Pull Tubing0 Stimulate-Frac 0 Waiver 0 Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development❑✓ Exploratory 0 ' 211-038-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22357-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028305 PBU C-42A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 12552 feet Plugs measured None feet true vertical 9014.11 feet Junk measured None feet Effective Depth measured 12486 feet Packer measured See Attachment feet true vertical 9015.32 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 37-117 37-117 0 0 Surface 3203 13-3/8"68#L-80 35-3238 35-3236.8 5020 2260 Intermediate None None None None None None Production 8781 9-5/8"47#L-80 33-8814 33-8468.02 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9369-9370 feet 9370-9372 feet 9372-9374 feet 11180-11510 feet 11670-12100 feet 12350-12460 feet True Vertical depth 8818.71-8819.21 feet 8819.21-8820.19 feet 8820.19-8821.18 feet 9026.39-9025.05 feet 9020.63-9022.95 feet 9018.62-9015.64 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 32-9437 32-8850.87 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: 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: 315 5308 3 0 282 Subsequent to operation: 1149 9361 10 0 345 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑✓ _ Service 0 Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil- Q Gas U WDSPLU GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUCJ 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 Garry Catron Email Garrv.CatroneBP.Com Printed Name Garry Catron Title PDC PE Signature AitCZE Phone 564-4424 Date 11/16/2012 RP' �'Tl1 71 / 3//) I,/ Z2 / I3 Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028305 SW Name Type MD TVD _ Depscription C-42A PACKER 8502 8147.13 7" Baker H Packer C-42A PACKER 9400 8761.2 4-1/2" Baker S-3 Perm Packer OMup CD ;CD CD O O 111 e- O H Tr 0q 0 co COQ) CO m OOCDCD (OupauO crA) Nupf- r CACA (OO 00 v- 0O CD — (O In CA 00 O M 00 OO CO CA 00 0O CO co O M N MN O M M M M O OO 0 4.11 CD N CO N Tr 00 r- 8 WN OO N Tr . C)) CA CN 00 M O) 03 te) CI Lo CNI CID N 00 M o 0 co M CC) C v- :3 - 3 • Q 0 0 0 0 0 co co 00 ao w U 0 J J 1:3 ' M � 8 U) N CO C� c O0) O) CD _ N UN CV 0000 N N N. ' M M N L O I) In in co O O d co ' O N 0000 CNS) Off) Z. 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F._ 3 M o o p Z o c� E 2 m N c~i) a) 0) n N O na) w 6 -0 J cA O O w 2 d F- ow N Q J oL.Li4) a'6Z ° � o Y6 o 00 C - cp o0 b oh 0 c'> .( U 0 �--w ° H o -0 -2 0 C 0 a) c'') U) Q � W W 2O � Oa c° CO H M O o UY �-- NU) � co U) w ° aQ > rn I- .1- 0_ co � p � � No � ai tr Qa' Q w xrn > a) o A > H 2 0 inOcruncn > Nct o w fY0 E ao N w IL ++ 't F- IL io 2 O L.I-I E a W W II o O w CU a) 2 } in 2 J O a 0 H F- w co N > o N J LL. d °L CL J 0M -IU) F- Oa < ZQrx Q) 2 _ N C X U) 0 > * a3UnOrn o � OJ w CC ,- 0 P_)� � � � ° mo -E.-3)I- 2Un * �_ p 0LLo° 1321 Qpc � UJn0 � a) w Z0 � I u) Q � °�) � \ W cjpU � M 0-� 0 [r Oo0 § '- Z Ja Lo a) o o c L 22 wN op O J LL O N C O a D O C r ° 5 p LL * O W O C J D } W O II C t t CO N « 2a ^OF- Co1- - c� wOQUYO a) C > - a) m o a) w oOcoW � F-- C � OXmF-op � o) � Y N—owWO ocn o .00 � a> aa0a JO O J UCrX II Qz20 .2 -_ * o2'� ~ z -0 -� W • o * w Lu w �CL - a t o Q °�° � CLJ � ZU) cOJC) OLUIX a a) •szf- -) J -jci) * � OCJaO 0 < NoNOo J m j u am0 Y � 0_ COO o j a) E 2 m ƒ 7 \ f _ m a) \ E f CL C © E N.- -0 O) CN -5 / \.g CD @ ® 0 / k \CI $ o LU . U) M Cl) O / / \ \ / E ƒ _o 0 i & / 7 \ .g q / 2 •(7) 2 0 \ \ \ o y \ \ t W \(I) .g o < $ .\ £ . E < E \ / / ) \ �R . \ I I a a CU 0_ F— & § © 0 1- 309 / - ® @ % 6 j ƒ ./may \ 02 / / \ \ \ / \ \ \ / \ / \ / 7 s & / A / • TREE= 4-1/16'CNV -- -- - WELLHEAD= 13-5/8'FMC ACTUATOR= BAKER C C-4 2 A SAFETY NOTES: WELL ANGLE >70°@ 9681' INIT.KB.ELEV= 72.50' BF.ELEV= 35.20' KOP= 6231' I Max Angle= 95'frp 10679' 2197' J-14-1/2"HES HXO SSSV NP,D=3.813" Dab=MD= 9485' FCTI Datum TVD= 8800 SS h}-ESGAS LFT MANDRILS 13-3/8"CSG,68#,L-80 NSCC,D=12.415• H 3238' 1) ST MD ND DEV TYPE VLV LATCH PORT DATE 2 4239 4238 0 TGPDX DMY RM 0 08/23/12 1 6875 6847 25 TGPDX OMY RM 0 08/23/12 TOP OF CMT(SCMT LOG ON 8/4/12) - 8248' I �7 r•• 8494' H9-5/8"X r BKR TIEBACK SLV,D=? C.. ►.A •• ►•* ►,4 8507 -19-5/8"X 7"BKR H LNRTEACK PKR? Minimum ID = 2.31" 9365 ►• , �,4 BAKER CMD SLIDING SLEEVE ;�; ;� { 8545' -1s-5/8"X r TM/TIEBACK SLY,D=7.3r • 9-5/8"CSG,47#,L-80 NSCC,D=8.681" H 8814'-_1 • -m e4 OK 9330'-9332' -{TUBING PUNCH(10/02/96) •• ►•� •j• ►�• 9369' 9374'(-TUBING PUNCH(10/12/12) •• •i ►: 1 1 9370' -4-1/2"HES X NP,ID=3.813" ---.....,__---------...„......c__ ' _- 9390'HAD 4-1/r BKR KB LTP,D=2.45'(10/23/12) - 9365'SLM r 9406' 3.70'BKR GEN 1 DEPLOY SLV,ID=3.00' 2'PIN,ID=2. r 11-937, SLA) (9381'PER SLB MCNL ON 07/12/88) (3-11 BKR CMD SLD SLV w/2.31'X LOCK FLOW - 9378'SLM 9380'-r X 4-1/7 BKR S-3 PKR,ID=3.937" INSERT w/ORIFICES INSTALLED,ID=7' (9400'PER SLB MCNL ON 07/12198) I 9404' H4-1/2"I-ES X NP,D=3.813"(BRIM)LNR) I I 9425' H4-1/7 FES XN NP,MILLED TO 3-80"(4/20/11) 4-1/7'TBG,12.6#,L-80 BTC-M,.0152 bpf,D=3.958' 9437' / \ '. 9437 H4-1/7'WLEG,D=3.958• I BEHIND 9468' -I ELM)TT LOGGED 09/19/96 CT LNR 3-1/7 LNR 9.3#,L-80 STL,.0087 bpf,D=2.997 H 9466' I I 9433' -13-1/2"OTIS X NP,ID=2.817 TOP OF CEMENT H 9600' I 9466' i--I3-1 a'X 3-3/16"XO,D=2.786" r x 4-1/7'WHPSTOCK(05/10/11) -I 9790' iri : 7"LN ,29#,L-80NSCC,.0371bpf,D=6.184" -{ - 0PERFORATION SUMMARYREF LOG: SLB GR/CCU MCNL ON 05/25/11ANGLEATTOPPERF: 60"@9370' i• Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11180-11510 0 05/23/11 r 6 11670-12100 0 05/23/11 r 6 12350-12460 O 05/23/11 ‘ 10366' -3-3/16"X2-7/8'MD,D=2.37r 10367 -{2-7l8"MARKER JONT 3-3/16"LNR 6.20#,L-80 TCL,.0076 bpf,D=2.80" H 10366' FBTD(BKR LATCH COLLAR) -{ 12486' 2-78"LNR,6.4#,L-80 STL,.0058 bpf,D=2.441" H 12524' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/07/93 13-9 INITIAL COMPLETION 09/15/12 KJB/PJC PERF CORRECITON(08/31/12) WELL:C-42A 10/06/95 D-16 RWO 09/26/12 PM/PJC LNR CORRECTIONS PERMIT No:1110380 05/29/11 NORDIC 1 CTD SIDETRACK(C-42A) 11/01/12 DLW/PJC KB PKR/SLD SLV/ORFICE(10/23/12) API No:50-029-22357-01 08/27/12 MSS/JMD GLV C/O(08/23/12) 11/01/12 PM/PJC TOC CORRECTION(SCMT 8/4/12) SEC 19,T11N,R14E,481'FNL&1220'FEL 08/27/12 MSS/.MWD PULLED PATCH/LTP(08/25/12) _ 09/04/12 JCT/JMD ADPERF(08/31/12) 1 BP Exploration(Alaska) 2_2-1012_ 0 tit C7 c to w..2,e.1,i II ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ C3 ❑ ❑ C)�7 U U U U U U0 U U U U U U0 -Ng cg &.` .. Go 05 OCD U • ~ O O Z r `� ro o y, 0 5 Z F ♦7. N -o Z C o M Q) U1 ! ,— rr- 1- r- 00 — V) W U a3 _ rn �j o c E Y rc Q 't• N:. . N N N N N N N N N N N N N N Y , N Z �.r,,// fr s L-Iw Li-) bD W ~ .i+ a+ a+ r r+ r r �, ++ r �+ +�+ s1 CV (0( os , , O , l7 U c. U V U V U U U y U U U U a) N O x co co ti .. 8 0 0 0 o c 0 0 0 0 V) c c 0 Q V) t wI .. r=' l O CO v CO r m ti CO rn rn m ami v) u tV to J N N N O N O N O O N N a- e- a- X O- o a I At t)111-- 4' r • cn f 3 0 000 � 0 10HJ O � � LL LL (9 0 = z re -J Q re 1-- 0 re _1c�) � aa � � aaa Z O 0 F O O D u- O ►i O O r° z 2 ce H E z 2 2i- O 2 O 2 2 E. W a cn O O W W U) Ce W re W W cn 2 . N co 22m9.-. 29: 22 N 0 N O .-I ri N O � ~i) E -1 _________4_4___ 1 )ii Z Q X X X X X X X X x X X x X X a o 1 1 I— v) 6 N CC mon a E `. _ CO G-�'_;;cc o in 0w N O c) f,0 to , M O) Q) O CID is W O a- O p O O o in N O O 0 N O so a O O O T 'C� • - 0 0 0 0 Oi 0 O C 0 0 0 O 0 0 O. CO o^ �`P O } -1 } .- E U O } {�J U d et o w o N.N. CO D H CO O ao m O CO re W 1- H "O o ,-1 , I- < m N ❑ N U tD F- Q U N o o_ rn , U CO U m U m CO U U U m U U U c o aN 1110 is N 1.f � 7, > CT) C � F'. co m 6) V CM N ^ C ,--1, cC ro CD _ Y M M O oO Q a) = n Q "' �" Y Y o a o N o N `o rn rn o^'c c o°Jo E c w E 11 u Q CZ Y NJ v N W m U N N v —I v rc s y _= ? o o Z O Z C? N M N ti 0 2 2 2 m m v 0 m r Q. ro . N v N M N co d O u v V) 0 iro > N Q X d m 01 Q Zil° 30 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, November 02, 2012 8:58 AM 'Rd To: 'AK, D&C Well Integrity Coordinator' Subject: RE: Request to POP Producer C-42A(PTD#2110380) TxIA Communication OK to put C-42A on production to flow test the well Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator©bp.com] Sent: Friday, November 02, 2012 7:36 AM To: Regg, James B (DOA) Subject: Request to POP Producer C-42A (PTD #2110380)TxIA Communication Jim, Producer C-42A(PTD#2110380) has known TxIA communication that was repaired with a tubing patch set at 7170'- 7200' MD . The patch was recently pulled so perforations could be added and a modified Liner Top Packer assembly with orifice valve set below the patch depth for in-situ gas lifting. BPXA would like to gain permission to flow this well for a period of no more than 28 days so 2-3 well tests can be captured to evaluate success of the wellwork prior to re-installing a tubing patch to restore TxIA integrity. The goal of the well testing will be to determine if the orifice is sized correctly for in-situ gas lift. Pending the well testing results, the LTP assembly may have to be pulled to change the orifice size and troubleshoot further. Prior to pulling the patch an MIT-IA passed to 3000 psi on 08/23/2012. After pulling the patch and setting the modified LTP assembly, a CMIT-TxIA passed to 3000 psi on 10/23/2012. These tests confirm integrity of the production casing. A TIO Plot and wellbore schematic are attached for reference. Please feel free to call if you would like to discuss further. Thank you, Mehreen Vazir BP Alaska - Well Integrity� � Coordinator G Global VVells Organization WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 1 • ¢ SSt� g 30c°8(5 �f� l • a • F 0.1 • r • 1 • • • • � a V I • • y r • • o a OO L Qo N .— N N CD CN 2 U N 0. CI- 0_ 'TREE= 4-1/16'CIW WELLHEADr---,, 13-5/8"FMC1 ACTUATOR= BAKER CI C.-42A SAFETY NOTES: WELL ANGLE >70.@ 9681' INR.KB.ELEV= 72.50'1 BF.ELEV= 35.20'' KOP= 6231' 1I 1 Max Angle---, 95'© 10679' Datum MD= 9485'i Datum TVD= 8800'SS , (E) L 2197' -4-1/2"HES 1-0(0 SSSV NP,ID=3.813" hFESGAS LET MANDRELS 13-3/8"CSG,68/1,L-80 NSCC,D=12A15" — 3238' 74 —........ ST MD ND DB/ TYPE VLV LATCH PORT DATE ..... 2 4239 4238 0 TGPDX DMY RM 0 08/23/12 L 1 6875 6847 25 TGFOX MY RM 0 08/23/12 ITOP OF CMT(SCMT LOG ON 8/4/12) 1— 8248. i ... 8494' H9-5/8"X 7"BKR TEBACK SLV,ID=? -'4 ' 4 •p 8502' H9-5/8"X 7"BKR H LNR TEBACK PKR? 0 4 Minimum ID = 2,31" @ 9365' i *I • BAKER CMD SLIDING SLEEVE • II 4 4 8545' —197- X 7"TM/TIEBACK SLV,ID=7.37" 4------ . 4 • • 4 9330' -9332' HTUBING PUNCH(10/02/96) 9-5/8"CSG,47d,L-80 NSCC,ID=8.681" H 8814* -°' *". • 4 ,. •4, • 4 'A 9369'-9374' —ITUBING PUNCH(10/12/12) i •- 4 WI ti .e. I I 9370' —4-1 rr FES X NP,ID=3.813" 9390'E1MD ,,, „„ 4-1/2-BKR KB LW,ID=2.45"(19123/12) — 9365'buy! 9406' 13.70"BKR GEN II DEPLOY SLV,ID=300 (3-117 PIN,ID=2.37"g-9370"SUM) I )0381'PER SIB MCNL ON 07/12/98) _ BKR CMD SLD SLV w/2.31"X LOCK FLOW — 8378.8,1 „,li i' 2‹ x 9380' 1-7"X 4-1/2"BKR S-3 PKR,ID=3.937" INSERT w/ORIFICES INSTALLED,ID=7^ , (9400'PER SIB MCNL ON 07/12198) I I 9404' H4-1/2"HES X NP,ID=3.813"(BE111ND LNR) I I 9425' —4-1/2:,ALHESEGX1=.NDM:3,M.9E5LL8.ED TO 3B.8E0H"I(N4/2D0/11) .9437' --14-1/2 4-1/2-TBG,12.6#,L-80 BTC-M,.0152 bpf,D=3.958" -I 9437' / \ CT LNR 9458' ---1E_MDIT LOGGED 09/19/96 3-1/2"LMR,9.3#,L-80 STL,.0087 bpf,D=2.992" — 9466' I I 9433' H 3-1/2"OTIS X kW,D=2.812" TOP OF CEMENT — 9600' , [ 9466' 7*x 4-1/2"VVHPSTOCK(05/10/11) - 9790' • •'•- 7-LNR,29#,L-80 Nscc,.0371 bpf,10=6.184" - -9790 •$'. • • • ••• • 0• MILOUT WhDOW(C-42A) 9796 -9802' PERFORATION SUMMARY ii • 0: •. .• REF LOG. SLB GR/CCU MCNL ON 05125/11 • ,,,• ANGLE AT TOP PERF: 60°@ 9370' N • ' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 2* 6 11180-11510 0 05/23111 2* 6 11670-12100 0 05/23/11 r 6 12350-12460 0 05123/11 10366' -I 10367' 3-3/18-X2-7/8")13,ID=2.377' - i 2-7/8"MARKLR JOIN( 3-3/16"LM1R,6.20#,L-80 TCH,.0076 bpf,ID=2.80" —1 10366' PBTD(BKR LATCH COLLAR) — 12486' 2-7/8"LNR,6.4d,L-80 STL,.0058 bpf,ID=2.441" H 12524' r A DATE REV BY-1 COMMENTS I DATE 1 REV BY COMMENTS PRUDHOE BAY UNIT 05/07/93 0-9 ;INITIAL COMPLETION 09/15/12 KJB/PJC PERF CORRECITON(08/31/12) WELL: C-42A 10/06/95 D-16 1RWO 09/26/121 PM/PJC LNR CORRECTIONS PERMIT No:t110380 05/29/11 NORDIC IICTD SIDETRACK(C-42A) 11/01/12 IDLW/PJC KB PKR/SLD SLV/ORIFICE(10/23/12) API No:50-029-22357-01 08/27/12 MSS/JMD1GLV C/O(08/23/12) 11/01/12 PM/PJC TOC CORRECTION(SCMT 514712) SEC 19,711N,R14E,481FNL&1220'FEL 08/27/12 MSS/J1467PULLED PATCH/LIP(08/25/12) i ... 09/04/12 JCT/JIMD IADPERF(08/31/12) T I BP Exploration(Alaska) InG`_GI V.IGLJ STATE OF ALASKA 3KA OIL AND GAS CONSERVATION COW 'ION OCT 12 2012 , RE. JRT OF SUNDRY WELL OPER...1 IONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate I✓I Other U Performed: Alter Casing ❑ Pull Tubing0 Stimulate-Frac ❑ Waiver 0 Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Wel 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: BP Exploration(Alaska),Inc Name: Development Exploratory 0 r. 211-038-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99519-6612 50-029-22357-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028305 ' PBU^C-42A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): s To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 12552 feet Plugs measured None feet true vertical 9014.11 feet Junk measured None feet Effective Depth measured 12486 feet Packer measured See Attachment feet true vertical 9015.32 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 37-117 37-117 0 0 Surface 3203 13-3/8"68#L-80 35-3238 35-3236.8 5020 2260 Intermediate None None None None None None Production 8781 9-5/8"47#L-80 33-8814 33-8468.02 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9370-9372 feet 11180-11510 feet 11670-12100 feet 12350-12460 feet True Vertical depth 8819.21-8820.19 feet 9026.39-9025.05 feet 9020.63-9022.95 feet 9018.62-9015.64 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 32-9437 32-8850.87 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): e" -i ' 1370--Ili '.Treatment descriptions including volumes used and final pressure: 4 /0•rS/2-- 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1031 10766 73 0 211 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: .41 Copies of Logs and Surveys Run Exploratory❑ Development❑✓ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑✓ - Gas U WDSPLU GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUCJ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerha s.#b•.com Printed Name Nita Summerha s Title Petrotechnical Data Technician w. Sign- .� �I,' i, ��7444.,, _ Phone 564-4035 Date 10/12/2012 R DMS OCT 1.5 r Form 10-404 Revised 10/2012 ,, (o/j/.. Submit Original Only Daily Report of Well Operations ADL0028305 ACTIVITYDATE SUMMARY • " ► pre e-me scm DRIFT W/2' x 1.50" STEM, 2.25" CENT, 1 3/4" S-BAILER TO 9895' SLM/9932' MD(stop due to dev, bailer empty) CURRENTLY RUNNING 2.20" CENT, SLB MEMORY GAUGES. 5/3/2012 ****CONT JOB ON 5-4-12**** ****CONT JOB FROM 5-3-12****(pre e-line scmt) RUN 2.20" CENT, SLB MEMORY GAUGES AS PER PROGRAM (good data) ATTEMPT TO SET 4 1/2"WHIDDON CATCHER SUB.(thick parrafin at 956' SLM). 5/4/2012 ****CONT JOB ON 5-5-12**** T/I/0=269/528/13 Assist slickline Pumped 5 bbl meth spear followed by 145 bbls 180 deg dsl down tbg for brush and flush rig down (wireline on well has control annulus valves 5/5/2012 open to gauges) FWHP=560/556/248 ****CONT JOB FROM 5-4-12****(pre e-line scmt) LRS PUMP 140 BBLS HOT DIESEL. BRUSH TUBING W/ RIH W/4 1/2" BRUSH, 3.50" GAUGE RING. SET 4 1/2"WHIDDON CATCHER SUB @ 7141' SLM. PULL 4 1/2"WHIDDON CATCHER FROM 7141' SLM. ****WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED******G/L WORK NOT 5/5/2012 COMPLETE DUE TO NORDIC 1 GETTING ON C-12 ** 171/0 137/536/71 Temp= SI Assist[-line (SCMT log, Add perfs) Load tubing with 5 bbls meth, 232 bbls 1% KCL. Pump an additional 348 bbls 1% KCL while E-line logs. Feeze protect tubing with 12 bbls meth, 30 bbls crude. FWHP 200/685/512 SLB on well at 8/4/2012 departure ***WELL SHUT IN ON ARRIVAL*** (SLB E-LINE SCMT LOG) INITIAL T/I/O = 280/520/0 PSI LRS PUMPED 232 BBLS OF 1% KCL FOR LOAD AND KILL UNABLE TO GET DOWN PASSED 9325' LOGGED MAIN PASS FROM 9300'TO 7200' FIELD PICK TOC = 8250' FINAL T/I/O = 600/700/480 PSI 8/4/2012 ***WELL SHUT IN UPON DEPARTURE *** ****WELL S/I ON ARRIVAL****(pre e-line scmt) SET 4 1/2"WCS ON BKR PATCH @ 7171' MD PULL 1-1/2" DOME GLV FROM STA#2 @ 4239' MD PULL 1-1/2" S/O GLV FROM STA# 1 @ 6875' MD SET 1-1/2" DUMMY GLV IN STA#2 @ 4239' MD LRS LOADING CURRENTLY LOADING IA W/CRUDE. 8/22/2012 ***CONT. ON 8/23/12 WSR*** T/I/0=289/839/vac Temp=Sl Assist Slickline Load &test MIT-IA to 3000 psi (Add perfs) Pumped 5 bbl meth spear, 100 bbls diesel, 79 bbls crude ***wsr continued to 08- 8/22/2012 23-12*** T/I/O = SSV/630/vac. Temp = SI. IA FL for Slick Line. No AL. IA FL @ -6300' (500' above sta#1 SO). 8/22/2012 SL in control of valves on departure. NOVP. 12:05 ***wsr continued from 08-22-12*** T/I/0=289/839/vac Temp=Sl Assist Slickline Load &test MIT-IA to 3000 psi PASSED (Add perfs) Pumped an additional 200 bbls crude for a total of 100 bbls diesel &280 bbls crude to load IA. pressured IA up with 7 bbls crude to reach test psi. IA lost 101 psi in 1st 15 min. IA lost 36 psi in 2nd 15 min for a total loss of 137 psi in 30 min test. bled back -6 bbls. Pumped 3 bbls meth to freeze 8/23/2012 protect Flowline to lat valve per pad op. ***wsr continued to 08-23-12*** Daily Report of Well Operations ADL0028305 """CONT. FROM 8/22/12 WSR***(pre e-line scmt) SET RM-DGLV IN STA#2 @ 6880' SLM/6875' MD LRS ATTEMPT MIT-IA TO 3000psi (failed) PULLED 4-1/2"WCS FROM 7154' SLM/7171' MD(empty) SET 4-1/2" LTTP IN PATCH @ 7160' SLM/7171' MD LRS ATTEMPT MIT-T @ 3000psi (failed) PULLED RM-DGLV FROM STA#2 @ 6880' SLM/6875' MD RAN POCKET POKER TO STA#2 @ 6880' SLM/6875' MD SET RM-DGLV IN STA. #1 AT 6,880' SLM/6,875' MD LRS PERFORMED PASSING MIT-IA TO 3000psi (see Irs log) MADE MULTIPLE RUNS TO OBSTRUCTION AT 1,780' SLM (recovered 3 cups of hydrates) ***CONT. WSR ON 8-24-12*** 8/23/2012 ***Wsr continued from 08-23-12*** T/I/0=289/839/vac Temp=SI Assist Slickline Freeze protect, work hydrates (add perfs) Pumped 24 bbls 60/40 meth, 4 bbls crude down tbg to work hydrates. pumped an additional 40 bbls crude down tbg to freeze 8/24/2012 protect tbg. final WHp's 1600/440/0 SSL on well at departure IA/OA= OTG ***CONT. WSR ON 8-23-12*** (pre-adperf) DRIFT TBG W/2.25" CENT, S. BAILER TO 4,000' SLM DRIFT TBG W/4-1/2" BLB, 3.50" G. RING & UNABLE TO PASS 2,567' SLM DRIFT TBG W/3.0" S. BAILER TO 4,000' SLM (recovered hydrates) DRIFT TBG W/4-1/2" BLB, 3.50" G. RING TO 4,000 SLM PULLED 4-1/2" LTTP FROM 7,160' SLM (7,171' MD) LRS FREEZE PROTECTED TBG W/40 BBLS OF CRUDE MADE SEVERAL ATTEMPTS TO PULL 4-1/2" BAKER KB PATCH AT 7,156' SLM (7,171' MD). NO MOVEMENT. 8/24/2012 ***CONT. WSR ON 8-25-12*** ***CON I. WSR FROM 8-24-12*** (pre-adperf) PULLED 4-1/2" KB PATCH FROM 7160' SLM/7171' MD. MISSING 3 ELEMENTS. RAN 3.75" WIRE GRAB & BRUSH TO LTP @ 9352' SLM/9370' MD (recovered 4 small pieces of element) RAN 3.80" DRIFT& BRUSH TO LTP @ 9360' SLM/9370' MD PULLED 4-1/2" LTP FROM 9360' SLM/9370' MD. MISSING 1 ELEMENT. RAN 3.75"WIRE GRAB & BRUSH TO LINER TOP AT 9,386' SLM/9,406' MD (recovered 5 small pieces of rubber element) RAN 2.50" DMY GUN &3.25" LIB TO DEPLOYMENY SLEEVE (good impression) ***WELL LEFT SHUT-IN ON DEPARTURE, PAD OP NOTIFIED*** 8/25/2012 T/1/0 = 850/100/0. Temp=Sl. 1 BG FL (E-Line call-in). No AL. I BG FE© 1850', 30 bbls. 8/31/2012 SLB in control of valves upon departure. ***WELL SHUT IN ON ARRIVAL*** (ELINE: PERF) INITIAL T/I/O = 900/100/0 PERFORATE INTERVAL 9370' -9372'WITH 2.5"2506 POWERJET OMEGA CHARGES. 6 SPF. 60 DEG PHASE. CCL TO TOP SHOT= 6.2'. CCL STOP DEPTH = 9363.8'. FINAL T/I/O = 875/75/0 WELL SHUT IN ON DEPARTURE 8/31/2012 ***JOB COMPLETED ON 31-AUG-2012 *** Daily Report of Well Operations ADL0028305 FLUIDS PUMPED BBLS _ 490 DIESEL 30 METH 24 60/40 METH 580 1% KCL 480 CRUDE 1604 TOTAL Packers and SSV's Attachment ADL0028305 SW Name Type MD ND Depscription C-42A PACKER 8502 8147.13 7" Baker H Packer C-42A PACKER 9400 8761.2 4-1/2" Baker S-3 Perm Packer CL 0gg000 6 ® T- RKS 15 N- CD vtq ¥ Q E 277 � gq Tr CO 03 OD 1.0 03 - 00 Q TrNt@Aup � CDCD@o OD • 4 a # OD 01 o • @o - og10 @ODoTrn03 o OD @ 03 OD a CO up N-100o q n gcynnnn OD COOD8 4.0c & o2upv- % 01 ODTg0gTt 0) mCOno O 2 ul o C npCcio01 01 0 0000 2 9co $ 9c? co -- 0 e - 22 � % $ % q enkCV- - ao U cy _ - Eo a) ® - b RT—r- . q � q & f4 �oini2co00 © cy co CV 2 Oif o cQ 0 & § < o 00otxao � 2 2WWUJQQ ozz2cenD 0 = M 13. U) TRE= 4-1!16"CIW W1LI EAD= 13-5/8"FINC (A SAFE ETES: WELL ANGLE >70°@ 9681' ACTUATOR= BAKER C NT.KB.ELEV= 72.50' BF.ELEV= 35.20' :j I KOP= 6350' Max Angle= 95°@ 10679' - 2197' 41/2"FES HX SSSV NP,H.SD=3.813" Datum MD= 9485' 0 Datum ND= 8800'SS hi-ESGAS LFT MANDR k ST MD ND DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,68#,L-80 NSCC,13=12.415" —{ 3238' 2 4239 4238 0 TGPDX DMY RM 0 08/23/12 L1 6875 6847 25 TGPDX DMY RM 0 08/23/12 TOP OF CMT(LW SQZ 10/02/96) H 8822' •• •v.• 8494' —{9-5/8'X 7'BKR TACK SLV,ID=? ‘• • 4 8502' —9-5/8"X 7"BKR H LNR TIEBACK PKR? Minimum ID =2.377" @ 10366' l;. :.• 3-3116" X 2-7/8" XO .% �� -�s-s/8'x 7"T1w r AcK sLv,D=7.37- • ►� 9-5/8"CSG,47#,L-80 NSCC,ID=8.681" -8814' �• • ►� • i• 9330'-9332' —{TUBING PUNCH(10/02/96) • • ► ■ • !• 9370' 14-1/2"HES X NP,D=3.813" 9390'H..M D ' _.. 9381' 3.70"BKR GEN I DEPLOY SLV,D=3.00" 1(SLB MCNL ON 07112198) X r 9400' 7"X 4-1/2"BKR S-3 PKR ID=3.937" (SLB MCNL ON 07/12/98) L9404' H4-1/2"HES X NP,ID=3.813"(BEHIND LNR) 9425' H4-1/7 HES XN NP,MILLED TO 3.80"(4/20/11) 4-1/2"TBG,12.6#,L-80 BTC-M,.0152 bpf,D=3.958" —{ 9437' 7 \—I 943T —{4-1/2"V11LEG,D=3.958" BEHIND 9458' —I B_MD TT LOGGED 09/19/96 CT LNR 3-1/2"LNR,9.3#,L-80 STL,.0087 bpf,13=2.992" H 9466' TOP OF( 'IT H 9600' I 9433' H 3-1/2"OTIS X NP,ID=2.812" 9466' H3-1/2"X 3-3/16"XO,D=2.786' 7'x 4-1/2"WHPSTOCK(05/10/11) H 9790' •• r•- 7"LNR,2W,L-80 NSCC,.0371 bpf,D=6.184" --I —9790 ►••• ►••• ►••• 0••• R32FORATION Sl1NFN1RY ►••• •• I MLLOUT WINDOW(C-42A) 9796'-9802' ►•• .••• ►•• •• REF LOG: SLB GR/CCL/MCNL ON 05/25/11 11••�•, .• ANGLE AT TOP FUZE: 60°@ 9370' •►•• Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE / 10366' H3-3/16"X 2-7/8"XO,D=2.377" 2.5" 6 9370-9372 0 08/31/12 ✓ 1036T —{MARKER JOM 2" 6 11180-11510 0 05/23/11 z. 2" 6 11670-12100 0 05/23/11 2" 6 12350-12460 0 05/23/11 3-3/16"LN,6.20#,L-80 TCII,.0076 bpf,ID=2.80" H 10366' PBTD(BKR LATCH COLLAR) H 12486' 2-7/8"LNR,6.4#,L-80 STL,.0058 bpf,13=2.441" --I 12524' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UGIT 05/07/93 D-9 INITIAL COMPLETION 09/15/12 KJB/PJC PERF COEfTON(08/31/12) WELL. C-42A 10/06/95 D-16 RWO 09/26/12 PMPJC LNR CORRECTIONS RERMT No:'1110380 05/29/11 NORDIC 1 CTD SIDETRACK(C-42A) AR No: 50-029-22357-01 08/27/12 MSS/JMD GLV GO(08/23/12) SEC 19,T11N,R14E 481'FNL&1220'Fa 08/27/12 MSS/JMD PUL®PATCH&KB LTP(08/25/12) 09/04/12 JCT/JMD ADPBRF(08/31/12) BP Exploration(Alaska) N _ V, cr- 6-- 1 H I H O ca . 0 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0- u U o -r U "v !{1 Z r O , G 1 o °1, CU 5 E. 0 '11 in V1 O C^ () a) N m `CJI/ (/) Z r to = LP (U Ol 03 rn 0.5 I:j, 4N N CV N CV N N N N e- N N N N N N ` Q) .". w T C .0 C) CS) CA j. CA 6) CA CA ` N @ 03 ,--. ,..• 7.,‘ C r i (J CA co 7 7 7 CA N = 7 D 3 04 3 7 = 7 N u1 O CLs (Ti •,,, l7Q2 < ? ? LL < < < 2 < < ai ,,, NIa4 ln u RS CA 10 N N N A- N a- e- CU U X Q t C,. X 0 cc O 0 O J � ".- z aFP 00 0 w aoP a °° CD � =Jam aw J o< aOw 5 O ®. Cl o Fn'' � 0aY ® Yw2p 5 s- ce a CC a f- = a = 0 O w a ri 0 O O p O O O O ® O c) O V O O W R W a. w W U w U w now a. J w UJ a 2 0 2 a 2 2 X 2 X 2 U a cn 2 -J a E, N PD s- ES F- w (,) a obN ii I- `^ N X X X X X X X X X X X X X X X X N Z 0 Q c CI 1- 1— v) a 9 " , P CA I e xt cir, E , ra• en W ® 0 0 0 r® , ®- N — o ® N 0 0 £ ' U 0 O 0 C., ® ® a ® g �? Y N. on ® ,L , I o CD Q ® a 0 h Tt ® 't R co 0 R co co 0 z ao ¢0 <d o 0 ae 0 an O v- an N N➢ ! v co a p a. m m a l OO (D CD CH 0,CO 0 fa U Oa O 2S O CO co tau 0p .0 )r. a.+ tri Nc 1_,...) � y� �.+ Qui 1 co m tv ,n iC7,� tR7 p an 6� id1 c �i c , a. Ca , ¢ w N an 0 0 N COQ Ca 0 c.) ®o < `g ® L 'NJ o v _ ,G n os ® o ® ® asa to to a® c1D <-. CC s Iv N •> "I y y < ® 7 co P r r ® a� ® q`7 C7O N v -1 Cu co 0 O w. Z A ry E Z > 0- 0 do En— 0. P in 0 g U m L 7.3 (7 b 2 N m oCl- w in as• Chi § r1 Q ,><< .. \P _ 1 x CT-U m rn s ter, _ / ...............'. CU m v W r D D N D 8 � � m 1Hm mamD zs ,+, H c. 72- sr • O mART. 00 3 0 1 o 0030 p nomm�00i. vi .�0 W 0 O N C C 9, P m Co o m r- m o N 0 -. Ill WWWWWWWWW ornro b1bbb66 Hw jh. 66o -< " 30 0 0000 c N .0"0000000 ik 0 A V 01 OD'.W z Z rrrrrrrrr z c0i c0i c0i c0i c0i c0i c0i c0i c0i 0 m m m m m m m m m 000000000 m cc 0m00000000 mmmmmmm G) Z-l2-I'Izz z O r r rrr r z mo 0 0 0 m m c 0 O i O N w N N-.w A Y C o m C m 9 v O m CO r >N.) 0 Z N v? U• ry F a mE3N O ' N r 3m (IDT Q 0 ° N 0 m °, NN 2 !".Z.0). 0=' C ID V N Wm (nE 5:1900 Nica D W N X>0 m m N 00) 0 ,. 2E 00 FI 7 N f/1 4-1 n O 0 3 3 N N A / i. N O c4W Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L[Terrie.Hubble@bp.com] Sent: Tuesday, July 05, 2011 12:18 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU C-42A/PTD#211-038 Hi Art, Please reference the following well: Well Name: PBU C-42A Permit#: 211-038 API #: 50-029-22357-01-00 Top Perf MD: 11180' Bottom Perf MD: 12460' This well began Production on June 25, 2011 Method of Operations is: Flowing Date of Test: 06/25/11 Hours Tested: 8 24-Hour Rate/Oil-Bbl: 989 24-Hour Rate/Gas-Mcf: 10,739 24-Hour Rate/Water-Bbl: 70 Test Rate/Oil-Bbl: 330 Test Rate/Gas-Mcf: 3,580 Test Rate/Water-Bbl: 23 Choke Size: 176 Gas-Oil Ration: 10,857 Flow Tubing Pressure: 1,600 Casing Pressure: 1,100 Oil Gravity-API: Not Available 1 Letter of Transmittal r& u BAKER Date: July 1, 2011 HUGHES To: From: State of Alaska AOGCC Baker Hughes INTEQ 333 W. 7th Ave., Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Bill Michaelson Please find enclosed the directional survey data for the following well(s): C-42A 2W O3' E-23CPB1 E-23CPB2 E-23C ., E-19C 02-21B �� 15-48CU�. ® ,• 15-O5BPBI 15-05B ,�� sl4°) Enclosed for each well(s): 1/%0 2 hardcopy prints of directional survey reports 1 compact disk containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: 1 O , State of Alaska AOGCC DATE: STATE OF ALASKA ALASKA. .AND GAS CONSERVATION COMMISSIC. REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other Q TUBING PATCH Performed: Alter Casing ❑ Pull Tubing❑ Perforate New Pool ❑ Waivers Time Extension ❑ 7171'/7206' Change Approved Program ❑ Operat.Shutdown❑ Perforate ❑ Re-enter Suspended Well ❑ 2.Operator BP Exploration(Alaska),Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development IS Exploratory ❑ — 211-038 3.Address: P.O.Box 196612 Stratigraphic Service ❑ 6.API Number: Anchorage,AK 99519-6612 - 50-029-22357-01-00 8.Property Designation(Lease Number): _ 9.Well Name and Number: ADLO-028305 .. PBU C-42A 10.Field/Pool(s): PRUDHOE BAY FIELD/PRUDHOE OIL POOL 11.Present Well Condition Summary: Total Depth measured 12552 feet Plugs(measured) None feet true vertical 9014 feet Junk(measured) None feet • Effective Depth measured 12486 feet Packer(measured) 7171,7206 8502,8551 9380,9383 feet true vertical 9015 feet (true vertical) 7106 7135 8220,8261 8824,8826 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 20" Surface - 112 Surface - 112 1490 470 Surface 13-3/8" 35 - 3238 35 - 3237 5020 2260 Production 9-5/8" 33 - 8814 36 - 8468 6870 4760 Liner 7" 8545 - 9802 8256 - 8985 8160 7020 Liner 3-1/2" 9406 - 9467 8837 - 8864 10160 10530 Liner 3-3/16" 9467 - 10367 8864 - 9038 Liner 2-7/8" 10367 - 12524 9038 - 9015 Perforation depth: Measured depth: SEE ATTACHED- _ _ _ _ True Vertical depth: _ - _ - - Tubing:(size,grade,measured and true vertical depth) 4-1/2"12.6# L-80 32-9437 32-8851 Packers and SSSV(type,measured and true vertical depth) Two 4.5 KB BKR Patch 7171.7206 7106.7135 7"BKR H&7"TIW Packer 8502,8551 8220.8261 4-12"BKR S-3 Packer&4.5 KB Lnr Top Pkr \Mel 8824,8826 12.Stimulation or cement squeeze summary: �N '•7p A �nl' Intervals treated(measured): Treatment descriptions including volumes used and final pressure: Aio 1 i f�rl�Gci .C,iinn fission AnneCdge 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI SI SI 0 Subsequent to operation: 1003 11166 73 211 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory Development 2 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL 0 GSTOR ❑ WINJ 0 WAGS GINJ 0 SUSPE 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: NA Contact Elizabeth Barker Printed Name Elizabeth Barker Title Data Manager Signature f �� 4A,A� Phone (907)564-5674 Date 6/30/2011 Form 10-404 Revised 10/2010 RBDMS JUN 3 0 Submit Original Only ■ co.2 $ as in csi woo0 £ 0) ■ co CL / O.A22 o co = 0 0 0.a) ■ ■ 0 $ 2 > S & \ > . . 0 A - 0CD 99 � 29r � iuu � QU 2 ± m < 0. ƒ £ 3 O O L L w 2 ■ Li. —u N N c c 0 LLEwc0IW < O ■ 0 0. Q z z 2 D 1—m ƒw LU cn cf) \ w c0 � � co = w _ cal <▪ a o. tNI <0 a.2 C � / / / / � / % O 2 o0L > 0 tr. ƒ 0 0 LULU ( www � ¥ � � a a a a < _ / 2 2 O q w q q z < < < L c , , , L in in L � 0_ < gg@ � o / EwWj < < < I co ƒ 0 / / / 3 0 3 0 3 e = O R E g g & L u EL o < < _ = L i 2 2 2 0 2 3000 $ \ c3c3 \� kk / 0 C-42A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/11/2011 ELINE PATCH SET INITIAL T/I/O = 0/0/0 PSI SPOT EQUIPMENT, MEET WITH DSO, PJSM WITH BAKER *******JOB CONTINUED ON FOLLOWING DAY******* 6/12/2011 (ELINE PATCH SET) SET BAKER 4.5" PATCH OVER KNOWN LEAK AT 7182' SET UPPER SEALING ELEMENT AT 7172'AND BOTTOM SEALING ELEMENT AT 7202', TOP OF PATCH AT 7171' . PATCH HAS A 4" GS FISHING NECK UP AND WLEG DOWN AND WEIGHS APPROX 450 LBS OD OF PATCH = 3.7", MINNIMUM ID THRU PATCH = 2.45", OAL = 35.87' FINAL T/I/O = 0/0/0 PSI *******JOB COMPLETE AND TURNED OVER TO DSO*******(WELL LEFT SHUT- IN UPON DEPARTURE) FLUIDS PUMPED BBLS 3 DIESEL 3 TOTAL TREE= 4-1/16"CW ACTUATOR 13 BAKER C PJC /"+ P1 /l �� C-42A SAFETY NOTA_ . WELL ANGLE >70°@ 9681' KB.ELEV = 72.50' I�aJ ti✓ IJ /`1 BF.ELEV = 35.20' KOP=_ 6350' 2197' —14-1/2"HES HXO SSSV NIP, ID=3.813" Max Angle= 95"@ 10679' Datum MD= 9485' hHESGAS LIFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 113-3/8"CSG,__684, L-80, ID=12,4,15" H., 3238' 2 4239 4238 0 TGPDX DOME RA 16 06/14/11 M. 1 6875 6847 25 TGPDX SO RA 20 06/14/11 L___ BAKER 45 KB PATCH,ID=2.45"(06/12/11) --1 7171' -7206' L i c ii TOP OF CMT( LNR SQZ 10/02/96) 882 ' _-'` • —19-5/8" 0 j�j ��e 8494' X T BKR TIEBACK SLV, ID=? Minimum ID = 2.36" @ 9383 -I,4, .4 8502' —19-5/8"X 7"BKR H LNR TIEBACK PKR re: ♦ 8545' —I9-5/8"X 7"TIW TIEBACK SLV,ID=7.37" 45 KB LINER TOP PACKER 0• �� • 8551' --19-5/8"X 7"TIW PKR/HGR,ID=6.18" 4' .4 9-5/8"CSG,47#,L-80, ID=8.681" -1 8814' •-. j •i • .� ►• 9370' —14-1/2"HES X NIP,ID=3.813" 4 • •• • A • 9380' —17"X 4-1/2"BKR S-3 PKR, ID=3.937" 9383' —145 KB LNR TOP PKR, ID=2.36" 1 9404' H4-1/2"HES X NIP,ID=3.813"(BEHIND LNR) 9406' —13.70"BKR GEN II DEPLOY SLV, ID=3.00" 9425' —4-1/2"HES XN NIP,MIILLED TO 3.80"(4/20/11) 4-1/2"TBG, 12.64,L-80 BTC-M. .0152 bpf, ID=3.958" — 9437' I--- \— I 9437' —14-1/2"WLEG,ID=3.958" BEHIND 9458' H ELMD TT LOGGED 09/19/96 CT LNR 3-1/2"LNR,9.3#,L-80 STL, .0087 bpf, ID=2.992" H 9466' 9433' —13-1/2"OTIS X NIP, ID=2.812" TOP OF CEMENT —I 9600' 9466' —I 3-1/2"X 3-3/16"XO, ID=2.786" 7"x 4-1/2"WHIPSTOCK(05/10/11) — 9790' 7"LNR,29#, NT-80, .0371 bpf, ID=6.184" --I —9790 ► P! ►S! ♦♦ ►�•�• ►•�• PERFORATION SUMMARY C.**! jj. MILLOUT WINDOW(C-42A) 9796'-9802' REF LOG: SLB LEE TNN/TNF/GR/CCL ON 05/25/11? ►••4 �• ANGLE AT TOP PERF: 88°@ 11180' ►•" fr Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11180- 11510 0 05/23/11 2" 6 11670- 12100 0 05/23/11 10366' —I3-3/16"X 2-7/8"XO,ID=2.377" 2" 6 12350- 12460 0 05/23/11 3-3/16"LNR,6.20#, L-80 TCII,.0076 bpf,ID=2.80" — 10366' ' PBTD(BKR LATCH COLLAR) —I 12486' ' 2-7/8"LNR,6.44, L-80 STL, .0058 bpf, ID=2.441" IH 12524' )� DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/07/93 D-9 ORIGINAL COMPLETION WELL: C-42A 10/06/95 D-16 RWO PERMIT No: 1110380 04/29/11 NORDIC 1 CTD SIDETRACK(C-42A) AR No: 50-029-22357-01 05/30/11 PJC DRLG DRAFT CORRECTIONS SEC 19,T11N,R14E,481'FNL&1220'FEL 06/15/11 SRD/PJC SET PATCH(6/12/11) 06/26/11 ALH/PJC GLV C/O(6/14/11) BP Exploration(Alaska) 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ® Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One 0 Service 0 Stratigraphic 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska)Inc. 5/28/2011 211-038 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 5/12/2011 _ a 50-029-22357-01-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 5/21/2011 - PBU C-42A 481'FNL, 1220'FEL, SEC. 19,T11 N, R14E, UM 8. KB(ft above MSL): 72.5' 15.Field/Pool(s): Top of Productive Horizon: 4353'FNL,4910'FEL, SEC. 17,T11 N, R14E, UM GL(ft above MSL): 35.2' Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD): Oil Pool 3055'FNL,3621'FEL, SEC. 17,T11 N, R14E, UM 12486' 9015' -. 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 664137 y- 5960733 Zone- ASP4 12552' 9014' ADL 028305 TPI: x- 665690 y- 5962175 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 666947 y- 5963502 Zone- ASP4 None 18.Directional Survey: ® Yes 0 No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD DIR, GR, RES, GR/CCL/MCNL 9796' 8983' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT.PER FT. GRADE Top BOTTOM ToP I BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 112' .Surface 112' 30" 281 cu ft Arcticset 13-3/8" 68# L-80 35' 3238' 35' 3237' 16" 2313 cu ft Permafrost'E'.489 cu ft Class'G' 9-5/8" 47# L-80 36' 8814' 36' 8468' 12-1/4" 421 cu ft Class'G' 7" 29# L-80 8545' 9796' 8256' 8983' 8-1/2" 421 cu ft Class'G' 3-1/2"x 3-3/16" 9.3#/6.2# _ L-80 9406' 12524' 8837' 9015' 4-1/4" 185 cu ft Class'G' x 2-7/8" /6.4# 24. Open to production or injection? ®Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) (MD+TVD of Top&Bottom;Perforation Size and Number): 2"Gun Diameter,6 spf 4-1/2", 12.6#, L-80 9437' 9380'/8824' " MD ND MD TVD 11180'-11510' 9026'-9025' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 11670'-12100' 9021'-9023' 12350'-12460' 9019'-9016' + 7�L7dt3..zo,: ,.>. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 2500' Freeze Protected w/60 Bbls of Diesel , ,44-,. i .1"1-1rED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,Gas Lift,etc.): Not on Production Yet N/A Date of Test: Hours Tested: Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and p ence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and labora •2 ,sults per 20 AAC 250.071. Nonep 1�� c 4 '1ilk .. RBDMS JUN 27 ZQ - ��` • $r,�m�sOn Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ��; WI gt Submit Original Only ,-,- '�� 6 o&/l9/2o// 29.,GEOLOGIC MARKERS(List all formations and mar' icountered): 30. AATION TESTS NAME MD ND Well Tested? 0 Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Zone 1B 9795' 8983' None TDF/Zone 1A 9912' 9025' TDF/Zone 1A(invert) 12202' 9021' Formation at Total Depth(Name): TDF/Zone 1A(from base) 12202' 9021' 31.List of Attachments: Summary of Daily Drilling Reports,Well Schematic Diagram,Surveys 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Terre Hubble � � 1.4 Title: Drilling Technologist Date: 61 ((1 PBU C-42A 211-038 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No./Approval No. Drilling Engineer: Jacob Leemhuis, 564-4989 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 MC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 MC 25.071. Form 10-407 Revised 12/2009 Submit Original Only c North America -ALASKA- BP Page 1 of 23 Operation Summary Report Common Well Name:C-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project:Prudhoe Bay Site: PB C Pad Rig Name/No.:NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To j Hrs Task Code NPT NPT Depth Phase Description of Operations �_—(hr) (ft) 5/7/2011 06:30 - 07:00 0.50 RIGD P PRE PJSM TO PUMP METHANOL THRU HARDLINE TO FLOWBACK TANK AND OOA BLEED TANK. 07:00 - 10:30 3.50 RIGD P PRE PUMP METHANOL THRU HARDLINE TO FLOWBACK TANK AND OOA BLEED TANK. BLOWDOWN WITH AIR. RD HARDLINE TO FLOWBACK TANK AND OOA BLEED TANK. 10:30 - 11:00 0.50 RIGD P ` PRE PJSM TO JACK UP RIG AND MOVE OFF WELL. 11:00 - 12:00 1.00 RIGD P PRE JACK UP RIG AND MOVE OFF WELL 20'AND l - SET DOWN. 12:00 - 12:30 0.50 RIGD P PRE PJSM TO INSTALL SCOPING RAM IN DERRICK. 12:30 - 19:30 7.00 RIGD P PRE INSTALL SCOPING RAM IN DERRICK. 19:30 - 20:30 1.00 RIGD P PRE ROUTE INSPECTION FROM 06-02A TO C-42A. 20:30 - 21:00 0.50 RIGD P PRE PJSM WITH SECURITY TO MOVE RIG. 21:00 - 00:00 3.00 MOB P PRE JACK RIG UP TURN AROUND AND DRIVE TO C-PAD. 5/8/2011 00:00 - 07:00 7.00 RIGD N RREP PRE DRILLERS SIDE OUTSIDE REAR TIRE BLEW A BEAD. CHANGING TIRE ON THE SPINE ROAD BETWEEN OXBOW TURN OFF AND PUMP STATION 1. 07:00 - 07:30 0.50 RIGD N RREP PRE CREW CHANGE OUT AND PJSM. 07:30 - 08:30 1.00 RIGD PRE FINISH CHANGING TIRE AND JACK UP RIG. 08:30 - 12:30 4.00 MOB N RREP PRE MOVE RIG TO C-42A. 12:30 - 13:00 0.50 MOB P PRE I PJSM TO BACK RIG OVER C-42A. 13:00 - 13:30 0.50 MOB P PRE BACK RIG OVER WELL. 13:30 - 18:00 4.50 MOB P �. PRE ACCEPT RIG AT 13:30. SPOT CUTTINGS BOX,WELDING SHOP, SATELITE OFFICE AND FUEL TRAILER. 18:00 - 18:30 0.50 BOPSUR P PRE PJSM TO REMOVE TREE CAP AND NU BOP'S. BOP TEST WITNESS WAIVED BY LOU ! GRIMALDI WITH AOGCC.- - 18:30 - 00:00 5.50 BOPSUR P PRE JACK UP AND LEVEL RIG.REMOVE TREE CAP AND NU BOP'S. 5/9/2011 00:00 - 01:00 1.00 BOPSUR P PRE RU TO TEST ROPE. i 01:00 - 11:45 10.75 BOPSUR P j PRE TEST BOPE. CHECKED TORQUE ON TREE BOLTS. 250PS1 LOW/3500 PSI HIGH,ANNULAR 2500PSI. • ALSO SUCCESSFULLY TESTED SWAB, MASTER,AND SSV TO 3500 PSI. 11:45 - 13:00 1.25 BOPSUR P PRE PJSM. REVIEW SOP: CTD PULLING AND SETTING BPV AND TWC ANC ONPARE FOR CONSISTANCY WITH VALVE CREW WRITTEN PROCEDURE AND NORDIC PROCEDURE. BRING VALVE CREW LUBRICATOR TO RIG FLOOR. 113:00 - 13:45 0.75 BOPSUR P I PRE PRESSURE TEST LUBRICATOR TO 250 PSI LOW,3500 PSI HIGH. LUBRICATE OUT BPV. Printed 6/6/2011 1:36:54PM North America-ALASKA- BP Page 2 of 23 Operation Summary Report Common Well Name: C-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay ' Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor: NORDIC CALISTA UWI: I. Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:45 - 15:00 1.25 BOPSUR P PRE SECURE WELL WITH SWAB AND MASTER. RIG DOWN LUBRICATOR. INSTALL NIGHT CAP. ,15:00 - 15:30 0.50 KILLW P WEXIT H2S DRILL-EVACUATE RIG-ALL PERSONELL ACCOUNTED FOR. 15:30 - 16:15 0.75 KILLW P WEXIT PRESSURE TEST NIGHT CAP. PREPARE TO OPEN UP AND FILL WELL. 16:15 - 19:45 3.50 KILLW P WEXIT OPEN UP WELL AND NO PRESSURE OR FLOW NOTED AT SURFACE. FILL THROUGH KILL LINE AND RETURNS NOTED AT 75 BBLS • AWAY. SHUT DOWN PUMP FOR 20 MINUTES AND FILL HOLE AGAIN. PUMPED 80 BBLS IN 45 MINUTES BEFORE WE CAUGHT FLUID. CALL DRILLING SUPERINTENDENT AND ODE AND DISCUSS PLAN FORWARD BEGIN MIXING HIGH VIS PILL. 19:45 - 21:00 1.25 KILLW P WEXIT PUMP 37BBL HI VIS PILL AND SPOT ACROSS I PERFS. PUMPED 7BBLS INTO PERFS AND SAW PRESSURE CLIMB TO 50 PSI. 21:00 - 22:00 1.00 KILLW P WEXIT FILLING HOLE ACROSS TOP WITH 96 BPH I LOSSES AFTER FIRST 10 MINUTES.. 1 j BUILDING ANOTHER 37 BBL HI VIS PILL. i LOSSES DROPPED OFF TO 45 BPH AFTER 40 MINUTES. CALLED SUPERINTENDANT AND TOWN � I ENGINEER. DECISION MADE TO CONTINUE WITH WELL PLAN. _ 22:00 - 22:50 0.83 KILLW P WEXIT FILL PITS WITH 300 BLLS OF 2%KCL. 22:50 - 23:30 0.67 KILLW P 1 WEXIT RIG EVACUATION,H2S AND MANDOWN DRILL. _ GOOD AAR.TWO KCL TRUCK DRIVERS WERE NOT ON OUR 189 HARMONY HUB SO WE HAD TO GO GET THEM.THE BULK FUEL TRUCK DRIVER SHERMAN SHUT DOWN HIS PUMP,SUCKED BACK HIS LINE AND SHUT I I OFF HIS TRUCK.THE RESPONSE TIME WAS __ GREAT AT 3 MINUTES AND 50 SECONDS. _ 23:30 - 23:45 0.25 KILLW P j WEXIT PJSM TO PUMP SLACK FORWARD. 23:45 - 00:00 I 0.25 KILLW P I WEXIT SHUT IN WELL AND PUMP 35 BELS FROM COIL TO CUTTINGS BOX TO GET TO CLEAN KCL. ' WELL SHUT IN FOR 15 MINUTES AND IT TOOK 8 BBLS TO FILL WELL. PT FILTER HOUSINGS 300 PSV 3500 PSI PVT 208 BBLS. 5/10/2011 00:00 - 02:00 2.00 KILLW P WEXIT STAND INJECTOR BACK TO PERFORM SLACK MANAGEMENT. MEG AND CONTINUITY TEST E-LINE. PUMP ALL SLACK BACK INTO REEL. CUT COIL BACK 288'TO FIND E-LINE. 02:00 - 03:00 1.00 KILLW P WEXIT CUT 295'COIL TOTAL. MEG TEST E-LINE AGAIN. PULL TEST TO 35K. 103:00 - 04:10 1.17 KILLW P t( WEXIT HEAD UP BAKER CTC. PT TO 3500 PSI. 04:10 - 06:30 2.33 KILLW ' P 1 I WEXIT PT INNER.REEL VALVE AND PACK OFF. 06:30 - 07:30 1.00 STWHIP I P WEXIT MU AND RIH WITH BAKER WHIPSTOCK. Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 3 of 23 Operation Summary Report Common Well Name: C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor: NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 08:15 ' 0.75 STWHIP P WEXIT MU INJECTOR HEAD AND BRING PUMP ONLINE PUMPING THROUGH COIL. STAGE UP TO 2 BPM 1200 PSI FILLING HOLE. 10 BBLS TO FILL HOLE. ESTABLISH LOSS RATE OF-50 BPH. 08:15 - 08:45 0.50 STWHIP P T WEXIT RIH W/WHIPSTOCK ASSEMBLY TO 3719'MD. 85 FPM. PUMPING 1 BPM DOWN COIL. LOSS RATE -45 BPH. 08:45 - 09:00 0.25 STWHIP P WEXIT PERFORM WELL CONTROL DRILL-KICK WHILE TRIPPING. 09:00 - 10:00 1.00 STWHIP P ..I WEXIT CONTINUE RIH W/WHIPSTOCK BHA FROM 3719'TO 8940'CTMD. 10:00 - 11:10 1.17 STWHIP P WEXIT TIE IN LOG FROM 8940'TO 9891.7 AT 1.0 FPM PUMPING 1.1 BPM AT 400 PSI. • LOSS RATE 35 BPH. CORRECT DEPTH-4FT. 11:10 11:35 0.42 1 STWHIP P WEXIT RIH FOR CCL LOG 11:35 - 11:45 0.17 1 STWHIP P WEXIT CCL FROM 9960'TO 9700'1200 FPM 11:45 - 13:00 1.25 STWHIP P WEXIT WO WSL CHANGE OUT 13:00 - 13:45 0.75 STWHIP ' P WEXIT TIE IN LOG WITH NO CORRECTION 13:45 - 14:15 0.50 STWHIP P WEXIT RELOG CCL AT 600 FPM, FIRST CCL IS SHOWING 30'JOINTS COMPARED TO 40+ FOOT JOINTS ON LOG IN THE WELL PLAN 14:15 - 15:10 0.92 1 STWHIP P ' WEXIT 2ND LOG IS SHOWING SHORTER JOINTS THAN THE FIRST CCL RELOG AGAIN START ANOTHER 34 BBL HI-VIS PILL DOWN THE COIL 15:10 - 15:30 0.33 STWHIP P WEXIT RIH TO 9960'TO RELOG CCL 15:30 - 15:45 0.25 STWHIP P WEXIT CCL NOT WORKING,TROUBLESHOOT MWD CCL 15:45 - 16:00 0.25 STWHIP P ' WEXIT CLOSE IN CHOKE AND BH HI VIS PILL TO LINER 16:00 - 17:00 1.00 STWHIP P WEXIT BUMP IN WHP AT 22 BBLS OUT,OPEN CHOKE AND LAY IN THE REMAINDER OF THE PILL WELL STILL TAKING FLUID,SHUT DOWN PUMP AND CLOSE CHOKE TO ALLOW PILL TO GAIN GEL STENGTH 16:30 BHI CANNOT GET CCL TO WORK 117:00 - 17:15 0.25 STWHIP P WEXIT SHUT DOWN FOR 1 HR,OPEN CHOKE AND COME ONLINE 17:15 - 19:35 2.33 STWHIP P 1 WEXIT WELL TOOK 11 BBLS,POOH HOLDING 50-100 PSI WHP WHILE POOH WITH WS. PVT=318 19:35 - 20:00 0.42 STWHIP P L WEXIT FLOW CHECK AND PJSM FOR BHA SWAP. 20:00 - 21:00 1.00 STWHIP P WEXIT POP INJECTOR OFF WELL AND LD LQC,SUB WEAR PROTECTION AND POWERCOMMS. PU DIFFERENT TESTED LQC,SUB WEAR PROTECTION AND POWERCOMMS. SLB INSTALLING CDPID. 21:00 23:00 2.00 STWHIP P WEXIT STAB INJECTOR ON WELL. TEST COILTRAK. RIH W/WS BHA#2 75FPM. PUMPING 0.39 BPM IN MW 0.54 BPM OUT AT 88 PSI. TEST COILTRAK AT 2000'. Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 4 of 23 Operation Summary Report Common Well Name: C-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 STWHIP P WEXIT GR TIE IN.CORRECTION MINUS 4' LOGGING CCL FROM 9960 TO TBG TAIL. 1150 FPH 5/11/2011 00:00 - 00:35 0.58 STWHIP P WEXIT LOGGING CCL FROM 9960 TO TBG TAIL AT 1150 FPH. PUMPING 0.4 BPM. LOSSES 13BPH. 00:35 - 01:00 0.42 STWHIP P WEXITLOOKING AT LOGS WITH GEO. CALLED TOWN ODE TO DISCUSS SECOND CCL TOOL NOT READING IN 7". WE DO NOT HAVE ENOUGH DATA TO CONFORTABLLY SETA WHIPSTOCK BETWEEN COLLARS. DECIDED TO HAVE GEO AL OCHES RUN OVER TO PBOC AND SEARCH FOR COLLAR LOGS AND OR CASING TALLY ON 7 INCH. 01:00 - 02:00 1.00 STWHIP P WEXIT WAITING ON LOGS AND CASING TALLY/LINER RUN FOR 7"FROM PBOC. PVT 282 BBL. 02:00 - 03:00 1.00 STWHIP P WEXIT LOOK A SEVERAL DIFERENT CCL LOGS ALL OF WHICH SHOWED A COLLAR AT 9700'+/-1'. SEVERAL COLLARS BELOW 9700'DO NOT SHOW UP ON ANY OF THE LOGS. COMPARED GR FROM THESE LOGS AND THE BAKER INTEQ AND PDC LOG AND THEY MATCH.WITH THE 7"CASING TALLY/LINER RUN COLLAR DEPTHS WERE CALCULATED FROM BOTTOM UP AND THE COLLAR AT 9701'ON THE LOG CALCULATED AT 9701'. 03:00 - 03:30 0.50 STWHIP P WEXIT ORIENT THE WS 180 ROHS FOR LOWSIDE EXIT AND SET TOP OF WS AT 9790'. RIH WT 22K,UP WT 42K. PU TO NEUTRAL WT 32K PUMPING AT.25 BPM, SHEARED THE WS AT 3200 PSI. THE TOP OF WS WAS SET 9'BELOW THE COLLAR PER WELLPLAN AT 9790'. 16 BPH LOSSES OVER LAST 3.5 HOURS.PVT 224 BBL. 03:30 - 05:30 2.00 STWHIP P WEXIT POOH 80 FPM WITH WS SETTING BHA#2. PUMPING 1.66 BPM IN MM/.64 BPM OUT MM HOLDING 110 PSI WELLHEAD PRESSURE. 05:30 - 05:45 0.25 STWHIP P WEXIT FLOW CHECK WELL.ON A VACUUM. PJSM TO LD WS SETTING BHA AND PICK UP CMT NOZZLE BHA. 05:45 - 07:00 : 1.25 STWHIP P WEXIT STANDBACK INJECTOR AND LD WS SETTING I ( BHA. _ I _ 06:30 SLB CMT CREW ON LOCATION 07:00 - 08:00 1.00 STWHIP I P 1 WEXIT PU INJECTOR AND REMOVE BHI CHECKS MU CMT NOZZLE BHA W/1 JT OF 2-3/8"PH6 08:00 - 10:00 2.00 STWHIP P WEXIT RIH 10:00 10:15 : 0.25 STWHIP P WEXIT 9760'WT CK 37.5k,RIHWT 21.5k TAG AT 9788.9', PU AND RETAG TO CONFIRM AND TAGGED AT 9802' TAGGED AT SAME DEPTH,CORRECT DEPTH TO 9790',PU 10'AND PAINT FLAG Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 5 of 23 Operation Summary Report Common Well Name:C-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/7/2011 I End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To l Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) 1 , (ft) 10:15 - 10:30 ! 0.25 1 STWHIP P WEXIT WE ARE STILL WAITING FORA DIRTY TRUCK TIED UP AT PAD 3 ESTABLISH LOSS RATE WHILE TAKING RETURNS 1 BPM IN AND 0.7 BPM OUT= 14 BPH 2.5 BPM IN AND 2.16 OUT=20.5 BPH 10:30 - 11:15 0.75 STWHIP P j WEXIT OFF LOAD 100 BBLS OF USED KCL FOR REMAINDER OF NEW KCL ON A TRUCK TO MAKE HIM MY DIRTY VAC I NEED 11:15 - 11:30 ' 0.25 1 STWHIP P WEXIT OFF LOAD NEW KCL TO PITS AND FREEZE PROTECT TT LINE 11:30 - 11:40 0.17 STWHIP P , WEXIT CLOSE CHOKE FOR INJECTION RATE AND PRESSURE AT 1 BPM,230 PSI INJECTION I PRESSURE AT 1 BPM 11:40 - 12:15 0.58 STWHIP P WEXIT PJSM TO PUMP CMT 12:15 - 12:50 0.58 STWHIP P WEXIT PRIME CMT PUMP 12:50 - 14:22 1.53 STWHIP P WEXIT START CMT OPS -PUMP 5 BBLS OF KCL -SHUT DOWN PUMP TO PT CMT LINE TO 250 AND 4000 PSI -BATCH UP TUB AND PULL SAMPLE 13:07 CMT TO WT AT -13:07 ONLINE WITH CMT DOWN COIL H 13:08 ZERO IN MM AT 13.5 PPG I-13:10 RIG MM—0.20 LOWER ON DENSITY -13:16 INCREASE RATE TO 2.5 BPM -13:22 20 BBLS AWAY IN/OUT RATES=2.47/ 2.10 13:29 40 BBLS AWAY,SHUT DOWN PUMP AND BACK FLUSH CMT LINE -13:33 ONLINE WITH THE RIG PUMP TRYING TO CATCH THE CMT -13:37 50 BBLS AWAY SHUT IN CHOKE AND REDUCE RATE TO 2.0 BPM WHP @ 410 PSI -13:40 55 BBLS AWAY SWAP TO BIOZAN IAP= 1240 PSI -13:41 57 BBLS AWAY INCREASE RATE UNTIL WE SEE A AHANGE IN WHP i-13:46 65 BBLS AWAY CMT AT TOP OF 4.5" ' LINER I-13:48 68 BBLS AWAY IA AND WHP TO RISING, RATE TO 1.0 BPM WHP@ 510 PSI INJ BASE -13:49 70 BBLS AWAY CMT AT TO SLOT IN LINER -13:52 72 BBLS AWAY WHP CLIMBING @ 600 PSI -13:54 75 BBLS AWAY WHP @ 660 PSI -13:59 80 BBLS AWAY WHP @ 740 PSI -14:01 82.5 BBLS BUMP IN WHP TO 940 PSI -14:02 84.0 BBLS OPEN CHOKE -14:04 2 BBLS BACK START PU HOLE I -14:08 5 BBLS BACK -14:18 98.5 BBLS AWAY CMT OUT,9 BBLS BACK TOC @ 9537' LOST 5.5 BBLS WHILE i LAYING IN 14:22 I 15:00 0.63 STWHIP P � WEXIT PULLED TO 9100'BRING WHP BACK UP TO � �, 750 PSI 1 I -14:23 WHP BLEEDING OFF CALL ODE Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 6 of 23 • • Operation Summary Report Common Well Name: C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00©72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase ' Description of Operations (hr) (ft) 15:00 - 15:15 0.25 STWHIP P WEXIT WHP BLED DOWN TO 220 PSI,DISCUSSION WITH TOWN ODE'S IS TO TRY TO ESTABLISH 'SQUEEZE PRESSURE, IN MM @ 102 BBLS -15:10 WHP @ 1000 PSI AFTER PUMPING 1.1 BBLS AND STARTING TO FLAT LINE,SHUT DOWN PUMP AND WHP SLOWLY BLEEDING OFF.CALL ODE'S AND DISCUSS CALLING • THIS GOOD AND CLEAN OUT TO 10'FROM THE TOWS 15:15 - 15:40 0.42 STWHIP P WEXIT 700 PSI SQUEEZE IS GOOD,SLOWLY BLEED OFF WHP TO 500 PSI AND START CLEAN OUT,WHEN RATE IS INCREASED TO 3+BPM REDUCE WHP TO 300 PSI BIOZAN 10 BBLS FROM NOZZLE, RIH FROM 9100' 15:40 - 17:00 I 1.33 STWHIP P WEXIT 9780'AT 3.15 BPM WHP @ 290 PSI, RETURNS ARE 1:1 PUH CHASING CMT 15:50 9400'RIH FOR 2ND PASS 16:05 9780'3.0 BPM 1:1 RETURNS WITH 300 PSI WHP 106 BBLS BACK WE HAVE CMT IN OUR RETURNS 17:00 - 19:15 2.25 STWHIP P WEXIT WELL IS CLEAN POOH 19:15 - 19:30 0.25 STWHIP P WEXIT PJSM TO STANDBACK INJECTOR, LD CMT BHA AND PU NOZZLE TO JET STACK. I � FLOW CHECK,STATIC. 19:30 - 20:00 0.50 I STWHIP P WEXIT STAND BACK INJECTOR. LD CMT BHA AND PU NOZZLE TO JET STACK. 20:00 - 20:30 0.50 ' STWHIP P WEXIT JET STACK 2 BPM. PVT 282 BBLS 20:30 - 21:20 0.83 STWHIP P WEXIT PUMP SLACK MANAGEMENT WITH 25 BBLS FRESH WATER. 21:20 - 23:00 1.67 STWHIP P WEXIT STAND INJECTOR BACK. MEG AND CONTINUITY TEST, CHECKS GOOD. FUNCTION RAMS AND LOOK THEM OVER FOR CEMNENT,THEY ARE CLEAN. 23:00 - 23:50 0.83 STWHIP P WEXIT MU WINDOW MILLING BHA. WINDOW MILL GAUGE RING 3.79"NOGO AND 3.80"GO. STRING REAMER GAUGE RING 3.78"NOGO • AND 3.79"GO. STAB INJECTOR ONTO WELL. 23:50 - 00:00 0.17 STWHIP P WEXIT IH. PVT 205. 5/12/2011 00:00 - 00:05 0.08 STWHIP P WEXIT RIH.PVT 205. ONLY RAN INTO HOLE 500'WHEN ELINE PULLED OUT OF HEAD. 00:05 - 01:00 0.92 STWHIP P • WEXIT POOH BHA#4,STAND INJECTOR BACK. FIX ELINE THAT PULLED OUT OF HEAD. 01:00 - 01:25 0.42 STWHIP P WEXIT PUMP SLACK FORWARD AGAIN WITH 25 BBLS FRESH WATER. HOLE IS STATIC. 01:25 - 03:00 1.58 STWHIP P WEXIT RIH WITH BHA#5(SAME AS BHA#4)94 FPM PUMPING 1.0 BPM IN MM/1.53 BPM OUT AT 550 PSI. 03:00 - 03:30 0.50 STWHIP P WEXIT GR TIE FROM 9000'TO 9031'. CORRECTION-2.5'. 03:30 - 03:45 0.25 STWHIP P WEXIT CLOSE EDC AND RIH TO TOWS. DRY TAG WS PINCH POINT AT 9,792.8' Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 7 of 23 • Operation Summary Report Common Well Name: C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor: NORDIC CALISTA UWI: Active Datum:49 42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) t_ (ft) 03:45 - 05:00 1.25 ' STWHIP P i i WEXIT i PUMPING 2.8 BPM IN MM AT FS=2300 PSI. i TAG AT 9791.4'MILLING GREEN CMT. 9792.0',WOB 0.5K,2420 PSI 9792.5',WOB 0.5K,2460 PSI 9793.0',WOB 0.8K,2500 PSI I I 9793.5',WOB 0.9K,2545 PSI 9794.0',WOB 1.7K,2660 PSI 9795',WOB 2.7K,3000 PSI 9795.6',WOB 4.4K, 3170 PSI 9795.9',WOB 3.8K,3060PSI 05:00 - 06:00 1.00 STWHIP P WEXIT CREW CHANGE 9796.8'PU TO CHECK WOB FOR ZERO AND TO DISCUSS IF WE ARE MILLINMG CMT OR j METAL 06:00 - 06:40 0.67 STWHIP P ' -- WEXIT LOOKING AT THE TRENDS FOR THE WOB,@ 04:35 THE DRILL OFFS CHANGED SIGNIFICANTLY AT 9795.5'AND CONTINUED THE SAME SLOW DRILL OFF PATTERN. CHECKED THE MAGNETS AND WE HAVE METAL,CLEANED THEM OFF AND CHECKED A FEW MINUTES LATER AND WE HAVE MORE • • METAL. LOOKING AT ALL THE INFORMATION IT LOOKS LIKE WE ARE ON STEEL SO WE • ARE GOING TO CALL TOW AT 9795.5' 06:40 - 10:30 i 3.83 • STWHIP P WEXIT 9796.7'CONTINUE MILLING WINDOW FREE SPIN 2700 PSI @ 2.8 BPM 1 I-07:20 9797.5' WOB=3.46K DP=310 PSI @ • • 3010 PSI -07:40 9798.0' WOB=4.18K DP=355 PSI @ 3055 PSI I -07:55 9798.5' WOB=4.28K DP=310 PSI @ 3010 PSI -08:20 9799.0' WOB=4.20K DP=280 PSI @ 2980 PSI -08:45 9799.5' WOB=3.46K DP=310 PSI @ 3010 PSI -09:05 9800.0' WOB=3.63K DP=290 PSI @ 2990 PSI -09:25 9800.5' WOB=2.98K DP=300 PSI @ 3000 PSI SLOW ROP,800#DROP IN WOB 09:55 9801.0' WOB= 1.60K DP= 150 PSI @ 2850 PSI NOT MUCH WOB OR DP, RIH 0.3'AND SEE IF !WE SEE GET MOTOR WORK AND WOB -10:06 9801.3' WOB=2.20K DP=300 PSI @ 3000 PSI -10:20 9801.5'NOT MUCH HAPPENING WOB <1K WITH ONLY-100 PSI DP. RIH AND TRY TO GET SOME WOB TO SEE IF WE ARE STILL • ON STEEL OR DRILLING FORMATION -10:24 9801.9'SMALL INCREASE IN MOTOR WORK 10:30 - 11:15 0.75 1 STWHIP P WEXIT MILLED 1'TO9802.5'WITH 200 PSI INCREASE IN MOTOR WORK,LOOKS LIKE WE POPPED OUT AT 9801.5' 9802.6'LOOKS LIKE THE STRING MILL IS AT THE BOTTOM OF THE WINDOW, PU AND DRESS BOTTOM OF WINDOW AT 2'PER HOUR AS PER PLAN Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 8 of 23 • Operation Summary Report Common Well Name: C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00(4)72.50ft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:15 - 12:00 0.75 STWHIP P WEXIT 9802.5'GETTING SAME MOTOR WORK AS BEFORE AT THIS DEPTH CONTINUE MILLING AT 2 FPH TO MAKE SURE BOTTOM OF WINDOW IS CLEAN 12:00 - 12:25 0.42 STWHIP P WEXIT 9803'DRILL RAT HOLE 12:25 - 13:55 1.50 STWHIP P WEXIT DRILLED TO 9812'BACKREAM WINDOW AT 1 FPM FROM 9802'TO 9785' 9785'RIH AND REAM DOWN @ 1FPM 9812'BACKREAM AGAIN AT 1 FPM 13:55 - 14:05 0.17 STWHIP P WEXIT DRY DRIFT CLEAN IN BOTH DIRECTIONS, POOH 14:05 - 14:15 0.17 STWHIP P WEXIT *****KICK WHILE DRILLING DRILL***** SLB DRILLER ANNOUNCED THAT HE HAD AN INCREASE IN FLOW AND HAS PICKED UP OFF BOTTOM AND SHUT DOWN HIS PUMP. ALL PERSONNEL REPORTED FROM THEIR DESIGNATED STATIONS WAITING FOR INSTRUCTIONS.WELL WAS SIMULATED TO BE SHUT IN WITH THE HCR WHEN FLOW CONTINUED AT THE SHAKER. DRILL WAS COMPLETED WITH AN AAR 14:15 15:50_ 1.58 STWHIP P WEXIT SHUT DOWN PUMP AND OPEN EDC,POOH 15:50 - 15:55 j 0.08 STWHIP I, P WEXIT STOP AT 500'AND CLOSE THE EDC THEN FINISH POOH HOLD PJSM WITH CREW TO LD THE MILLING BHA AND PU THE BUILD BHA 15:55 - 16:15 0.33 STWHIP P WEXIT OOH,FLOW CHECK WELL 16:15 - 17:15 1.00 STWHIP P WEXIT PU INJECTOR TO LD MILLING BHA CHECK TREE BOLTS FOR TORQUE,TREE BOLTS ARE TIGHT BOTH MILLS GAUGED 3.79"GO 3.78"NO-GO 17:15 - 17:50 0.58 DRILL P PROD1 MU BUILD 3.1*BHA WITH RERUN HYC 3211M BIT 17:50 - 19:25 1.58 DRILL P PROD1 RIH PVT=273 BBLS PUMPING 2.0 BPM AT 1645 PSI 19:25 - 21:45 2.33 DRILL P PROD1 LOG GR TIE IN FROM 8790'-8990'. 80 FPH PUMPING 2 BPM AT 1790 PSI PVT 318 BBLS, NO LOSSES CORRECTION-4'. 21:45 - 22:20 0.58 DRILL P PROD1 RIH TO9730' _ PUMPING 2 BPM AT 1825 PSI. 22:20 - 23:20 1.00 DRILL ' P PROD1 CLOSE EDC. LOG 80 FPH FROM 9730'TO TD AT 9812'. PUMPING.27 BPM AT 1085 PSI. TAG BOTTOM AT 9812'. PVT 321 BBL 23:20 00:00 , 0.67 DRILL P PROD1 DRILL AHEAD FROM 9812' FS 2950 PSI. 2.5K WOB,PUMPING 2.9 BPM AT 3010 PSI. 5/13/2011 00:00 - 02:00 2.00 DRILL P PROD1 DRILL AHEAD FROM 9814' FS 2950 PSI. 2.5K WOB,PUMPING 2.9 BPM AT 3010 PSI. PVT 322 BBLS.NO LOSSES. 02:00 - 04:00 2.00 DRILL P ! PROD1 DRILL AHEAD FROM 9845' FS 2950 PSI.ROP 45 FPH 3.6K WOB,PUMPING 2.9 BPM AT 3200 PSI. PVT 322 BBLS.NO LOSSES. Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 9 of 23 Operation Summary Report Common Well Name:C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA I UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 05:50 1.83 DRILL P PROD1 DRILL AHEAD FROM 9890' • FS 2950 PSI.ROP 24 FPH 2.7K WOB,PUMPING 2.9 BPM AT 3020 PSI. PVT 322 BBLS.NO LOSSES. 05:50 - 07:10 1.33 DRILL P PROD1 SUSPEND DRILLING OPS FOR GROUP DISCUSSION WITH WTL AND DRLG SUPT 07:10 - 08:20 1.17 DRILL P I . PROD1 9925'CONTINUE DRILLING OPS 07:30 9936'SLOW DRILLING 3.8K WOB NOT -- -----. MUCH MOTOR WORK 08:20 - 08:40 0.33 DRILL P PROD1 WIPER TO WINDOW 08:40 - 08:50 0.17 DRILL P I PROD1 CONTINUE DRILLING 2.71 BPM @2765 PSI VERY SLOW ROP 10-16 FPH 08:50 - 09:10 0.33 DRILL P PROD1 PU OFF BOTTOM A FEW FEET THEN RIH AND LIGHTLY TAG TD AND STOP.CIRC FOR A FEW MINUTES TO TRY AND CLEAR BIT IF ITS BALLED UP 09:10 10:15 1.08 DRILL P PROD1 CONTINUE DRILLING WITH A LITTLE BETTER ROP @ 25 FPH 10:15 - 11:45 1.50 DRILL P PROD1 9965'CONTINUE SLOW DRILLING WITH NEAR I MAX WOB 11:45 12:10 0.42 DRILL ' P PROD1 9995'LOOKS LIKE WE DRILLED OUT OF OUR _ SHALE AS ROP IS INCREASING TO 60-75 FPH 12:10 - 13:00 0.83 DRILL P PROD1 10025'DRILLING AHEAD NO LOSSES 2,98 IN 3.08 OUT WHP/IA/OA/=40/681/127 PSI ROP=30-40 FPH WOB=3.8K 13:00 - 13:45 0.75 DRILL P PROD1 10050' 2 98 IN 3.08 OUT WHP/IA/OA/=40/681/127 PSI ROP= 10-30 FPH WOB=4.5K PU FOR 100'WIPER 13:45 - 14:10 0.42 DRILL P PROD1 LANDED POOH FOR LATERAL BHA STARTED SEEING MHO IN 10000'SAMPLE @ 8966 TVD W E ARE GOING TO TARGET 8964'TVD 14:10 - 15:30 1.33 I DRILL P PROD1 ABOVE WINDOW,SHUT DOWN TO FLOW CHECK WELL,OPEN EDC AND POOH 15:30 - 15:45 0.25 j DRILL P PROD1 --KICK WHILE TRIPPING DRILL***** j ! SLB DRILLER ANNOUNCED THAT HE HAD A • PIT GAIN WHILE PULLING OOH.ALL CREW MEMBERS REPORTED TO THEIR STATIONS WAITING FOR INSTRUCTIONS. COMPLETED DRILL WITH AN AAR 15:45 - 16:05 I 0.33 DRILL I P PROD1 OOH FLOW CHECK WELL AND HOLD PJSM TO LD THE BUILD BHA 16:05 - 16:20 0.25 DRILL P ! PROD1 PJSM TO LD BHA 16:20 17:25 1.08 DRILL P ! PROD1 LD BHA BHA OOH BIT WAS PARTIALLY PACKED OFF WITH WHITE CLAY BIT GRADE 1-1-NO-A-X-I-NO-BHA 17:25 - 18:15 0.83 DRILL I N SFAL 10,075.00 PROD1 REPLACE GOOSENECK ROLLERS. 18:15 - 18:45 0.50 DRILL P PROD1 PJSM TO MU LATERAL DRILLING BHA#7( 1.3 BEND MOTOR AND 4.25 BI-CENTER HYC BIT). 18:45 - 19:15 0.50 DRILL P PROD1 MU LATERAL DRILLING BHA. 19:15 - 21:15 2.00 DRILL P PROD1 RIH 90 FPM PUMPING.3 BPM IN MM/.81 BPM OUT MM AT 1100 PSI. PVT 303 BBLS Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 10 of 23 Operation Summary Report Common Well Name. C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor: NORDIC CALISTA UWI Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:15 - 22:00 0.75 DRILL P PROD1 LOG GR TIE IN 100 FPH FROM 9810'TO 9834'. PUMPING.29 BPM.UP WT 33.5K. CORRECTION-4' 22:00 - 22:10 0.17 DRILL P PROD1 ESTABLISH SLOW PUMP RATES. 122:10 - 23:25 1.25 DRILL P PROD1 TAGGED AT 10076'.FS 2790 PSI.PVT 314. DRILLING 100 FPH. UP WT 33K.DN WT 18K. PUMPING 2.56 BPM IN MMU 2.62 BPM OUT MM AT 3300 PSI. 23:25 - 00:00 0.58 DRILL P PROD1 100'BHA WIPER TRIP AT 10,200'. 5/14/2011 00:00 - 01:00 1.00 DRILL P PROD1 FS 2875 PSI.PVT 314. DRILLING 135 FPH. UP WT 34K. DN WT 16K. WOB.8K. PUMPING 2.56 BPM IN MM/2.62 BPM OUT MM AT 3250 PSL 01:00 - 01:15 0.25 DRILL P PROD1 100'BHA WIPER TRIP. 01:15 - 01:30 0.25 DRILL P PROD1 DRILLING 72 FPH.UP WT 34K.DN WT 16K. WOB.7K.PVT 314 BBLS. PUMPING 2.55 BPM IN MMU 2.60 BPM OUT MM AT 2940 PSI. EDC 10.05 01:30 - 03:00 ! 1.50 DRILL P PROD1 WIPER TRIP TO TUBING TAIL. OPEN EDC IN 7"AND CLEAN 7"TO 9400'. CLOSE EDC AND WIPER TO BOTTOM. 03:00 - 05:30 2.50 DRILLP l PROD1 DRILLING 62 FPH. UP WW T 34K.DN T 16K. • WOB 1.7K. PVT 314 BBLS. PUMPING 2.60 BPM IN MM/2.67 BPM OUT MM AT 3310 PSI. EDC 9.94 PUMP 10 HIGH VIS SWEEP. 05:30 - 07:00 1.50 DRILL P - PROD1 HIGH VIS SWEEP OUT BIT. WIPER TRIP. ! PUMPING 2.42 BPM AT 2622 PSI. GR TIE IN AT 9820' SPR'S AT 06:30 @ 10450' PUMP#1 2.50 BPM @ 2700 PSI 113 SPM 11.25 BPM @ 1640 PSI 56 SPM 0.30BPM @1200 PSI 14SPM PUMP#2 2.50 BPM @ 2725 PSI 130 SPM 1.25 BPM @ 1700 PSI 68 SPM 0.30 BPM@ 1300 PSI 21 SPM 07:00 - 07:30 0.50 DRILL P PROD1 DRILLING AHEAD FROM 10,450' FS 2740 PSI,2.5 BPM AT 3200 PSI,DWOB 1.6K ROP 100-140 FPH PVT=312 BBLS WI-VIA/OA=33/680/122 PSI ECO=9.93 PPG 07:30 - 08:40 1.17 DRILL P PROD1 DRILLING AHEAD FROM 10,500' FS 2740 PSI,2.5 BPM AT 3200 PSI,DWOB 2.23K ROP 100-120 FPH PVT=311 BBLS WH/IA/OA=29/690/128 PSI ECD=9.97 PPG TOOL VIBRATION IS AT 4-5, INCREASE RATE FROM 2.5 TO 2.7 BPM TO SEE IF IT IMPROVES VIBRATION IS NOW AT 1-2 Printed 6/6/2011 1:36:54PM North America-ALASKA- BP Page 11 of 23 Operation Summary Report Common Well Name:C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site:PB C Pad Rig Name/No.: NORDIC 1 Spud DaterTime: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code j NPT 1 NPT Depth 1 Phase Description of Operations (hr) - I (ft) ±— 108:40 - 09:00 0.33 DRILL 1 P 1 PROD1 DRILLING AHEAD FROM 10,555'ROP 1 INCREASE • FS 3000 PSI,2.7 BPM AT 3200 PSI,DWOB • 0.63K • ROP 150 FPH PVT=306 BBLS WH/IA/OA=29/690/128 PSI • ECD=9.94 PPG DRILLING AT 8959'TVD. GEO WANTS TO • DROP DOWN TO STAY IN THIS SAND AND LEVEL OFF 09:00 - 09:45 0.75 DRILL P PROD1 WIPER TO WINDOW PU TO 9810'THEN RIH TO 9880'TO OPEN THE EDC AND JET UP INTO THE TT 09:45 - 10:00 0.25 DRILL P PROD1 PRESSURES NOT BALANCING BETWEEN 1 ANN&BORE ENOUGH TO OPEN EDC POSSIBLY FROM IA BLEED OFF.CLOSE 1 CHOKE AND APPLY A LITTLE WHP TO BALANCE PRESSURES. PRESSURES BALANCED OPEN EDC AND JET UP INTO THE TUBING 10:00 - 10:50 0.83 DRILL P PROD1 9490'BIT DEPTH 9440'EDC DEPTH PACKING OFF AT TUBING TAIL BOTTOMS UP PACKED OFF OUT MICRO MOTION,GETTING LARGE AMOUNT OF SILTSTONE CHUNKS AND COAL 10:50 - 11:10 0.33 DRILL P . PROD1 :9780'CLOSE EDC AND RIH TO BOTTOM. 10600'SAMPLE SHOWED HOT PLAN IS TO 'COME UP 5'TVD***** 11:10 - 11:40 0.50 DRILL P PROD1 TAGGING IN SHALE at 10160'AND PULLING HEAVY, CLEANED UP AND RIH CLEAN 11:40 - 12:00 0.33 1 DRILL P PROD1 DRILLING AHEAD FROM 10,600' 1 FS 2950 PSI,2.7 BPM AT 3125 PSI,DWOB 11.81K 1 ROP 140 FPH PVT=297 BBLS WI-/IA/OA=33/718/172 PSI ECD=10.03 PPG 12:00 - 12:35 0.58 DRILL P1 PROD1 DRILLING AHEAD FROM 10,650' • FS 2950 PSI,2.7 BPM AT 3125 PSI,DWOB 1.11K ROP 30 FPH PVT=288 BBLS ; WH/IA/OA=33/750/178 PSI ECD= 10.12 PPG - __-; __ _ __li 12.35 12:50 0.25 1 DRILL P PROD1 10660'SWAP TO NEW MUD 12:50 - 14:15 1.42 DRILL P PROD1 DIFFERNTUALLY STUCK ON BOTTOM AT 10670', NEW MUD ALMOST AT THE BIT AND WE CAN ORIENT CALLED WTL, DRLG SUPT&ODE 13:05 12 BBLS OF NEW MUD OUT, SHUT DOWN PUMP AND ALLOW EVERYTHING TO • RELAX 13:20 RELAXED FOR 15 MIN TRY PULLING FREE,COILIFE AT 8%AT THIS DEPTH 13:30 PULLED 6 TIMES TO MAX WT AND NO MOVEMENT, FINISH MUD SWAP AND SEE IF THAT WORKS 13:35 CALLED FOR 60 BBLS OF MINERAL OIL JUST INCASE 14:10 BOTTOMS UP AND NEW MUD ALL THE WAY AROUND, RELAX FOR 5 MIN AND PULL MAX WT 14:15 PULL TO MAX WT Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 12 of 23 • Operation Summary Report Common Well Name: C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release:5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT 1 NPT Depth Phase Description of Operations (hr) 1 ( � r —h 14:15 - 15:30 1.25 DRILL P � PROD1 I PULLED FREE ON FIRST PULL,SHORT TRIP TO WINDOW TO GIVE NEW MUD TIME TO BUILD A WALL CAKE AND TO ALSO TIE IN. '15:30 - 16:25 0.92 DRILL P PROD1 PULL INTO CASING TO REPAIR INJECTOR GRIPPER BLOCK CLOSE TOP SET OF PIPE/SLIP RAMS TO SECURE PIPE TO SWAP OUT GRIPPER BLOCK RAM CLOSED WITH 19.6K HANG WEIGHT 116:25 - 17:30 I 1.08 DRILL P ' PROD1 TIE IN CORRECT DEPTH+11'AND RIH 17:30 - 18:15 '; 0.75 DRILL P PROD1 DRILLING AHEAD FROM 10,674' . FS 2743 PSI,2.6 BPM AT 2988 PSI,DWOB 1.5K I ROP 75 FPH, PVT=319 BBLS � UP WT 34K, DN WT 16K. WH/IA/OA=29/660/74 PSI ECD=9.92 PPG HAVING HI VIBRATIONS, PUMP FLUCTUATIONS AND TF ALL THE WAY AROUND 18:15 - 18:30 0.25 DRILL P t PROD1 CREW CHANGE AND ESTABLISHING SLOW • PUMP RATES 18:30 - 18:45 , 0.25 DRILL P PROD1 DRILLING AHEAD FROM 10,737' FS 2850 PSI,2.6 BPM AT 3265 PSI,DWOB 1.6K ROP 120 FPH PVT=313 BBLS I 'WI-/IA/OA=29/690/104 PSI 11 WW ECD= 10.04 PPG UP T 35.3K,DN T 15.7K 18:45 19:00 .L_ 0.25 DRILL P PROD1 100'BHA WIPER TRIP 19:00 20:00 1.00 DRILL P PROD1 I DRILLING AHEAD FROM 10,770' IFS 2800 PSI,2.5 BPM AT 3180 PSI,DWOB 1.6K ROP 50 FPH PVT=313 BBLS WH/IA/OA=29/675/87 PSI ECD=9.98 PPG i UP WT 34K,DN WT 15K 20:00 - 23:20 3.33 DRILL P T PROD1 WIPER TRIP TO WINDOW_ WENEED12-14DEGREEPER100' DOGLEGS AND WE ARE AVERAGING 9.5'S ALL DAY. DECIDED TO PULL BHA AND SWAP 1.3 MOTOR FOR A 1.5 DEGREE BENT MOTOR. ALSO THOUGHT BI CENTER BIT WAS NOT I STAYING ENGAGED IN FORMATION,SO WE SWAPPED TO A GAUGE BIT. OPEN EDC AT 9,788'. JETTED WS AND WINDOW THEN JETTED THE 7"CASING 3 TIMES DUE TO LARGE AMOUNTS OF CUTTINGS COMMING OVER THE SHAKER AND PLUGGING OFF THE OUT MM. THE HOLE WAS ALSO PACKING OFF SEVERAL TIMES. POOH 32 FPM PUMPING 3.71 BPM AT 3160 PSI. HOLE IS CLEAN. 23:20 - 23:30 0.17 DRILL P j C PROD1 FLOW CHECK AT 9750' i WELL STATIC. 23:30 - 00:00 0.50 DRILL r P PROD1 POOH AT 100 FPM PUMPING 3.7 BPM AT 3100 • PSI. 5/15/2011 00:00 - 01:35 1.58 DRILL P ! i PROD1 POOH AT 100 FPM PUMPING 3.7BPM AT 3100 , i PSI. Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 13 of 23 Operation Summary Report Common Well Name:C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00©72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:35 - 01:45 0.17 DRILL I PROD1 FLOW CHECK WELL AT SURFACE.STATIC. CLOSE EDC. 01:45 - 02:00 0.25 DRILL P PROD1 PJSM TO LD DRILLING BHA,CLEAN OUT MM, CLEAN OUT THE HI PRESSURE FILTERS, INSPECT EOP,JET STACK AND PT THE QUICK TEST PORT. 02:00 - 02:40 0.67 DRILL P PROD1 POP OFF WELL LD DRILLING BHA PU SWIZZLE STICK. 02:40 - 03:15 0.58 DRILL P PROD1 JET THE STACK. 03:15 - 04:25 1.17 DRILL P PROD1 PULL APART OUT MM AND CLEAN OUT. PULLED PIECES OF CUTTINGS OUT OF OUT MM AND BYPASS THAT ARE 2"X1"X1/2". I COIL HAD FLAT SPOTS, GOUGES AND SCRAPES.CUT 20'OF COIL AND REHEAD. PULL TEST TO 35K.CONTINUITY AND MEG TEST GOOD. UPPER CHECK IN UQC LOOKS BAD AT ONLY 66 HRS REPLACED IT. 04:25 - 06:00 I 1.58 DRILL P PROD1 HEAD UP BAKER UQC. 06:00 - 06:30 0.50 DRILL P - PROD1 INSTALL NIGHT CAP, PRESSURE TEST .[ BARRIERS TO REMOVE OUT MICRO-MOTION '06:30 - 07:00 0.50 DRILL P PROD1 REMOVE MICRO-MOTION TO INSPECT FOR DEBRIS PRESSURE TEST BHI UQC CHECK VALVES 07:00 - 07:20 0.33 DRILL P PROD1 FUNCTION TEST BOPE 07:20 - 09:00 1.67 DRILL P PROD1 'FOUND LARGE CHUNKS OF SILTSTONE PACKED OFF IN TUBES REINSTALL MICRO-MOTION AND PRESSURE TEST CONNECTIONS 09:00 - 09:30 0.50 DRILL P PROD1 r PRESSURE TEST LINES TO MICRO-MOTION I __ AFTER REINSTALLING ,09:30 - 09:45 0.25 DRILL P PROD1 OPEN MASTER&SWAB AND FILL HOLE, TOOK 2 BBLS 09:45 10:00 0.25 DRILL P PROD1 PJSM TO MU THE DRILLING BHA 10:00 - 10:50 0.83 DRILL P I PROD1 MU 1.5°LATERAL BHA WITH NEW HYC 3.75" RAZOR EDGE BIT 10:50 - 12:40 1.83 DRILL P PROD1 RIH CIRCULATING THROUGH EDC 12:40 - 13:05 0.42 I DRILL P PROD1 9750'CLOSE EDC,RIH TO 9810'TO LOG RA TIE IN AT 9810' 13:05 - 13:50 0.75 DRILL P I PROD-1 CORRECT DEPTH-5.3'AND RIH TO BOTTOM 13:50 - 14:30 0.67 DRILL P PROD1 DRILLING AHEAD FROM 10,801' FS 2670 PSI,2.6 BPM AT 2880 PSI DWOB 2.1K, ROP 150 FPH W WIA/OA=44/679/10 PSI ECD=10.03 PPG PVT=305 BBLS 14:05 FAST ROP,DRILLED 25'PU TO CHECK WT AND GET SURVEY 14:30 - 14:50 0.33 DRILL P PROD1 DRILLING AHEAD FROM 10,850' FS 2670 PSI,2.6 BPM AT 2900 PSI DWOB 1.22K, ROP 150 FPH WH/IA/OA=48/701/10 PSI ECD=10.03 PPG PVT=305 BBLS 14:50 - 15:15 0.42 DRILL P PROD1 DRILLING AHEAD FROM 10,900' FS 2670 PSI,2.6 BPM AT 3000 PSI DWOB 1.22K, ROP 150 FPH WH/IA/OA=59/734/18 PSI ECD=10.11 PPG PVT=303 BBLS Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 14 of 23 Operation Summary Report Common Well Name: C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor: NORDIC CALISTA UWI: Active Datum:49 42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ T15.15 - 15:50 0.58 I DRILL P I PROD1 WIPERTOWINDOW 15:50 - 16:15 0.42 1 DRILL P PROD1 PULLING HEAVY AT 10190' PULLED HEAVY AT 10120' 16:15 - 17:15 1.00 1 DRILL PPROD1 RIH FROM 8910' 1 I SPR'S AT 06:30 @ 10450' PUMP#1 1 2.50 BPM @ 2550 PSI 113 SPM 1.25 BPM@1580 PSI 56 SPM 1 0.50 BPM @ 1200 PSI 14 SPM PUMP#2 2.50 BPM @ 2725 PSI 130 SPM • 1.25 BPM @ 1700 PSI 68 SPM 0.50 BPM @ 1250 PSI 21 SPM 17:15 - 17:45 0.50 DRILL P ' 1 PROD1 DRILLING AHEAD FROM 10,950' FS 2670 PSI,2.6 BPM AT 2950 PSI • DWOB 1.2K, ROP 150 FPH WH/IA/OA=44/696/46 PSI ECD=10.03 PPG PVT=298 BBLS 17:45 - 18:35 0.83 DRILL P PROD1 DRILLING AHEAD FROM 11,000' FS 2670 PSI,2.6 BPM AT 3050 PSI i DWOB 1.53K, ROP 120 FPH WH/IA/OA=48/738/63 PSI ECD=10.14 PPG PVT=297 BBLS 18:35 - 19:10 —0.58 1 DRILL P PROD1 DRILLING AHEAD FROM 11,050' FS 2670 PSI,2.6 BPM AT 3020 PSI DWOB 1.88K, ROP 115 FPH ' WI-/IA/OA=48/738/63 PSI ECD=10.14 PPG PVT=295 BBLS — —---r------ T — 19 :10 - 20:45 1.58 1 DRILL P �', PROD1 WIPER TO WINDOW FROM 11,100' PULLING HEAVY @ 10,200'TO 10,100 WITH 15-20K OVER PULLS. ' i OPEN EDC,WASH WINDOW @ 2.8 BPM,2450 PSI FROM 9,820'TO 9,880' ECD= 10.20 PVT 278 BBLS 20:45 - 22:30 1.75 DRILL P PROD1 WASH 7"TBG TO TAIL PIPE @ 3.7 BPM,3230 [PSI FROM 9,820'TO 9,400' !WHEN AT TBG TAIL PIPE PULLING 5K OVER 1 PULL WITH INCREASE IN CIRC PRESSURE TO 3600 PSI. ' REDUCE TO 1.5 BPM RIH TO 9,600'. INCREASE TO 3.7 BPM 3300 PSI PUH @ 15 FPM. CIRCULATE AND WASH JUST BELOW TBG I TAIL @ 9,424'CIRCULATE BOTTOMS UP. NOTE AT SHAKER- 1/2"PIECES OF SHALE AND SANDSTONE. ECD=10.47 PPG. PVT 278 BBLS. CUTTINGS TO LARGE TO PASS OUT MICRO MOTION. PLUGGING MICRO MOTION BYPASS MICRO MOTION UNTIL CUTTINGS AT ' SHAKER SLOW DOWN. 22:30 - 23:30 1.00 DRILL P , PROD1 CONTINUE PUH WASHING CUTTINGS TO 7,200'FOR 35 DEG INCLINATION iPUMPING 3.7 BPM,3350 PSI.CIRCULATE i • UNTIL HOLE IS CLEAN. Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 15 of 23 Operation Summary Report Common Well Name:C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor: NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To I Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:30 - 00:00 0.50 DRILL P F I PROD1 WASH DOWN @ 100 FPM,3.6 BPM @ 3230 PSI FROM 7,200'TO 9,830' CONTINUE SEEING SHALE AND SANDSTONE I PIECES AT SHAKER. CIRCULATE AN ADDITIONAL BOTTOMS UP CLEANING UP HOLE ECD=10.27 PPG.PVT=280 BBLS. 5/16/2011 :00:00 - 01:45 1.75 j DRILL P 1 PROD1 CONTINUE TO CLEAN AND WASH 7"LINER FROM 9,830'TO 9,400' I ' LINE RETURNS BACK TO OUT MICRO I1 I MOTION.STILL RESTRICTED. I PJSM.CLEAN OUT MICRO MOTION. FOUND PIECE 1"X 1 1/2"SANDSTONE.LINE UP OUT MICRO MOTION. 01:45 - 02:00 0.25 DRILL P PROD1 CLOSE EDC.TIE IN LOG @ 9,820'+ 10' �- ___ ! _. _ __ CORRECTION. 02:00 - 03:20 1.33 DRILL I P PROD1 RIH,WORK PAST SHALES PUMPING 1 BPM 1500 PSI FROM 10,100'TO 10,200'. CONTINUE TO WORK TO BOTTOM. I i TIGHT @ 10,340'TO 10,360'. INCREASE PUMP RATE TO 2.52 BPM 2680 PSI 1 AT 10,430'PAST SHALES. TAG TD @ 11,100' SPR#1 MP @ 11,050'= 1.25BPM 1640PS1, I .3BPM 1200PSI ` SPR#2 MP @ 11,050'=1.25BPM 1650PS1, .3BPM 1200PSI 03:20 - 05:10 1.83 DRILL P 7 PROD1 DRILLING AHEAD FROM 11,100 FS 2655 PSI,2.6 BPM AT 2970 PSI. DWOB 1.5K, ROP 160 FPH. WH/IA/OA=40/724/231 PSI. ECD= 10.13 PPG PVT=286 BBLS. PUMP 10 BBL 110 LSRV SWEEP. NO EXTRA CUTTINGS NOTED @ SHAKER. •05:10 06:10 1.00 DRILL P DRILLING TO 11,253' — — - PROD1 WIPER TRIP TO WINDOW 06:10 - 06:55 0.75 DRILL P ! PROD1 PULLED TO 9810', RIH TO 9880'AND OPEN THE EDC TO CIRC A BOTTOMS UP.THE AUDITOR WOULD LIKE TO RUN A WELL • CONTROL DRILL TO INCLUDE SHUTTING IN THE WELL WITH RON PHILLIPS TO I COMPLETE HIS AUDIT. BOTTOMS UP WAS CLEAN,JUST FINE CUTTINGS _ WELL WILL NOT BE SHUT IN DURING DRILL 06:55 - 07:30 0.58 DRILL j P PROD1 PERFORM WELL CONTROL DRILL WHILE CONTINUING TO PUMP 07:30 - 08:20 0.83 DRILL P PROD1 DRILL COMPLETED,SWAP SHAKER SCREENS 08:20 - 09:30 1.17 DRILL P I PROD1 RIH TO WINDOW AND CLOSE EDC, RIH TO BOTTOM Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 16 of 23 Operation Summary Report Common Well Name: C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 1 Spud Date/Time: Rig Release:5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/199300:00©72.50ft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 09:45 0.25 DRILL P PROD1 RECORD SLOW PUMP RATE PRESSURES SPR'S AT 09:30 @ 11300' PUMP#1 2.50 BPM @ 2690 PSI 115 SPM 1.25 BPM @ 1740 PSI 59 SPM 0.50 BPM @ 1265 PSI 21 SPM PUMP#2 2.50BPM @2644PSI 117SPM 1.25BPM @1710 PSI 64SPM r I 0.50 BPM @ 1271 PSI 26 SPM 09:45 10:15 0.50 DRILL P PROD1 DRILLING AHEAD FROM 11,250' FS 2680 PSI,2.5 BPM AT 3350 PSI WOB 3.2K, ROP 100 FPH WH/IA/OA=44/750/250 PSI ECD=10.1 PPG PVT=281 BBLS 10:15 - 10:50 0.58 DRILL N DFAL 11,294.00 PROD1 PU OFF BOTTOM MWD SHUT DOWN 10:50 - 13:30 2.67 DRILL N DEAL 11,294.00 ' PROD1 MWD HAND HAS TESTED ALL THE SURFACE LINES AND THINKS THE PROBLEM MIGHT BE DOWNHOLE.START POOH TO CASING BEING VERY CAUTIOUS WHEN PULLING THROUGH SHALES,WE DO NOT HAVE AN EDC MWD HAND CANNOT FIND ANYTHING WRONG AT SURFACE,POOH TO INSPECT MWD SHALE AT 10200'TO 10150 WAS CLEAN SMALL AMOUNT OF WORK AT 10141' 13:30 - 13:40 0.17 DRILL N DFAL 11,294.00 PROD1 OOH FLOW CHECK WELL RIG CREW ALMOST DONE REPLACING OUT MICRO-MOTION PJSM TO LD BHA 13:40 - 14:15 0.58 DRILL N DEAL' 11,294.00 PROD1 PU INJECTOR AND TEST WIRE WIRE TESTED GOOD, PROBLEM IS IN THE MWD 14:15 - 14:40 0.42 DRILL N DFAL 11,294.00 PROD1 BIT LOOKS GOOD FINISH INSTALL OF NEW OUT MM AND PT 'CONNECTIONS 14:40 - 15:00 0.33 DRILL N DFAL 11,294.00 PROD1 PLAN FORWARD IS TO CHANGE OUT MWD, PU THE LOW SPEED HIGH FLOW MOTOR AND RERUN THE THE SAME BIT 15:00 - 15:25 0.42 DRILL N DFAL 11,294.00 PROD1 PT MICRO-MOTION CONNECTIONS 15:25 - 15:40 0.25 DRILL N DFAL 11,294.00 PROD1 PJSM TO MU THE BHA 15:40 - 16:00 0.33 DRILL N DFAL i 11,294.00 PROD1 MU THE BHA AS PER PLAN FORWARD 16:00 - 16:30 0.50 DRILL N DFAL 11,294.00 PROD1 PU INJECECTOR,SLB POWER PACK IS PRESSURING UP THE REEL PRESSURE TO HIGH.PULL BHA AND STAND BACK IN THE A-LEG WHILE TROUBLE SHOOTING PROBLEM. A VALVE WAS NOT FULLY OPENED AFTER REPLACING AN 0-RING ON THE HYDRAULIC FILTER CAN AND IS NOW WORKING FINE. 16:30 - 17:00 0.50 DRILL N DFAL 11,294.00 PROD1 MU THE BHA,ULTRA LOW SPEED MOTOR,1.4 DEGREE BEND AND RERUN HYC GAUGE 3.75"BIT S/N 131509. 17:00 - 19:30 2.50 DRILL N DFAL 11,294.00 PROD1 GR LOG TIE IN AT WS RA TAG. Printed 6/6/2011 1:36:54PM North America -ALASKA- BP Page 17 of 23 Operation Summary Report Common Well Name:C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 20:30 1.00 DRILL P PROD1 CCL LOG FROM 9300'TO 9600'TO VERIFY CORRECT DEPTH FOR LINER TOP SPACE ' OUT,19'DISCREPANCY BETWEEN LOGS, WELLBORE DIAGRAM AND 1995 LINER SUMMARY. ONLY 21'BETWEEN NIPPLES AND 12'TO TUBING TAIL.THE PLAN TO SET THE I 1 LINER TOP AT 9440'COULD HAVE PUT IT BELOW TUBING TAIL. 20:30 - 21:30 1.00 DRILL N SFAL 9,550.00 PROD1 TROUBLE SHOOT OUT MICRO MOTION. NORDIC RIG ELECTRICIAN IS HOURED OUT. CALLED SLB THEIR TECHS ARE ALSO HOURED OUT.CALLED ADW CTD FIELD OPS SUPERINTENDANTAND WAS INSTRUCTED TO REMAIN IN CASED HOLE AND STRAP THE PITS EVERY 15 MINUTES.PUT NORDIC ON DOWN TIME UNTIL THEY GET THE MM OUT I I i CALIBRATED.CALLED AND INFORMED TOWN i ODE. 21:30 - 00:00 2.50 DRILL N SFAL 9,550.00 PROD1 REMAIN IN CASED HOLE AND STRAP THE r PITS EVERY 15 MINUTES. 5/17/2011 00:00 - 04:00 4.00 DRILL N SFAL 9,550.00 PROD1 REMAIN IN CASED HOLE AND STRAP THE , PITS EVERY 15 MINUTES. PUMP MIN RATE. PVT 259 BBLS. LOAD LINER IN PIPE SHED 04:00 - 09:45 5.75 .'-,DRILL N j SFAL ! 9,550.00 PROD1 CONTINUE CIRCULATING WAITING FOR MM REPAIR PVT=259 BBLS 09:45 - 10:30 0.75 DRILL N SFAL 9,550 00 I PROD1 PRESSURE TEST MM CONNECTIONS 10:30 - 10:40 0.17 DRILL N SFALT 9,550.00 PROD1 'CLOSE EDC AND RIH 10:40 - 10:50 0.17 DRILL N I SFAL ' 9,550.00 PROD1 LOG 15'SECTION FOR BHI TO OVERLAP/COMPARE THIS MWD TO THE LAST MWD RAN 10:50 - 11:25 0.58 DRILL N ' SFAL 9,550.00 PROD1 SHALE FROM 10100'TO 10200'WAS CLEAN,1 SMALL TAG BECAUSE THE TF WAS 180 OUT_ 11:25 - 11:45 0.33 DRILL N I SFAL 9,550.00 PROD1 SPR'S AT 11:30 @ 11300' PUMP#1 2.50 BPM @ 2728 PSI 117 SPM ,1.25 BPM @ 1700 PSI 58 SPM 0.50 BPM @ 1320 PSI 22 SPM PUMP#2 2.50 BPM @ 2745 PSI 119 SPM ' 1.25 BPM @ 1685 PSI 64 SPM 0.50BPM @1315 PSI 27SPM 11:45 - 12:20 0.58 DRILL P PROD1 DRILLING AHEAD FROM 11,297' FS 3300 PSI,3.1 BPM AT 3350 PSI WOB 3.05K, ROP 95 FPH • WH/IA/OA=26/740/5 PSI ECD=10.2 PPG PVT=261 BBLS 12:20 - 13:20 1.00 DRILL I P PROD1 DRILLING AHEAD FROM 11350' FS 3300 PSI,3.1 BPM AT 3500 PSI II WOB 2.61K, ROP 12OFPH WH/IA/OA=40/756/10 PSI --------------- — ECD=10.25 PPG PVT=260 BBLS 13:20 - 15:45 2.42 DRILL i P PROD1 WIPER TO WINDOW PVT=258 BBLS I , SHALE FROM 10200'TO 10100'MOTOR WORK 1 DEPTHS I -10136' -10122' Printed 6/6/2011 1:36:54PM ''orth America -ALASKA- BP Page 18 of 23 Operation Summary Report Common Well Name: C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site:PBC Pad Rig Name/No.:NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor.NORDIC CALISTA UWI: • Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) (ft) 15:45 - 16:30 0.75 DRILL P PROD1 DRILLING AHEAD FROM 11450' FS 3300 PSI,3.1 BPM AT 3450 PSI WOB 2.36K, ROP 110FPH WH/IA/OA=40/769/110 PSI ECD=10.26 PPG PVT=253 BBLS 16:30 - 16:55 0.42 DRILL P PROD1 DRILLING AHEAD FROM 11500' FS 3300 PSI,3.1 BPM AT 3450 PSI WOB 2.36K, ROP 110FPH i WI-/IA/OA=40/769/110 PSI L —_ I ECD=10.40 PPG PVT=252 BBLS 16:55 - 17:50 0.92 DRILL P PROD1 ROP DROPPED OFF AND TAKING ALOT OF I WEIGHT TO DRILL i PU A BHA LENGTH AND TRY DRILLING I STILL TAKING A LOT OF WT TO GET WT TO I i I BIT THEN JUST DRILLS OFF 17:50 - 19:00 1.17 DRILL P PROD1 TAKING LESS WT TO DRILL FORA FEW FEET THEN STARTED STACKING AGAIN. DIRTY TRUCKS JUST ARRIVED ON LOCATION. PJSM FOR MUD DISPLACEMENT.PERFORM BHA WIPER TRIP. 19:00 - 20:00 1.00 DRILL P PROD1 SWAP TO NEW DRILLING MUD. CONTINUE TO DRILL AHEAD UNTIL NEW MUD I I , TO BIT. DRLG FS 2940 PSI/3 BPM. 20:00 - 20:15 0.25 DRILL P PROD1 P/U&ESTABLISH SPR's W/NEW MUD @ 11548'MD. I PUMP#1 3.0 BPM @ 2864 PSI 138 SPM 1.5 BPM @ 1692 PSI 70 SPM i 0.90 BPM @ 1355 PSI 42 SPM ._,i PUMP#2 3.0 BPM @ 2871 PSI 141 SPM 1.50 BPM @ 1655 PSI 70 SPM 0.90 BPM 01355 PSI 44 SPM 20:15 - 21:45 1.50 DRILL P PROD1 NEW MUD TO SURFACE 3 BPM/2817 PSI. DRILL AHEAD.WORK SHALE SPOTS AS NEEDED. 21:45 - 22:55 1.17 DRILL P + PROD1 PERFORM WIPER TRIP TO WINDOW.FROM 11592'MD.PUW=36K.3 BPM. 22:55 - 00:00 1.08 DRILL P PROD1 OPEN EDC.JET 7"CSG UP TO TBG TAIL. JET CUTTINGS UP FROM 7000'MD. 1 — ...._._ 4.2 BPM/3413 PSI. 5/18/2011 00:00 - 00:30 1 0.50 DRILL P PROD1 CONTINUE TO JET CUTTINGS UP FROM 7000' MD. 4.2 BPM/3413 PSI. 100:30 - 01:45 1.25 DRILL P ! PROD1 CLOSE EDC.RIH.WASH TO BTM.MONITOR RETURNS. _I__ CHECK PVT W/MANUAL STRAP. 01:45 - 03:50 2.08 DRILL P PROD1 WORK PIPE TO BTM F/11490'TO 11590'MD. DRILL AHEAD TO 11750'MD.FS-2.9 BPM/ i_ 2840 PSI 03:50 - 06:00 2.17 DRILL P 1 PROD1 WIPER TRIP TO WINDOW FROM 11,750'MD. Printed 6/6/2011 1:36:54PM `forth America -ALASKA- BP Page 19 of 23 Operation Summary Report Common Well Name: C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay I Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (ft) 06:00 - 07:15 1.25 DRILL P PROD1 •i 11550'STACKING WT WITH NO WOB OR MOTOR WORK THEN IT GIVES IT BACK. NOT MAKING ANY PROGRESS.MAKE A SLOW BACKREAM FOR 100'. BACKREAM WAS CLEAN LOOKS MORE LIKE HYDRAULICS. REDUCE PUMP RATE AND AT 11550'AND MADE IT DOWN TO 11600'AT 1 BPM BUT STILL HAVING TROUBLE GETTING ANY DEEPER. REDUCE RATE TO 0.5 BPM AND MADE IT TO 11672'AND STILL HAVING • PROBLEMS WITH STACK BRING PUMP TO FULL RATE AND DO A SLOW BACKREAM TO 11500' RIH AND STILL HAVING STACKING PROBLEMS 07:15 - 09:20 2.08 ! DRILL P PROD1 DRILLING AHEAD FROM 11,755' FS 3065 PSI,3.1 BPM AT 3200 PSI • WOB 3.05K, ROP 25 FPH WH/IA/OA=44/719/327 PSI i � I ECD=10.15 PPG PVT=307 BBLS MUD WT IN/OUT=8.65/8.70(MM NEEDS TO BE CALIBRATED AT SURFACE) HIGH VIBRATION AT 3.1 BPM TRY REDUCING RATE TO 2.8 BPM,VIBRATION CLEANED UP. 09:20 - 10:20 1.00 DRILL P PROD1 DRILLING AHEAD FROM 11,850' FS 2840 PSI,2.8 BPM AT 3300 PSI WOB 3.5K, ROP 60 FPH WH/IA/OA=62/748/356 PSI ECD=10.17 PPG PVT=304 BBLS STACKING WT PU AND TRY TO DRILL NOT ABLE TO GET BACK ON BOTTOM 10:20 - 11:45 1.42 DRILL P PROD1 CAN'T GET BACK TO BOTTOM MAKE A SLOW BACKREAM TO 11500',VAC TRUCK ON LOCATION WITH NSX LUBE TO INCREASE CONCENTRATION TO 6%. 11:45 - 13:00 1.25 DRILL P PROD1 60 BBLS OF MUD WITH INCREASE IN LUBES TO 6%AROUND BIT. ATTEMPT TO RIH WITH WEIGHT TRANSFER ISSUES. SUSPECT CUTTINGS ISSUES. CONDUCT WIPER TRIP TO WINDOW. SHALES FROM 11,650'TO 11,500'NOT AN ISSUE. PUW STEADY AT 36-37K, MW IN 8.6 PPG,MW OUT 8.7 PPG. STOP AND RIH TO 9880';COME DOWN OFF OF PUMPS AND OPEN EDC. 13:00 - 14:00 1.00 DRILL P PROD1 PICK UP IN OPEN HOLE AT 1.7 BPM,1655 PSI UNTIL INTO WINDOW. BRING ON PUMPS TO 4.1 BPM,3600 PSI,AND CONTINUE WITH WIPER TO TUBING TAIL AT 9450'. CIRCULATE BOTTOMS UP. BOTTOMS UP HAS—15% INCREASE IN SAND AND SMALL, ROUNDED SHALES. CONDUCT KICK WHILE TRIPPING DRILL. 14:00 - 14:30 0.50 DRILL P PROD1 CLOSE EDC. RIH WITH BHA TO 10,270'. 2.9 BPM,3065 PSI, MW IN 8.7 PPG,MW OUT 8.7 PPG. MM ERRATIC. TROUBLESHOOT CHOKE,PRESSURE TRANSDUCERS,OUT MICROMOTION. MM PLUGGED OFF. 130 BBLS AFTER BOTTOMS UP 14:30 - 15:30 1.00 DRILL N SFAL PROD1 POH INTO WINDOW TO WORK ON MM. OPEN EDC AT WINDOW. MM UNPLUGGED AND PRESSURE TESTED. RIH TO CONTINUE DRILLING. Printed 6/6/2011 1:36:54PM "orth America -ALASKA- BP Page 20 of 23 Operation Summary Report Common Well Name: C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) I Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release:5/28/2011 Rig Contractor: NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code I NPT ' NPT Depth 1 Phase Description of Operations (hr) (ft) • 15:30 - 16:00 0.50 DRILL P PROD1 1 AAR ON KICK DRILL WITH GOOD CREW I 'RESPONSE, DISCUSSION ON REACTION AND SUGGESTIONS FOR IMPROVEMENT. 1- 116:00 - 17:30 1.50 DRILL P PROD1 •CLOSE EDC. RIH WITH BHA TO TD of 11,854' AT 2.7 BPM,2710 PSI, MW IN 8.6 PPG,MW 1 : OUT 8.7 PPG. HAD TO WORK THROUGH 11,620-11,650'. TAGGED UP AND HAD TO WORK SEVERAL TIMES TO GET DOWN FROM • l 1 11,845'TO 11,854'. PU AND SO WEIGHTS ARE NORMAL, NO WOB TRANSFER,ATTEMPTS ! TO OBTAIN MOTOR WORK OR STALLING UNSUCCESSFUL. DO NOT SUSPECT CUTTINGS BED RESTRICTIONS; RETURNS I ACROSS SHAKERS LIGHT SAND. 17:30 - 00:00 6.50 DRILL 1 P , PROD1 MONITOR WELL-OK.POH FOR BHA INSPECTION AT 2.8 BPM,2920 PSI. PUW 33-34K. HELD KICK W/TRIPPING DRILL& AAR @ 9820'MD. POH.OPEN EDC AT j WINDOW,INCREASE PUMPS TO 3.7 BPM/ 3260 PSI.CIRCULATE B/U,WASH WINDOW& i ! 7"LINER.MONITOR WELL-OK. CONTINUE ' TO POH. PRESSURED UP AT TT @ 9510'MD. CBU 3.5 BPM/2875 PSI. CONTINUE TO POH& FLOW CHECK PRE BHA©SURFACE.TAG j UP. RIH 500'AND CLOSE EDC. POH.SET I I I BACK INJECTOR. PJSM FOR R/D DRLG BHA. INSPECT 50'OF EOP ABOVE COIL CONNECTOR.NOTED GOUGES 5'ABOVE CC. 5/19/2011 00:00 - 02:30 2.50 DRILL P j PROD1 R/D DRLG BHA.CUT 10'OF COIL, REHEAD COIL CONNECTOR&PULL TEST TO 35K. INSTALL BAKER UQC&PRESSURE TEST TO -- 4K. 02:30 - 04:30 1, 2.00 DRILL P i PROD1 PERFORM MAINTENANCE,REPAIR DRIP IN HYDRAULIC LINE. ' I INSPECT CHAIN.CHANGE OUT PACKOFFS. 04:30 - 05:30 1.00 DRILL , P ' • PROD1 TEST PACKOFFS 250 PSI LOW/3500 PSI _ HIGH PRESSURE. CONDUCT FLOW CHECK. 05: 30 - 06:30 1.00 DRILL P , PROD1 M/U NEW BHA: 3.75"GAUGED BIT,2 7/8" , ULTRA LS MOTOR WITH 1.4 DEG BEND, HOT, DGS,DPS, EDC,POWERCOMMS,WEAR I SUB, LQC, UQC,XO, CTC. MU TO INJECTOR HEAD. CONDUCT CHANGE OUT WITH INCOMING CREW,DISCUSS PLAN FORWARD. 06:30 - 10:00 3.50 DRILL P PROD1 RIH WITH DRILLING BHA. CONDUCT SURFACE TEST OF AGITATOR,GOOD TEST. CONTINUE RIH T/9700'(JUST ABOVE 7"LNR WINDOW©9794'MD). FLOW CHECKED WELL @ 9500'. NO FLOW. CALIBRATED MICRO MOTION OUT METER ON TRIP IN. 10:00 10:30 i 0.50 DRILL P ! PROD1 HELD KICK WHILE DRILLING DRILL AND AAR t 1 1 WITH RIG CREWS. 10:30 - 12:30 2.00 DRILL P PROD1 PASS THROUGH 7"LNR WINDOW AND CONTINUE TO RIH F/9700'T/CURRENT TOTAL DEPTH OF 11854'MD. LOGGED GR TIE-IN F/9820-9850'MD(-2.5'CORRECTION). TAKE AND RECORD SLOW PUMP RATES AT 11,800'. ENCOUNTERED NO TIGHT SPOTS ON THE TIH. 1. Printed 6/6/2011 1:36:54PM 'Forth America-ALASKA- BP Page 21 of 23 Operation Summary Report Common Well Name:C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 15:00 2.50 DRILL P PROD1 DIRECTIONALLY DRILL F/11,854'T/12,000' MD. FS 3800 PSI,2.70-2.73 BPM,3811-3948 PSI WOB 1.63-2.4K, ROP 80-106 FPH WH/IA/OA=33/735/225 PSI ECD=10.19-10.33 PPG MW IN 8.8 PPG,MW OUT 8.7 PPG PVT=286 BBLS AT 12,000' 15:00 - 18:00 3.00 DRILL P PROD1 WIPER TRIP TO WINDOW AT 2.8 BPM, 3580-3630 PSI,RETURNS STEADY WITH NO NOTICEABLE LARGE SHALE DEBRIS. TURN AROUND AND RUN BACK IN HOLE. WORK THROUGH 11,620'-11,650'AND 11,890'-12,000' MD. 18:00 - 21:30 3.50 DRILL P PROD1 DIRECTIONALLY DRILL F/12,000'MD. @ 12,050'MD PUMP:30 BBLS NEW MUD, CHASE W/30 BBLS HVS,50 BBLS MUD,30 BBLS LVS, DRLD TO 12,150'MD.WIPER TRIP TO TBG TAIL @ 9,428'MD. FS 3755 PSI,2.67 BPM,3600 PSI WOB 1.71 -2.4K, ROP 70 FPH WI-I/IA/OA=34/736/330 PSI ECD=10.6 PPG PVT=294 BBLS AT 12,150' MD.' 21:30 - 23:15 1.75 DRILL P PROD1 UNABLE TO OPEN EDC.FLOW CHECK WELL- OK. 23:15 - 00:00 0.75 DRILL N DFAL 12,150.00 PROD1 POH FOR EDC FAILURE. @ 9000'MD FLOW CHECK WELL(FOR LOSSES)-OK. 5/20/2011 00:00 - 01:45 1.75 DRILL N DFAL 12,150.00 PROD1 CONTINUE TO POH TO SURFACE F/EDC FAILURE. PULL UP TO 100'MD. JOG TO 500'MD.FLOW CHECK-OK. PJSM 02:05 - 03:24 1.32 DRILL N DFAL 12,150.00 PROD1 POH.STAND BACK INJECTOR. BLOW DOWN COILTRAK. CHANGE EDC ON BHA.STAB ON&TEST TOOL-OK. 03:24 - 05:00 1.60 DRILL N DFAL 12,150.00 PROD1 MU DRILLING BHA W/NEW EDC.SAME BIT& BHA. (BIT LOOKED GOOD) BHA: 3.75"GAUGED BIT,2 7/8"ULTRA LS MOTOR WITH 1.4 DEG BEND,AGITATOR, FLAPPER VALVE ASSEMBLY, HOT,DGS, DPS, EDC,POWERCOMMS,WEAR SUB,LQC,UQC, XO, CTC 05:00 - 06:30 1.50 DRILL N DFAL 12,150.00 PROD1 RIH TO WINDOW. 06:30 - 07:45 1.25 DRILL N DFAL 12,150.00 PROD1 OPEN EDC AND RUN DOWN PAST WINDOW. BEGIN SLOW WIPER TRIP UP TO TUBING TAIL TO CLEAN SECTION THAT WAS NOT CLEANED ON TRIP OUT DUE TO EDC FAILURE. 07:45 - 09:15 1.50 DRILL N DFAL 12,150.00 PROD1 RIH TO WINDOW AT HIGH RUNNING RATE TO ENSURE THAT POSSIBLE CUTTINGS LAYING ON BOTTOM ARE STIRRED UP. COMPLETE BU AT WINDOW,SHAKERS LOOK GOOD. CONTINUE TO RIH,LOG TIE IN WITH-2' CORRECTION. RIH TO TD WITH NO PROBLEMS. Printed 6/6/2011 1:36:54PM `Iorth America -ALASKA- BP Page 22 of 23 Operation Summary Report Common Well Name:C-42 AFE No Event Type: RE-ENTER-ONSHORE(RON) li Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) • Project: Prudhoe Bay l Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations -. (hr) (ft) 09:15 - 11:45 2.50 DRILL I P PROD1 DIRECTIONALLY DRILL F/12,150'MD TO 12,284' FS 3770 PSI,2.67 BPM,3600 PSI WOB 1.71 -2.4K, ROP 70 FPH 1 WH/IA/OA=26/644/330 PSI ECD=10.0-10.3 PPG 11:45 - 13:15 1.50 DRILL P PROD1 WIPER TRIP TO WINDOW. PUW 39K. NO PU PROBLEMS. SHAKERS HAD GOOD RETURNS ENTIRE TRIP. 13:15 - 15:50 2.58 DRILL P PROD1 RIH TO TD AT 12,284'. SOW 16-17K. HAD TO WORK TO BOTTOM FROM 11,900'TO TD. 15:50 - 17:30 1.67 DRILL ' P • PROD1 DIRECTIONALLY DRILL F/12,284'MD TO 12,425' FS 3290 PSI,2.47-2.59 BPM,3570 PSI WOB.90-1.55, ROP 75-110 FPH WH/IA/OA=25/698/364 PSI ECD= 10.1 PPG 17:30 - 19:00 1.50 DRILL P PROD1 WIPER TRIP TO WINDOW AT 2.7 BPM,3740 PSI. PUMP 17 BBL HI-VIS SWEEP BEFORE LEAVING BOTTOM AND AGAIN AT 11,700'TO HELP MOVE CUTTINGS. • • UNABLE TO OPEN EDC(MISSED POSITION). CALL TOWN ENGINEER&DISCUSS • OPTIONS... • DECISION IS TO POH C/O EDC, RIH&DRILL FINAL 125'PER ENG/GEO. FLOW CHECK-OK. 19:00 21:30 2.50 DRILL P PROD1 POH TO SURFACE.JOG BACK TO 500'MD. FLOW CHECK. 21:30 - 21:45 0.25 i DRILL P PROD1 POH,CHECKING COIL LAST 20'. -OK. 21:45 - 22:15 0.50 DRILL ] P PROD1 STAND BACK INJECTOR.BLOW DOWN j COILTRAK.PULL BHA. 22:15 - 23:30 1.25 DRILL P . PROD1 P/U SAME BHA W/NEW EDC.STAB ON INJECTOR.TEST TOOL. 23:30 - 00:00 0.50 DRILL P PROD1 RIH W/EDC IN THE OPEN POSITION. N 4-1/2"PUMPED 1.7 BPM/2170 PSI. 5/21/2011 00:00 - 01:30 1.50 DRILL P I PROD1 'CONTINUE TO RIH W/NEW OPEN EDC. IN 4-1/2"PUMPED 1.7 BPM/2170 PSI. - IN 7"PUMPED 3.4 BPM/3100 PSI. 01:30 - 02:00 j 0.50 DRILL P - PROD1 CIRCULATE BTMS UP @ WINDOW. 3.7 BPM/3240 PSI. 02:00 - 02:30 I 0.50 DRILL P PROD1 RIH THROUGH WINDOW TO TIE-IN DEPTH,RA TIE-IN. CORRECT DEPTH+0.5'. 02:30 04:00 1.50 DRILL P PROD1 RIH TO BTM.TAGGED BTM 13'DEEP. NOTED RATTY HOLE FROM 11,600'TO TD. ORIENTED AS NEEDED TO GET TO BTM. 2.54 BPM/3410 PSI. 04:00 - 05:00 1.00 DRILL P PROD1 DRILL AHEAD W/3K ON BIT.F/12,425'MD. 2.60 BPM/3840 PSI MW IN=8.75 PPG.MW OUT=8.67 PPG. FS 3457 PSI. 05:00 - 06:30 1.50 DRILL P PROD1 DRILLING AHEAD 06:30 - 07:05 0.58 DRILL P I PROD1 DRILLING AHEAD FROM 12,515' FS 3540 PSI,2.6 BPM AT 3650 PSI WOB 0.9K, ROP 45 FPH • • WI-1/1A/OA=29/679/339 PSI t • ECD=10.19 PPG PVT=283 BBLS 07:05 - 07:40 0.58 DRILL P PROD1 STACKING WT,PU FOR BHA WIPER Printed 6/6/2011 1:36:54PM "orth America -ALASKA- BP Page 23 of 23 Operation Summary Report Common Well Name:C-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 5/7/2011 End Date: X3-00YT3-C(1,667,988.00) Project: Prudhoe Bay Site: PB C Pad 1 Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:40 - 07:45 0.08 DRILL P PROD1 DRILLED TO TOTAL DEPTH OF 12,555'MD, 8,942'TVD. (AN EXTRA 5'FOR COMPRESSION)PU WT 54K, PU 50'THEN TAG TO VERIFY WE DRILLED TO AT LEAST 12,550'MD. 07:45 - 10:20 2.58 DRILL P PROD1 TAG BOTTOM @ 12,552'POOH TO TIE IN 12,160'PULLING HEAVY RIH AND THEN BACK THROUGH TO CLEAN IT UP _ 11,750' 10:20 10:30 0.17 DRILL P PROD1 0' H - � PRPULLED T09810',JOG IN HOLE THEN POOH TO CASING TO OPEN THE EDC 10:30 - 11:15 0.75 DRILL I P PROD1 OPEN EDC ABOVE WINDOW AND BRING UP PUMPS UP TO 4.1 BPM TO JET HOLE CLEAN. I RUN BACK IN HOLE T/9,870'MD(EDC—10' BELOW WINDOW). RECIPRICATE PIPE THROUGH WINDOW AND IN 7"CSG. APPROX.GAL SIZED BUCKET OF PEBBLE-SIZED, ROUNDED CUTTINGS RETURNED AFTER BOTTOMS UP CIRCULATION. CLOSED ECD. 11:15 - 11:30 0.25 DRILL P PROD1 RIH THROUGH WINDOW TO TIE-IN DEPTH, RA TIE-IN. I CORRECT DEPTH+6' 11:30 14:30 3.00 I DRILL P PROD1 RIH,WT TRANSFER ISSUES STARTING AT 1 11,570'MD ALL THE WAY TO TD 114:30 - 15:00 ' 0.50 1 DRILL P PROD1 TAG TD AT 12,552'MD/8,942'TVD START _ LINER PILL W/TORQLESS BEADS 15:00 - 16:25 1.42 DRILL i P PROD1 58 BBLS, LINER PILL AT THE BIT,LET 2 BBLS OUT REDUCE RATE AND POOH LAYING IN _ 16:25 - 16:40 0.25 DRILL P + " PROD1 PULLED INTO CASING CLEAN AT MIN RATE, j CIRC LAST OF BEAD PILL OUT 16:40 - 17:00 0.33 DRILL P I PROD1 IN CASING SHUT DOWN THE PUMP TO FLOW i _ CHECK WELL BEFORE POOH 17:00 - 17:15 0.25 DRILL P I PROD1 POOH 17:15 - 17:20 0.08 DRILL P PROD1 STOP FOR WELL CONTROL DRILL 17:20 - 19:45 2.42 ' DRILL P I PROD1 POOH TO 9,177'MD TO PAINT 9,100'MD EOP FLAG. STOP @ 6300'MD&FLAG EOP. 3.69 BPM/3750 PSI.PUW=29K. POH TO 100'MD,FLOW CHECK&CLOSE 1 EDC. I I CALIBRATE MICRO MOTION. 1 ; PUMP SLACK OUT OF COIL. 19:45 - 20:00 0.25 DRILL l P I i PROD1 SET BACK INJECTOR&BLOW DOWN I I i COILTRAK. .20:00 - 20:30 0.50 i DRILL ! P I I PROD1 L/D BHA. ——— --+ --T_ __ 20:30 - 21.00 0.50 P PROD1 PJSM F/MM CALIBRATION&SLB CHAIN INSPECTION. 21:00 - 21:30 0.50 DRILL - P PROD1 CALIBRATE MM-IN DENSITY-OK. INSPECT CHAIN. 21:30 - 21:45 0.25 DRILL P 1 PROD1 DISCONNECT BHI UQC 21:45 - 23:30 1.75 7 DRILL P I 1 PROD1 PUMP OUT E-LINE.CUT 160 OF WIRE. 23:30 - 00:00 0.50 DRILL P PROD1 R/U TO PUMP 3/4"BALL FOR GAUGE BALL RUN&ENSURE NO BIRDS NESTS. I Printed 6/6/2011 1:36:54PM • North America -ALASKA- BP Page 1 of 8 Operation Summary Report Common Well Name:C-42 AFE No Event Type: COM-ONSHORE(CON) Start Date: 5/18/2011 End Date: 5/28/2011 X3-00YT3-C(1,078,066.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor: NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase ' Description of Operations (hr ) (ft) 5/22/2011 100:00 - 01:30 1.50 CASING I'', P RUNPRD CONTINUE TO R/U TO PUMP 3/4"BALL. I I PUMP:3/4"GAUGE BALL FOR RUN TO ENSURE NO BIRDS NESTS. 101:30 - 01:40 0.17 CASING P RUNPRD RECOVER BALL. 01:40 - 02:00 0.33 CASING ! P RUNPRD LOAD BTT TOOLS TO RIG FLOOR. 02:00 - 02:15 0.25 CASING P RUNPRD CUT OFF CC AND 17'OF 2-3/8"COIL TBG. 02:15 - 03:00 0.75 CASING P RUNPRD INSTALL CC&PT TO 35000#/3500 PSI. 03:00 - 04:15 1.25 CASING P RUNPRD PJSM.R/U TO RUN LINER. 04:15 - 11:00 6.75 CASING P RUNPRD RUN 2-7/8"X 3-3/16"X 3-1/2"LINER PER TALLY: GUIDE SHOE, FLOAT COLLAR,1 FULL JOINT OF 2 7/8", FLOAT COLLAR,2 7/8"PUP AND LATCH COLLAR,2 7/8"PUP, STAGE COLLAR,66 JTS(2097.25')2 7/8"LINER,2 7/8" MARKER JOINT,XO,29 JTS(898.61')3 3/16" LINER,XO,1 JOINT 3 1/2"LINER,X NIPPLE,3 1/2"PUP, BTT GEN 2 DEPLOYMENT SLEEVE W/4"GS PROFILE. ALL FULL JTS HAVE CEMENTRALIZERS. CONTACTED AOGCC TO GIVE NOTICE OF UPCOMING BOP TEST. RUNPRD MU SELRT TO LINER ASSEMBLY. 1100 12:30 1 1.50 CASING P LY.i' —_-_-__ 12:30 14:00 1.50 CASING P RUNPRD RIH WITH LINER ASSEMBLY TO WINDOW FLAG DEPTH. PUW=34K. CORRECT TO FLAG DEPTH BY 10'. CONTINUE TO RIH WITH ASSEMBLY. 14:00 - 00:00 10.00 CASING P RUNPRD ,PROBLEMS: RIH AT 11,300'. PRIMARY TROUBLE IS STACKING OUT. WORK DOWN 1 1 (FROM 11,300'- 11,500'AND 11,600'-11,665'. PUMP 1-2.5 BPM/1200-2000 PSI. WORK PIPE AND FLOW RATES.CONTACT TOWN ENG AND DISCUSS STATEGY. PUMP 40 BBLS 2% KCL FOLLOWED BY 40 BBLS NEW MUD- POSITIVE RESULTS DISPLAYED BY ROP INCREASE.CONTINUE TO WORK PIPE DOWN FROM 11,665'MD. CONTACT TOWN ENG AND DISCUSS PUMPING SERIES(5)OF 20 BBLS 2%KCL FOLLOWED BY 20 BBLS NEW MUD. MADE 100'OF HOLE IN 1-1/2 HRS TO 12,281' MD.-GOOD RESULTS.WORK PIPE AND FLOW RATES AS NEEDED.ORDERED MORE NEW MUD. -CONTACTED AOGCC REGARDING DIFFICULTY WITH LINER RUN AND THAT IT MAY IMPACT REQUIRED BOP FUNCTION TEST. PERMISSION GIVEN TO DELAY FUNCTION TEST PAST MIDNIGHT SINCE FULL BOP TEST WILL BE CONDUCTED AS SOON AS LINER IS LANDED AND CEMENTED. 5/23/2011 00:00 - 12:45 12.75 CASING P RUNPRD CONTINUE TO WORK PIPE FROM 12,280'TO 12,516'MD WITH 10K DOWN WEIGHT(FOR LINER SETTING PURPOSES). OBSERVED FLAG AT CALCULATED TD DEPTH WITH -0.8 BPM/1000 PSI TO 2.45 BPM/2355 PSI. ALTERNATED BETWEEN KCL WITH MUD SWEEPS AND THEN CIRCULATED FRESH MUD WITH LUBES ALL THE WAY AROUND. PUWATTD4IK. Printed 6/6/2011 1:37:21 PM North America -ALASKA- BP Page 2 of 8 • Operation Summary Report Common Well Name:C-42 AFE No Event Type:COM-ONSHORE(CON) Start Date:5/18/2011 End Date:5/28/2011 X3-00YT3-C(1,078,066.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor: NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00©72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:45 13:30 0.75 CASING P RUNPRD DROP 5/8"BALL AND CIRCULATE DOWN. BEGIN CIRCULATION AT 2 BPM, SLOW TO.6 • BPM. BALL ON SEAT AT 43.2 BBLS AWAY. CONTINUE TO PRESSURE UP TO 4500 PSI TO :SHEAR AND RELEASE RUNNING TOOL FROM LINER. PUW FROM LINER RELEASE 34K. • SET DOWN 10K; LINER SHOE AT 12,524' IN COMPRESSION,12,514'AT NEUTRAL. ESTIMATE LINER TOP AT 9396'. 13:30 - 15:30 2.00 CEMT P RUNPRD DISPLACE WELL TO KCL AND CIRCULATE TO CONDITION HOLE AT 2.3 BPM,1900 PSI ICP, 1400 PSI FCP AT 2.3 BPM. IN AND OUT RATES GOOD. CEMENTERS RIGGING UP. CONDUCT PJSM ON CEMENT JOB. 15:30 - 18:00 2.50 CEMT P RUNPRD CEMENT 2 7/8"PRODUCTION LINER -BYPASS REEL FILTERS. -ESTABLISH CIRCULATION RATE OF 1.5 BPM, 560 PSI. PRIME CEMENT UNIT. -BATCH 35 BBLS 15.8 PPG LINER SLURRY AT 1615 HRS. SEND SAMPLE TO LAB. -PUMP 5 BBLS KCL, PT LINES TO 5000 PSI. -PUMP 33 BBLS CEMENT,1.3 BPM,3600 PSI. • -LINE UP RIG PUMP AND PUMP 100 BBLS 2#/BBL BIOZAN,2.5 BPM,1730 PSI. • -SLOW DOWN PUMP TO 1.5 BPM WITH CEMENT AT LINER RUNNING TOOL. 1-SPEED PUMP BACK UP TO 2.0 BPM; 1 • CEMENT AT SHOE AT 78.7 BBLS AWAY -P/U 13',BREAKOVER WT 40K -OPEN BAKER CHOKE,STACK 10 K INTO LINER DEPLOYMENT SLEEVE. CLOSE BAKER CHOKE. EXHAUST 2 BBLS CEMENT FROM COIL, PUMP 3 BBLS,1.5 BPM(89.6 BBLS AWAY). PRESSURE UP TO SHEAR WIPER PLUG AT 3950 PSI AT.4BPM, -PUMP 19.3 BBLS TO BUMP WIPER PLUG. PRESSURE UP TO 3200 PSI SLOWLY;33.3 BBLS RETURNED -BLEED OFF, OPEN BAKER CHOKE, CHECK FLOATS. FLOATS HOLDING. PRESSURE UP 1000 PSI, UNSTING. PUMP AT.5 BPM TO CONTAMINATE WITH BIOZAN JUST ABOVE LINER TOP. -CIP @ 1800 HRS; CALCULATED TOC AT 9600' 18:00 - 22:00 4.00 CEMT P RUNPRD PUMP 2#/BBL BIOZAN WHILE SLOWLY PULLING UPHOLE TO CONTAMINATE CEMENT TO 3280'. STOP PULLING UP HOLE (5 MINUTES,TOWN ENG OK'D). CONTINUE TO PUMP,TAKING RETURNS TO PIT WITH CITRIC ACID.CONTINUE PUMPING OUT OF HOLE. SLIGHT CEMENT CONTAMINATED KCL TO SURFACE NOTED. FLOW CHECK AT SURFACE-OK. L/D SELRT. 22:00 - 23:00 1.00 BOPSUR P WHDTRE JET STACK WITH SWIZZLE STICK.SERVICE TREE. -SERVICE/GREASE TREE VALVES Printed 6/6/2011 1:37:21 PM 1 `forth America -ALASKA- BP Page 3 of 8 Operation Summary Report Common Well Name: C-42 AFE No Event Type: COM-ONSHORE(CON) Start Date: 5/18/2011 End Date: 5/28/2011 X3-00YT3-C(1,078,066.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor: NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase ' Description of Operations (hr) (ft) 23:00 - 00:00 1.00 r BOPSUR ' P ! WHDTRE R/U&TEST BOPE:TEST WITNESS WAIVED j I BY LOU GRIMALDI/AOGCC. TEST MASTER&SWAB VALVES 250 PSI LOW /3500 PSI HIGH PRESSURE-NO GO ON ' FIRST ATTEMPT. INSPECT AND FUNCTION TEST RAMS. _i__ I TEST PER BP/AOGCC REGULATIONS. 5/24/2011 00:00 - 13:30 13.50 BOPSUR P WHDTRE CONTINUE BOPE TEST: CONDUCT ACCUMULATOR FUNCTION AND DRAW DOWN TEST. 1 200 PSI INCREASE=29 SECONDS. I FULL SYSTEM PRESURE= 116 SECONDS. FUNCTION CHOKE VALVES TO ENSURE FLUID PACKED; RE-TEST MASTER AND SWAB SALVE,GOOD TEST. 13:30 - 18:00 4.50 EVAL P OTHCMP I MOBILIZE WORKSTRING TO RIG FLOOR. PRESSURE TEST BPV TO 250 PSI LOW AND 3500 PSI HIGH. PJSM ON MAKING UP BHA ' ' AND MU CNL TOOL. MU BHA:2.3"MILL, MOTOR,2-JTS 1.25"WORK STRING,MEMORY LOGGING CARRIER, CIRC SUB, DISCONNECT, 108-JTS 1.25"WORK STRING, DISCONNECT, DUAL BPV,2-JTS PI-16 WORK STRING, T SWIVEL,CTC. — - — - - 18:00 - 21:00 3.00 EVAL P ii OTHCMP RIH WITH CLEANOUT AND LOGGING BHA ON P COIL T09,100'MD. 21:00 - 00:00 3.00 1 EVAL OTHCMP PUW=28K,SOW=15.5K LOG DOWN @ 30 FPM W/MCNL-GR-CCL FROM 9,100'TO 12,408'MD. PUMP RATE 1.4 BPM/2350 PSI. TAGGED 77'HIGH.ATTEMPT TO DRILL OFF W/UP TO 7.5K WOB. WORK ON BOTTOM SEVERAL TIMES AND 1 ATTEMPT TO DRILL OFF. NO-GO.CALL TOWN ENG.AGREE TO LOG UP WHILE SPOTTING PERF PILL. WILL CALL WHEN OOH AND LOGS ANALYZED. f —_ LOG UP @ 1.4 BPM/2350 PSI. 5/25/2011 00:00 - 01:30 1.50 EVAL P OTHCMP LOG UP FROM 12,408'TO 8,500'MD TO I ENSURE TIE-IN/CORRELATION -LAY IN PERF PILL ON LOG UP RUN. 01:30 - 05:00 , 3.50 EVAL P OTHCMP POH W/CLEANOUT/LOGGING BHA. _ L/D LOGGING TOOLS. 05:00 - 09:00 I 4.00 EVAL P OTHCMP INTERPRET LOG AND CORRELATE TO PDC LOG. CORRECT PBTD TO 12,492'WITH LINER TOP SET AT 9,381'. ATTEMPT TO TEST THE LINER LAP TO 2400 PSI SEVERAL TIMES, UNSUCCESSFUL DUE TO PRESSURE BLEED OFF. BLEED ANNULUS TO CHECK IF GAS WILL COME BACK OR FLUID PACKED. FLUID PACKED. ATTEMPT ONE MORE TIME, FAILED. NOTIFY BAKER TO DEPLOY LINER ' TOP PACKER. 09:00 - 10:00 1.00 PERFOB P OTHCMP WORK WITH SLB PERFORATORS TO CONFIRM SET DEPTH PER LOG. PJSM ON RUNNING PERF GUNS I Printed 6/6/2011 1:37:21 PM iw North America -ALASKA- BP Page 4 of 8 Operation Summary Report Common Well Name: C-42 AFE No Event Type: COM-ONSHORE(CON) Start Date: 5/18/2011 End Date: 5/28/2011 X3-00YT3-C(1,078,066.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor: NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 10:00 - 15:00 5.00 PERFOB P (ft) OTHCMP MU 2"6-SPF PERF GUNS PER RUNNING TALLY. MU FIRING HEAD,DISCONNECT,XO, 'WORK STRING,XO,DISCONNECT,DBPV,XO, 2 JTS PH6,XO,SWIVEL,XO,CTC. PERFORM KICK WHILE TRIPPING DRILL W/ PERF GUNS IN HOLE. 15:00 - 17:45 2.75 PERFOB P OTHCMP RIH WITH PERFORATION ASSEMBLY ON COIL. MECHANICAL AND CTDS DEPTHS ON TRACK AT 7396'. PUW AT 9000'30K. PUMP RATE:0.34 BPM/154 PSI.RIH TO PBTD @ 12460.7'MD. 17:45 - 18:00 0.25 PERFOB P ' OTHCMP TAG @ CDTS 12,451'MD.EIM 9053.9, MECHANICAL COUNTER 9063'MD.WT CHECK @ 12350'MD.38K.RIH WT 18K. 18:00 - 19:10 1.17 PERFOB P OTHCMP P/U&TAG AGAIN @ 12450'MD. DISCUSS TIE-IN.CALL TOWN ENG,AGREE TO I USE T.O.L.FOR TIE-IN FOR SHOOTING DEPTH. 19:10 - 20:00 0.83 PERFOB P OTHCMP TAG PBTD AND CORRECT TO 12,482'MD.PER T.O.L.9406'MD. P/U TO 12460.7 TO FIRE GUNS. 20:00 - 20:30 0.50 PERFOB P r OTHCMP PUMP FIRING SEQUENCE.FIRE GUNS/ SLOWLY PICK UP. 20:30 - 21:30 j 1.00 PERFOB P OTHCMP LOST ALL RETURNS. IMMEDIATE 3 BBL LOSS TO CATCH FLUID. PUMPING 1 TO 1, POH. 21:30 - 23:00 1.50 PERFOB P OTHCMP POH,STOP @ 9300'FLOW CHECK- 0.3 BBLS TO CATCH.HOLE STABLE. POH TO BHA.1 BPM/800 PSI. 23:00 - 00:00 1.00 PERFOB P OTHCMP PJSM.R/U&UD 2 JTS OF PH-6 STAND BACK 1-1/4"CS HYDRIL DRILL PIPE. HOLE IS STABLE. 5/26/2011 00:00 - 01:00 1.00 PERFOB P OTHCMP CONTINUE STANDING BACK 1-1/4"CS HYDRIL DRILL PIPE. 01:00 - 05:00 ' 4.00 PERFOB P i OTHCMP UD SLB-2"PERF GUNS.ALL SHOTS FIRED. 05:00 - 07:00 2.00 PERFOB P • OTHCMP CLEAR&CLEAN RIG FLOOR,OFFLOAD PERF GUNS. MOBILIZE LINER TOP PACKER TO RIG FLOOR. PREP FOR RUNNING LINER TOP PACKER. 07:00 - 10:45 I 3.75 I CASING P RUNPRD MU LINER TOP PACKER. RIH WITH ASSEMBLY. Printed 6/6/2011 1:37:21 PM • North America -ALASKA- BP Page 5 of 8 Operation Summary Report Common Well Name:C-42 AFE No Event Type: COM-ONSHORE(CON) Start Date: 5/18/2011 End Date: 5/28/2011 X3-00YT3-C(1,078,066.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor: NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:45 - 17:00 6.25 CASING P RUNPRD SLOW RUNNING SPEED. INITIAL TAG OF LINER TOP DEPLOYMENT SLEEVE AT 9,410' COIL DEPTH. PU, RUN BACK DOWN TO CONFIRM ENTRY AT 9410'COIL DEPTH. OPEN BAKER CHOKE,SET DOWN INTO DEPLOYMENT SLEEVE TO NO GO ASSEMBLY. INITIAL PUW AT 34K, ROSE TO 42K. STOP PICKING UP. SET BACK DOWN WITH NO PROBLEM. PICK UP AGAIN WITH RISE IN PUW. BAKER TECH CONTACT FIELD TECH,WSL CONSULT WITH FIELD SUPERINTENDENT. -WORK STRING TO 50K PU, NO SUCCESS. ATTEMPT TO CONTINUE PICKUPS TO 50K QUICKLY TO SEE IF POSSIBLE DEBRIS WILL BREAKAWAY. PU AGAIN AND BROKE FREE. -PICK UP OUT OF DEPLOYMENT SLEEVE, DROP 5/8"BALL AND PUMP DOWN. ATTEMPT TO SEAT BALL SEVERAL TIMES. PUMP 1 1/2 it i I TIMES TUBING VOLUME WITHOUT SEATING BALL. MIX AND PUMP LL HI-VISPILL.U NO GO ON GETTING BALLON SEAT. 288 BBLS IN PITS. 17:00 - 19:00 2.00 CASING N DFAL 9,382.00 RUNPRD POH WITH ASSEMBLY FOR INSPECTION. CONDUCT PJSM ON FLOW CHECK, _ INSPECTING BHA. 19:00 - 19:15 0.25 - CASING N DFAL 9,382.00 RUNPRD FLOW CHECK WELL BEFORE BHA IN BOP 19:15 - 20:00 0.75 CASING 1 N 1 DFAL ! 9,382.00 RUNPRD STAND BACK INJECTOR. POH WITH BHA, 'INSPECT PACKER AND RUNNING TOOL. j ! RECOVERED RUNNING TOOL BUT MISSING LINERTOP PACKER ASSEMBLY FROM BHA. LINER TOP PACKER RUNNING TOOL SEALS WERE VISIBLY DAMAGED AND OUT OF POSITION. 5/8"BALL RECOVERED ON SEAT 'i BUT SHEAR PINS WERE INTACT AND HADN'T 'MOVED-EVIDENCE THAT BALL LANDED ON SEAT AFTER LINERTOP PACKER ASSEMBLY WAS GONE ENABLING US TO PUMP AROUND IT EVEN WITH BALL ON SEAT. SCRAPE MARKS NOTED ON COIL TUBING 6 FEET ABOVE COIL TUBING CONNECTOR WHEN LAYING DOWN BHA. 20:00 - 23:00 3.00 FISH N DFAL 9,382.00 RUNPRD TRANSPORT RECOVERED LINERTOP PACKER ASSEMBLY TO BAKER SHOP AND DEVELOP PLAN FORWARD FOR FISHING, CLEANOUT,AND RERUNNING. FISHING BHA AND OPS NOTES REVIEWED AND APPROVED BY RIG TEAM,SUPERINTENDANT GREG SARBER,AND WTL JOHN SMART. 23:00 - 00:00 1.00 FISH N DFAL 9.382.00 RUNPRD MAKE UP FISHING BHA-4"GS HYDRAULIC RELEASE SPEAR, RUPTURE DISK, HYDRAULIC DISCONNECT, OIL JAR,2EA WEIGHT BAR,INTENSIFIER, DUAL FLAPPER CHECK VALVE,XO,2EA 2-3/8"PH6,XO, LOCKABLE SWIVEL,XO, BOT CTC. Printed 6/6/2011 1:37:21 PM "Drth America -ALASKA- BP Page 6 of 8 Operation Summary Report Common Well Name: C-42 AFE No Event Type: COM-ONSHORE(CON) Start Date: 5/18/2011 End Date: 5/28/2011 X3-00YT3-C(1,078,066.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00©72.50ft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations 5/27/2011 00:00 - 00:45 1 0.75 FISH N DFAL 9,382.00 I RUNPRD I CONTINUE MAKE UP FISHING BHA-4"GS 1HYDRAULIC RELEASE SPEAR,RUPTURE DISK, HYDRAULIC DISCONNECT, OIL JAR, • 2EA WEIGHT BAR, INTENSIFIER,DUAL FLAPPER CHECK VALVE,XO,2EA 2-3/8"PH6, XO, LOCKABLE SWIVEL,XO, BOT CTC. FLUID LOSSES OVER LAST 4 HOURS LESS THAN 0.5 BPH 00:45 - 02:30 1.75 FISH N DFAL 9,382.00 RUNPRD RIH W/FISHING ASSEMBLY-85-100 FPH. I PUMPING.45 BPM,-150 PSI. 02:30 - 02:45 ! 0.25 FISH N i DFAL 9,382.00 RUNPRD ESTABLISH BASELINE PARAMETERS. PU- 34K, SO-21K @ 9300'CTMD. 0.43 BPM-150 PSI. RIH AND TAG UP AT 9393'CTMD. 1 .' BRING PUMPS TO MIN RATE. 1 SLACK OFF 4K. PU WITH NO OVERPULL. I I SLACK OFF AGAIN WITH 5K AND PICK UP. OVERPULL 12K TO 46K CTW AND WAIT FOR JARS TO FIRE. 3.5 MINUTES AND JARS i I FIRED. PU TO 50K COIL WEIGHT-STILL NOT FREE. SLACK OFF 5K-SAW-1 FOOT DOWNWARD MOVEMENT BEFORE HANGING UP AGAIN. CONTINUE TO SLACK OFF TO 12K COIL TUBING WEIGHT(9K STACKED ON FISH). PU TO 60K COIL WEIGHT(26K OVERPULL)- 1 I 1.5 MINUTES AND JARS FIRED. I I I PULL TO 62K AND FISH CAME FREE. LINE UP TO PUMP DOWN BACKSIDE WHILE POOH. 02:45 - 05:00 2.25 FISH N DFAL 9,382.00 RUNPRD POH WITH FISHING BHA @ 70-80 FPM. HOLDING-350-400 PSI ON ANNULUS TO AVOID SWABBING WITH 3.7"OD LINER TOP PACKER ASSEMBLY. 05.00 - 05:30 0.50 • FISH N DFAL 9,382.00 RUNPRD LD FISH. PACKER SEALS LOOK NEW,SEAL ASSEMBLY SEALS SCARRED,PACKED OFF DEBRIS IN GAPS IN ASSEMBLY. 05:30 - 09:30 4.00 CASING ' N 1 DFAL : 9,382.00 RUNPRD CONSULT WITH TOWN ON CLEANOUT BHA. BAKER REP TO PU BHA FROM DEADHORSE. REP ON LOCATION. MOBILIZE BHA TO II FLOOR,COMPLETE BHA SUMMARY. PJSM ON MU OF BHA. 09:30 10:00 I, 0.50 CASING N DFAL 9,382.00 RUNPRD MU CLEANOUT BHA:2 3/8"POLISH MILL, EXTENSION, NO GO SUB WITH BRASS I TATTLETALE,XO, HCC STRING MILL, EXTREME MUD MOTOR, DUAL CIRC SUB, HIGH LOAD HYDRAULIC DISCONNECT, BOWEN JAR INTENSIFIER, DUAL FLAPPER CHECK VALVE, XO,2-2 7/8"PH6 JTS,XO, LOCKABLE SWIVEL,XO,CTC 10:00 - 12:40 2.67 CASING N DFAL 9,382.00 RUNPRD RIH WITH CLEANOUT BHA TO 9200'. PUW 33K,1710 PSI AT 2.5 BPM. DOWN ON PUMPS. CONTINUE TO RIH,TAG AT 9411'. PU 10', PUW 34K. COME ON WITH PUMPS TO 2.5 BPM,1695 PSI. Printed 6/6/2011 1:37:21 PM "orth America -ALASKA- BP Page 7 of 8 • Operation Summary Report Common Well Name: C-42 AFE No Event Type: COM-ONSHORE(CON) Start Date: 5/18/2011 End Date: 5/28/2011 X3-00YT3-C(1,078,066.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49:42 4/10/1993 00:00 @72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:40 - 13:30 0.83 CASING N DFAL 9,382.00 RUNPRD WITH PUMPS AT 2.5 BPM,RIH AT 1 FPM. 2530 PSI AT 2.6 BPM AT 9411'. PRESSURE BEGAN TO RISE AND OUT RATE FELL OFF WITH j LANDING OF NO GO. PU AND COME OFF PUMPS. ESTABLISH CIRCULATION AT 2.0 BPM, RE-ENTER DEPLOYMENT SLEEVE;2400 PSI AT 2.0 BPM. PICK BACK UP TO 9408', ESTABLISH PUMP RATES AT 2.0 BPM,1320 PSI. RUN INTO DEPLOYMENT SLEEVE AT 1 FPM. 13:30 - 15:45 2.25 CASING N LDFAL 9,382.00 RUNPRD POH WITH NO ISSUES. FLOW CHECK AT SURFACE. CONTINUE TO POH. PJSM ON LD • AND PU OF BHA. 15:45 - 16:30 0.75 CASING ! N DFAL ! 9,382.00 RUNPRD LD CLEANOUT BHA. STRING MILL AND - POLISH MILL IN GAUGE. BRASS TATTLETALES INDICATE THAT CLEANOUT � POLISH MILL ENTERED INTO DEPLOYMENT SLEEVE. DRIFT CTC WITH 3/4"BALL. 16:30 - 17:30 1.00 CASING N DFAL 9,382.00 RUNPRD MU LINER TOP PACKER BHA:SEAL ASSEMBLY, LOCATOR,3 EACH 2 7/8"TUBING PUPS FOR SPACEOUT,4"GS RETRIEVING PROFILE AND 45"KB PACKER,4"GH RUNNING TOOL, HYDRAULIC DISCONNECT, i XO,2 JTS 23/8"PH6 WORK STRING,X0,CTC 17:30 - 19:15 1.75 CASING j N DFAL 9,382.00 RUNPRD RIH WITH LTP ASSEMBLY ON COIL TO 6,700' CTMD 19:15 - 19:45 0.50 CASING P , RUNPRD KICK WHILE TRIPPING DRILL AND AFTER ACTION REVIEW 119:45 - 20:15 0.50 CASING N DFAL9,382 00 RUNPRD CONTINUE RIH WITH LINER TOP PACKER ASSEMBLY. 30 FPM,21K COIL WEIGHT. 9,382.00 - � � RUNPRD TAKE PARAMETERS. 35K UPWEIGHT,21.5K 20:15 20:30 !I 0.25 CASING N DFAL DOWNWEIGHT. 0.28 BPM,77 PSI. SLACK OFF LOOKING FOR PRESSURE INCREASE. 9410.5 SAW PRESSURE INCREASE TO 150 • PSI AS STINGER ENTERS DEPLOYMENT SLEEVE. SHUT DOWN PUMPS AND SLACK OFF TO 9419.8 AT COIL WEIGHT OF 10K(11K SLACKED OFF). PICKUP AND CALL BREAKOVER AT 9414.7. CONTINUE UP 1.4 FEET TO 9413.3 FOR SET DEPTH. PU TO 9380.8 TO POSITION COIL FOR BALL DROP. 20:30 - 21:00 0.50 CASING N ' RUNPRD 'PRESSURE PUMPS TO 2900 AND LAUNCH BALL. CHASE BALL AT 1.9 BPM,830 PSI. BALL OVER GOOSENECK AT 26 BBLS ' ' PUMPED. AT 35 BBLS AWAY,(COIL VOLUME 58)SLOW PUMPS TO.8 BPM,240 PSI. BALL ON SEAT AT 44.8 BBLS PUMPED. I PRESSURE CLIMBED TO 550 PSI AND SHUT DOWN PUMPS. SET DOWN 10K. PICK UP 1.5'. PRESSURE UP TO 2000 PSI. CONFIRM SET. PICK UP TO NEUTRAL. TOP OF LINER TOP PACKER @ 9,383.24'MD. Printed 6/6/2011 1:37:21 PM • - "orth America -ALASKA- BP Page 8 of 8 Operation Summary Report Common Well Name:C-42 AFE No Event Type:COM-ONSHORE(CON) Start Date:5/18/2011 End Date: 5/28/2011 X3-00YT3-C(1,078,066.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.: NORDIC 1 I Spud Date/Time: Rig Release: 5/28/2011 Rig Contractor:NORDIC CALISTA UWI: Active Datum:49: 42 4/10/1993 00:00©72.50ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) (ft) 21:00 - 23:00 2.00 CASING N RUNPRD PRESSURE TEST LTP TO 250 PSI LOW&2400 PSI HIGH PRESSURE. LEAK DISCOVERED @ PACKOFFS. PRESSURE UP PACK OFFS. RETEST-OK. CALL J SMART OK TEST. RELEASE FROM LT PACKER. 23:00 - 00:00 1.00 CASING N RUNPRD FLOW TEST. POH TO 4100'MD. 5/28/2011 00:00 01:00 1.00 CASING P RUNPRD CONDUCT CATAGORY 3 INSPECTION ON HCR CONTINUE TO POH.@ 500'FLOW CHECK. POH. 01:00 - 02:00 1.00 CASING P RUNPRD L/D BHA&RUNNING TOOL. 02:00 - 03:15 1.25 WHSUR P POST M/U NOZZLE&SWIZZLE STICK. RIH TO 2500'MD. LRS—LOAD COIL W/60 BBLS OF DIESEL 03:15 - 03:40 0.42 WHSUR P POST POH LAYING IN DIESEL 03:40 - 04:00 0.33 WHSUR '} P POST FLOW CHECK WELL @ 500'MD.POH TO SURFACE. 04:00 - 05:30 1.50 WHSUR P POST OOH.LID BHA. BLOW BACK COIL. PULL INJECTOR OVER. VALVE CREW ON { LOCATION. MOBILIZE TOOLS WHILE BLOWING DOWN. 05:30 - 06:00 0.50 h WHSUR P POST PJSM ON RU OF LUBRICATOR,PRESSURE TESTING,SETTING BPV. 06:00 - 07:30 1.50 WHSUR P POST RU LUBRICATOR. RU TEST PUMP AND LINES. PRESSURE TEST LUBRICATOR TO 250 PSI LOW,3500 PSI HIGH. 07:30 - 08:00 0.50 WHSUR P POST TINSTALL BPV. RD LUBRICATOR. INSTALL NIGHT CAP 08:00 - 09:00 1.00 WHSUR P POST PRESSURE TEST AGAINST CLOSED MASTER AND SWAB TO VERIFY SECOND BARRIER. RD TEST EQUIPMENT 09:00 - 11:00 2.00 BOPSUR P ' POST SECURE BOP STACK. OPEN RAM DOORS AND INSPECT RAM BODIES. 11:00 - 16:00 5.00 BOPSUR P POST CONDUCT CATEGORY 3 HCR INSPECTION (REQUIRED BY JUNE 6) 16.00 - 18:00 2.00 BOPSUR P POST ND BOP,PREPARE TO MOVE RIG OFF C-42 RELEASE RIG @ 18:00 HRS. Printed 6/6/2011 1:37:21 PM VI r BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB C Pad C-42 - Slot 42 C-42A Survey: MWD Survey Report - Geographic 31 May, 2011 HUGHES Survey Report-Geographic . by I NTEQ 51.04* Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-42-Slot 42 Project: Prudhoe Bay TVD Reference: 49:42 4/10/1993 00:00 @ 72.50ft(generic drillinc Site: PB C Pad MD Reference: 49:42 4/10/1993 00:00 @ 72.50ft(generic drillinc Well: C-42 North Reference: True Wellbore: C-42A Survey Calculation Method: Minimum Curvature Design: C-42A Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY 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 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 ° Well C-42 API No 500292235700 Well Position +N/-S 0.00 ft Northing: 5,960,733.31 ft Latitude: 70° 17'56.588 N +E/-W 0.00 ft Easting: 664,137.33 ft Longitude: 148°40' 14.317 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore C-42A API No 500292235701 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 5/15/2011 21.59 80.99 57,655 Design C-42A — — Audit Notes: Version: Phase: ACTUAL Tie On Depth: 9,744.79 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 39.50 0.00 0.00 46.69 Survey Program Date: 5/31/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 532.11 9,744.79 1 : MWD-Standard(C-42) MWD MWD-Standard 9,789.20 12,552.00 MWD(C-42A) MWD MWD-Standard 5/31/2011 10:50:13AM Page 2 COMPASS 2003.16 Build 73 BAKER 0 p HUGHES Survey Report-Geographic INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-42-Slot 42 Project: Prudhoe Bay TVD Reference: 49:42 4/10/1993 00:00 @ 72.50ft(generic drillinc Site: PB C Pad MD Reference: 49:42 4/10/1993 00:00 @ 72.50ft(generic drillinc Well: C-42 North Reference: True Wellbore: C-42A Survey Calculation Method: Minimum Curvature Design: C-42A Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,744.79 73.61 46.73 8,969.76 1,283.21 1,492.93 5,962,048.73 665,601.78 70°18'9.207 N 148°39'30.788 W TIP 9,789.20 75.52 46.55 8,981.58 1,312.60 1,524.05 5,962,078.79 665,632.25 70°18'9.496 N 148°39'29.881 W KOP 9,818.18 72.29 43.10 8,989.62 1,332.34 1,543.68 5,962,098.95 665,651.44 70° 18'9.690 N 148°39'29.308 W 9,848.80 65.15 33.87 9,000.74 1,354.60 1,561.44 5,962,121.59 665,668.71 70° 18'9.909 N 148°39'28.790 W 9,886.42 66.48 22.07 9,016.20 1,384.84 1,577.48 5,962,152.18 665,684.08 70°18'10.206 N 148°39'28.322 W 9,918.24 73.32 11.02 9,027.16 1,413.43 1,585.91 5,962,180.94 665,691.88 70°18'10.487 N 148°39'28.077 W 9,946.36 80.94 1.14 9,033.43 1,440.64 1,588.77 5,962,208.20 665,694.15 70°18'10.755 N 148°39'27.993 W 9,980.20 84.68 347.36 9,037.69 1,473.95 1,585.40 5,962,241.43 665,690.05 70°18'11.083 N 148°39'28.091 W 10,010.58 83.38 335.44 9,040.86 1,502.54 1,575.79 5,962,269.80 665,679.82 70° 18'11.364 N 148°39'28.371 W 10,040.60 83.27 322.56 9,044.36 1,528.04 1,560.46 5,962,294.96 665,663.94 70°18'11.615 N 148°39'28.818 W 10,070.40 91.81 315.32 9,045.64 1,550.45 1,540.93 5,962,316.94 665,643.93 70° 18'11.835 N 148°39'29.387 W 10,100.60 91.44 309.76 9,044.79 1,570.85 1,518.70 5,962,336.85 665,621.25 70° 18'12.036 N 148°39'30.035 W 10,130.72 91.57 305.59 9,043.99 1,589.25 1,494.87 5,962,354.72 665,597.03 70°18'12.217 N 148°39'30.730 W 10,180.96 92.06 313.66 9,042.40 1,621.25 1,456.23 5,962,385.86 665,557.70 70° 18'12.532 N 148°39'31.857 W 10,210.70 91.32 318.30 9,041.52 1,642.62 1,435.58 5,962,406.78 665,536.59 70° 18'12.742 N 148°39'32.459 W 10,240.76 91.26 323.08 9,040.85 1,665.87 1,416.54 5,962,429.60 665,517.05 70°18'12.970 N 148°39'33.013 W 10,270.12 91.60 325.81 9,040.11 1,689.74 1,399.48 5,962,453.09 665,499.47 70° 18'13.205 N 148°39'33.511 W 10,307.56 90.98 329.53 9,039.27 1,721.37 1,379.46 5,962,484.27 665,478.77 70°18'13.516 N 148°39'34.094 W 10,354.86 91.54 332.97 9,038.23 1,762.82 1,356.72 5,962,525.21 665,455.13 70°18'13.924 N 148°39'34.757 W 10,389.60 94.45 337.01 9,036.41 1,794.25 1,342.06 5,962,556.31 665,439.79 70'18'14.233 N 148°39'35.185 W 10,419.66 93.32 340.87 9,034.38 1,822.23 1,331.28 5,962,584.05 665,428.41 70°18'14.508 N 148°39'35.499 W 10,450.32 91.29 344.65 9,033.14 1,851.48 1,322.21 5,962,613.10 665,418.69 70°18'14.796 N 148°39'35.763 W 10,480.36 90.80 348.47 9,032.59 1,880.69 1,315.23 5,962,642.14 665,411.08 70°18'15.083 N 148°39'35.967 W 10,514.06 90.40 351.70 9,032.24 1,913.88 1,309.43 5,962,675.19 665,404.55 70°18'15.410 N 148°39'36.136 W 10,547.40 88.83 354.41 9,032.47 1,946.97 1,305.40 5,962,708.19 665,399.80 70°18'15.735 N 148°39'36.253 W 10,578.58 87.26 356.03 9,033.53 1,978.02 1,302.80 5,962,739.17 665,396.53 70°18'16.041 N 148°39'36.328 W 10,614.70 90.40 359.29 9,034.27 2,014.09 1,301.33 5,962,775.20 665,394.27 70°18'16.395 N 148°39'36.371 W 10,638.80 92.30 0.44 9,033.70 2,038.19 1,301.27 5,962,799.28 665,393.68 70°18'16.632 N 148°39'36.373 W 10,668.52 93.01 2.12 9,032.32 2,067.86 1,301.93 5,962,828.97 665,393.70 70°18'16.924 N 148°39'36.353 W 10,698.58 93.62 5.43 9,030.58 2,097.80 1,303.91 5,962,858.94 665,395.02 70°18'17.219 N 148°39'36.296 W 10,728.28 93.75 8.68 9,028.67 2,127.21 1,307.55 5,962,888.42 665,398.01 70°18'17.508 N 148°39'36.189 W 10,756.00 90.71 10.21 9,027.60 2,154.53 1,312.09 5,962,915.83 665,401.96 70°18'17.777 N 148°39'36.057 W 10,789.69 92.98 15.41 9,026.51 2,187.36 1,319.55 5,962,948.81 665,408.70 70° 18'18.099 N 148°39'35.839 W 10,816.11 90.98 18.54 9,025.60 2,212.60 1,327.26 5,962,974.22 665,415.86 70°18'18.348 N 148°39'35.614 W 10,846.95 91.26 23.76 9,024.99 2,241.35 1,338.38 5,963,003.20 665,426.35 70°18'18.630 N 148°39'35.290 W 10,881.39 89.72 29.98 9,024.70 2,272.06 1,353.94 5,963,034.23 665,441.23 70°18'18.932 N 148°39'34.836 W 10,919.47 90.06 34.14 9,024.77 2,304.32 1,374.15 5,963,066.93 665,460.73 70° 18'19.250 N 148°39'34.246 W 10,946.99 88.71 40.38 9,025.07 2,326.21 1,390.80 5,963,089.18 665,476.90 70° 18'19.465 N 148°39'33.761 W 10,977.59 87.94 43.98 9,025.96 2,348.87 1,411.33 5,963,112.28 665,496.93 70°18'19.688 N 148°39'33.162 W 11,006.49 88.77 48.63 9,026.79 2,368.83 1,432.22 5,963,132.68 665,517.37 70° 18'19.884 N 148°39'32.553 W 11,037.55 89.75 54.24 9,027.19 2,388.18 1,456.49 5,963,152.56 665,541.21 70°18'20.074 N 148°39'31.845 W 11,077.89 92.92 58.66 9,026.25 2,410.46 1,490.09 5,963,175.57 665,574.31 70° 18'20.293 N 148°39'30.865 W 11,114.03 89.94 64.94 9,025.35 2,427.52 1,521.91 5,963,193.32 665,605.75 70° 18'20.461 N 148°39'29.937 W 11,154.73 89.02 72.28 9,025.72 2,442.35 1,559.78 5,963,208.98 665,643.28 70° 18'20.607 N 148°39'28.832 W 11,190.31 87.51 77.83 9,026.80 2,451.52 1,594.12 5,963,218.89 665,677.42 70° 18'20.697 N 148°39'27.831 W 11,219.43 88.49 82.30 9,027.82 2,456.54 1,622.78 5,963,224.53 665,705.96 70° 18'20.746 N 148°39'26.995 W 11,248.51 92.03 90.15 9,027.68 2,458.45 1,651.77 5,963,227.08 665,734.90 70° 18'20.765 N 148°39'26.150 W 11,278.79 92.89 97.88 9,026.38 2,456.34 1,681.93 5,963,225.62 665,765.09 70° 18'20.744 N 148°39'25.270 W 11,309.35 89.28 95.47 9,025.80 2,452.79 1,712.27 5,963,222.74 665,795.50 70°18'20.709 N 148°39'24.386 W 11,339.11 88.50 91.57 9,026.38 2,450.96 1,741.96 5,963,221.56 665,825.22 70° 18'20.691 N 148°39'23.520 W 11,369.17 90.80 87.17 9,026.56 2,451.29 1,772.01 5,963,222.55 665,855.25 70°18'20.694 N 148°39'22.643 W 11,399.25 90.95 81.65 9,026.10 2,454.22 1,801.93 5,963,226.13 665,885.10 70° 18'20.723 N 148°39'21.771 W 11,429.07 91.17 77.96 9,025.55 2,459.50 1,831.27 5,963,232.04 665,914.32 70° 18'20.775 N 148°39'20.915 W 5/31/2011 10:50:13AM Page 3 COMPASS 2003.16 Build 73 RA ER■ HUGHES Survey Report-Geographic 0 p INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-42-Slot 42 Project: Prudhoe Bay TVD Reference: 49:42 4/10/1993 00:00 @ 72.50ft(generic drillinc Site: PB C Pad MD Reference: 49:42 4/10/1993 00:00 @ 72.50ft(generic drillinc Well: C-42 North Reference: True Wellbore: C-42A Survey Calculation Method: Minimum Curvature Design: C-42A Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +EI-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 11,458.87 90.98 75.15 9,024.99 2,466.42 1,860.24 5,963,239.60 665,943.13 70°18'20.843 N 148°39'20.070 W 11,493.53 89.35 70.05 9,024.89 2,476.78 1,893.30 5,963,250.68 665,975.96 70° 18'20.945 N 148°39'19.106 W 11,529.15 89.79 66.87 9,025.16 2,489.86 1,926.43 5,963,264.48 666,008.79 70° 18'21.073 N 148°39'18.140 W 11,558.73 90.18 61.47 9,025.17 2,502.74 1,953.05 5,963,277.94 666,035.11 70°18'21.200 N 148°39'17.364 W 11,588.93 92.52 55.77 9,024.46 2,518.46 1,978.81 5,963,294.21 666,060.53 70°18'21.354 N 148°39'16.612 W 11,618.85 91.69 57.91 9,023.36 2,534.81 2,003.84 5,963,311.10 666,085.19 70° 18'21.515 N 148°39'15.882 W 11,649.17 93.22 63.76 9,022.06 2,549.57 2,030.28 5,963,326.43 666,111.30 70° 18'21.660 N 148°39'15.111 W 11,678.93 95.26 69.42 9,019.86 2,561.35 2,057.50 5,963,338.81 666,138.25 70°18'21.776 N 148°39'14.317 W 11,708.83 92.00 73.00 9,017.96 2,570.96 2,085.74 5,963,349.03 666,166.28 70° 18'21.870 N 148°39'13.494 W 11,738.85 89.88 75.49 9,017.47 2,579.11 2,114.63 5,963,357.81 666,194.98 70° 18'21.950 N 148°39'12.651 W 11,769.97 88.77 80.30 9,017.84 2,585.63 2,145.04 5,963,364.99 666,225.24 70°18'22.015 N 148°39'11.764 W 11,798.77 88.04 85.10 9,018.64 2,589.29 2,173.59 5,963,369.27 666,253.70 70°18'22.050 N 148°39'10.932 W 11,836.36 87.39 92.36 9,020.14 2,590.12 2,211.11 5,963,370.93 666,291.19 70°18'22.059 N 148°39'9.837 W 11,875,80 90.77 98.96 9,020.77 2,586.24 2,250.33 5,963,367.90 666,330.48 70°18'22.020 N 148°39'8.694 W 11,904.38 91.44 105.10 9,020.22 2,580.28 2,278.26 5,963,362.55 666,358.54 70°18'21.962 N 148°39'7.879 W 11,931.86 89.66 109.06 9,019.96 2,572.21 2,304.52 5,963,355.06 666,384.97 70°18'21.882 N 148°39'7.114 W 11,962.20 89.05 109.63 9,020.30 2,562.16 2,333.15 5,963,345.64 666,413.80 70°18'21.783 N 148°39'6.279 W 11,999.86 86.28 104.14 9,021.83 2,551.24 2,369.14 5,963,335.50 666,450.02 70°18'21.676 N 148°39'5.230 W 12,030.88 87.27 99.74 9,023.58 2,544.83 2,399.43 5,963,329.76 666,480.44 70°18'21.613 N 148°39'4.346 W 12,061.38 92.43 99.49 9,023.66 2,539.74 2,429.49 5,963,325.33 666,510.60 70°18'21.562 N 148°39'3.470 W 12,097.78 89.82 92.39 9,022.94 2,535.98 2,465.66 5,963,322.36 666,546.85 70°18'21.525 N 148°39'2.415 W 12,129.44 91.41 89.74 9,022.60 2,535.39 2,497.31 5,963,322.46 666,578.50 70°18'21.519 N 148°39'1.492 W' 12,159.50 91.48 87.02 9,021.85 2,536.24 2,527.35 5,963,323.96 666,608.51 70°18'21.528 N 148°39'0.616 W 12,200.02 90.71 85.43 9,021.07 2,538.91 2,567.77 5,963,327.51 666,648.86 70°18'21.554 N 148°38'59.437 W 12,230.22 89.51 80.15 9,021.01 2,542.70 2,597.72 5,963,331.96 666,678.72 70°18'21.591 N 148°38'58.564 W 12,259.72 89.11 73.40 9,021.37 2,549.44 2,626.42 5,963,339.33 666,707.26 70'18'21.657 N 148°38'57.727 W 12,293.08 91.10 67.30 9,021.31 2,560.65 2,657.82 5,963,351.22 666,738.41 70°18'21.767 N 148°38'56.811 W 12,331.20 93.90 59.95 9,019.64 2,577.56 2,691.91 5,963,368.86 666,772.12 70° 18'21.933 N 148°38'55.817 W 12,357.14 91.75 58.74 9,018.37 2,590.76 2,714.20 5,963,382.55 666,794.11 70° 18'22.063 N 148°38'55.167 W 12,410.24 90.86 51.27 9,017.15 2,621.19 2,757.66 5,963,413.92 666,836.89 70°18'22.362 N 148°38'53.899 W 12,439.02 92.46 47.08 9,016.32 2,639.99 2,779.42 5,963,433.19 666,858.24 70°18'22.547 N 148°38'53.264 W 12,472.88 90.49 51.97 9,015.45 2,661.95 2,805.16 5,963,455.71 666,883.49 70° 18'22.763 N 148°38'52.513 W 12,499.04 90.77 54.97 9,015.16 2,677.52 2,826.18 5,963,471.73 666,904.16 70°18'22.916 N 148°38'51.900 W 12,513.90 91.20 57.43 9,014.90 2,685.79 2,838.52 5,963,480.26 666,916.32 70°18'22.997 N 148°38'51.540 W 12,552.00 91.20 57.43 9,014.11 2,706.29 2,870.62 5,963,501.46 666,947.96 70° 18'23.199 N 148°38'50.604 W TD-2 7/8" 5/31/2011 10:50:13AM Page 4 COMPASS 2003.16 Build 73 TREE`- ' ' 4-1/16"CM/ WELLHEAD EL OR= 13-BAKER C PJC DRAFT KB. C-42 A SAFETY NG1 NELL ANGLE >70°@ 9681' ELEV = 72.50' BF.ELEV = 35.20' 1 1 I KOP= 6350' 2197' H 4-1/2"HES HXO SSSV NIP, ID=3.813" Max Angle= 95°@ 10679' Datum MD= 9485' ��i --- ,,, Datum_TVD= ----i810.SS hHESGAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG, 68#,L-80, ID=12.415" — 3238' 2 4239 4238 0 TGPDX DOME RA 16 06/14/11 1 6875 6847 25 TGPDX SO RA 20 06/14/11 BAKER 45 KB PATCH, ID=2.45"(06/12/11) —I 7171' -7206' TOP OF CMT(LNR SQZ 10/02/96) —I 8822' 0••• :��; 8494' —I9-5/8"X 7"BKR TIEBACK SLV,ID=? Minimum ID = 2.36" @ 9383' ,41 • 8502' —19-5/8"X 7"BKR H LNR TIEBACK PKR l'k • ••, 8545 H9-5/8"X 7"TM/TIEBACK SLV, ID=7.37" 45 KB LINER TOP PACKER ►• .4 •' . 8551' H9-5/8"X 7"TM/PKR/HGR, ID=6.18" 4 9-5/8"CSG,47#, L-80, ID=8.681" H 8814' •j j �4 • •• ► 9370' —4-1/2"HES X NIP,ID=3.813" •4 • •• • • 9380' H7"X 4-1/2"BKR S-3 PKR, ID=3.937" 9383' -145 KB LNR TOP PKR, ID=2.36" a i 9404' -4-1/2"HES X NIP,ID=3.813"(BEHIND LNR) ir1 9406' —13.70"BKR GEN II DEPLOY SLV, ID=3.00" ."I 9425' H4-1/2"HES XN NIP, MILLED TO 3.80"(4/20/11) 4-1/2"TBG, 12.64,L-80 BTC-M,.0152 bpf, ID=3.958" H 9437' / \--I 9437'_1-4-1/2"WLEG, ID=3.953" BEHIND 9458' H ELMD TT LOGGED 09/19/96 CT LNR 3-1/2"LNR,9.3#, L-80 STL, .0087 bpf, ID=2.992" — 9466' 1 1 9433' -13-1/2"OTIS X NIP, ID=2.812" TOP OF CEMENT --I 9600' 7"x 4-1/2"WHIPSTOCK(05/10/11) — 9790' 9466' H3-1/2"X 3-3/16"XO. ID=2.786" 7"LNR,29#, NT-80, .0371 bpf, ID=6.184" -•1-- -9790 ►•�v P" ►••• �•••• •• ••• PERFORATION SUMMARY ►�•: jam• MILLOUT WINDOW(C-42A) 9796'-9802' • REF LOG: SLB LEE TNN/TNF/GR/CCL ON 05/25/11? ►••• •••• ANGLE AT TOP PERF: 88'@ 11180' • ►•• fr Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 2" 6 11180- 11510 0 05/23/11 2" 6 11670- 12100 0 05/23/11 10366' -3-3/16"X 2-7/8"XO,ID=2.377" 2" 6 12350- 12460 0 05/23/11 / I 3-3/16"LNR, 6.204,L-80 TCII, .0076 bpf. ID=2.30" — 10366' I I PBTD(BKR LATCH COLLAR) H 12486' 2-7/8"LNR, 6.44, L-80 STL, .0058 bpf. ID=2.441" H 12524' V DATE REV BY COMMENTS ` DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/07/93 D-9 ORIGINAL COMPLETION WELL: C-42A 10/06/95 D-16 RWO PERMIT No:'2110380 04/29/11 NORDIC 1 CTD SIDETRACK(C-42A) API No: 50-029-22357-01 05/30/11 PJC DRLG DRAFT CORRECTIONS SEC 19,T11N,R140 481'FNL&1220'FEL 06/15/11 SRD/PJC SET PATCH(6/12/11) 06/16/11 ALH/PJC GLV C/O(6/14/11) BP Exploration (Alaska) SITAITE RIF AILASSEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION CODII►IISSIONT ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-42A BP Exploration (Alaska), Inc. Permit No: 211-038 Surface Location: 481' FNL, 1220' FEL, SEC. 19, T11 N, R14E, UM Bottomhole Location: 3101' FNL, 3602' FEL, SEC. 17, T11N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, '4/ Da - T. Seamount, Jr. C air DATED this I � d y of March, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED' t ALA OIL AND GAS CONSERVATION COMM" 'ON BAR ® � 201 4�'- PERMIT TO DRILL j...9// 20 AAC 25.005 �{I��;(t��( �f � 1 a.Type of work: lb.Proposed Well Class: ®Development Oil 0 Service-Winj 0 Single Zone A' h`a CD�1�ES• ❑ Drill ®Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbediflp?ORs Hydrates ❑ Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp Shale Gas 2. Operator Name: 5.Bond: ® Blanket 0 Single Well 11. Well Name and Number. BP Exploration(Alaska)Inc. Bond No. 6194193 PBU C-42A 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 12450' ND 8955'ss Prudhoe Bay Field/Prudhoe 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Bay Oil Pool Surface: ADL 028305 481'FNL, 1220'FEL, SEC. 19,T11N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 366'FSL,254'FEL, SEC. 18,T11N, R14E, UM May 1,2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3101'FNL,3602'FEL, SEC. 17,T11N, R14E, UM 2560 22970' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 72.50 feet 15.Distance to Nearest Well Open Surface: x- 664137 y-5960733 Zone- ASP4 GL Elevation above MSL: feet to Same Pool: 1265' 16.Deviated Wells: Kickoff Depth: 9800 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92 degrees Downhole: 3232 Surface: 2352 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling, Length MD TVD 1 MDD (including stage data) 4-1/4" 3-3/16"x 2-7/8" 62#/6A# L-80 TCII/STL 3040' 9410' 8838' 12450'` N 8955'ss 194 cu ft 15.8 ooa Class'G' ✓ 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 11103' 902¢' None 11103' 9025' None Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 20" 281 cu ft Arcticset 112' 112' Surface 3203' 13-3/8" 2313 cu ft PF"E"/489 cu ft Class'G' 3238' 3237' Intermediate 8778' 9-5/8" 421 cu ft Class'G' 8814' 8468' Production Liner 1596' 7" 421 cu ft Class'G' 8545'- 10141' 8256'-9020' Liner 1117' 4-1/2" Uncemented Slotted Liner 9984'- 11101' 9019'-9025' Perforation Depth MD(ft): Slotted:10248'-11068' Perforation Depth ND(ft): Slotted:9016'-9026' 20.Attachments: ❑ Property Plat ®BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis ®Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the fo -•oink` tru- •rrect. Contact Jacob Leemhuis,564-4989 Printed Name Jo A /'enA e Title Engineering Team Leader . i Prepared By Name/Number Signature Phone 564-4711 Date 94/'/i Elizabeth Barker,564-5674 Commission Use Only Permit To Drill API Number: Perm' Pipprovat Date: See cover letter for Number „:„?//02,13P50-029-22357-01-00 -)f II III other requirements Conditions of Approval: If box is checked,well maynot be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales: [K Other. 3 SO D f S` i3� es f Samples Req'd: Oyes 'No Mud Log Req'd: ❑Yes Gd'No A`Zgpa p5• Ann•jo., 7";:s1-6•&:..„) H2S Measures: Off Yes 0 No Directional Survey Req'd: 0/Yes 0 No a 3 7// /`' / Date Allir APPROVED BY THE COMMISSION ,COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 months from the date of approval(20 25.005(g)) ub�mitIn Duplicate ORIGINAL 310-1/ )0,4 To: Alaska Oil & Gas Conservation Commission From: Jacob Leemhuis b 0 p CTD Engineer Date: March 7, 2011 Re: C-42A Permit to Drill request Approval is requested for a permit to drill a CTD sidetrack from well C-42. Well C-42 was drilled in April 1993 as a horizontal producer(bonzai completion)targeting Zone 1 A& 1B. A RWO in Oct 1995 . replaced the tubing to address TxIA communication, and the liner lap was squeezed in 1996 to eliminate communication between the Sag River and the IA. Otherwise, the well produced fulltime until late 1997 when it began cycling. The well continued to cycle for the next 5 years with -50% on time until it developed TxIA communication. A tubing leak was identified at 7182' MD and was patched with an Eclipse patch from 7169-7204' in Nov 2002. The well was brought back online but continued to cycle until it developed TxIA communication again in May 2006. The leaking Eclipse patch was pulled and replaced with a 35' Baker KB patch in Aug 2007. The well was brought back online but cycled poorly with declining oil rates. The well is currently shut-in for high GOR. In January 6, 2011 a caliper was run through tubing and liner to deviation. The tubing is in average condition and the 7" liner(to deviation) is in good condition. The MIT-IA passed to 3,000 psi and MIT-OA passed to 2,000 psi in January 2011. The proposed plan for C-42A is to drill a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig on or around May 1, 2011. The existing 4-1/2" slotted liner will be plugged with cement down squeeze past whipstock and primary cement job. The sidetrack, C-42A, will exit the existing 7" liner and kick off in Ivishak Zone 2A and land in Zone 1 A. A schematic diagram of the proposed sidetrack is attached for reference. CTD Sidetrack Summary Pre-Rig Work Summary: (April 1, 2011) 1. F MIT-IA to 3000 psi; MIT-OA to 2000 psi. 2. S Pull 4-1/2" Baker KB Patch at 7,169'-7,204' 3. S Pull 2-7/8" HES NIP Reducer at 9,404' 4. S Dummy 4-1/2" x 7"TT WS drift 5. E Mill 4-1/2"HES XN NIP to 3.8" at 9,425' 6. W Test: PPPOT-T. Torque LDS 7. V PT MV, SV, WV 8. 0 Blind and bleed lines, remove well house, level pad 9. F Load& kill well prior to setting BPV. Freeze protect to 2,500' 10. V Set TWC —24 hrs prior to rig arrival ' Rig Work: (scheduled to bei )n May 1, 2011) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Run 4-1/2"x 7"TT Baker Whipstock, 180 degree orientation,to 9,790' 3. Down squeeze 21 bbls of 15.8 ppg cement past WS 4. Mill 3.8"window at 9,794' and 10' of rathole. Swap the well to Flo-Pro. 5. Drill Build: 4.25" OH, 271' (35 deg/100 planned) 6. Drill Lateral: 4.25" OH, 2,339' (12 deg/100 planned) with resistivity 7. Run 3-3/16"x 2-7/8" carbon liner leaving TOL at 9,410' 8. Pump primary cement leaving TOC at 9,500', 37.6 bbls of 15.8 ppg liner cmt planned rTD 9. Cleanout liner and MCNL/GR/CCL log ,2g flocs 10. Test liner lap to 2000 psi. 11. Perforate liner per asset instructions (1,200') 12. Freeze protect well, RDMO Post Rig: 1. Re-install well house and attach production lines 2. Pull BPV 3. Rerun 4-1/2" Baker KB Patch 4. Run GLV 5. RU PBGL 6. Test separator(1,200' of perfs) Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Geo Vis for milling window and drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 2,660' MD of 4-1/4" hole Casing Program: • 3-3/16"6.2 lbf, L-80 TCII—(9,410'-10,400')XO to 2-7/8"6.4 lbf, L-80 STL—(10,400' MD to 12450' MD). • A minimum of 34.6 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9,500' MD. . 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 92.00°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property—22,970'. • Distance to nearest well within pool— 1,265'to C-37B • Logging • MWD directional, Gamma Ray and resistivity will be run over all of the open hole section. • Cased hole GR/CCUMCNL logs will be run. Anti-Collision Failures • C-36A—70.12 ft. ctr-ctr, Currently producing Hazards • No planned crossings of faults. • There are no wells on DS2 with H2S > 100 ppm Reservoir Pressure • The reservoir pressure on C-42A is expected to be 3232 psi at 8,800' TVDSS. (7.06 ppg equivalent). • Maximum expected surface pressure with gas(0.10 psi/ft)to surface is 2352 psi. Jacob Leemhuis CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble • TREE= 4-1/16"CNV SAFETY TES: WELL ANGLE >70' 9684'. 4-1/2" ACTUATOR FMC = 135✓81'OTIS C-42 CHROM .KB.ELEV= 72.50' BF.ELEV= 35.20' KOP= 6350' Max Angle= 95 10152' 2197' H 4-1/2"HES HXO SSSVN, ID=3.813" Datum MD= 9486' 0 Datum TVD= 8800'SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,68#, L-80, ID=12.415" — 3238' -Al2 4239 4166 0 TGPDX DMY RA 0 05/21/06 LIIII 1 6875 6808 24 TGPDX DMY RA 0 05/21/06 Minimum ID =2.313" @ 9404' (HES) 2-7I8" REDUCING NIPPLE $------------- 7169'-7204' H4-1/7'BAKER KB PATCH, 0=2.45" S TOP OF CMT(LNR SQZ 10/02/96) —I 8822' 0+ 8494' 1H9-5/8"X 7"BKR TIEBACK SLV, ID=9 est1 8502' _--{9-5/8"X 7"BKR H LNR TIEBACK PKR el"0 ' 8545' 1-19-5/8"X 7"TMJ TIEBACK SLV,ID=7.37" 0 8551' H9-5/8"X 7"TWPKR/HGR, ID=6.18" 7 9-5/8"CSG,47#, L-80,ID=8.681" H 8814' 9370' H4-1/2"HES X NIP,ID=3.813" .. 9380' H7"X 4-1/2"BKR S-3 PKR, ID=3.937" 9404' H4-1/7 HES X NIP, ID=3.813" 9404' H 2-7/8"HES NIP REDUCER,ID=2.313" ' ! 9425' H4-1/7'HES XN NIP,ID=3.725" 4-1/2'TBG, 12.6#, L-80, .0152 bpf, ID=3.958" — 9424' / \_ 9437' H4-1/2"WLEG, ID=3.958" TM/OVERSHOT CT GUIDE, ID=4.00" 9970' S 9458' H ELMD TT LOGGED 09/19/96 S g_---- 9984' HT'X 4-1/2"TM/SS PKR,ID=4.00" 00000\---___ 9989' —4-1/2"PORTED JT 7"LNR,29#, NT-80, .0371 bpf, ID=6.184" — 10141' PERFORATION SUMMARY .\ REF LOG: SPERRY-SUN MWD/GR ON 04/25/93 - ANGLE AT TOP PERF: 59 @ 9330' ''. . Note:Refer to Production DB for historical perf data " -, ,'-. SIZE SPF INTERVAL Opn/Sqz DATE .. 1-9/16" 4 9330-9332 S 10/02/96 .. lipt 4-1/2" SLTD 10248-11068 0 05/05/93 " 4-1/2"SLTD LNR, 12.6#, 13-CR,.0152 bpf,ID=3.958" H 11068' 4-1/2"12.68 LNR SHOE, ID=3.958" H 11101' TD J-1 11103' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT metro ORIGINAL COMPLETION 06/10/06 TWS/PAG SET XXN PLUG WELL: C-42 1QI08/25 RINO 07/29/07 CJN/SV PULL XXN PLUG(07/26/07) PERMIT No: 1930500 11/24/02 JB/TP ECLIPSE PATCH SET 08/26/07 TEL/SV PATCH SET(08/23/07) API No: 50-029-22357-00 12/08/02 JNYTLH GLV C/O 09/17/07 PJC WBS CORRECTIONS SEC 19,T11 N,R14E,481'SNL&1220'WEL 05/21/06 TEL/PJC GLV C/O 06/08/06 JCM/PAG PULL ECLIPSE PATCH BP Exploration(Alaska) •I TREE=' 4-1116"CW C�4,2A SAFETY N TES: WELL ANGLE >70'@ 9684'. 4-1/2" WELLHEAD= 13-5/8"FMC CHROM R. ACTUATOR= OTIS --- TxIA leak KB. aEv= 72 50' CTD sidetrack BF. ELEV= 35.20' double valve IA KOP= 6350' Mix Angle= 95 10152' 2197' --I 4-1/2"HES HXO SSSV N, ID=3.813" Datum MD= 9486' O Datum TVD= 8800'SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE --- 13-3/8"CSG,681,L-80, ID=12.415" H 3238' F , ,2 4239 4166 0 TGPDX DMY RA 0 05/21/06 ' I 1 6875 6808 24 TGPDX DMY RA 0 05/21/06 Minimum ID = y (" i* 7169'-7204' 14-1/7'BAKER KB PATCH,ID=2.45" TOP OF CMT( LNR SQZ 10/02/96) H 8822' 419 �. 8494' —19-5/8"X 7"BKR TIEBACK SLV, ID=7 ,, k4,0 8502' 19-5/8"X 7"BKR H LNR TIEBACK PKR I. 11 8545' —19-5/8"X 7"TW TIEBACK SLV,ID=7.37" lj l' 8551' H 9-5/8"X 7"TW PKR/HGR, ID=6.18" I.) /i 9-5/8"CSG,47*, L-80, ID=8.681" —1 8814' 1—A 4• �, TSGR 8780' • .4 9370' H4-1/2"HES X NIP,ID=3.813" • 4, 1. 1 J9380' H7"X 4-1/2"BKR S-3 PKR ID=3.937" 6 9404' H4-1/7'HES X NIP, ID=3.813" TOL proposed —1 9410' —63 .. - 9404' �2-7/8"HES NIP REDUCER,ID= 2.313"to be a ren. I 9425' H 1/2"HES XN NIP, ID=3.725" 4-1/2"TBG, 12.6*,L-80, .0152 bpf, ID=3.958" —1 9424' / \ 943r H4-1/2"wLEG, 10=3.958" H 9500' 9458' H ELMD TT LOGGED 09/19/96 11 4-117'x 7"whipstock H 9790' 760 10400' H3-3116"x 2-7/8"XO zone 2, lowside exit TW OVERSHOT CT GUIDE ID=4.00" H 9970 ' 13-3/16'x 2-7/8"cemented liner H 12450' ' -1 c PERFORATION SUMMARY r REF LOG: SPERRY-SUN MWD/GR ON 04/25/93 9984' --17"X 4-1/2"TW SS PKR,ID=4.00" ANGLE ATTOP PERF: 59@9330' 00000� Note: Refer to Production DB for historical pert data 9989' �4 1/2"PORTED JT SIZE SPF INTERVAL Opn/Sqz DATE , , '7"LNR,29*, NT-80, .0371 bpf,ID=6.184" —{ 10141' 1-9/16" 4 9330-9332 S 10/02/96 4-1/2" SLID 10248-11068 O 05/05/93 Bonsai contingency completion I I I I I I 4-1/2"SLTD LNR, 12.6*, 13-CR,.0152 bpf, ID=3.958" —1 11068' I TD --I 11103' J k DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/07/93 ORIGINAL COMPLETION 06/10/06 TWS/PAG SET XXN PLUG WELL: C-42 10/06/95 RWO 07/29/07 CJN/SV PULL XXN PLUG(0726/07) PERMIT No: 11/24/02 JB/TP ECLIPSE PATCH SET 08/26/07 TEL/SV PATCH SET(08/23/07) AR No: 50-029-22357- 12/138/02 JMVTLH GLV C/O 09/17/07 PJC WBS CORRECTIONS SEC 19,T11 N, R14E,481'SNL&1220'WEL 05/21/06 TEL/PJC GLV C/O 11/15/10 MSE PROPOSED CTD SIDETRACK 06/08/06 JCNVPAG PULL ECLIPSE PATCH BP Exploration (Alaska) 0 C) CO v O C) 0 0 0 0 N. o v o 0 Q c o 0 0 0 D o v o 0 0 0 0 o a oui o 0 o v m 0 0 0O 0 0 0 Q = 0 n u) N. cD cq a) C) a) a) co CO m ) m 0 -a U A o CO u.V M ~ O a) O 0) N C0 O co O) U) N. 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N s� 5 E 5 s Mill BP BAKER HUGHES Travelling Cylinder Report 0 by 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-42-Slot 42 Project: Prudhoe Bay TVD Reference: 49:42 4/10/1993 00:00 @ 72.50ft(generic drilling rig) Reference Site: PB C Pad MD Reference: 49:42 4/10/1993 00:00 @ 72.50ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: C-42 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore C-42A Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 5 Offset ND Reference: Offset Datum 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-03-C-03B-C-03B 9,757.39 11,275.00 494.42 176.62 318.14 Pass-Major Risk C-04-C-04-C-04 11,050.00 10,075.00 1,341.59 580.64 795.09 Pass-Major Risk C-04-C-04A-C-04A 12,375.00 12,100.00 699.02 369.11 334.78 Pass-Major Risk C-04-C-04APB1 -C-04APB1 11,178.30 10,775.00 926.01 330.22 600.82 Pass-Major Risk C-04-C-04APB2-C-04APB2 11,113.63 10,600.00 950.29 392.74 563.26 Pass-Major Risk C-04-C-04APB3-C-04APB3 11,100.00 10,563.00 980.17 405.41 580.61 Pass-Major Risk C-04-C-04B-C-04B 10,878.30 10,800.00 1,141.01 565.00 581.08 Pass-Major Risk C-04-C-04B-Plan#5 10,888.36 10,775.00 1,074.59 559.99 519.77 Pass-Major Risk C-08-C-08-C-08 Out of range C-08-C-08A-C-08A Out of range C-08-C-08APB1 -C-08APB1 Out of range C-08-C-08B-C-08B Out of range C-08-C-08BPB1 -C-08BPB1 Out of range C-11_DIMS-C-11 -C-11 Out of range C-11_DIMS-C-11A-C-11A Out of range C-13-C-13-C-13 Out of range C-13A-C-13A-C-13A Out of range C-14-C-14-C-14 Out of range C-15-C-15A-C-15A Out of range C-18-C-18-C-18 Out of range C-18-C-18A-C-18A Out of range C-18-C-18B-C-18B Out of range C-18-C-18BPB1 -C-18BPB1 Out of range C-19-C-19-C-19 12,442.19 9,575.00 1,437.23 796.75 1,201.62 Pass-Major Risk C-19A-C-19A-C-19A 12,442.19 9,575.00 1,437.23 796.75 1,201.62 Pass-Major Risk C-19B-C-19B-C-19B 12,442.19 9,575.00 1,437.22 796.76 1,201.62 Pass-Major Risk C-19BPB1 -C-19BPB1 -C-19BPB1 12,442.19 9,575.00 1,437.22 796.76 1,201.62 Pass-Major Risk C-20-C-20-C-20 Out of range C-20-C-20A-C-20A Out of range C-20-C-20B-C-20B Out of range C-20-C-20C-C-20C Out of range C-33-C-33-C-33 Out of range C-33-C-33A-C-33A Out of range C-33-C-33A-Plan#2 Out of range C-33-C-33PB1 -C-33PB1 Out of range C-35-C-35A-C-35A Out of range C-35-C-35B-C-35B Out of range C-36-C-36-C-36 Out of range C-36A-C-36A-C-36A 9,935.98 12,007.00 70.12 17.48 69.85 Pass-Minor 1/100 C-36APB1 -C-36APB1 -C-36APB1 10,414.62 10,978.00 927.90 487.90 453.74 Pass-Major Risk C-37-C-37-C-37 12,250.00 9,875.00 1,198.18 306.67 891.90 Pass-Major Risk C-37-C-37A-C-37A 12,250.00 9,875.00 1,198.18 306.89 891.67 Pass-Major Risk C-37-C-37APB1 -C-37APB1 12,250.00 9,875.00 1,198.18 306.91 891.65 Pass-Major Risk C-37-C-37APB2-C-37APB2 12,250.00 9,875.00 1,198.18 306.91 891.65 Pass-Major Risk C-37-C-37B-C-37B 12,266.94 10,300.00 695.58 311.32 384.27 Pass-Major Risk C-37 DO NOT USE-C-37-C-37 12,250.00 9,875.00 1,198.18 306.62 891.94 Pass-Major Risk C-37_DO NOT USE-C-37A-C-37A 12,250.00 9,875.00 1,198.18 306.89 891.67 Pass-Major Risk C-37 DO NOT USE-C-37APB1 -C-37APB1 12,250.00 9,875.00 1,198.18 306.87 891.70 Pass-Major Risk C-37_DO NOT USE-C-37APB2-C-37APB2 12,250.00 9,875.00 1,198.18 306.87 891.70 Pass-Major Risk C-38-C-38-C-38 Out of range C-42-C-42-C-42 9,775.00 9,775.00 0.00 3.62 -1.77 FAIL-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/3/2011 2:27:36PM Page 3 of 48 COMPASS 2003.16 Build 73 & ■ BP HUGHES Travelling Cylinder Report 0 bp BAKER INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-42-Slot 42 Project: Prudhoe Bay TVD Reference: 49:42 4/10/1993 00:00©72.50ft(generic drilling rig) Reference Site: PB C Pad MD Reference: 49:42 4/10/1993 00:00©72.50ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: C-42 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore C-42A Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 5 Offset TVD Reference: Offset Datum Offset Design PB C Pad- C-03-C-03B-C-03B Offset Site Error. 0.00ft • Survey Program: 109-GYD-CT-CMS,8202-MWD+IFR+MS Rule Assigned:Major Risk Offset Well Error: 0.00ft 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 +Ej-w Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (') (ft) (ft) (f) (ft) (ft) (ft) 9,757.39 8,973.26 11,275.00 9,008.93 26.90 20.27 142.05 924.72 1,830.27 0.28 494.42 176.62 318.14 Pass-MajorRisk,CC,ES,£ 9,775.26 8,978.02 11,250.00 9,008.49 27.10 20.22 141.20 927.36 1,855.13 0.28 509.01 177.14 332.10 Pass-Major Risk 9,793.62 8,982.70 11,225.00 9,007.82 27.31 20.18 140.40 930.09 1,879.97 0.28 523.65 177.66 346.13 Pass-MajorRisk 9,810.00 8,987.08 11,200.00 9,007.09 27.47 20.13 139.64 932.89 1,904.80 0.28 538.31 178.03 360.33 Pass-Major Risk 9,820.00 8,990.13 11,175.00 9,006.55 27.56 20.09 137.58 935.74 1,929.63 0.28 553.28 177.75 375.47 Pass-Major Risk 9,825.69 8,992.08 11,150.00 9,006.00 27.61 20.05 136.07 938.69 1,954.45 0.28 568.64 177.46 391.05 Pass-Major Risk 9,830.00 8,993.67 11,125.00 9,005.30 27.65 20.01 134.70 941.81 1,979.24 0.28 584.34 177.18 407.00 Pass-Major Risk 9,840.00 8,997.70 11,075.00 9,004.64 27.74 19.94 131.85 948.94 2,028.73 0.28 616.45 176.48 439.82 Pass-Major Risk 9,840.00 8,997.70 11,100.00 9,004.80 27.74 19.97 132.66 945.22 2,004.01 0.28 600.27 176.57 423.45 Pass-Major Risk 9,850.00 9,001.89 11,000.00 9,005.39 27.83 19.84 127.65 960.12 2,102.88 0.28 667.67 174.75 492.95 Pass-Major Risk 9,850.00 9,001.89 11,025.00 9,004.98 27.83 19.87 128.28 956.45 2,078.16 0.28 650.10 174.84 475.17 Pass-Major Risk 9,850.00 9,001.89 11,050.00 9,004.71 27.83 19.90 128.96 952.71 2,053.44 0.28 633.08 174.94 457.96 Pass-Major Risk 9,860.00 9,005.91 10,925.00 9,008.03 27.92 19.74 123.91 972.72 2,176.76 0.28 721.40 172.82 549.02 Pass-Major Risk 9,860.00 9,005.91 10,950.00 9,006.89 27.92 19.77 124.39 968.04 2,152.22 0.28 703.44 172.91 530.87 Pass-Major Risk 9,860.00 9,005.91 10,975.00 9,005.99 27.92 19.81 124.91 963.84 2,127.60 0.28 685.58 173.00 512.81 Pass-Major Risk 9,865.88 9,008.19 10,900.00 9,009.18 27.97 19.71 122.17 977.69 2,201.23 0.28 739.44 171.51 568.48 Pass-Major Risk 9,870.00 9,009.75 10,850.00 9,011.27 28.01 19.64 120.41 987.91 2,250.13 0.28 776.37 170.39 606.72 Pass-Major Risk 9,870.00 9,009.75 10,875.00 9,010.29 28.01 19.67 120.82 982.82 2,225.67 0.28 757.74 170.47 587.91 Pass-Major Risk 9,874.60 9,011.45 10,825.00 9,012.12 28.05 19.61 118.99 993.01 2,274.59 0.28 795.29 169.14 626.95 Pass-Major Risk 9,880.00 9,013.39 10,750.00 9,013.39 28.10 19.52 116.66 1,008.39 2,347.98 0.28 853.63 167.42 687.26 Pass-Major Risk 9,880.00 9,013.39 10,775.00 9,013.25 28.10 19.55 117.03 1,003.25 2,323.51 0.28 833.93 167.49 667.38 Pass-Major Risk 9,880.00 9,013.39 10,800.00 9,012.82 28.10 19.58 117.40 998.13 2,29905 0.28 814.50 167.57 647.79 Pass-Major Risk 9,884.77 9,01505 10,725.00 9,013.45 28.14 19.50 115.23 1,013.59 2,372.43 0.28 873.49 165.92 708.65 Pass-Major Risk 9,890.00 9,016.82 10,625.00 9,013.33 28.19 19.41 112.75 1,036.55 2,469.75 0.28 953.88 164.01 791.22 Pass-Major Risk 9,890.00 9,016.82 10,650.00 9,013.41 28.19 19.43 113.05 1,030.59 2,445.47 0.28 933.58 164.06 770.78 Pass-Major Risk 9,890.00 9,016.82 10,675.00 9,013.46 28.19 19.45 113.37 1,024.57 2,421.21 0.28 913.55 164.11 750.61 Pass-Major Risk 9,890.00 9,016.82 10,700.00 9,013.48 28.19 19.47 113.69 1,018,89 2,396.86 0.28 893.56 164.16 730.47 Pass-Major Risk 9,900.00 9,020.02 10,500.00 9,018.22 28.27 19.34 109.47 1,064.55 2,591.44 0.28 1,058.68 160.26 899.83 Pass-Major Risk 9,900.00 9,020.02 10,525.00 9,016.74 28.27 19.35 109.62 1,059.03 2,567.11 0.28 1,037.35 160.30 878.41 Pass-Major Risk 9,900.00 9,020.02 10,550.00 9,015.27 28.27 19.37 109.78 1,053.57 2,542.75 0.28 1,016.15 160.34 857.12 Pass-MajorRisk 9,900.00 9,020.02 10,575.00 9,014.02 28.27 19.38 109.95 1,048.07 2,518.40 0.28 995.14 160.38 836.02 Pass-Major Risk 9,900.00 9,020.02 10,600.00 9,013.36 28.27 19.40 110.17 1,042.40 2,494.06 0.28 974.40 160.42 815.18 Pass-Major Risk 9,905.58 9,021.71 10,475.00 9,019.50 28.32 19.32 108.03 1,069.98 2,615.81 0.28 1,080.13 158.07 923.35 Pass-Major Risk 9,910.00 9,022.99 10,325.00 9,017.65 28.36 19.25 105.90 1,097.89 2,763.06 0.29 1,213.75 156.06 1,059.17 Pass-MajorRisk 9,910.00 9,022.99 10,350.00 9,019.53 28.36 19.26 106.13 1,093.09 2,738.60 0.29 1,191.34 156.09 1,036.65 Pass-MajorRisk 9,910.00 9,022.99 10,375.00 9,020.70 28.36 19.27 106.35 1,088.25 2,714.10 0.29 1,169.01 156.13 1,014.22 Pass-MajorRisk 9,910.00 9,022.99 10,400.00 9,020.99 28.36 19.28 106.53 1,083.65 2,689.53 0.29 1,146.65 156.17 991.76 Pass-MajorRisk 9,910.00 9,022.99 10,425.00 9,020.74 28.36 19.30 106.68 1,079.25 2,664.93 0.28 1,124.30 156.20 969.34 Pass-Major Risk 9,910.00 9,022.99 10,450.00 9,020.26 28.36 19.31 106.83 1,074.80 2,640.33 0.28 1,102.09 156.24 947.05 Pass-Major Risk 9,915.53 9,024.53 10,300.00 9,015.32 28.40 19.24 104.35 1,102.02 2,787.61 0.29 1,236.40 153.69 1,084.07 Pass-Major Risk 9,920.00 9,025.72 10,075.00 8,958.49 28.44 19.16 100.21 1,134.78 2,999.67 0.29 1,437.17 151.31 1,288.07 Pass-MajorRisk 9,920.00 9,025.72 10,100.00 8,971.59 28.44 19.17 100.77 1,131.25 2,978.68 0.29 1,416.82 151.36 1,267.46 Pass-MajorRisk 9,920.00 9,025.72 10,125.00 8,982.97 28.44 19.18 101.27 1,127.78 2,956.70 0.29 1,395.68 151.41 1,246.09 Pass-MajorRisk 9,920.00 9,025.72 10,150.00 8,992.25 28.44 19.18 101.72 1,124.21 2,933.77 0.29 1,373.80 151.46 1,224.01 Pass-MajorRisk 9,920.00 9,025.72 10,175.00 8,999.32 28.44 19.19 102.08 1,120.55 2,910.08 0.29 1,351.33 151.50 1,201.37 Pass-MajorRisk 9,920.00 9,025.72 10,200.00 9,004.37 28.44 19.20 102.38 1,116.86 2,885.88 0.29 1,328.48 151.55 1,178.38 Pass-MajorRisk 9,920.00 9,025.72 10,225.00 9,007.67 28.44 19.21 102.61 1,113.06 2,861.40 0.29 1,305.46 151.59 1,155,25Pass-Major Risk 9,920.00 9,02572 10,250.00 9,010.32 28.44 1922 102.83 1,109.34 2,836.82 0.29 1,282.41 151.63 1,132.10Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/3/2011 2:27:36PM Page 4 of 48 COMPASS 2003.16 Build 73 B ,, BP b O • MONIS Travelling Cylinder Report rE.,. ENTEQ W Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-42-Slot 42 Project: Prudhoe Bay TVD Reference: 49:42 4/10/1993 00:00 @ 72.50ft(generic drilling rig) Reference Site: PB C Pad MD Reference: 49:42 4/10/1993 00:00 @ 72.50ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: C-42 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore C-42A Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 5 Offset TVD Reference: Offset Datum Offset Design PB C Pad- C-03-C-03B-C-03B Offset Site Error: 0 00f Survey Program: 109-GYD-CT-CMS,8202-MWD+IFR+MS Rule Assigned:Major Risk Offset Well Error: 0.00ft 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 (ft) (ft) (ft) (ft) (ft) (ft) (1 (ft) (ft) (ft) (ft) (ft) (ft) 9,920.00 9,025.72 10,275.00 9,012.84 28.44 19.23 103.05 1,105.72 2,812.21 0.29 1,259.39 151.68 1,108.97 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/3/2011 2:27:36PM Page 5 of 48 COMPASS 2003.16 Build 73 A. 11 • U I U lv w 0 ml g 11 a N £� I =a m f i l 1 a I — Y. — _ ill 111 1 g 1 ° �4 g 0 o II 111 1 C - I I.A ►D ; n � 11 t a _�4/6 '! € IUBm V o lJ JT H .O O V G U r 2 `Q 4E gs $ F 8 z Q c ¢ 9re a z _ — I 4 1:I 8 I ° Q i I > I Ci m I II : 1 0 III J I nn III O 1 Y I J� LL v o I o 0 . 0 U Mg > > Z . x “. 5I- IIII u IIII. u < ^ 21 ° 1 SII Iii Z CIO il 75 > Ogg W : , J 0 o Em li o v„1fa • • • •U re ^ fit IIII 11=1 Z II IaQ S I n a ILLI 8 II a 3 III'. iM U . W Id r m v ®„ 5 v Ce mil Y t Ill O t , .•-4 ICI O - Et .. - ii _ N J 111 �i 1I i r CI m 1 IX o Im O i : 1 Si 0• ! g 1 5 .. i AL I I .1)1191 1 ® p .. o I Z li(-111 1I I 1Iv Alaska Department of Natur?' '?esources Land Administration System Page 1 of 1 Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources ( find Alaska DNR Case Summary File Type: ADL File Number: 28305 Printable Case File Summary See Township,Range,Section and Acreage? Yes 0 No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28305 NIT Search for Status Plat Updates As of 03/09/2011 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E.BENSON BL ATTN:LAND MANAGER-ALASKA ANCHORAGE AK 995196612 Case Type:784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2480.000 Date Initiated:05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: U Township: 011N Range: 014E Section: 17 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 014E Section: 18 Section Acres: 599 Meridian: U Township: 011N Range: 014E Section: 19 Section Acres: 601 Meridian: U Township: 011N Range: 014E Section: 20 Section Acres: 640 Legal Description 05-28-1965 ***SALE NOTICE LEGAL DESCRIPTION*** C14-126 11 N 14E UM 17,18,19,20 2480.00 U-3- 7 End of Case Summary Last updated on 03/09/2011. Not sure who to contact?Have a question about DNR?Visit the Public Information Center. Report technical problems with this page to the Webmaster. Site optimized for Netscape 7,IE 6 or above. This site also requires that all COOKIES must be accepted. State of Alaska Natural Resources LAS Home Copyright Privacy System Status http://dnr.alaska.gov/proj ects/las/Case_Summary.cfin?FileType=ADL&FileNumber=28305... 3/9/2011 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME )4'�/ Zr- 41,/9 PTD# 0?//032r- /Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: 4' 'Z, C 3;4 POOL: �,eL/Oh/OE 2'9Y ©/G Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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