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198-201
7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU P2-59A Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-201 50-029-22096-01-00 ADL 0365548 14975 Conductor Surface Intermediate Liner Liner 9028 90 2949 13385 531 1891 14670 20" 13-3/8" 9-5/8" 7" 3-3/16" 9033 24 - 114 41 - 2990 24 - 13409 13112 - 13643 13079 - 14970 2920 24 - 114 41 - 2680 24 - 8820 8587 - 9008 8563 - 9028 14787 1500 1140 4760 4790 10530 14670 2320 5020 6870 6890 10160 13720 - 14930 3-1/2" 9.2# x 4-1/2" 12.6# 13cr80 , L80 24 - 130129060 - 9033 Structural 3-1/2" HES TNT , 12780 , 8351 4-1/2" Baker S3 , 12937 , 8462 4-1/2" Otis MHR , 13057 , 8546 No SSSV Installed Date: Bo York Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY 10/1/25 Current Pools: PT MCINTYRE OIL Proposed Pools: PT MCINTYRE 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 10:35 am, Sep 12, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.09.11 17:11:38 - 08'00' Bo York (1248) 325-555 SFD 9/17/2025 , ADL 0034624 SFD DSR-9/12/25 10-404 Perforating gun BHA not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders. Ensure well is dead before breaking containment JJL 9/22/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.22 20:24:06 -08'00'09/22/25 RBDMS JSB 092625 Page 1 of 12 FCO & Extended Perforating P2-59A PTD: 198-201 Well Name:P2-59A API Number:50-029-21742-00 Current Status:Operable, Shut In Rig:SL/CTU Estimated Start Date:10/1/25 Estimated Duration:3days Reg. Approval Required?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Carrie Janowski 907-564-5179 First Call Engineer:Michael Hibbert 907-903-5990 Second Call Engineer:Jerry Lau 907-360-6233 Expected Rates Post Work ~.2 MMSCFD, 100 BOPD and 1500 BWPD Current Bottom Hole Pressure:3600 psi @ 8,800’ TVD 7.9 PPGE Maximum Expected BHP:3800 psi @ 8,800 TVD 8.4 PPGE Max. Anticipated Surface Pressure:2920 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2450 psi – 3/8/25 Min ID:2.37” @ 13,079’ LTP Max Angle:97° @ 14,947’ MD – 70 deg at 13,749 MD Well History: P2-59 was drilled in Dec 1990 and was a failure. After only producing 14k bo it was CTD sidetracked in May 1999. After a failed frac attempt a CT FCO was executed and a lot of trouble was encountered in the area above the LTP (review WSRs from 1/3/2000-4/23/2000). On 5/20/2000 again CT was unable to get into LTP with 2.25” nozzle. A 2” nozzle was successful the next day with 10’ of stingers. In Jan 2014 CT successfully drifted to CIBP with 2.31” nozzle and also ran 4x gun runs (with 2” guns) without issue at the LTP. Objective: Execute a fill/scale cleanout in P2-59A and get the tubing and liner free of fill/scale. Run extended perforation guns to add footage to the Kuparuk production interval. Procedure Slickline –Complete 1. Pulled SSSV on 6/17/25. SL tagged between 10,380’ to 11,730’ with various sized drifts. Bailers came back with sand in them. Coil – order 2% KCL for FCO MIRU CT – need ~15,000’ of usable coiled tubing for this job. Order 2% KCL as this formation is more sensitive to clay swelling damage than Ivishak wells. 1. MU and RIH with ~2.75” JSN (min ID in upper completion is 2.813”). 2. Dry tag. Pump 2% and gel pills and cleanout down to LTP at 13,079’. Pump a large gel pill off bottom and chase solids pumping to surface. If unable to make progress with nozzle then POOH and PU a motor and 2.75” mill. Complete milling down to LTP, and chase solids back to surface. 3. If FCO was going well with a nozzle then PU a 2.25-2.3” JSN and proceed with FCO down into the liner. FCO down to the CIBP at 14,670’. Pump gel pill off bottom and chase to surface. 4. If a mill was needed in the upper completion then skip the nozzle liner run and MU 2.30” motor and mill and mill scale/fill down to CIBP at 14,670’. POOH chasing solids to surface. a. BHP is such that returns should be maintainable without gas lift but be prepared before cleaning out across the perfs that the well could start taking fluid. 50-029-22096-01-00 SFD Page 2 of 12 FCO & Extended Perforating P2-59A PTD: 198-201 Coil – Extended Perforating – Order 2% KCL for well kill and open-hole deployment operations 1. MU GR/CCL tools in 2.25” carrier and RIH. Flag pipe for perforating from 13,643’ – 13,720’ MD. a. Attached and annotated log is attached below – PDS Jewelry Log 7/28/2007. 2. POOH. Send correlation log to Michael Hibbert and Joe Syzdek for confirmation. Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 3. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 4. Bullhead 1.2x wellbore volume ~293 bbls 2% KCL down tubing. Max tubing pressure 2500 psi, can go to 2750 psi to overcome SI WHP. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 244 bbls b. 3-1/2” tubing – 13,012’ x .0.0087 bpf = 238 bbls c. 4-1/2” tubing – 67’ x .0152 bpf = 1 bbls d. 3-3/16” liner – 641’ x .0076 bpf = 5 bbls 5. At surface, prepare for deployment of TCP guns. 6. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 2% KCl as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 7.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. e.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 8.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 2” MaxForce Guns or equivalent Perf Interval Tie In and perforate these depths Total Gun Length Weight of Gun (lbs) 13,643’ – 13,720’ 77’ 430 lbs (5.58 ppf) - Estimated weight based on 2” guns 3-1/2" volume to 13,012' = 113.2 bbls - JJL Page 3 of 12 FCO & Extended Perforating P2-59A PTD: 198-201 9. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 10. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 11. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 12. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 13. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 14. RDMO CTU. 15. Turn well over to Operations POP. Slickline – 1. Set SSSV Attachments: Wellbore Schematic, Proposed Schematic, Tie-In Log, BOPE and rig-up diagram, Sundry Change Form Page 4 of 12 FCO & Extended Perforating P2-59A PTD: 198-201 Current Wellbore Schematic Page 5 of 12 FCO & Extended Perforating P2-59A PTD: 198-201 Page 6 of 12 FCO & Extended Perforating P2-59A PTD: 198-201 Proposed Wellbore Schematic Page 7 of 12 FCO & Extended Perforating P2-59A PTD: 198-201 Perforate – 13,643’ – 13,720’ Page 8 of 12 FCO & Extended Perforating P2-59A PTD: 198-201 Tie-in Log Perforate 13,643’ – 13,720’ Page 9 of 12 FCO & Extended Perforating P2-59A PTD: 198-201 BOP Schematic Page 10 of 12 FCO & Extended Perforating P2-59A PTD: 198-201 Page 11 of 12 FCO & Extended Perforating P2-59A PTD: 198-201 Page 12 of 12 FCO & Extended Perforating P2-59A PTD: 198-201 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 HAK Prepare d By (Initials) HAK Appro ved By (Initial s) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date STATE OF ALASKA RECEIVED • ,SKA OIL AND GAS CONSERVATION Cv1AMISSION• LIAR 2 4 2015 REPORT OF SUNDRY WELL OPERATIONS Ar)GCC 1. Operations Performed: ❑Abandon Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well ❑Alter Casing IN Pull Tubing 0 Stimulate-Frac 0 Waiver 0 Other ❑Change Approved Program 0 Operation Shutdown 0 Stimulate-Other 0 Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 198401 3. Address: ®Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-22096-01-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 365548 PBU P2-59A 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Prudhoe Bay/Pt McIntyre 11. Present well condition summary: Total depth: measured 14975' feet Plugs:(measured) 12992', 14670' feet true vertical 9028' feet Junk:(measured) 14787' feet Effective depth: measured 14670' feet Packer: (measured) 12780', 12937', 13057' feet true vertical 9033' feet Packer: (true vertical) 8352',8462',8547' feet Casing Length Size MD ND Burst Collapse Structural Conductor 114' 20" 114' 114' 2320 1500 Surface 2990' 13-3/8" 2900' 2679' 5020 2270 Intermediate 13373' 9-5/8" 36'- 13409' 36'-8820' 6870 4760 Production Liner 531' 7" 13112'- 13643' 8587'-9008' 8160 7020 Liner 1858' 3-3/16" 13112'- 14970' 8587'-9028' Perforation Depth' Measured Depth: 13720'-14930' feet True Vertical Depth: 9060'-9033' feet Tubing(size,grade,measured and true vertical depth): 3-1/2", 9.2#x 13Cr80/L-80 13148' 8614' 4-1/2", 12.6# measured and true vertical depth): 9-5/8"x 3-1/2"HES r T Packer, 12780', 8352', Packers and SSSV (type, 9-5/8"x 4-1/2"Baker S-3 Packer, 12937', 8462', 9-5/8"x 4-1/2"Otis MHR Packer 13057' 8547' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: Sat/1° • 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 562 312 810 2100 991 Subsequent to operation: 0 0 0 0 - 0 14.Attachments: 0 Copies of Logs and Surveys run 15.Well Class after work: 0 Exploratory 0 Stratigraphic ®Development 0 Service ®Daily Report of Well Operations 16. Well Status after work: IS Oil 0 Gas 0 WDSPL ®Well Schematic Diagram 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt' Contact: Sean McLaughlin,564-4387 N/A Email Sean.MCLaughlin@bp.com Printed Name: Joe Lastufk Title: Drilling Technologist Signature: A P ne: 564-4091 Date:5/24'h 5 Form 10-404 Revised 10/2012 177 L 4Pq l 70 y71V717.0* -- RBDMSVit grj4i{ta1%4/11x015 4- P2-59A, Well History (Pre-Rig Workover) Date Summary 01/14/15 T/I/O=SSV/2350/540,Temp=SI. PPPOT-T(PASS), PPPOT-IC (PASS), pre RWO. PPPOT-T: Stung into test port(2100 psi), bled void to 0 psi. Functioned LDS,all moved freely(1"). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port(500 psi), bled void to 0 psi. Functioned LDS, all moved freely(1"). Pumped through void,good returns. Pressured void to 3500 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min(PASS). Bled void to 0 psi. 01/25/15 T/I/0=1152/2447/363,Temp=S/I.Thaw Tubing Hydrates(Hydrates) Pumped a total of 25 bbls meth down flowline to refreeze protect P2-04 from P2-59 flowline. Pressured up tubing with .5 bbls meth to to reach 3000 psi monitored psi. Pumped 10 bbls meth spear followed by 77 bbls 180*crude down IA to thaw tubing hydrates. Unit has mechanical issues,turn job over to LRS unit 23. FWHP's=1384/2583/440. 01/25/15 T/I/O= 1107/2455/396 TUBING THAW**Pumped 52 bbls 180*Crude down IA. 01/26/15 T/I/0=1956/2554/454 Temp=Sl Thaw Hydrates in Tbg/Hot Oil Treatment(HOT OIL TBG WASH) Pumped 828 bbls of 180*crude down IA to thaw Tbg. Pumped a total 6 bbls neat down Tbg in attempt to pump down Tbg but all attempts have locked up. 01/27/15 Pumped 687 bbls 180*Crude, 85 bbls 200*1% KCL,6 bbls Neat Meth down IA to Thaw tubing Pumped 6 bbls total of Neat Meth down tubing before well locked up Pumped 27 bbls down F/L to freeze protect. 01/28/15 T/I/O= 1000/886/559 TUBING THAW Pumped 207 bbls 1%KCL down IA to thaw tubing Pumped 580 bbls 180*Crude down IA to displace water Pumped 11 bbls Neat Meth, 96 bbls 180*Crude down tubing for H.O.T. Pumped 10 bbls Neat Meth down F/L to freeze protect, 22 neat down adjacent FL SV,WV, SSV=Closed MV=Open IA/OA=OTG's F/P tag hung on WV AFE sign hung around MV FWHP's= 2200/1000/500 DSO notified upon departure. 02/01/15 T/I/O=880/790/390.Temp=SI. T& IA FL(slickline request).AL SI @ casing valve(2450 psi).T FL near surface. IA FL @ surface. SV,WV, SSV=C. MV=0. IA, OA=OTG. 0130. 02/02/15 PULLED 3-1/2" K-VALVE(ser#k-318)@ 2095'SLM/2114'MD. DRIFT TO 4-1/2"ECLIPSE LTP @ 13,089'SLM/13,109' ELMD (+20'correction, no sample). RUN SLB DUAL SBHPS(good data). 02/02/15 T/I/0=793/761/404 TEMP=S1 CMIT-TxIA TO 3500 PSI Assist SSL with Load&Test(RWO EXPENSE) Pumped 3 bbls meth spear,followed by 71 bbls of 90*crude. Pump truck broke turned over to other pump truck. FWHP=1161/1150/404. 02/02/15 T/I/O=Temp=SI Assist Slickline, Loaded IA with 3 bbls neat and 150 bbls crude(neat and 70 bbls crude from LRS 23, 80 bbls crude from LRS 76). Loaded TBG with 3 bbls neat methanol and 25 bbls crude. 02/03/15 SET 3-1/2"XX PLUG (w/4-3/16"eq ports&4-1/8"eq ports), @ 12,968'SLM/12,992' MD LRS PERFORM PASSING CMITxIA. PULLED STA#3(9188'),#4(6609'),#5(3527') RK-LGLV SET STA#5(3527'),#4(6609'),#3(9188') RK-DGLV. 02/03/15 Assist Slickline. CMIT TxIA to 3500**PASS**Pumped 14 bbls crude to reach test pressure.WV=closed, IA/OA=OTG FLUID PACKED ANNULUS,WATCH FOR THERMAL EXPANSION-Caution tags and Sign hung on IA and WV, Well. FWHP=288/266/390. Page 1 of 2 P2-59A, Well History (Pre-Rig Workover) Date Summary 02/04/15 PULLED WHIDDON (empty) FROM 12,964'SLM/12.992'MD. R/D SWCP 4519. 02/06/15 FINISH TUBING PUNCH FROM 12848-12850. CCL TO TOP SHOT IS 3.8 FT, CCL STOP AT 12344.2'. RIG UP RCT. CCL ONLY PICKING UP INTERMITTENT COLLARS.TROUBLESHOOT SYSTEM. RIH WITH RCT, STOP AND DO TURN AROUNDS EVERY 1500 FT TO CHECK FOR COLLARS,THEY ONLY SHOW UP RELIABLY COMING UPHOLE.WSL SAID TO CONTINUE. 02/07/15 E-LINE TUBING CUTTER. CONTINUED TO RUN IN HOLE. CUT 3.5"TUBING AT 12883'GOOD INDICATION OF CUT. 9.3' FROM CCL TO RCT. CCL STOP DEPTH AT 12873.7'. POOH CHECK CUTTER LOOKS GOOD. RDMO. RETURNED WELL TO DSO (LEFT SHUT IN). 02/08/15 T/I/O= 164/126/363 Temp=S/I (Obj: Pre RWO). Pumped 17 bbls Neat McOH down F/L of P2-57 to free ice plug and to establish flow path. Pumped 14 bbls 180*Diesel down F/L of P2-57 to ensure hydrates were clear. 02/09/15 (Obj. Pre RWO) Cric-Out well. Pumped 10 bbls Neat McOH down TBG up IA of P2-59 taking returns to F/L of P2-57. Pumped 1354 bbls 9.8 Brine down TBG up IA of P2-59 taking returns to F/L of P2-57. Pumped 2 bbls Neat McOH followed by 40 bbls Diesel and a 2 bbl Neat McOH tail down TBG up IA of P2- 59 taking returns to P2-57. Pumped 15 bbls Neat McOH followed by 2 bbls Diesel down hard line to P2- 57 to freeze protect F/L and hard line. Let TBG and IA U-Tube for 60 min. Bleed TBG/IA to 300 psi. FWHP=300/300/350 WV,SSV,SV=CLOSED MV=OPEN CV's=OTG AFE sign hung on MV Notified DSO Watch for Thermal Expansion. 02/13/15 T/I/O= 150/150/550, Conduct PJSM w/crew, Set CIW"H"#295 ,Tagged @ 125", Installed swab valve temp#10, Installed 2"Temp valve#72 on IA,Job complete, Final T/I/O=TWC/0/550. 02/15/15 T/I/O=TWCNac/340.Temp=SI. Bleed OAP to 0 psi, shut lower OA casing valve. (RWO prep). No wellhouse,flowline or AL line. No wellhead scaffolding. OA FL near surface. Bled OAP from 340 psi to 0 psi in 4.5 hrs(gas). 02/16/15 Bleed OAP to 0 psi, shut lower OA casing valve. (RWO prep). Held open bleed on OA for 7 hrs. Monitor BUR for 1 hr. OAP increased 1 psi. Final WHP's=TWCNAC/1. SV, MV=C. IA, OA=OTG. NOVP. 0400. Page 2 of 2 North America-ALASKA-BP Page 1 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 X4-0111R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292209600 Active datum:ORIG KELLY BUSHING @40.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/15/2015 06:00 - 06:30 0.50 RIGD P PRE PJSM. RIG DOWN AND PREPARE TO MOVE OFF WELL S-16. -CLEAN AND CLEAR CELLAR. -RID,CLEAN AND CLEAR RIG FLOOR. -PREPARE RIG FLOOR TO UD DERRICK. 1*SIMOPS: -R/D AND STAGE MUD PUMP#2,CUTTINGS BOX AND CREW TRAILER OUT RIGS MOVE PATH. -MOBILIZE ALL RIG SUPPORT EQUIPMENT FROM S-16 TO P2. OBTAIN WELL WORK TRANSFER PERMIT FOR WELL P2-59 ON 2/14/15. PAD OPERATOR AGREED THAT PLACEMENT OF THE WSL OFFICE IS WELL OUT OF THE 300'RED ZONE OF THE RIG AS WELLAS THE MANIFOLD BUILDING. 06:30 - 08:30 2.00 MOB P PRE PJSM. MOVE RIG OFF OF WELL S-16. -CONTACT PAD OPERATOR TO WITNESS RIG MOVING OFF WELL. PAD OPERATOR WAIVED WITNESS. RAISE CELLAR DOORS,STAIRS AND I LANDINGS. -POSITION RIG CREW MEMBERS AND VERIFY RADIO COMMUNICATION. -FUNCTION TEST ESD ON MOVING SYSTEM BEFORE MOVING RIG.TEST PASS. -MOB RIG OFF WELL S-16 AND STAGE IN MIDDLE OF S-PAD. 08:30 - 09:30 1.00 MOB P PRE PJSM AND REVIEW DDI SOP FOR LAYING DOWN DERRICK. LAY DOWN DERRICK FOR RIG MOVE. -PERFORM SPCC AND EQUIPMENT CHECKS. -BRIDLE-UP,AS PER DDI SOP. PULL DERRICK PINS. -LOWER AND SECURE DERRICK FOR RIG MOVE. 09:30 - 12:00 2.50 MOB P PRE PJSM. REMOVE BOP STACK AND INSTALL REAR BOOSTERS. -SECURE BOP STACK IN CRADLE AND REMOVE FROM CELLAR. -INSTALL REAR BOOSTERS. Printed 3/9/2015 10:50:58AM North America-ALASKA-BP Page 2 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 X4-0111R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292209600 Active datum:ORIG KELLY BUSHING @40.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 00:00 12.00 MOB P PRE PJSM WITH RIG CREW,SECURITY AND SUPPORT CREW. MOBILIZE RIG FROM S-PAD TO P2,WELL P2-59A. -CONDUCT RADIO COMMUNICATIONS CHECKS. -MOB RIG DOWN S-PAD ACCESS RD TO LEFT ON SPINE RD. 14:30 HRS -MOB RIG DOWN SPINE RD TO LEFT ON K-PAD ACCESS RD. 21:00 HRS -MOB RIG DOWN K-PAD ACCESS RD TO K-PAD. -POSITION RIG TO THE SIDE FOR RIG CREW CHANGE OUT. 24 HR NOTICE FOR INITIAL BOPE TEST, SUBMITTED ON 2/15/15 AT 13:19 HRS WITH INTENT TO TEST BOPE ON 2/16/15 AT 23:30 HRS. SIMOPS: -DHD ON P2 AT 16:30 HRS. PJSM WITH DHD,SCS AND WSL. DHD R/U TO BLEED OA PRESSURE. -DHD BLEED OA PRESSURE AT 17:30 HRS,F/ 340 PSI T/0 PSI. TOOK 3.5 HRS TO BLEED OA PRESSURE TO 0 PSI. -DHD MAINTAIN OPEN BLEED ON OA FROM 21:00 HRS. 2/16/2015 00:00 - 06:00 6.00 MOB P PRE PJSM WITH RIG CREW,SECURITY AND SUPPORT CREW. MOBILIZE RIG FROM S-PAD TO P2,WELL P2-59A. -CONDUCT RADIO COMMUNICATIONS CHECKS. -MOB RIG DOWN K-PAD ACCESS RD FROM K-PAD TO WEST DOCK INTERSECTION. -MOB RIG ACROSS WEST DOCK RD TO P2 ACCESS RD. -MOB RIG DOWN P2 ACCESS RD TO LEFT ON ICE RD. -MOB RIG DOWN ICE RD AND STAGE IN MIDDLE OF P2. 06:00 - 07:30 1.50 MOB P PRE PJSM. REMOVE REAR BOOSTERS AND SECURE BOP STACK IN CELLAR. -R/D AND REMOVE REAR BOOSTERS. -MOB BOP STACK TO CELLAR. -REMOVE BOP STACK FROM CRADLE AND SECURE BOP STACK ON STUMP IN CELLAR. Printed 3/9/2015 10:50:58AM North America-ALASKA-BP Page 3 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 X4-0111R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292209600 Active datum:ORIG KELLY BUSHING©40.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 08:30 1.00 RIGU P PRE PJSM.VERIFY WELL PRESSURES AND VALVE ALIGNMENT IN PREPARATION FOR POSITIONING RIG OVER WELL P2-59A. -CHECKED PRESSURES ON WELL BEFORE MOVING OVER WELL P2-59A. -OA GAUGE INOPERABLE. *REPLACE GAUGE ON OA. *TUBING PRESSURE=0 PSI,IA PRESSURE= 0 PSI,OA PRESSURE=70 PSI. -RIG UP BLEED TRAILER,BLEED PRESSURE ON 0/A TO 0 PSI. *ALL GAS,WELL DATA INDICATES GAS IS METHANE. 08:30 - 10:00 1.50 RIGU P PRE PJSM. PREPARE TO MOVE IN AND POSITION RIG OVER WELL P2-59A. -LAY AND POSITION RIG MATS AROUND I WELL P2-59A,FOR RIG FOOTPRINT. CONTACT PAD OPERATOR TO WITNESS RIG MOVING OVER WELL. *PAD OPERATOR WAIVED WITNESS. CONDUCT RADIO COMMUNICATIONS CHECKS. -FUNCTION TEST ESD ON MOVING SYSTEM BEFORE MOVING RIG OVER WELL.-TEST PASS. -POSITION AND CENTER RIG OVER WELL. -LEVEL/SHIM RIG AND LOWER CELLAR DOORS. 10:00 - 13:00 3.00 RIGU P PRE PJSM. RAISE DERRICK. -PREPARE,RAISE DERRICK,INSTALL PINS AND SECURE DERRICK. -BRIDLE DOWN. -R/U RIG FLOOR EQUIPMENT. -INSTALL AND SECURE ALL LANDINGS AROUND RIG. 13:00 - 15:30 2.50 DHB P DECOMP PJSM.PRESSURE TEST TWC FROM ABOVE. -RIG UP LINES AND TEST EQUIPMENT. PRESSURE TEST TWC FROM ABOVE TO 250/3,500 PSI FOR 5 CHARTED MINS EACH.- TEST PASS. BLEED OFF ALL PRESSURE AND R/D LINES/ TEST EQUIPMENT. -VOID DRY HOLE TREE OF FLUID. *SIMOPS: -POSITION,SPOT AND R/U CUTTINGS BOX, CREW TRAILER AND BULK FUEL TANK. -HARDLINE CREW,R/U AND TEST HARDLINE FROM RIG TO FLOWBACK TANK TO 250/ 4,200 PSI FOR 5 CHARTED MINS EACH.- TEST PASS. -PREPARE PITS AND TAKE ON 9.8 PPG UNHEATED BRINE. -HEAT 9.8 PPG BRINE IN PITS TO 120°. *RIG ACCEPTED AT 11:00 HRS,2/16/2015. Printed 3/9/2015 10:50:58AM North America-ALASKA-BP Page 4 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 X4-0111R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:OOAM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292209600 Active datum:ORIG KELLY BUSHING @40.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 18:00 2.50 WHSUR P DECOMP PJSM WITH RIG CREWAND FMC REPS. NIPPLE DOWN 4-1/16"x 13-5/8"5M ADAPTER AND 4-1/16"DRY HOLE TREE. -CAMERON REPS,BLED ALL PRESSURE FROM ADAPTER VOID AND CONTROL LINES. -N/D ADAPTER AND DRY HOLE TREE. *BARRIERS IN PLACE=TWC,TTP,PACKER, CSG VALVES,KWF AND TBG HANGER. 18:00 - 22:30 4.50 BOPSUR P DECOMP PJSM. NIPPLE UP 13-5/8"5M BOPE. -N/U 13-5/8"5M SPACER SPOOL. N/U 13-5/8"BOPE. CHANGE UPPER PIPE RAMS F/9-5/8"FIXED RAMS T/3-1/2"x 6"VBR AND LOWER PIPE RAMS F/2-7/8"x 5"VBR T/3-1/2"x 6"VBR. R/U HYDRAULIC CONTROL LINES,CHOKE AND KILL LINES TO BOPE. -R/U TURN BUCKLES,BELL NIPPLE,FLOW LINE,HOLE FILL LINE,BLEEDER LINES AND MOUSE HOLE. 22:30 - 23:30 1.00 BOPSUR P DECOMP RIG EVACUATION DRILL. -CONDUCT RIG EVACUATION DRILL DUE TO SIMULATED IGNITION OF H2S RELEASE, CAUSING ONE MAN TO GO DOWN, •FOLLOWED BYAAR. *SIMULATED ESD OF RIG AND ALL RIG CREW • 'MEMBERS REPORTED TO SAFE BRIEFING AREA. 23:30 - 00:00 0.50 BOPSUR P DECOMP PJSM. RIG UP TO PRESSURE TEST 13-5/8" 5M BOPE. -INSTALL BAILS AND ELEVATORS. -R/U LINES AND TEST EQUIPMENT. 'OA PRESSURE AT 00:00 HRS=20 PSI 2/17/2015 00:00 - 00:30 0.50 BOPSUR I P DECOMP SERVICE RIG. -LUBRICATE TOP DRIVE,ST-80 AND BLOCKS. -INSPECT AND SERVICE PIPE SKATE RIG FLOOR EQUIPMENT. -CROWN-O-MATIC AND SPCC CHECKS- GOOD. 00:30 - 01:30 1.00 BOPSUR P DECOMP RIG EVACUATION DRILL. -CONDUCT RIG EVACUATION DRILL DUE TO SIMULATED H2S RELEASE,CAUSING ONE MAN TO GO DOWN,FOLLOWED BY AAR. *SIMULATED ESD OF RIG AND ALL RIG CREW MEMBERS REPORTED TO SAFE BRIEFING AREA. 01:30 - 02:30 1.00 BOPSUR P DECOMP PJSM. FUNCTION TEST ROPE. -FUNCTION TEST ALL BOPE COMPONENTS FROM REMOTE PANEL.-TEST PASS. -R/U STACK WASHER. -WASH AND WARM BOPE WITH HEATED 9.8 PPG BRINE. -R/D STACK WASHER. -BLOW DOWN TOP DRIVE. -VOID BOPE OF 9.8 PPG BRINE. Printed 3/9/2015 10:50:58AM North America-ALASKA-BP Page 5 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 X4-0111R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292209600 Active datum:ORIG KELLY BUSHING @40.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 04:30 2.00 BOPSUR P DECOMP PJSM ON TESTING BOPE,WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. SHELL TEST 13-5/8"5M BOPE. -R/U FLOOR VALVES,CROSSOVERS BOPE TEST ASSEMBLY AND EQUIPMENT. -ESTABLISH EXCLUSION ZONES AND NOTIFY ALL ON WELL SITE OF PRESSURE TESTING OPERATIONS IN PROGRESS. FILL STACK AND CHOKE MANIFOLD TO MGS. 9 BBLS TO FILL GAS BUSTER. -ATTEMPT TO SHELL TEST BOPE WITH ANNULAR PREVENTER SHUT ON 3-1/2"TEST JT.-NO SUCCESS. LEAK OBSERVED ON BLIND/SHEAR RAMS AND BLIND/SHEAR RAM DOOR SEALS. 04:30 - 06:30 2.00 BOPSUR N RREP DECOMP PJSM.INSPECT BLIND/SHEAR RAMS AND DOOR SEALS. -VOID BOPE OF FLUID. -BLOW CHOKE MANIFOLD AND CHOKE/KILL LINES. OPEN BLIND/SHEAR RAM DOORS. REMOVE AND INSPECT BLIND/SHEAR RAMS AND DOOR SEALS. OBSERVED DAMAGE ON LOWER BLIND/SHEAR RAM SEALS. *BARRIERS IN PLACE=TWC,TTP,PACKER, CSG VALVES,KWF AND TBG HANGER. -SECURE WELL FOR SAFETY STAND DOWN. 06:30 - 10:00 3.50 BOPSUR P DECOMP SAFETY STAND DOWN W/ALL CREW MEMBERS,DOYON TOOLPUSHER AND SUPERINTENDENT. -BP SUPERINTENDENT AND WSL,SITE CONTROL SPECIALIST AND WSL OF THE FUTURE ALSO PARTICIPATING. -DISCUSS RECENT INCIDENTS AND REVIEW PLAN TO COMMIT TO WORK SAFELY. -RIG CREW CREATES ITS OWN PERSONAL PLAN TO IMPROVE WITH EACH CREW MEMBER CONTRIBUTING. -PLAN IS REVIEWED AND SENT TO BP SUPERINTENDENT.PERMISSION IS RECEIVED TO GO BACK TO WORK. 10:00 - 12:00 2.00 BOPSUR N RREP DECOMP PJSM.REPLACE BLIND/SHEAR RAMS AND DOOR SEALS. -INSPECT RAM CAVITIES. -INSTALL NEW BLIND/SHEAR RAMS AND DOOR SEALS. 12:00 - 12:30 0.50 BOPSUR P DECOMP SERVICE RIG. LUBRICATE TOP DRIVE,ST-80 AND BLOCKS. -INSPECT AND SERVICE PIPE SKATE RIG FLOOR EQUIPMENT. -CROWN-O-MATIC AND SPCC CHECKS- GOOD. *OA PRESSURE AT 12:00 HRS=20 PSI 12:30 - 13:30 1.00 BOPSUR N RREP DECOMP PJSM.REPLACE BLIND/SHEAR RAMS AND DOOR SEALS. -CLOSE AND SECURE BLIND/SHEAR RAM DOORS. Printed 3/9/2015 10:50:58AM North America-ALASKA-BP Page 6 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 X4-0111R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UVN:500292209600 Active datum:ORIG KELLY BUSHING @40.45usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth Phase : Description of Operations (hr) (usft) 13:30 - 14:00 0.50 BOPSUR P DECOMP PJSM ON TESTING BOPE,WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. SHELL TEST 13-5/8"5M BOPE. -R/U FLOOR VALVES,CROSSOVERS BOPE TEST ASSEMBLY AND EQUIPMENT. -ESTABLISH EXCLUSION ZONES AND NOTIFY FALL ON WELL SITE OF PRESSURE TESTING OPERATIONS IN PROGRESS. -FILL STACK AND CHOKE MANIFOLD TO MGS. "9 BBLS TO FILL GAS BUSTER. -SHELL TEST BOP WITH ANNULAR PREVENTER SHUT ON 3-1/2"TEST JT,TO 250 /3,500 PSI. TEST PASS. 14.00 - 18:30 . 4.50 BOPSUR P DECOMP PRESSURE TEST 13-5/8"5M BOPE UTILIZING DONUT TEST JOINTS,AS PER DDI SOP, • AOGCC AND BP REQUIREMENTS. -PRESSURE TEST BOPE WITH 3-1/2"AND 4" TEST JTS TO 250/3,500 PSI FOR 5 CHARTED MINS EACH.-TEST PASS. -PRESSURE TEST ANNULAR PREVENTER WITH 3-1/2"TEST JT TO 250/3,500 PSI FOR 5 CHARTED MINS EACH.-TEST PASS. PERFORM ACCUMULATOR DRAW DOWN TEST.-TEST PASS. *TEST UPPER PIPE RAMS AND LOWER PIPE RAMS,DRESSED WITH 3-1/2"x 6"VBR WITH 3-1/2"AND 4"TEST JTS. 1*TEST DART VALVE,(2)SAFETY VALVES,ALL CHOKE VALVES AND VALVES ON MUD CROSS. *TEST IBOP AND UPPER AND LOWER KELLY VALVES. *TEST GAS ALARMS. CHUCK SCHEVE WITH AOGCC,WAIVED WITNESS ON 2/16/2015 AT 07:45 HRS. 18:30 - 19:00 0.50 BOPSUR P DECOMP PJSM. RIG DOWN BOPE TEST EQUIPMENT. -BLOW DOWN CHOKE MANIFOLD AND CHOKE/KILL LINES. -VOID BOPE OF FLUID. -R/D BOPE TEST ASSEMBLY AND EQUIPMENT. 19:00 - 22:00 3.00 BOPSUR N RREP DECOMP PJSM. REPLACE WASH PIPE PACKING ON TOP DRIVE. REPLACE WASH PIPE PACKING ON TOP DRIVE. -TEST WASH PIPE ON TOP DRIVE TO 250/ 3,500 PSI FOR 5 CHARTED MINS EACH.- TEST PASS. Printed 3/9/2015 10:50:58AM North America-ALASKA-BP Page 7 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 X4-0111R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292209600 Active datum:ORIG KELLY BUSHING©40.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) '22:00 - 00:00 2.00 DHB P DECOMP PJSM WITH RIG AND DSM CREW. RIG UP AND TEST DUTCH RISER/DSM LUBRICATOR TO RETRIEVE TWC. -MOB DSM LUBRICATOR TO RIG FLOOR. -R/U DUTCH RISER AND RILDS. -CLOSE ANNULAR PREVENTER. -R/U DSM LUBRICATOR WITH QTS. -R/U LINES AND TEST EQUIPMENT. -PRESSURE TEST DUTCH RISER AND DSM LUBRICATOR TO 250/3,500 PSI FOR 5 CHARTED MINS EACH.-TEST PASS. *OA PRESSURE AT 00:00 HRS=30 PSI 2/18/2015 00:00 01:30 1.50 DHB P DECOMP PJSM WITH RIG AND DSM CREW. RETRIEVE TWC. -RETRIEVE TWC WITH TESTED LUBRICATOR.. *NO PRESSURE UNDER TWC. TBG AND IA PRESSURE=0 PSI,OA PRESSURE=30 PSI. -R/D AND L/D LUBRICATOR WITH TWC. -OPEN ANNULAR PREVENTER. '-BOLDS ON DUTCH RISER. -L/D DUTCH RISER. *OA PRESSURE AT 00:00 HRS=40 PSI 01:30 - 03:00 1.50 CONDHL P DECOMP PJSM. RIG UP TO CIRCULATE OUT DIESEL FREEZE PROTECT. -R/U CHOKE SKID AND LINES TO CIRC OUT FREEZE PROTECT. -PURGE AND PRESSURE TEST LINES FROM MUD PUMP TO CHOKE SKID TO 250/3,500 PSI FOR 5 CHARTED MINS EACH.-TEST PASS. 03:00 - 04:30 1.50 CONDHL P DECOMP PJSM WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. CIRCULATE OUT DIESEL FREEZE PROTECT. -PUMP 14 BBLS OF 9.8 PPG BRINE DOWN IA, TAKING RETURNS UP TUBING TO FLOWBACK TANK. *PUMP RATE=4 BPM WITH 500 PSI. -LINE UP TO PUMP DOWN TUBING. -PUMP 78 BBLS OF 9.8 PPG BRINE DOWN TUBING,TAKING RETURNS UP IA TO FLOWBACK TANK. *PUMP RATE=5 BPM WITH 650 PSI. *APPROXIMATELY 40 BBLS DIESEL RECOVERED. -ACQUIRE SLOW PUMP RATES. *#1 MP=30 SPM WITH 130 PSI,40 SPM WITH 290 PSI. -10 MIN FLOW CHECK.-WELL STABLE. -BLOWN DOWN CHOKE SKID AND CIRC LINES. Printed 3/9/2015 10:50:58AM North America-ALASKA-BP Page 8 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 X4-0111R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292209600 Active datum:ORIG KELLY BUSHING @40.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 06:00 1.50 CONDHL P DECOMP PJSM. RIG UP KILL LINE TO BOPE AND PRESSURE TEST SAME. -R/U KILL LINE TO BOPE. -R/U TEST EQUIPMENT. '-PRESSURE TEST KILL LINE TO 250/3,500 PSI FOR 5 CHARTED MINS EACH.-TEST PASS. BLOW DOWN CHOKE SKID AND CIRC LINES. -R/D TEST EQUIPMENT. 06:00 - 07:00 1.00 PULL P DECOMP PJSM WITH RIG CREWAND FMC REP. REVIEW PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. PULL TUBING HANGER FREE AND CIRCULATE BOTTOMS UP THROUGH MUD GAS SEPARATOR. M/U X-OVER TO FOSV FOR WELL CONTROL. -M/U LANDING JT WITH X-OVER TO TOP OF TBG HANGER. "7 1/2 TURNS -M/U TOP DRIVE. -FMC REP,BOLDS. *LDS OUT=4 3/4" -PULL HANGER FREE AND 3'OFF SEAT. -CLOSE ANNULAR PREVENTER. -ATTEMPT TO CIRC B/U THRU MGS. -BRING ON PUMP AND STAGE UP PUMP RATE TO 6 BPM,PRESSURE UP TO 1,300 PSI AND OBSERVED STRING WT LOSS OF 20K ON WT INDICATOR. -SHUT DOWN PUMP. 10 MIN FLOW CHECK.- WELL STABLE. -VERIFY NO PRESSURE AND OPEN ANNULAR PREVENTER. -PULL TBG HANGER TO RIG FLOOR AND CLOSE ANNULAR PREVENTER. "PUW=120K, SOW=95K(ALL WT CHECKS INCLUDE 40K TOP DRIVE). 07:00 - 10:00 3.00 CONDHL P DECOMP PJSM.CIRCULATE BOTTOMS UP THRU MUD GAS SEPARATOR. -ACQUIRE SLOW PUMP RATES. "#1 MP=30 SPM WITH 130 PSI,40 SPM WITH 240 PSI. -CIRC B/U THRU MGS AT 6 BPM WITH 560 PSI,UNTIL CLEAN RETURNS. "ICP=660 PSI, FCP=560 PSI *TOTAL VOLUME PUMPED=835 BBLS "SIMOPS: -MOB POWER TONGS,SPOOLING UNIT AND 3-1/2"HANDLING EQUIPMENT TO RIG FLOOR. -R/U POWER TONGS AND 3-1/2"HANDLING EQUIPMENT. Printed 3/9/2015 10:50:58AM North America-ALASKA-BP Page 9 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 X4-0111R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:OOAM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292209600 Active datum:ORIG KELLY BUSHING @40.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 10:30 0.50 CONDHL P DECOMP MONITOR WELL. -10 MIN FLOW CHECK.-WELL STABLE. -VERIFY NO PRESSURE AND OPEN ANNULAR PREVENTER. -BREAK CIRC AT 2 BPM WITH 180 PSI. TOTAL VOLUME PUMPED=10 BBLS -ACQUIRE SLOW PUMP RATES. *#1 MP=30 SPM WITH 140 PSI,40 SPM WITH 250 PSI. -10 MIN FLOW CHECK.-WELL STABLE. -BLOW DOWN CHOKE MANIFOLD AND CIRC LINES,DRAIN MUD GAS SEPARATOR. 10:30 - 12:00 1.50 PULL P ' DECOMP PJSM WITH RIG CREWAND SLB SPOOLER. TERMINATE CONTROL LINE AND LAY DOWN TUBING HANGER. -BLOW DOWN TOP DRIVE. -R/U 3-1/2"HANDLING EQUIPMENT AND SLB SPOOLING UNIT. L/D LANDING JT AND TBG HANGER ASSEMBLY. *NO FLUID LOSSES LAST(12)HRS BLED OA AT 10:30 HRS F/50 PSI T/10 PSI (ALL GAS) 12:00 - 12:30 0.50 PULL P DECOMP SERVICE RIG. -LUBRICATE TOP DRIVE,ST-80 AND BLOCKS. -INSPECT AND SERVICE PIPE SKATE RIG FLOOR EQUIPMENT. -CROWN-O-MATIC AND SPCC CHECKS- GOOD. 12:30 - 17:00 4.50 PULL P DECOMP PJSM WITH RIG CREWAND SLB REP. PULL OUT OF HOLE,LAYING DOWN 3-1/2"9.2# 13CR-80 VAMTOP COMPLETION. -PUMP A DRY JOB(WEIGHTED PILL)DUE TO FLUID U-TUBING. -POOH,LAYING DOWN 3 1/2"COMPLETION TO PIPE SHED,SPOOLING SINGLE CONTROL LINE F/RCT CUT AT 12,883 T/10,736'. TERMINATE CONTROL LINE AND UD SSSV ASSEMBLY. RECOVERED:(6)3-1/2"PUP JTS,(64)JTS OF 3-1/2"TBG AND(72)SS BANDS. -R/D SLB CONTROL LINE SPOOLING UNIT AND CONTROL LINE. -CLEAN AND CLEAR RIG FLOOR OF CONTROL LINE SPOOLING EQUIPMENT. *BLED OA PRESSURE TO O PSI AT 15:00 HRS. (ALL GAS). 17:00 - 00:00 7.00 PULL P DECOMP PULLOUT OF HOLE,LAYING DOWN 3-1/2" 9.2#13CR-80 VAMTOP COMPLETION. POOH,LAYING DOWN 3 1/2"COMPLETION TO PIPE SHED F/10,736'T/6,107'. *RECOVERED:(147)JTS OF 3-1/2"TBG *TOTAL OF(211)JTS RECOVERED. *NO FLUID LOSSES LAST(12)HRS Printed 3/9/2015 10:50:58AM • North America-ALASKA-BP Page 10 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 X4-0111 R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292209600 Active datum:ORIG KELLY BUSHING @40.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/19/2015 00:00 - 00:30 0.50 PULL P DECOMP SERVICE RIG. -LUBRICATE TOP DRIVE,ST-SO AND BLOCKS. -INSPECT AND SERVICE PIPE SKATE RIG FLOOR EQUIPMENT. -CROWN-O-MATIC AND SPCC CHECKS- GOOD. 00:30 - 06:00 5.50 PULL P DECOMP CONTINUE TO PULL OUT OF HOLE,LAYING DOWN 3-1/2"9.2#13CR-S0 VAMTOP COMPLETION. -POOH,LAYING DOWN 3 1/2"COMPLETION TO PIPE SHED F/6,107'T/SURFACE. *RECOVERED:(191)JTS OF 3-1/2"TBG *TOTAL OF(402)JTS RECOVERED. *5 GLM MANDRELS. *72 SS BANDS. 1 -CUT OFF JT=7.82',JT#402 WITH PERFORATIONS. *NO FLUID LOSSES LAST(6)HRS 06:00 - 12:00 6.00 RUNCOM P RUNCMP PJSM.LOAD AND STRAP 3 1/2"TUBING IN PIPE SHED.(420 JTS). -CLEAR/CLEAN RIG FLOOR&EQUIPMENT. -SCHLUMBERGER OUT TO FORMULATE A LAYOUT PLAN FOR SPOOLERS. -0/A BLED DOWN FROM 10 PSI TO 0 PSI @ 09:00 HRS. 12:00 - 18:30 6.50 RUNCOM P RUNCMP PJSM.CONTINUE TO LOAD AND TALLY 3 1/2" VAM TOP TUBING IN PIPE SHED. -RIG UP SCHLUMBERGER SPOOLING UNITS ON RIG FLOOR. RIG UP SHEAVES,BRING SCHLUMBERGER EQUIPMENT TO FLOOR. -BRING CANNON CLAMPS TO RIG FLOOR, COUNT PIPE AND CHECK JEWELRY. R/U TORQUE TURN EQUIP. 18:30 - 00:00 5.50 RUNCOM P RUNCMP PJSM.RUN 3-1/2"9.3#13CR-80 VAMTOP COMPLETION. -CO.REP,PUSHER,HALLIBURTON,SLB,AND CREW IN ATTENDANCE. • -DISCUSS PIPE HANDLING SELF VERIFICATION CHECKLIST WITH CREWS -ALL TUBING DRIFTED WITH 2.867"OD DRIFT. -USE TORQUE TURN SERVICES TO 2,900 FT-LBS. -M/U TAIL PIPE ASSEMBLY AND PACKER -ALL CONNECTIONS BELOW PACKER BAKER-LOCED. -M/U SAPHIRE GAUGE AND ATTACH I-WIRE, TEST GAUGE MANDREL TO 5K PSI. -USE JET LUBE SEAL GUARD THREAD COMPOUND. -TEST I-WIRE EVERY 1100'MD -RIH FROM SURFACE TO 1659'MD. -©45 JTS IN,PUW=54K SOW=57K. -LOSSES TO THE WELL=0 BBLS. Printed 3/9/2015 10:50:58AM • North America-ALASKA-BP Page 11 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 X4-0111R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292209600 Active datum:ORIG KELLY BUSHING @40.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/20/2015 00:00 - 00:30 0.50 RUNCOM P RUNCMP SERVICE RIG. -LUBRICATE TOP DRIVE,ST-80 AND BLOCKS. -INSPECT AND SERVICE PIPE SKATE RIG FLOOR EQUIPMENT. CROWN-O-MATIC AND SPCC CHECKS- GOOD. 00:30 - 15:00 14.50 RUNCOM P RUNCMP RUN 3-1/2"9.3#13CR-80 VAMTOP COMPLETION. -ALL TUBING DRIFTED WITH 2.867 OD DRIFT. USE TORQUE TURN SERVICES TO 2,900 FT-LBS. -USE JET LUBE SEAL GUARD THREAD COMPOUND. '-CANNON CLAMP ON EVERY COLLAR. TEST I-WIRE EVERY 1100'MD -RIH F/1720'MD TO 8219'MD.UP WT=88K, DOWN WT=79K,INCLUDES 40K TOP DRIVE. -OA PRESSURE @ 09:00 =15 PSI,BLED TO 0 PSI. -LOSSES TO THE WELL @ 15:00=0 BBLS. 15:00 - 16:00 1.00 RUNCOM P RUNCMP PRE TOUR MEETING WITH CREW COMING IN FROM DAYS OFF. -REVIEW OF RECENT INCIDENTS AND DISCUSS OPERATIONS. -ORIENTATION OF(2)NEW HANDS AND REVIEW OF COMMITMENT TO SAFETY. -DOYON SAFETY,DOYON SUPERINTENDENT,BP SUPERINTENDENT PRESENT. 16:00 - 00:00 8.00 RUNCOM P RUNCMP CON'T RUN 3-1/2"9.3#13CR-80 VAMTOP COMPLETION. -ALL TUBING DRIFTED WITH 2.867"OD DRIFT. -USE TORQUE TURN SERVICES TO 2,900 FT-LBS. -USE JET LUBE SEAL GUARD THREAD COMPOUND. -CANNON CLAMP ON EVERY COLLAR. -TEST I-WIRE EVERY 1100'MD -RIH F/8219'MD TO 10371'MD.UP WT=108K, DOWN WT=90K,INCLUDES 40K TOP DRIVE. -PICKED UP CIM @ 8079'MD,CURRENTLY RUNNING IN HOLE W/TWO LINES -OA PRESSURE @ 00:00 =0 PSI. -LOSSES TO THE WELL @ 00:00=0 BBLS. -D1 KICK W/TRIPPING DRILL(SIMULATED SHEARING CONTROL LINE AND CIM LINE) 2/21/2015 00:00 - 00:30 0.50 RUNCOM P RUNCMP SERVICE RIG. -LUBRICATE TOP DRIVE,ST-80 AND BLOCKS. -INSPECT AND SERVICE PIPE SKATE RIG FLOOR EQUIPMENT. -CROWN-O-MATIC AND SPCC CHECKS- GOOD. Printed 3/9/2015 10:50:58AM • • North America-ALASKA-BP Page 12 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 X4-0111R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:OOAM Rig Release: Rig Contractor DOYON DRILLING INC. UWI:500292209600 Active datum:ORIG KELLY BUSHING @40.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 06:00 5.50 RUNCOM P RUNCMP PJSM,CON'T RUN 3-1/2"9.3#13CR-80 VAMTOP COMPLETION. -ALL TUBING DRIFTED WITH 2.867"OD DRIFT. -USE TORQUE TURN SERVICES TO 2,900 FT-LBS. -USE JET LUBE SEAL GUARD THREAD COMPOUND. -CANNON CLAMP ON EVERY COLLAR. -TEST I-WIRE EVERY 1100'MD -RIH F/10371'MD TO 12350'MD. -PICKED UP CIM @ 8079'MD,PICKED UP SCSSSV @ 10672'MD CURRENTLY RUNNING IN HOLE W/THREE LINES -OA PRESSURE @ 06:00 =5 PSI. -LOSSES TO THE WELL @ 06:00=0 BBLS. 06:00 - 09:00 3.00 RUNCOM P RUNCMP CONTINUE TO RIH W/3.5"9.3#13CR-80 VAM TOP TUBING W/I WIRE,CIL AND CONTROL LINE. -TORQUE TURNING CONNECTIONS TO 2900 FT/LBS,TESTING I WIRE EVERY 1000'. -CANNON CLAMPS ON EVERY COLLAR.UP WT=125K,DOWN WT=100K,ALL WT CHECKS INCLUDE 40K TOP DRIVE. -OBSERVE TAG ON 1ST SET OF SHEAR PINS ON OVERSHOT 22.5'IN ON JT#392.6K DOWN. -OBSERVE 2ND SET OF SHEAR PINS SHEAR ON OVERSHOT 30.5'IN ON JT#392,6K DOWN. -PICK UP JT#393 AND LOCATE OUT ON TUBING STUB W/OVERSHOT 33'IN ON#392& 393. -CALCULATE SPACE OUT,NO PUP JTS REQUIRED,WILL BE 5.7'OFF OF TUBING STUB. -LAY DOWN JTS#393ƈ. 09:00 - 12:00 3.00 RUNCOM P RUNCMP PJSM.PICK UP LANDING JT&HANGER.MAKE UP SAME. -SCHLUMBERGER AND FMC TERMINATE CIM, I WIRE AND CONTROL LINES AND TEST,OK. -DRAIN STACK AND LAND HANGER.FMC RUN IN LOCK DOWN SCREWS.3 3/4"=IN. -NO SLOW PUMP RATES TAKEN,391 JTS TOTAL RUN.LOSSES FOR LAST(12)HRS=0 BBLS. -SINGLE LINE CANNON CLAMPS USED=248, 3 LINE CANNON CLAMPS USED=151. -SINGLE LINE MID JT CLAMPS USED=13,3 LINE MID JT CLAMPS USED=5.SPECIAL CLAMPS USED=2. 12:00 - 14:00 2.00 RUNCOM P RUNCMP PJSM.CLEAR/CLEAN RIG FLOOR. -REMOVE SCHLUMBERGER SPOOLERS& TOOLS. -LAY DOWN LANDING JT.BREAK DOWN FLOOR VALVES&X/OS. -PLACE SUB RACK BACK IN PLACE,INSTALL SUBS ON SUB RACK,ORGANIZE FLOOR. Printed 3/9/2015 10:50:58AM North America-ALASKA-BP Page 13 of 13 Operation Summary Report Common Well Name:P2-59 AFE No Event Type:WORKOVER(WO) Start Date:2/15/2015 End Date:2/22/2015 1X4-0111R-E:(2,903,000.00) Project:Point McIntyre Site:Pt Mac 2 Rig Name/No.:DOYON 16 Spud Date/Time:11/5/1990 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292209600 Active datum:ORIG KELLY BUSHING @40.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 18:30 4.50 RUNCOM P RUNCMP PJSM.SPOT AND RIG UP LITTLE RED SERVICES. -MANIFOLD IN LITTLE RED LINES TO CIRCULATING MANIFOLD. -PRESSURE TEST LINES TO BE PUMPED WITH @ 250/3500 PSI. -PUMP 42BBLS OF 80DEG DIESEL @ 2.6BPM/450PSI T/FREEZE PROTECT. -LET DIESEL U-TUBE 1 HR. -MOBILIZE 2-7/8"X 5"RAMS TO CELLAR. 18:30 - 19:30 1.00 RUNCOM P RUNCMP INSTALL TWC AND TEST F/ABOVE T/250PSI LOW,3500PSI HIGH(GOOD TEST) -DRAIN BOPE -FMC REP ON HAND TO SET AND TEST TWC 19:30 - 22:00 2.50 '; RUNCOM P RUNCMP CLEAN AND CLEAR ALL FLUID LINES,CLEAR EXCESS TOOLS FROM RIG FLOOR -FLUSH BOPE W/JOHNNY WACKER -FLUSH CHOKE,TOP DRIVE,MUD PUMP, AND ALL SURFACE EQUIPMENT W/FRESH WATER -DRAIN STACK AND BLOW DOWN ALL LINES 22:00 - 00:00 2.00 RUNCOM P i RUNCMP CHANGE OUT UPPER PIPE RAMS T/2-7/8"X 5"VBR'S PJSM,PULL RISER/MOUSE HOLE/TURNBUCKLES/KOOMEY LINES -STATE NOTIFIED OF BOPE TEST FOR WELL P2-10,AOGCC REP BOB NOBLE WAIVED WITNESS -OA PRESSURE @ 00:00=0 PSI. -LOSSES TO THE WELL @ 00:00=0 BBLS. 2/22/2015 00:00 - 02:00 2.00 BOPSUR P RUNCMP CONT CHANGING UPPER PIPE RAMS T/2-7/8" XS" -CLOSE RAM DOORS,N/D BOPE BOLTS F/ WELL HEAD 02 00 - 06:00 4.00 WHSUR P RUNCMP RACK BACK BOPE ON STUMP,TERMINATE CONTROL LINES THROUGH WELLHEAD AND ADAPTER FLANGE. 06:00 - 07:00 1.00 WHSUR P RUNCMP PJSM.NIPPLE UP DRY HOLE TREE. -FILL W/DIESEL,VISUAL TEST ON TREE:250 PSI/5000 PSI/5 MIN EACH. 07:00 - 08:00 1.00 WHSUR P RUNCMP -SECURE WELL,RELEASE RIG @ 08:00 HRS., 02/22/2015. Printed 3/9/2015 10:50.58AM TREE= +' 4-1/2'CNV SAFETY S:WELL REQUIRES A SSSV "'DOGLEG/TIGHT ACTUATOR= BAKERC EAD= FMC P 2-59A BAARRER EXISTS B tETW®V UPPER& OWER OUI ER ANNULUS- ACTUAT 1471AL KB.ELI 40.45' SEE RVVO 2007 DRLG FLE FOR DE/ALS(06/14/09) BF.ELEV= 444 -4 KOP= 1050' �� �� 2224' -I3-1/2'SLB BP6i SCSSSV,D=2.813" 20"COND, - ? �� tj Max Angle= 97"@ 14947' 0 I 0 I !j 133#,K-55, i 0 13435' et GAS LFT/CHEMICAL MANDRELS Datum MD= --- • Datum ND= 8800'SSS D=18.750" �� 1",,� ST MD ND DEV TYPE VLV LATCH PORT DATE 9-5/8"HES ES CEMENTER -I 2745' 8 3517 2995 53 MMG DMY RK 0 02120/15 13-3/8'ESP,D=8.681" (NOT SET 04/08/07) -1 2748' '7 4817 3767 58 NM DMY RK 0 02120/15 _ 6 6620 4756 56 MMG DMY RK 0 02/20/15 9-5/8"CSG,47#,L-80 TC11,D=8.681" -{ 2765' . 5 7887 5507 55 MMS DMY RK 0 02/20/15 13-3/8"CSG,68#,N-80 CY HE,D=12.415" I- 2990' 4 9184 6253 57 MMG DMY RK 0 02120/15 3 10514 6997 53 MAG DMY RK 0 02/20/15 3/8"CAPLLARY TUBE -f 4817' 2 11562 7605 55 MAG DMY RK 0 02/20/15 1 12547 8195 49 MAG DMY RK 0 02120/15 •--................ 'STA#7=q 8N(AL MANDREL Minimum ID = 2.370" @ 13079'CTM 12680' 13-1/2"NIGPDCSNGLE DROP SAPPHRE LTP W/BKR SEAL ASSY 1 GUAGE,D=2.913" 12748' H3-1/2"HES X NP,D=2.813" \ 12780' -I9-518'X 3-1/2'HES TNT PKR,D=2.949" 3-1/2"TBG,9.2#,13CR-80 VAM TOP, -I 12881' �_ 12817' H3-1/2"I-ES X NP,113=2.813" VAM TOP,.0087 bpf,D=2.992' 3-1/2'TBG STUB(02/07/15) -112883' ELMD ' 12914' -I3-1/2'FES X NP,D=2.813" 9-5/8"X 3-1/2"UNIQUE OVERSHOT H 12896' 12935' H3-1/2'X 4-112"XO,D=2.992" (2( 12937' -19-518"X 4-112"BKR S-3 PKR 0=2.920' _ 12941' H4-112"X 3-1/2"XO,D=2.992' 3-1/2"TBG,9.2#,13CR-80, - 13012' I8 12992' -{3-112"HES X NP,ID=2.813" VAM TOP,.0087 bpf,D=2.992' _` \ 12992' -13-1/2"PX PLUG(02/03/15) 13012' -3-1/2"X4-1/2"XO,D=2.992" 4-1/2"TUBING STUB - 13014' 13016' --I9-5/8"X 4-1/2"UNIQUE OVERSHOT 4 N 13032' -14-1/2"PKR SWS X NP,D=3.813" \ 13039' -OTIS SBR&SEAL ASSY,D=3.850" 4-1/2"ECLPSE LTPw/BKR SEAL ASSY, -I 13079'CTM I g \ 1305T -I9-518"X 4-1/2"OTIS MSR PKR D=3.850' 1)=2.370"(13109'ELM LOGGED 11/05/06) \\\ 13063' -I6"OTIS MLLOUT EXT'4SION,D=4.768" 3-1/2'BKR DEPLOY SLV,D=3.00" 13112' 13112' -I9-5/8'OTIS TNv LNR PKR&HGR D=? BEHIND 13115' --14-1/2"PKR SWS X NP,D=3.813" CT LNR 14-112 TBG,12.6#,L80,.0152 bpf,D=3.958" 1--1 13147' - 13116' -13-1/2"X 3-3/16"XO,D=2.786" 9-5/8"CSG,47#,NT-80S NSCC,D=8.681" -I 13409' ' 13136' -14-1/2"PKR SWS X NP,D=3.813" BEHIND 1 13148' -14-1/2"WLEG,D=3.958" CT LNR 7"MARKER JOINT -I 13592' PERFORATION SUMMARY 7'MLLOUT WINDOW(P2-59A) 13643'- 13649' RIEF LOG: DFUSFUGR on 12/17/90 ANGLE AT TOP PERF: 60"@ 13720' 4\ 14670'ctrn {2.562"OD CIBP(10123/99) Note:Refer to Production D8 for historical pert data all* 14787'ctfrl -"FISH-MLLED&PUSHED SIZE SPF NTERVAL Opn/Sqz SHOT SQZ 141.•4�.... ` 41111iri TO BOTTOM(10/23/99) 11111111 SEE PG 2 FOR PERFORATION NFORMATION 1�1�1�1�1�1�11 i/ ` ` 14936' H PE/TD Illiir 3-3/16'LNR,6.2#,L-80 TCI, -{ 14970' 7"LNR,29#,L-80,.0371 bpf, D=6.184" -I 14348' .s+` .0076 bpf,D=2.800" -..„1, DATE I REV BY COMMENTS DATE REV BY COMMENTS PONT WINTY RE UNIT 12/22/90 ALAI 3 ORIGINAL COMPLETION WELL P2-59A 05/05/99 CTD SIDETRACK PERMIT No:9982010 04/19/07 N4ES RWO AR Nb: 50-029-22096-01 02/22/15 0-16 RWO SEC 14,T12N,R14E,535'FNL&1048'FWL 03/04/15 JMD DRLG HO CORRECTIONS 03/20/15 SIWJMD ANAL ODE APPROVAL BP Exploration(Alaska) P2-59A • ., p 4 �.� o.. A I In ■ I I l r I 23 PERFORATION SUMMARY B RE=LOG: DFUSFUGR on 12/17/90 ANGLE AT TOP PERF: 60`@ 13720' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 2" 6 13720- 13900 0 07/30/07 2" 6 13722-13742 0 01/24/14 2" 6 13772- 13792 0 01/24/14 2" 6 13822-13842 0 01/25/14 2" 6 13872- 13892 0 01/26/14 2" 6 13900-14150 0 04/17/05 2" 6 14250-14350 0 04/17/05 2-1/8" 6 14570- 14630 0 05/04/99 2" 6 14730- 14806 C 08/23/99 2" 6 14806-14889 C 08/23/99 2' 6 14889- 14930 C 08/23/99 1 • aoir .....I.4 //**41, DATE REV BY COMMENTS DATE ' REV BY COMMENTS PONT MCNTY RE UNT 12/22/90 AUCI 3 ORIGINAL COMPLETION WELL: P2-59A 05/05/99 CTD SIDETRACK PERMIT No:'1982010 04/19107 N4E6 F VO AR No: 50-029-22096-01 02/22/15 D-16 RYVO SEC 14,T12N,R14E,535'FNL&1048'FWL 03/04/15 IAD DREG HO CORRECTIONS 03/20/15 SMUMD ANAL ODEAR'ROVAL BP Exploration(Alaska) It 1�11 ,nn Regg, James B (DOA) From: AK, OPS Gas Lift Engr [AKOPSGasLiftEngr@bp.com] Sent: Wednesday, May 11, 2011 4:34 PM To: Regg, James B (DOA) Subject: AOGCC, Request approval to install PB (K Type) Valve in Well P2-59 Attachments: P2-59 2011-04-28 PB valve.xls Hello Jim, Not sure if my alternate sent this to you. If so, please disregard. Per the AOGCC correspondence dated June 16, 2006, Bulletin No. 06-04 regarding subsurface controlled subsurface safety valves, I am requesting approval to install a "PB" Valve in well P2-59. P2-59 has a failed and inoperable TRSSSV and now requires the installation of a PB -Valve to meet state regulations. Attached is the PB valve design sheet that contains all pertinent information/data regarding the well's flow characteristics, PB -Valve configuration, trip/closure pressure, etc. If you have not already received this request, my alternate must have failed to submit it to you. If you have any design questions please feel free to contact me. «P2-59 2011-04-28 PB valve.xls>> Thanks, Johnny Kenda Arctic Lift Systems Inc. GPB, Gas Lift Eng. 907-659-5863 907-659-3423 (p) 601-807-8992(c) 6'�,,4NNED MAR 6- 7 2012 mmo RDW rruwwu xruMsaw[us .� Well: P2-59 Date: 4/28/2011 Wireline Work Request p-fD AFE: APMP02WL59 Engineer: Stan Groff Ver. c.1 rie/ot P2-59 Distribution Wireline (4) Reading File IOR: 200 FTS: IOR AWGRS Job Scope: PB SV H2S Level: ........................................................... Problem Description According to new AOGCC regulations a subsurface safety valve needs to be installed in this well. A Weatherford PB safety valve will be used. NOTE: Pressures were recorded by gauge at FTP of 224 psi and 374 psi. Valve calculations were based on these pressures. Initial Problem Review Remedial Plan - WIRELINE ACTION Install PB safety valve set at Ptro of 430 psi at 60"F. Operate well at >450 psi. Valve designed to close when FTP drops to 200 psi. I. Date Work Completed Problem Resolved ? Y N: Well Status/Results Date Well Review (Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Avg. WC (%) Lift Gas (MMSCF/D) TGLR (SCF/STBL/D) FTP (psi)/Steady? CLP (psi)/Steady? Casing Press. (psi)/Steady? Orifice Depth: IA Fluid Level: Date of FL Survey: Follow-up Recommendations: Expected NOB: Actual NOB: MGOR used for NOB.- Orifice OB: by MAINTENANCE ONLY (e.g. Fix AC, Shallower for Slugging) RATE (Non -Post -WW) (e.g. deepen, optimize orifice) Post-Wellwork "PB" Valve Calculation Sheet Well # P2-59 (Pi, 1w m" ) Date: 04/28/11 Test Data Test Date 04/19/11 Gross Fluid Rate 1347 BLPD Flowing Well Head Pressure 224 psi Flowing Well Head Temperature 58 deg F GOR 5789 scf/bbl TGLR 3630 scf/bbl Setting pressures based on measured data taken at time of test. Flowing Pressure Calculations Based on Muk -Brill Multiphase Flow Correlation "K" Valve Setting Depth TVD 2036 ft Flowing Tubing Pressure With Gas Lift 224 psi Flowing Tubing Pressure Without Gas Lift N/A psi Valve set to close at 225# Pwh Flowing Tubing Pressure @ 25# Pwh 992 psi PB" Valve Test Rack Set Pressure at 60 deg F 619 psi NOTE: Well needs to flow at > 450# Pwh Valve set to close at 225# Pwh K Tubing Pressure at Valve 622 BPT (psis) 636 >1238 <1238 Temperature (deg F) at Valv 62.5 a 4.6E-07 7.635E-07 b 1.005745 1.004835 Base Pressure 633.355024 c -637.0675 -636.40565 Base Temp (TV -60) 2.5 633.24505 633.038943 Corrected Pressure 633.038943 psia TCF 0.99471864 olume Ratio for Valve Size = 1.257 Pb @ 60 = Test Rack Pressure = 618.714995 492 Volume Ratios 4 1/2" & 5 1/2" 1.314 3 1/2"' 1.257 2 7/8" 1.211 2 3/8" j 1.204 e e WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 EDE Disk P2 - 59 P2 - 59 Coil Flag Jewelry Log 28-Jul-07 I ~33ö 28-Ju1-07 f 5"3d ~ 1) 2) 3) 4) 5) 6) 7) EDE Disk 1~ff -c90( Sf;ANNED AUt; 11 Z007 Signed: {}_lL E:lV- ED' "... ,<¡¡.; \1- - -- ' REC' ~."-' Print Name: (if... f ~.f-¡ Á (,L ¡1An. b fA.,~ o.i Date : !\Jaska Oil & Gas Cons. commission Anchoæ~e AUG 1 6 Z007 PROAcTIVE DIAGNOSTIC SERVICES, INc., 130 W.INTERNATlONALAIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEæ¡)MEMORYLOG.COM WEBSITE: W\I'JW.MEMORYLOG.COM D:\Master _Copy _00_ PDSANC-2OxxIZ _ Wonl\Disttibution\Transmittal_ Sheets\Transmit_ OriginaI,doc RE: Nabors 4 -ES BOP stack confilauration for P2 -59A Subject: RE: Nabors 4 -ES BOP stack configuration for P2 -59A From: "Reem, David C" <ReemDC@BP.com> Date: Tue, 27 Mar 2007 09:38:38 -0800 To: Thomas Maunder <tom_maunder@admin. state.ak.us> Tom, maximum anticiapted WHP here is 3160 psi so thus the required 4 -ram stack. What is significantly different on this well is the fact that it was a PM2 exploration well that was drilled before the pad was built up w/gravel. As such, you can open up the wellhouse and stub your toe on the swab cap. The wellhead is —8' below the gravel surface which allows us to get the 4 -stack BOPE under 4ES`s floor.... unlike when the wellhead is above the gravel level. Hope this explanation helps out in why we're headed down this road. From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, March 27, 2007 9:34 AM To: Roach, Frank Cc: Reem, David C Subject: Re: Nabors 4 -ES BOP stack configuration for 132-59A Frank and Dave, Could you provide a little explanation of the change. As I remember 4ES usually runs 2 rams and an annular. In this case there are 3 rams. ...�.-�....- Thanks in advance, Tom Maunder, PE AOGCC Roach, Frank wrote, On 3/27/2007 9:04 AM: SCANNED MAR 2 7 2007 Mr. Maunder, «4ES BOP Config P2-59A.ZIP>> Attached is the proposed BOP configuration for P2 -59A. Weather permitting, we should be moving onto the well sometime tomorrow. Any questions or concerns, please let me know. Regards, -Frank Roach I of 1 3/27/2007 9:49 AM 2-7/8" x 5" VBR Blind/Shear Rams (14" Operators) Mud Cross 3-1/2" x 6" VBR 54 1/8" 55 1/8" 33 1/4" 19 1/2" CAL 189 15' 9" Studded 44 1/4" Flanged 55 1/8" Jay Measured 57 3/4" �_ i · STATE OF ALASKA A /ffó-¡ RECEIVED ALAWÁ OIL AND GAS CONSERVATION COM~ION MAY 1 6 2007 REPORT OF SUNDRY WELL OPERATIONS i~laska Oil & Gas Cons. Commission 1. Operations Performed: " o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 198-201 ~ 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22096-01-00 - 7. KB Elevation (ft): 40.45' 9. Well Name and Number: ^ PBU P2-59A ~ 8. Property Designation: 10. Field I Pool(s): ADL 365548 ./ Prudhoe Bay Field I Point Mcintyre Pool 11. Present well condition summary Total depth: measured 14975 / feet true vertical 9028 ' feet Plugs (measured) 14670 Effective depth: measured 14670 feet Junk (measured) None true vertical 9033 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 114' 20" 114' 114' 2320 1500 Surface 2990' 13-3/8" 2990' 2679' 5020 2270 Intermediate 13409' 9-5/8" 13409' 8820' 6870 4760 Production Liner 531' 7" 13112' - 13643' 8587' - 9008' 8160 7020 Liner 1858' 3-3/16" 13112' - 14970' 8587' - 9028' SCANNED MAY 2'22007 Perforation Depth MD (ft): 13900' - 14930' Perforation Depth TVD (ft): 9070' - 9033' 3-1/2",9.2# x 4-1/2", 12.6# 13Cr80 I L-80 13148' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 3-1/2" Baker 'S-3' packer; 12937'; 9-5/8" x 4-112" Otis 'MHR' packer 13057' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pulled tubing from -13014', dressed to -13023'. Cut and pull 9-5/8" casing from -2763'. Run 9-518" tieback, cemented wi 180 Bbls of Class 'G' (1011 cu ft 11.16 Yield). Run new 3-1/2" Chrome tubina to tubina stub at -13014. 13. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Kris Hanas, 564-4338 307 -020 Printed Name Terrie Hubble Title Technical Assistant Signature ~fll\ I' (J ~~ OS;[I ,/c. Prepared By Name/Number: Phone 564-4628 Date I c.:. D7 Terrie Hubble, 564-4628 Form 10-404 Revise'ã' 04/2006 !'lNl JU.." I#"l MAY , 1 1007 Submit Original Only OR' h I ~, f\ I 2 It-l \ '" Digital Wellfile , . Page 1 of 2 . Well: P2-59 Well Events for SurfaceWell - P2-59 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GPMA -> P2 -> P2-59 Date Range: 07/Feb/2007 to 27/Mar/2007 Data Source(s): DIMS, AWGRS Events Source Well 8Y'LGRS P2-59A AWGRS P2-59A Date 03/26/2007 03/25/2007 AWGRS P2-59A 03/24/2007 A_WGRS P2-59A 03/23/2007 AWGRS P2-59A 03/23/2007 AWGRS P2-59A 03/22/2007 8WGRS P2-59A 03/22/2007 AWGR~ P2-59A 03/22/2007 AWGRS P2-59A 03/21/2007 AWGRS P2-59A 03/21/2007 8WGRS P2-59A 03/21/2007 AWGRS P2-59A 03/20/2007 8WGRS P2-59A 03/19/2007 8WGRS P2-59A 03/18/2007 AWGRS P2-59A 03/17/2007 Description T/I/O=20/25/200. Temp SI. WHP's (post bleed, pre rig). WHP's unchanged. T/I/O = 20/25/200. Temp = SI. Well house & flow line removed. Bleed WHP's to 0 psi (pre- rig). Bled TBGP from 20 psi to 0 psi in 20 min. SI monitor for 30 min. Bled lAP from 25 psi to o psi in 30 min. OA FL @ surface. Bled OAP from 200 psi to 180 in 1 hr & 30 min. Approx 25 bbls diesel returns. SI, monitored for 30 min. OAP increased 20 psi during monitor. Final WHP's 0+/0+/200. ***CONTINUED FROM 24-MAR-2007*** STRING SHOT / TUBING PUNCHER PERFORMED 09- MAR-2007. CHEMICAL CUT 4-1/2" TUBING AT 13014' WITH 3-5/8" SLB POWER CUTTER. *****JOB COMPLETE***** STRING SHOT / TUBING PUNCHER PERFORMED 09-MAR-2007. CHEMICAL CUT 4-1/2" TUBING @ 13,014' ***CONTINUED ON 24-MAR-07*** ***WSR CONTINUED FROM 3/22/2007*** (Pre rwo) DUMP BAILER 2 (50 LBS) BAGS OF SLUGGITS ON TOP OF 4 1/2" WRP PLUG @13,056' SLM. RDMO. ****LEFT SSV DUMPED, AND NOTIFIED DSO OF WELL STATUS**** *** WELL SHUT IN *** (dump bail sluggits) RIG UP SLICKLINE UNIT. IN THE PROCESS OF RUNNING DUMP BAILER WITH 1 (50 LBS) BAG OF SLUGGITS. ****JOB STILL IN PROGRESS, WSR CONTINUED ON 3/23/2007**** T/I/O = 120/Vac/0 CMIT TxlA to 3500 psi (PASSED) (Pre RWO) Pumped 59 bbls of 9.8# brine. Pumped 17.9 bbls Diesel to reach test pressures. T/I lost % psi in first 15 min and 0/0 psi in second 15 min for a total loss of % psi in 30 min test. Bleed T/I pressures back, OA will not bleed down. Final WHPs 0/0/200 ***WSR CONTINUED FROM 3/21/2007*** (Pre rwo) RIG DOWN SLICKLINE UNIT ****LEFT SSSV DUMPED, NOTIFIED DSO OF WELL STATUS AND WRP IN HOLE**** Assist S-line, Job post-poned (s-line still fishing elements) ****WSR CONTINUED FROM 3/20/2007**** (Pre rwo) RAN 3.70" CENTRALIZER, 4.5" BL BRUSH, 3.61" SWAGE, BULLNOSE TO X-NIPPLE@ 13,007' SLM, RAN DOWN TO TAG LINER, LOCATED @ 13,080' SLM. PUH & FLAGGED WIRE @ 13,007' SLM, RECOVERED ( 4 ) HALF MOON PIECES OF PACKING. RAN 3.70" CENT, 4.5" BLB, BULLNOSE & BRUSHED X-NIPPLE. RECOVERED ( 1 ) FULL PIECE OF PACKING. SET 4 1/2" WRP PLUG WITH E-FIRE @13,056' SLM. (13,088' MD) RDMO. ****JOB STILL IN PROGRESS, WSR CONTINUED ON 3/22/2007**** T/I/O = 200/VAC/210. Temp = S/I. AL spool dropped. TBG and IA FLs (for SL). TBG FL @ 870'. IA FL indeterminate. ***WSR CONTINUED FROM 3/19/2007*** (Pre rwo) LATCHED AND PULLED 4 1/2" "XX" PLUG BODY FROM 13,009' SLM WITH BRAIDED LINE. RIG DOWN BRAIDED LINE AND SWAP BACK OVER TO .125" SLICKLINE TO SET E-FIRE/ WRP PLUG. ****JOB STILL IN PROGRESS, WSR CONTINUED ON 3/21/2007**** ***WSR CONTINUED FROM 3/18/2007*** (Pre rwo) ASSISTED DSO & GREASE CREW TO PREP TREE FOR RWO. MADE SEVERAL ATTEMPTS TO PULL 4 1/2" "XX" PLUG @13,009' SLM. RIGGED UP BRAIDED LINE WITH THIRD PARTY CRANE. ****JOB STILL IN PROGRESS, WSR CONTINUED ON 3/20/2007**** ***WSR CONTINUED FROM 3/17/2007*** (Pre RWO) ATTEMPT TO PULL XX TT PLUG @13,009' SLM (JAR 80 MINS). RAN 3.25" CENT, 10 x 2-1/4" P.BLR TO PLUG, BLR MT, GOOD MARKS ON BTM. ESTABLISHED WE CAN PUSH FLUID DOWN HOLE WITH GAS. FL STARTED AT 480', WITHIN 20 MINS FL DROPPED TO 1,875' SLM. RDMO TO ALLOW WELLHOUSE REMOVAL FOR UPCOMING RIG JOB. LATCH BACK UP TO TT PLUG AT 13,009'SLM WIGS. BLEEDING TBG PSI DOWN TO INITIAL SITP PRIOR TO JARRING ON PLUG. ***WSR CONTINUED ON 3/19/2007**** ***WELL WAS SHUT IN ON ARRIVAL*** (pre rwo) WSR CONTINUED FROM 3/16/2007. RAN 3" x 10' P.BLR TO 13,009'SLM (2 TBSP OF METAL SHAVINGS). RAN 3.75" CENT, 3.25" LIB TO 2,600' SLM, RAN INTO ASPHALTINES. RAN 3.27" CENT, 3.25" LIB TO 13,009' SLM (PIC OF TT PLUG FISHING NECK). RAN EQ.PRONG TO 13,009' SLM, NO PSI CHANGE, FL AT 740', MARKS ON PRONG. RAN KJ AND 3.80" GAUGE RING TO TOP OF PLUG AT 13,009' SLM. RAN 2 1/4" x 10' P.BLR ("'1 QUART OF SLUGGITS AND MARKS ON BTM). RIH W/4-1/2" GS TO PULL TT PLUG (SEE FL AT 600'). ****ATTEMPTING TO PULL PLUG, WSR CONTINUED ON 3/18/2007**** http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 5/14/2007 Digital Wellfile A\tVGRS P2-59A 03/16/2007 AWGRS P2-59A 03/15/2007 AWGRS P2-59A 03/10/2007 AWGRS P2-59A 03/09/2007 AWGRS P2-59A 02/13/2007 AWGRS P2-59A 02/13/2007 AWGRS P2-59A 02/12/2007 AwGRS P2-59A 02/12/2007 AWGRS P2-59A 02/11/2007 8WG_RS P2-59A 02/11/2007 AWGRS P2-59A 02/08/2007 AWGRS P2-59A 02/07/2007 . Page 2 of2 ***** Continued from 3/15 WSR ***** Circ-Out ( .WO). CMIT-TxIA (Failed) to 3500 psi. Pumped 20.8 bbls Diesel to reach test pressure.T/IA lost 400/400 and in the 2nd 15min T/IA lost 440/420 for a total loss of 840/820. Established an LLR of.2 bbls per min at 3000 psi. Bleed Pressure back to 0 psi MIT-OA (Failed) to 2000 psi.Pumped 50 bbls Diesel Established an LLR of 1.85 bbls per min at 800 psi. Bleed Pressure Back to 0 psi. Final WHPs 0/0/0. *****30B COMPLETE***** T/I/O = 900/900/150 Circ-Out (RWO Prep) . Pumped 5 bbls 60/40 Meth, 1340 bbls 9.8# Brine, 34 bbls 100*f Diesel down TBG taking returns up IA down jumper to Flow Line of P2- 60. Freeze Protected Flow Line of P2-60 w/ 15 bbls Diesel. ***Continued on 3/16/07 WSR*** T/I/0=650/860/140 Temp=SI No A/L Bleed TBG & lAP < 200 psi. (For E-line). TBG & IA FLs @ surface. Bled lAP from 860 psi to 660 psi in 30 min. TBG pressure tracked lAP and decreased to 450 psi. Returned 8 bbls to bleed trailer. Shut in and monitor for 15 min. TBG and IA pressure increased to 650 psi and 900 psi in 15 min. Final WHPs=650/900/140 INITIAL T/I/O 700/820/150. WELL SHUT-IN AT ARRIVAL. SMALL TUBING PUNCH, 4 SPF, 0 DEGREE PHASING, OVER INTERVAL 12,940- 12,942 FT 2 STRAND X 12 FT STRING SHOT OVER 13,003- 13,015 FT. BLED WHP TO 200 PSI, T/I/O RECOVERED TO 800/900/150. TAGGED SLUGGITS/PLUG AT 10,323 FT ELM ***JOB NOT COMPLETE*** T/I/O=850/900/250 CMIT Tx IA to 3500 psi (PASSED) MiT OA to 2000 psi (FAILED) - Established LLR of 1. 75 bpm @ 800 psi. (RWO prep) Tx IA pressured up to 3500/3500 psi with 14 bbls crude. T/I lost 80/40 psi in 15 minutes and 40/20 psi in second 15 minutes. For a total of 120/60 psi in 30 minutes. Bled pressure down. Pumped 50 bbls crude down OA to establish LLR of 1. 75 bpm @ 800 psi. Pressure fell imediately after shutting down. FWHP's= 1000/1000/160 *** CONT FROM 02-12-07 \tVSR *** (pre sdtrk) PULLED 41/2" XX TTP FROM X-NIP @ 13,027' SLM. RESET 4 1/2" XX TTP ON HP LOCK ( 25" OAL \tV/ (2) PCS 0.5 CAMCO PKG & (4) 1/8" & (4) 3/16" EQ PORTS) IN X-NIP @ 13,027' SLM...CHECK SET CONFIRMED GOOD SET. LRS PERFORMED CMIT TxIA TO 3500 PSI, ***PASSED***.....PERFORMED MIT-OA, **FAILED**, ESTABLISHED LEAK RATE AT 1.75 BPM @ 800 PSI. DUMP BAILED 2 BAG'S OF SLUGGIT'S ON TOP OF TTP @ 13027' SLM...TAG TOP OF SLUGGIT'S W/ 3.70" CENT. @ 13019' SLM *** LEFT WELL S/I *** ***WSR continued from 02-11-07***T/I/0= 1050/240/240 Assist S-line brush&flush(RWO prep)Spear into Tbg w/5bbls AMBNT meth followed by 125 bbls of diesel. Slick line to set plug. Attempt to CMIT TxIA, plug not holding. Pumped 100 bbls of crude down IA and 45 bbls of crude down tubing. Established a LLR of 1.25 BPM @ 3500 psi. Final WHP's = 1050/1080/250 *** CONT FROM 02-11-07 WSR *** (pre sdtrk) BRUSH/FLUSH TBG W/ 3.805 G-RING 4 1/2" BLB & SAMPLE BAILER ...TAGGED LINER TOP @ 13,103' SLM, BRUSHED X-NIP @ 13,027' SLM. SET 4 1/2" XX TTP ON HP LOCK ( 25" OAL W/ (8) 3/16" EQ. PORTS) @ 13027' SLM... CHECK SET CONFIRMED GOOD SET LRS PUMPED DOWN IA TO CMIT TxIA, W/ TBG TRACKING, COULD NOT PRESSURE UP OVER 3200 PSI, LEAK RATE ESTABLISHED @ 1.25 BPM...PUMPED DOWN TBG W/ IA TRACKING, PRESSURED UP TO 3500 PSI BUT NOT HOLDING, LEAK RATE ESTABLISHED @ 1.25 BPM EQUALIZED PLUG... RIH TO PULL PLUG *** JOB IN PROGRESS/ CONT ON 02-13-07 WSR *** Assisit S-line -Brush & Flush(RWO prep) ***WSR continued on 02-12-07*** *** WELL SI ON ARRIVAL *** (pre sdtrk) RIG UP SURFACE EQUIP & PREP FOR PT. *** JOB IN PROGRESS/ CONT ON 02-12-07 WSR *** Pre rig well head MIT: Rigged down, job postponed due to cellar restrictions. **** Still in progress ***** Pre rig wellhead MIT Ordered heater for Am , found the job is non hazardous confined space and will need air mover "heater" Still in Progress http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 5/14/2007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-59(09) P2-59(09) WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/28/2007 Rig Release: 4/19/2007 Rig Number: Spud Date: 11/5/1990 End: 4/19/2007 3/27/2007 23:00 - 00:00 1.00 MOB P PRE Disconnected rig modules. Scoped down and lowered derrick. 3/28/2007 00:00 - 01 :00 1.00 MOB P PRE Cont scoping down and lowering derrick. 01 :00 - 03:00 2.00 MOB P PRE Moved pits, pipe shed, sub away from 03-01. 03:00 - 10:00 7.00 MOB P PRE C/O BOP rams to double gate. 10:00 - 21 :00 11.00 MOB P PRE Moved rig from DS 03 to PM 2. 21 :00 - 23:00 2.00 RIGU P DECOMP Finished levelling well cellar area. Rig accepted @ 21 :00 hrs, 3/28/2007. Rig acceptance time adjusted back (8) hours to compensate for time spent reconfiguring BOPE stack after pulling off 03-01. 23:00 - 00:00 1.00 RIGU P DECOMP RU lubricator, set BPV, RD lubricator. 3/29/2007 00:00 - 03:30 3.50 RIGU P DECOMP Laid Herculite and rig mats. Positioned rig over well P2-59. 03:30 - 05:00 1.50 RIGU P DECOMP PJSM. Raise & scope up derrick. 04:30 - 06:00 1.50 BOPSU P DECOMP PJSM. Remove BOPE stack assembly from cellar area. Excavate cellar. 06:00 - 08:30 2.50 KILL P DECOMP PJSM. Continue to dig out cellar area, rig up lines to tree and tiger tank. 08:30 - 11 :00 2.50 KILL P DECOMP Wait on 2nd load of 120 degree 9.2 ppg brine. 11 :00 - 13:00 2.00 KILL P DECOMP Take on 2nd load of brine, thaw discharge line on tiger tank. 13:00 - 13:30 0.50 KILL P DECOMP Pre well kill safety meeting with over view of well program. 13:30 - 14:00 0.50 KILL P DECOMP Pressure test lines, 3500 psi, OK. Pump 20 bbls down tubing, shut in & do a quick pressure test on downhole plug, 1000 psi, OK. 14:00 - 16:30 2.50 KILL P DECOMP Line up and pump down tubing @ 4 - 5 bpm, 900 psi, taking 8.4 ppg returns thru choke to tiger tank. WI 50 bbls away, observe fluid back is 9.6 ppg. Continue to displace well to heated 9.2 ppg fluid, 560 bbls pumped. 16:30 - 19:00 2.50 KILL P DECOMP Waited on 3rd load of 120 deg 9.2 ppg brine. 19:00 - 20:30 1.50 KILL P DECOMP Pumped additional 290 bbls of 120 deg, 9.2 ppg brine down tubing. Returns 9.6 ppg. 20:30 - 21 :30 1.00 KILL P DECOMP Waited on 4th load of 120 deg 9.2 ppg brine. 21 :30 - 22:30 1.00 KILL P DECOMP Pumped additional 80 bbls of 120 deg, 9.2 ppg brine down tubing. Returns 9.2 ppg. 22:30 - 23:00 0.50 KILL P DECOMP Monitored well for 30 min. Well stable, no flow from tubing or annulus. 23:00 - 23:30 0.50 DHB P DECOMP Tested T x IA against tubing plug, to 1000 psi for 15 minutes (charted). Successful test. 23:30 - 00:00 0.50 WHSUR P DECOMP Installed TWC. 3/30/2007 00:00 - 02:30 2.50 WHSUR P DECOMP Continued installing TWC. Tested TWC from below to 1000 psi for 10 minutes. TWC would not test to 3500 psi from above. 02:30 - 03:30 1.00 WHSUR P DECOMP Waited for replacement TWC from FMC. 03:30 - 04:00 0.50 WHSUR P DECOMP Pulled TWC and installed replacement TWC. 04:00 - 06:00 2.00 WHSUR P DECOMP Attempted to test replacement TWC from above. Discovered very slight fluid leak at top flange on tree. Mitigated same and sucessfully tested TWC from above to 3500 psi for 10 minutes (charted). Tested from below, 1000 psi, charted, OK. 06:00 - 10:30 4.50 WHSUR P DECOMP PJSM. Blow down, rig down lines. Bleed void. N/D tree. Remove control lines from hanger. Service lock down screws. Check hanger threads, OK. 10:30 - 16:30 6.00 BOPSU P DECOMP PJSM. N/U 13 5/8" x 8' extension spool. N/U 13 5/8" BOPE pieces & assemble same on spool. Remove test spool due to height restrictions. Jack up, level sub. 16:30 - 00:00 7.50 BOPSU P DECOMP PJSM. N/U valves on mud cross. Dressed ram cavities with Printed: 4/23/2007 11 :03:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-59(09) P2-59(09) WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/28/2007 Rig Release: 4/19/2007 Rig Number: Spud Date: 11/5/1990 End: 4/19/2007 2-718" X 5" VBR, blindlshear ram, and 3-1/2" x 6" VBR, top to bottom. 3/31/2007 00:00 - 02:30 2.50 DECOMP Continued NU BOPE. RU test equipment, filled stack, performed function tests. 02:30 - 06:00 3.50 DECOMP Test BOPE components to 250 psi low 13500 psi high, charting all tests. Testing witnessed by L. Grimaldi, AOGCC. 06:00 - 10:00 4.00 DECOMP Continue to test the BOPE. Test upper & lower kelly valves. Drawdown test on accumulator. Tests witnessed by Nabors Toolpusher, Well Site Leaders & AOGCC State Rep Lou Grimaldi. Rig down test equipment. 10:00 - 11 :30 1.50 DECOMP PJSM. P/U luibricator, pull two way check valve, UD lubricator. 11 :30 - 14:00 2.50 DECOMP PJSM. M/U landing jt. BOLDs. Lockdowns tight, one was extremely uncooperative. Backed out gland nut enough to get lock down backed out. 14:00 - 16:00 2.00 PULL P DECOMP PJSM. Pull hanger, came free @ 140K, dropped back to 125K up wt. Picked up 2', drained stack, relanded and replaced lock down & gland nut with new one. Pulled hanger to floor, UD same. 16:00 - 17:30 1.50 PULL P DECOMP PJSM. Circulate tbg volume, 200 bbls 9.2 ppg brine, @ 5bpm I 290 psi. Small amount of crude I diesel back & then cleaned up right away. 17:30 - 21 :00 3.50 PULL P DECOMP POH, LD 4-1/2" tubing, spooling control lines. LD SSSV, recovered 4 ss bands, 35 clamps. 21 :00 - 22:00 1.00 PULL P DECOMP RD control line spooling unit, cleared rig floor. 22:00 - 00:00 2.00 PULL P DECOMP Resume POH, LD 4-1/2" tubing. 103 jts OOH @ 00:00 hrs. 4/1/2007 00:00 - 06:00 6.00 PULL P DECOMP Continue POH, LD 4-1/2" tubing. 240 jts OOH @ 04:00 hrs. 06:00 - 08:00 2.00 PULL P DECOMP PJSM. Continue to POOH wi & UD 4 1/2" tubing. Tubing looks to be in good shape. 326 jts laid down. UD last GLM & 1.16' of pup, leaving approximately 8.10' of stub. Chem cut looks good. 08:00 - 08:30 0.50 CLEAN P DECOMP Safety meeting. New driller. Discussed overview of operation and picking up the BHA. 08:30 - 10:00 1.50 CLEAN P DECOMP Clear I clean rig floor. Service rig, check crown 0 matic, inspect crown, check PVT equipment, all OK. 10:00 - 13:30 3.50 CLEAN P DECOMP PJSM. Pick up tubing dress off BHA. 13:30 - 00:00 10.50 CLEAN P DECOMP PJSM. RIH wi tubing stub dress off BHA. 159 jts in hole @ 18:00 hrs. 355 jts in hole @ 00:00 hrs. 4/2/2007 00:00 - 01 :30 1.50 CLEAN P DECOMP Continue RIH wi tubing stub dress off BHA. Tagged tubing stub @ 13,017' DPM. 01 :30 - 02:00 0.50 CLEAN P DECOMP Dressed tubing stub. Made multiple passes over tubing stub with shoe, ensuring that shoe moves freely over stub without rotation. Final total depth = 13,023'. 02:00 - 06:00 4.00 CLEAN P DECOMP Reverse circulated 30 bbl High-Vis sweep surface to surface. Initially pumped 3-1/2 bpm @ 1000 psi, increasing to 6 bpm @ 2430 psi. Scale, oily sand back in bottoms up. 06:00 - 07:00 1.00 CLEAN P DECOMP PJSM. Service rig, check crown 0 matic, PVT system, OK. 07:00 - 09:00 2.00 CLEAN P DECOMP PJSM. POOH w/3 1/2" DP, Lay down 51 jts. 09:00 - 14:00 5.00 CLEAN P DECOMP PJSM. POOH wi remaining 3 1/2" DP. 14:00 - 16:30 2.50 CLEAN P DECOMP PJSM. Stand back collars, UD tubing dress off BHA. Fill hole, close blind rams, pressure 9 5/8" casing to 1000 psi I 5 minutes, Plug is still good. 16:30 - 20:00 3.50 EVAL P TIEB1 PJSM. Nipple up shooting flange, rig up Schlumberger E Line.Tested lubricator and pack off to 500 psi. 20:00 - 22:00 2.00 EVAL P TIEB1 RIH with US IT to 13,000'. Printed: 4/23/2007 11 :03:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-59(09) P2-59(09) WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/28/2007 Rig Release: 4/19/2007 Rig Number: Spud Date: 11/5/1990 End: 4/19/2007 4/2/2007 22:00 - 00:00 2.00 EVAL P TIEB1 Logged with USIT in cement I corrosion mode up from 13,000'. 4/3/2007 00:00 - 07:00 7.00 EVAL P TIEB1 Continued USIT logging in cement I corrosion mode from 13,000' to surface. Made high resolution pass from 3100' to 1000'. Transmitted log data to Frank Roach. POOH wi USIT. 07:00 - 09:30 2.50 FISH P TIEB1 PJSM. RIH wi 4 strands string shot, tie in and fire across collar @ 2759'. Top of string shot @ 2753', bottom @ 2765'. POOH wi e line. 09:30 - 13:30 4.00 FISH P TIEB1 PJSM. Rig down E line, nipple down shooting flange, nipple up flowline. 13:30 - 14:00 0.50 FISH P TIEB1 PJSM - RIH w/9-5/8" Halco RBP. 14:00 - 16:15 2.25 FISH P TIEB1 RIH w/9-5/8" Halco RBP. Set RBP @ 3622' to COE. PIT RBP to 1000-psi for 10 charted miinutes. 16:15 - 18:00 1.75 FISH P TIEB1 Dump 2200-lbs. 20/40 mesh sand down DP. Tagged TOS @ 3566'. 18:00 - 19:30 1.50 FISH P TIEB1 Loaded, displaced well with 9.8 ppg brine. 19:30 - 21:30 2.00 FISH P TIEB1 POH, LD RBP running tool. 21 :30 - 23:00 1.50 FISH P TIEB1 Cleared rig floor. PUMU casing cutting BHA (BHA #2). 23:00 - 00:00 1.00 FISH P TIEB1 RIH with BHA #2. 4/4/2007 00:00 - 01 :30 1.50 FISH P TIEB1 Continued RIH with BHA #2. 01 :30 - 03:00 1.50 FISH P TIEB1 S&C drill line, adjusted drawworks brakes. 03:00 - 04:30 1.50 FISH P TIEB1 Attempted to locate casing collar. Pumped 3 bpm, 470 psi to extend cutter knives. Made two passes across cut depth but could not locate seam between casing joints. Will establish cut depth using DPM. 04:30 - 09:00 4.50 FISH P TIEB1 Circulated hot 9.8 ppg brine to heat well bore. 09:00 - 10:00 1.00 FISH P TIEB1 Establish fishing parameters - PUW = 62K, SOW = 57K, 80-RPM, Free torque - 2K-fVlbs., 4.5-bpm @ 1150-psi. Cut casing @ 2739' per plan forward. Established cut in 15-minutes of operation. Noted a loss of 6.0-Bbls. and 140-psi when casing breached. Continued rotating an additional 10 minutes. SID rotarty and pump. Picked kelly up 5' and reestablished pump pressure @ 300-psi @ 1.5-bpm. Slacked off and entered cut @ 2739' and tagged top of cut-off casing stub with a 6" gap between cut-off ends. Set kelly back. 10:00 - 10:15 0.25 FISH P TIEB1 PJSM - Rig up LRS and circulate out OA contents to open top tank. 10:15 - 11 :00 0.75 FISH P TIEB1 RU LRS lines and rig circulating lines to DP and OA. PIT LRS lines to 3500-psi. Rig up open top tank with herculite mist cover. Shear out circulating sub @ 1100-psi with rig pump. 11 :00 - 15:30 4.50 FISH P TIEB1 Displace DP volume with 20-Bbls. Diesel taking returns up IA to rig pits. Close annular preventer and open OA through Super Choke to open top tank. OAP = 130-psi. Bled OA to 30-psi with Diesel returns. Pumped 50-Bbls. diesel heated to 100-F @ 2.0-bpm @ 550-psi down DP taking returns from OA to open top tank. Let soak for 1-hr. Pump second dose of 50-Bbls. deisel at same parameters and let soak for 30-min. Pump third dose of diesel at same temp. rate and pressure and let soak for 30-minutes. Total diesel pumped = 205-Bbls. 15:30 - 16:00 0.50 FISH P TIEB1 RDMO LRS. 16:00 - 19:30 3.50 FISH P TIEB1 Circulate 9.8-ppg brine down DP with returns out OA to open top tank. Pump rate 5.5-bpm @ 790-psi. Flushed stack and lines. 19:30 - 21 :30 2.00 FISH P TIEB1 POH, LD 2 jts DP and pup jt. Stood back DC, BO/LD BHA #2, Printed: 4/23/2007 11 :03:47 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-59(09) P2-59(09) WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/28/2007 Rig Release: 4/19/2007 Rig Number: Spud Date: 11/5/1990 End: 4/19/2007 4/412007 19:30 - 21 :30 2.00 FISH P TIEB1 cleared floor. 21 :30 - 00:00 2.50 FISH P TIEB1 Held PJSM. PUMU casing spear ass'y (BHA #3). RIH, engaged grapple with 50k lb. BOLDS on casing hanger. 4/5/2007 00:00 - 02:30 2.50 FISH P TIEB1 RU to recover and LD 9-5/8" casing. Pulled hanger and casing free with 162k lb. LD casing hanger and casing spear BHA #3. 02:30 - 06:00 3.50 FISH P TIEB1 Held PJSM. POOH, LD 9-5/8" casing. 20 jts LD @ 05:30 hrs. Casing condition is generally good with no visible external corrosion and very little hydrocarbon material present. Stenciled labeling still visible. Avg BO torque is approx. 29k Ib-ft. 06:00 - 06:30 0.50 FISH P TIEB1 Diesel swapping out from OA creating imbalance in well. Circulating to displace diesel in 9-5/8" w/9.8-ppg brine. 06:30 - 13:00 6.50 FISH P TIEB1 Resume POH UD 9-5/8" Casing through pipe shed 1 x 1. Fluid losses = 20-Bbls. per hour. Pipe condition generally good with no visible external corrosion and very little hydrocarbons present. 13:00 - 15:00 2.00 FISH P TIEB1 Clear and clean floor. Rig down casing handling equipment. 15:00 - 18:00 3.00 FISH P TIEB1 PUMU BHA #4 - 12-1/4" burn shoe, 11-3/4" washpipe, 13-3/8" scraper, jars and 6-114" DC's. 18:00 - 20:30 2.50 FISH P TIEB1 RIH with BHA #4. 20:30 - 21 :30 1.00 FISH P TIEB1 Tagged casing stub @ 2739'. Rotated on and dressed stub. Washed to 2771'. Circ 3-1/2 bpm, 250 psi. 21 :30 - 00:00 2.50 FISH P TIEB1 POH with BHA #4. 4/6/2007 00:00 - 02:30 2.50 FISH P TIEB1 Continued POH with BHA #4. LD BHA #4, cleared rig floor. 02:30 - 04:30 2.00 FISH P TIEB1 PUMU back-off assembly (BHA #5). 04:30 - 07:00 2.50 FISH P TIEB1 RIH with BHA #5. Filled DP with fresh water every five stands. 07:00 - 07:30 0.50 FISH P TIEB1 Working pipe to obtain correct depth for backoff operation. Obstruction in 9-5/8" @ 2xxx'. Work pipe to target depth to place top and bottom slip sections of backoff assembly above and below collar to be backed off @ 2759'. 07:30 - 09:00 1.50 FISH P TIEB1 Backoff casing stub with 15K-ft.llbs. torque. Obtain 8 turns to the left on stub. 09:00 - 10:00 1.00 FISH P TIEB1 Release backoff tool. Drop 2.25" ball and shear open shear sub. Pump DP volume. Notified AOGCC-Jeff Jones of weekly BOPE test in next 24 hrs. 10:00 - 12:30 2.50 FISH P TIEB1 POH UD BHA #5. 12:30 - 13:30 1.00 FISH P TIEB1 Clear and clean floor. Service rig. Crew change and pre-tour HSE meeting. 13:30 - 14:00 0.50 TIEB1 PJSM - PUMU fishing BHA. 14:00 - 17:00 3.00 FISH P TIEB1 PUMU BHA #6: 9-5/8" spear, bumper sub, jars and DC's. RIH an engage sub @ 2733'. Establish fishing parameters and back off stub. 17:00 - 19:30 2.50 FISH TIEB1 POH wlBHA #6. UD 9-5/8" cut joint. 19:30 - 21 :30 2.00 BOPSU TIEB1 PUMU 13-3/8" storm packer. RIH 1 stand. Set packer and test to 1000 psi for 15 charted minutes. POH, LD running tool. 21 :30 - 00:00 2.50 BOPSU TIEB1 ND BOPE in preparation to swap double-gate to single gate. Removed Koomey lines. BIO annular and mud cross to remove double gate. Removed mud cross outlet valves. 4/7/2007 00:00 - 02:00 2.00 BOPSU TIEB1 Replaced double gate with single gate. Installed annular preventer. 02:00 - 08:00 6.00 BOPSU TIEB1 Torqued flanges. Installed mud cross valves. Installed test spool. Reconnected Koomey lines. 0730-hrs.: Contacted AOGCC - John Crisp to witness weekly BOPE test. Printed: 4/23/2007 11 :03:47 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-59(09) P2-59(09) WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/28/2007 Rig Release: 4/19/2007 Rig Number: Spud Date: 11/5/1990 End: 4/19/2007 Opportunity to witness testing waived by Mr. Crisp. Weekly BOPE test per AOGCC/BP requirements. 250-psi LP and 3500-psi HP. 13:00 - 13:30 0.50 TIEB1 Rig down BOPE test equipment. 13:30 - 15:00 1.50 TIEB1 PUMU 13-3/8" RTTS packer retrieving tool. RIH, engage RTTS and open storm valve. No pressure trapped under RTTS. Release RTTS. POH UD RTTS packer. POH and stand back 9 x 6-114" DC's. 15:00 - 15:30 0.50 CASE P TIEB1 Fill hole with 35-Bbls. 9.8-ppg brine. 15:30 - 20:00 4.50 CASE P TIEB1 Rig up floor and pipe shed to run 9-5/8" tie-back casing. Repair leak in rig mud pump discharge. 20:00 - 00:00 4.00 CASE P TIEB1 Ran 9-5/8" casing tieback. 40 jts run @ 00:00 hrs. 4/8/2007 00:00 - 03:00 3.00 CASE P TIEB1 Run 9-5/8" tieback. Torque connections to 17.5k ft-Ibs. 03:00 - 03:30 0.50 CASE P TIEB1 Screwed tieback into casing stub with 10k Ib-ft torque. 03:30 - 04:00 0.50 CASE P TIEB1 Pull tested tieback to 250k lb. Connection good. 04:00 - 06:00 2.00 CASE P TIEB1 RU to set ECP, test tieback and circulate. 06:00 - 07:00 1.00 CASE P TIEB1 Crew change and service rig. 07:00 - 09:00 2.00 CASE P TIEB1 Pull and maintain 250K hook load. Set TAMCAP 9-5/8" external casing packer - Pressure up 9-5/8" casing to 1050-psi, pressure bled off to 1025-psi in 5 minutes. Bumped pressure back up to 1050-psi and held for 10-charted minutes. Bumped pressure up to 11 OO-psi and held for 10-charted minutes. Increased pressure up to 2000-psi to test casing integrity for 30-charted minutes. Bled pressure on 9-5/8" casing back to O-psi. Pressure up OA: 9-5/8" x 13-3/8" annulus to 300-psi. Pressure leaks off rapidly. Pumped into OA @ 1.0-BPM @ 300-psi. and pumped away 5-Bbls. Increased rate to 2.0-BPM @ 400-psi and pumped away an additional 7.0-Bbls. 09:00 - 09:30 0.50 CASE P TIEB1 Monitor well while planning forward action. 09:30 - 10:00 0.50 CASE P TIEB1 2nd attempt to set TAMCAP 9-5/8" external casing packer- Pressure up IA: 9-518" casing to 1050-psi, bumped pressure up to 1100-psi and held for 10-charted minutes. Held pressure on IA @ 1100-psi and pressured up OA: 9-518" x 13-3/8" annulus to 300-psi. Pressure leaks off rapidly. Pumped into OA @ 1.0-BPM @ 300-psi. and pumped away 5-Bbls. Increased rate to 2.0-BPM @ 400-psi and pumped away an additional 7.0-Bbls. 10:00 - 19:30 9.50 CASE P TIEB1 Monitor well for no-flow from OA. 19:30 - 20:00 0.50 CASE P TIEB1 Sheared open ES cementer with 2500 psi. Confirmed fluid returns from OA. Total of 32 bbls required to fill OA after monidoring for 9 hrs. 20:00 - 22:30 2.50 CASE P TIEB1 Split tubing spool from casing head. Raised BOP stack. Installed 9-5/8" slips. 22:30 - 23:30 1.00 CASE P TIEB1 NU tubing spool to casing head. NU riser. 23:30 - 00:00 0.50 CASE P TIEB1 RU cementing lines. 4/9/2007 00:00 - 02:30 2.50 CASE P TIEB1 Continued RU lines. Circulated 9.8 ppg brine to heat well. Loaded plug in cement head. 02:30 - 06:00 3.50 CASE P TIEB1 Held PJSM. Tested lines to 4000 psi. Pumped 180 bbls 15.8 ppg cement with 1/2 ppb Cemnet. Bumped plug with 2200 psi @ 05:30 hrs. and 208-Bbls. total displacement. Final treating pressure 687-psi. Pressure up to 2200-psi to close ES cementer. Returned 32-Bbls. diesel and 10-Bbls. cement to open top tank. Printed: 4/23/2007 11 :03:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-59(09) P2-59(09) WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/28/2007 Rig Release: 4/19/2007 Rig Number: Spud Date: 11/5/1990 End: 4/19/2007 PJSM - Rig down cementers and N/D BOPE N/U BOPE. Rigging down cementing head and associated equpment. Bled off vacuum on O/A in 20-seconds. 07:30 - 08:00 TIEB1 PJSM - ND BOPElwellhead. NU BOPElwellhead. 08:00 - 15:00 TIEB1 ND BOPE, 8' riser and tubing spool. 15:00 - 00:00 TIEB1 NU new 8' riser spool, install secondary packoff in top of riser spool, make final cut on 9-5/8" Casing. Makeup new tubing spool. Test Casing packoff to 3800-psi. Removed Koomey lines. Filled void in new extension spool with diesel and tested to 3500 psi for 30 minutes. NU BOP stack to tubing spool. 4/10/2007 00:00 - 09:30 9.50 BOPSU P TIEB1 Removed mud cross valves. ND and PU annular. Removed and set aside single gate blind ram BOP. Installed double gate preventer with 3" x 6" VBR's and blindlshear rams. Rehook choke line and kill to mud cross. Installed Koomey lines. Cement UCA @ 1000-psi @ 0330-hrs. PIT annular preventer, blindlshear rams and upper pipe rams to 250-psi LP/3500-psi HP as well as Koomey test. Test all breaks to 3500-psi. 09:30 - 10:00 0.50 BOPSU P TIEB1 Rig down BOPE test equipment. Set wear ring. 10:00 - 10:30 0.50 BOPSU P TIEB1 PJSM - PUMU BHA #7. 10:30 - 11 :30 1.00 DRILL P TIEB1 PUMU BHA #7: 8-1/2" Bit, Boot Baskets, Bumper Sub, Jars and DC's. 11 :30 - 13:30 2.00 DRILL P TIEB1 RIH wlBHA #7. Tag TOC @ 2638'. 13:30 - 18:00 4.50 DRILL P TIEB1 Establish drilling parameters: PUW = 63k, SOW = 55K, 80 RPM, 4.0-BPM @ 260-psi, Free Torque = 3000-ft./lbs. Commence drilling cement w/5-10K WOB. Increased pump rate to 5.0-BPM. Tagged plug at 2747'. Mill to 2761'. Circ Hi-Vis sweep. 18:00 - 18:30 0.50 DRILL P TIEB1 Crew change. Check pit alarms and inspect derrick. 18:30 - 19:30 1.00 DRILL P TIEB1 Continue to drill out shoe track. Tag obstruction at 2764'. Mill obstruction from 2764'-2766'. Drilling parameters: 60 RPM, 5 BPM @ 380 psi, 10K WOB. 19:30 - 20:30 1.00 DRILL P TIEB1 SIB kelly, UD 3 singles and TIH. Tag sand @ 3568'. 20:30 - 22:00 1.50 DRILL P TIEB1 TOH w/DP. 22:00 - 23:30 1.50 DRILL P TIEB1 LD BHA #7. Clean junk baskets = 4 gal cmt, brass, aluminum. MU BHA #8 and stand back: 8-1/2" RCJB, boot baskets, 9-5/8" casing scraper, bumper sub, jars, DC's. 23:30 - 00:00 0.50 DRILL P TIEB1 RU to test 9-5/8" casing: close pipe rams, open OA valve. 4/11/2007 00:00 - 01 :00 1.00 DRILL P TIEB1 Pressure test 9-5/8" casing to 3500 psi for 45 charted minutes· good test. 01 :00 - 03:00 2.00 DRILL P TIEB1 TIH wi BHA #8. 03:00 - 05:00 2.00 DRILL P TIEB1 PJSM. Rotate scraper through shoe track from 2638' - 2790'. 60 RPM, 3-5 BPM, 250-600 psi. Encountered tight spot from 2766' to -2800' 05:00 - 07:30 2.50 CASE P TIEB1 Continue TIH to top of sand at 3568'. Tag @ 3562'. Hoover debris off top of sand and remove 5' of sand. 07:30 - 10:30 3.00 CASE P TIEB1 POH inspect contents of RCJB and lay down 9-5/8" scraper. Encountered tight spot in casing @ 2766' with 35K overpull required to pull free. Recovered complete aluminum ring and rubber cone from baffle plate. Casing scraper blades packed with rubber. 10:30 - 13:30 3.00 CASE P TIEB1 BO/LD Scraper. Make up and RIH w/BHA #9: 8-1/2" Mill Shoe, RCJB, 2 x 7" Boot Baskets, DC's and DP. Hoover off Printed: 4/23/2007 11 :03:47 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-59(09} P2-59(09} WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/28/2007 Rig Release: 4/19/2007 Rig Number: Spud Date: 11/5/1990 End: 4/19/2007 4/11/2007 10:30 - 13:30 3.00 CASE P TIEB1 top of sand @ 3568' to 3580'. 13:30 - 16:00 2.50 CASE P TIEB1 Swap hole over to 9.2-ppg brine. Pump 9.8 ppg brine to tiger tank. 16:00 - 18:00 2.00 CASE P TIEB1 TOOH wi 3.5" DP. 18:00 - 20:00 2.00 CASE P TIEB1 Stand back DC's. LD BHA #9. Clean RCJB & Boot Baskets. Recover 2 complete 1.5" turbo-clamp centralizers & 2 gal metal/sand. Redress RCJB. 20:00 - 22:00 2.00 CASE P TIEB1 RIH wi BHA #10 (RCJB Run #3): 8-1/2" Mill Shoe, RCJB, 2 x 7" Boot Baskets, Jars, DC's and DP. 22:00 - 22:30 0.50 CASE P TIEB1 Tag sand at 3583". Wash down 10' to 3593' wi RCJB. 22:30 - 00:00 1.50 CASE P TIEB1 TOH wi BHA #10. 4/12/2007 00:00 - 00:30 0.50 CASE P TIEB1 POH wi BHA #10. 00:30 - 02:30 2.00 CASE P TIEB1 SIB DC's. LD BHA #10. Clear rig floor. Recovered 2 small pieces of rubber from RCJB. 02:30 - 03:30 1.00 CASE P TIEB1 Clear rig floor. Take on 9.2 ppg brine in pits. 03:30 - 04:00 0.50 CASE P TIEB1 MU 9-518" RBP running tool on (2) 6-1/2" DC's. 04:00 - 06:00 2.00 CASE P TIEB1 TIH wi DP 37 stands. Tag TOS @ 3573'. 06:00 - 10:00 4.00 CASE P TIEB1 Reverse circulate sand off top of 9-5/8" Halco RBP. Release RBP and CBU. 10:00 - 11 :00 1.00 CASE P TIEB1 Repair hydraulic system. 11 :00 - 12:30 1.50 CASE P TIEB1 POH UD Halco 9-5/8" RBP. 12:30 - 13:30 1.00 FISH P TIEB1 PU MU BHA #11: 2-7/8" Muleshoe, 2-7/8" PAC Circ Sub, 2-7/8" PAC DP, 6-1/4" LBS, 6-1/4" Jars, 9 x 6-1/4" DC's. 1330-hrs.: Notified AOGCC of BOPE test on 4/13/07. 13:30 - 20:30 7.00 FISH P TIEB1 RIH wlBHA #11 on 3-1/2" DP from derrick. Conduct pre-tour checks. 20:30 - 21 :30 1.00 FISH P TIEB1 RIH to just above 4-1/2" stub located at 13021' DPM. Break circulation and reverse 120 bbls, 5 spm @ 1800 psi. 21 :30 - 22:30 1.00 FISH P TIEB1 Shear skirt wi 22k. MU 2 joints DP. Tag sluggits @ 13076'. Reverse circ & wash down to WRP @ 13084' DPM. 22:30 - 00:00 1.50 FISH P TIEB1 Reverse circulate 340 bbls until clean returns @ 4-5 bpm, 930-1750 psi. Recovered sandi cement, rubber & sluggits. 4/13/2007 00:00 - 08:00 8.00 FISH P TIEB1 TOH & LD BHA #11. Prepare to PU BHA #12 to pull Weatherford WRP. 08:00 - 09:00 1.00 FISH P TIEB1 PUMU BHA #12: Weatherford WRP OIS, shear pin guide assy., 2-7/8" PAC DP, jars, LBS and 6-1/4" DC's. 09:00 - 13:30 4.50 FISH TIEB1 RIH w/BHA #12. 13:30 - 14:30 1.00 BOPSU TIEB1 Pull wear ring. PUMU test plug. Set test plug and hang DP off in tubing spool. 14:30 - 15:00 0.50 BOPSU TIEB1 PJSM - Test BOPE. 15:00 - 20:00 5.00 BOPSU TIEB1 Perform weekly BOPE per AOGCC/BP requirements - 250-psi LP, 3500-psi HP. Chuck Sheve - AOGCC waived right to witness BOPE test. 20:00 - 20:30 0.50 BOPSU TIEB1 Drain BOP stack. P/U & pull test plug. UD same. 20:30 - 22:00 1.50 FISH TIEB1 Cut & slip 84' of drilling line. 22:00 - 00:00 2.00 FISH TlEB1 Con't RIH wi BHA # 12. (retreiving tool) on 31/2" DP. RIH wi 133 stands + single. 4/14/2007 00:00 - 01 :00 1.00 FISH P TIEB1 Attempt to go thru top of tubing stub wi retreiving tool. Unable to get thru. Worked pipe & slacked off up to 35K, Tried some rotation. The scalloped rim of tool appears to be hanging up on stub. Also tried circulation to get thru. No luck. Notified engineer & decided to pull tool & modify rather then tear up tool. 5 BPM @ 1500 psi. Printed: 4/23/2007 11 :03:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-59(09) P2-59(09) WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/28/2007 Rig Release: 4/19/2007 Rig Number: Spud Date: 11/5/1990 End: 4/19/2007 4/14/2007 01 :00 - 08:30 7.50 FISH P TIEB1 UD circulating head & single. POOH & stand back 3 1/2" DP. Pulled last 15 stands and DC's wet. 08:30 - 10:00 1.50 FISH P TIEB1 BHA plugged with scale. BOILD 8-1/2" cut lip guide. Modify overshot skirt to 45 degree angle muleshoe. PUMU 5-3/4" cut lip guide and extension to extend nose of cut lip guide past end of overshot nose. 10:00 - 15:00 5.00 FISH P TIEB1 RIH w/BHA #13 on 3-1/2" DP. 15:00 - 16:00 1.00 FISH P TIEB1 Establish fishing parameters: PUW = 215K, SOW = 87K. Engage top of 4-1/2" tubing stub @ 13,021'. Work and rotate WRP overshot into top of tubing stub. Circulating @ 4.0-BPM @ 970-psi. RIH to X nipple @ 13,039' and taking weight. Work overshot through X nipple and then stacking out. Forward plan is to mix and pump 2 x 50-Bbl. Safe-Lube pills to lube hole to reduce drag. 16:00 - 19:30 3.50 FISH P TIEB1 Circulating and monitoring hole. Pump 3.5 BPM @ 820 psi. Waiting on Safe Lube. 19:30 - 20:30 1.00 FISH P TIEB1 Circulate, Mix 2-50 bbls pills & spot down out side of DP & up -3000'. Pumped 185 bbls. 20:30 - 21 :30 1.00 FISH P TIEB1 Attempt to work pipe & RIH. Could not get deeper than this afternoon. @ 13035'. P/U Wt = 210 K, SIO Wt = 87K. No change from prior wts. Stuck pipe. Work pipe 55K over & jar free. Notify engineer & prep to POOH. 21 :30 - 00:00 2.50 FISH P TIEB1 POOH & stand back 31/2" DP. 4/15/2007 00:00 - 03:00 3.00 FISH P TIEB1 Con't to POOH & stand back 3 1/2" DP. 03:00 - 04:00 1.00 FISH P TIEB1 Stand back 3 stands of DCs. Break out & UD BHA # 13. Reteiving tool badly damaged, Egged. Appears to have been wedged between 4 1/2" tbg stub & 9 5/8" csg. Notify engineer & sent photos of tool. 04:00 - 05:00 1.00 FISH P TIEB1 Clear & clean rig floor. 05:00 - 09:30 4.50 FISH P TIEB1 PIU & M/U BHA #14 to dress off tbg stub. 09:30 - 13:30 4.00 FISH P TIEB1 RIH wlBHA #14 to 12,635'. 13:30 - 14:30 1.00 FISH P TIEB1 Weekly rig safety meeting attended by all crew. 14:30 - 16:30 2.00 FISH P TIEB1 Establish milling parameters: PUW = 195K, SOW = 92K. Mix and reverse circulate 50-Bbl. EP Mud Lube pill @ 5.0-BPM @ 1610-PSI. Pumped 400-9.2-ppg brine Bbls. flush to carry pill to -6600'. 16:30 - 17:30 1.00 FISH P TIEB1 Restablish milling parameters after pump EP mud lube pill. PUW = 172K, SOW = 103K, RPM = 60, Rotating Wieght = 135K, Pump Rate = 4.0-BPM @ 920-PSI. Tag top of 4-1/2" tubing stub and dress off 1'. Pick up kelly. Sid rotation and pump. Retag and verify l' of stub dressed off. Top of stub @ 13018'. 17:30 - 18:00 0.50 FISH P TIEB1 Set kelly back and blow down lines. 18:00 - 18:30 0.50 FISH P TIEB1 Crew change. Check PVT alarms. Inspect derrick. 18:30 - 23:00 4.50 FISH P TIEB1 POOH wi BHA #14. Stand back 31/2" DP 23:00 - 23:30 0.50 FISH P TIEB1 Stand back DCs. Break out & UD Dress off tools. 23:30 - 00:00 0.50 FISH P TIEB1 Clear & clean rig floor. 4/16/2007 00:00 - 01 :00 1.00 FISH P TIEB1 Finish clearing & cleaning rig floor. BHA was very dirty from EP-Iube & residue. 01 :00 . 02:00 1.00 FISH P TIEB1 P/U & M/U BHA #15 as follows: Cut Lip Guide, Ext, Bushing, 4 Ext, Shear out Sub, 3 jts Pac DP, XO, XO, Bumper Sub, Jars, XO, 9 * 6 1/4" DCs, XO, XO, Circ Sub. TL = 421.78'. RIH wi same. Printed: 4/2312007 11:03:47/>JA Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-59(09) P2-59(09) WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/28/2007 Rig Release: 4/19/2007 Rig Number: Spud Date: 11/5/1990 End: 4/19/2007 4/16/2007 02:00 - 03:00 1.00 FISH P TIEB1 Hold PJSM & weekly safety meeting wi all hands. 03:00 - 05:00 2.00 FISH P TIEB1 RIH wi BHA #15 on 3 1/2" DP. 05:00 - 06:00 1.00 FISH P TIEB1 Cut & slip 84' of drilling line. 06:00 - 11 :00 5.00 FISH P TIEB1 RIH wi BHA #15 on 31/2" DP. 11 :00 - 13:30 2.50 FISH P TIEB1 Tag top of 4-12" tubing stub @ 13,025'. Engage stub with 8-1/2" cut lip guide and ease down to enter stub with WRP stub. Entered stub with overshot, but did not see any shearing action from shear pin guied assy. Continued down to 13,080' and tagged up on fill. Rig up circulating eqpt. and broke circulation @ 4.0-BPM @ 1100-PSI and circulated down to top of WRP @ 13,084'. Set 5K1lbs. downweight on plug. Pump pressure increased to 1600-PSI. SID pump. Picked up and did not have any overpull to indicate that plug was released. No fluid loss to well at this point. Broke circulation @ 4.0-BPM @ 1100-PSI and eased back down on top of plug with 10Kllbs. downweight. Pump pressure increased to 1600-PSI and then dropped off to 11 OO-PSI. Pulled string up 25' and then went back down to see if we could go past original setting point. Went down 10' and plug started taking weight. Set 10Kllbs. downweight on plug. POH and lay down 1 jt. DP. Pulled next jt. up 15' and then went back down to verify plug still in overshot. Able to go back down all the way to floor level without plug taking weight. Well taking slightly more fluid than steel displacement pulled out of well. POH UD 2 jts. DP, fill ole and monitor for 1 hr. for fluid losses. Fluid lost = 11-Bbls in 1 hr. 13:30 - 00:00 10.50 FISH P TIEB1 POH LDDP 1 x 1 through pipe shed. Filling hole every 15 jts. pulled for well control. 4/17/2007 00:00 - 00:30 0.50 FISH P TIEB1 Finish POOH & LDDP. 00:30 - 02:30 2.00 FISH P TIEB1 UD 9* 6 1/4" DCs. Break out & UD BHA #15. UD WRP & reteiving tool. 02:30 - 03:30 1.00 FISH P TIEB1 M/U running tool. Pull Wear Bushing. UD same. 03:30 - 04:30 1.00 FISH P TIEB1 Clear & clean rig floor. 04:30 - 07:00 2.50 FISH P TIEB1 R/U tools & torque turn equip to run 31/2" completion. PJSM- All crew plus Nabors Casing crew. Reviewed Chrome Tubing Running and Handling Procedure. 07:00 - 18:00 RUNCMP PUMU completion BHA. Baker-Lok'd all connections below packer. Running 3-1/2" VAM Top tubing using compensator, torque turning connections to 2900-ft.lbs. optimum torque and applying Jet Lube Seal Guard thread compound as needed. Ran 180 jts in hole. 18:00 - 18:30 RUNCMP Crew change. Check PVT alarms. Inspect derrick. 18:30 - 00:00 RUNCMP Con't to RIH w/3 1/2" 13Cr Vam Top completion. Torque turn each connection to 2900 ft-Ibs. used Jet lube Seal Guard on connections. 4/18/2007 00:00 - 01:30 1.50 RUNCMP Continue to MU 3 1/2" completion. 01 :30 - 06:00 4.50 RUNCMP Hold PJSM for rigging up control-line spooler, sheaves, etc. and running same. MU SSSV and continue MU completion wi 1 band at top of every collar. 6000 psi on control line to hold SSSV open. Losing 5 bph. 06:00 - 06:30 0.50 RUNCMP Crew change. Inspect derrick. Check PVT alarms. 06:30 - 08:30 2.00 RUNCMP Con't to RIH wi 9.2# 13Cr, Vam Top completion. Torque turn all connections to 2900 ft-Ibs. Instal lied 1 SS controllineband Printed: 4/2312007 11 :03:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-59(09) P2-59(09) WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/28/2007 Rig Release: 4/19/2007 Rig Number: Spud Date: 11/5/1990 End: 4/19/2007 on each jt. Tagged up 27' in on Jt #406.Ran 406jts. Tagged up 23' in on jt# 406. SIO wi 8K & sheared pins in Overshot. Con't down 4 additional feet. PIU off tbg stub & re-tag to verify depth. PIU 2'. 09:00 - 10:00 RUNCMP POOH, UD 2 jts. Perform space out calculations. P/U 5 pup jts. 9.85',7.86',5.85',3.85',2.09'. Bury pups below jt #404. Overshot @ 13016', X Nipple @ 12992', S-3 Pkr @ 12937'. GLMs @ 12828',10974',9186',6609',3527'. SSSV @ 3527'. 10:00 - 12:00 RUNCMP M/U landing jt & hanger. Splice SS Control line to hanger. Pressure up control line & test to 5K for 10 min. Install needle valve Pressure up to & close needle valve. Wrap control line & secure needle valve to hanger neck. Land hanger & RILDS. 12:00 - 12:30 0.50 RUNCMP RID Torque turn equip & handling tools. 12:30 - 20:00 7.50 RUNCMP RlU lines to displace annulus wi hot inhibited brine. Close blind rams. Pump 150 bbls of 130 degree 9.2 ppg brine down annulus. Follow wi 800 bbls of 130 degree inhibited 9.2 ppg brine. Pump @ 3 BPM, 600 psi. 22:00 - 22:45 RUNCMP Suck stack out. PU landing joint, stab into top of tbg hanger. Drop Ball n' rod. Set packer & test tbg to 3500 psi for 30 minutes. Bleed tbg to 1500 psi and test IA to 3500 psi for 30 minutes (tbg squeezed to 2200 psi). Bleed pressure off tbg and shear SOV. Pump thru SOV both ways to verify flow path OK. Dry-rod in TWC and test from above and below to 1000 psi. 22:45 - 00:00 1.25 WHSUR P RUNCMP ND BOPE, NU Tree. 4/19/2007 00:00 - 06:00 6.00 BOPSU P WHDTRE ND BOPE. 06:00 - 10:00 4.00 BOPSU P WHDTRE Con't to N/D BOPE. Remove double gate from stack. Change out bland rams wi Blind/Shear Rams. 10:00 - 10:30 0.50 BOPSU WHDTRE Functio test rams. Remove stack from spool & set back over stump. Secure same. 10:30 - 16:00 5.50 WHSUR P WHDTRE Splice control line to Tbg Spool flange. test same. N/U adapter flange. test hanger void to 5000 psi for 30 min, Ok. 16:00 - 17:30 1.50 WHSUR P WHDTRE N/U new Cameron 4 1/8" Tree. Fill & test to 5000 psi for 30 min, Ok. 17:30 - 20:30 3.00 WHSUR P WHDTRE RU LRS to lA, Test lines and pump 20 bbls diesel. U-tube for 1 hour. 20:30 - 22:00 1.50 WHSUR P WHDTRE Blow down lines, sucure tree and cellar, inspect wellheadlcellar wi Pad Operator. Release rig @ 22:00. 4/20/2007 00:00 - 0.00 WHSUR WHDTRE Printed: 4/2312007 11 :03:47 AM WELLJiEAD= . ACTUATOR= KB. ElEV = BF. ElEV = KOP= FMC OTIS 40AS' . GAS LIFT MANDRElS DEV1YPE VLV LATCH 53 fIIMG DCR 56 M\nG DMY 57 M\nG DMY 55 M\nG DMY 48 M\nG DMY PORT DATE o 04117107 004/17/07 o 04/17107 o 04/17107 o 04/17/07 TVD 3013 4750 6254 7261 8386 4-112" Tubing Cut I 3.50" BKR DEf'!.C>YMENT SL\I' 10 =~.oo" I TOP OF 7" LNR TOP OF 3-3/1 ô" 6.'2jf. LNR, 10 = 2.800" 4-1/2" TIP, 12.6#, L80, .0152 bpf,lD = 3.958" 9-518" CSG, 47#, L-BO, 10 = 8.681" P2-59A PERFORA TION SUM\1A RY REF LOG:DlFLlSFUGR on 12117/90 ANG,LE AT TOP PERF: 95 @ 13900' Note: Refer to Production DB for historical perf data SPF INlERV A L Opnl DA TE ô -14150 0 04117/05 2" 6 14250 -14350 C 04117/05 2-1/8" 6 14570 - 14630 C 05104/99 2" 6 14730· 14806 C 08/23/99 2" ô 14806 - 14889 C 08/23/99 2" 6 14889 . 14930 C 08/23/99 7" LNR, 29J1., L-80, 10= 6.184" 14348' 3-3/16" LNR, 6.'2jf., L-80, .0076 bpf, ID = 2.800" DA TE REV BY COWENTSDA TE 12/22/90 ORIGINAL COMPLETION 12127/06 05/05/99 cm SIDETRACK 05103/05 JLGlPJC PERFS wrSntH PX PLUG SET (06/16105) 06119106 BSElPJC PULL PX PLUG 12114/06 AF/PJC PERF CORRECTIONS (08/23/99) REV BY COWMENTS Kef RWO - Repair IA x OA Com. SAFETY NOTES: DOGLEG I TIGHT SPOT NOTED BY COIL B~ 13730-13750'. WELL ANGLE> 70 DEG @ 1.&>90DEG@ 13785'. MinimumlD = 2.370" @13079'ctm LNR TOP PKR WI BKR SEAL ASSY 3-112",9.2#, 13CR-80, Vam TOP Tubing 12914' 3-1/2" HES X NIP, ID = 2.813" 12936 H9 5/8" x 4-1/2" S-3 PKR, 3.958" ID 13-1/2" HES X NIP, ID = 2.813" I 95/8" x 4 1/2" Unique Cr Overshot -14-1/2" SWS X NIP, 10 = 3.813" I -jTOPOFOTlS SBRASSY I 13079' eTM 4-112" ECLIPSE LNR TOP PKR, WI BKR SEAL ASSY, 10 = 2.370" 13115' -14-112" SWS X NIP, 10 = 3.813" (BEHIND PIPE) 13136' -14-1/2" SWS X NIP, 10= 3.S13" (BEHIND PIPE) 13148' -(4-112" WLEG, 10 = 3.958" (BEHIND PIPE) I 13057' H9-5IS" X 4-112" OTIS MHR PKR. 10 = 3.850" I 7" IVILLOUT \N'HXJW CUT FROM 13643' - 13649', (OFF\lVHlPSTOCK) 2.562" OD CISP SET ON1 0/23/99 FISH - 2.652" OD CIBP IVILLED & PUSHED TO BOTTOM (10/23/99) 14970' POINT MCINTYRE UNff WELL: P2-59A PERMffNo: '1982010 API No: 50-029-22096..01 SEC 14, T12N, R14E. 535' FNL & 1048' FWL BPExploration (Alaska) 04/30107 Schlumbepgep NO. 4237 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth l015 -'dOl sCANNED MAY ()'7 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay e 0 on DescflPt on ate o or S-21 11695054 LDL 03/27/07 , Y-31 11628764 MEM GLS 04/03/07 1 14-04 11660530 MEM PROD PROFILE 04/06/07 1 14-10 11626084 LDL 04/02/07 1 F-17A 11626083 LDL 03/31/07 1 F-30 11626078 LDL 03/26/07 1 X-21A 11660531 MEM PROD PROFILE 04/07/07 1 G-32A 11661134 MEM PROD PROFILE 03/30/07 1 X-36 11649959 MEM INJECTION PROFILE 04/12/07 1 06-24A 11637328 PRODUCTION PROFILE 04/16/07 1 X-36 11649959 MEM INJECTION PROFILE 04/12/07 1 12-02 N/A MEM INJECTION PROFILE 04/14/07 1 J-12 11686735 PROD PROFILE 04/13/07 1 B-26B 11628767 MEM PROD PROFILE 04/11/07 1 11-36 11626477 PROD PROFILE 04/17/07 1 03-18A 11626081 LDL 03/30/07 1 P2-59A 11630470 US IT 04/02/07 1 11-37 11626086 PRODUCTION PROFILE 04/22/07 1 X-10 11686739 LDL 04/23/07 1 WII J b# L . I D BL CI CD . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: ~:t~~~~~~i~~~6~::S~:~::~'LR2_1 R''''. E' CEIVED 900 E. Benson Blvd. "" Anchorage. Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: MAY 0 4 Z007 F\lø,ª CJil 8& Gas Cons. eommissioo ~ Received by: t1. Re: P2-59A (198-201) (aka Sundry 307-020. . Dave, In our conversation you indicated that there would be multiple plugs in the wellbore in addition to kill weight fluid providing isolation from the reservoir. Your request to employ the standard 2-ram stack during the replacement of the 9-5/8" casing is acceptable. Call or message with any questions. Tom Maunder, PE AOGCC SC:ANNED APR 1 0 2007 Reem, David C wrote, On 4/3/2007 8:56 AM: Tom, as we discussed over the phone, BP requests a BOPE variance from the AOGCC for the above captioned well. 4ES's bridge-cranes are unsuited to lifting the currently installed 3-ram and annular BOP stack. What we propose is to go back to 4ES's normal workover stack.. .2-ram and annular for a discreet phase of the workover. Specifically tying back in with new 9-5/8" casing after our cut and pull operation and cementing in the new casing. The stack needs to be lifted to enable installation of the 9-5/8" emergency slips. With the workover stack we know the bridge-cranes are adequate to perform this operation as we do it routinely. Once the new casing is installed and cemented, we would then go back to the 3-ram and annular stack for the rest of the workover. Your approval of this proposed variance is required for us to proceed with this plan. Call with questions or concerns regarding this plan. Thanks. 1 of 1 4/3/20079:14 AM TREE= V'1IELLHI:!A D = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 4-1/16" CrN FIVIC OTIS 40.45' .2- 59A Propose SAFETY NOTES: DOGLEG / TIGHT SPOT NOTED BY COIL BETWEEN 13730-13750'. WELL ANGLE> 70 DEG@ 13749' & > 90 DEG@ 13785'. 1050' _~@ 149~' 13435' 8800' SS GAS LIFT MANDRELS ST MD TVD DEV 1YÆ VLV LA TCH PORT DATE 1 3526 3013 53 MMG 2 6609 4750 56 MMG 3 9179 6250 57 MMG 4 10955 7250 55 MMG 5 12630 8250 48 MMG I 4-1/2" Tubing Cut 3.50" BKR DEPLOYMENT SLV, 10 = 3.00" I TOP OF 7" LNR I TOP OF 3-3/16" 6.2# LNR, 10 = 2.800" I 4-1/2" TTP, 12.6#, L80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, 10 = 8.681" H 13409' I PERFORA llON SUI\II\IIA RY REF LOG: DIFUSFUGRon 12/17/90 ANGLE AT TOP PERF: 95 @ 13900' Note: Refer to A-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 13900 - 14150 0 04117/05 2" 6 14250 - 14350 C 04117/05 2-1/8" 6 14570 - 14630 C 05/04199 2" 6 14730 - 14806 C 08/23/99 2" 6 14806 - 14889 C 08/23/99 2" 6 14889 - 14930 C 08/23/99 7" LNR, 29#, L-80, 10 = 6.184" H 14348' -13-112" TRSSSV,ID= ,~ ., ...) ç "" (i c....", " ". " .. ~ '" '" I '" s.'",. 9-518",47#, L-BO, TCII Casing to Surface 13-318" CSG, 68#, N-80, ID = 12.415" Minimum ID = 2.370" @ 13079'ctm LNR TOP PKR WI BKR SEAL ASSY 3-112",9.2#, 13CR-80, Vam TOP Tubing 12913' H 12924' H 3-1/2" HES X Nipple 2.813"10 9-518" x 4-1/2" Baker S-3 Packer 12950' 3-1/2" HES X Nipple 2.813" ID -I 4-1/2" x 9-5/8" Unique Machine Overshot --14-1/2" SWS X NIP, ID = 3.813" I TOP OF OTIS SBR ASSY 13067' --i9-5/8" X 4-112" OTIS MHR PKR, 10 = 3.850" 4-1/2" ECLIPSE LNR TOP PKR, W/ BKR SEAL ASSY, ID = 2.370" 13115' -14-112" SWS X NIP, 10 = 3.813" (BEHIND PIPE) 13136' --14-112" SWS X NIP, ID = 3.813" (BEHIND PIPE) 13148' --14-112" WLEG, ID = 3.958" (BB-IIND PIPE) I 7" MILLOUT WINDOW CUT FROM 13643' - 13649'. (OFF WHIPSTOCK) FISH - 2.652" 00 CIBP MILLED & PUSHEOTO BOTTOM (10123/99) 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.800" 14970' OA TE REV BY COMMENTS DA TE 12/22190 ORIGINAL COMPLETION 12/27/06 05/05199 crD SIDETRACK 05/03lOS JLGlPJC ÆRFS 09/23/05 WTSITLH PX PLUG SET (06/16/05) 06119/06 BSElPJC PULL PX PLUG 12/14/06 AF/PJC ÆRFCORRECTIONS (08123/99) REV BY COMMENTS KEH RWO - Repair IA x OA Com POINT MCIN1Y RE UNrr WELL: P2-59A ÆRMrr No: '1982010 API No: 50-029-22096-01 SEC 14, T12N, R14E, 535' FNL & 1048' FWL BP Exploration (Alaska) Schlulnbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 10~ ~r9() t 11/28/06 NO. 4058 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . Well Job# Log Description Date BL Color CD H-34 11477963 LDURST 11/07/06 1 Y-01B 11485468 MPPROF WIDEFT & GHOST 11/07/06 T 2-08/K-16 11487771 LDL 11/12/06 1 X-03A 11485772 MPPROF W/DEFT & GHOST 11/09/06 1 DS 09-51 11477933 INJECTION PROFILE 11/06/06 1 15-45A 11485469 MPPROF & INJECTION PROF 11/09/06 1 N-o-7 A 11296715 PROD PROFILE WIGHOST 09/10/06 1 DS 09-31C 11483591 INJECTION PROFILE 11/20/06 1 G-06A 11422979 SCMT 11/01/06 1 P2-59A 11414775 SCMT 11/05/06 1 NGI-06 11414773 USIT 11/01/06 1 A-43 11414774 USIT 11/03/06 1 01·26A 11001225 RST-SIGMA 05/24/05 1 1 I~ . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: NO\! ? 9 '?nm) Alaska Data & Consulting Services 2525 Gambell S~. S"~ ~o . A",,,,.,,, AX """l ATTN: Beth ê Received by: ( / 1'----- P2-59A (PTD #1982010) Classified as Problem Well ) ) S~~j~tt:J>2-5?A(PTI}#1982010)Cl~ssi~edasProblepl\¥ell .. ......... .......... ... ... .... .... ......... ...... Fr()m:."NSI],. ADWW ell. Integ#tyEl1gin~~r'~<NSU@WWeUlptegriti§ngineer@~P . com? Date: Sun, .05 Jl1n 200514:37:P3~0800 tRätk~r All , Well P2-59A (PTD #1982010) has sustained casing pressure on the OA and is classified as a Problem well. TIO's on 06/03/05 were 400/2100/1200. The OA is observed to re-pressure -320-480 psi/day. The plan forward for this well is as follows: 1. FB: MITOA to 3000 psi 2. W A V: Eval for IAxOA comm waiver Attached is a well bore schematic. Please call if you have any questions. «P2-59A. pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1~907~659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom SCANNED J U L 0 &~ 2005 .. Content-Description: P2-59A.pdf P2-59A.pdf . Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/20/2005 3:53 PM 'EL.LHF.AD = ¿IDà Tõ'ì~;~v",^.^ ä.ELEV= FMC .... w~... .."...,.."."",,'" OTIS 40.45' ) _Wl........__................~··,...,···"'.v···.··· op= ,,,,,.......,,.,,..,.,,.,,,,.,,,,,,. ax Angle = ..,..,,,.........,...,..,.......,..,...... 3tum MD :::: ';\1;11,1-" ., ,,)I.,.u.. 3tum TVO:::: 1050' ..,~f^,@1.1~46' 13435' .. """",·;·,,1 ¡,:, ,) 8800' SS SA FETY NOTES: DOGLEG / TIGHT SPOT NOTED BY COIL BElìNEEN 13730-13750'. WELL ANGLE> '70 DEG @ 13'749' & > 90 DEG @ 13785'. .. ) ...... ' } -....' } ft··..... --......... 2096' I-{ 4-1/2" OTIS SSSVN, 10:::: 3.813" GA S LIFT MA NDRELS . ST MO TVD DEV TYÆ VLV LATCH PORT DA- ~ .. 1 3533 3004 53 CA-MMG RK 113-3/8" CSG, 68#, N-80, 10 = 12.415" J-i 2990' 2 7516 5294 54 CA-MMG RK 3 10094 6750 56 CA-MMG RK L 4 11217 7404 54 CA- MMG RK 5 12302 8039 52 CA-MMG RK 6 12995 8503 46 CA - MMG RK Minimum ID = 2.370" @ 13079'ctm LNR TOP PKR W I BKR SEAL ASSY 3,50" BKR DEPLOY MENT SL V,. ID :::: 3.00" 1-1. 13112' I TOP OF 7" LNR I-{ 13113' TOP OF 3-3/16" 6.2# LNR, ID:::: 2.800" I-{ 13115' ~-1/2" TIP, 12.6#, l80, 0.0152 bpf, 10= :1.958" 1-1 13147' J w I 13032' I-{ 4-1/2" SWS X NIP, ID = 3.813" I 13039' ]-{ TOP OF OTIS SBR ASSY I 13057' I- 9-5/8" X 4-1/2" OTIS MHR PKR, ID:::: 3.850 r 13079'ctm 1- 4-1/2" ECLIPSE L.NR TOP PKR, W/ BKR SEAL ASSY, 10 = 2.370" cJ' ~., ':'... ~.':;: :>1. ® ~ t., § J ~ F ~r. ] I' 13115' l-f 4-1/2" SWS X NIP, ID = 3,813" I 13136' 1-1 4-1/2" SWS X NIP, ID = 3.813" I } \ 13148' 1--1 4-1/2" WlEG, ID = 3.958" I 9-5/8" CSG, 47#, l-80, 10 = 8.681"1-{ 13409' t----.A I. 7" MlllOUT WINDOW CUT FROM 13643' - 13649'. (OFF WHIPSTOCK) ÆRFORA TION SUMMARY REF LOG: DIFL./SFL./GR on 12/17/90 ANGL.E AT TOP Æ.RF: 95 @ 13900' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 13900 - 14150 0 04/17/05 2" 6 14250 - 14350 0 04/17/05 2-1/8" 6 14570-14630 0 05/04/99 2" 6 14730-14806 C 10/23/99 2" 6 14806-14889 C 10/23/99 2" 6 14889-14930 C 10/23/99 7" LNR, 29#, L-80, ID = 6.184" I-{ 14348' 14670'ctml-i 2.562" ODCIBPSEfON 10/23/99 FISH - 2.652" OD CIBP MilLED PUSHED DH BY CT ON 1 0/23/~ 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.800" l-i 14970' I OA TE REV BY COMMENTS 12/22/90 ORIGINAL COM PLEfION 05/05/99 CTD SIDETRACK 10/08/01 CH/KAK CORRECTIONS 04/26/04 DFRlKAK CSG CORRECTION 05/03/05 JLG/PJC PERFS DA TE REV BY COMMENTS POINT MClNTY RE UNrr WELL: P2-59A ÆRMrr No: "'1982010 API No: 50-029-22096-01 SEC 14, T12N, R14E, 535' FNL & 1048' FWL BP Exploration (Alaska) 198-201-0 POINT MCINTYRE P2-59A 50- 029-22096-01 BP EXPLORATION Roll/41: Start: Stop Roll #2: /~' ~.~S~L~ Stop (ALASKA) INC MD !_4975 TVD 09028 Completion ~ 5-/6/99 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/I) D 90530--./ 1,2 SPERRY GR OH 10/7/99 10/19/99 D 9138'~' I PDS INDUCTION OH 5/5/99 5/5/99 L DGR-MD ~~AL'~13650-14975 OH 10/21/99 10/28/99 . L DGR-TVD ~i~L 8965-9039 OH 10/21/99 10/28/99 L INDUCTION ~.~INAL 13398-13813 OH 5/5/99 5/5/99 Tuesday, May 01,2001 . Page 1 of 1 STATE OF ALASKA ALA,~,KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well_ Other_X (Frac) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration Alaska, Inc. Development~X RKB 40 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 service__ Point Mclntyre Unit 4. Location of well at surface 8. Well number 534' FNL, 4231' FEL, Sec. 14, T12N, R14E, UM P2-59A At top of productive interval 9. Permit number / approval number 2076' FNL, 1315' FEL, Sec. 02, T12N, R14E, UM 198-201 At effective depth 10. APl number 50-029-22096-01 At total depth 11. Field / Pool 2225' FNL, 178' FEL, Sec. 02, T12N, R14E, UM Point Mclntyre Oil Pool 12. Present well condition summary Total depth: measured 14975 feet Plugs (measured) Tagged PBTD @ 14650' MD (6/09/2000) true vertical 9028 feet CIBP @ 14670' MD. Effective depth: measured 14650 feet Junk(measured) 0RI( iNAL true vertical 9033 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 114' 20" 180 cubic ft Coldset II 114' 114' Surface 2950' 13-3/8" 24o2 cubic ft Coldset II 2990' 2679' Production 13369' 9-5/8" 285o cubic ~t C~ass G 13409' 8820' Liner 531' 7" 562 cubic It Class G 13643' 9008' Liner 1858' 3-3/16" 27.8 bbls LARC 14970' 9028' Perforation depth: measured 14570'- 14630'; (Isolated under ClBP @ 14730'- 14930'). true vertical 9037' - 9034'; (Isolated under ClBP @ 9037' - 9033'). u'.., ~ Tubing (size, grade, and measured depth) 4-1/2"12.6#, L-80 Tbg @ 13148' MD. Packers & SSSV (type & measured depth) 4-1/2" x 9-5/8" Otis Packer @ 13057' MD; 4-1/2" x 3-3/16" Eclipse Liner Top Packer @ 13079' MD. 4-1/2" OTIS SSSV LANDIGN NIPPLE, W/O SSSV @ 2096' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut in - - - Subsequent to operation 471 348 21 765 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~~ Title BP Engineer Date Mike Bill Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE P2-59A DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT Date Event Summary 10/22/1999: 12/14/1999: 5/02/2000: 5/20/2000: 5/29/2000: 5/31/2000: 6/02/2000: 6/04/2000: 6/09/2000: RIH & set CIBP @ 14670' MD, thus isolating the 14730' - 14930' perf interval: RIH & set 4-1/2" Eclipse liner top packer @ 13079' MD. RIH & set 4-1/2" Frac Sleeve @ 2074'. RIH & preformed FCO to 14650' MD. Injectivitytest: 0.5 bpm @ 3000 psi. MIRU & PT'd equipment to 9500 psi. Performed injection test. Performed a FB Hydraulic Fracture Treatment using 16/20 & 20/40 mesh ceramic proppant through the open perforation intervals f/14570' - 14630' MD. Performed injection test w/ Slick'water, then shutdown. FG = 0.67 & ISIP =1991 psi. Resumed Pumping Scour Staqe: (a) 20 bbls of Water, followed by (b) 66 bbls 40 # Gel w/1 ppa Scour, followed by (c) 250 bbls of 20# Liner Gel Flush, followed by (d) Shutdown. ISIP = 1840 psi. Resumed pumping Datafrac Treatment: (e) 25 bbls 40# Crosslinked Gel @ 15 bpm, followed by (f) 212 bbls 20# Linear Gel Flush @ 15 bpm, followed by (g) Shutdown. ISIP = 2281 psi. Resumed pumpin,q Frac Treatment: (h) 43 bbls 40# Crosslinked Pad @ 15 bpm, followed by (i) 190 bbls of crosslinked Gel w/proppant stages @ 2-10 ppa @ 15 bpm, followed by (j) 92 bbls of flush, followed by (k) Shutdown. Had near wellbore screenout 92 bbls into flush. Placed a total of 17505 lbs of proppant into FM. This was 34% of the design amount. Left 33600 lbs in wellbore. Max proppant concentration placed was 7.0 ppa. RD. RIH & FCO'd to 10800' CTM. RIH & FCO'd to 14660' CTM. RIH & pulled Frac Sleeve. Tagged frac sand @ 11765'. RIH & FCO'd to 14650' CTM. Placed well BOL & obtained a valid well test. . ~- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development~X RKB 40 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchora~le, AK 99510-0360 service__ Point Mclntyre Unit 4. Location of well at surface 8. Well number 534' FNL, 4231' FEL, Sec. 14, T12N, R14E, UM P2-59A At top of productive interval 9. Permit number / approval number 2076' FNL, 1315' FEL, Sec. 02, T12N, R14E, UM 98-201 At effective depth 10. APl number 50-029-22096-01 At total depth 11. Field / Pool 2225' FNL, 178' FEL, Sec. 02, T12N, R14E, UM Point Mclntyre Oil Pool 12. Present well condition summary Total depth: measured 14975 feet Plugs (measured) Tagged PBTD @ 14945' MD (8/21/1999) true vertical 9028 feet Effective depth: measured 14945 feet Junk (measured) true vertical 9031 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 114' 20" 180 cubic It Coldset II 1 14' 114' Surface 2950' 13-3/8" 2402 cubic It Coldset II 2990' 2679' Production 13369' 9-5/8" 2850 cubic It Class G 13409' 8820' Liner 531' 7" 562 cubic tt C~ass G 13643' 9008' Liner 1 858' 3-3/16" 27.8 bbls LARC 14970' 9028' Perforation depth: measured 14570' - 14630'; 14730' - 14930'. true vertical 9037' - 9034'; 9037' - 9033'. Tubing (size, grade, and measured depth) 4-1/2"12.6#, L-80Tbg @ 13148' MD. / ' ~ ' ! ~' ''-~ ~i:~"~"~ Packers & SSSV (type & measured depth) 4-1/2" x 9-5/8" Otis Packer @ 13057' MD. ~'~C~0~~-'; 4-1/2" OTIS SSSV LANDIGN NIPPLE, W/O SSSV @ 2096' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 446 352 0 651 Subsequent to operation 330 209 3 804 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations .__X Oil .__X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Erin Ob~ . ¢ Prepared by Padl Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE · P2-59A '" DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 8/21/1999 - 8/23/1999: 8/29/1999: MIRU CTU. PT'd equip to 4000 psi. RIH & logged GR-CCL tie in f/14945' - 13500' MD. POOH w/logging tools. RIH w/CT conveyed pedorating guns & shot 200' of Add Perforations @: 14730' - 14930' MD (Kuparuk River Zone) Used 2" carriers & all shots @ 6 SPF, 60° phasing, random orientation, & underbalanced. POOH w/guns. ASF. RD. Jetted Hot Oil to 14150' MD for hydrates / paraffin. Returned well to production & obtained a valid welltest. STATE OF ALASKA ALAS'~ OIL AND GAS CONSERVATION COMM'i~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil E] Gas D Suspended D Abandoned FI service D 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 98-201 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22096-01 4. Location of well at surface '; ': :'7:. '7:.'~..~i:i '~ ~ ~ 9. Unit or Lease Name 535' FNL, 4230' FEL, SEC. 14, T12N, R14E, UM ; ~)--/~(_0/('¢r./'-, .~----~.- ~:' llllJ~l~ Point Uclntyre Unit At Top Producing Interval ~.: 10. Well Number At Total Depth ~" ...... 11. Field and Pool , 2225' FNL, 178' FEL, SEC 02, T12N, R14E, UM Point Mclntyre Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 41.5 feetI ADL 365548 Point Mclntyre Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions April 23, 1999 April 30, 1998 May 6, 1999I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 14975' MD /9028' TVD 14931' MD /9033' TVD YES [~] No DI 2096' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD/GR. 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 133# K-55 Surface 114' 26" 180 cubic ft Coldset II 13-3/8" 68# NT80CYHE Surface 2990' 17-1/2" 2402 cubic ft Coldset II 9-5/8" 47# NT80S Surface 13409' 12-1/4" 2850 cubic ft Class G 7" 29# L-80 13112' 13643' 8-1/2" 562 cubic ft Class G 3-3/16" 6.2# L-80 13112' 14970' 4-1/8" 27.8 bbls of Latex Acid Resistive Cement 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 13148' 13057' 4-1/2" 13848' 14570' - 14630' MD; 9037' - 9034' TVD; @ 6 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 27. PRODUGTION TEST0 1.-;) ! fL~ ! tt I A I Date Firsl Production Method of Operation (Flowing, gas lift, etc.)I \ I L7 ii ~L May 14, 1999 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 5/15/1999 3.0 Test Pedod >I 600 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') Press. 750 psi 24-Hour Rate > 533 332 52 ~,~ ~ 28. CORE DATA .~. ~" ~ ~' J ~ # z- ~- Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas orwater. Submit core chips. ~' "~ %= t~, ~ ~ ~ D * This 10-407 is submitted as directed per the 10-401 form approved October 08, 1998 (Permit #98-20~,~: ...... ~ra Oil& Gas Cons. Commissi~ Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Ugnu Colville Mudstone HRZ Kalubik Ck Kuparuk River GEOLOGIC MARKERS ' " MEAS. DEPTH 7305' 10483' 13466' 13605' 13642' TRUE VERT. DEPTH 5164' 6978' 8866' 8978' 9007' 30. ' ~¢ FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF ATTACHMENTS Summary of P2-59A CT Sidetrack Drilling Operations + Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed /~'7~~~'~?'- Title AAI Coil Tubing Drilling Supervisor ~' Bruce E Smith P E Date INSTRUCTIONS Prepared by Paul Rauf 263-4990. General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item27: Method of Operation: Flowing, GasLift, RodPump, Hydraulic Pump, Submersible, Waterlnjection, Shut-in, Other-explain. Item 28: If no cores tnken, indicnte "none". P2-59A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 4/21/1999: 4/22/1999: 4/23/1999: 4/24/1999: 4/25/1999: 4/26/1999: 4/27/1999: 4/28/1999: 4/29/1999: 4/30/1999: 5/01/1999: 5/02/1999: 5/03/1999: 5/04/1999: 5/05/1999: 5/06/1999: MIRU CTU. Continue MIRU. P-I-'d BOPE. Open master & PT'd well to 2000 psi - pass. RIH w/BHA & milled Cement f/ 13635' - 13641' MD. Time milled window to 13647' & POOH. CTU maintenance. RIH & dressed window interval. Drilled into FM to 13651' MD. POOH. TOW = 13643'. BOW = 13649'. RIH & drilled 13735' MD. Swapped to 10.3 ppg mud. Performed LOT of EMW of 10.87 ppg. Drilled to 13820'. POOH. RIH w/logging tools (mem resistivity) & logged OH. POOH. RIH & drilled to 13920' MD. Drilled to 14205'. Drilled to 14624'. Mud losses started @ 14460'. Drilled to 14628'. Circulated LCM pill in OH. Drilled to 14850'. Drilled to TD @ 14975'. PUH & laid in LCM pill. POOH. RIH w/3-3/16" liner. Unable to get liner to TD so POOH w/liner. RIH w/bi-centered bit & conditioned OH to TD. New mud. POOH. RIH w/1858' liner. Landed liner @ 14970'. TOL = 13112'. Unstung f/liner. Pumped 27.8 bbls jof 15 ppg LARC to cement liner. Pressured up to 1000 psi. POOH w/CT. PT'd BOPE. RIH w/BHA & tagged PBTD @ 14931'. No motor work to TD. POOH w/BHA. Tested liner lap to 2000 psi - press bled to 1803 psi in 30 min. RIH w/CT & pumped in new mud in liner. POOH. RIH w/perforation guns & tagged PBTD. With a 2-1/8" Ultrajet carrier, shot 60' of initial perforations @: 14570' - 14630' MD (Kuparuk River FM) Reference Log: Sperry Sun LWD 4/29/1999. All shots @ 6 SPF. POOH w/guns. ASF. RIH w/CT & swapped well to Crude. POOH w/ CT. Left 300 psi on well. RDMOL. Placed well on initial production & obtained a valid well test. Sidetrack Summary Page I Shared Services Drilling Alaska Prudhoe Bay Unit Alaska State Plane Zone 4 Point Mclntyre Pad 2, Slot P2-59(09) ~2-59(09)- ~2-59A Job No. AKMW90111, Surveyed: 29 April, 1999 ORIGINAL REC : VED SURVEY REPORT 20 May, 1999 ~Y ~1 1999 Abska Oi~ & Gas Cons. Commis~ior~ Your Ref: API-500292209601 Surface Coordinates: 5998041.90 N, 681297.60 E (70° 23' 59.5504" N, Kelly Bushing: 40.45ft above Mean Sea Level 148° 31'27.8019" W) DRILLING SERVICES Survey Ref: svy8565 Sperry-Sun Drilling Services Survey Report for P2-59(09) - P2-59A Your Ref: API-500292209601 Job No. AKMW90111, Surveyed: 29 April, 1999 Shared Services Drilling Alaska Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 13606.95 36.630 34.920 8939.46 8979.91 13640.00 36.370 34.510 8966.03 9006.48 13665.27 40.690 35.200 8985.79 9026.24 13694.90 51.680 35.280 9006.27 9046.72 13721.56 60.820 37.710 9021.07 9061.52 13748.65 71.540 38.770 9031.99 9072.44 13772.29 83.670 40.350 9037.06 9077.51 13795.96 92.110 47.910 9037.93 9078.38 13824.33 93.160 57.400 9036.62 9077.07 13853.40 95.620 61.620 9034.40 9074.85 13884.44 95.540 63.910 9031.38 9071.83 13915.95 93.080 69.000 9029.01 9069.46 13947.51 93.950 69.530 9027.07 9067.52 13977.08 95.710 72.680 9024.58 9065.03 14008.15 96.500 76.560 9021.28 9061.73 14039.80 95.710 79.550 9017.91 9058.36 14070.20 95.100 82.890 9015.05 9055.50 14100.47 94.220 84.120 9012.59 9053.04 14131.63 92.720 89.040 9010.70 9051.15 14192.33 95.010 93.080 9006.61 9047.06 14220.68 95.010 95.370 9004.13 9044.58 14251.01 92.280 97.830 9002.20 9042.65 14274.43 91.320 100.820 9001.47 9041.92 14305.31 89.650 104.690 9001.21 9041.66 14332.07 89.030 107.850 9001.52 9041.97 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 9000.69 N 2892.20 E 6007110.11N 683970.59 E 9016.85 N 2903.40 E 6007126.53 N 683981.39 E 9029.76 N 2912.40 E 6007139.66 N 683990.08 E 9047.19 N 2924.72 E 6007157.39 N 684001.97 E 9064.98 N 2937.90 E 6007175.48 N 684014.72 E 9084,41N 2953.23 E 6007195.28 N 684029.57 E 9102.17 N 2967,91 E 6007213.39 N 684043,82 E 9119,12 N 2984.36 E 6007230.74 N 684059.85 E 9136.29 N 3006.86 E 6007248.45 N 684081.93 E 9150.99 N 3031.83 E 6007263.75 N 684106.53 E 9165.13 N 3059.29 E 6007278.55 N 684133.65 E 9177.68 N 3088.09 E 6007291.79 N 684162.13 E 9188.83 N 3117.55 E 6007303.66 N 684191.31 E 9198.37 N 3145.42 E 6007313,87 N 684218.94 E 9206.56 N 3175.20 E 6007322.78 N 684248,51 E 9213.07 N 3205.99 E 6007330.04 N 684279.13 E 9217.69 N 3235.89 E 6007335.38 N 684308.92 E 9221.10 N 3265.87 E 6007339.52 N 684338.80 E 9222.96 N 3296.91 E 6007342.13 N 684369.78 E 9221.84 N 3357.44 E 6007342.48 N 684430.33 E 9219.76 N 3385.60 E 6007341,08 N 684458,53 E 9216.28 N 3415.67 E 6007338.33 N 684488.67 E 9212.49 N 3438.76 E 6007335.10 N 684511.85 E 9205.67 N 3468,87 E 6007329,02 N 684542.12 E 9198.18 N 3494.56 E 6007322.15 N 684567.98 E Alaska State Plane Zone 4 Point Mclntyre Pad 2 Dogleg Rate (°/100ft) Vertical Section (ft) Comment 1.079 17.180 37.091 35.107 39.733 51.723 47.836 33.619 16.765 7.347 17.899 3.226 12.169 12.675 9.719 11.120 4.985 16.479 7.637 8.047 12.105 13.403 13.649 12.033 9389.78 9409.12 9424.60 9445.58 9467.23 9491.26 9513.51 9535.75 9560.71 9584.44 9608.69 9632.05 9654.41 9674.65 9694.45 9713.14 9729.74 9745.27 9759.83 9783.91 9793.69 9802.99 9809.12 9815.40 9819.22 TIE-ON SURVEY WINDOW POINT Continued... 20 May, 1999 - 9:17 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for P2-59(09) - P2-59A Your Ref: API-500292209601 Job No. AKMW90111, Surveyed: 29 April, 1999 Shared Services Drilling Alaska Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 14365.22 89.380 108.730 9001.98 9042.43 14399.70 90.790 112.250 9001.92 9042.37 14446.47 92.280 116.290 9000.67 9041.12 14481.08 92.200 118.050 8999.32 9039.77 14518,77 90.530 123.140 8998.42 9038.87 14557.00 92,110 129.300 8997.54 9037.99 14602.04 93.690 133.510 8995.26 9035.71 14628.51 91,670 130.880 8994.02 9034,47 14659.40 90.000 130.700 8993.57 9034.02 14692.62 86.840 127.030 8994.49 9034,94 14734.94 86.130 125.080 8997,08 9037.53 14762,28 88.240 122.040 8998.42 9038.87 14791.41 91.580 121.910 8998.47 9038.92 14819.99 92.280 121.210 8997.51 9037.96 14851.23 90.530 117.680 8996.74 9037.19 14893.02 92.640 116.280 8995.59 9036.04 14926.18 94.660 117.170 8993,47 9033.92 14946.96 96.590 117.520 8991.44 9031.89 14975.00 96.590 117.520 8988.22 9028.67 9187.77 N 3526.03 E 6007312.51N 684599.69 E 9175.71 N 3558.32 E 6007301.23 N 684632.27 E 9156.50 N 3600.93 E 6007283.06 N 684675.33 E 9140.70 N 3631.70 E 6007268.02 N 684706.47 E 9121.53 N 3664.12 E 6007249.64 N 684739.35 E 9098.96 N 3694.94 E 6007227.82 N 684770.71 E 9069.22 N 3728.67 E 6007198.91 N 684805.15 E 9051.46 N 3748.26 E 6007181.63 N 684825.16 E 9031.29 N 3771.64 E 6007162.03 N 684849.03 E 9010.45 N 3797.49 E 6007141.83 N 684875.38 E 8985.59 N 3831.64 E 6007117.81N 684910.12 E 8970.50 N 3854.39 E 6007103.27 N 684933.23 E 8955.08 N 3879.09 E 6007088.45 N 684958.30 E 8940.13 N 3903.43 E 6007074.10 N 684982.99 E 8924.78 N 3930.62 E 6007059.41 N 685010.55 E 8905.83 N 3967.85 E 6007041.37 N 685048.22 E 8890.95 N 3997.40 E 6007027.21 N 685078.13 E 8881.45 N 4015.77 E 6007018.16 N 685096.72 E 8868.58 N 4040.48 E 6007005.89 N 685121.73 E All data is in feet unless otherwise stated. Directions and coordinates are relative to Vertical depths are relative to Well Reference. Northings and Eastings are relative Magnetic Declination at Surface is 27.867° (29-Apr-99) True North. to Well Reference. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 24.494° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14975.00ft., The Bottom Hole Displacement is 9745.62ft., in the Direction of 24.494° (True). Alaska State Plane Zone 4 Point Mclntyre Pad 2 Dogleg Rate (°/100ft) Vertical Section (ft) Comment 2.857 10.997 9,204 5.087 14.209 16,630 9.972 12.519 5.438 14.574 4.896 13.524 11.475 3.463 12.609 6.059 6.654 9,438 0.000 9822.8O 9825.21 9825.39 9823.78 9819.78 9812.01 9798.93 9790.90 9782.23 9773.99 9765.52 9761.22 9757.43 9753.91 9751.22 9749.41 9748.12 9747.09 9745.62 PROJECTED SURVEY Continued... 20 May, 1999 - 9:17 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for P2-59(09) - P2-59A Your Ref: API-500292209601 Job No. AKMW90111, Surveyed: 29 April, 1999 Shared Services Drilling Alaska Prudhoe Bay Unit Alaska State Plane Zone 4 Point Mclntyre Pad 2 Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 13606.95 8979.91 9000.69 N 2892.20 E 13640.00 9006,48 9016.85 N 2903.40 E 14975.00 9028.67 8868.58 N 4040.48 E Comment TIE-ON SURVEY WINDOW POINT PROJECTED SURVEY 20 May, 1999 - 9:17 - 4 - DrillQuest Sperry-Sun Drilling Services LIS Scan Utility Tue Oct 05 14:11:18 1999 Reel Header Service name ............. LISTPE Date ..................... 99/10/05 Origin ................... STS Reel Name ................ UNK/~OWN Continuation Number ...... 01 Previous Reel Name ....... UNKI~OWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/10/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNK~OWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER POINT MCINTYRE MWD/MAD LOGS WELL NAME: API NUMBER: OPEP~ATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MW-90111 C. ZAWADZKI M. JOHNSON RECEIVED 0 CT 1 9 1999 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 05-0CT-99 MWD RUN 2 AK-MW-90111 C. ZAWADZKI M. JOHNSON 14 lin 014 535 1048 .00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 40.40 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2990.0 9. 625 13409.0 7. 000 13640.0 4 . 130 14975 . 0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-2 ARE DIRECTIONAL WITH NATURAL GAMMA RAY PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. DIGITAL DATA IS SHIFTED TO THE PDC GR LOG OF 12/1990 WITH KBE=40.45'AMSL. KICKOFF POINT FOR THIS WELL IS 13640'MD, 8965'SSTVD. 4. MWD RUNS 1-2 REPRESENT WELL P2-59A WITH API#: 50-029-22096-01 THIS WELL REACHED A TOTAL DEPTH (TD) OF 14975'MD, 8988'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA P~AY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 13633.5 14945.0 ROP 13667.0 14975.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 13633.5 13634.0 13635.0 13635.5 13637.0 13636.5 13641.0 13640.0 EQUIVALENT UNSHIFTED DEPTH 14975.5 14974.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 13650.0 13820.0 13820.0 14975.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 13633.5 14975.5 14304.5 2685 13633.5 ROP 0.29 2164.65 47.6977 2618 13667 GR 43.21 219.39 87.0567 2624 13633.5 Last Reading 14975.5 14975.5 14945 First Reading For Entire File .......... 13633.5 Last Reading For Entire File ........... 14975.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEA/DER FILE NUMBER: 2 RuAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13634.0 13788.5 ROP 13666.0 13820.0 $ LOG HEADER DATA DATE LOGGED: 25-APR-99 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM A/~GLE: 36.2 MAXIMUM ANGLE: 92.1 INSITE 3.2 PCG 7.72, PCD 1.03C MEMORY 13820.0 13650.0 13820.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER PCG 72 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 4.130 4.1 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 10.40 .0 8.3 7.4 .000 .000 .000 .000 61.1 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA/qDOFF (IN) : EWR FREQUENCY (HZ) : REM2LRKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 13634 13820 13727 373 13634 GR 45.02 219.39 78.9241 310 13634 ROP 1.44 53.03 23.8693 309 13666 Last Reading 13820 13788.5 13820 First Reading For Entire File .......... 13634 Last Reading For Entire File ........... 13820 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 R31W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13789 . 0 14944 . 0 ROP 13821.0 14974.5 $ LOG HEADER DATA DATE LOGGED: 29-APR-99 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REA_L-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 86.1 MAXIMUM ANGLE: 96.6 INSITE 3.2 PCG 7.72, PCD 1.03C MEMORY 14975.0 13820.0 14975.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATLSlAL GAMMA PROBE $ TOOL NUMBER PCG 72 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 4.130 4.1 BOREHOLE CONDITIONS MUD TYPE: MIlD DENSITY (LB/G): MUD VISCOSITY (S) : MI/D PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 10.30 .0 8.6 4.6 .000 .000 .000 .000 61.1 NEUTRON TOOL 5CATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 13789 14974.5 14381.8 2372 13789 GR 43.21 127.54 88.139 2311 13789 ROP 0.29 2164.65 50.8919 2308 13821 Last Reading 14974.5 14944 14974.5 First Reading For Entire File .......... 13789 Last Reading For Entire File ........... 14974.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/10/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/10/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Physical EOF End Of LIS File o Ft I I_1_1 IM G SEFIL/II: E S WELl, LOG TRANSMITrAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 October 21, 1999 MWD Formation Evaluation Logs P2-59A, AK-MW-90111 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Sitverado Way, ~G, Anchorage, AK 99518 P2-59A : 2" x 5" MD Gamma Ray Logs: 50-029-22096-01 2" x 5" TVD Gamma Ray Logs: 50-029-22096-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia ¢,ECe gED· .. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 0 I::t I I_1_ I ~1G WELL LOG TRANSM1TT~ To.' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - P2-59A, October 7, 1999 AK-MW-90111 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22096-01 ""'" ~ 9 1999 gj~l~ 0~1 & Gas Gms, C0mmi~n 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 20-May-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re' Distribution of Survey Data for Well P2-59A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 13,606.95' MD 13,640.00' MD 14,975.00' MD (if applicable) ~Jaska 0ii & Gas ~.s. Commission Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company /.OG TRANSMITTAL ProActive Diagnostic Services, Inc. To: ARCO Alaska, Inc. AOGCC Lori Taylor RE' Distribution-Final Print(s) The technical data listed below is being submitted herewith. a signed copy of this transmittal letter to the attention of ' Carl Jablonski/Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 Please acknowledge receipt by returning ? LOG DIGITAL i MYLAR / BLUE WELL ..t~ DATE TYPE DATA i SEPIA FILM LINE ~-%~ \ ~ I PRINT(S) , Open Hole t J I 1 Res. Eval. CH t I 1 Mech. CH Signed: ~(~)~'~,~ Date' Print Name: ~,~, '"~d.~ ~ (' ProActive Diagnostic Services, Inc., Phone: (907) 659-2307 Fax: (907) 659-2314 E-mail: pdsprudhoe@NA800.net Pouch 340112, Prudhoe Bay, AK 99734 Website: v~vw.mcmorylog.¢om C:LMy Documents\Excel_Word_DocumentskDistribution_FormskArco_ptmac_form.doc Geoquest 3940 Arctic Blvd Anchorage. AK 99503 ANN: Sherrie NO. 12274 Company Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1/26/99 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL Sepia Tape R-40 ~ ~?~C-~ 99026 IMPULSR GR 981113 1 1 1 R-40 99026 IMPULSR GRTVD 981113 1 1 W-19A ~ ~'~' 99022 IMPULSE-ADN 981215 1 1 1 W- 19A 99022 IMPULSE-ADN TVD 981215 1 1 W- 19A 99022 DENSITY/NEUTRON 981215 1 1 W-19A 99022 DENSITY/NEUTRON TVD 981215 1 1 R-20A M,~ (,-- ~{ 98623 IMPULSE 980715 1 *REDO-TO ADD A&H CURVES TO EDITED FILE. PRINTS ARE CORRECT. R-23A ~ ~(.~E:::~[ 99006 ]IMPULSE 971120 1 *REDO-TO ADD A&H CURVES TO EDITED FILE. PRINTS ARE CORRECT. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: ,/~.,/~ ~L~]~1~ Schlumberger GeoQuest BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: ECE VED 04 I999 Jaska oil & Gas Cons. Commission 3940 Arctic BIvd Anchorage, AK 99503 AI-rN: Sherrie-"~-,.~ 1/18/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99,503 A'n'N: Sherrie NO. 12240 Company Alaska Oil & Gas Cons Comm Altn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL Sepia Tape Z-38 ~1~ '~r/.~ ~ 98434 IMPULSE/GR MD (PDC) 980620 1 1 I Z-38 98434 IMPULSE/GR TVD (PDC) 980620 1 1 R-gaA Lk~(.~ ,~ ~'~ (p I 98623 IMPULSE/GR/RES MD 980715 1 1 1 R-20A 98623 IMPULSE/GR/RES TVD 980715 1 1 R-23A .~ ?~, c~ (_o c.~ 99006 I MPULSE/GR/RES MD 971120 1 1 1 R-23A -- 99006 IMPULSE/GR/RESTVD 971120 1 1 R-23A 99006 IMPULSE/BOREHOLE PROF 971120 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center MB3-3 900 E. Benson Blvd, Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED JAN 2.1 1999 Gas Cons, Commission Schlumberger GeoQuest 3940 Arctic Blvd ~nlzCNh,, or~ge:ieAK 99~3~ Received .'~ ~~'~,,¢ TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 8, 1998 Steven Ward Senior Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Point Mclntvre P2-59a ARCO Alaska, Inc. Permit No: 98-201 Sur Loc: 535'FNL, 1048'FWL. Sec. 14. T12N. R14E. UM Btmhole Loc. 1690'FNL, 1061'FEL. Sec. 02, T12N. R14E. UM Dear Mr. Ward: Enclosed is thc approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blo~vout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Colmnission to witness a test of BOPE installed prior to drilling new hole. Notice ma.,,' be given bv contacting thc Commission petroleum field inspector on the North Slope pager at 659-3607. Chairma~ --' BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Departmcnt of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA c'", AND GAS CONSERVATION COMMISSION ,_ , PERMIT TO DRILL ~... 20 AAC 25.005 la. Type of work: Drill [~] Redrill [~1 I lb. Type of well. Exploratory[~ Stratigraphic Test [~ Development Oil r~ Re-Entry I-'] Deepen E~I service ~] Development Gas E~ single zone r~ Multiple Zone BI 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKBE 41.5' = feet Point Mclntyre 3. Address 6. Property Designation P.O. Box 100360, Anchorage, AK 99510 ADL 365548 4. Location of well at surface 7. Unit or Property name 11. Type Bond (see 20 AAC 25.025) 535' FNL, 1048' FWL, Sec. 14, T12N, R14E Point Mclntyre Statewide At top of production interval 8. Well number Number 2077 FNL, 3964' FWL, Sec. 02, T12N, R14E P2-59a U-630610 At total depth 9. Approximate spud date Amount 1690' FNL, 1061' FEL, Sec. 02, T12N, R14E Oct, 1998 $200,000 12. Distance to nearest 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line feetI feet /3": ~¢k:2 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (~)(2)) / Kickoff depth 13615 feet Maximum hole angle 92 Maximum surface 3610 psig At total depth (TVD) 4489 @ 9041' tvd 18. Casing program Settin~l Depth size Specifications To p Bottom Quality of cement ,, Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include state data) 4 1/8" 3 3/16" 6.2 L-80 TC II 2600' 13100' 8578' 15700' 9041' /7j¢ bbls Class 'G' - ?.+ 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total Depth: measured: 14375 feet Plugs (measured) None. S 3 0 !998 true vertical: 9577 feet Effective Depth: ~aska 0il & Gas Cons. O0mmissi( measured: 13678 feet Junk (measured) FISH -2.5' on true vertical: 9037 feet CCTU Fishing neck / washout nn771~. Casing Length Size Cemented Measured depth True vertical depth Conductor 114' 20" 180 f¢ Coldset II 114' 114' Surface 2990' 133/~" 2402 f¢ Coldset II 2990' 2680 .q ~/,, ft~ Intermediate 13409' ~- .~ 2850 Class G 13409' 8820 Liner 1235' 7" 562 f¢ Class G 13113-14348 8588-9555 Perforation depth: measured 13646-13686' true vertical 9010-9053' .~0. Attachments Filing fee ~ Property plat r-] BOP Sketch IX] Diverter Sketch [--I Drilling Program Drilling fluid program [--] Time vs depth plot r-] Refraction analysis ~ Seabed report [~ 20 AAC 25.050 requirements 17. I hereby cedify that the foregoing i/.s true and correct to the_best of my knowledge. S i ned Stepl?l.en W~rd -.,/Lc'~Z¢' -¢ Sr. Engineer Date September 30, 1998 ;~,.. Commission Use Only Permit..~lumbe, I APl number I Approva, date I See cover letter other for · requirements Conditions of approval Sample required .. r-] Yes J~ No Mudlog required I--lYes J~ No Hydrogen sulfide measures [--~Yes ~ N°¥.¢-"~'. Directional survey required i~Yes E~ No Required working pressure for BOPE...' [~'2M; E~]3M; ~L5M;[--]10M; [~15 Other: .. 0r.i.~t.~l Signed By by order of Approved by ~,:~.~..;, mC Inhnqfnn Commissioner the commission Date Form 10-401 Rev 12-1-85 SUBMIT IN TRIPLICATE P2-59A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 3-3/16" cemented liner. Perforate and produce. Intended Procedure: Set whipstock top at ~-13610' md. Cement squeeze and plugback the existing completion to~,~d. RU CTD unit and test BOPE. Mill window in 7" casing at ~-13615' md. Drill 10' of formation with 10.3 ppg Flopro fluid and perform Leak off test to 10.8 ppg. Directionally drill 4.125" x 2000' horizontal well to access Lower Romeo reserves. Build angle to -~92° at TD. · Run and cement 3-3/16" liner to TD. · Perforate selected intervals. · Place well on production. September 29, 1998 Company: Well: Calculation Method: Vertical Sect. Plane: Vertical Sect. Plane: Measured Depth from: True Vertical Depth: ARCO Alaska, Inc. P2-59A Minimum Curvature 95.100 TRUE 93.710 GRID RKB Sea level Proposal Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN Rig: CDR - Nabors/Transocean Field: Prudhoe Bay, Alaska Mag. Declination: 28.050 Grid Correction: 1.390 Total Correction: 26.660 RKB tleight: 40.45 Coords.- ASP Coords. GRID Coords. TRUE N(+)/S(-) E(+)/W(-) Lat. (Y) Dep. (X) Job No: AFE No: BHI Rep: Job Start Date: Job End Date: DLS (°/100 ft): 100.00 Comments Tie in Position Kick off Point 3 684117.07 684167.02 684184.93 684222.53 684262.33 684304.15 684325.75 684347.77 684370.19 684392.99 684416.13 684439~58 684463.33 Meas. Incl. TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Tool Face Vertical Build Turn Depth Angle Azi. Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Section Comments (dog) (deg) (deg) (fl) Lat. (Y) Deo. (X) Lat. (Y) Dep. (X) Lat. (Y) Deo. (X) (°/100~) (from TIP) (°/100fi) (°/100~) 14350.00 91.06 76.18 74.79 9026.74 9447.04 3420.04 6007568.54 684487.32 9526.67 3189.69 8.00 90.00 2566.72 -0.08 8.00 14375.00 91.03 78.17 76.78 9026.28 9452.59 3444.41 6007574.67 684511.5~ 9532.80 3213.92 8.00 90.00 2590.50 -0.12 7.96 14400.00 91.00 80.17 78.78 9025.84 9457.29 3468.96 6007579.96 684535.99 9538.09 3238.35 8.00 90.00 2614.53 -0.12 8.00 14425.0C 90.97 82.17 80.78 9025.41 9461.12 3493.66 6007584.40 684560.58 9542.53 3262.94 8.00 90.00 2638.79 -0.12 8.00 14450.0E 90.94 84.17 82.78 9024.99 9464.10 3518.48 6007587.97 684585.32 9546.10 3287.68 8.00 90.00 2663.25 -0.12 8.00 14475.00' 90.91 86.17 84.78 9024.59 9466.20 3543.39 6007590.68 684610.17 9548.81 3312.53 8.00 90.00 2687.87 -0.12 8.00 14500.00 90.87 88.17 86.78 9024.20 9467.43 3568.35 6007592.52 684635.10 9550.65 3337.46 8.00~ 90.00 2712.63 -0.16 8.00 14525.00 90.84 90.17 88.78 9023.83 9467.80 3593.35 6007593.4~ 684660.08 9551.62 3362.44 8.00 90.00 2737.49 -0.12 8.00 14550.00 90.80 92.17 90.78 9023.47 9467.29 3618.34 6007593.58 684685.07 9551.71 3387.43 8.00 91.00 2762.43 -0.16 8.0C 14575.00 90.77 94.17 92.78 9023.13 9465.90 3643.29 6007592.81' 684710.06 9550.94 3412.42 8.00 91.00 2787.41 -0.12 8.0C 14600.00 90.73 96.17 94.78 9022.80 9463.65 3668.19 6007591,16 684735.00 9549.29 3437.36 8.00 91.00 2812.41 -0.16 8.00 14625.00 90.69 98.17 96.78 9022.49 9460.53 3692.99 6007588.64 684759.87 9546.77 3462.23 8.00 91.00 2837.39 -0.16 8.00 14650.00 90.65 100.16 98.77 9022.20 9456.55 3717.67 6007585.26 684784.64 9543.39 3487.00 8.00 91.00 2862.32 -0.16 7.96 14675.00 90.61 102.16 100.77 9021.92 9451.71 3742.19 6007581.02 684809.27 9539.15 3511.63 8.00 91.00 2887.18 -0.16 8.00 14700.00 90.57 104.16 102.77 9021.67 9446.02 3766.53 6007575.92 684833.74 9534.05 3536.10 8.00 91.00 2911.93 -0.16 8.00 14725.00 90.53 106.16 104.77 9021.43 9439.48 3790.66 6007569.97 684858.02 9528.10 3560.38 8.00 91.00 2936.54 -0.16 8.00 14750.0C 90.49 108.16 106.77 9021.2C 9432.11 3814.55 6007563.18 684882.08 9521.31 3584.44 8.00 91.00 2960.99 -0.16 8.00 14775.0¢ 90.45 110.16 108.77 9021.00 9423.90 3838.16 6007555.55 684905.88 9513.68 3608.24 8.00 91.00 2985.24 -0.16 8.00 14800.0¢ 90.40 112.16 110.77 9020.81 9414.88 3861.47 6007547.09 684929.41 9505.22 3631.77 8.00 91.00 3009.26 -0.20 8.00 14825.0£ 90.36 114.16 112.77 9020.65 9405.05 3884.46 6007537.82 684952.62 9495.95 3654.98 8.00 91.00 3033.03 -0.16 8.00 14850.00 90.32 116.16 114.77 9020.50 9394.42 3907.08 6007527.74 684975.50 9485.87 3677.86 8.00 91.00 3056.51 -0.16 8.00 14875.00 90.27 118.15 116.76 9020.37 9383.01 3929.33 6007516.88 684998.01 9475.01 3700.37 8.00 91.00 3079.68 -0.20 7.96 14900.00 90.23 120.15 118.76 9020.26 9370.83 3951.16 6007505.22 685020.13 9463.36 3722.49 8.00 91.00 3102.51 -0.16 8.00 14925.00 90.18 122.15 120.76 9020.17 9357.90 3972.55 6007492.82 685041.84 9450.96 3744.20 8.00 91.00 3124.96 -0.20 8.00 14950.00 90.14 124.15 122.76 9020.10 9344.23 3993.48 6007479.6~, 685063.09 9437.80 3765.45 8.00 91.00 3147.03 -0.16 8.0C 14975.00 90.09 126.15 124.76 9020.05 9329.84 4013.92 6007465.78 685083.87 9423.91 3786.23 8.00 91.00 3168.66 -0.20 8.00 15000.00 90.05 128.15 126.76 9020.02 9314.74 4033.85 6007451.17 685104.16 9409.30 3806.52 8.00 91.00 3189.85 -0.16 8.0E 15023.38 90.00 130.02 128.63 9020.01 9300.00 4051.99 6007436.87 685122.66 9395.00 3825.02 8.00 -69.00 3209.24 -0.21 8.0¢ 4 15025.00 90.05 129.90 128.51 9020.01 9298.96 4053.24 6007435.86 685123.93 9393.99 3826.29 8.00 -69.00 3210.57 3.09 -7.41 15050.00 90.74 128.02 126.63 9019.84 9283.25 4072.67 6007420.62 685143.74 9378.75 3846.10 8.00 -69.00 3231.33 2.76 -7.52 15075.00 91.43 126.14 124.75 9019.36 9268.18 4092.61 6007406.04 685164.04 9364.17 3866.40 8.00 -69.00 3252.53 2.76 -7.52 15076.88 91.48 126.00 124.61 9019.32 9267.07 4094.13 6007404.97 685165.5¢ 9363.10 3867.95 8.00 88.00 3254.14 2.66 -7.45 5 15100.0C 91.50 126.92 125.53 9018.72 9253.33 4112.72 6007391.69 685184.5¢ 9349.82 3886.86 4.00 88.00 3273.88 0.09 3.98 15125.0¢ 91.53 127.92 126.53 9018.05 9238.15 4132.57 6007376.99 685204.71 9335.12 3907.07 4.00 88.00 3294.99 0.12 4.00 15150.0£ 91.56 128.92 127.53 9017.38 9222.62 4152.15 6007361.94 685224.66, 9320.07 3927.02 4.00 88.00 3315.87 0.12 4.00 15175.00 91.58 129.92 128.53 9016.70 9206.75 4171.45 6007346.54 685244.35 9304.67 3946.71 4.00 88.00 3336.51 0.08 4.00 15200.00 91.61 130.92 129.53 9016.00 9190.55 4190.48 6007330.81 685263.76 9288.94 3966.12 4.00 88.00 3356.90 0.12 4.00 15225.00 91.63 131.92 130.53 9015.29 9174.01 4209.22 6007314.72 685282.89 9272.86 3985.25 4.00 88.00 3377.04 0.08 4.00 15250.00 91.66 132.92 131.53 9014.58 9157.16 4227.67 6007298.32 685301.75 9256.46 4004.11 4.00 88.00 3396.91 0.12 4.00 15275.00 91.68 133.92 132.53 9013.85 9139.98 4245.82 6007281.6C 685320.31 9239.73 4022.67 4.00 88.00 3416.51 0.08 4.00 15300.00 91.70 134.92 133.53 9013.11 9122.49 4263.66 6007264.55 685338.57 9222.68 4040.93 4.00' 88.00 3435.84, 0.08 4.00 15325.00 91.72 135.92 134.53 9012.36 9104.69 4281.20 6007247.18 685356.54 9205.31 4058.90 4.00 88.00 3454.90 0.08 4.00 15350.00 91.75 136.92 135.53 9011.61 9086.59 4298.43 6007229.50 685374.20 9187.63 4076.56 4.00 88.00 3473.66 0.12 4.00 15375.00 91.77 137.92 136.53 9010.84 9068.19 4315.34 6007211.52 685391.55 9169.65 4093.91 4.00 88.00 3492.14 0.08 4.00 15400.00 91.79 138.92 137.53 9010.06 9049.50 4331.92 6007193.23 685408.58 9151.36 4110.94 4.00 88.00 3510.32 0.08 4.0E 15425.00 91.81 139.92 138.53 9009.28 9030.52 4348.18 6007174.65 685425.29 9132.78 4127.65 4.00 88.00 3528.19 0.08 4.00 15450.00 91.83 140.92 139.53 9008.48 9011.26 4364.10 6007155.79 685441.67 9113.92 4144.03 4.00 88.00 3545.76 0.08 4.0¢ 15475.0~ 91.85 141.92 140.53' 9007.68 8991.73 4379.68 6007136.64 685457.73 9094.77 4160.09 4.00 88.00 3563.02 0.08 4.00 15500.0C 91.87 142.92 141.53 9006.87 8971.93 4394.92 6007117.21 685473.44 9075.34 4175.80 4.00 88.00 3579.95 0.08 4.00 Meas, Incl, TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Tool Face Vertical Build Turn · Depth Angle Azi, Azi, TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Section Comments (deg) (deg) (deg) (~) Lat, (Y) Dep, (X) Lat. (Y) Dep, (X) Lat. (Y) Dep. (X) (°/100n) (from TIP) (°/100~) (°/100n) 15575.00 91.92 145.92 144.53 9004.39 8910.97 4438.53 6007057.33 685518.51 9015.46 4220.87 4.00 89.00 3628.81 0.08 4.00 15600.0G 91.94 146.92 145.53 9003.55 8890.16 4452.35 6007036.86 685532.84 8994.99 4235.20 4.00 89.00 3644.42 0.08 4.00 15625.0C 91.95 147.92 146.53 9002.7C 8869.10 4465.80 6007016.13 685546.8C 8974.26 4249.16 4.00 89.00 3659.69 0.04 4.00 15650.0C 91.97 148.92 147.53 9001.85 8847.82 4478.88 6006995.17 685560.3~ 8953.30 4262.75 4.00 89.00 3674.62 0.08 4.00 15675,00' 91.98 149.92' 148.53 9000.99 8826.31 4491.59 6006973.98 685573.62 8932.11 4275.98 4.00 89.00 3689.19 0.04 4.0G 15700.001 91.99 150.92 149.53 9000.12 8804.58 4503.93 6006952.55 685586.48~ 8910.68 4288.84 4.00 89.00 3703.40 0.04 4.00 15703.29 92.00 151.06 149.67 9000.0 8801.70 4505.52 6006949.72 685588.14 8907.85 4290.50 4.00 0.00 3705.24 0.30 4.26 T.D. I We. Il Structure · P2-Sg .._.. __ __ Coord,ntlt..s . Field · Point Mclntyre Location · North Slope, Alaska .......... ' · / ( ' --- .o,~, ..g.., '"TEO --- . Fast (.feet) -> 2550 2700 2850 5000 5 150 5500 5.lbO 3600 5/50 3900 4050 .1200 .15bO 4580 .1650 ,lSOO 9600 .... ~., .... /'~ '~x "*~, 5~ 9500 ,' %. xx~N 9 150 ,,, " P2-Sgbhs / Kick afl Point. tie on -- 8852,64 Tvd, 8949.90 N, 2850.89 E ,' ,' 8850 ,,' . P2-59ehs , " '[,D, & k-nd al Build 9000,00 lv('l, 8801,68 N, 4505,50 E ,' 8/00 ',, ,' / ',, , , " ~ ~55C) ,, ,, ",, 8400 ',,, ',, ~ lic. on - 56,21 Inc, 13500.00 Mci, 8aS?,Sa 'lvrh 2049,9S W~ ',,, Kick off Point ', T,D, &' End of I~uild/Turn 92.00 Inc, 15/0o.:.9 Mci, 9000,C)0 1'vd, 370b.24 Vs ',,,, ..... i ...... n ..... i ....... i ........ i ...... 1 ...... i i ~ ........ 1 ....... 1 ...... i ........ i ..... ~ ...... 1 ........ i ..... 1500 1650 1800 1950 21 O0 2250 2400 2550 2/00 2850 5000 5150 5500 5450 5600 5750 5900 4050 4200 4550 4500 4650 Verticml Section (feet) Azimuth 95.10 with reference 0.00 N, 0.00 E from P2-59 Alaska L. AY~OUT C T Drilling Wellhead Detail ~,, Methanol Injection Otis 7" WLA Quick Connect ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7" Riser Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual ~ Gate BOPE Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold Cutters or Combination CuttedBlinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Hydraulic over Electric ~ 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus 13-3/8" Annulus P2-59A Proposed CT Sidetrack Horizontal 4-1/2" Tubing Packer @ 13057__-- 7" Liner Top~ 13113' 4-1/2" SWS Nipple @ 13115' & 13136' Cement top in 7" -9800" 7"Casing Shoe @ 14348' 4-1/2" Otis SVLN Nipple@ 2096' 4-1/2" Camco MMG GLM's 9-5/8" Casing shoe @ 13409' Top of 3-3/16" Liner in TT Window cut in 7" at ,,,13615'- 13620' 4" Open hole Current perforations cement squeezed Initial Perfs 3-3/16" liner TD @~ 157OO' STATE OF ALASKA AL' 'A OIL AND GAS CONSERVATION COt,'- 'SSION APP~-~CATION FOR SUNDRY APPt-,--~VALS 1'. Type of Request: Abandon ~ Suspended__ Operation Shutdown m Re-enter suspended well Alter casing_ Repair well _ Plugging X Time extension_ Stimulate Change approved program __ Pull tubing__ Vadancem Perforate__ Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 535' FNL, 1048' FWL, Sec. 14, T12N, R14E At top of production interval 2077 FNL, 3964' FWL, Sec. 02, T12N, R14E At effective depth 1691' FNL, 4218' FWL, Sec. 02, T12N, R14E At total depth 1690' FNL, 1061' FEL, Sec. 02, T12N, R14E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKBE = 41.5' 7. Unit or Property name Point Mclntyre 8. Well number P2-59' 9. Permit number 90-140 10. APl number 500292209600 11. Field/Pool Point Mclntyre feet 12. Present well condition summary Total Depth: measured: true vertical: Effective Depth: measured: true vertical: Casing Length Size Conductor 114' 20" Surface 2990' 13-3/8" 14375 feet 9577 feet 13678 feet 9037 feet Cemented 180 ft3 Coldset II 2402 f¢ Coldset II Plugs (measured) Junk (measured) None. FISH -2.5' on top of filI/PKR CCTU Fishing neck / washout nozzle Measured depth True vertical depth 114' 114' 2990' 2680 Intermediate 13409' 9-5/8" 2850 f¢ Class G Liner 1235' measured 13646-13686' true vertical 13409' 7," 562 f¢ Class G 13113-14348 Perforation depth: . : DUPLICATE Tubing (size, grade, and measured depth) 4-1/2'' 12.6# LB0 @ 13148'; 4-'/2" 12.6# LB0 @ 13833-13848' Packers and SSSV (type and measured depth) 4-1/2" x 9-5/8" Otis Pkr @ 13057'MD; WRSV SSSV profile at 2096' MD 3. Attachments 882O 8588-9555 RECEIVED Description summary of proposal ~ Detailed operation program $~? ,; 0 i998 BOP sketch ~ - ....... A~horoge 14. Estimated date for commencing operation Oct, 1998 oi~ Date approved Status of well classification as: 16. If proposal was verbally approved Name of approver Service Gas Suspended Date September 30, 1998 17. I hereby certify that the foregoing&.~.~_..and correct to the best of my knowledge. Signed Stephen Ward -,~~"-' ,~/-~~ue Sr. Engineer I-(DH (.;fOMMI~5~51LJN U,..'Sb ONLY Conditi~un; ;nft;;dPrt~va_~: Notify Commission ~eenatative_m witness Mechanical Integr~~, ~%~ent ~ Approved by order of the Commission __ ~'~'" Commissioner Date I^..,ova,,,,oZ¢¢¢. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST COMPANY ~~.-_ c~ --- FIELI) & POOl.._ .... ~"~"~,/'~:~<::~ ...................... INIT CLASS _~-Z'_ ___._/. - <::2, ~/ ADMINISTRATION ENGINEERING WELl.. NAM ~,.~.~;:,~PROGRAM: exp [] dev/~;~' redrll~s'~v [] wellbore segll ann. disposal para I Perndt fee attached ...................... 2. Lease ~umber appropriate ................... 3. Unique well name and number .................. 4 Well located in a defined pool ................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficienl acreage available in drilling ~lnit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... GEOL AREA ~"~' <~ UNIT# ../._~_...~_~,~:D ......... ON/OFF SHORE APPR ~ 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMl- vol adequate to circulate on conductor & surf csg ..... 17. CM ! vol adequate to tie-in long string to sLIrf csg ........ 18. CMf' will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a '10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to _~o psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H~S gas probable ................. Y N Y N Y N DalaPemiit can be issued w,o hydrogen sulfide measureSpresented on potential overpressure zones ....... ..... ~Y N/~-.,~_ii~ii.-..__-~'._-_i"~iii'ii~ii'"-' .. .................................. Seismic analysis of shallow gas zones. ' Seabed condition survey (if off-shore) ............. (;ontact name/phone for weekly progress reports ...... z,/ Y N J'exploratory only] .......................................................................................... ,. Y N Y N GEOLOGY 30. 31. 32. 33. ~ ,...,..- ANNULAR DISPOSAL 35. With proper cemenling records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or caL~se drilling waste... to surface; ............................ (C) wili not impair mechanical integrity of the well ~sed for disposal; (I;)) will nol damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: JDH ~ RNC Comments/Instructions: , M chel~hsl I~,v
