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212-113
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU Z-61 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-113 50-029-23474-00-00 17891 Conductor Surface Intermediate Liner Production Liner 9008 80 2068 2949 14072 3941 14330 20" 13-3/8" 9-5/8" 7" 4-1/2" 8919 41 - 121 41 - 2109 1957 - 4906 37 - 14109 13948 - 17889 41 - 121 41 - 2031 1894 - 3506 37 - 8763 8630 - 9008 14620 470 2260 3090 5410 7500 14330, 14358 1490 5020 5750 7240 8430 11310 - 17835 4-1/2" 12.6# 13Cr80 35 - 11232, 13803 - 6593 - 9003 Structural 4-1/2" HES TNT Packer 13830, 8532 11128, 13830 6475, 8532 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, Borealis Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0047450, 0028262, 0028240 35 - 6542, 8511 - 8634 Perforations from 11310' - 11413'MD See attached treating reports 24 416 231 555 363 1659 937 313 358 323-290 13b. Pools active after work:Borealis Oil 4-1/2" HES TNT Perm Packer 11128, 6475 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 12:41 pm, May 23, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.05.22 19:22:31 - 08'00' Torin Roschinger (4662) CDW 05/23/2024WCB 8-28-2024 RBDMS JSB 053024 DSR-5/23/24 ACTIVITYDATE SUMMARY 3/12/2024 ***WELL S/I ON ARRIVAL*** BRUSHED X-NIP @ 11159'MD w/4-1/2'' BLB, 3.80'' G-RING SET 3.81'' PX-PLUG BODY IN X-NIP @ 11159'MD SET P-PRONG IN PX-PLUG BODY @ 11159'MD SET 4-1/2'' WHIDDON CATCHER SUB ON P-PRONG @ 11159'MD PULL ST #1 @ 11,028' MD ***GO ON WEATHER STANDBY DUE TO LOW TEMPS*** 3/13/2024 ***CONT WSR FROM 03-12-2024*** PULL ST #2 DOME @ 10,454' MD PULLED BK-GLV FROM ST#3 @ 9426'MD PULLED BK-GLV FROM ST#4 @ 7691'MD PULLED BK-GLV FROM ST#5 @ 4019'MD SET BK-DGLV IN ST#5 @ 4019'MD SET BK-DGLV IN ST#4 @ 7691'MD SET BK-DGLV IN ST#3 @ 9426'MD SET BK-DGLV IN ST#2 @ 10454' MD ***GO ON WEATHER STANDBY DUE TO LOW TEMPS*** 3/13/2024 T/I/O=1300/1300/0 Assist Slickline load and test,*** Cold weather standby*** continue job on 3-14-24 3/14/2024 ***CONTINUED FROM 3-13-24*** SET BK-FLOWSLV IN ST#1 @ 11028' MD T-BIRD CIRC 373bbls 1% KCl + FP TBG & IA TO 2500' ***MOVE TO WEATHER TICKET, STANDBY FOR LOW TEMPS (-40)*** 3/14/2024 T/I/O=1300/1300/0 Assist slickline with load and test, ***cold weather stand by -41*** job continued from 3/13/24-Pumped 2 BBLS 60/40 Spear followed by 373 BBLS 1%KCL followed by 89 BBLS crude. Pumped 1 BBLS tail spear. Swap to the Flowline Pumped 3 BBLS 60/40 to Freeze Protect the Flowline. U-Tube crude in well for TBG and IA freeze protect. FWHP=1250/1200/0 continue job on 3-15-24 3/15/2024 ***CONTINUED FROM 3-14-24*** PULLED ST#1 BK-FLOW SLV FROM 11028' MD SET ST#1 BK-DGLV @ 11028' MD TURN WELL OVER TO T-BIRD FOR MITs (see t-bird log) ***MOVE TO WEATHER TICKET*** 3/15/2024 T/I/O=1250/1200/0 Assist Slickline*** job continued from 3-14-24*** Pumped 14 BBLS Crude down IA to bring pressure to 1000 PSI. Pumped 2.8 BBLS crude down the TBG for A MIT-T ***PASS*** @ 4218/1040/0 1st 15 min TBG lost 28 PSI, 2nd 15 min TBG lost 12 PSI. ***PASS***. FWHP=962/1001/0 (Continue job on 3-16-24) Daily Report of Well Operations PBU Z-61 Daily Report of Well Operations PBU Z-61 3/16/2024 ***CONTINUED FROM 3-15-24*** PULLED WHIDOON CATCHER FROM 11140' SLM PULLED P-PRONG FROM 11159' MD PULLED 4-1/2'' PX-PLUG BODY FROM 11159' MD ***JOB COMPLETE, WELL LEFT S/I*** 3/16/2024 T/I/O=964/995/0 Assis slickline, Job continued from 3-15-24 MIT-IA ***PASS***Pumped 12.2 BBLS crude to Reach max PSI of 1398/3610/0, 1st 15 min 1394/3581/0 IA lost 29 PSI, 2nd 15 min 1390/3565/0 IA lost 16 PSI. ***PASS*** FWHP=894/244/0 3/27/2024 T/I/O = 213/683/7 Injectivity Test pre Frac (Fracturing) LRS Unit 46 & LRS Unit 72. Pump # 2 pumped 6.7 bbls of crude @ 0.5 BPM down IA to reach max PSI of 1500. Pump # 2 pumped 130 bbls & Pump # 1 pumped 80 bbls of 100*F 1% KCL @ 5 BPM to displace TBG volume (210 bbls total) TBG = 1654psi. SD for 15 min to monitor PSI, after 15 min TBG = 387psi. Pump # 1 online with 1% KCL @ 1BPM for 5 min TBG = 1281psi, increased rate to 2 BPM for 5 min TBG = 1556psi. Increased rate to 3 BPM for 5 min TBG = 1706psi. Increased rate to 4 BPM for 5 min, TBG = 1800psi. Increased rate to 5 BPM for 5 min TBG = 1859. Pump # 2 online. 1 BPM for 5 min (6 BPM total) TBG = 1932psi. Increased rate to 2 BPM for 5 min (7 BPM total) TBG = 2010psi. Increased rate to 3 BPM for 5 min (8 BPM total) TBG = 2052psi. Increased rate to 4 BPM for 5 min (9 BPM total) TBG = 2144psi. Increased rate to 5 BPM (10 BPM total) TBG = 2186psi. SD & monitor TBG for 30 minutes. After 30 min TBG = 442psi. Total 1% KCL bbls pumped during step rate test = Pump # 1 = 251 bbls, Pump # 2 = 102 bbls (353 bbls combined). Pump # 2 Freeze Protected TBG with 4 bbls of 60/40 and 41 bbls of crude. FWHP = 1996/638/13 3/27/2024 T/I/O= 204/683/0. LRS Pump #2 Injectivity/Step Rate Test (FRACTURING). See Pump #1 report for further details. Pumped 130 bbls of 109*F KCl as part of 210 bbl TBG load. Pumped 102 bbls of 1% KCl in conjuction with LRS 46 to achieve step rate up to 10 bpm rate at 2200 psi. Freeze protected the TBG with 3 bbls of 60/40 Meoh and 41 bbls of crude. Final T/I/O= 404/638/1. 4/23/2024 Z-61: Scope- FRAC STIM OF KUPARUK C SANDS. Spot & RU remaining SLB Frac equipment.LRS Pump truck heat diesel. PT Treating Iron per the program. Pump Frac Stim in the KRU C Sands per the Pump schedule. OE Redesigned pump schedule after the data Frac. Pumped 150k lbs of 16/20 CarboLITE at 20 bpm. Flush was called early & we screened out just after 9 ppa hit the perfs. Delivered 105,000 lbs of Propant behind pipe, right at 60% of the job design.Squeeze ~35 bbls of FP in the well. Clean oup surface lines. Secure the well & notify Pad Operator. RD SLB frac equipment. Prep for CTU FCO. Frac Job complete. CTU up next for FCO 4/23/2024 LRS 72 Assist SLB (FRACTURING). Fill SLB transport with 90 bbls of 100*F diesel. Test each PRV at 3350 psi. Rig to bleed OA as needed to OTT. Hold IA pressure as directed. Final IA/OA = 450/1. g OE Redesigned pump schedule after the data Frac. Pumped 150k lbs of 16/20g CarboLITE at 20 bpm. Flush was called early & we screened out just after 9 ppa hityj the perfs. Delivered 105,000 lbs of Propant behind pipe, right at 60% of the job design. LRS Unit 46 & LRS Unit 72.jy (g) Pump # 2 pumped 6.7 bbls of crude @ 0.5 BPM down IA to reach max PSI of 1500.@ Pump # 2 pumped 130 bbls & Pump # 1 pumped 80 bbls of 100*F 1% KCL @ 5 BPM @ to displace TBG volume (210 bbls total) TBG = 1654psi. SD for 15 min to monitor () PSI, after 15 min TBG = 387psi. Pump # 1 online with 1% KCL @ 1BPM for 5 min@ TBG = 1281psi, increased rate to 2 BPM for 5 min TBG = 1556psi. Increased rate to 3 BPM for 5 min TBG = 1706psi. Increased rate to 4 BPM for 5 min, TBG = 1800psi. Increased rate to 5 BPM for 5 min TBG = 1859. Pump # 2 online. 1 BPM for 5 min (6 BPM total) TBG = 1932psi. Increased rate to 2 BPM for 5 min (7 BPM total) TBG =)() 2010psi. Increased rate to 3 BPM for 5 min (8 BPM total) TBG = 2052psi. Increased() rate to 4 BPM for 5 min (9 BPM total) TBG = 2144psi. Increased rate to 5 BPM (10 ()( BPM total) TBG = 2186psi. SD & monitor TBG for 30 minutes. After 30 min TBG = ) 442psi. Total 1% KCL bbls pumped during step rate test = Pump # 1 = 251 bbls, g Pump # 2 = 102 bbls (353 bbls combined). Pump # 2 Freeze Protected TBG with 4( bbls of 60/40 and 41 bbls of crude. f Daily Report of Well Operations PBU Z-61 4/24/2024 LRS #2 coil. 2" 0.156WT Objective: FCO post frac MIRU LRS CTU #2. Standby for Worley to load fluids. M/U Slim BHA & RIH - 2" Rev Nozzle. At 2300' ctm, swap coil and well over to KCI. Establish 1:1 returns. Begin reverse cleanout 2,500' ctm. ***FCO In Progress*** 4/25/2024 LRS #2 coil. 2" 0.156WT Objective: FCO post frac Continue reverse cleanout 2700' - 4,000. 9.3 ppg sand returns at 2800'ctm. At 4000' ctm, broke through bridge and lost WHP, Circ, and returns. Swap to conventional and clear the coil. Establsih returns 1:1. Continue conventional FCO 4000' ctm - 7,150' ctm. Reciprocate pipe while Worley catches up w/fluids. Continue FCO taking bites and sweeping with gel 7,150' - 11,450'. Pump final gel sweepat 11,450' and chase out of hole. Make passes and jet across GLM's 1 - 5 while Pooh w/BHA. FP coil w/60 bbls of diesel. FP tubing w/48 bbls of diesel. RDMO LRS CTU #2. ***Job Completed*** 4/27/2024 ***WELL S/I ON ARRIVAL***(fracturing) BRUSHED GLM'S AND X-NIPPLES DOWN TO 11,180' SLM (coil shavings in brush) RAN 3.60" CENT, TEL, 3.0" SAMPLE BAILER, LOC TT @ 11,188' SLM (44' corr). TAG HARD TD @ 11,857' SLM (488' rat hole, sample of frac sand) ***CONT WSR ON 4/28/24*** 4/28/2024 ***CONT WSR FROM 4/27/24*** (fracturing) SET 4 1/2" X-CATCHER IN X-NIPPLE @ 11,104' MD PULLED BK-DGLV FROM STA #4 @ 7,691' MD. PULLED BK-DGLV FROM STA #1 @ 11,028' MD. PULLED BK-DGLV FROM STA #2 @ 10,454' MD. PULLED BK-DGLV FROM STA #3 @ 9,425' MD. PULLED BK-DGLV FROM STA #5 @ 4,019' MD. SET BK-LGLV (16/64",1694#) IN ST#5 @ 4,019' MD. SET BK-LGLV (16/64",1717#) IN ST#4 @ 7,691' MD. SET BK-LGLV (16/64",1712#) IN ST#3 @ 9,425' MD. SET BK-LGLV (16/64",1700#) IN ST#2 @ 10,454' MD. SET BK-S/O (24/64") IN ST#1 @ 11,028' MD. ***CONT WSR FROM 4/28/24*** 4/28/2024 Well Testing Unit # 6, Begin WSR, IL well Z-61, OL well Z-69, Unit move, SB for Slickline, Continue WSR on 4/29/24 4/29/2024 ***CONT WSR FROM 4/28/24*** (fracturing) PULLED 4 1/2" X-CATCHER FROM 11,104' MD (empty) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 4/29/2024 Well Testing Unit # 6, Cont WSR from 4/28/24, IL well Z-61, OL well Z-69, Cont SB for Slickline, RU, PT, POP, Flowback, Continue WSR on 4/29/24 4/30/2024 Well Testing Unit # 6, Cont WSR from 4/29/24, IL well Z-61, OL well Z-69, Flowback, Continue WSR on 5/1/24 5/1/2024 Well Testing Unit # 6, Cont WSR from 4/30/24, IL well Z-61, OL well Z-69, Flowback, Continue WSR on 5/2/24 5/2/2024 Well Testing Unit # 6, Cont WSR from 5/1/24, IL well Z-61, OL well Z-69, Flowback, 12 hr PBWT, Continue WSR on 5/3/24 5/3/2024 Well Testing Unit # 6, Cont WSR from 5/2/24, IL well Z-61, OL well Z-69, Flowback, Cont 12 hr PBWT, BD, RD, End WSR 12:38:14 13:15:44 13:53:14 14:30:44 15:08:14 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 Pressure - psi0 5 10 15 20 25 Rate - bbl/min0 2 4 6 8 10 12 14 16 18 20 Prop Con - PPATreating Pressure Annulus Pressure Slurry Rate Prop Conc BH Prop Con Main Treatment © Schlumberger 1994-2017 Hilcorp Z-61 04-23-2024 12:20:23 12:53:43 13:27:03 14:00:23 14:33:43 Time - hh:mm:ss 0 100 200 300 400 J532, S123_CONC - gal/mgal0 1 2 3 4 5 6 F103, L065, L071_CONC - gal/mgal0 1 2 3 4 5 J475_Conc0 10 20 30 40 PCM_GUAR_CONC_STPT - lb/mgalJ532 Conc S123 Conc F103 Conc L065 Conc L071 Conc J580 Conc J475 Conc Additive Plot © Schlumberger 1994-2017 Hilcorp Z-61 04-23-2024 Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 04/23/2024 Job End Date: 04/23/2024 State: Alaska County: Beechey Point API Number: 50-029-23474-00-00 Operator Name: Hilcorp Alaska, LLC Well Name and Number: Z-61 Latitude: 70.298055 Longitude: -149.190745 Datum: NAD27 Federal Well: NO Indian Well: NO True Vertical Depth: 9008 Total Base Water Volume (gal)*: 51238 Total Base Non Water Volume: 0 Water Source Percent Surface Water, < 1000TDS 100.00% Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Comments F103 Schlumberger Surfactant Fluid Schlumberger N/A J475 Schlumberger Breaker J475 J532 Schlumberger Crosslinker J580 Schlumberger Gel J580 L065 Schlumberger Scale Inhibitor L071 Schlumberger Clay Control Agent M275 Schlumberger Bactericide S123 Schlumberger Activator S522- 1620 Schlumberger Propping Agent Items above are Trade Names. Items below are the individual ingredients. Water (Including Mix Water 7732-18-5 0.00000 80.81643 None Supplied by Client)* Ceramic materials and wares, chemicals 66402-68-4 97.04311 18.61634 None Guar gum 9000-30-0 1.23571 0.23705 None 2-hydroxy-N,N,N- trimethylethanaminium chloride 67-48-1 0.29914 0.05738 None 1, 2, 3 - Propanetriol 56-81-5 0.21349 0.04096 None Ethylene Glycol 107-21-1 0.19627 0.03765 None 2-Propenoic acid, polymer with sodium phosphinate 129898-01-7 0.18339 0.03518 None Sodium tetraborate decahydrate 1303-96-4 0.17433 0.03344 None Diammonium peroxodisulphate 7727-54-0 0.14660 0.02812 None Propan-2-ol 67-63-0 0.14127 0.02710 None 2-butoxyethanol 111-76-2 0.07550 0.01448 None Ethoxylated C11 Alcohol 34398-01-1 0.06935 0.01330 None Alcohols, c11-15-secondary, ethoxylated 68131-40-8 0.06578 0.01262 None Ethoxylated Alcohol 68131-39-5 0.03764 0.00722 None Sodium chloride 7647-14-5 0.03668 0.00704 None Vinylidene chloride/methylacrylate copolymer 25038-72-6 0.03482 0.00668 None Calcium chloride 10043-52-4 0.01883 0.00361 None Diatomaceous earth, calcined 91053-39-3 0.00887 0.00170 None 1-undecanol (impurity) 112-42-5 0.00604 0.00116 None Silicon Dioxide (Impurity) 7631-86-9 0.00310 0.00059 None 2,2''-oxydiethanol (impurity) 111-46-6 0.00198 0.00038 None Magnesium nitrate 10377-60-3 0.00177 0.00034 None 5-chloro-2-methyl-4- isothiazolin-3-one and 2- methyl-4-isothiazolin-3-one 55965-84-9 0.00106 0.00020 None Sodium hydroxide (impurity) 1310-73-2 0.00099 0.00019 None Potassium chloride (impurity) 7447-40-7 0.00099 0.00019 None Magnesium silicate hydrate (talc)14807-96-6 0.00092 0.00018 None poly(tetrafluoroethylene) 9002-84-0 0.00092 0.00018 None Magnesium chloride 7786-30-3 0.00089 0.00017 None Acetic acid, potassium salt (impurity)127-08-2 0.00023 0.00004 None Cristobalite 14464-46-1 0.00018 0.00003 None Quartz, Crystalline silica 14808-60-7 0.00018 0.00003 None Acetic acid (impurity) 64-19-7 0.00004 0.00001 None * Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) 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 planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU Z-61 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-113 50-029-23474-00-00 471 ADL 0047450, 0028262, 0028240 17891 Conductor Surface Intermediate Production Liner 9008 80 2068 2949 14072 3941 14330 20" 13-3/8" 9-5/8" 7" 4-1/2" 8919 41 - 121 41 - 2109 1957 - 4906 37 - 14109 13948 - 17889 1633 41 - 121 41 - 2031 1894 - 3506 37 - 8763 8630 - 9008 None 470 2260 3090 5410 7500 14330, 14358 1490 5020 5750 7240 8430 11310 - 17835 4-1/2" 12.6# 13Cr80 35 - 11232, 13803 -139536593 - 9003 Structural 4-1/2" HES TNT Packer 4-1/2" HES TNT Perm Packer 11128, 6475 13830, 8532 Date: Torin Roschinger Area Operations Manager Claire Mayfield claire.mayfield@hilcorp.com 907.564.4375 PRUDHOE BAY 6/5/2023 Current Pools: Borealis Oil Proposed Pools: Borealis Oil 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 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-290 By Grace Christianson at 12:00 pm, May 16, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.05.16 11:12:33 -08'00' Torin Roschinger (4662) Fracture Stimulate 6/5/2023 1633 SFD 5/26/2023 10-404 CDW 05/26/2023 MGR30MAY23 DSR-5/17/23GCW 05/31/23 05/31/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.05.31 12:21:03 -08'00' RBDMS JSB 060123 Frac post RWO Well: Z-61 PTD: 212-113 Well Name:Z-61 API Number:50-029-23474-00 Current Status:Operable Shut In producer for marginals Estimated Start Date:6/05/2023 Rig:SL/Coil Sundry #Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:212-113 First Call Engineer:Claire Mayfield (907) 564-4375 (O)(713) 443-3631 (M) Second Call Engineer:Brodie Wages (907) 564-5006 (O)(907) 380-9836 (M) Current Bottom Hole Pressure:2293 psi @ 6600’ TVDss 6.7 PPG | (4/7/2023 static) Max. Anticipated Surface Pressure:1633 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 950 psi (Taken on 5/1/2023) Min ID:3.813” X at 2416’ MD Max Angle:98 Deg @ 14848’ MD 70 deg: 14562’ (~Vertical to Kuparuk) Formation Tops: Kuparuk: 11,310’ MD / 6,594’ TVD Sag: 14,105’ MD / 8,759’ TVD Ivishak: 14,346’ MD / 8,759’ TVD MITs: MIT-T: 3530 psi on 3/17/2023 MIT-IA: 4001 psi on 5/1/2023 Brief Well Summary: Z-61 was drilled as an ivishak producer in 2013, but was shut in for high TGOR. It was recently recompleted to the Kuparuk reservoir to test production rates and water cuts at the Kuparuk interval. The Ivishak is isolated but not permanently abandoned in the event future EWE debottlenecking projects make it economically viable to produce. The well was put on production but made very low fluid rates. Going forward the well will be frac’d to stimulate fluid production. Notes Regarding Wellbore Condition x Drilled in 2013 and completed with 13cr tbg x USIT log of the 7” production casing shows TOC at ~10,780’. x Some history of OA repressurization, but appears to be from and external source x Well has a history of shallow paraffin to ~800’ x Last drift attempt on 8/21 could not get past X-Nipple at 13,801’ MD with 3.80” swage, but able to drift with 3.70” dummy whipstock. x Well was secured with an evo trieve for LTSI on 8/22/19 and passed a CMIT-TxIA to 2,443psi. x Evo trieve plug pulle and TBG caliper ran 2/2/2023 to assess the condition of the 4.5” completion. x 2/19/2023 set CIPB above Sag and Ivishak, dumped cement on top, passed CMIT to 2650psi x 3/17/2023 completed RWO to pull tubing and re-run tubing with production packer above Kuparuk x 3/21/2023 perforated Kuparuk reservoir Objective: x DMY valves, circ packer fluid, frac and flowback e Ivishak is isolated but not permanently abandoned recently recompleted to the Kuparuk Frac post RWO Well: Z-61 PTD: 212-113 Sundry Procedure (Approval Required to Proceed) Slickline with fullbore assist 1. Set plug in X nipple at 11,159’MD 2. Dummy GLVs above St1 3. Pull St1 GLV for circ’ing in KWF 4. Load hole with 1% KCl + Freeze protect a. Total T+IA volume to St#1: 373 bbls b. Freeze protect volume to 2500’ in tbg and IA: 38bbl + 47bbls = 85 bbls 5. Dummy st#1 6. MIT-T to 4000 psi, hold 1000psi on IA 7. Obtain 3500 psi MIT-IA a. Hold 1000 psi on the tubing during MIT-IA 8. Pull plug in X nipple Frac/Special Projects 1. Spot water tanks and fill with fresh water a. Heat water to 110 degF b. Minimum pumping temp for water: 90 degF 2. Pull water from each tank and have SLB lab test our water quality: a. pH - ~7 i. Higher pH delays the hydration of the gel and delays break b. Calcium/magnesium <500 mg/l i. Mg/Ca Negative side effects in the formation such as carbonate deposits, which tend to be insoluble c. Bicarbonate - <400 mg/l i. High bicarbonate levels will cause slow hydration times and elevated delay times with X-linking fluids. If we have elevated bicarbonate levels and have introduced delay agents, it could have an exponential effect in delay times. d. Chlorides-<10,000 mg/l i. This fluid system should be able to cope with elevated Chloride levels e. Iron (Fe+3) - <5 mg/l i. Elevated Iron concentrations exist, the ammonium persulfate (breaker) can have an accelerated effect. Can cause viscosity degradation in linear gels (especially if batch mixed). Also can interfere with X-linking b/c iron will tie up the X-linking sites. f. TDS – minimal/<5000 i. Effects depend on the solids that are dissolved in the fluid. Frac post RWO Well: Z-61 PTD: 212-113 3. Frac per pump schedule MIT-T 4000 psi MIT-IA 3530 psi Maximum Anticipated Treating Pressure:2900 psi @ 25 BPM IA Pop-off Set Pressure (~95% of MIT-IA):3350 psi IA Minimum Hold Pressure (POP-off – 300 psi):3000 psi Maximum Allowable Treating Pressure (MATP = Ann hold + MIT-T): 4500 psi (tree limited to 5000psi) Stagger Pump Kickouts Between 90 – 95% of MATP: 4050 - 4300 Global Kickout (95% of MATP):4300 psi N2 POP-off set pressure (MATP + 1000 psi):5500 psi Treating Line Test Pressure (MATP + 1000 psi):5500 psi x If treating pressure starts acting sporadic, consider dropping rate to as low as 11 ppa. If it is acting up at 11 ppa, we should be on flush. Slickline This step may need to be performed prior to coil FCO if stable returns cannot be established 1. Drift, tag fill – determine whether coil FCO likely needed 2. Install catcher 3. Install LGLVs 4. Pull catcher 5. RDMO Coil Tubing - Pending – Only FCO if unable to get returns due to fill 1. MIRU and pressure test 2. MU JSN or down jet 3. FCO to 11,460’ 4. POH Testers: 1. MIRU, pressure test 2. POP the well to ASRC with 1-1.5 MMSCFD Lift gas at minimum choke, adjust GL rate as necessary to eliminate slugging. Flow the initial returns to the flowline as long as the shake-outs meet the returned fluid/solids management guidelines. 3. Limit flow to 500 bpd 4. If solids are < 1%, after 1.5 wellbore volumes (120 bbls) increase the production rate to 750 BLPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1%, increase flow to 1000 BFPD. 6. Flow bottoms up and sample for solids production. If solids are still below 1% continue to increase the flow rate in 250 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1%; allow well clean up before choke is opened further. 7. Once at FOC, stabilize the well for 4 hrs. Obtain an 8 hr welltest. Pressure test treating lines to 5500 psi. Test IA pop off system to 5500 psi. - mgr A Minimum Frac post RWO Well: Z-61 PTD: 212-113 Current WBD: Frac post RWO Well: Z-61 PTD: 212-113 Z-61 Fracture Stimulation PTD: 212-113 Page 1 Date: May 12, 2023 Subject: Z-61 Fracture Stimulation From: Claire Mayfield O: (907) 564-4375 C: (713) 443-3631 To: AOGCC Estimated Start Date: 6/05/2023 Attached is Hilcorp’s proposal and supporting documents to perform a fracture stimulation on well Z-61 in the Kuparuk reservoir of the Prudhoe Bay Unit. The objective of this program is to perform a single stage fracture stimulation to the existing Kuparuk perforations to improve well performance. Z-61 was recently recompleted as a Kuparuk producer, previously an Ivishak producer. The Ivishak perforations were plugged on 2/18/2023 with 28 feet of cement on top of a cast iron bridge plug. Isolation from the Ivishak was demonstrated with a state witnessed passing MIT on 2/19/2023. An Hilcorp requests a variance to sections 20 AAC 25. 283, a, 3- 4 which require identification of fresh - water aquifers and a plan for base-water sampling. Please direct questions or comments to Claire Mayfield. 6/05/2023 Z-61 Fracture Stimulation PTD: 212-113 Page 2 SECTION 1 - AFFIDAVIT (20 AAC 25. 283, a, 1): Below is an affidavit stating that the owners, landowners, surface owners and operators identified on a plat within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283, a 1 Z-61 Fracture Stimulation PTD: 212-113 Page 3 SIGNED AFFIDAVIT: 20 AAC 25.283(m) 20 AAC 25.283(a)(1) Z-61 Fracture Stimulation PTD: 212-113 Page 4 COPY OF NOTIFICATION SENT VIA EMAIL: Z-61 Fracture Stimulation PTD: 212-113 Page 5 SECTION 2: PLAT IDENTIFYING ALL WELLS WITHIN ½ MILE (20 AAC 25. 283, a, 2): Plat of wells within one-half mile of Z-61 trajectory. Z-61 Fracture Stimulation PTD: 212-113 Page 6 List of wells in Plat 20 AAC 25.283, a, 2 Sw Name Well Class Desc Well Status Desc Sw Name Well Class Desc Well Status Desc Z-01 Development Abandoned Z-21A Development Oil Producer Shut-In Z-01A Development Abandoned Z-22 Development Abandoned Z-01APB1 Development Plugged Back For Redrill Z-220 Development Oil Producer Flowing Z-01APB2 Development Plugged Back For Redrill Z-220PB1 Development Plugged Back For Redrill Z-01B Development Oil Producer Shut-In Z-220PB2 Development Plugged Back For Redrill Z-02 Development Abandoned Z-221 Service Miscible Injector Shut-In Z-02A Service Water Injector Injecting Z-222 Development Oil Producer Gas Lift Z-03 Development Abandoned Z-223 Service Water Injector Shut-In Z-03A Development Oil Producer Gas Lift Z-228 Development Oil Producer Gas Lift Z-04 Development Abandoned Z-229 Development Oil Producer Gas Lift Z-04A Development Oil Producer Gas Lift Z-228 Development Oil Producer Gas Lift Z-05 Development Abandoned Z-22A Development Abandoned Z-05A Development Oil Producer Shut-In Z-22B Development Oil Producer Shut-In Z-05APB1 Development Plugged Back For Redrill Z-23 Development Abandoned Z-06 Development Abandoned Z-23A Development Abandoned Z-06A Development Oil Producer Gas Lift Z-23B Development Abandoned Z-07 Development Abandoned Z-23C Development Oil Producer Shut-In Z-07A Development Abandoned Z-23PB1 Development Plugged Back For Redrill Z-07B Development Oil Producer Shut-In Z-24 Development Oil Producer Flowing Z-08 Development Abandoned Z-25 Service Miscible Injector Operating Z-08A Development Oil Producer Shut-In Z-26 Development Abandoned Z-09 Development Abandoned Z-26A Development Oil Producer Gas Lift Z-09A Development Oil Producer Shut-In Z-27 Development Oil Producer Gas Lift Z-10 Development Abandoned Z-28 Service Water Injector Injecting Z-100 Development Oil Producer Flowing Z-29 Development Oil Producer Shut-In Z-101 Development Oil Producer Shut-In Z-30 Development Abandoned Z-102 Service Miscible Injector Operating Z-30A Development Oil Producer Shut-In Z-102PB1 Service Plugged Back For Redrill Z-31 Service Miscible Injector Operating Z-103 Service Water Injector Injecting Z-32 Development Abandoned Z-103PB1 Service Plugged Back For Redrill Z-32A Development Abandoned Z-103PB2 Service Plugged Back For Redrill Z-32B Development Abandoned Z-108 Development Oil Producer Shut-In Z-32BL1 Development Abandoned Z-10A Development Oil Producer Gas Lift Z-32BPB1 Service Plugged Back For Redrill Z-11 Development Abandoned Z-32BPB2 Development Plugged Back For Redrill Z-112 Development Oil Producer Gas Lift Z-32C Development Oil Producer Gas Lift Z-112PB1 Development Plugged Back For Redrill Z-33 Development Abandoned Z-112PB2 Development Plugged Back For Redrill Z-33A Service Water Injector Injecting Z-113 Development Oil Producer Flowing Z-34 Development Water Injector Shut-In Z-113PB1 Development Plugged Back For Redrill Z-35 Development Oil Producer Shut-In Z-114 Service Miscible Injector Operating Z-35PB1 Development Plugged Back For Redrill Z-115 Development Oil Producer Gas Lift Z-38 Development Oil Producer Shut-In Z-116 Service Water Injector Injecting Z-38PB1 Development Plugged Back For Redrill Z-116PB1 Service Plugged Back For Redrill Z-39 Development Abandoned Z-116PB2 Service Plugged Back For Redrill Z-39A Development Oil Producer Shut-In Z-11A Development Oil Producer Gas Lift Z-40 Development Oil Producer Gas Lift Z-12 Service Water Injector Injecting Z-46 Development Abandoned Z-13 Development Abandoned Z-46A Development Oil Producer Gas Lift Z-13A Development Oil Producer Gas Lift Z-50 Development Oil Producer Gas Lift Z-13APB1 Development Plugged Back For Redrill Z-504A Service Water Injector Shut-In Z-14 Development Abandoned Z-504B Service Water Injector Shut-In Z-14A Service Abandoned Z-61 Development Oil Producer Shut-In Z-14B Development Oil Producer Shut-In Z-61PB1 Development Plugged Back For Redrill Z-15 Development Abandoned Z-65 Development Oil Producer Shut-In Z-15A Development Oil Producer Shut-In Z-65PB1 Development Plugged Back For Redrill Z-15APB1 Development Plugged Back For Redrill Z-66 Development Oil Producer Shut-In Z-15APB2 Development Plugged Back For Redrill Z-66PB1 Development Plugged Back For Redrill Z-16 Development Abandoned Z-67 Service Miscible Injector Operating Z-16A Development Oil Producer Shut-In Z-68 Development Suspended Z-17 Development Abandoned Z-68PB1 Development Plugged Back For Redrill Z-17A Development Oil Producer Shut-In Z-69 Development Oil Producer Gas Lift Z-17APB1 Development Plugged Back For Redrill Z-70 Development Suspended Z-18 Service Water Injector Injecting Z-71 Development Oil Producer Shut-In Z-19 Development Abandoned HYDRATE-01 Exploratory Suspended Z-19A Service Water Injector Injecting HYDRATE-02 Exploratory Gas Producer Z-19XX Never Drilled Never Drilled - Well CancelledHYDRATE-P1 Exploratory Gas Producer Z-20 Development Oil Producer Flowing HYDRATE-P2 Exploratory Gas Producer Z-21 Development Abandoned K071112 Exploratory Suspended Z-210 Service Water Injector Shut-In K071112PB1 Exploratory Suspended Z-210PB1 Service Plugged Back For Redrill CHEV181112 Exploratory Suspended Z-61 Fracture Stimulation PTD: 212-113 Page 7 SECTION 3: EXEMPTION FOR FRESWATER AQUIFERS (20 AAC 25. 283, a, 3): Well Z-61 is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated July 11, 1986 where Standard Alaska Production Company requested the Alaska Oil and Gas Conservation Commission to issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II Injection activities. Findings 1- 4 state: 1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are situated at a depth and location that makes recovery of water for drinking water purposes economically impracticable. 3. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are reported to have total dissolved solids content of 7000 mg/ I or more. 4. By letter of July 1, 1986, EPA- Region 10 advises that the aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a non-substantial program revision not requiring notice in the Federal Registrar. Per the above findings, " Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC 25. 440" thus allowing Hilcorp exemption from 20 AAC 25. 283, a, 3- 4 which require identification of freshwater aquifers and establishing a plan for base-water sampling. Z-61 Fracture Stimulation PTD: 212-113 Page 8 SECTION 4: PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283.a.4 There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. Z-61 Fracture Stimulation PTD: 212-113 Page 9 SECTION 5: DETAILED CEMENTING AND CASING INFORMATION (20 AAC 25. 283, a, 5): All casing is cemented in accordance with 20 AAC 25.52, b and tested in accordance with 20 AAC 25.030, g when completed. See wellbore schematic for casing details: Z-61 Fracture Stimulation PTD: 212-113 Page 10 Z-61 Fracture Stimulation PTD: 212-113 Page 11 SECTION 6: ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283, a, 6 Summary: Z-61 spudded on 1/2/2013 and drilled the 16” surface hole from 120’ to 2119’. They ran 13-3/8” casing to 2109’ but had issues cementing to surface around the shoe, ultimately pumping six additional top- down remedial cement jobs. On the final remedial cement job, cement returns were observed at surface. After WOC, they pressure tested the 13-3/8” casing 250psi low, 3500psi high 30 min each and passed. Drilling progressed out the surface casing shoe into new formation making 12-1/4” hole to 4906’MD and ran 9-5/8” liner to 4906’ MD placing the top of liner at 1957’MD. The liner was cemented with 101 bbls 12.0 ppg Litecrete cement, followed by 189 bbls 15.9ppg class G cement, no losses were observed. The 8-3/4” intermediate hole was drilled out of the 9-5/8” liner shoe to 14,144’MD with ~0-10 BPH losses throughout. The 7” casing was run to 14,144’MD and cemented with 288.6 bbls Litecrete 11.5ppg followed by 22 bbls 15.8ppg Class G cement. While displacing cement, a total of 360 bbls losses were reported. The casing was pressure tested 250psi low / 5000psi high and passed. A USIT log on Eline was run and found top of cement at ~10,750’ in the 7” casing. The 6-1/8” production hole was drilled out of the 7” casing shoe to TD 17,891’MD. The 4-1/2” liner was run to 17,891’ MD, the liner hanger and liner top packer was set at 13,948’MD. The liner top packer was tested to 250psi low and 3500psi high and passed on the second attempt. Finally, 4-1/2” tubing was run in hole from surface to 8,606’ MD. The production packer was set and pressure tested completing the well on 2/20/2013. The well was put on production. On 2/18/2023, a CIBP was set in the 4-1/2” liner at 14,358’ MD with cement dump bailed on top to isolate the Ivishak reservoir. On 3/30/2023, a rig workover was completed to recomplete the well to the Kuparuk reservoir. The original 4-1/2” tubing was cut at 13,804’MD, pulled, then re-ran to 11,232’MD and new production packer set at 11,128’ MD. 103’ of perfs were added in the Kuparuk post rig, and the well is waiting to be stimulated with a single stage frac. All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, Hilcorp has determined that this well can be successfully fractured within its design limits. A frac in 2012 conducted on a similarly designed offset well, Z-115, had a max treating pressure of 3415psi which is similar or higher than what is planned for Z-61. 14,109' SFD single stage frac. Agree. SFD 5/26/2023 14,114' SFD f 3415p Z-61 Fracture Stimulation PTD: 212-113 Page 12 SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO PRESSURE TEST CASINGS AND TUBING INSTALLED IN THE WELL 20 AAC 25.283, A, 7 On 3/17/2023, the production casing was pressure tested to 3530 psi for a passing MIT-IA. On 5/1/2023, the tubing was pressure tested to 4001 psi for a passing MIT-T. The production casing annulus pressure will be monitored during the frac, if any change of pressure is seen outside of thermal expansion, the job will be flushed and the pressure source diagnosed before frac operations continue. Z-61 Fracture Stimulation PTD: 212-113 Page 13 SECTION 8: PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283, A, 8 Wellbore Tubular Ratings Size/Name Weight Grade Burst, psi Collapse, psi 13-3/8” Surface Casing 68#L80 5020 2260 9-5/8” Surface Casing 40#L80 5750 3090 7” Production Casing 26#13Cr-80 7240 5410 4-1/2” Production Tubing 12.6#13Cr-80 8430 7500 4-1/2” Production Liner 12.6#13Cr-80 8430 7500 Wellhead FMC manufactured wellhead, rated to 5, 000 psi. Tubing head adaptor: 11" 5, 000 psi x 4-1/16" 5,000 psi Tubing Spool: 11” 5,000psi w/ 2-1/16” side outlets Casing Spool: 11” 5,000psi w/ 2-1/16” side outlets Tree: CIW 4-1/16” 5,000psi No tree saver planned to be used. Planned surface treating pressure <4000psi. Z-61 Fracture Stimulation PTD: 212-113 Page 14 SECTION 9: DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283, A, 9 Formation MD Top MD Bot TVDss Top TVDss Bot TVD Thickness Frac Grad psi/ft Lith. Desc. THRZ 10979 11243 -6283 -6453 170 0.7 Shale TKLB 11243 11308 -6453 -6495 42 0.7 Shale Top Kup/C interval 11308 11414 -6495 -6564 68 0.62 Silts/SS LCU/ Kuparuk B 11414 11533 -6564 -6639 76 0.64 Silts/SS Kuparuk A 11533 11656 -6639 -6717 77 0.66 Silts/SS Miluveach 11656 12650 -6717 7467 750 0.7 Shale Z-61 Fracture Stimulation PTD: 212-113 Page 15 SECTION 10: LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283, a, 10 Plat of wells within one-half mile of Z-61 wellbore reservoir trajectory and location of faults. The blue line indicates the approximate fracture length and orientation of the frac’s. The plat shows the location and orientation of each well that transects the confining zone. Hilcorp has formed the opinion, based on the following assessments for each well and seismic, well and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Z-61 Fracture Stimulation PTD: 212-113 Page 16 Casing and Cement assessments for all wells that transect the confining zone: Z-61:After cementing the surface casing (13-3/8”) and surface casing liner (9-5/8”), the 8-3/4” intermediate hole was drilled to 14,144’MD where 7” casing was run and cemented in place with 288.6 bbls Litecrete 11.5ppg followed by 22 bbls 15.8ppg Class G cement. A USIT log was run and found TOC at 10,750’ MD/-6139TVDss, top of Kuparuk interval at 11308’MD/-6495TVDss. Z-61PB1:2000’ plug back of the 12-1/4” hole made below the surface casing set in Z-61. After cementing the surface casing (13-3/8”) and surface casing liner (9-5/8”), the 8-3/4” intermediate hole was drilled to 14,144’MD where 7” casing was run and cemented in place with 288.6 bbls Litecrete 11.5ppg followed by 22 bbls 15.8ppg Class G cement. A USIT log was run and found TOC at 10,750’ MD/- 6139TVDss, top of Kuparuk interval at 11308’MD/-6495TVDss. Z-19:After cementing the surface casing, intermediate hole was drilled to 13802’ MD and cemented with 2569 sx Class G cement. A USIT log was run pre-P&A of this well years later before a planned sidetrack that found TOC at 2385' MD/-2110TVDss, top of Kuparuk interval at 10090’ MD/-6649TVDss. For Z-19’s P&A, tubing was cut at 4000', USIT log ran, lower completion was cemented from TD to above production packer of cut tubing. A 7-5/8" CIBP was set at 3275' MD and cement laid from the plug to 2475' MD effectively isolating the Ivishak and the Kuparuk reservoirs from the sidetrack. Z-19A:The 7” intermediate casing was run and landed at 10643’ MD. The casing was cemented in three stages. During Stage One a lead slurry of 121.7 bbls of 12.3 ppg LiteCrete cement and a tail slurry of 156.8 bbls of 15.8 ppg Premium G cement with Gasblok were pumped at TD. In Stage Two the ES cementer was opened at 8557’, and a lead slurry of 168.3 bbls of 10.8 ppg LiteCrete cement with Gasblok and a tail slurry of 155.5 bbls of 15.8 ppg Premium G cement with Gasblok were pumped. When the second stage cement reached 300 psi compressive strength a final third stage was mixed and pumped down the annulus from the surface. A total of 132.6 bbls of 11.6 ppg of LiteCrete with Gasblock were pumped. A USIT log was run and located TOC at 2400’ MD/-2139 TVDss, top of Kuparuk interval at 10366’MD/-6458 TVDss. Z-114:The 7” intermediate casing was run and landed at 10235’ MD. The casing was cemented with 177.5 bbls 11.5ppg Litecrete followed by 38bbl of 15.8ppg class G tail cement and displacement saw 99% returns. After cementing casing, a USIT log located cement top at 4000' MD/-3823 TVDss top of Kuparuk interval at 9856’MD/-6411 TVDss. Z-115:The 7” production casing was landed at 11369' MD and cemented with 145.1 bbl 12ppg Litecrete and 41.1 bbl of 15.8ppg Gasblok cement, no losses noted. TOC calculated at 6589’ MD / -4090 TVDss using estimated 30% washout. Top of Kuparuk interval is 10932’ MD / -6484 TVDss. Casing was pressure tested 250psi low 5min and 3500psi high 30 min, passed. There has been no CBL log across the production casing in this well. Z-116PB1, Z-116BP2, Z-116: After cementing the 9-5/8” intermediate liner, an 8-3/4” hole was drilled to 12960’ MD. The 7” production casing was landed at 12945’ MD and cemented with 180 bbls of 11ppg Litecrete cement followed by 21 bbl 15.8ppg Class G tail cement. A USIT log dated 2011-12-22 was run from 12250 to surface and located TOC in the 7” casing at 6340' MD / -3370 TVDss. Top of Kuparuk 10,750’ Z-61 Fracture Stimulation PTD: 212-113 Page 17 interval is 12498’ MD / -6661 TVDss. After the 7” casing was set, two sidetracks were made through a window in the 7” casing at 12502’MD and the second sidetrack became the final well injection section where a 4-1/2” liner was set and cemented. K071112PB1, K071112: Exploration well drilled in 1970, abandoned in 1980. After drilling the initial 9- 7/8” hole to 9300’MD, tools fell down hole and there were issues attempting to recover, so they decided to set a cement plug and sidetrack. They ultimately set 7 cement plugs between 8955’MD and 6743’MD in PB1 before being able to sidetrack. They began drilling new 9-7/8” hole at 6756’ MD to 9320’ MD. 7” casing was run to 9304’ with a DV tool at 7004’ and casing tie back hanger at 1971’. 676 sacks of class G cement were pumped around the shoe, and when the DV tool was opened at 7004’, it returned 10 sacks of cement through the DV tool. Then cement was pumped through the DV tool with 1169 sacks of class G cement. It was reported that 10bbls of cement cut mud was returned at the tie back sub at 1971’ but volumetric calculation with 30% washout estimates TOC at 3448’MD. Lastly, they squeezed the top of 7” casing hanger with 125 sacks cement, followed by 200 sacks of cement and tested the squeeze. Top of Kuparuk interval is at 6798’MD. There were 5 perforation intervals all plugged or squeezed: the 3 deepest perf intervals each have a bridge plug set above them (3 BPs) and the two shallower intervals were squeezed with 100 and 150 sacks of cement respectively. A bridge plug was set at 2527’ then 3-1/2” tubing was run to 2503’. In April 1980, the well was successfully plugged and abandoned to surface. Z-61 Fracture StimulationPTD: 212-113Page 18WellNameCasing type Casing SizeCasing SetDepthHoleSizeVol cmtTOC est.viaTOC TOCTop of payIntervalZonalIsolation?Latest MITin MD feet in Cu Ft MD feet TVDss feet TVDss feetZ-61 Intermediate 7 14144 8.75 1742 USIT Log 10750 -6139 -6495 YES MIT-IA: 3/2023 to 3530 psi, MIT-T 5/2023 to 4001 psiZ-61PB1 Intermediate 7 14144 8.75 1742 USIT Log 10750 -6139 -6495 YES MIT-IA: 3/2023 to 3530 psi, MIT-T 5/2023 to 4001 psiZ-115 Production 7 11369 8.75 1027 Volumetric 6589 -4090 -6484 YES MIT-IA: 7/22/2012 to 4000 psiZ-19 Intermediate 7.625 13802 9.875 2954 USIT Log 2385 -2110 -6649 YES 1/11/2006 Pre-P&A CMIT failed, MIT-OA to 2000psi passed.Z-19A Intermediate 7 12643 9.875 4123 USIT Log 2400 -2139 -6458 YES MIT-IA: 4-10/2023 to 3896 psiZ-114 Production 7 10235 8.75 1207 USIT Log 4000 -3823 -6411 YES MIT-IA: 10/2021 to 2910 psiZ-116 Production 7 12945 8.75 1128 USIT Log 6340 -3370 -6661 YES MIT-IA: 2/2022 to 3237 psiZ-116PB1 Production 7 12945 8.75 1128 USIT Log 6340 -3370 -6661 YES MIT-IA: 2/2022 to 3237 psiZ-116PB2 Production 7 12945 8.75 1128 USIT Log 6340 -3370 -6661 YES MIT-IA: 2/2022 to 3237 psiK071112Production 7 9304 9.875 2381 Volumetric2nd stg: 3448'1st stg: 7004'2nd stg: -33751st stg: -6839-6641 YES P&A'd in 1980K071112PB1Production 7 7004 9.875 2381 Volumetric2nd stg: 3448'1st stg: 7004'2nd stg: -33751st stg: -6839-6643 YES P&A'd in 1980 Z-61 Fracture Stimulation PTD: 212-113 Page 19 SECTION 11: LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFING ZONES 20 AAC 25.283, A, 11 Hilcorp’s technical analysis based on seismic, well and other subsurface information available indicates that there are 4 mapped faults that transect the Kuparuk interval and enter the confining zone within the ½ radius of the production and confining zone trajectory for the planned Z-61. Fracture gradients within the confining zone (Kalubik and HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. The HRZ and Kalubik in this area are predominately shale with some silts with an estimated fracture pressure of ~13.5ppg. Faults 1-4 intersect the production interval and confining zone within the ½ mile radius of the planned fracs. Their displacements, sense of throw, and zone in which they terminate upwards are given below. The wellbore trajectory is essentially a vertical/slant penetration. Maximum stress direction is estimated to be ~30 deg W of N. The frac stage should have sufficient offset to and should not intersect faults #1, #2 #3 and #4. The frac is 720’ from fault #1, 1680’ from fault #2, 1300’ from fault #3, 2500’ from fault #4 and maximum anticipated fracture half length of 300’ is well short of this distance. Half length is modeled using hydraulic fracture modelling software and is corroborated by what we have seen in other frac treatments. If a sudden drop in treating pressure or increase in pump rate is seen during the stimulation that cannot be explaining by fluids pumped or annular pressure monitoring, pumping operation will stop until a plan forward and explanation can be put forth. Fault Throw Direction Top Bottom 1 100-250' DTW Sagavanirktok Basement 2 0-40' DTW Colville Miluveach 3 0-50' DTN Colville Lisburne 4 40-80' DTW Colville Basement Z-61 Fracture StimulationPTD: 212-113Page 20SECTION 12: PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283, a, 12Fracture Stimulation Pump SchedulePlease see Frac program included with this sundry applicationATTACHMENT 1: PUMP SCHEDULEMIT-T4000Pressure Test6000Max WHT Pressure5000Slurry Rate25Proppant DensityWell NameZ-61AFEMIT-IA3500Pump Trips4700Ann Pressure3500Fluid Type28# X-LinkProppant UsedSTEP STAGE AVERAGE COMMENTS FLUID PUMPCF DIRTY VOLUME DIRTY VOLUME PROPPANT## PPA TYPERATERATESTAGE CUM STAGE CUM STAGE CUM SIZE GROSS CUM(BPM)(BPM)(BBL) (BBL) (GAL) (GAL) (LBS) (LBS) (BBL) (BBL)028# X-Link0.0000 0000.00Step-Rate-TestN/A 2525.0000 001Prime up, pressure testFreezeProt 55.01010420 420 10 102Displace ball to seat~KCl 55.0100420 0103Injection test~KCl 2525.075853,150 3,570 75 85Shut down and monitor pressure0.0850 3,570 0 854Calibration Test28# X-Link 2525.008503,570 0 855Flush~KCl 2525.00850 3,570 0 85 HARD SHUTDOWN, MONITOR PRESSURE TILL CLOSURE.FLUID PUMPCF DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUMESTEP STAGE AVERAGE COMMENTS TYPE RATERATESTAGE CUM TOT JOB STAGE CUM STAGE CUM SIZE GROSS CUM## PPA (BPM)(BPM)(BBL) (BBL) (BBL) (GAL) (GAL) (LBS) (LBS) (BBL) (BBL)Volume to Top Perf 17261PAD28# X-Link 2525.0200285 3708,400 11,970 0 0 200 285721FLAT28# X-Link 2523.925310 3951,050 13,020 1,006 1,00616/20 C-Lite24 309832FLAT28# X-Link 2523.025335 4201,050 14,070 1,929 2,93516/20 C-Lite23 331943FLAT28# X-Link 2522.125360 4451,050 15,120 2,781 5,71616/20 C-Lite23 3541054FLAT28# X-Link 2521.225385 4701,050 16,170 3,568 9,28416/20 C-Lite22 3761165FLAT28# X-Link 2520.525410 4951,050 17,220 4,299 13,58316/20 C-Lite21 3961276FLAT28# X-Link 2519.825435 5201,050 18,270 4,978 18,56116/20 C-Lite20 4171387FLAT28# X-Link 2519.1150585 6706,300 24,570 33,671 52,23316/20 C-Lite116 5331498FLAT28# X-Link 2518.5150735 8206,300 30,870 37,224 89,45716/20 C-Lite113 64615109FLAT28# X-Link 2517.9150885 9706,300 37,170 40,552 130,00916/20 C-Lite109 755161110FLAT28# X-Link 2517.31501,035 1,1206,300 43,470 43,676 173,68516/20 CBL106 860171211FLAT28# X-Link 2516.81501,185 1,2706,300 49,770 46,613 220,29816/20 CBL102 9631813FlushFLUSH~KCl 2525.01341,319 1,4045,626 55,396 0 220,298 134 1,0971914 FLUSHFreezeProt 2525.0381,357 1,4421,598 56,994 0 220,298 38 1,135CLEAN VOLUME Z-61 Fracture Stimulation PTD: 212-113 Page 21 Table 5 – Anticipated Pressures MIT-T 4000 psi MIT-IA 3530 psi Maximum Anticipated Treating Pressure:2900 psi @ 25 BPM IA Pop-off Set Pressure (~95% of MIT-IA):3350 psi IA Minimum Hold Pressure (POP-off – 300 psi):3000 psi Maximum Allowable Treating Pressure (MATP = Ann hold + MIT-T):4500 psi (tree limited to 5000psi) Stagger Pump Kickouts Between 90 – 95% of MATP:4050 - 4300 Global Kickout (95% of MATP):4300 psi N2 POP-off set pressure (MATP + 1000 psi):5500 psi Treating Line Test Pressure (MATP + 1000 psi):5500 psi OA Pressure:Monitor Max Anticipated Proppant Loading:11 PPA There are three overpressure devices that protect the surface equipment and wellbore from overpressure. 1) Each individual frac pump has an electronic kickout that will shift the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are staggered between 90% and 95% of the maximum allowable treating pressure. 2) A primary pressure transducer in the treating line will trigger a global kickout that will shift all the pumps into neutral. 3) There is a manual kickout that is controlled from the frac van that can shift all pumps into neutral. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. Based on a regional stress map, the maximum horizontal stress in the Kuparuk sands is determined to run ~30° W of N). The slant section of the well though the Kuparuk is drilled parallel to the maximum horizontal stress meaning the induced fracture will also be directionally parallel to the wellbore. 2900 Z-61 Fracture Stimulation PTD: 212-113 Page 22 Frac Dimensions: Frac #MD Location, ft TVDss top, ft TVDss Bottom, ft Frac Half-Length, ft 1 11,360 -6501 -6562 ~300’ Disclaimer Notice: This model was generated using commercially available modelling software and is based on engineering estimates of reservoir properties. Hilcorp is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. Z-61 Fracture Stimulation PTD: 212-113 Page 23 Frac Modelling: Maximum Anticipated Treating Pressure: ~2900 psi Surface pressure is calculated based on a closure pressure of ~0.66 psi/ ft or ~4363 psi. Closure pressure plus anticipated net pressure to be built (550 psi) and friction pressure minus hydrostatic results in a surface pressure of ~2900 psi at the time of flush. Note, modeled pressures were calibrated using historical frac pressure data from nearby, analog well Z-115 that saw a max treating pressure of 3415, but had a higher estimated net pressure of 1101psi. If Z-61 frac generates a similar net pressure, max treating pressure could reach ~3460psi, which still does not require a tree saver. 4360 psi (closure)+ 550 psi (net)+ 970 psi (friction)- 2970 psi (hydrostatic)= 2910 psi (max surface press) The difference in closure pressures of the confining shale layers determines height of the fracture. Average confining layer stress is anticipated to be ~0.7 psi/ ft limiting fracture height to ~109 ft TVD. Fracture half-length is determined from confining layer stress as well as leak-off and formation modulus. The modeled frac is anticipated to reach a half-length of ~300 ft. Z-61 Fracture Stimulation PTD: 212-113 Page 24 Z-61 Fracture Stimulation PTD: 212-113 Page 25 Pre-Job Anticipated Chemicals to be pumped: 47,658 gal Z-61 Fracture Stimulation PTD: 212-113 Page 26 SECTION 13: POST FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283, A, 13 After the fracture stimulation and potentially during the post frac coil fill cleanout, the well will be put on production through portable well testers. All liquids will be captured and either sent to production facilities or diverted to flowback tanks if solid% becomes too high for our facilities to manage. The initial flowback period is intended to produce back the fracture fluids to tanks as quickly as possible, until the well is produced less than 10% water cut and less than 0.5% solids, at which time the produced fluids meet the GC2 acceptance criteria for start-up. There will be a tank farm on pad to store the produced fluids from flowback operations. The flowback fluids not suitable for GC2 processing will be hauled to another facilities slop tanks for additional settling time and or disposal. Hilcorp will work to separate and recover fluid that meets the facility specification for the flowback fluids. A fluid manifest form will be completed for each load trucked offsite. Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: May 12, 2023Subject: Changes to Approved Sundry Procedure for Well Z-61Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU Z-61 (PTD No. 212-113; Sundry No. 323-290) Paragraph Sub-Paragraph Section Complete? AOGCC Page 1 May 26, 2023 (a) Application for Sundry Approval (a)(1) Affidavit Provided with application. SFD 5/26/2023 (a)(2) Plat Provided with application. SFD 5/26/2023 (a)(2)(A) Well location Surface location lies in Section 19 of T11N, R12E, UM. Wellbore passes through Section 18 of T11N, R12E; the single-stage frac interval lies in Section 7, T11N, R12E; the deeper, isolated portion of the well continues through Section 6, T11N, R12E to the well TD within Section 1, T11N, R11E, UM. SFD 5/26/2023 (a)(2)(B) Each water well within ½ mile None: According to the Water Estate map available through DNR’s Alaska Mapper application (accessed online May 26 2023), there are no wells are used for drinking water purposes are known to lie within ½ mile of the surface location of PBU Z-61. There are no subsurface water rights or temporary subsurface water rights within 4-¾ miles of the surface location of PBU Z-61. SFD 5/26/2023 (a)(2)(C) Identify all well types within ½ mile List of all wells within ½-mile radius of the PBU Z-61 well path is provided with application. SFD 5/26/2023 (a)(3) Freshwater aquifers: geological name; measured and true vertical depth None. No freshwater aquifers are present within the Prudhoe Bay Unit per Aquifer Exemption Order No. 1. An outline of the EPA’s current Aquifer Exemption Area for the Prudhoe Bay Unit is available on the EPA’s “Alaska Oil & Gas Aquifer Exemptions Interactive Map” available online under the “Permits” section of EPA Region 10’s web page at https://www.epa.gov/uic/underground-injection-control-region-10-ak-id-or-and-wa. SFD 5/26/2023 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU Z-61 (PTD No. 212-113; Sundry No. 323-290) Paragraph Sub-Paragraph Section Complete? AOGCC Page 2 May 26, 2023 (a)(4) Baseline water sampling plan None required: No freshwater aquifers are present. SFD 5/26/2023 (a)(5) Casing and cementing information Provided with application. Proposed schematic attached, as built no generated to date. MGR 5-30-23 (a)(6) Casing and cementing operation assessment 7” casing went as planned. CBL shows very good bond in area of the intended perf/frac interval. No issues with cement for the upcoming stimulation. 7”casing was pressure tested to 4001 psi . MGR 5/30/23 (a)(6)(A) Casing cemented below lowermost freshwater aquifer and conforms to 20 AAC 25.030 No freshwater aquifers present. (See Section (a)(3), above.) SFD 5/26/2023 (a)(6)( B) Each hydrocarbon zone is isolated Yes: Surface casing was set at 2,109’ MD (-X1,934’ TVDSS) and cemented to surface following six additional top-down remedial cementing operations. For PBU Z-61, 8-3/4” hole was drilled from the base of surface casing to a total depth of 14,114’ MD (-8,670’ TVDSS) and surface casing was set at 14,109’ MD (-8,666’ TVDSS). Top of good-quality cement interpreted from the CBL is about 10,780’ MD (-6,159’ TVDSS). So, cement isolates ethe Kuparuk from the underlying Sag River/Shublik/Ivishak and from the overlying Schrader Bluff. SFD 5/26/2023 (a)(7) Pressure test: information and pressure-test plans for casing and tubing installed in well Provided with application. 3530 psi MITIA completed, 4000 psi MITT completed. CDW 5/26/2023 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU Z-61 (PTD No. 212-113; Sundry No. 323-290) Paragraph Sub-Paragraph Section Complete? AOGCC Page 3 May 26, 2023 (a)(8) Pressure ratings and schematics: wellbore, wellhead, BOPE, treating head Provided with application. 5K psi wellhead max. frac. Pressure 2900-4500 psi. Pump knock out 4050-4300 and GORV 5500 psi. lines test 5500 psi. CDW 5/26/2023 (a)(9)(A) Fracturing and confining zones: lithologic description for each zone (a)(9)(B) Geological name of each zone (a)(9)(C) and (a)(9)(D) Measured and true vertical depths (a)(9)(E) Fracture pressure for each zone Upper confining zones: HRZ and Kalubik interval consisting of condensed mudstone, claystone and silty claystone that has an aggregate thickness of about 212’ true vertical thickness (TVT). Fracture gradient is expected to range from about 0.70 psi/ft (13.5 ppg EMW). Fracturing Zone: Perforated interval from 11,310’ to 11,413’ MD (-6,497’ to –6,563’ TVDSS) lies the Kuparuk C that has an aggregate thickness of about 70’ true vertical thickness (TVT). Fracture gradient expected to range from about 0.62 psi/ft (11.9 ppg EMW). Lower confining zones: Mudstone and siltstone within the Kuparuk B and A intervals that are 155’ thick underlain by Miluveach Shale which is 750’ thick in this area. Fracture gradient expected to range from about 0.64 to 0.70 psi/ft (12.3 to 13.5 ppg EMW). SFD 5/26/2023 (a)(10) Location, orientation, report on mechanical condition of each well 11 wells identified and evaluated including Z-61 and plugged Z-61PBI and others. Cement tops mostly verified with USIT but 2 wells have volumetric cement calculations (but do have 2 stage cement jobs) CDW 5/26/2023 (a)(11) Sufficient information to determine wells will not interfere with containment within ½ mile Yes. There are seven wells and four plugged-back wellbores within ½ mile of PBU Z-61. Cement-isolation is demonstrated by USIT logs for five wells and three plugged-back wellbores. Volumetric cement calculations support cement-isolation for the remaining two wells and one plugged-back wellbore. SFD 5/26/2023 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU Z-61 (PTD No. 212-113; Sundry No. 323-290) Paragraph Sub-Paragraph Section Complete? AOGCC Page 4 May 26, 2023 (a)(11) Faults and fractures, Location, orientation (a)(11) Faults and fractures, Sufficient information to determine no interference with containment within ½ mile None. The operator has identified four faults using seismic and well data within a ½-mile radius of PBU Z-61. The nearest fault trends north and lies 720’ directly west of the fracturing perforations. The maximum stress direction in this area trends N30°W in this area and the modeled fracture half-length is 300’, so it is unlikely that any faults will interfere with containment of the injected fracturing fluids; however, if there are indications that a fracture has intersected a fault or natural-fracture interval during frac operations, the operator will go to flush and terminate the stage immediately. SFD 5/26/2023 (a)(12) Proposed program for fracturing operation Provided with application. CDW 5/26/2023 (a)(12)(A) Estimated volume Provided with application. 1442 bbl total dirty vol. 220K lb total proppant CDW 5/26/2023 (a)(12)(B) Additives: names, purposes, concentrations Provided with application. CDW 5/26/2023 (a)(12)(C) Chemical name and CAS number of each Provided with application. Schlumberger disclosure provided. CDW 5/26/2023 (a)(12)(D) Inert substances , weight or volume of each Provided with application. CDW 5/26/2023 (a)(12)(E) Maximum treating pressure with supporting info to determine appropriateness for program Simulation shows max surface pressure 2910 psi. Max. 4500 psi allowable treating pressure. Max pressure is 4050 psi to 4300 psi to Pump shutdown. With 3000 psi minimum back pressure IA (IA popoff set 3350 psi), max tubing differential should only be 1300 psi. CDW 5/26/2023 (a)(12)(F) Fractures – height, length, MD and TVD to top, description of fracturing model Provided with application. The anticipated half-length of the induced fracture is 300’ according to the Operator’s computer simulation. Computer simulation indicates the anticipated height of the induced fractures will be 60’ (top SFD 5/26/2023 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU Z-61 (PTD No. 212-113; Sundry No. 323-290) Paragraph Sub-Paragraph Section Complete? AOGCC Page 5 May 26, 2023 of about -6,501’ and base of about 6,562’ TVDSS), so induced fractures will likely penetrate into, but not through, the overlying confining interval that is about 212’ thick in this area. (a)(13) Proposed program for post-fracturing well cleanup and fluid recovery Well cleanout and flowback procedure provided with application. No disposal identified CDW 5/26/2023 (b)Testing of casing or intermediate casing Tested >110% of max anticipated pressure 3000 psi back pressure, tested to 3530 psi, popoff set as 3350 psi CDW 5/26/2023 (c) Fracturing string (c)(1) Packer >100’ below TOC of production or intermediate casing 4.5” tubing anchored with packers set at approx.. 11128, 13830, and 13948 ft with perforations of 11310-11413 ft and sliding sleeves from 14378 to 17657 ft. 9-5/8” intermediate surface casing tied back to 13-3/8” surface casing which had significant cementing difficulties and remedial cement pumping jobs were required before cement was achieved to surface. 7” casing cement had losses but passed pressure testing. TOC in 7” casing at 10780 ft logged by USIT. USIT/CBL conservatively shows good cement at area of interest so no cement concerns. MGR 5-30-23 (c)(2) Tested >110% of max anticipated pressure differential Tubing tested to 4001 psi. Max pressure differential is estimated as 1300 psi (4300 with 3000 psi backpressure) so test of 4001 psi satisfies 110% CDW 5/26/2023 (d) Pressure relief valve Line pressure <= test pressure, remotely controlled shut-in device 5500 psi line pressure test, pump knock out staggered 4050-4300 psi with max. global kickout 5500 psi. IA PRV set as 3350 psi. CDW 5/26/2023 (e) Confinement Frac fluids confined to approved formations Provided with application. CDW 5/26/2023 (f) Surface casing pressures Monitored with gauge and pressure relief device IA PRV set at 3350 psi. Surface annulus open. Frac pressures continuously monitored. CDW 5/26/2023 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU Z-61 (PTD No. 212-113; Sundry No. 323-290) Paragraph Sub-Paragraph Section Complete? AOGCC Page 6 May 26, 2023 (g) Annulus pressure monitoring & notification 500 psi criteria During hydraulic fracturing operations, all annulus pressures must be continuously monitored and recorded. If at any time during hydraulic fracturing operations the annulus pressure increases more than 500 psig above those anticipated increases caused by pressure or thermal transfer, the operator shall: CDW 5/26/2023 (g)(1) Notify AOGCC within 24 hours (g)(2) Corrective action or surveillance (g)(3) Sundry to AOGCC (h) Sundry Report (i) Reporting (i)(1) FracFocus Reporting (i)(2) AOGCC Reporting: printed & electronic (j) Post-frac water sampling plan Not required (see Section (a)(3), above), (k) Confidential information Clearly marked and specific facts supporting nondisclosure (l) Variances requested Modifications of deadlines, requests for variances or waivers 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU Z-61 (PTD No. 212-113; Sundry No. 323-290) Paragraph Sub-Paragraph Section Complete? AOGCC Page 7 May 26, 2023 No plan for post fracture water well analysis. Commission may require this depending on performance of the fracturing operation. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT Z-61 JBR 04/17/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Tested with 4 1/2" test joint, tested all gas alarms and PVT's, Annular was functioned and passed retest, Manual choke was tested and failed, Choke was replaced and I did not witness the retest. Precharge bottles = 11 each at 1000psi each. Test Results TEST DATA Rig Rep:A. Hansen / J. HenryOperator:Hilcorp North Slope, LLC Operator Rep:D. Scarpella / A. Bass Rig Owner/Rig No.:Nordic 3 PTD#:2121130 DATE:3/14/2023 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopBDB230315032326 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7.5 MASP: 2591 Sundry No: 323-001 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 13 PNo. Valves 1 FManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"FP #1 Rams 1 2 7/8x5 1/2 P #2 Rams 1 Blind P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 1 3 1/8"P Check Valve 0 NA BOP Misc 1 3"NA System Pressure P2975 Pressure After Closure P1750 200 PSI Attained P24 Full Pressure Attained P125 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P4@2000 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P18 #1 Rams P4 #2 Rams P4 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 99 9999 99 9 FFP Annular was functioned and passed retest,Manual choke was tested and failed, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Claire Mayfield Subject:20230228 1640 PTD212-113 PBUZ-61 - Approved to waive AOGCC witnessed tag of CIBP Date:Tuesday, February 28, 2023 4:46:52 PM Claire, Hilcorp is approved to waive the AOGCC witnessed Eline tag of the CIBP (@~14,358’ MD) and 25’ of cement. The witnessed passing CMIT-TxIA to 2500 psi is sufficient. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Tuesday, February 28, 2023 11:36 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Z-61 Pre-Rig Witness Step Hi Mel, We recently had AOGCC witness the CMIT on Z-61’s CIBP set pre-rig (CMIT passed and witnessed by AOGCC on 2/19/2023). However, the CMIT was witnessed prior to the cement being bailed on top of the plug. Does the AOGCC need to witness the “tag” portion of the work as well? Thanks, Claire Mayfield Hilcorp Energy Company Prudhoe Bay West – Operations Engineer Office: (907) 564-4375 Cell: (713) 443-3631 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 4, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-61 PRUDHOE BAY UNIT Z-61 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/04/2023 Z-61 50-029-23474-00-00 212-113-0 N SPT 8533 2121130 2500 270 2650 2615 2604 23 24 26 26 OTHER P Kam StJohn 2/18/2023 MIT TxIA to 2500 psi per sundry 323-001 for tubing cut pre rig. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT Z-61 Inspection Date: Tubing OA Packer Depth 377 2741 2705 2691IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230219090401 BBL Pumped:5.4 BBL Returned:6 Tuesday, April 4, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 2LOSURGXFHUUHVHUYRLULVRODWLRQSOXJIRUWEJZRUNRYHU MIT TxIA to 2500 psi per sundry 323-001 James B. Regg Digitally signed by James B. Regg Date: 2023.04.04 14:45:19 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU Z-61 Install new tubing Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-113 50-029-23474-00-00 17891 Conductor Surface Intermediate Production Liner 9008 80 2068 2949 14072 3941 14330 20" 13-3/8" 9-5/8" 7" 4-1/2" 8919 41 - 121 41 - 2109 1957 - 4906 37 - 14109 13948 - 17889 41 - 121 41 - 2031 1894 - 3506 37 - 8763 8630 - 9008 None 470 2260 3090 5410 7500 14330, 14358 1490 5020 5750 7240 8430 11310 - 17835 4-1/2" 12.6# 13Cr80 35 - 11232, 13803 -13953 6593 - 9003 Structural 4-1/2" HES TNT Packer 11128, 6475 11128, 13830 6475, 8532 Stan Golis Sr. Area Operations Manager Claire Mayfield Claire.Mayfield@hilcorp.com 907-564-4375 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0047450, 0028262, 0028240 35 - 6542, 8511 - 8634 Tubing from 14330 to 14358 MD Dump bail 15-gallons of 17-ppg Neo Super Slurry Cement 24 Well Not Online 555 1659 650 313 700 323-001 13b. Pools active after work:Borealis Oil 4-1/2" HES TNT Perm 13830, 8532 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Kayla Junke at 10:48 am, Apr 07, 2023 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.04.07 06:04:23 -08'00' Stan Golis (880) DSR-4/13/23 RBDMS JSB 041123 WCB 11-29-2023 ACTIVITY DATE SUMMARY 1/4/2023 T/I/A=SHUT IN/1650/20 Check psi. on, ICPO, 750 psi., bled off quickly, test ICPO 500/5 min., no psi loss, test to 3500 psi,/30 min., lost 100 psi first 15 min., lost 0 psi. second 15 min, bled off test psi. Check psi on tbg hgr void, 1450 psi, bled off quickly, function all ULDS1 at a time to out msmt. 4-3/4", re-torqued to 500 ft/lbs, all functioned like new, test tbg hgr void 500 psi/5 min., no psi. loss, test to 5,000 psi/30 min., lost 150 psi first 15 min., lost 0 psi second 15 min., bled off test psi. SBMS had no psi., 1/29/2023 ***WELL S/I ON ARRIVAL*** RUN 2-3/8" DOGLESS GS TO EQUALIZE EVO-TRIEVE, UNABLE TO EQUALIZE LAY DOWN TO REPACK STUFFING BOX *** CONTINUE ON 1/30/2023 *** 1/30/2023 *** CONTINUE FROM 1/29/2023 *** REPACK STUFFING BOX RUN VARIOUS PUMP BAILERS DOWN TO EVO-TRIEVE S/D @ 13,902' SLM, WORK BAILERS W/NO SOLID RETURNS RUN KJ, 3.70''CENT, 3'x1-7/8'', 3.73''CENT, XO, 2-3/8'' DOGGLESS GR, TRY AND EQUALIZE EVO-TRIEVE @ VARIOUS PRESSURES ADD 5' x 2-1/8" stem & 3' x 2-1/8" ROLLER (2.60" WHEELS) RUN KJ, 3.70''CENT, 3'x1-7/8'', 3.73''CENT, XO, 2-3/8'' DOGGLE SS GR, PRESSURE TUBING UP TO 2600 psi, JAR DOWN TO EQUALIZE EVO-TRIEVE, SEE PRESSURE DROP TO 500 psi AFTER JARRING FOR 30 MIN *** CONTINUE ON 1/30/2023 *** 1/31/2023 TFS Unit 3 Weather Standby 1/31/2023 *** CONTINUE FROM 1/30/2023 *** WINDS SPEEDS INCREASED TO 35+ MPH, ABORT RUN TO PULL EVO-TRIEVE. ON WEATHER HOLD *** CONTINUE ON 2/1/2023 *** 2/1/2023 TFS Unit 3 Weather Standby 2/1/2023 T/I/0= 300/800/0 Assist Slickline (Load TBG). Pumped 169 bbls crude down TBG to assist SL with brush n flush and TBG load. Job continues next day 2/1/2023 *** CONTINUE FROM 1/31/2023 *** ON WEATHER HOLD PULL 4-1/2" EVO-TRIEVE FROM 13,905' SLM / 13,895' MD, HANG UP IN ALL JEWLERY COMING OUT PIECE OF ELEMENT & 4 SLIPS BROKEN, MISSING PIECE FROM EACH. DRIFT WITH 4-1/2" BRUSH, 3.75" G-RING TO 14,620' SLM (14,610' MD) WHILE LOADING WELL WITH 220 BBLS CRUDE TO PUSH DEBRIS BELOW CIBP SET DEPTH *** CONTINUE ON 2/2/2023 *** 2/2/2023 *** CONTINUE FROM 2/1/2023 *** DRIFT W/ 2.83" CENT, 23.5' x 2.78" DUMMY GUNS FREELY TO TO 14,620' SLM / 14,610' MD RAN HALIBURTON 40 ARM CALIPER FROM DEVIATION @ 14,620' SLM TO SURFACE. (GOOD DATA) ***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE PAD-OP NOTIFIED*** Daily Report of Well Operations PBU Z-61 RAN HALIBURTON 40 ARM CALIPER FROM DEVIATION @ 14,620' SLM TO SURFACE. (GOOD DATA) DRIFT W/ 2.83" CENT, 23.5' x 2.78" DUMMY GUNS FREELY TO TO 14,620' SLM / Y 14,610' MD PULL 4-1/2" EVO-TRIEVE FROM 13,905' SLM / 13,895' MD Daily Report of Well Operations PBU Z-61 2/2/2023 Job continues from previous day. Assist Slickline (Load TBG). Pumped 59 bbls crude down TBG to assist Sickline. Hang tag. SL on well upon departure 2/18/2023 ***WELL S/I ON ARRIVAL*** PRESSURE TEST PCE 200#LP-3000#HP RIH W/ 1-7/16 CHD (1" FN), 1-11/16" GR/CCL, 2" BRT, 1-11/16 SWITCH HOUSING, BKR #10, CIBP (19' OAL) CCL OFFSET=16.7', CIBP ME SET DEPTH=14,358', CCL STOP DEPTH=14,341.3' JOB CONTINUED ON 2/19/2023 ***WELL LEFT S/I*** 2/18/2023 Pre E-Line Load TBG and IA (RWO CAPITAL) IWHP T/I/O = 512/750/39. Pumped 1 bbls 60/40, 310 bbls 1% KCL, 3 bbls 60/40, and 47 bbls 130* DSL down IA. Pumped 415 bbls 1% KCL and 38 bbls 90* DSL down TBG. E-Line set CIBP. ***CMIT TxIA PASSED*** (2750 max, 2500 target. Pumped 8.7 bbls diesel down TxIA to reach test pressure. Loss of 4/6 TxIA 1st 15 min. Loss of 2/3 TxIA 2nd 15 min. FWP=290/300/25 2/19/2023 ***WELL S/I ON ARRIVAL*** JOB CONTINUED FROM 2/18/2023 STATE WITNESS CMIT - TXIA BY KAM STJOHN, AOGCC. PASSED. SEE MIT DATA TAB FOR PRESSURE DETAIL ELINE PU 3" BAILER WITH CEMENT PRESSURE TEST PCE 200#LP-3,000#HP RIH W/ 1-7/16" CHD (1" FN), 2-1/8" CCL, 3" DUMP BAILER (LOADED W/ 7.5 GAL OF 17 PPG CEMENT, 28' OAL) BAILER BOTTOM PLUNGER FOUND OPEN, CEMENT PREMATURELY DUMPED AT ~9160 FT. POOH AND RDMO ELINE ***WELL LEFT S/I*** 2/19/2023 AOGCC MIT-TxIA (RWO CAPITAL) AOGCC CMIT-TxIA to 2650 psi ***PASS*** Max Applied = 2750 psi Target = 2500 psi Pumped 5.4 bbls DSL down IA to take Tbg/IA to 2650/2741 psi. Tbg/IA lost 35/36 psi in 1st 15 mins and 11/14 in 2nd psi for a total loss of 46/50 psi in 30 min test. Bled Tbg/IA to 200 psi and got back ~6 bbls. ELine in control of well per LRS departue. IA,OA=OTG *Witnessed by State Rep SaintJohn and WSS Sonnefeld **Tags hung on MV and IA 2/24/2023 ***WELL S/I ON ARRIVAL***(pre-rwo) DRIFTED/BRUSHED TBG W/ 4-1/2" BRUSH & 3.76" GAUGE RING, TOOLS S/D @ 14,367' SLM. DRIFTED TBG W/ 22' x 2-7/8" PJO DUMMY GUNS W/ 3.16" RINGS TO 14,367' SLM. ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** ***DRIFTED W/ 20' x 3.70" DUMMY WHIPSTOCK TO 3,000' SLM FOR SUBSIDENCE SURVEILLANCE*** CIBP shown correctly on new WBS, below. -WCB This post-CIBP set passing combo was required in Sundry 323-001. -WCB ***CMIT TxIA PASSED*** (2750 max, 2500 target. Pumped 8.7 bbls diesel down(g TxIA to reach test pressure. Loss of 4/6 TxIA 1st 15 min. Loss of 2/3 TxIA 2nd 15 min. FWP=290/300/25 STATE WITNESS CMIT - TXIA BY KAM STJOHN, AOGCC. PASSED RIH W/ 1-7/16" CHD (1" FN), 2-1/8" CCL, 3" DUMP BAILER (LOADED W/ 7.5 GAL () OF 17 PPG CEMENT, 28' OAL)) BAILER BOTTOM PLUNGER FOUND OPEN, CEMENT PREMATURELY DUMPED AT ~9160 FT. POOH AND RDMO ELINE ) CIBP ME SET DEPTH=14,358 Daily Report of Well Operations PBU Z-61 2/27/2023 ***WELL S/I ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP RIH W/ 1-7/16" CHD (1" FN), 2.60" ROLLER, 2" WEIGHT, 1-11/16" WEIGHT, 2.60" ROLLER, 2-1/8" CCL, 3" BAILER (41' OAL) TS SAT DOWN @ 4,350' RIH W/ 1-7/16" CHD (1" FN), 2.60" ROLLER, 2" WEIGHT, 1-11/16" WEIGHT, 2.60" ROLLER, 2-1/8" CCL, 2-1/2" BAILER (49' OAL) DRIFTED TO PLUG @ 14,357.6' W/ 30' X 2-1/2" BAILER ***WELL LEFT S/I*** JOB CONTINUED 2/28/2023 2/28/2023 JOB CONTINUED FROM 2/27/2023 PRESSURE TEST PCE TO 200#LP-3,000#HP RIH W/ 1-7/16" CHD (1" FN), 2.60" ROLLER, 2" WEIGHT, 1-11/16" WEIGHT, 2.60" ROLLER, 2-1/2" BAILER (FILLED W/ 5 GAL 17 PPG CEMENT, 49' OAL) ESTIMATED TOC @ 14,350.2' ***WELL LEFT S/I*** JOB CONTINUED ON 3/01/2023 3/1/2023 ***CONTINUED FROM 2-28-2023 WSR*** PRESSURE TEST PCE 250LP-3000HP(good) DUMP 10 GALLONS OF 17 PPG NEO SUPER SLURRY CEMENT ON CIBP AT 14358' MD. TOTAL CEMENT=15 GALLONS. ESTIMATED TOC=14333'. ***JOB COMPLETE*** 3/2/2023 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(ru eline) SPOT IN EQUIPMENT. LAY DOWN LUBE FOR NIGHT. ...CONT ON 3-MAR-2023... 3/3/2023 ...CONT FROM 2-MAR-2023... TAG TOC AT 14330' ELMD. ...CONT ON 4-MAR-2023... 3/4/2023 ...CONT FROM 3-MAR-2023...(hes conveyed welltec cutter) CUT TUBING AT 13804'. CCL TO CUTTER OFFSET: 18.3'. CCL STOP DEPTH: 13785.7'. TIE INTO TUBING TALLY REOCRD DATED 16-FEB-2013. 3/5/2023 ...CONT FROM 4-MAR-2023 WSR...(rdmo eline) RIG DOWN ELINE. ***JOB COMPLETE, TURNED OVER TO DSO*** 3/10/2023 T/I/O=SI/700/0. Set VR plug. RD 2 1/6" IA valve. RU 2 1/6" FMC 120 Tag #208. Torque to API specs. PT against VR plug 300psi low & 3500 psi High (PASSED). Pulled VR plug. Installed tapped blind flange. PT against valve gate 2500 psi (PASSED). ***JOB COMPLETE***. RDMO. Final WHP's SI/700/0. 3/10/2023 T/I/O = 500/666/29. ***Circ Out*** Pumped 8.7 bbls 60/40, 157bbls 1%KCl w/ 4drums of Deep Clean, 465 bbls seawater, 33 bbls 100* diesel down tubing, up IA, to tanks. U-tube freeze protect to 1000'. Pumped 2.5 bbls 60/40 to FP choke trailer and all hard lines. Tags hung. Pad op notified upon departure. FWHP's = 90/89/63. 3/11/2023 T/I/O=0/0/0 Set 4" H BPV #706 LTT {PASSED}. ***JOB COMPLETE*** RDMO Final WHP's=BPV/0/0. (g ) DUMP 10 GALLONS OF 17 PPG NEO SUPER SLURRY CEMENT ON CIBP AT 14358' MD. TOTAL CEMENT=15 GALLONS. ESTIMATED TOC=14333'. So more than 25' cement atop CIBP. -WCB CUT TUBING AT 13804'. TAG TOC AT 14330' ELMD Daily Report of Well Operations PBU Z-61 3/12/2023 T/I/O = BPV/0/40. Temp = SI. Bleed WHPs to 0 psi (pre-rig). No AL. No well house or scaffolding, Dry Hole Tree Installed. Bled OAP to BT from 40 psi to 0 psi in 15 mins (All Gas). Held open bleed for 30 mins. Monitored for 30 mins. Final WHPs = BPV/0/0. SV, MV = C. IA, OA = OTG. 11:00 3/12/2023 Nordic 3 RWO Job Scope: Recomplete from Ivishak to Kuparuk Move off well and travel from W-04 to edge of Z Pad in 7 hours. Set rig mats and hang new tree in cellar. Move over well. ***Cont on WSR 3/13/23*** 3/13/2023 Pull 4" HBPV, set 4" CTSHBPV. Bleed off THA void. N/D tree (SBMS stayed in THA). clean void, inspect TBG HGR neck and lift threads. Install CTS plug. Test to 4M for 5 min. Passed. Install new BX160. S/B for BOP N/U and test. 3/13/2023 Nordic 3 Job Scope: Recomplete from Ivishak to Kuparuk Remove cuttings chute due to interference w/ adjacent wellhouse. Spot rig over well. Pull 4" H type BPV Set CTS. ND dry hole tree. Vault Rep checked pulling thread (good). NU BOPE. Install bell nipple. RU to test and shell test BOPE 250/3200 psi. Call out AOGCC. Test BOP's in progress. Witnessed by Brian Bixby. Re-install cuttings chute during test. Take on 600 bbls 1% KCl. ***Cont on WSR 3/14/23*** 3/14/2023 Pull CTS plug, Pull 4" CTSHBPV. S/B for circulate. M/U landing joint. BOLDS, Pull TBG HGR to rig floor. Lay down TBG HGR made up to landing joint to pipe shed. S/B for recompletion 3/14/2023 Nordic 3 Job Scope: Recomplete from Ivishak to Schrader Test BOPE to 250/3000 psi per Sundry. Witnessed by Brian Bixby. Two Fail/Passes (Annular functioned and manual choke replaced).Hanger pulled free @ 190K and to the floor @ 150K. Start pulling 4-1/2 13Cr completion. ***Cont. on WSR 3/15/23*** 3/15/2023 ***ASSIST NORDIC 3*** (rwo capital) RAN 5.99" JUNK BASKET TO 4 1/2" TBG STUB @ 13803' SLM (Empty). ***CONTINUED ON 3/16/23 WSR*** 3/15/2023 Nordic 3 Job Scope: Recomplete from Ivishak to Kuparuk Completed pulling completion. Rigged up slickline and ran 5.99" OD Junk Basket to Tbg stub @ 13803' SLM. ***Cont on WSR 3/16/23*** 3/16/2023 ***CONTINUED FROM 3/15/23 WSR*** SET 5.90" SCOOP GUIDE AT 13804' MD. ***JOB COMPLETE*** 3/16/2023 Nordic 3 Job Scope: Recomplete from Ivishak to Kuparuk Slickline tag Tbg stub @ 13,804'. Shear pins and set scoop guide @ 13,808 SLM. RD Slickline. Rerun 4-1/2" 13-Cr Vam Top 12.6# completion, GBR torque turned to spec. Ran 122 jts and torque turn proximity switch stopped counting turns during make-up. Replaced proximity switch. Ran 16 joints and same issue reoccured. Call out replacement tongs. 5.75 hrs NPT. RU replacment tongs in progress. ***Cont on WSR 3/17/23*** 3/17/2023 TFS unit 4 Assist Nordic 3 RIG with 10 BBL DSL FP, ***Job continued on 03/18/2023*** BOLDS, Pull g TBG HGR to rig floor. Lay down TBG HGR )g Start pulling 4-1/2 13Cr completion. Completed pulling completion Nordic 3 RWO Job Scope: Recomplete from Ivishak to Kuparuk gg @ Rerun 4-1/2" 13-Cr Vam Top 12.6# completion Daily Report of Well Operations PBU Z-61 3/17/2023 Nordic 3 Job Scope: Recomplete from Ivishak to Kuparuk. Set up replacement tongs. Continue running completion @ Jt #138 of 262. Land completion 148K PUW, 90K SOW. RD GBR Casing. Prep for rig move. Rig up to pump Packer Fluids. Reverse in 150 bbls of 1% KCl with 1% EPT-3744 corrosion inhibitor displaced w/ 62 bbls 1% KCKL. Corr inhib. spotted from 3317' to below packer. Drop Ball & Rod and set Packer per HES @ 3500 psi. MIT-T & IA per the sundry, MIT -T by pressuring up tubing to 4550psi. Inconclusive. Lost 140 psi in 30 mins. No increase in casing pressure. Bled Tbg pressure to 2000psi. MIT - IA 3530 psi (Pass) lost 45 psi in 1st 15 mins and 20 psi in 2nd 15 mins. Witness waived - Kam StJohn. Bleed Tbg pressure to shear out DCK valve in GLM. Freeze protect well with 10 bbls of diesel and u-tube. Well freeze protected to 300'. Set TWC. Empty pits. ND BOPE. NU and test tree to 5000 psi. End Job @ 02:00 am. ***Job Complete*** 3/17/2023 Land tubing hanger at 25.82', verify mark through IA valve, torque gland nuts & LDS to 450 ft lbs. LDS in = 3-3/4". After freeze protect & u-tube set TWC with dry rod 6 LH turns. 3/18/2023 ***Job continued from 03/17/2023*** TFS unit 4 assist Nordic rig Pressure test Tree to 5000 psi. 3/18/2023 Assist with NU Tree & adapter, Test tree at 5000 psi good test. Test adapter at 5000 psi for 15 min, good test 3/19/2023 ***WELL S/I ON ARRIVAL*** (rwo capital) PULLED BALL & ROD f/ RHC PLUG BODY @ 11149' MD PULLED BK-DGLVS AT ST# 5 (11,028" md), ST# 4 (10,454' md), ST# 3 (9,426' md) & ST# 2 (7,691' md) ***CONTINUE ON 3/20/23 WSR*** 3/19/2023 T/I/O=0/0/0 Freeze protect TxIA (Post RWO) Pumped 90 bbls 50*F Diesel down IA while taking TBG returns to tanks. U-Tube TxIA for 1.5 hours. Final T/I/O= 32/31/4 3/20/2023 ***CONTINUED FROM 3/19/23 WSR*** (RWO) PULLED BEK-SOV @ STA# 1 (4,019' md) SET BK-LGLV'S @ ST# 1 (4,019' md), ST# 2 (7,691' md), ST# 3 (9426' md) & ST# 4 (10454' md) SET BK-OGLV @ ST# 5 (11028' md) PULLED 3.81" RHC PLUG BODY @ 11159' MD DRIFT TBG TO 11500' SLM w/ 33' x 3.16" DMY GUNS (no issues) ***JOB COMPLETE, WELL LEFT, SI, DSO NOTIFIED*** 3/21/2023 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(perforate) PERFORATE 11371'-11413' USING 2.875" HSC LOADED W/ MAXFORCE CHARGES. CORRELATED TO SLB VISION LOG DATED 02-JAN-2013. ...JOB CONT ON 22-MAR-2023... 3/22/2023 ...CONT FROM 21-MAR-2023...(adperf) PERFORATE 11310'-11371' USING 2.875", 6 SPF, 60 DEG PHASED HSC, LOADED W/ 17.5 GR MAXFORCE CHARGES. CORRELATED TO SLB VISION LOG DATED 2-JAN-2013. ***JOB COMPLETED*** 3/26/2023 LRS Well Test Unit 1. SLBU. Begin WSR 3/26/23. IL well Z-61, OL well Z-61KF. MIRU, PT. Cont WSR on 3/27/23 Continue running completion @ Jt #138 of 262 PERFORATE 11371'-11413' MIT-T & IA per the sundry, MIT -T by pressuring up tubing to 4550psi. Inconclusive. Lost 140 psi in 30yygg mins. No increase in casing pressure. Bled Tbg pressure to 2000psi. The adperfs are correctly shown on the new WBS, below. -WCB Drop Ball & Rod and set Packer per HES @ 3500 psi@ MIT - IA 3530 psi (Pass) Land tubing hanger at 25.82', PERFORATE 11310'-11371' () PULLED BALL & ROD f/ RHC PLUG BODY @ 11149' MD Daily Report of Well Operations PBU Z-61 3/27/2023 T/I/O = 290/1370/0. Temp = SI. T & IA FL (LRS test unit request). ALP = 1370 psi, open @ CV. T FL @ surface. IA FL @ 7691' (3337' above sta # 5, SO). Schematic has not been updated. LRS test unit in control of well upon departure. SV = O. WV = C. SSV, MV = O. IA, OA = OTG. 12:00 3/27/2023 LRS Well Test Unit 1. SLBU. Cont WSR from 3/26/23. IL well Z-61, OL well Z-61KF. POP well, Shut in Stack out, Repop. Cont WSR on 3/28/23 3/28/2023 ***WELL S/I ON ARRIVAL*** (RWO Capital) POLLARD #60 RIG UP ***CONTINUE ON 3/29/23 WSR*** 3/28/2023 LRS Well Test Unit 1. SLBU. Cont WSR from 3/27/23. IL well Z-61, OL well Z-61KF. Shut in stack out, Re POP, perfom HOT, Re POP, flowback, BD, De-inventrory, RD. Cont WSR on 3/29/23 3/28/2023 Assist Well Testers with Hot Oil Treatment (RWO CAPITAL) Pumped 2 bbls 60/40 meth down FL for FP. Pumped 3 bbls 60/40 meth spear and 172 bbls 190* Crude down TBG. FWHP=2173/1705/3 Left well in Well Testers Control. 3/28/2023 T/I/O = 300/600/0. Temp = SI. IA FL (LRS test unit request). ALP = online. IA FL @ 4019' (sta # 1, Dome). LRS test unit in control of well upon departure. SV = O. WV = C. SSV, MV = O. IA, OA = OTG. 13:50 3/29/2023 LRS Well Test Unit 1. SLBU. Cont WSR from 3/28/23. IL well Z-61, OL well Z-61KF. RU, PT, POP, Flowback,TIFL. Cont WSR on 3/30/23 3/29/2023 T/I/O = 290/570/0. Temp = SI. T & IA FL (LRS testers request). ALP = 600 psi, open @ CV. T FL @ near surface. IA FL @ 11028' (sta # 5, SO). LRS test unit in control of well upon departure, SV = O. WV = C. SSV, MV = O. IA, OA = OTG. 18:00 3/29/2023 T/I/O = 1710/1620/VAC. Temp = SI. Cold TIFL **PASS** (SLB req). ALP = 1750 psi, SI @ CV. IA FL @ 11028' (sta #5 SO, 193 bbls). Bled IAP to production to 690 psi in 2 hrs. Monitor for 1 hr. WHPs & IA FL unchanged. Well returned to SLB. Final WHPs = 1710/690/VAC. WV, SSV = C. SV, MV = O. IA, OA = OTG. 07:00. 3/29/2023 T/I/O=1730/1730/0 Assist S-Line (RWO) Freeze protect FL w/ 3 bbls 60/40 SL on well at time of departure. 3/29/2023 ***CONTINUED FROM 3/28/23 WSR*** (RWO Capital) RAN 1.43" LIB TO ST# 1 AT 4019' MD (impression of BK latch) DHD PERFORMED PASSING TIFL ON IA ****WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS**** 3/29/2023 T/I/O = 550/860/0+. Temp = SI. TIFL **PASS**(SLB req.). ALP = 1250 psi, online. Testers RU on well. Tbg FL inconclusive, unable to isolate from 3" hardline @ wellhead. IA FL @ 11028' (sta #5 SO, 193 bbls). Ops backflowed on well to stack out WHPs to 1640/1190/0+ in 5 min. Bled IAP to production from 1190 psi to 620 psi in 1 hr. IA FL unchanged. Monitored for 1 hr. WHPs & IA FL unchanged. Well returned to Testers. Final WHPs = 1640/620/0+. SV, WV = C. SSV, MV = O. IA, OA = OTG. 03:00. Daily Report of Well Operations PBU Z-61 3/30/2023 T/I/O = 1030/1020/0. Temp = SI. Cold TIFL **PASS**(SLB req). ALP = 1800 psi, SI @ CV. T FL @ 7934' (243' below sta #4 DOME). IA FL @ 11028' (sta #5 SO, 193 bbls). Ops backflowed on well to stack out WHPs to 1560/1320/0 in 5 min. Bled IAP to Z-115 production from 1320 psi to 460 psi in 1 hr 30 min. During bleed Tbg psi decreased 60 psi. IA FL unchanged. Monitored for 1 hr. Tbg psi decreased 10 psi. IAP and IA FL unchanged. Well returned to SLB. Final WHPs = 1490/460/0. WV = C. SV, SSV, MV = O. IA, OA = OTG. 22:30. **Job continued from 3-30-23 WSR** 3/30/2023 LRS Well Test Unit 1. SLBU. Cont WSR from 3/29/23. IL well Z-61, OL well Z-61 KF. RU, PT, POP, Flowback,TIFL. Cont WSR on 3/31/23 3/30/2023 Travel to location, SB for SL 3/30/2023 ***WELL S/I ON ARRIVAL*** DRIFT w/ 3.74" CENT, 2" SAMPLE BAILER TO 11,500' SLM (no issues) SET 4-1/2" X-CATCHER IN X-NIPPLE @ 11,104' MD PULLED BK-LGLV FROM ST#4 @ 7,691' MD & ST#5 @ 4,109' MD SET BK-LGVL IN ST#5 @ 4,109' MD & ST#4 @ 7,691' MD DHD PERFOMED PASSING TIFL PULL 4 1/2" X-CATCHER @ 11,104' MD ***CONTINUE 3/31/23*** 3/31/2023 T/I/O=1460/359/6 HPBD Pumped a 10 bbls 60/40 spear followed by 170 bbls dsl to load tbg, preform step rate injectivity test @ 1,2,3,4 bpm and a 50 bbl HPBD @ 5 bpm Total 270 bbls dsl. ( see log for details) final WHP's 1442/1244/0 turn well over to testers 3/31/2023 LRS Well Test Unit 1. SLBU. Continued from 3/30/23 WSR. IL Z-61, OLl Z-61 KF. 3/31/2023 ***CONTINUE FROM 3/30/23*** RIG DOWN POLLARD #59, TRAVEL TO L-112 ***END TICKET*** 4/1/2023 T/I/O = 600/620/0. Temp = SI. T & IA FL (Ops request). AL SI @ CV. IA FL @ 11028' (sta #5 SO, 193 bbls). T FL @ 8240'. SV, WV, SSV = C. MV = O. IA & OA = OTG. 16:00 4/1/2023 T/I/O= 500/600/0 Freeze Protect for the Well testers Pumped 4 BBLS 60/40 down FL to FP. FWHP=500/600/0 4/1/2023 LRS Well Test Unit 1. SLBU. Continued from 3/31/23 WSR. IL Z-61, OL Z-61 KF. 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 planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER Install new tubing Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-113 50-029-23474-00-00 ADL 0047450 , 0028262 , 0028240 17891 Conductor Surface Intermediate Production Liner 9008 80 2068 2949 14072 3941 13895 20" 13-3/8" 9-5/8" 7" 4-1/2" 8587 41 - 121 41 - 2109 1957 - 4906 37 - 14109 13948 - 17889 2591 41 - 121 41 - 2031 1894 - 3506 37 - 8763 8630 - 9008 none 470 2260 3090 5410 7500 13895 1490 5020 5750 7240 8430 14349 - 17835 4-1/2" 12.6# 13Cr80 35 - 139538929 - 9003 Structural 4-1/2" HES TNT Perm No SSSV 13830 / 8532 Date: Stan Golis Operations Manager Josh Stephens Josh.Stephens@hilcorp.com 970.779.1200 PRUDHOE BAY 2/15/2023 Current Pools: PRUDHOE OIL Proposed Pools: BOREALIS OIL 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 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov PBU Z-61 By Anne Prysunka at 8:20 am, Jan 05, 2023 323-001 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.01.04 17:29:26 -09'00' Stan Golis (880) SFD 1/5/2023 Perforate New Pool BOREALIS OIL CO 471. CO 471.011 SFD DSR-1/6/23 10-404 BOPE test to 3000 psi. Annular to 2500 psi. MGR01FEB23 Eline tag and pressure test (to 2500 psi) of Ivishak reservoir abandonment plug at ~14,330' MD. 2591 GCW 02/07/23 JLC 2/7/2023 2/7/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.07 15:07:53 -09'00' RBDMS JSB 020823 Recomplete to Kuparuk Well: PBU Z-61 PTD: 212-113 Well Name:PBU Z-61 API Number:50-029-23474-00 Current Status:Not Operable Producer Estimated Start Date:2/17/2022 Rig:Nordic 3 Sundry #Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:212-113 First Call Engineer:Josh Stephens (907)777-8420 (970) 779-1200 (M) Second Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Current Bottom Hole Pressure (Estimate):3642 psi @ 8800’ TVD .414 psi/ft (Z-27 SBHPS 5/2013) Kill Weight Fluid:8.0ppg 8.42 PPG with 2500’ freeze protect Max. Anticipated Surface Pressure:2591psi (Based on 0.1 psi/ft gas gradient) Last SI WHP:1700psi (8/1/2022) Min ID:3.813” at 2017’ MD Max Angle:98 degrees at 14,875’ MD Hole Angle >70 Degrees 14,562’ MD Max DLS 16.1 degrees/110’ at 14,183 Formation Tops Kuparuk: 11,310’ MD / 6,594’ TVD Sag: 14,105’ MD / 8,759’ TVD Ivishak: 14,346’ MD / 8,759’ TVD MITs: CMIT-TxIA: 2443 psi on 8/22/2019 Brief Well Summary: The Ivishak reservoir no longer remains economically viable and the Kuparuk interval for Z-61 motherbore is in a perfect location to test Kuparuk production. A RWO is planned to recomplete to Kuparuk to test production rates and water cuts at the Kuparuk interval. The Ivishak will be isolated but not permanently abandoned in the event future EWE debottlenecking projects make it economically viable to produce. Notes Regarding Wellbore Condition x Drilled in 2013 and completed with 13cr tbg x USIT log of the 7” production casing shows TOC at ~10,780’. x Some history of OA repressurization, but appears to be from and external source x Well has a history of shallow paraffin to ~800’ x Last drift attempt on 8/21 could not get past X-Nipple at 13,801’ MD with 3.80” swage, but able to drift with 3.70” dummy whipstock. x Well was secured with an evo trieve for LTSI on 8/22/19 and passed a CMIT-TxIA to 2,443psi. A TBG caliper will be ran to assess the condition of the 4.5” completion. If the TBG is in good condition it will be re-used for the Kuparuk recomplete. s TOC at ~10,780’. 8.42 PPG o recomplete to Kuparuk to test production Ivishak will be isolated but not permanently abandoned Recomplete to Kuparuk Well: PBU Z-61 PTD: 212-113 Objective: Isolate the Ivishak formation, pull the 4-1/2” tubing and recomplete to Kuparuk Pre-Rig 1. Obtain updated pressure tests on WH seals Slickline 1. Drift TBG to Evo plug at 13,865’ 2. Equalize and pull 4.5” EvoTrieve plug 3. Drift to deviation a. CIBP must be set @ 14,328’ or deeper b. 16 deg DLS @ 14,183’ c. 70 deg @ 14,562’ 4. Run multi finger caliper from deviation to surface. a. Send data to OE to assess TBG condition for reuse. Sundry Procedure (Approval Required to Proceed) Fullbore 1. Assist EL with L&K and CMIT Eline 1. L&K TBG and IA with 1% KCL, Freeze protect with diesel a. TBG volume to top sleeve 218bbls, TBG volume to 2,500’ 38bbls b. IA volume to GLM #1 255bbls, IA volume to 2,500’ 47bbls 2. Set CIBP @ ~14358’ (middle of 20’ pup above XXD #9) 3. Perform an AOGCC witnessed CMIT-TxIA to 2,500psi a. 24 Hour notification must be made to the AOGCC before testing 4. Dump bail 25’ of cement on CIBP if CMIT passes Eline 1. Cut tubing @ 13,804’ a. 2’ below collar in 14’ pup joint b. Utilize Welltech cutter so scoop guide can be placed over cut Pre-RWO*Note: Depending on timing of rig move, well kill and BOP installation steps may be performed on rig rather than pre-rig. 1. Spot Pump Truck, RU and PT. a. Circulate in at least 150 bbls of 160 degree 1% KCl with 4 drums of DeepClean followed by 450bbls of 1% KCL b. Circulate down the TBG and out the IA to prevent circulation short cutting through LGLVs c. Annular Volume to cut: 260 bbls Fluid density > 8.42 ppg. t CIBP @ ~14358’ Recomplete to Kuparuk Well: PBU Z-61 PTD: 212-113 d. Tubing Volume to cut: 210 bbls e. Rock in surface freeze protect if on rig or full freeze protect if pre rig 2. RDMO pumpers 3. RD well house and flowlines. Clear and level area around well. 4. Set BPV w/insert (TWC) and test. ND Tree and THA. 5. NU BOPE configured top down: Annular, 2-7/8”x5” VBRs, Blinds and integral flow cross. RWO Procedure: 1. MIRU Nordic 3 workover rig and ancillary equipment 2. Bleed TBG/IA pressures to ~0psi. Kill well w/1% KCl as needed. 3. Test BOPE to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “Nordic 3 Test Procedure” c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram and Annular on 4-1/2”and on 4”test joint. i. The VBR’s must be tested with largest and smallest diameter pipe to be ran. The annular must be tested with smallest size to be ran. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull TWC insert and BPV. a. Utilize lubricator for BPV removal if potential for trapped pressure exists. 5. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. ~13,804’ of 4-1/2” 12.6# tubing weighs ~ 152.3klbs (buoyed by 8.4 ppg fluid) b. If pulled up to 230 Klbs (80% of 4-1/2” yield strength) with no hanger movement, RU eline and consult OE about second TBG cut depths. 6. POOH and lay down the 4-1/2” tubing. a. Save tubing, tubing will most likely be reused pending caliper results 7. RU Slickline 8. RIH with Northern Solutions 4.5”x7” scoop guide and set over tubing stub. 9. PU 4-1/2” completion and run per Z-61 Proposed Completion Running Order. a. Load IA with inhibited KWF brine b. Land tubing with mule shoe/WLEG @ ~11,190’ c. Production Packer must be set within 200 above perf interval d. Ensure RHC plug body pre-installed in lowermost X profile 10. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. 11. Drop ball and rod and hydraulically set the packer per manufacturer’s setting procedure a. Conduct MIT-T to 4500 psi and MIT-IA to 3,500 psi for 30 mins (charted, state witnessed) 12. Shear circ valve in shallow GLM and circ freeze protect. 13. Bleed tubing pressure back to ~0 psi. Set BPV with TWC insert. 14. RDMO ASR WO Rig and ancillary equipment. Move to next well location. Recomplete to Kuparuk Well: PBU Z-61 PTD: 212-113 15. RU crane. ND BOPE. Post-Rig Procedure: Well Support 1. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 2. Pull BPV with TWC insert. 3. Replace wellhouse and gauge(s) if removed. Slickline 1. Spot Slickline unit, RU and PT. 2. RIH and pull RHC plug from X profile at ±11045’ MD 3. Install LGLV design per GLE 4. RDMO and turn well over to operations. Eline 5. Perforate per geologist a. Charges will be 2-7/8” MaxForce or similar b. 6 SPF c. 60 deg Phasing Testers - Slow Bean up Procedure 1. POP the well to ASRC with 1-1.5 MMSCFD Lift gas at minimum choke, adjust GL rate as necessary to eliminate slugging. Flow the initial returns to the flowline as long as the shake-outs meet the returned fluid/solids management guidelines. 2. Limit flow to 500 bpd 3. If solids are < 1%, after 1.5 wellbore volumes (270 bbls) increase the production rate to 750 BLPD. 4. Flow bottoms up and sample for solids production. If solids are still below 1%, increase flow to 1000 BFPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1% continue to increase the flow rate in 250 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1%; allow well clean up before choke is opened further. 6. Once at FOC, stabilize the well for 4 hrs. Obtain an 8 hr welltest. Operations 6. Obtain AOGCC witnessed SVS test within 5 days of putting well online. (Kuparuk C interval: ~ 11,310' - 11,413' MD) SFD 1/5/2023 Recomplete to Kuparuk Well: PBU Z-61 PTD: 212-113 Current WBD: Recomplete to Kuparuk Well: PBU Z-61 PTD: 212-113 Proposed WBD: Recomplete to Kuparuk Well: PBU Z-61 PTD: 212-113 Nordic Rig 3 BOP Schematic: Recomplete to Kuparuk Well: PBU Z-61 PTD: 212-113 USIT log of 7” Production Casing: Recomplete to Kuparuk Well: PBU Z-61 PTD: 212-113 Recomplete to Kuparuk Well: PBU Z-61 PTD: 212-113 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 Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 1110 i Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday, August 14, 2016 7:33 AM To: AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad Z; Peru, Cale; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity; Grey, Leighton;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: OPERABLE: Producer Z-61 (PTD#2121130)Well Barriers Confirmed All, Producer Z-61 (PTD#2121130)was Under Evaluation due to sustained outer annulus(OA)casing pressure over MOASP, reported on 07/18/16.Subsequent work has confirmed two competent well barrier envelopes,as evidenced by a passing CMIT-TxIA and a passing MIT-T.The OA repressurization,which occurs most frequently when the well is first brought online,appears to be from an external source via the open surface casing shoe; it does not appear to be artificial lift or formation gas.The well is reclassified as Operable. Work Completed: 1. Collect IA and OA gas samples—Completed 07/20/16;samples are dissimilar 2. Slickline:Set tubing tail plug—Completed 07/29/16 3. Fullbore:CMIT-TxIA—Completed 07/29/16; PASSED to 2500 psi 4. Slickline:Troubleshoot gas lift valves—Completed 08/03/16 5. Fullbore: MIT-T—Completed 08/03/16; PASSED to 2500 psi 6. Operations: Put on Production—Done 08/05/16 7. Downhole Diagnostics:Warm OA re-pressurization test—Completed 08/11/16; OA build-up rate=0 psi/day Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) SCANNED JAN i 82017, 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWellIntegritvCoordinator@BP.com From: AK, G 'e UPT Well Integrity Sent: Thursday, Ju - 2016 7:32 PM To: AK, OPS GC2 Field O: L; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, GWO - Slickline; AK, GWO SUPT Special Projects; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Ca -; 'K, OPS Well Pad Z; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO • •'- Well Integrity; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (jim.reqg@alaska.gov)'; AK, GWO SUPT Well -•rity Subject: UNDER EVALUATION: Producer Z-61 (PTD #212 I Sustained Casing Pressure Outer Annulus Over MOASP All, 1 • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday,July 21, 2016 7:32 PM To: AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK,GWO SUPT Slickline;AK, GWO SUPT Special Projects;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Optt Engr; Peru, Cale;AK, OPS Well Pad Z;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA);AK, GWO SUPT Well Integrity Subject: UNDER EVALUATION: Producer Z-61 (PTD#2121130) Sustained Casing Pressure Outer Annulus Over MOASP All, Producer Z-61(PTD#2121130)was reported to have sustained casing pressure on the outer annulus over MOASP on July 18th, 2016.The OA pressure was 1100 psi with gas returns and subsequently bled down to 240 psi.The well is now reclassified as Under Evaluation and on a 28 day clock to verify well barriers. Plan Forward: 1. Slickline:Set tubing tail plug 2. Fullbore: CMIT-TxIA 3. Downhole Diagnostics:Warm OA re-pressurization test 4. Well Integrity: Further diagnostics as needed Please call with any questions or concerns. SCANNED NOV 1 8 2016 Ryan Holt (A(t?t71me 1,k ( te,,) BP Alaska-Well Integrity GVV Global Wells Organization Office: 907.659.5102 1 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM( N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 212-113 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory El AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23474-00-00 7. Property Designation(Lease Number): ADL 0047450 - 8. Well Name and Number: PBU Z-61 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 17891 feet Plugs measured feet true vertical 9008 feet Junk measured feet MAR 2 3 2016 Effective Depth: measured 17876 feet Packer measured 13830 feet true vertical 9007 feet Packer true vertical 8532.88 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 41 -121 41 -121 1490 470 Surface 2068 13-3/8"68#L-80 41 -2109 41 -2031 5020 2260 Intermediate Production 14072 7"26#L-80 37-14109 37-8763 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet N True vertical depth: See Attachment feet %��"S) Z11 11i Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 35-13953 35-8634 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 17 0 0 1012 222 Subsequent to operation: 252 0 1122 1673 288 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature i(, Phone +1 907 564 4424 Date 3/23/16 Form 10-404 Revised 5/2015 V-rL 4/r rL RBDMS v v MAR 2 5 2016 Submit Original Only • • 0 0 0 0 0 0 a N V O IC) 10 N in M I- U N o 00000 i O) N LC) CO CO 7 V O N r` CO r 10 N- IC) CO CO x- CO CO CO N CO CO O O CO N LO O M N CO CO 0) CO • 1 1 1 1 1 1 H L I- 0) CO LC) • V CO CO CO M v- O C a) O O E Oco LC) N N 00 O • N f` CO r r 14 � r C°r I` LO lf) a)N VVMOma) CM ▪ m H a o O O coo = JCO J M M i r r 00 J N 10 O *k CO CO V) ,- ' M N (Ni V rn © N 1.0 NN CON N t N _ Cb En CO d- c 00 O O O O O J N N CO Z 01 0 0 '7• 000 O• Cu a a X Z z W O w w m ODZZD U (/) 0 J J f- • • CD U) p. 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(A M M M M (T M M M M M 00 M N N N N N N N N N N N 4 a W V UJ W Z J W W L- W O CO N N N CO A- N N 0 N m ? W J J J a' < < a Cn LL E u d cc E ca z � co co co co co co co co co c I M M MO- 0- 0- 0 -100W0_ WNN NNNNNNNNNNNN < < m m LL u m m a Cr • 0 Packers and SSV's Attachment PBU Z-61 SW Name Type MD TVD Depscription Z-61 PACKER 1956 1893.85 10-3/4"x 13-3/8"ZXP Lnr Top Packer Z-61 TBG PACKER 13830 8532.88 4-1/2" HES TNT Perm Packer Z-61 PACKER 14308 8905.69 4-1/2" Swell Packer Z-61 PACKER 14469 8984.6 4-1/2" Swell Packer Z-61 PACKER 15057 9015.77 4-1/2" Swell Packer Z-61 PACKER 15443 8970.11 4-1/2" Swell Packer Z-61 PACKER 16011 8963.57 4-1/2" Swell Packer Z-61 PACKER 16357 8957.09 4-1/2" Swell Packer Z-61 PACKER 16901 8960.93 4-1/2" Swell Packer Z-61 PACKER 17487 8981.08 4-1/2" Swell Packer Z-61 PACKER 17835 9003.24 4-1/2" Swell Packer . 0 • £ g & \ E0 \ / a) = k / E = c 2 g o C ao_ o ƒ 7/ U -0 § 7 U % / C � ° �: } I g 0_ { / /t Q) a) • \ 5 0 c) / k a) a) < = b 2 0 % 2 $ m I .E r m / ƒ > m ca c C / \ .E c ^ m E c 9 % � o % _% 2© � 7 7 Ea oke 7 o ?0 ° © I / ° 2 2 .000 ' ± U \ o 0 &2I t 0I - f C / / : f1E ƒ ® © # ƒ ± o » - @ E § 9 - = n ca ƒ ƒ & = m o ¢ § 0 D E e 2Ti S = _ _ C) . m a 0 ± e § / \ o o 4 / 2 � O / \ / 7 / kk / / 0f o / _ _ > » e o 2 o > CD ®< - _ 9 i I 0 n \ = I 6 \ I I 2 as as 0 0 E 2 \ \ 0 CD % M _ _ % O = O = o � H H e > � y R I - . + t 0 > > CD -o / > < c & > J 0 / _0 / a CD / / 1-) 00co_ cv O � �� 0 2 0 \ / \ ƒ 0 / 0 \ q 0 0 i I % 2 c- CD- H 0 / 0H / 0 0 m / 2 ...____c / ( a) co2 _ R ± t \ 2 / $ $ U 3 o c m U [ / © m k 2 2 a G / @ G R 4- _. a 2 0 ® 0 U \ / % . / / / R \ f t \ 1.1 k ƒ c \ f / E § I / E $ _ / \ S t \ _c c .§ e / Rem �.g e o 0 ' I q 0) C .R .c _J o k = # c roc = # ® t " o k o 0 = O G / @ / H , o - k/ / u) � / \ / / / R / � Y � U t U $ U m@ g t U $ \ .g E & U t e ! 2 ƒ 2 L / e co CO (C) \ d \ d / 2 / o 5 \ / CO / InA © 0 t & A 4 WEL F AD 4-1/16"FMC • Z-61 CHROMEG 8 LNR**ANGLE>70°@ 14562'"•• ACTUATOR= LEO INITIAL KB.ELEV= 96.7' I N 11AL.BF.ELEV= 55.9' I mi--1 509' H 13-3/8"TAM PORT COLLAR,D=12.420" KOP= 475' 2017' -{4-1/2"HES X NP,D=3.813" Max Angle= 98°@ 14848' , ' Datum MD= 14293' Datum 7V D= 8800.SS 1957' -13-3/8"X 10-3/4"ZXPN LIP& 20"X 30"INSULATE CONDUCTOR, 80' ll FLEX LOCK HGR ,D=9.45" 91.5#,A-53,D=19.124" 1990' H 10-3/4'X 9-5/8"LNR X0,D=8.835" 13-3/8"CSG,68#,L-80 BTC,0=12.415" -I 2109' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 95/8"CSG,40#,L-80 BTC,D=8.835" H 4906' (---411 dh, 8 4329 3246 65 KBG2 DONE BK 16 07/17/13 7 7547 4690 63 KBG2 DMY BK 0 02/16/13 6 8907 5307 64 KBG2 DONE BK 16 07/17/13 TOP OF CEMENT(LOGGED BY RIG) H 10760' 5 10352 6003 55 KBG2 DMY BK 0 02/16/13 4 4 11258 6559 49 KBG2 DM' BK 0 02/16/13 3 12081 7106 42 KBG2 DOME BK 16 07/17/13 ii. ri iti 2 12694 7601 33 KBG2 DMY BK 0 07/17/13 Minimum ID =3.813" @ 2017' ; 1 13766 8480 34 KBG2 SO BK 20 11/02/14 4-1/2" HES X NIPPLEb. 13801' -I4-1/2"HES X160,D=3.813" ' 13830' _47'X 4-1/2"HES TNT PKR,D=3.856' 13865' -14-1/2"FES X NP,D=3.813" 07 v. ot ii 13941' H4-1/2"FES X NP,D=3.813" 07 W 13948' --{7'X 5"BKR FRD-E ZXPN LTP,D=4.32° 4-1/2"TBG,12.6#,13CR-80 VAM TOP, 13952' I ,p 13953' -14-1/2" LEG,D=4.00 .0152 bpf,0-3.958" ��1 Igthd --I ELM)TT NOT LOGGED 7'CSG,26#,L-80 VAM TOP FIC -{ 14109' 0383 bpf.ID=6.276 *1 13972' -1 7'X 5"BKR FLEX-LOCK HGR,D=5.25" HES SWELL PACKERS 13981' -5'X 4-1/2"XO BUSHING,D=3.91' NO SIZE TOP DEPTH IAN D nu. 8 4-1/2" 14308 3.958" 1..:411 Ern 3033 SLIDING SLV,ID=3.813" 7 4-1/2" 14469 3.958" NO DEPTH CVC DATE 6 4-12" 15057 3.958" _ 9 14378 0 08/30/15 c.5 4-12" 15443 3.958" ��- 8 14680 C 04/14/13 4 4-12" 16011 3.958" :._.:. 7 15269 0 08/30/15 3 4-12" 16357 3.958" isi nem 6 15612 0 0128/14 2 4-12" 16901 3.958' 5 15876 0 01/28/14 so no se 1 4-12" 17487 _ 3.958' _ _ 4 16222 C 04/14/13 _ 3 16726 0 0128/14 Elm= P9WORATION SUMMARY _ 2 17152 0 04/14/13 REF LOG:SLB VISION SVC OH on 02/15/13 1.'n1 �I 1 17657 0 01/28/14 --- 0=OPH4 C=CLOSED ANGLE AT TOP PERE:74°@ 14595' .-._.-_. Note:Refer to Production DB for historical perf data _ --- SIZE SFS INTERVAL Opn/Sgz SHOT SOZ III=II 2" 6 14595-14600 0 02/23/16 '7.... ' 2" 6 16152-16157 0 0223116 •In• 17797' H4-1/2"BKR ST IF'T TOOL VERFICATION SUB,D=3.86' 17820' H4-1/2"BKR ISOLATION VALVE,D=1.00" PBTD -{ 17820' 4-12"LNR,12.6#,13CR-80 HYD 521, -{ 17819'_" 17823' 4-1/2"X 3-12"XO,0=2.992" .0152 bpf,ID=3.958" _4 :4 17835' H3-1/2"HES SWELL PKR,D=2.992" 4-1/2"LNR,12.6#,L-80 BT,.0152 bpf,D=3.958" - 17889' ,�1 et17865' -13-1/2" 2""X 4 1XO,D=2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 02/20/13 D-25 INTIAL COMPLETION 11/06/14 DJS/JND GLV C/O(11/02/14) WaL: Z-61 08/05/13 SWC/JM)GLV C/0(07/17/13) 09/11/15 KAB/JMD PKR/SLV CORRECTION(07/30/15) PERM'No: 2121130 12/04/13 WEC/JND CLOSED SSD(1128!13) 09/11/15 JTCJJMJ SHFTED SLVS OPEN(08/30/15) API No: 50-029-23474-00 02/03/14 ALMJMJ OPENED SSD(01/28/14) 03/22/16 JLS/JM) PBRFS(02/23/16) Sm. 19,T11N,R12E,846'FM.&2207'FWL 09/23/14 JI*JJM3 GLV C/O(0920/14) 10/25/14 STF/PJC FULLSO/SET CRC-GLM#1 BP Exploration(Alaska) O O 1 I O C N N N m. 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CO co CO c. co CO _01 CT a) a) _0) C7) O _m _O m _m _O 0) _O O m O) CA O O 0 0 U U 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 MO CO co O O O O O O co co co co CO CO CO CO Co CO ✓ cl) CC) u) N N N N N N N 0 0 0 0 0 0 0 0 0 ✓ N N N N N N N N N N N N N N N N N •N N N N N N N N N N M CO M M co co co co co n- ;N N N N N N N N N N N N N N N N N N N N1 0• 0) O co N. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C) U E Q a2WW CD CA o ° LULWWWWWWLU ww LU W LU LU LU o _ o o N x (� ❑ ❑ x ✓ ,x 0 2' 2 > a x y M o m J O E .c v .cc -o w c`3 E 0 'o x y a) = N ? m U) N c c c c a x ui N O a X 2 2 " p) 0 7 a > N N Ln 0 >. > C C - >. >' 7 7 CI) a) a) a) ,9 9 _U U_ _U U_ U_ Z d d (O Z fn (n o ❑ c N co Z 2 Z Z Z >. >. 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E 1 0 m 0 0 I, av 2 o o oN aI U Uc. D c I `" t0 0 J (~ r n 1 E 0 Q `f c Eto o o a U milk ~ E `I M 8 5 co II G = N c c f9 COQ N d W m N •O I— E 0 z 7 0 N c O) N c0 o f4 U .p+ c 0 4111 C , • .2a. C a Q O u L I D U o o co 1 z I = MN O Q li O O HN N a (!)0) O N N IP Q N CO V M >- m N E a 10 o o e = ai > a w a) .` rn fx H m 0 O so to =' d 0 o c c g z c m o ZS c,) p n o 0 o +r C c U 0a y CO U E ° v' o n " E E p o E y I, E I a 0 a 0 c) U a c ! o 1 1 0 S 4116 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeIIlntegrityCoordinator@bp.com] Sent: Saturday, September 14, 2013 12:57 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity;AK, OPS Well Pad Z; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; Regg, James B(DOA); AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: OPERABLE: Producer Z-61 (PTD#2121130) Passing TIFL All, Producer Z-61 (PTD#2121130) had a passing TIFL performed on 9/14/2013,verifying two competent barrers. At this time the well is reclassified as Operable. Thank you, Laurie Climer r.IIILrIun(:./cri l Ui.sbrmi) BPP Alaska - Well Integrity Coordinator ' t„:„,,Nois oryar„2 i1 ori WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@aBP.com From: AK, D&C Well Integrity Coordinator Sent: Friday, September 06, 2013 7:26 PM To: OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS C2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; *aniel, Ryan; AK, D&C Wireline Operations Team Lea. AK, D&C Well Services Operations Team Lead; AK, RES GPB West ' -IIs Opt Engr; AK, RES GPB East Wells Opt Engr; Bu n, Kaity; AK, OPS Well Pad Z; 'chris.wallace@. .ska.gov' Cc: AK, D&C DHD ell Integrity Engineer; 'jim.regg@alaska.gov'; 'AK, c:C Projects Well Integrity Engineer'; Climer, Laurie A Subject: UNDER EVALU• ON: Producer Z-61 (PTD #2121130) IA exceed-• OASP All, Producer Z-61 (PTD#2121130) IA exc- ded MOASP on 09/03/2013 with TBG/IA/OA=226 2040/0 psi due to a suspected hydrate plug.At this time the well is recla ified as Under Evaluation for further diagnostics. • hot oil treatment was performed on 09/04/2013. Plan forward: 1. DHD: perform a warm TIFL 2. WIE:further evaluation as needed A copy of the wellbore schematic and the TIO plot has been included fo eference. 1 �� Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Friday, September 06, 2013 7:26 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS Well Pad Z; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; Regg, James B (DOA); AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer Z-61 (PTD #2121130) IA exceeded MOASP Attachments: Producer Z-61 TIO Plot 09-06-13.docx; Z-61 Wellbore Schematic.pdf All, Producer Z-61 (PTD#2121130) IA exceeded MOASP on 09/03/2013 with TBG/IA/OA= 220/2040/0 psi due to a suspected hydrate plug. At this time the well is reclassified as Under Evaluation for further diagnostics. A hot oil treatment was performed on 09/04/2013. Plan forward: 1. DHD: perform a warm TIFL 2. WIE: further evaluation as needed A copy of the wellbore schematic and the TIO plot has been included for reference. Please call with any questions. Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator V!N Goth \Nos pwtyn'zat'On WIC Office: 907.659.5102 WIC Email: AKDCWe1lIntegrityCoordinator(q,BP.com 1 Producer Z-61 (PTD#2121130) TIO Plot 09/06/2013 WO Tho tO 2W0 + OA 00A • 000n On 1AW 06m'1] Min OfiIW3 wan .. - OBnO'11 06i-•- f2t t� 1+.; IFS= 4-1/16"CIW WELLHEAD- FMC Z-61 -61 SAFE 1TES: WELL ANGLE>70°@ 14562'"•• ACTUATOR= LEO CHROmc 113G 8. LNR••• MIAL KB.11EV= 96.1 M1AL.BF.ELEV= 55.9' 509' -13-3/8"TAM PORT COLLAR D=12.420" KOP= 475' Max Angle= 98°@ 14848' I I 2017' ---I4-1/2"HES X NP,D=3.813' Datum MD= T 14293' Datum TVD= 8800.SS 01957' 13-3/8"X 10-3/4"ZXPN LTP& 20"X 30"INSULATE CONDUCTOR --I 80' P I FLEX LOCK HGR D=9.45" 91.5#,A-53,D= 19.124" 1990' H 10-3/4"X 9-5/8"LNR XO,D=8.835" 13-3/8'CSG,68#,L-80 BTC,D=12.415' 2109' GAS LFT MANDRELS ST MD TVD DEV TY FE VLV LATCH PORT DATE 9-518'CSG,40#,L-60 BTC,D=8.835' H 4906' I. 8 4329 3246 65 KBG2 DOME BK 16 07/17/13 7 7547 4690 63 KBG2 DMY BK 0 02/16/13 6 8907 5307 64 KBG2 DOME BK 16 07/17/13 I TOP OF CB'AB'JT(LOGGED BY RIG)J-I 10760' 5 10352 6003 55 KBG2 DMY BK 0 02/16/13 -4 4 11258 6559 49 KBG2 DMY BK 0 02/16/13 1 3 12081 7106 42 KBG2 DOME BK 16 07/17/13 .' 2 12694 7601 33 KBG2 DMY BK 0 07/17/13 Minimum ID =3.813" @ 2017' • 1 13766 8480 34 KBG2 SO BK 20 07/17/13 4-1/2" HES X NIPPLE •• I 13801' H4-112"HES X NP,D=3.813" V r ....0 13830' _17"X 4-1/2"HES TNT PKR,D=3.856" • • ' 13865' --I4-112'HES X NP,D=3.813' y v + I 11339494 -1-14: -74 -l47 1/2' "HBESKR X HRD NP,ED XF 3.8LTP3' ,D=4.32" -74 4-1/2"TBG,12.6#,13CR-80 VAM TOP, H 13952' .,y t1 13953' -14-1/2'NLEG,D=4.00 .0152 bpf,ID-3.958" -I ELMD TT NOT LOGGED 7"CSG,26#,L-80 VAM TOP HC H 14109' .4 13972' H7'X 5"BKR FLEX-LOCK HGR,D=5.25" .0383 bpi.13=6.276 , 13981' -15"X 4-1/2"XO BUSHING,D=3.91' HE'S SWELL PACKEM XXD SLIDING SLV,ID=3813" NO SIZE TOP DEATH MN D NO DE F T H 0/C C ATE 8 4-1/2" 14308 3.958" .-41111. 9 14378 C 04/14/13 7 4-1/2" 14469 3.958" 8 14680 C 04/14/13 6 4-1/2" 15057 3.958" '='11111' 7 15269 C 04/14/13 5 4-1/2" 15443 3.958" 6 15612 C 04/14/13 ._. 4 4-1/2" 16011 3.958' 5 15876 C 04/14/13 3 4-1/2" 16357 3.958' .:.iii.:. 4 16222 C 04/14/13 2 4-1/2" 16901 3.958' en es IN 3 16726 C 04/14/13 1 4-1/2" 17487 3.958" '=• '=' 2 17152 0 04/14/13 us' 1 17657 C 04/14/13 1.17.1 07;1 O=OPEN C=CLOSED mi• annomm •o• •MI 11.In•• 17797' --I4-1/2'BKR SHFT TOOL VE RFICATION SUB,D=3.86' R3TD H 17820' 17820' H4-1/2"BKR ISOLATION VALVE,ID=1.00" 4-1/2"LNR 12.6#,13CR-80 HY0521, H 17819' 17823' -{4-112"X 3-1/2"XO,D=2.992" .0152 bpf,D=3.958' . :.4 17835' -13-1/2"HES SWELL PKR,ID=2.992" 4-1/2'LNR 12.6#,L-80 BT,.0152 bpf,D=3.958' -{ 17889' 17866' --13-1/2'X 4-1/2"XO,D=2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDtiOE BAY UNIT 02/20/13 D-25 INITIAL COMPLETION 08/05/13 SWC/JMD GLV C/O(07/17/13) WELL: Z-61 02/23/13 PJC DRLG DRAFT COTiREi"TONS PERMT ND: 121130 02/25/13 KI-VPJC FFIAL DRLG CORRECTIONS AR No: 50-029-23474-00 02/27/13 PJC 4-1/2"LINER CORRECTON S . 19,T11N,R12E,846'FTL&2207'FW. 03/29/13 TM PJC GLV GO 04/25/13 JJUPJC &AFT SLD SLV(04/14/13) BP Exploration(Alaska) 2.\2' x`45 DATA LOGGED .M K BENDS Z3� + .M K BENDER w ` Schiumberger RECEIVED Drilling &Measurements AUG 15 eni3 MWD/LWD Log Product Delivery AOGCC A,OGCC Customer BP Exploration Alaska Inc Dispatched To: Makana Bender Well No Z-61 Date Dispatched: 14-Aug-13 Installation/Rig DOYON 25 Dispatched By: STEPHANIE PACILLO Data Survey No Of Prints No of CDs Z-61 Log 1 1 2 in MD 1 2 in TVD 1 5 in MD 1 5 in TVD 1 Received By: Please sign and return one copyto: Drilling&Measurements 2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 hechetoCcD-slb.com Hector Echeto Fax 907-561-8317 TRANSMITTAL#:6401 0 4111 i t6.— i ii) ^I�^^m N ya p {p a iii �Ipb�p 1pp�pp<'fpp !WA Mil pmo MmMm NTNgO bpNpnN� ta�f mn�N 'OtO� NNN'ON OsiNte y1 5 V a O a a 0 t h CJ N N N NNN 8 m a^N O N O r tE§M a N N N i(f a b NNN,, rrnnn nn nnn rrrnrr, coI.Sin ,7g,N •-Somme a p 00008 88888 88888 88888 88888 88822 maE E22 f6 O N 0 N N 01 N NNN N d J W*,Oi Oi TTM 01 t 01 0 01 4 01 4 O1 4 Ci O>01 01 fo 4 fo fo 2 4 01 1 01*O) 4.T Oi T lT aaaaa aaaaa aaaaa ev°�aa aaaaa aaaaa aaaaa aaaaa . . . i Q NOOMS;SdbbON6"bbO NOa MO nphN V80 Hs— NC ',7- = 9 000 NONOO O0 ' NnMn y28nm01 N^ NN §2<82 O,- 9bbNb3 M zgwww www-- cowmmma821g bND2 22222 gNN NNNNM NNNNM qNE NNNqMNNNNM NNNNM NNNNM NN cM MERE f0`�O`IO`00 n^�O\IO`O MERE 000IO`IO` OIO\IO`n I0` f0�IO\Pn0 EREPE O N Uu RJ cg0p28Mpp .9,1'-'78.9 22'.284 b<.r4 . mnN 22822 N2NL,!aP2 N v212NNN Ni;F, gF, y7,", NNoQ2 A2yNQSEM an.c.3lggE W 1m" titil i[ EMI miliqIREi§ NDN§b S §O pNObP-b NnNpi1:-.8"2 nn478 pmrNm b0V8 ,f„.3 2,181:-:41NM1g N� �NNA Mei gOEbA2232bERM 21111 111 iAqWpAbWg§ NNNN NNNNM yQNNM 21n00 tm!M 0GOOiO !!! rVNN Ompyn !F vb N$ T O 6 W_00000 ,9422,7- 88842,ZnC8282; t 8M 08 "8" ON L"On No b .2bN 48SON A0m0A W0V'N rrC C. 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Nl-6 ,nrAm MM2 « 4,“.:;:g < p o 1 It ' 0 • D4TA OG3 D z\2--"3 M K BENDER 2.3 206 Schiumberger RECEIVED Drilling & Measurements MWD/LWD Log Product Delivery AOGCC Customer BP Exploration Alaska Inc Dispatched To: Makana Bender Well No Z-61 PB1 Date Dispatched: 14-Aug-13 Installation/Rig DOYON 25 Dispatched By: STEPHANIE PACILLO Data Survey No Of Prints No of CDs Z-61 PB1 Log 1 1 2 in MD 1 2inTVD 1 5 in MD 1 5 in TVD 1 Received By: 729604• Please sign and return one copyto: Drilling&Measurements 2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 hecheto@slb.com Hector Echeto Fax 907-561-8317 TRANSMITTAL#:6401 0 to CO v x D N y 0 S NIP -o N N co n _, N o 0. , o W 13 n S al rn m X Z Z#1n, nom, z = v d R r co fn N -a i D CI 04 3 m a 3 CD (A vii N c �' 0 0 a o -I W V 0 V v O am i A (n K N (D rT zr as �• I•3CO D � no W D D W m o X ° d Z\Z-`13 N A N n to W t0 .. OM LC/ G N .Ni S 0 "2-2-7..2_,O O O CO W C) C) O W 0 W W C) C) C) W O C) O ---J O co a coco 0 CON_ Cr, o o C D En o 0 D A A C C O 0 8 2 0 0 0 0 p n A O g , 2 -4 W W o o o 3 � O 0 0 0 0 0 0 0 0 0 0 o o o o 7z ,G 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C r-r 0 0 N A 0 0 � 0 0 0 0 a o o 0 m Cl) O O 00 - -I N 0) (71 ,-,c) (e1 W 0) o W N A W Xi W (") to N O - w 01 W O N A W CDCD CD CD . Cl) 0 c H H O 70 D x o Z !•^ • N o 9 x x x x x x x x x x x )C x x x x (/1 m H N s CO N 01 W 0 C 73 E 71 E K -1 71 73 3 73 71 71 71 73 73 (n Cn 0 C) C) C) x (n a) 0 cn co cn cn j -1 O Z Z Z O H H Z H -1 -1 --1 -1 CO O n r r r ,i fn r fn W fn W X 73 m O r D 73 D X D X D X X -I 3 -I O C) z z r W j 0 ir 7 x 07 co (o V W N ti 00 V V 00 U1 O A O V r' ^, 7' rD u., T fn L Z L Z Q (n L L Z 0 Z cn L z fn O W (L x O • CD /p 0 C O O A (D O O O N 0) C G) "' v N C < C < K .a 7 7 . n < -O < 13 ni . a)CIO c W " N N N N N N N N N N N N N N N [@� S� 90 O � � c \ G M to v '^. 7 cal 0 ell Ln 6 z 1 - z fa CA W (1) " caro w o o K 1 0 �a ., R 0 ?r 00000000000000000 N O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 c4 CD 0 c. cn 0 114 McMains, Stephen E (DOA) From: Lastufka, Joseph N [Joseph.Lastufka@bp.com] Sent: Wednesday, April 24, 2013 8:41 AM To: Hunt, Jennifer L (DOT) Cc: McMains, Stephen E (DOA) Subject: PBU Z-61 / PTD#212-113 Hi Jennifer, Please reference the following well: () c _cJ Well Name: PBU Z-61 Permit#: 212-113 API #: 50-029-23474-00-00 Date of Test: 4/23/13 Type of Test: IPT (Initial Production Test) Choke Size: 96 Choke Unit: Production Method: Gas Lifted Duration (Hours Tested): 4 Top Reference (Top Perf MD): 14378' Bottom Reference (Bottom Perf MD): 17657' Tubing Flowing (Pressure): 280 Casing Pressure: 840 Total Test(Rate f/0, W, G): 40 / 1 /0 24-Hour Rate (0, W, G): 237/6/0 Gravity (Oil, API): Not Available GOR (Gas-Oil Ratio): 0 This well began Production on %BAMS APR 2 4 2013 T Method of Operations on this date: 4/20/2013 1 REQ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status. . ®Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned ❑Suspended 1b Well Class 20AAC 25 105 20AAC 25 110 0 Exploratory 0 Stratigraphic • 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One ®Development 0 Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 2/20/2013 / 212-113 • 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 1/2/2013 50-029-23474-00-00 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 2/13/2013 PBU Z-61 4434' FSL,2747'FEL, Sec. 19,T11N, R12E, UM 8. KB(ft above MSL): 96 4 15 Field/Pool(s) Top of Productive Horizon: 3855' FSL,2528'FEL, Sec. 07,T11N, R12E, UM GL(ft above MSL): 55.9' • Prudhoe Bay/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD) 764' FSL,68' FEL, Sec.01,T11N, R11 E, UM 17876' • 9007' • 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: ,, Surface: x- 599929 • y- 5959240 ' Zone- ASP4 17891'I 9008' 4 ADL 028262,047450&028240 TPI: x- 599975 y- 5969222 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 597496 y- 5971378 Zone- ASP4 None 18. Directional Surve : 19 Water depth,if offshore: 20. Thickness of Permafrost(ND): y ®Yes 0 No (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1846' 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071)' 22.Re-Drill/Lateral Top Window MD/TVD: MWD/GR/Res, MWD/GR/Res/Neu/Den, USIT N/A 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT GRADE Top BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 41' 120' 41' 120' 260 sx Arctic Set(Approx.) 13-3/8" 68# L-80 41' 2109' _ 41' 2031' 16" 2509 sx DeepCrete,164 sx'G',932 sx DeepCrete,1183 sx AS I, 526 sx AS Light,1280 sx AS I,2304 sx'G',2168 sx'G',604 sx AS I 9-5/8" 40# L-80 1957' 4906' 1895' 3506' 12-1/4" 346 sx LiteCrete, 907 sx Class'G' 7" 26# L-80 37' 14109' 37' 8763' 8-3/4" 926 sx LiteCrete, 106 sx Class'G' 4-1/2" 12.6 13Cr80 13948' 17889' 8630' 9008' 6-1/8" Uncemented Slotted Liner, Swell Packers 24. Open to production or injection? ®Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ) 4-1/2"Sliding Sleeves w/Swell Packers 4-1/2", 12.6#, 13Cr80 13953' 13830'/8533' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 14378' 8944' ,':. ''2P`I WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No • 14680' 9046' ] ' . 15269' 8990' / G/` DEPTH INTERVAL(MD AMOUNT AND KIND OF MATERIAL USED 15612' 8955' , if. 2000' Freeze Protect w/70 Bbls Diesel 15876' 8957' ,e ,, . . 16222' 8961' 16726' 8952' 17152' 8955' 17657' 8991' 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No ' Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None R9DMS MAR 2 0 Zp1 Form 10-407 Revised 10/2012 �CONTI E O R RSE Submit Original Only vLF6// j/4- ?61 (zit 6 'a� �)� G 29. GEOLOGIC MARKERS(List all formations and r a encounter 30. RMATION TESTS NAME MD TVD Well Tested? 0 Yes ®No ' Permafrost Top 34' 34' If yes,list intervals and formations tested,briefly summarizing test Permafrost Base 1941' 1880' results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 MC 25.071. Ungu 3922' 3060' None Schrader Bluff N 7372' 4612' Schrader Bluff 0 7754' 4788' Base of Schrader Bluff 8582' 5163' HRZ 10979' 6380' Kalubik 11243' 6550' Kuparuk C 11310' 6593' LCU 11414' 6660' Kuparuk B 11414' 6660' Kuparuk A 11533' 6736' Miluveach 11656' 6813' Kingak 12650' 7564' Sag River 14104' 8759' Shublik 14146' 8793' Eileen 14301' 8901' Ivishak/Zone 4 14347' 8928' Zone 4/Eileen(Invert) 15717' 8951' Eileen/Zone 4(Revert) 15820' 8953' Zone 4/Eileen(Invert) 16485' 8950' Eileen/Zone 4(Revert) 16692' 8949' Formation at Total Depth: Ivishak/Zone 4 ' 16692' 8949' 31.List of Attachment Summary of Daily Drilling Reports,Well Schematic Diagram,Surveys 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kris Hones,564-4841 Email: Kristopher.Honas@bp.com 1 Printed Name: .: Last a Title: Drilling Technologist Signatu • I Phone 564-4091 Date:.5/1916 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory Information required by 20 MC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 MC 25.071. Form 10-407 Revised 10/2012 Submit Original Only TRRE=4-1/16"DBL MASTER VALVE VVEI.LEPAD= FRAC SAFETAIllp TES: WELL ANGLE>70*@ 14562'*** ACTUATOR= PJCHRG&LNR*** INITIAL KB_REV= 96.7' [' 4 INITIAL.BF.REV 55.9' DRAFT I =I--I 509' H13-3/8"TAM FORT COLLAR,D=12.420" KOP= - - 475' Max Angle= 98 @ 14848' I I 2017' H4-1/2"HES X NP,ID=3.813" Datum KID= 14293' Datum TVD= 8800.SS ►moi 1957' -13-318"X 10-3/4"ZXPN LTP& 20"X 30"NSULATE CONDUCTOR 80" FLEX LOCK HGR,D=9.45" 91.5#,A-53,D=19.124" 1990' H10-3/4"X 9-5/8"LNR XO,0=&835" 13-3/8"CSG,68#,L-80 BTC,D=12.415" 2109' GAS LIFT MANDTaS ST MD TVD DEV TYPE VLV LATCH FORT DATE 9-5/8"CSG,40#,L-80 BTC,D=8.835" -I 4906' i ih. 8 4329 3246 65 KBG2 DCK BB 0 02/16/13 7 7547 4690 63 KBG2 DMY BK 0 02/16/13 6 8907 5307 64 KBG2 DMY BK 0 02/16/13 TOP OF CEMENT(LOGGED BY RIG) -I 10760' I5 10352 6003 55 KBG2 DMY BK 0 02116/13 4 11258 6559 49 KBG2 DMY BK 0 02/16/13 ao 3 12081 7106 42 KBG2 DM' BK 0 02/16/13 2 12694 7601 33 KBG2 DMY BK 0 02/16/13 Minimum ID =3.813" @ 2017' 1 13766 8480 34 KBG2 DMY BK 0 02/16/13 4-112" HES X NIPPLE y 13801' -I4-112"HES X NP,b=3.813' 13830' _IT'X 4-1/2"HES TNT PKR,b=3.856" ir 13865' -14-1/2"HES X NP,D=3.813" 'sc. I I 13941' H4-1/2"HES X NP,ID=3.813" 13948' -17'X 5"BKR HRD-E ZX FN LTP,b=4.32" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, - 13952' ; �- 13953' -I4-1/2"VVLEG,D=4.00 .0152 bpf,ID-3.958" ELMD TT NOT LOGGED r CSG,26#,L-80 VAM TOP HC - 14109' * 413972' -IT X 5"BKR FLEX-LOCK HGR,D=5.25" 1 .0383 bpf.D=6176 1 1411lo 13981' -5"X 4-1/2"XO BUSHING,D=3.91' P7.4 ICII HIES SWELL PACKERS XXD SLICING SLV,ID=3.813" 1.141ini.7;4NO SIZE I TOP DEPTH MND NO DEPTH OIC DATE 8 4-1/2" 14308 3.958" ._•Ili•- 9 14378 C 02/15/13 7 4-1/2" 14469 3.958" atm Nu 8 14680 C 02/15/13 6 4-1/2" 15057 3.958" ='_*I 7 15269 C 02/15/13 5 4-1/2' 15443 3.958" 6 15612 C 02/15/13 _.�.-. 4 4-1/2" 16011 3.958" 5 15876 C 02/15/13 3 4-1/2" 16357 3.958" >-_+1111.. 4 16222 C 02/15/13 2 4-1/2" 16901 3.958" 3 16726 C 02/15/13 1 4-1/2" 17487 3.958" '='ill•=• 2 17152 C 02/15/13 1 17657 C 02/15/13 ' -• 0=OPEN C=CLOSED atm NI --- 17797' H4-1/2"BKR SHIFT TOOL V ERPICATION SUB,0=3.86" 17820' -14-1/2"BKR ISOLATION VALVE.D=1.00" 4-1/2"LNR,12.6#,13CR 80 HYD 521, --1 17819' .0152 bpf,ID.--3.958" 17823' H4-1/2"X 3-1/2"XO,D=2.992" PB1D -I 17876" 11'4 2i 17835' H3-1/2"HES SVVELL PKR,ID=2.992" 4-1/2"LNR 12.6#,L-80 BT,.0087 bpf,D=2.992" --I 17889' -----"---I 17866' -13-1/2"X 4-1/2"XO,D=2.992" DATE REV BY COIVIVENTS [ DATE REV BY CUMVBNTS PRUDHOEBAY IHF 02/20/13 0-25 IMTIAL COMPLETION WELL: Z-61 02/23/13 PJC DRLG DRAFT CORRECTORS PERMT No:72121130 AR No: 50-029-23474-00 SEC.19,T11N,R12E,846'FN-&2207'FWL BP Exploration(Alaska) BP AMERICA LOT/ FIT Summary Well Name: Z-61 Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP)(psi) (ppg) 01/18/13 FIT 2,138.30 2,030.30 9.20 380.00 1,350.66 12.80 02/08/13 FIT 14,109.00 8,762.00 8.50 1,150.00 5,018.94 11.03 Page 1 of 1 ,u,. �`''�# " ' North America-ALASKA-BPs Pa e 1 of 46 Operation Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194 00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 12/29/2012 00:00 - 01:30 1.50 MOB P PRE PREP DERRICK TO LAY OVER,B/D CIRC LINES AND R/D HOSES 01:30 - 05:00 3.50 MOB P PRE R/D SERVICE LINES AT INTERCONNECTS, SWAP TO COLD START GENERATORS AND UNPLUG POWER -WALK POWER COMPLEX AWAY FROM PUMP COMPLEX AND SPOT FOR MOVE 05:00 - 07:00 2.00 MOB P PRE RAISE C-SECTION,SPOT PUMP AND PIT COMPLEX FOR RIG MOVE 07:00 - 09:00 2.00 MOB P PRE LOWER CATTLE CHUTE 09:00 - 10:30 1.50 MOB P PRE PREP AND SKID RIG FLOOR 10:30 - 12:00 1.50 MOB P PRE PREP AND LAYOVER DERRICK 12:00 - 21:00 9.00 MOB P PRE POSITION RIG MATS,UN-PIN AND WALK PIPE SHED FROM SUB -POSITION AND PIN JEEP TO SUB -REPOSITION MATS,HOOK UP TRUCK TO SUB AND STAGE FOR MOVE -CLEAN AND"SECURE CELLAR 21:00 - 23:30 2.50 MOB P PRE MOVE PARTS TRAILERS,CASING SHED,PIPE SHED,AND SUB COMPLEXES FROM Y PAD TO SPINE ROAD 23:30 - 00:00 0.50 MOB N HMAN PRE REAR WHEELS ON SOW HAULING PIPE SHED WENT OFF ROAD WHEN MAKING TURN AT GC-2 ACCESS ROAD ONTO SPINE ROAD. 12/30/2012 00:00 - 05:30 5.50 MOB N HMAN PRE DEVELOP EXTRACTION PLAN AND ASSEMBLE EQUIPMENT TO PULL SOW BACK ONTO ROADWAY -SUCCESSFULLY PULL REAR WHEELS OF SOW BACK ONTO ROADWAY -INSPECT SOW AND FOUND NO DAMAGE 05:30 - 10:30 5.00 MOB P. PRE MOVE SUB,CASING SHED,PIPESHED,AND PARTS TRAILERS TO Z PAD 10:30 - 18:00 7.50 MOB P PRE SPOT SUB OVER WELL ON Z-61 SIM-OPS:MOVE PITS,PUMP,AND POWER COMPLEXES FROM Y PAD TO Z PAD 18:00 - 22:30 4.50 MOB P PRE SPOT RIG MATS AROUND Z-61 -POSITION PITS,PUMP,AND POWER COMPLEXES WITH TRUCKS ON RIG MATS 22:30 - 23:00 0.50 MOB P PRE INSTALL AND PIN KING PIN HEADER ON PIPESHED 23:00 - 00:00 1.00 MOB P PRE HOOKUP TRUCK TO PIPE SHED AND STAGE -WALK PIPE SHED INTO POSTION 12/31/2012 00:00 - 07:30 7.50 MOB P PRE WALK PIPE SHED UNDER SUB AND BACK INTO POSITION -SHIM 4.5'AND PIN -RAISE DERRICK -SKID FLOOR 07:30 - 10:30 3.00 MOB P PRE LOWER C-SECTION -WALK PITS AND PUMP COMPLEX INTO POSITION -SPOT CSG SHED WITH TRUCK 10:30 - 12:00 1.50 MOB P PRE RAISE CATTLE CHUTE -WALK CSG SHED INTO POSITION AND SHIM 6" -PLUG IN MODULES AND CONNECT SERVICE LINES Printed 3/4/2013 2:44:52PM I ) e a North America-ALASKA-B Page 2 of 46 ..xx.,. .. .K� Operation Sum 7,4 ;.2 • •. Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 18:00 6.00 MOB P PRE CONTINUE PLUGGING IN MODULES AND CONNECT SERVICE LINES -FOLD DOWN ALL STAIRWAYS AND LANDINGS -HOOK UP HIGH PRESSURE MUD LINES -INSTALL STEAM TRAPS AND SEND STEAM AROUND RIG WEATHERTIGHT CATTLE CHUTE -CLEAN UP RIG UP TOOLS AND EQUIPMENT -TEST GENERATOR ESD 18 00 - 23:00 5.00 MOB P PRE POWER UP RIG,ON PRIME MOVERS -POWER UP AMPHION -BRIDLE UP AND SCOPE DERRICK -R/D BRIDAL LINES -HOOK UP KELLY HOSE -PLUG IN DERRICK LIGHTS RIGACCEPTEDSQ 4930 23:00 - 00:00 1.00 RIGU P PRE R/U TO SLIP AND CUT DRILLING LINE,PULL 30'-0F NEW LINE UPON FLOOR 1/1/2013 00:00 - 00:30 0.50 RIGU P PRE HOLD Z-61 PRE-SPUD WITH FLEAGLE CREW 00:30 - 05:00 4.50 RIGU P PRE CUT AND SLIP DRILLING LINE -PULL 500'OF DRILLING LINE ON FLOOR -HANG BLOCKS -SLIP ON 500'OF LINE,CUT OFF USED LINE AND SEND OFF FLOOR -REINSTALL HOOK LOAD SENSOR -REMOVE HANGING LINE FROM BLOCKS 05:00 - 08:30 3.50 BOPSUR P PRE P/U SURFACE RISER AND N/U TO DIVERTER IN CELLAR -N/U SURFACE BAG -N/U 3 ADDITIONAL SECTIONS OF DIVERTER VENT LINE 08:30 - 12:00 3.50 BOPSUR P PRE INSTALL OPERATING HOSES TO KNIFE VALVE AND SURFACE BAG -INSTALL 4"CONDUCTOR VALVES -SEAL UP CELLAR AREA -C/O SAVER SUB ON TOP DRIVE CALIBRATE TOTCO PVT SYSTEM AND PUMP DATA 12:00 - 16:00 4.00 BOPSUR P PRE INSTALL DRLG RISER -INSTALL AND M/U TURNBUCKLES TO DIVERTER -INSTALL FLOWLINE JETS -CALIBRATE BLOCK HEIGHT -TEST GAS ALARMS -CLEAR AND CLEAN FLOOR 16:00 - 16:30 0.50 BOPSUR P PRE D-3 DIVERTER DRILL FOLLOWED BYAAR Printed 3/4/2013 2:44:52PM t 1 North America-ALASKA BP Pages of 46 , :.. Operation maty R R . ail Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12 00 OOAM Rig Release.2/15/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 00:00 7.50 RIGU P PRE P/U 22 STANDS 5"DP AND STAND BACK -TO TO 33,500 FT-LBS P/U JARS FOR BHA#2 AND M/U ON 2 SINGLES OF HWDP AND STAND BACK P/U COLLARS FOR BHA#2 AND STAND BACK PERFORM KOOMEY DRAWDOWN TEST. ACCUMULATOR PSI=3050 -PSI AFTER CLOSING 21-1/4"DIVERTER= 2200. -KNIFE VALVE OPENING TIME=3 SECONDS -ANNULAR CLOSING TIME=35 SECONDS -11 SECONDS TO RECOVER 200 PSI WITH 2 ELECTRIC PUMPS. -46 SECONDS TO RECOVER TO FULL PRESSURE WITH 2 ELECTRIC PUMPS AND 2 AIR PUMPS. -6 NITROGEN BOTTLES AVERAGE PSI=2075 1/2/2013 00:00 - 01:00 1.00 RIGU P PRE L/D DC,TORQUE LIFT SUB,M/U TO STUMP AND STND BACK 01:00 - 02:30 1.50 RIGU P PRE R/U SLB E-LINE,GYRODATA 02:30 - 04:30 2.00 RIGU P PRE C/O SLIP INSERTS,M/U BHA#1 -FILL STACK,CHECK FOR LEAKS,TIGHTEN TWO FLANGES ON JET LINE 04:30 - 05:00 0.50 RIGU P PRE SERVICE RIG 05:00 - 07:00 2.00 RIGU N RREP -0.7 PRE TROUBLE SHOOT MUD PUMPS,POWER CABLES INSTALLED INCORRECTLY AT INTERCONNECT 07:00 - 07:30 0.50 RIGU P PRE TEST MUD LINES TO 3500 PSI 07:30 - 08:00 0.50 RIGU N SFAL -0.7 PRE THAW FROZEN LOWER WELL CONTROL VALVE ON TOP DRIVE 08:00 - 11:30 3.50 DRILL P SURF DRILL 16"SURFACE HOLE FROM 120'TO 225' MD(225'TVD) -445 GPM,290 PSI ON/245 PSI OFF -MW 8.6 IN/8.6 OUT -40 RPM,4KTQON/0KTQOFF -5-10K WOB -AST=1.27 HRS,ART=0.54 HRS,ADT=1.81 HRS,TOTAL BIT HRS 1.81 -P/U=50K,S/O=50K,ROT=50K 11:30 - 15:00 3.50 DRILL N RREP 224.3 SURF UNPLUG CUTTINGS TANK OFF-LOAD LINE 15:00 - 17:00 2.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 225'TO 278' MD(278'TVD) -440 GPM,450 PSI ON/350 PSI OFF MW 8.6 1N/8.7+OUT -0 RPM,0 KTQON/0 KTQOFF -10KWOB -AST=1.21 HRS,ART=O HRS,ADT=1.21 HRS,TOTAL BIT HRS 3.02 -P/U=50K,S/O=60K,ROT=55K 17:00 - 17:30 0.50 DRILL P SURF GYRO @ 278' -PROJECTED BIT DEPTH WITHIN 4'OF EAST 0-500'HARD LINE -CONSULT WITH TOWN,DECISION MADE TO POOH Printed 3/4/2013 2:44:52PM 1 J Page 4 of 46 North America-ALASKA-BP• Operation Stun.,,, •cert Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date 12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/me:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 19:30 2.00 DRILL N DPRB 277.3 SURF MONITORWELL-STATIC -POOH F/278'T/SURFACE,VERIFY MOTOR SCRIBE STILLADJUSTED TO 2.12 -VERIFY UBHO SUB ORIENTING KEY SLOT TIGHT AND ALIGNED WITH MOTOR SCRIBE 19:30 - 20:00 0.50 DRILL N DPRB 277.3 SURF P/U STD OF DC AND RIH TO 148' 20:00 - 20:30 0.50 DRILL N DPRB 277.3 SURF GYRO SURVEY @ 145' 20:30 - 00:00 3.50 DRILL N DPRB 277.3 • SURF TROUGH 16"SURFACE HOLE FROM 148'TO 215'MD(215'TVD) -440 GPM,590 PSI ON/350 PSI OFF MW 8.7+IN/8.7+OUT -0 RPM,0KTQON/0KTQOFF -1KWOB -P/U=55 K,S/O=60 K,RQT=K GYRO EVERY 30' 1/3/2013 00:00 - 04:00 4.00 DRILL N DPRB 277.3 SURF TROUGH 16"SURFACE HOLE FROM 215'TO 255'MD(255'TVD) -440 GPM,590 PSI ON/350 PSI OFF MW 8.7+IN 18.7+OUT -0 RPM,0KTQON/0KTQOFF -OKWOB -P/U=61 K,S/0=71 K,ROT=K GYRO EVERY 30' 04:00 - 05:00 1.00 DRILL N DPRB 277.3 SURF JET FLOW LINE T/CLEAR GRAVEL 05:00 - 06:00 1.00 DRILL N DPRB 277.3 SURF TROUGH 16"SURFACE HOLE FROM 255'TO 277'MD(277'TVD) -440 GPM,590 PSI ON/350 PSI OFF MW 8.7+IN/8.7+OUT -0 RPM,0KTQON/0KTQOFF -OKWOB -P/U=61 K,S/O=71 K,ROT=K GYRO EVERY 30' 06:00 - 06:30 0.50 DRILL N WAFT 277.3 SURF WAIT ON ORDERS,MAKE DECISION TURN UP MOTOR TO 2.38° 06:30 - 09:00 2.50 DRILL N DPRB 277.3 SURF POOH,ADJUST MOTOR TO 2.38,ORIENT UBHO AND INSPECT BIT 09:00 - 10:00 1.00 DRILL N DPRB 277.3 SURF RIH TO 278' 10:00 - 22:00 12.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 278'TO 522' MD(521'TVD) -550 GPM,650 PSI ON/540 PSI OFF -MW 9.0 IN/9.0 OUT -40 RPM,3-5 K TQ ON/3-5 K TQ OFF -10-25K WOB -AST=6.77 HRS,ART=3.51 HRS,ADT=10.28 HRS,TOTAL BIT HRS 13.3 -P/U=65K,S/O=80K,ROT=75K 22:00 - 23:00 1.00 DRILL P SURF MONITOR WELL 10 MIN.WELL STATIC,POOH FROM 522',PULLED TIGHT©460' -UNABLE TO WORK BACK TO BOTTOM -M/U TD,BRING PUMPS UP TO 500 GPM,450 PSI -WORK PIPE FREE,ATTEMPT TO PUMP OUT THROUGH TIGHT SPOT -UNABLE TO PUMP OUT THROUGH TIGHT SPOT -BACKREAM PAST TIGHT SPOT,10 RPM,500 GPM,450 PSI TO 431' 23:00 - 00:00 1.00 DRILL P SURF POOH FROM 431'TO 152' Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 5 of 46 Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. 'UW: Active datum:Z-61 Actual©96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/4/2013 00:00 - 01:00 1.00 DRILL P SURF CONTINUE POOH FROM 152'TO SURFACE -UD BHA COMPONENTS AS DIRECTED BY DD -MONITOR HOLE FILL ON PIT#1 01:00 - 03:00 2.00 DRILL P SURF REMOVE PS-21 SLIPS AND INSTALL MASTER BUSHING IN ROTARY -CLEAR AND CLEAN RIG FLOOR -MONITOR HOLE FILL ON PIT#1 03:00 - 03:30 0.50 DRILL P SURF PJSM P/U BHA#4 -MONITOR HOLE FILL ON PIT#1 _ 03:30 - 05:00 1.50 DRILL P SURF CONTINUE P/U BHA#4 HOLE TIGHT AT 370' -KELLY UP AND WORK THROUGH @ 20 RPM, 300 GPM,300 PSI -MONITOR WELL ON PIT#1 05:00 - 06:00 1.00 DRILL P SURF CONTINUE WORKING THROUGH TIGHT SPOT FROM O70'TO410',@20RPM -300 GPM,400 PSI,3-5 K TQ -CONTINUE[N HOLE TO 483' 06:00 - 07:00 1.00 DRILL P SURF SHALLOW TEST MWD @ 500 GPM,650 PSI, TEST GOOD -BLOW DOWN TD -ORIENT W/GYRO 07:00 - 12:00 5.0,0-- DRILL P SURF WASH DN FROM 483'TO 522' -DRILL 16"SURFACE HOLE FROM 522'TO 705'MD(703'TVD) -603 GPM,965 PSI ON/880 PSI OFF MW 9.0 IN/9.0 OUT -40 RPM,3-5KTQON/3KTQOFF -30K WOB -AST=2.37 HRS,ART=0.49 HRS,ADT=2.86 HRS,TOTAL BIT HRS 16.16 -P/U=96K,S/O=98K,ROT=100K -TOTAL JRS.HRS 2.86 12:00 - 21:00 9.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 705'TO 1048' ✓ MD(1043'ND) -604 GPM,1028 PSI ON/940 PSI OFF -MW 9.0+IN/9.0+OUT -40 RPM,6-7 K TQ ON/2-3 K TQ OFF -20-35K WOB -AST=2.28 HRS,ART=2.27 HRS,ADT=4.55 HRS,TOTAL BIT HRS 20.71 -P/U=96K,S/O=105K,ROT=92K -TOTAL JRS.HRS 7.41 21:00 - 21:30 0.50 DRILL P SURF SERVICE RIG 21:30 - 22:30 1.00 DRILL N RREP 1,047.3 SURF C/O WASH PIPE SWIVEL PACKING ✓ 22:30 - 23:30 1.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 1048'TO 1080'MD(1075'TVD) -602 GPM,1050 PSI ON/980 PSI OFF -MW 9.0+IN/9.0+OUT -40 RPM,6-7 K TQ ON/2-3 K TQ OFF -30K WOB -AST=0.57 HRS,ART=0.15 HRS,ADT=0.72 HRS,TOTAL BIT HRS 21.43 -P/U=100K,S/O=106K,ROT=95K -TOTAL JRS.HRS 8.13 23:30 - 00:00 0.50 DRILL N HMAN 1,079.3 SURF CUTTINGS TANK OFF LOAD LINE PLUGGED OFF Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page s of ds Op '•n Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 fX3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/lime:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/5/2013 00:00 - 10:00 10.00 DRILL N HMAN 1,079.3 SURF CONTINUE UNPLUGGING CUTTINGS TANK OFF LOAD LINE -CIRCULATE AND RECIPROCATE(dl 20 RPM, 300 GPM,280 PSI,3 K TQ -RACK 1 STD BACK EVERY HOUR TO 760' 10:00 - 12:00 2.00 DRILL N HMAN 1,079.3 SURF POOH FROM 760'TO 300' -MONITOR HOLE FILL ON TRIP TANK CONTINUE UNPLUGGING CUTTINGS TANK OFF LOAD LINE 12:00 - 15:00 3.00 DRILL N HMAN 1,079.3 SURF CONTINUE CLEAN OUT OF CUTTINGS TANK LINE -WASH TO BOTTOM(4140 RPM,600 GPM, 1040 PSI,3-5 K 15:00 - 00:00 9.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 1080'TO 1351'MD(1336'TVD) -603 GPM,1070 PSI ON/950 PSI OFF MW 9.0+IN/9.0+OUT -40 RPM,7-8KTOON/4KTQOFF -25-35K WOB -AST=3.68 MRS,ART=2.39 HRS,ADT=6.07 HRS,TOTAL BIT HRS 27.5 -P/U=100K,S/O=106K,ROT=95K -TOTAL JRS.HRS 14.20 1/6/2013 00:00 - 12:00 12.00---, CIRRI P SURF -DRILL 16"SURFACE HOLE FROM 1351'TO 1901'MD(1848'TVD) -600 GPM,1280 PSI ON/1030 PSI OFF -MW 9.15 IN/9.15 OUT -40 RPM,10KTQON/7KTQOFF -35K WOB -AST=2.86 HRS,ART=5.85 HRS,ADT=8.71 HRS,TOTAL BIT HRS 36.21 -P/U=112K,S/O=115K,ROT=114K -TOTAL JRS.HRS 22.91 12:00 - 16:00 4.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 1901'TO 2081'MD(2006'TVD) -650 GPM,1225 PSI ON/1025 PSI OFF • -MW 9.25 IN/9.25 OUT -40 RPM,10-12 K TQ ON/6-7 K TQ OFF -30-45K WOB 16:00 - 16:30 0.50 DRILL P SURF CBU,0 RPM,650 GPM,1025 PSI 16:30 - 18:00 1.50 DRILL P SURF MONITOR WELL,STATIC -BACK REAM FROM 2081'TO 1700',40 RPM, 603 GPM,1055 PSI,7 K TQ -P/U 120K,S/O 118K,ROT 116K -NO TIGHT SPOTS 18:00 - 19:00 1.00 DRILL P SURF WASH TO BOTTOM AND ATTEMPT TO SLIDE, UNABLE, DRILL 16"SURFACE HOLE FROM 2081'TO 2119'MD(2040'TVD) -650 GPM,1225 PSI ON/1060 PSI OFF -MW 9.25 IN/9.25 OUT -40 RPM,9-10 K TQ ON/6-7 K TO OFF -20K WOB -AST=0.68 HRS,ART=1.19 HRS,ADT=1.87 HRS,TOTAL BIT HRS 38.08 -P/U=122K,5/0=115K,ROT=119K -TOTAL JRS.HRS 24.78 19:00 - 20:30 1.50 DRILL P SURF CIRCULATE 1X'S BUS WHILE ROTATING AND RECIPROCATING -40 RPM,645 GPM,1190 PSI,8K TO Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 7 of 46 Operation $411, epo, Common Well Name Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/me:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 22:30 2.00 DRILL P SURF UD DBL OFF THE TOP OF STD#14 TO RECIPROCATE FULL STD -CIRCULATE 5X'S BUS WHILE ROTATING AND RECIPROCATING -40 RPM,645 GPM,1190 PSI,8K TQ -LSYP 50,YP-82,TREAT MUD WHILE CIRCULATING -LSYP 32,YP-56 SHAKERS CLEAN,PJSM,PREP TO POOH 22:30 23:30 1.00 DRILL P SURF P/U DBL AND POOH FROM 2119' -PULL TIGHT AT 1393',40K OVER -RIH TO 1430'AND KELLY UP 23:30 - 00:00 0.50 DRILL P SURF PUMP 0011 FROM 1430'TO 1335' -500 GPM,870 PSI,P/U 115K,S/O 105K 1/7/2013 00:00 - 01:30 1.50 DRILL P SURF WORK TIGHT SPOT FROM 1400' -BACK REAM FROM 1335'TO 1050',40 RPM, 600 GPM,980 PSI,5K TQ 01:30 - 02:00 0.50 DRILL P SURF RIH ON ELEVATORS FROM 1050'TO 2119' -MONITOR DISPLACEMENT ON TRIP TANK 02:00 - 03:30 1.50 DRILL P SURF ROTATE AND RECIPROCATE -CIRCULATE TO CLEAN HOLE AND ADJUST LSYP TO 35 AND YP TO 50 ON MUD -40 RPM,600 GPM,1280 PSI,2X BUS 03:30 - 05:00 1.50 DRILL P SURF POOH ON ELEVATORS FROM 2119'TO 240' -MONITOR DISPLACEMENT ON PIT#2 05:00 - 07:30 2.50 DRILL P SURF UD BHA -MONITOR WELL ON PIT#2 07:30 - 08:30 1.00 CASING P SURF CLEAN RIG FLOOR -MONITOR WELL ON PIT#2 08:30 - 13:30 5.00 CASING P SURF R/U 13-3/8"CSG.EQUIPMENT -C/O BAILS,M/U FRANKS FILL UP TOOL, INSTALL 350 TON SPIDERS,SINGLE JOINT ELEVATORS -INSTALL STABBING BOARD -MONITOR WELL ON PIT#2 -PJSM FOR RUNNING CASING WITH CO REP, TOOLPUSHER,CREW,CSG.CREW 13:30 - 15:00 1.50 CASING P SURF DRAIN STACK FOR HANGER DUMMY RUN -CELLAR PUMP UNABLE TO PUMP VISCOUS MUD -R/U SUPER SUCKER AND DRAIN STACK -PERFORM HANGER DUMMY RUN W/LND JOINT,MARK SAME FOR FOR LANDING CSG 15:00 - 17:30 2.50 CASING P SURF RUN 5 JTS 13-3/8"CSG TO 270' -FILL EVERY JNT WITH FRANKS TOOL 17:30 - 18:30 1.00 CASING N RREP 269.3 SURF BACK UPS ON POWER TONGS NOT FUNCTIONING -HYDRAULIC QUICK DISCONNECT MALFUNCTIONED,STOPPING FLOW -REPAIRED QUICK DISCONNECT 18:30 - 22:00 3.50 CASING P 716.3 SURF CONTINUE RUNNING 13-3/8"CSG FROM 270' TO 717' -FILL PIPE WHILE RIH -ROTARY BUSHINGS MUST BE REMOVED ON EACH JT TO FIT CENTRALIZER THRU ROTARY TABLE -CIRCULATE 5 MINUTES EVERY 10 JTS Printed 3/4/2013 2:44:52PM - - ae8of46 "North America-ALASKA-BP � � >a • Operation ��: • • o Common Well Name Z-61 AFE No Event Type.DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 23:30 1.50 CASING N SFAL 716.3 SURF RAPID PRESSURE INCREASE WHILE FILLING PIPE -CHECK ALL SURFACE EQUIPMENT -R/D FRANKS FILL UP TOOLAND BLOW DOWN TOP DRIVE -STEAM MUD SAVER VALVE ON FRANKS TOOL --CLEANED SMALL FINES OFF TOP OF MUD SAVER VALVE IN FILL UP TOOL -CLEANED SUCTION STRAINERS IN MUD PUMPS,FOUND FINES IN SUCTION STRAINERS 23:30 - 00:00 0.50 CASING P SURF CONTINUE RUNNING 13-3/8"CSG FROM 717' TO 837' 1/8/2013 00:00 - 01:00 1.00 CASING N SFAL 836.3 SURF EXPERIENCE SAME PROBLEM WITH FRANKS TOOL - R/D FRANKS FILL UP TOOL AND BLOW DOWN TOP DRIVE -SWAP TO PIT#4 FOR HOLE FILL -CHANGE OUT BOTTOM SECTION OF FRANKS TOOL 01:00 - 05:00 4.00 CASING P 1,839.3 SURF CONTINUE RUNNING 13-3/8"CSG FROM 837' MD TO 1,840'MD' 05:00 - 05:30 0.50 CASING P 1,845.3 SURF WORK THROUGH OBSTRUCTION AT 1,840'MD TO 1,846'MD -255 GPM,240 PSI PU=161K,SO=140K 05:30 - 07:00 1.50 CASING P 2,084.3 SURF CIRCULATE WHILE RECIPROCATING PIPE FROM 2,100'MD TO 2,085'MD -255 GPM,240 PSI 07:00 - 09:00 2.00 CASING P 2,099.3 SURF CONT.TO RIH FROM 1,864'MD TO 2,100'MD 09:00 - 10:00 1.00 CASING P 2,084.3 SURF CIRCULATE WHILE RECIPROCATING PIPE FROM 2,100'MD TO 2,085'MD -435 GPM,610 PSI -SIMOPS:RIG DOWN POWER TONGS 10:00 - 10:30 0.50 CEMT P 2,084.3 SURF LD FRANKS TOOL,RU CEMENT HEAD 10:30 - 12:00 1.50 CEMT P 2,108.3 SURF LAND CASING HANGER ON LANDING RING. 13-3/8"CASING SHOE AT 2,109'MD -CIRCULATE AND CONDITION MUD WHILE RECIPROCATING FROM 2,109'MD TO 2,095' MD 12:00 - 13:00 1.00 CEMT P 2,108.3 SURF CIRCULATE UNTIL SHAKERS RUN CLEAN -486 GPM,415 PSI 13:00 - 16:00 3.00 CEMT P 2,108.3 SURF CIRCULATE AND CONDITION MUD TOAYP 13, LSYP 26 -335 GPM,230 PSI AOGCC WAS GIVEN 24 HR NOTIFICATION FOR UPCOMING INITIAL BOPE TESTING -BOB NOBLE WAIVED THE STATES RIGHT TO WITNESS • Printed 3/4/2013 2.44.52PM North America-ALASKA-B Page 9 of 46 Op . mmary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12'00:OOAM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UW: Active datum Z-61 Actual @96 Oft(above Mean Sea Level) Date ' From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 00:00 8.00 CASING P 2,108.3 SURF CEMENT 13-3/8"SURFACE CASING AS FOLLOWS: -PJSM FOR 13-3/8"CEMENTING WITH SCHLUMBERGER AND CH2MHILL -LINE UP TO SCHLUMBERGER CEMENTERS. -ATTEMPT TO TEST LINES,FLASH FROZE LINE,THAW LINE -PUMP 20-BBLS OF WATER,TEST LINES TO 250/3500 PSI,5-MINUTES EACH CHARTED, GOOD TEST. -PUMP 104 BBLS OF 11.0-PPG MUDPUSH II. TEST FIELD SAMPLE AS PER PROCEDURE. -DROP BOTTOM PLUG -PUMP 841-BBLS(2511 SX)11.0-PPG LEAD DEEPCRETE CEMENT.YIELD 1.88 CUFT/SK PUMP 34-BBLS(164.5 SX)15.8-PPG CLASS 'G' TAIL CEMENT.YIELD 1.16 CUFT/SK -CROP TOP PLUG.KICK OUT PLUG WITH 5-BBLS OF WATER. -SWITCH OVER TO RIG PUMPS FOR DISPLACEMENT -DISPLACE WITH 9.2 PPG DRILPLEX MUD -PUMP AT 8 BPM,WITH 460 PSI -LOSE RETURNS—82 BBLS INTO DISPLACEMENT -REDUCE RATE TO 2 BPM,330 PSI TO ESTABLISH RETURNS,UNSUCCESSFUL -STAGE PUMP RATE UP TO 5 BPM,570 PSI -REDUCED PUMP RATE TO 2 BPM,470 PSI FOR FINAL 10 BBLS PRIOR TO BUMPING PLUG -PLUG BUMPED AT 295.7 BBLS INTO DISPLACEMENT -307.7 BBLS CALCULATED DISPLACEMENT -HELD 500 PSI OVER FINAL CIRCULATING RATE -BLEED PRESSURE&CHECK FLOATS, FLOATS HOLDINQ. TOTAL LOSS WHILE PUMPING CEMENT-174 BBLS TOTAL LOSSES WHILE PUMPING DISPLACEMET-276 1/9/2013 00:00 - 02:30 2.50 CEMT P SURF RD UPPER LANDING JOINT -CHANGE OUT BAILS,REMOVED SLIPS -START PICKING UP TAM SHIFTING TOOL PER PESI REP. CALLED TOWN ODE AND DAY WSL TO LET THEM KNOW WE DID NOT GET CEMENT TO SURFACE. -SENT AN EMAIL NOTIFICATION TO THE AOGCC. BOB NOBLE CALLED AND SAID HE WAS GOING TO WAIVE THE RIGHT TO WITNESS. HE REQUESTED THAT ONCE WE GET CEMENT TO SURFACE THAT WE SEND AN EMAIL 10 JIM REG EXPLAINING HOW MUCH CEMENT WAS PUMPED AND HOW CEMENT WAS BROUGHT TO SURFACE. Printed 3/4/2013 2:44:52PM North America-ALASKA-B' Page 10 of 46 Operation Summary Report • Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Dateillme:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 08:00 5.50 CEMT P SURF RU&RUN 13-3/8"TAM PORT SHIFTING TOOL ON 5"DP TO 508'MD OPEN COLLAR PORT FOR CIRCULATION -1 BPM,500 PSI -LITTLE TO NO RETURNS 08:00 - 10:30 2.50 CEMT P SURF INCREASE RATE STAGE UP TO 7 BPM,800 PSI -NO RETURNS -UNABLE TO ESTABLISH CIRCULATION 10:30 - 15:00 4.50 CEMT P SURF PREPARE PLAN FORWARD FOR REMEDIAL CEMENT JOB. -PUMP THROUGH TAM PORT COLLAR INTERMITTENTLY WHILE WAITING ON MUD PUSH II FROM SLB. 15:00 - 18:30 3.50 CEMT P SURF WHILE WAITING ON MUD PUSH II,OPENED 4" CONDUCTOR VALVES&NOTICED SLIGHT RETURNS -APPROX 25%RETURNS PUMPED 40 BBLS OF DRILLPLEX WITH RED DYE -PUMPED TOTAL 450 BBLS,NO DYE BACK TO SURFACE -EST LOSS RATES AT 20&30 BPM WERE 84 BPH 18:30 - 19:30 1.00 CEMT P SURF DISCUSSION WITH TOWN ODE AND WELLS TEAM LEAD DECISION MADE TO GO FORWARD WITH PLANNED CMT JOB -CONT PUMPING AT 1.5 BPM,430 PSI -80%LOSS OF FLUID -SHUT DOWN PRIOR TO CEMENT JOB AND OBSERVED WELL. -BLEED PRESSURE FROM 430 PSI TO 325 PSI -WELL FLOWING BACK-25 BBLS IN 20 MIN Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 11 of 47 Operation Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.04usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 00:00 4.50 CEMT P SURF PJSM FOR CEMENT JOB WITH RIG CREW, SLB AND THIRD PARTY SUPPRORT. PUMP REMEDIAL JOB THROUGH TAM PORT COLLAR -PJSM ON CMT JOB WITH SLB,DOYON,MI -BLOW AIR THROUGH CEMENT LINE,RU CHART RECORDER -PUMP 10 BBLS OF H2O,TEST STALL -PRESSURE TEST LINES 250/3500 PSI FOR 5/5 CHARTED MIN EACH -PUMP 25 BBLS OF 10 PPG MUDPUSH II AT 2 BPM,425 PSI --15%RETURNS -PUMP 312 BBLS OF 11PPG DEEPCRETE ATS BPM,450 PSI -PUMP PRESSURE FALLING 50 PSI FOR EVERY 90 BBLS PUMPED,REGAINING 50 PSI OVER ADDITIONAL 90 BBLS PUMPED -15%RETURNS WHILE PUMPING CEMENT. ALL RETURNS TAKEN TO THE CELLAR. -DISPLACE WITH 6 BBLS OF MUD PUSH -RQIAT.F.SHIFTING TOOLAND CLOSE TAM PORT COLLAR -PRESSURE TO 1500 PSI,CONFIRM PORT IS CLOSED. NO CEMENT RETURNED TO SURFACE,TOTAL OF 47 BBLS OF 9.2 PPG MUD RETURNED TO SURFACE DAILY MUD LOSS=743 BBLS 1/10/2013 00:00 - 01:00 1.00 CEMT P SURF CIRCULATE OUT EXCESS CEMENT AND MUD PUSH. -CIRCULATE AT 18 BPM WITH 1500 PSI 01:00 - 02:30 1.50 CEMT P SURF POOH WITH TAM COLLAR SHIFTING TOOL ON 5"DP -LD DP AND SEND FOR INSPECTION AND CLEANING -LD SHIFTING TOOL. SENT NOTIFICATION OF NO CEMENT TO SURFACE TO THE AOGCC VIA EMAIL 02:30 - 04:00 1.50 CEMT N CEMT 2,118.34 SURF CLEAN AND CLEAR RIG FLOOR -CLEAN OUT FLOW LINE BOX -MONITORING WELL FLOW AT THE PITS -INITIAL FLOW RATE AROUND 10 BPH, SLOWLY TAPERING OFF -PU 1-1/4"CS HYDRIL PIPE HANDLING EQPT, LOAD CS HYDRIL Printed 3/15/2013 2:10:45PM North America-ALASKA-BP Page 12 of 46 • Operation Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/me:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual©96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 07:30 3.50 CEMT N CEMT 2,118.3 SURF PU 5"DP WHILE WAITING ON CEMENT FOR TOP JOB -RIH WITH 5"DOUBLES FROM THE PIPE SHED,RACK BACK STANDS -FLOW RATE FROM THE WELL AT 6 BPH AT 06:00 TELEPHONE DISCUSSION WITH AOGCC REP JOHN CRISP AROUND THE UPCOMING CEMENT TOP JOB-HE WOULD LIKE A TWO HOUR NOTICE PRIOR TO STARTING THE JOB PERFORMED BLIND PICK TO REPLACE DRILLING LINE SPOOL -HELD PJSM WITH BP HSE,PEAK,AND DDI PERSONNEL 07:30 - 08:30 1.00 CEMT N CEMT 2,118.3 SURF FUNCTION TEST DIVERTER -CLOSING TIME=15 SEC 08:30 - 14:00 5.50 CEMT N CEMT 2,118.3 SURF CONTINUE PICKING UP 5"DP AND MAKING UP STANDS 14:00 - 00:00 10.00 CEMT N CEMT 2,118.3 SURF MONITOR FLOW RATE -14:00=3.3 BPH -HOURLY FLOW CHECK -21:00=.95 BPH - -RIH W/5"DP SINGLES,MU IN STANDS -24:00=1 BPH -REPLACED CUTTINGS TANK OFFLOAD LINE 1/11/2013 00:00 - 12:00 12.00 CEMT N CEMT 2,118.3 SURF MONITORWELLRETURNS. -06:00= 26 GPH -08:30=25 GPH -12:00=35 GPH -CONT.MU 5"DP IN STANDS FOR NEXT HOLE SECTION -NO MEASUREABLE GAS IN MUD RETURNS 12:00 - 13:30 1.50 CEMT P 2,118.3 SURF COMPLETED L2RA,RECEIVED APPROVAL FROM TOWN TO PROCEED. -L2RA CONDUCTED BY BP HSE,WSL, TOOLPUSHER,AND SUPERINTENDENT 13:30 - 18:30 5.00 CEMT P 2,118.3 SURF -N/D SURFACE ANNULAR,RISER,SURFACE -REMOVE'T'FROM CELLAR -RESEAL CELLAR BOX 18:30 - 19:30 1.00 CEMT N CEMT 2,118.3 SURF CUT WINDOW IN CONDUCTOR PIPE. 19:30 - 23:00 3.50 CEMT N CEMT 2,118.3 SURF PU AND RUN 1-1/4",N-80,3.02#CS-HYDRIL T/ 140'MD F/TOP OF CONDUCTOR -PUMPING DOWN W/TEST PUMP,50 PSI -ENCOUNTERED 2 BRIDGES -125'MD,250 PSI -134'MD,250 PSI -140'MD-DEPTH OF REFUSAL -CONFIRMED DEPTH W/AOGCC REP.JOHN CRISP 23:00 - 00:00 1.00 CEMT N CEMT 2,118.3 SURF RU CEMENTING LINE -CONFIRM CIRCULATION THROUGH 1-1/4" PIPE W/CHARGE PUMP(GOOD) Printed 3/4/2013 2:44.52PM North America-ALASKA-BP Page 13 of 46 ,.. . � . . ,,. ,, .• ,, to a e•ort Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194 00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/12/2013 00:00 - 04:00 4.00 CEMT N CEMT 2,118.3 SURF PJSM FOR CEMENT JOB -AOGCC REP.JOHN CRISP-PRESENT FOR JOB cV -CIRCULATE 9.2 PPG MUD TO CLEAR THE 1-1/4"LINE 'cO\J -PUMPED 10 BBLS OF WATER AHEAD TO HEAT THE LINES,TAKING RETURNS TO THE "CUTTINGS TANK -PUMP 196 BBLS,15.7 PPG ARCTIC SET-1 CEMENT -PUMPED CEMENT AT 1 BPM,PRESSURE ' RANGE 90-100 PSI -FOR EVERY 1 BBLS CEMENT PUMPED,1 BBLS OF 9.2 PPG MUD RETURNED AT SURFACE FOR ENTIRE JOB -PUMPED 3 BBLS OF WATER BEHIND TO CLEAR THE HYDRIL PIPE -NO CEMENT TO SURFACE 04:00 - 05:00 1.00 CEMT N CEMT 2,118.3 SURF CEMENTERS FLUSHED THEIR LINES TO THE CUTTINGS TANK. -BLOW BACK TO THE CEMENTERS FROM THE RIG. 05:00 - 12:00 7.00 CEMT N CEMT 2,118.3 SURF WAIT ON CEMENT THICKENING TIME -ESTABLISH CIRCULATION EVERY -CLEAN TANK ROOM GENERAL HOUSEKEEPING -COMPLETE WORK ORDERS -INSPECT AND SERVICE ST-80 IRON ROUGHNECK -INSPECT AND SERVICE TOP DRIVE AND MUD PUMPS 12:00 - 16:00 4.00 CEMT. P 2,118.3 SURF NU CASING AND TUBING SPOOL TO WELLHEAD -PT LOWER SEALASSEMBLY PER FMC REP. (FAILED TEST) -ND SPOOLS,REDRESS SEAL AREA, CONTINUE TO ESTABLISH CIRCULATION. 16:00 - 18:00 2.00 CEMT P 2,118.3 SURF NU CASING AND TUBING SPOOL TO WELLHEAD -NU 2'AND 14'HIGH PRESSURE RISER SPOOL -RETEST WELLHEAD SEAL ASSEMBLY -1000 PSI FOR 15 CHARTED MIN(FAILED) -PLAN TO NU BOP STACKAND RETEST 18:00 - 21:00 3.00 CEMT N CEMT 2,118.3 SURF ESTABLISH CIRCULATION EVERY HOUR W/1- BBL PUMPED -COMPLETE WORK ORDERS -C/O MIX PUMP#2 21:00 - 00:00 3.00 CEMT N CEMT 2,118.3 SURF PUMP SECOND TOP JOB TO SURFACE - -HOLD PJSM W/SLB,WSL,DDI -PUMP 5 BBLS H2O 'UV -PT CEMENTING LINES -1200 PSI(GOOD) �b -PUMP 255 BBLS,10.7 PPG ARCTIC SET LITE_ J CEMENT -2.5 BPM,250 PSI -PUMP 212 BBLS 15.7 PPG ARCTIC SET-1 -2.5 BPM,400 PSI -100%RETURNS- 467 BBLS OF CEMENT PUMPED,467 BBLS 9.2 PPG MUD RETURNED TO SURFACE -NO INDICATIONS OF CEMENT AT SURFACE Printed 3/4/2013 2:44:52PM forth America-ALASKA-BP Page 14 of 46 Operation Su Et.z Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI Active datum Z-61 Actual©96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/13/2013 00:00 - 06:00 6.00 CEMT N CEMT 2,118.3 SURF BLOW DOWN AND RIG DOWN CEMENTING UNIT. PERIODICALLY ESTABLISH CIRCULATION -1BBLS VOLUME EVERY HOUR 06:00 - 08:00 2.00 CEMT N CEMT 2,118.3 SURF PERIODICALLY ESTABLISH CIRCULATION EVERY HOUR WITH CHARGE PUMP. - <1 BBL PUMPED GENERAL HOUSE KEEPING AROUND THE RIG. 08:00 - 11:00 3.00 CEMT P SURF NU BOP STACK,INSTALL FLOW NIPPLE, FLOW LINE,&FLOW BOX.RU CHOKE AND KILL LINES. PHASE III WEATHER CONDITION CALLED AT 09:45-HRS. 11:00 - 00:00 13.00 CEMT N WAIT 2,118.3 SURF ESTABLISH CIRCULATION THROUGH 1-1/4" PIPE WITH CHARGE PUMP. -<1 BBL EVERY HOUR -GENERAL RIG MAINTENANCE AND CLEANING PHASE III WEATHER CONDITIONS CALLED -EMERGENCY TRAVEL ONLY. REFERENCE BP PHASE WEATHER/ROAD CONDITIONS OPERATING PROCEDURES FOR JOURNEY MANAGEMENT PLAN FOR ALL TRAVEL INCLUDING LEADERSHIP AND CREW CHANGEOUT. 1/14/2013 00:00 - 12:00 12.00 CEMT N WAIT 2,118.3 SURF ESTABLISH CIRCULATION THROUGH 1-1/4" PIPE —1BBLEVERY HOUR -GENERAL RIG MAINTENANCE AND CLEANING PHASE III WEATHER CONDITIONS CONTINUE. -EMERGENCY TRAVEL ONLY. REFERENCE BP PHASE WEATHER/ROAD CONDITIONS OPERATING PROCEDURES FOR JOURNEY MANAGEMENT PLAN FOR ALL TRAVEL INCLUDING LEADERSHIP AND CREW CHANGEOUT. MANAGING CREW CHANGES WITH JOURNEY MANAGEMENT PLANS AND COORDINATION THROUGH AK,HSSEE H&S ADV D&C(DRILLING)AND IMT. ALL NON-ESSENTIAL RIG PERSONNEL STAGED IN RIG CAMP. Printed 3/4/2013 2:44:52PM • • North America-ALASKA-BP Page 1501 461 Operation Summary Report , Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 00:00 12 00 CEMT N WAIT 2,118.3 SURF ESTABLISH CIRCULATION THROUGH 1-1/4" PIPE 1BBL EVERY HOUR -GENERAL RIG MAINTENANCE AND CLEANING PHASE III WEATHER CONDITIONS CONTINUE. -EMERGENCY TRAVEL ONLY. REFERENCE BP PHASE WEATHER/ROAD CONDITIONS OPERATING PROCEDURES FOR JOURNEY MANAGEMENT PLAN FOR ALL TRAVEL INCLUDING LEADERSHIP AND CREW CHANGEOUT. MANAGING CREW CHANGES WITH JOURNEY MANAGEMENT PLANS AND COORDINATION THROUGH AK,HSSEE H&S ADV D&C(DRILLING)AND IMT. ALL NON-ESSENTIAL RIG PERSONNEL STAGED AT RIG CAMP AT MOBIL PAD. IMT IMPOSED LOCKDOWN ON FURTHER CREW CHANGES AT 17:00-HRS.PENDING IMPROVEMENT IN WEATHER CONDITIONS. DAY RIG SUPPORT CREWAND RIG LEADERSHIP TEAM STUCK AT RIG UNTIL 1/15/2013 00 00 - 07:00 7.00 CEMT N WAIT 2,118.3 SURF ESTABLISH CIRCULATION THROUGH 1-1/4" PIPE 1BBL EVERY HOUR -GENERAL RIG MAINTENANCE AND CLEANING PHASE III WEATHER CONDITIONS CONTINUE. -EMERGENCY TRAVEL ONLY. REFERENCE BP PHASE WEATHER/ROAD CONDITIONS OPERATING PROCEDURES FOR JOURNEY MANAGEMENT PLAN FOR ALL TRAVEL INCLUDING LEADERSHIP AND CREW CHANGE OUT. MANAGING CREW CHANGES WITH JOURNEY MANAGEMENT PLANS AND COORDINATION THROUGH AK,HSE H&SADV D&C(DRILLING)AND IMT. ALL NON-ESSENTIAL RIG PERSONNEL STAGED AT RIG CAMP AT MOBIL PAD. IMT IMPOSED LOCK DOWN ON FURTHER CREW CHANGES AT 17:00-HRS.ON 1/14/2013 PENDING IMPROVEMENT IN WEATHER CONDITIONS. DAY RIG SUPPORT CREWAND RIG LEADERSHIP TEAM STUCK AT RIG ALL NIGHT. 07:00 - 10:30 3.50 CEMT N WAIT 2,118.3 SURF WEATHER CONDITIONS LOVVERED TO PHASE 2 -CLEAN OUT DRIFTS AROUND THE RIG -DIG OUT TRUCKS AND FUEL STATIONS ESTABLISH CIRCULATION THROUGH 1-1/4" PIPE 1BBL EVERY HOUR Printed 3/4/2013 2:44:52PM • • North America-ALASKA-BP Page 1s of 46" *oration Summary Repo .. • ;; n- w Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 17:30 7.00 CEMT P SURF RU TEST EQUIPMENT FOR INITIAL BOPE TESTING TEST BOPE.TESTED ANNULAR AND RAMS TO 250 PSI LOW/3500 PSI HIGH FOR 5 MIN EACH.TEST 4"&5"DP.ALL TESTS CHARTED. SEE BOP TEST ATTACHMENTS. PERFORMED ACCUMULATOR TEST:SYSTEM PRESSURE 3075 PSI. MANIFOLD PRESSURE 1,500-PSI. PRESSURE AFTER CLOSING ALL RAMS AND ANNULAR PREVENTER 1,600 PSI. RECOVERED 1ST 200 PSI-19 SECONDS. FULL RECOVERY IN 92 SECONDS. AVERAGE PRESSURE 6 NITROGEN BOTTLES= 2133-PSI. AOGCC BOB NOBLE WAVED WITNESS TO BOPE TEST. 17:30 - 19:00 1.50 CEMT P SURF RIG DOWN TESTING EQUIPMENT -BLOW DOWN CHOKE AND KILL LINES -PULL TEST PLUG -INSTALL WEAR RING 12.375 ID -INSTALL STRIP-O-MATIC 19:00 - 00:00 5.00 CEMI P SURF PICK UP AND MAKE UP BHA#5,12-1/4" DRILLING BHA,RIH -12.25"MILL TOOTH BIT -MUD MOTOR -ARC8 TOOL,GA/RES/PWD -MWD-TELESCOPE -NMDC -JARS -HWDP -5'DP -RIH TO 835'AND PERFORM SHALLOW HOLE TEST-GOOD TEST 1/16/2013 00:00 - 01:00 1.00 CEMT P SURF PICK UP AND MAKE UP BHA#5.12-1/4" DRILLING BHA -12.25"MILL TOOTH BIT • -MUD MOTOR -ARC8 TOOL,Gr/RES/PWD -MWD-TELESCOPE -NMDC -JARS -HWDP -5'DP -RIH TO 835'AND PERFORM SHALLOW HOLE TEST-GOOD TEST 01:00 - 02:30 1.50 CEMT P SURF RIH WTH BHA#5 ON 5"DP -RIH TO—2000' -CEMENTERS ON LOCATION©01:30, RIGGING UP 02:30 - 03:00 0.50 CEMT P SURF CIRCULATE TWO SURFACE TO SURFACE -10-14 BPM,WITH 1025 PSI -CONTINUE RIGGING UP CEMENTERS -BLOWAIR TO MAKE SURE LINES TO CEMENTERS ARE CLEAR Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 17 of 46 Opera i• . 11. ry Report, Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release 2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.Oft(above Mean Sea Level) r-� Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) - 03:00 - 07:30 4.50 CEMT N CEMT 2,118.3 SURF PJSM FOR PUMPING TOP OUT CEMENT JOB PUMP TOP OUT CEMENT JOB#3 -PUMP 5 BBLS H2O TO HEAT LINES TAKING RETURNS TO CUTTINGS TANK -BATCHING 15.8 PPG CLASS G CEMENT -PT CEMENTING LINES -1200 PSI(GOOD) -PUMP 476 BBLS,15.8 PPG,1.16 CUFT/SK, "G"CLASS CEMENT,2304 SAC_KS -2.5-3 BPM,650-1000 PSI -83 BBLS RETURNED TO SURFACE 07:30 - 08:30 1.00 CEMT N CEMT 2,118.3 SURF FLUSH SURFACE LINES WITH BLACK WATER PILLAND FRESH H2O -BLOW DOWN LINES CLEAN VALVES AND SENSORS IN CEMENT MANIFOLDS -MONITOR SLIGHT FLOW BACK AT CONDUCTOR ROUGHLY 25 BPH TO START DROPPING OFF TO 1/4 BPH SIX HOURS LATER 08:30 - 17:30 9.00 CEMT P SURF PJSM FOR SLIPPING NEW DRILL LINE -SLIP ON 1900'OF NEW DRILL LINE -BLOW DOWN TOP DRIVE,CALIBRATE BLOCKS -ESTABLISH CIRCULATION THROUGH THE 5" DRILL STING AT 1970'MD -3 BPM WITH 220 PSI -MAINTIAIN CIRCULATION THROUGH THE 1-1/4"CEMENT LINE EVERY HOUR 17:30 - 00:00 6.50 CEMT N - CEMT 2,118.3. SURF PJSM FOR PUMPING TOP OUT CEMENT JOB PUMP TOP OUT CEMENT JOB#4 -PUMP 5 BBLS H2O TO HEAT LINES TAKING RETURNS TO CUTTINGS TANK -BATCHING 15.8 PPG CLASS G CEMENT -PT CEMENTING LINES -1200 PSI(GOOD) _PUMP 448 BBLS,15.8 PPG,1.16 CUFT/SK, "G"CLASS CEMENT,2168 SACKS -PUMPING AT 1 BPM,450 PSI -84 BBLS RETURNED TO SURFACE DURING CEMENT JOB 1/17/2013 00:00 - 01:30 1.50 CEMT N CEMT 2,118.3 SURF FLUSH SURFACE LINES WITH BLACK WATER PILLAND FRESH H2O -BLOW DOWN LINES -CLEAN VALVES AND SENSORS IN CEMENT MANIFOLDS -MONITOR SLIGHT FLOW BACK AT CONDUCTOR ROUGHLY 12 BPH TO START TAPERING OFF QUICKLY. 01:30 - 02:30 1.00 CEMT N CEMT 2,118.3 SURF ESTABLISH CIRCULATION THROUGH THE 1-1/4"PIPE -PREP CELLAR FOR THE WELDER TO CUT NEW HOLE IN THE CELLAR. -INITIATE HOT WORK PERMIT FOR CUTTING NEW HOLE IN CONDUCTOR -CUT 5"BY 20"HOLE TO RUN SECOND 1-1/4" TOP OUT LINE Printed 3/4/2013 2:44:52PM Page 19 of 46 North America-ALASKA-BP Ope.,, .. n mmary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 09:30 7.00 CEMT N CEMT 2,118.3 SURF LOAD 1-1/4'PIPE&HANDLING EQUIPMENT TO THE RIG FLOOR -RIG UP AND RUN IN THE HOLE WITH PIPE, WASHING DOWN BELOW THE CONDUCTOR AT 80' -RAN THE 1-1/4"TO REFUSAL AT 87' -RU 1502 CONNECTION TO THE 1-1/4"IN THE CELLAR TO PUMP CEMENT. -LOADING MORE CEMENT IN THE SILOS. -BLOWAIR TO THE CEMENTERS TO VERIFY CLEAR LINE. -SLB THAWING A FROZEN VALVE. -PRIMING PUMPS AND START BATCHING CEMENT 09:30 - 11:30 2.00 CEMT N CEMT 2,118.3 SURF PJSM FOR PUMPING TOP OUT CEMENT JOB PUMP TOP OUT CEMENT JOB#5 -PUMP 5 BBLS H2O TO HEAT LINES TAKING RETURNS TO CUTTINGS TANK -BATCHING 15.PPG AS1 -PT CEMENTING LINES -1200 PSI(GOOD) -PUMP 100 BBLS,15.7 PPG,.93 CUFT/SK, AS1 CEMENT,604 SACKS -PUMPING AT 1 BPM,45 PSI,GOT CEMENT TO SURFACE -SAW 15.0 PPG CEMENT 40 BBLS INTO PUMPING,GOT 15.7 WITH 50 BBLS PUMPED -LOST 10 BBLS 11:30 - 13:30 2.00 CEMT N CEMT 2,118.3 SURF FLUSH SURFACE LINES WITH BLACK WATER PILL AND FRESH H2O -BLOW DOWN LINES -CLEAN VALVES AND SENSORS IN CEMENT MANIFOLDS -MONITOR SLIGHT FLOW BACK AT CONDUCTOR.2.5 BBLS TOTAL OVER 6 HOURS. 1.5 BBLS OF CEMENTAND 1 BBL OF WATER. 13:30 - 15:30 2.00 CEMT N CEMT 2,118.3 SURF PULL AND LAY DOWN THE SECOND STRING OF 1-1/4"HYDRIL PIPE,LD HANDLING EQPT -ATTEMPT TO FLUSH LINES WITH TEST PUMP-FAILED 15:30 - 16:00 0.50 CEMT N CEMT 2,118.3 SURF RECIPROCATE DRILL STRING AND CIRCULATE -650 GPM,1100 PSI -PUW-118K,SOW-111K 16:00 - 17:30 1.50 CEMT P SURF BLOW DOWN TOP DRIVE&RIG UP TEST EQUIPMENT -PRESSURE TEST 13-3/8"r:ASINS -250 PSI LOW FOR 5 MIN,3500 PSI HIGH FOR 30 MIN,CHARTED -CRT-AK-10-45 PRESSURE TESTING GUIDELINES. TEST CONFIRMED WITH WELLBORE INTEGRITY TESTING CALCULATOR,TEST RESULTS FORWARDED TO ROTARY WTL FOR ATP. -AUTHORIZATION GRANTED. Printed 3/4/2013 2:44:52PM 110 North America-ALASKA-BP Page 19 of 46 Operation Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 20:00 2.50 CEMT P SURF OBTAIN SPR'S AND DRILLING PARAMETERS PER SLB MWD -DRILL OUT CEMENT&FLOAT EQUIPMENT FROM F/2,020'TO 2,098' -20 RPM'S,5 K WOB,6K TQ -PUW-128K.SOW-122K,ROT-116K TAG FLOAT COLLAR ON DEPTH SPR'S @ 1974'MD,1910'TVD-MW=9.2 PPG, TIME=18:00 #1 MP-20/30 SPM=220/330 PSI #2 MP-20/30 SPM=200/280 PSI 20:00 - 21:00 1.00 CEMT P SURF DISPLACE WELL TO 9.2 PPG LSND MUD -700 GPM,924 PSI -20 RPM,7K TQ -CLEAN OUT UNDER SHAKERS 21:00 - 22:30 1.50 CEMT P SURF CONTINUE DRILLING SHOE TRACK FROM 2,098'MD TO 2119'MD&20'OF NEW FORMATION TO 2140'MD -P/U=128K,S/O=125K,ROT=116K -650 GPM,924 PSI -50 RPM,10-11K TQ ON,6-8K TQ OFF -WOB 12-25K -ADT=.15,ART=0,AST=.15,TOTAL BIT HOURS=.15,TOTAL JAR HOURS=25.1 SPR'S @ 2100'MD,2020'ND-MW=9.2 PPG, TIME=20:30 #1 MP-20/30 SPM=140/180 PSI #2 MP-20/30 SPM=120/140 PSI 22:30 - 23:30 1.00 CEMT P SURF CIRCULATE BOTTOMS UP MW9.2IN/ 9.2 OUT -OBTAIN CLEAN HOLE ECD @ 800 GPM,1520 PSI=9.56 PPG -MONITOR WELL FOR 10 MIN,WELL STATIC 23:30 - 00:00 0.50 DRILL P INTI PULL UP INTO THE 13-3/8"CASING AND PERFORM FIT PERFORM FIT AT 2140"MD,2031'TVD -MW 9.2 PPG -FIRST ATTEMPT FOR FIT WAS PUMPED AT 1/4 BPM WHICH GAVE US A 10.3 EMW. -TALKED TO THE ODE AND DECIDED TO PERFORM ANOTHER TEST PUMPING AT 1/2 BPM.PER ADW SOP FOR LOT/FIT -SI,ICCESSFULL FIT TO 380 PSI, 12.8 PPG EMW,PUMPING AT 1/2 BPM - APPROVAL TO PROCEED-12.8 PPG EMW LEAK OFF PRESSURE -ODE APPROVAL TO CONTINUE OPERATIONS WITH A GREATER THAN 50 BBL KICK TOLERANCE 1/18/2013 00:00 - 01:00 1.00 DRILL P INTI MONITOR PRESSURE AFTER FIT RIGGING DOWN TESTING EQUIPMENT Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 20 of 46 C-)139 ' •.� r Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 12:00 11.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 2,139'MD TO 2921'MD,2610'TVD -750 GPM,1400 PSI ON/1350 PSI OFF -MW 9.3 IN/9.3 OUT,ECD=9.66 PPG -40 RPM,7K TQ -15-25K WOB -P/U=157K,S/O=145K,ROT=153K AST=2.44,ART=1.11,ADT=3.55,TOTAL BIT HOURS=3.7,TOTAL JAR HOURS 28.5 SPR'S @ 2631 MD,2441'TVD-MW=9.3 PPG, TIME=08:30 #1 MP-20/30 SPM=100/120 PSI #2 MP-20/30 SPM=90/110 PSI OBSERVED HYDRATES-2400'MD 2,270' 12:00 - 00:00 12.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 2,921'MD 2610'tvd TO 4,279'MD 3,239'tvd -900 GPM,2100 PSI ON/1940 PSI OFF MW 9.3 IN/9.3OUT,ECD=9.89 PPG -40 RPM,12K TQ ON,8K TQ OFF -15-25K WOB -P/U=165K,S/O=105K,ROT=126K AST=1.41,ART=4.31,ADT=5.72,TOTAL BIT HOURS=9.42,TOTAL JAR HOURS 34.6 SPR'S @ 3667'MD,2957'ND-MW=9.3 PPG, TIME=18:30 #1 MP-20/30 SPM=100/120 PSI #2 MP-20/30 SPM=80/100 PSI SPR'S @ 4246'MD,3234'TVD-MW=9.3 PPG, TIME=21:25 #1 MP-20/30 SPM=100/130 PSI #2 MP-20/30 SPM=100/120 PSI 1/19/2013 00.00 - 07:30 7.50 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 4,279'MD 3,239'ND TO TD OF 4,889'MD 3,507'ND -900 GPM,2100 PSI ON/1940 PSI OFF -MW 9.2+IN/9.2+OUT,ECD=9.82 PPG -40-100 RPM,10-15 K TQ ON,8K TQ OFF -15-25K WOB -P/U=177K,S/O=106K,ROT=132K - AST=1.65,ART=1.48,ADT=3.13,TOTAL BIT HOURS=12.55,TOTAL JAR HOURS 37.4 SPR'S @ 4,889'MD,3,507'ND-MW=9.2 PPG,TIME=08:36 #1 MP-20/30 SPM=80/100 PSI #2 MP-20/30 SPM=80/100 PSI 07:30 - 09:30 2.00 DRILL P INTI CIRCULATE HOLE CLEAN WHILE RECIPROCATING PIPE -CIRCULATE 2.5 BOTTOMS UP -900 GPM,2000 PSI. -PUMPED HIGH VIS SWEEP WITH NUT PLUG MONITOR WELL PRIOR TO PULLING OFF BOTTOM-WELL STATIC Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 21 of 46 .. Operation, mmary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 I End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud DateTme:1/2/2013 12:00:00AM Rig Release 2/15/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-61 Actual©96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 15:00 5.50 DRILL P INTI POOH ON ELEVATORS F/4,889'MD TO 3776' MD -PULLED TIGHT FROM 3,776'TO 3,300',35-45 K OVERPULL,WIPING EACH STAND -PUMPED OUT OF THE HOLE F/3300'TO 2,160' AT THE 13-3/8"SHOE PUW-125K,SOW-112K 15:00 - 15:30 0.50 DRILL P INTI ROTATE AND RECIPROCATE WHILE PUMPING SURF TO SURF -CIRCULATE THE 13-3/8"CASING WITH 800 GPM,1325 PSI -80 RPM,4K TQ OFF.PUW-137K,SOW-108K, 115K 15:30 - 20:00 4.50 DRILL P INTI RIH F/2,160'MD TO 2202'MD -TAKING WT AT 2,202',40K DOWN -ATTEMPTED TO ORIENTATE AND SLIDE THROUGH WITH PUMPS OFF -ATTEMPT TO ORIENTATE WITH LOW PUMP RATE,NOTABLE TO GET BACK INTO ORIGINAL 12-25"HOLE. -PULLED UP HOLE TO RETAKE SURVEYS F/ 2,140'AND 2,158' SURVEY DIFFERENCES AT 2,150'SHOW THIS IS WHERE SIDE OCCURRED. SLB CONFIRMED THIS WITH THEIR TOWN ENGINEERS. NOTIFIED TOWN ODE OF SIDETRACK OPERATIONS. ACCIDENTAL SIDE TRACK-END OF(PB1) WELL BORE-SEE CONTINUATION OF DAILY REPORT ON ORIGINAL WELL BORE. 20:00 - 21:00 1.00 DRILL N DPRB 2,149.3 INTI START OPEN HOLE SIDE TRACK -DRILL 12.25"SIDETRACK FROM 2,150'TO 2,351' -SLIDE AND ROTATE TO 2,351' -900 GPM,2100 PSI ON/1940 PSI OFF -MW 9.2+IN/9.2+OUT, -40 RPM,10-15 KTQ ON,8K TQ OFF -15-25K WOB -P/U=177K,S/O=106K,ROT=132K 21:00 - 22:00 1.00 DRILL N DPRB 2,149.3 INTI PULL BACK UP TO GET NEW LOG STARTING THE SIDETRACK -LOG DOWN FROM 2,180'TO MD TO 2,350', NO PUMPS&NO ROTATION 22:00 - 00:00 2.00 DRILL N DPRB 2,149.3 INTI -DRILL 12.25"OH SIDETRACK FROM 2,150' MD 2067'TO 2510'MD 2,366" -750 GPM,1390 PSI ON/1300 PSI OFF -MW 9.2+IN/9.2+OUT, -40 RPM,10-15 K TQ ON,8K TQ OFF -15-25K WOB -P/U=127K,S/O=120K,ROT=127K - AST=1.67,ART=.67,ADT=2.39,TOTAL BIT HOURS=14.94,TOTAL JAR HOURS 39.9 SPR'S @ 2346'MD,2235'TVD-MW=9.3 PPG, TIME=20:00 #1 MP-20/30 SPM=115/120 PSI #2 MP-20/30 SPM=80/100 PSI Printed 3/4/2013 2:44:52PM • North America-ALASKA-BP Page 22 of 46 Operation Summa R.e•ort Common Wlell Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) ✓ 1/20/2013 00:00 - 12:00 12.00 DRILL N DPRB 2,149.3 INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 2,510'MD 2,366'ND TO 3,772'MD 2,990'ND -800-900 GPM,1650-2100 PSI ON/1500-1850 PSI OFF -MW 9.35 IN/9.35 OUT,ECD=9.98 PPG -40-100 RPM,7-8 K TQ ON,6K TQ OFF -15-30-K WOB P/U=136K,S/O=122K,ROT=121K - AST=1.36,ART=3.75,ADT=5.11,TOTAL BIT HOURS=20.0,TOTAL JAR HOURS 44.9 SPR'S @ 2,824'MD,2,559'ND-MW=9.4 PPG,TIME=03:50 #1 MP-20/30 SPM=100/110 PSI #2 MP-20/30 SPM=100/120 PSI. SPR'S @ 3488'MD,2,858'ND-MW=9.35 PPG,TIME=09:40 #1 MP-20/30 SPM=100/110 PSI #2 MP-20/30-SPM=100/120 PSI TOP OF THE SV1 AT 3,222' -SEEING GAS HYDRATES BREAK OUT FROM 1500 UNITS WITH A PEAK OF 9500 UNITS WHILE DRILLING THROUGH THE SV1. CIRCULATING WITH THE DEGASSER WHILE DRILLING MAINTAINING MW FROM 9.2 PPG TO 9.4 PPG 12:00 - 15:30 3.50 DRILL N DPRB 2,149.3 INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 3,772'MD 2,990'ND TO 3,865'MD -800-900 GPM,1650-2100 PSI ON/1500-1850 PSI OFF -MW 9.35 IN/9.35 OUT,ECD=9.98 PPG -40-100 RPM,7-8 K TQ ON,6K TQ OFF -15-30-K WOB 15:30 - 16:00 0.50 DRILL N RREP 2,149.3 INTI POOH FROM 3,865'MD TO 3,694' CHANGE OUT SWIVEL PACKING ON TOP DRIVE 16:00 - 00:00 8.00 DRILL N DPRB 2,149.3 INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 3,865'MD,3033'ND TO 4,719'MD 3,416'ND -800-900 GPM,1650-2100 PSI ON/1500-1850 PSI OFF -MW 9.35 IN/9.35 OUT,ECD=9.98 PPG -40-100 RPM,11-13 K TQ ON,8K TQ OFF -15-30-K WOB -P/U=174K,S/O=110K,ROT=134K - AST=2.20,ART=6.33,ADT=9.89,TOTAL BIT HOURS=24.83,TOTAL JAR HOURS 49.7 -PUMPED 25 BBL HI VIS SWEEP W/NUT PLUG -TIGHT SPOT AT 4150',20K OVERPULL AND TQ INCREASE FROM 8K TO 11K SPR'S @ 3,960'MD,3,077'ND-MW=9.3 PPG,TIME=14:15 #1 MP-20/30 SPM=140/160 PSI #2 MP-20/30 SPM=140/160 PSI Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 23 of 46 Operation Summary Report 3 4 Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Daterme:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UW: Active datum Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/21/2013 00:00 - 02:00 2.00 DRILL N DPRB 2,149.3 INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 4,719'MD 3,416'TVD TO TD 4906'MD 3,510' TVD -800-900 GPM,1650-2100 PSI ON/1500-1850 PSI OFF -MW 9.35 IN/9.35 OUT,ECD=9.78 PPG -40-100 RPM,11-13 K TQ ON,8K TO OFF -15-30-K WOB -P/U=174K,S/O=110K,ROT=134K - AST=.89,ART=.29,ADT=1.18,TOTAL BIT HOURS=26.0,TOTAL JAR HOURS 44.9 SPR'S @ 4,906'MD,3,506'ND-MW=9..25 PPG,TIME 02:30 #1 MP-20/30 SPM=100/120 PSI #2 MP-20/30 SPM=90/110 PSI. 02:00 - 04:00 2.00 DRILL N DPRB 2,149.3 INTI CIRCULATE HOLE CLEAN WHILE RECIPROCATING PIPE -CIRCULATE 3 BOTTOMS UP -900 GPM,2000 PSI,40-80 RPM,ECD-9.77 PPG -PUMPED HIGH VIS SWEEP WITH NUT PLUG -PUW-177,SOW-109,ROT-138 W/11-12 TO MONITOR WELL PRIOR TO PULLING OFF BOTTOM-WELL STATIC 04:00 - 07:00 3.00 DRILL N DPRB 2,149.3 INTI POOH ON ELEVATORS FOR SHORT TRIP FROM 4,906'MD,3,506'ND -WORKED TIGHT SPOTS AT 4,668', 4,627',4,612'&4,320'30-45K OVER PULL -WIPED EACH OF THESE SPOTS WITH ENTIRE STAND. -PULLED CONSITENTLY TIGHT AT FROM 3,900',SHOWED SIGNS OF SWABBBING AT 3700'. 07:00 - 12:00 5.00 DRILL N DPRB 2,149.3 INTI PUMPE OUT OF THE HOLE F/3700'MD TO TO 3,582' -PUMP OUT AT 212 GPM,300 PSI,STARTED PACKING OF -BACK REAM&PUMP OUT OF THE HOLE FROM 3582'TO 2069'40'IN THE 13-3/8"SHOE. -800 GPM,1500 PSI,10-18 TO,@ 80 RPM 12:00 - 13:00 1.00 DRILL P INTI CIRCULATE CASING CLEAN -800 GPM,1409 PSI,80 RPM,4K TQ, -P/U=122K,S/O=120K,ROT=121K 13:00 - 13:30 0.50 DRILL P INTI RIG SERVICE,GREASE SWIVEL PACKING ON TOP DRIVE BLOW DOWN TOP DRIVE 13:30 - 17:00 3.50 DRILL P INTI MONITOR WELL FOR TEN MIN-WELL STATIC -TIH ON ELEVATORS FROM 2,069'TO 4,316' -TAKING WEIGHT AT 4316'WITH 45K DOWN, PUMPED WITH 87 GPM AND 150 PSI TO WORK THROUGH TO 4,340' CONT RIH ON ELEVATORS F/4,340'MD TO TO 4,906'MD. -MONITORING TRIP FOR DISPLACEMENT -PUW-176,SOW-114 Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 24 of 46 Operation Su II 1,0 p,,; •• y a • • Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date 2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 21:00 4.00 DRILL P INTI CIRCULATE HOLE CLEAN AT TD 4,906'MD 3,506'TVD -ROTATE AND RECIPROCATE WHILE PUMPING 900 GPM,2130 PSI,100 RPM,12K TQ -PUMP 40 BBL HIGH VIS SWEEP WTH NUT PLUG,SWEEP BROUGHT BACK MARBLE AND PING PONG BALL SIZED CLAY BALLS, PUMPED A SECOND 40 BBL HIGH VIS SWEEP WITH NUT PLUG. -MW IN/OUT,9.3 PPG/9.4 PPG --'PUW-170,SOW-114,ROT-137 W/11-12 TQ 21 00 - 23:00 2.00 DRILL P INTI MONITOR THE WELL PRIOR TO PULLING OFF BOTTOM-WELL STATIC -POOH ON ELEVATORS FROM 4,906'(TD)TO THE 13-3/8"SHOE 2,109'MD NO OVER PULL SEEN FOR ENTIRE TRIP 23:00 - 00:00 1.00 DRILL P INTI CIRCULATED 13-3/8"CASING CLEAN 2,060' 800 GPM,1350 PSI,80 RPM -CIRCULATED TWO BOTTOMS UP.SAW VERY LITTLE SOLIDS OVER THE SHAKERS 1/22/2013 00:00 - 01:30 1.50 DRILL P INTI CIRCULATE 13-3/8"CASING CLEAN AT 2069' -000 GPM,1350 PSI,80 RPM -CIRC 2 BOTTOMS UP.SAW VERY LITTLE SOLIDS OVER THE SHAKERS -SHUT DOWN TO MONITOR THE WELL -GAS BREAKING OUT,MONITOR FOR 15 MIN. -CIRC BOTTOMS UP,MONITOR WELL-WELL STATIC NO GAS BREAK OUT. 01:30 - 03:00 1.50 DRILL P INTI POOH FROM 2,069'TO 837'MD' -MONITOR WELL PRIOR TO PULLING BHA ACROSS BOP STACK -WELL HAS SOME GAS BREAKING OUT AND DROPPING AT THE SAME TIME. -CONTACTED DAY WSL TO CONFIRM PLAN FORWARD WITH THE WELL CONDITION BEFORE LAYING DOWN BHA. 03:00 - 07:30 4.50 DRILL P INTI L/D 12.25"DRILLING BHA#5 -RACK BACK HWDP -BIT GRADE 5-7-WT-A-F-8-NO-TD 07:30 - 08:00 0.50 CASING P INTI CLEAN AND CLEAR RIG FLOOR -SEND OUT BHA#5 08:00 - 09:00 1.00 BOPSUR P INTI M/U STACK WASHER AND FLUSH STACK 09:00 - 09:30 0.50 BOPSUR P INTI DRAIN STACK AND PULL WEAR BUSHING 09:30 - 10:30 1.00 BOPSUR P INTI C/O UPPER RAMS TO 9-5/8"FIXED RAMS 10:30 - 12:00 1.50 BOPSUR P INTI TEST 9-5/8"RAMS TO 250 LOW/3500 HIGH FOR 5/5 MIN EACH -R/D TEST EQUIPMENT 12:00 - 14:00 2.00 CASING P INTI M/U 9-5/8"LINER HANGER/PACKER AND STAND BACK IN DERRICK 14:00 - 15:00 1.00 CASING P INTI M/U SINGLE AND PUP TO CEMENT HEAD -STAGE IN PIPESHED 15:00 - 16:00 1.00 CASING P INTI R/U TO RUN 9-5/8"LINER 16:00 - 16:30 0.50 CASING P INTI PJSM FOR RUNNING LINER -M/U 9-5/8"SHOE TRACK TO 126' -FILL LINER AND VERIFY FLOATS HOLDING. FLOATS GOOD -BAKER LOCK ALL BTC CONNECTIONS BELOW LANDING COLLAR JOINT Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 25 of 46 Operation Su Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date 12/29/2012 End Date 2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 20:30 4.00 CASING P INTI RUN 9-5/8"LINER ASSEMBLY PER PROGRAM -M/U 9-5/8",40 LB-FT BTC LINER,APPLY BEST-O-LIFE 2000NM.M/U BTC CONNECTIONS TO MARK. -MW 9.4 IN/9.4 OUT RUN 9-5/8"LINER TO 2,070'MD -FILL EVERY JOINT TOP OFF EVERY 10 JOINTS LOSSES AT 1 BPH 20:30 - 21:30 1.00 CASING P INTI CIRC 1.5X LINER VOL AT 13-3/8"SHOE -10 BPM,108 PSI 21:30 - 22:30 1.00 CASING P INTI CONT RUNNING 9-5/8"LINER FROM 2,070'TO 2,873'MD -FILL EVERY JOINT -TOP OFF EVERY 10 JOINTS 22:30 - 23:00 0.50 CASING : P INTI M/U LINER HANGER/LINER TOP PACKER ASSEMBLY TO 9-5/8"LINER 23:00 - 00:00 1.00 CASING P INTI RUN 9-5/8"LINER ON 5"DRILLPIPE FROM 2,949'TO 3,549'MD 1/23/2013 00:00 - 02:30 2.50 CASING P INT1 CONT TO RUN 9-5/8"LINER ON 5"DRILLPIPE FROM 3,549'TO 4,876'MD CIRC EVERY 10 STANDS AT 3 BPM FOR 5 MIN 02:30 - 03:00 0.50 CASING P INTI M/U CEMENT HEAD AND TAG LINER ON DEPTH AT 4,906'MD 03:00 - 05:30 2.50 CASING P INTI CIRC 2 BOTTOMS UP AND CONDITION MUD PU 197K,SO 113K -STAGE PUMPS TO 7 BPM,335 PSI Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 26 of 46 • Operation Summary Report . :. av Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194 00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:30 - 09:30 4.00 CEMT P INTI CEMENT 9-5/8"LINER AS FOLLOWS: HOLD PJSM WITH SLB CEMENTERS,DDI RIG CREW,BP,BAKER CEMENT PUMPING: -PRESSURE TEST LINES TO 250 LOW/4500 HIGH FOR 5 MIN EACH. GOOD TEST PUMP 65 BBLS 10.5 PPG MUD PUSH II AT 5.5 BPM PUMP 101 BBLS,12.0 PPG LITECRETE LEAD CEMENT AT 4.2 BPM INITIAL,5.5 BPM FINAL, YIELD 1.64 CU FT/SX(346 SX) -PUMP 189 BBLS,15.9 PPG CLASS G CEMENT AT 4.6 BPM INITIAL,3.0 BPM FINAL, YIELD 1.17 CU FT/SX(911 SX) -DROP DRILL PIPE WIPER DART.POSITIVE INDICATION DART LEFT CEMENT HEAD. -RECIPROCATE IN 15'STROKES UNTIL LWP LATCH UP -DISPLACE WITH SLB 7 BPM,100 PSI -25 BELS AWAY:REDUCE RATE TO 3 BPM -33 BBLS AWAY:LATCH UP WIPER PLUG WITH 1600 PSI -DISPLACE AT7 BPM,PRESSURE STEADILY INCREASING TO 850 PSI -240 BBLS AWAY:SLOW PUMP TO 2 BPM,600 PSI PRIOR TO BUMP -BUMP PLUG AT 249 BBLS(ON CALCULATED DISPLACEMENT) -INCREASE PSI TO 2300 PSI TO SET HANGER -S/O 50K TO CONFIRM HANGER SET -INCREASE PRESSURE TO 4000 PSI TO SET LINER TOP PACKER AND RELEASE RUNNING TOOL WITH PUSHER TOOL -BLEED OFF PRESSURE&CHECK FLOATS. FLOATS HOLDING. -CEMENT IN PLACE AT 9:15 HRS -NO LOSSES WHILE PUMPING CEMENT _-GOOD LIFT PRESSURE THROUGHOUT JOB 09:30 - 10:00 0.50 CEMT P INTI BLOW DOWN CEMENT LINES AND SLB. R/D CEMENT HOSE 10:00 - 11:00 1.00 CEMT P INTI SWAP TO RIG PUMPS AND CIRC OUT EXCESS CEMENT -PRESSURE UP TO 500 PSI AND P/U TO VERIFY RELEASE(PSI DROPPED @ 16'UP) -CONT TO P/U 30'AND CIRC BOTTOMS UP AT 10 BPM -5 BBLS CEMENT BACK TO SURFACE OVER LAST 50 BBLS OF CIRCULATION 11:00 - 11:30 0.50 CEMT P INTI UD CEMENT HEAD.POOH TO 1870',MONITOR WELL 11:30 - 12:00 0.50 CEMT P INTI CIRC AND CONDITION MUD FOR LOGGING RUN -6 BPM,100 PSI 12:00 - 14:00 2.00 CEMT P INTI POOH ON ELEVATORS FROM 1870'TO SURFACE 14:00 - 14:30 0.50 CEMT P INTI UD 9 5/8"LINER RUNNING TOOL AS PER BAKER REP 14:30 - 15:00 0.50 CEMT P INTI M/U STACK WASHER AND FLUSH STACK 15:00 - 15:30 0.50 CEMT P INTI R/D CEMENT HEAD Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 27 of 46 •eration Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 IX3-0130L-C:DRILL(11,611,194 00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/me:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 - 16:00 0.50 CASING C SURF PJSM FOR RUNNING WIRELINE -SLB WIRELINE CREW,DDI RIG CREW,BP WSL 16:00 - 18:00 2.00 CASING C SURF M/U E-LINE CBLNDL LOGGING ASSEMBLY 18:00 - 18:30 0.50 CASING X SFAL SURF TROUBLESHOOT FROZEN ENCODER ON E-LINE UNIT 18:30 - 23:00 4.50 CASING C SURF RIH WITH SLB CBL-VDL E-LINE. -2 LOGGING RUNS THROUGH SURFACE CASING • 23:00 - 00:00 1.00 CASING C SURF UD AND R/D SLB E-LINE 1/24/2013 00:00 - 01:00 1.00 BOPSUR P INTI CHANGE UPPER RAMS TO 2-7/8"X 5-1/2" VBR'S 01:00 - 03:00 2.00 BOPSUR P INTI R/U TO TEST BOPE 03:00 - 08:30 5.50 BOPSUR P INTI TEST BOPE TO 250 LOW/3500 HIGH FOR 5 MIN EACH WITH 4"AND 5"TEST JOINTS.ALL TESTS CHARTED.SEE BOP TEST ATTACHMENT. 08:30 - 09:30 1.00 BOPSUR P INTI R/D BOPE TEST EQUIPMENT 09:30 - 10:00 0.50 CASING - N RREP INTI DISCOVERED KELLY HOSE FROZEN REMOVE KELLY HOSE FOR TOPDRIVE TO THAW 10:00 - 11:30 1.50 CASING P INTI R/U AND TEST 13 3/8"CASING&9 5/8"LINER FOR 250 LOW/3500 HIGH FOR 5/30 MIN GOOD TEST R/D TEST EQUIP WTL APPROVED TO PROCEED OPERATIONS 11:30 - 20:00 8.50 CASING N RREP INTI CONTINUE TO THAW KELLY HOSE THAW 30'ICE PLUG IN KELLY HOSE THAW GOOSENECK ON TOP OF STANDPIPE CONFIRM STANDPIPE IS CLEAR(GOOD) _ 20:00 - 22:00 2.00 CASING N . RREP INTI HANG KELLY HOSE B/D TO ENSURE LINE IS CLEAR 22:00 - 00:00 2.00 CASING P INTI M/U 8 3/4"DRILLING BHA#6 TO 116' 1/25/2013 00:00 - 01:30 1.50 CASING P INTI CONTINUE M/U 8-3/4"INTERMEDIATE DRILLING BHA#6 TO 852' 01:30 - 02:30 1 1.00 CASING P INTI MUD COMING BACK VERY THICK WITH LARGE CHUNKS OF CONTAMINATED CEMENT -STAGE PUMPS UP TO 400 GPM,360 PSI -CIRCULATE AND CONDITION MUD 02:30 - 03:00 0.50 CASING P INTI SHALLOW HOLE TEST MWD -550 GPM,1150 PSI 03:00 - 04:30 1.50 CASING P INTI RIH ON 4"DOUBLES FROM THE PIPESHED FROM 852'TO 1,800'MD 04:30 - 06:00 1.50 CASING P INTI CIRCULATE AND CONDITION MUD -550 GPM,1280 PSI -CIRC OUT THICK,CEMENT CONTAMINATED MUD IN WELL 1 06:00 - 07:30 1.50 CASING P INTI CONT RIH ON 4"DOUBLES FROM 1,800'TO 2,750'MD 07:30 - 09:00 1.50 CASING P INTI CIRC AND CONDITION MUD -580 GPM,1800 PSI -MINIMAL SIGNS OF CEMENT CONTAMINATED MUD 09:00 - 10:30 ' 1.50 CASING P INTI CONT RIH ON 4"DOUBLES FROM 2,750'TO 3,700'MD Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 28 of 46 ;. �,. ,z. �.eration Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date.2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UW: Active datum:Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 11:00 0.50 CASING P INTI CIRC AND CONDITION MUD -582 GPM,1975 PSI -MINIMAL SIGNS OF CEMENT CONTAMINATED MUD 11:00 - 11:30 0.50 CASING P INTI RIH ON 4"DOUBLES FROM 3,700'TO 4,745' MD 11:30 - 12:30 1.00 CASING P INTI WASH AND REAM DOWN WITH 5"DRILLPIPE FROM 4,745'TO 4,873'MD -584 GPM,2170 PSI -TAG UP LINER WIPER PLUG ON DEPTH 12:30 - 14:00 1.50 DRILL P INTI DRILL OUT SHOE TRACK FROM 4,873'TO 4896'MD -582 GPM,2220 PSI -40 RPM,8-9K TQ -5K WOB -P/U 144K,S/O 97K,ROT 120K 14:00 - 15:00 1.00 DRILL P INTI PUMP 40 BBLS SPACER AND DISPLACE WELL TO NEW 9.2 PPG LSND MUD -500 GPM,1420 PSI 40 RPM,8-9K TQ 15:00 - 15:30 0.50 DRILL . P. INTI DRILL OUT REMAINING SHOE TRACK AND 20' OF NEW FORMATION FROM 4,896'TO 4,926' MD(3,520'TVD) -580 GPM,1925 PSI -40 RPM,7-8K TQ -8K WOB 15:30 - 16:00 0.50 DRILL P INTI CIRC BOTTOMS UP WHILE ROT AND RECIP -580 GPM,1900 PSI -40 RPM,7-8KTQ MONITOR WELL FOR 10 MIN-STATIC 16:00 - 19:30 3.50 DRILL P INTI PULL UP INTO THE 9-5/8"LINER AND PERFORM LOT PERFORM LOT AT 4906'MD,3508'TVD -MW 9.2 PPG -FIRST ATTEMPT FOR LOT WAS STOPPED AT 678 PSI WHICH GAVE A LOT OF 12.92 EMW. -DISCUSSED WITH TOWN AND DECIDED TO_ PERFORM 2ND LOT 2ND LOT SUCCESSFULL TO 965 PSI,14.49_ PPG EMW -ODE APPROVAL TO CONTINUE OPERATIONS WITH A GREATER THAN 50 BBL KICK TOLERANCE 19:30 - 00:00 4.50 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM 4923'TO 5412'MD(3730'TVD) -582 GPM,1940 PSI ON/1840 PSI OFF -MW 9.2 IN/9.2 OUT -ECD 9.9 PPG(CALC ECD 9.66 PPG) -100 RPM,8K TQ ON/7KTQOFF -4-6K WOB -AST=0.33 HRS,ART=1.5,ADT=1.83 HRS -P/U=137K,S/O=103K,ROT=116K SPR'S AT 5314'MD(3679'TVD),TIME 23:25, MW 9.2 PPG #1 MP-20/30 SPM=240/320 PSI #2 MP-20/30 SPM=240/320 PSI Printed 3/4/2013 2:44:52PM NorthAmerica-ALASKA-BP 0age 29 of 46 Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor DOYON DRILLING INC. Active datum:Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/26/2013 00:00 - 12 00 12.00 DRILL P INT2 DRILL 8-3/4 INTERMEDIATE#2 HOLE FROM 5412'TO 6644MD(4290'TVD) -582 GPM,2250 PSI ON/2150 PSI OFF -MW 9.2 IN/9.2 OUT -ECD 9.94 PPG(CALC ECD 9.73 PPG) -100 RPM,8-9K TQ ON/7-8K TQ OFF -10-15K WOB -AST 1.07,ART 3.77,ADT 4.84 HRS -P/U=145K,S/0=116K,ROT=127K -PUMP 30 BBLS HIGH VIS SWEEP WITH NUT PLUG EVERY 800,30-40%INCREASE IN CUTTINGS W/SWEEP SPR'S AT 5791'MD(3899'TVD),TIME 03:23, MW9.15 PPG' #1 MP-20/30 SPM=310/370 PSI #2 MP-20/30 SPM=310/370 PSI SPR'S AT 6263'MD(4123'ND),TIME 07:00, MW 9.2 PPG- #1 MP-20/30 SPM=300/340 PSI #2 MP-20/30 SPM=280/340 PSI 12:00 - 00:00 12.00 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM 6644'TO 7687'MD(4750'TVD) -582 GPM,2500 PSI ON/2230 PSI OFF -MW 9.2 IN/9.2 OUT -ECD 9.98 PPG(CALC ECD 9.75 PPG) -100 RPM,11-12K TQ ON/8-9K TO OFF -6-10K WOB -AST 2.14,ART 3.32,ADT 5.46 HRS -P/U=159K,S/O=134K,ROT=149K -PUMP 30 BBLS HIGH VIS SWEEP WITH NUT PLUG EVERY 800',30-40%INCREASE IN CUTTINGS W/SWEEP SPR'S AT 6739'MD(4325'ND),TIME 13:17, MW 9.2 PPG #1 MP-20/30 SPM=300/340 PSI #2 MP-20/30 SPM=280/340 PSI SPR'S AT 7212'MD(4538'ND),TIME 18:30, MW 9.2 PPG #1 MP-20/30 SPM=340/400 PSI #2 MP-20/30 SPM=340/400 PSI SPR'S AT 7687'MD(4750'ND),TIME 23:45, MW 9.2 PPG #1 MP-20/30 SPM=260/340 PSI #2 MP-20/30 SPM=260/340 PSI Printed 3/4/2013 2 44 52PM • Noah America-ALASKA B .age o • Operation jna Fie•ort Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/27/2013 00:00 - 12:00 12.00 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM 7687'MD TO 9014"MD(5355'TVD) -582 GPM,2500 PSI ON/2230 PSI OFF -MW 9.2 IN/9.2 OUT -ECD 10.27 PPG(CALC ECD 9.79 PPG) -100 RPM,12-14K TQ ON/8K TQ OFF -14KWOB AST 1.35,ART 4.88,ADT 6.23 HRS -P/U=178K,S/O=146K,ROT=163K -PUMP 30 BBLS HIGH VIS SWEEP WITH NUT PLUG EVERY 800',30-40%INCREASE IN CUTTINGS W/SWEEP SPR'S AT 8350'MD(5054'TVD),TIME 05:46, MW 9.25 PPG #1 MP-20/30 SPM=280/340 PSI #2 MP-20/30 SPM=280/340 PSI SPR'S AT 8844'MD(5261'TVD),TIME 10:25, MW 9.2 PPG- #1 MP-20/30 SPM=270/340 PSI #2 MP-20/30 SPM=270/340 PSI 12:00 - 00:00 12.00 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM 9014"MD TO 9996'(5806'TVD) 582 GPM,3460 PSI ON 13160 PSI OFF MW 10.2 IN/10.2 OUT -ECD 11.66 PPG(CALC ECD 10.8 PPG) -100 RPM,12-14K TQ ON/8K TQ OFF -14KWOB -AST 2.37,ART 3.94,ADT 6.31 HRS -P/U=193K,S/O=150K,ROT=170K -PUMP 30 BBLS HIGH VIS SWEEP WITH SUPER SWEEP EVERY 800',30-40% INCREASE IN CUTTINGS W/SWEEP SPR'S AT 9393'MD(5518'TVD),TIME 16:00, MW 9.2 PPG #1 MP-20/30 SPM=280/360 PSI #2 MP-20/30 SPM=280/350 PSI SPR'S AT 9862'MD(5735'ND),TIME 22:15, MW 9.8 PPG #1 MP-20/30 SPM=340/440 PSI #2 MP-20/30 SPM=340/420 PSI Printed 3/4/2013 2:44:52PM North America- Page-BP 318f46 Operation Summary Resort Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date 2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/28/2013 00:00 - 12:00 12.00 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM 9996'TO 10,718'MD(6220'TVD) -538 GPM,3200 PSI ON/3040 PSI OFF -MW 10.7 IN/10.7 OUT -ECD 11.98 PPG(CALC ECD 11.29 PPG) -100 RPM,14K TQ ON/12K TQ OFF -14KWOB AST 1.61,ART 4.18,ADT 5.79 HRS -P/U=207K,S/O=156K,ROT=183K PUMP 30 BBLS HIGH VIS SWEEP WITH SUPER SWEEP EVERY 800',30-40% INCREASE IN CUTTINGS W/SWEEP -LOSSES AT 10 BPH SPR'SAT 10,056'MD(5834'ND),TIME 01:00, MW 10.2 PPG #1 MP-20/30 SPM=410/500 PSI #2 MP-20/30 SPM=400/500 PSI SPR'SAT 10,529'MD(6104'TVD),TIME 09:30, MW 10.7 PPG #1 MP-20/30 SPM=410/510 PSI #2 MP-20/30 SPM=410/510 PSI 12:00 - 13:00 1.00 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM 10,718'MD TO 10,813'(6274'TVD) -540 GPM,3200 PSI ON/2930 PSI OFF MW 10.7 IN/10.7 OUT -ECD 11.96 PPG(CALC ECD 11.29 PPG) -100 RPM,14-15K TQ ON/12K TQ OFF 14K WOB -AST 0,ART 0.76,ADT 0.76 HRS -P/U=210K,S/O=156K,ROT=183K -PUMP 30 BBLS HIGH VIS SWEEP WITH SUPER SWEEP,30-40%INCREASE IN CUTTINGS W/SWEEP -LOSSES AT 10 BPH 13:00 - 15:30 2.50 DRILL P INT2 CIRCULATE 2 BU,ROTATE AND RECIPROCATE -582 GPM,3250 PSI -100 RPM,10 KTQ FLOW CHECK 10 MIN(STATIC) 15:30 - 16:00 0.50 DRILL P INT2 POOH ON ELEVATORS 10,813'TO 10,550'MD -MONITOR FILL W/TRIP TANK -25K OVERPULLAND BEGAN SWABBING -RIH ON ELEVATORS TO 10,627'MD -P/U 210K,S/O 155K 16:00 - 20:30 4.50 DRILL P INT2 BROOH FROM 10,627'MD TO 9,869'MD -583 GPM 3250 PSI -100 RPM, 10-11 TO -REDUCE TO 550GPM TO CONTROL ECD -LOSSES AT 10 BPH CON'T BROOH 9,869'MD TO 8,827'MD -550 GPM 3100 PSI -80 RPM,10-11KTQ -ECD INCREASING TO 12.2 PPG Printed 3/4/2013 2:44:52PM North America 010 ALASKA-BP Page 32 of 46 Operation Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI Active datum:Z-61 Actual @96 Oft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT NPT Depth Phase Descnption of Operations (hr) (ft) 20:30 - 21:00 0.50 DRILL N DPRB 8,827.0 INT2 LOSS RATE INCREASED TO 120 BPH WHILE BACKREAMING SHUT DOWN PUMPS AND MONITOR WELL AT 8827'MD -OBSERVE TRICKLE OF FLOW DOWN FLOW-LINE,INSTALL FULL OPENING SAFETY VALVE,SHUT WELL IN -VERIFY SHUT IN,WELL SECURE AT 21:00 HRS 21:00 - 22:30 1.50 DRILL N DPRB 8,827.0 t INT2 MONITOR PRESSURES AND MAKE LEVEL'0' NOTIFICATIONS - ICP INCREASED TO 130 PSI AFTER 25 MIN MW 10.7 IN/10.7 OUT PERFORM WELLBORE BREATHING EXHALE TEST THROUGH CHOKE. -TRACK TIME BETWEEN EVERY 1 BBL INCREMENT RETURNED -1 BBL=7MIN 31 SEC -NEXT 1 BBL=6'MIN 28 SEC NEXT 0.6 BBL=11 MIN 6 SEC -TOTAL OF 2.6 BBLS RETURNED ON EXHALE TEST -SHUT IN CHOKE,SICP=70 PSI -CONFIRMED WELLBORE BREATHING AND CONSULT TOWN -WTLAPPROVED TO OPEN WELL AND CONTINUE OPERATIONS 22:30 - 23:00 0.50 DRILL ' N DPRB 8,827.0 INT2 L/D FULL OPENING SAFETY VALVE,RIH ONE STAND,BLOW DOWN CHOKE AND KILL LINE 23:00 - 23:30 0.50 DRILL N DPRB 8,827.0 INT2 CIRC BOTTOMS UP WHILE ROTATING AND RECIPROCATING -STAGE PUMPS TO 450 GPM,2240 PSI -40-70 RPM,9-10K TQ -LOSS RATE 15 BPH 23:30 - 00:00 0.50 DRILL P 8,827.0 INT2 BROOH FROM 8,922'TO 8,827'MD -450 GPM,2240 PSI -70 RPM,9-10K TQ 1/29/2013 00:00 - 08:30 8.50 DRILL P INT2 CONTINUE BACKREAMING OUT OF HOLE FROM 8827'MD TO 4,760'MD -380-570 GPM,1780-2880 PSI -40-100 RPM,10K TQ -ADJUST FLOW RATE AS NEEDED TO KEEP ECD UNDER 12.0 PPG -LOSSES AT 15 BPH 08:30 - 10:00 1.50 DRILL P INT2 CBUAT4,760'MDABOV SHOE,ROT&RECIP, FLOW CHECK(STATIC) 10:00 - 12:30 2.50 DRILL P INT2 CUT/SLIP DRLG LINE,MONITOR WELL ACROSS TRIP TANK 12:30 - 13:00 0.50 DRILL P INT2 SERVICE TDS, MONITOR WELL ACROSS TRIP TANK 13:00 - 13:30 0.50 DRILL P INT2 PERFORM BLOCK CALIBRATIONS,MONITOR WELL ACROSS TRIP TANK Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 33 of 46 tion Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Descnption of Operations (hr) (ft) 13:30 - 18:00 4.50 DRILL P INT2 RIH FROM 4,760'MD TO 10,722'MD,WASH LAST STD TO BTM @ 10,813'MD -STAGE PUMPS TO 566 GPM,3360 PSI -40 RPM,12-13KTQ -MONITOR ECD'S AND LOSS RATE -11.7 PPG ECD,NO LOSSES RECORD SCR'S @ 10,813'MD W/10.6 MW #1 MP- 20/30 SPM=360/460 PSI #2 MP-20/30 SPM=360/460 PSI 18:00 - 00:00 6.00 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM 10,813'MD TO 11,098'(6455'TVD) -580 GPM;.3680 PSI ON/3370 PSI OFF MW 10.7 IN/10.7 OUT ECD 11.85 PPG(CALC ECD 11.27 PPG) -120 RPM,16-18K TQ:ON/14-16K TQ OFF -9K WOB -AST 0.81,ART 1.73,ADT 2.54 HRS -P/U=222K,S/G=155K,ROT=186K -REDUCE ROP TO LIMIT ECD UNDER 12.0PPG -PUMP 30 BBLS HIGH VIS SWEEP WITH SUPER SWEEP EVERY 500',30-40% INCREASE IN CUTTINGS DURING SWEEP -NO LOSSES ✓ 1/30/2013 00:00 - 12:00 12.00 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM 11,098'TO 11,786'(6898'ND) -580 GPM,3660 PSI ON/3440 PSI OFF MW 10.7 IN/10.7 OUT -ECD 11.85 PPG(CALC ECD 11.27 PPG) -120 RPM,15-16K TO ON/15-16K TQ OFF 10K WOB -AST 0.88,ART 5.56,ADT 6.44 HRS -P/U=230K,S/O=159K,ROT=180K -REDUCE ROP TO LIMIT ECD UNDER 12.0PPG -NO LOSSES -PUMP 30 BBLS HIGH VIS SUPER SWEEP EVERY 500',20-30%INCREASE IN CUTTINGS DURING SWEEP 12 00 - 00:00 12.00 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM 11,786'TO 12,425'MD(7374') -580 GPM,3640 PSI ON/3460 PSI OFF -MW 10.7 IN/10.7 OUT -ECD 11.85 PPG(CALC ECD 11.27 PPG) -120 RPM,13-14K TQ ON/12K TQ OFF -10KWOB -AST 2.10,ART 5.56,ADT 7.61 HRS -P/U=250K,S/0=171K,ROT=205K -REDUCE ROP TO LIMIT ECD UNDER 12.0PPG -NO LOSSES -PUMP 30 BBLS HIGH VIS SUPER SWEEP EVERY 500',30%INCREASE IN CUTTINGS DURING SWEEP Printed 3/4/2013 2:44.52PM rr "North America-ALISKA= P ` Operation Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/me:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/31/2013 00:00 - 12:00 12.00 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM 12,425'MD TO 12,994'MD(7848'TVD) -581 GPM,3680 PSI ON/3470 PSI OFF -MW 10.8 IN/10.8 OUT ECD 11.85 PPG(CALC ECD 11.37 PPG) -120 RPM,18-19K TQ ON/16-17K TQ OFF -6-8K WOB AST 0.74,ART 5.98,ADT 6.72 HRS -P/U=230K,S/O=159K,ROT=180K -REDUCE ROP TO LIMIT ECD UNDER 12.OPPG -39 BBL LOSS FOR TOUR -PUMP 30 BBLS HIGH VIS SUPER SWEEP EVERY 500',30-40%INCREASE IN CUTTINGS -DURING SWEEP 12:00 - 00:00 12.00 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM 12,994'MD TO 13,644'MD(8380 TVD) 581 GPM,3995 PSI ON/3670 PSI OFF -MW 10.8 IN/10.8 OUT ECD 12 PPG(CALC ECD 11.37 PPG) -120 RPM,22K TQ ON/22K TQ OFF -10KWOB -AST 0.37,ART 5.95,ADT 6.32 HRS P/U=230K,S/O=159K,ROT=180K CONTROL ROP TO LIMIT ECD UNDER 12.3PPG -NO LOSSES -PUMP 30 BBLS HIGH VIS SUPER SWEEP EVERY 500',30-40%INCREASE IN CUTTINGS DURING SWEEP, 2/1/2013 00:00 - 08:30 8.50 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM ✓ 13,644'MD TO 14,111'MD(8765'TVD) -580 GPM,3950 PSI ON/3680 PSI OFF MW 10.8 IN/10.8OUT -ECD 11.94 PPG(CALC ECD 11.37 PPG) -120 RPM,22-24K TQ ON/18-19K TQ OFF -8K WOB -P/U=305K,S/O=183K,ROT=241K -CONTROL ROP TO LIMIT ECD UNDER 12.3PPG -NO LOSSES -PUMP 30 BBLS HIGH VIS SUPER SWEEP EVERY 500',30-40%INCREASE IN CUTTINGS DURING SWEEP 08:30 - 10:00 1.50 DRILL P INT2 CBU FOR SAMPLES,ROT AND RECIP STRING 580 GPM 3710 PSI 10:00 - 10:30 0.50 DRILL P INT2 DRILL 8-3/4"INTERMEDIATE#2 HOLE FROM 14,111'MD TO TD @ 14,114(8766'ND) -580 GPM,3950 PSI ON/3680 PSI OFF -MW 10.8 IN/10.8 OUT -ECD 11.78 PPG(CALC ECD 11.37 PPG) -120 RPM,22-24K TQ ON/18-19K TQ OFF -8K WOB -P/U=305K,S/O=183K,ROT=241K -CONTROL ROP TO LIMIT ECD UNDER 12.3PPG -NO LOSSES SPR'S AT 14,114'MD(8768'ND),TIME 10:15, MW 10.8 PPG #1 MP-20/30 SPM=360/480 PSI #2 MP-20/30 SPM=360/480 PSI Printed 3/4/2013 2:44:52PM - a ._�,. �,,�..: North America-ALASKA-BP Page 35 of 46 i ar,� ��.� � , Operation Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud DateRme:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 14:00 3.50 DRILL P INT2 CIRC,ROT AND RECIP STRING 580 GPM 3650 PSI 120 RPM 21/23 TQ PUMP HI-VIS NUT PLUG SWEEP @ 11:45 HRS MONTIOR WELL FOR 10 MINS(STATIC) 14:00 - 17:00 3.00 DRILL P INT2 PUMP OUT OF HOLE F/14,104'MD TO 12,143' MD 85 GPM,445 PSI PU WT 310K,SO WT 180K 17:00 - 18:00 1.00 DRILL P INT2 POOH ON ELEVATORS 12,143'MD TO 11,574' M D, MONTIOR WELL ON TRIP TANK ENCOUNTER 50K OVER PULL @ 11,574'MD_ 18:00 - 19:00 1.00 DRILL P INT2 CBU WHILE ROT AND RECIP STRING, 582 GPM, 3500 PSI 100`RPM, 12/13KTQ 19:00 - 00:00 5.00 DRILL P INT2 BACK REAM OOH,11,574'MD TO 9210'MD 555 GPM,3100 PSI 80 RPM,8/9K.TQ 2/2/2013 00:00 - 02:00 2.00 DRILL P INT2 BACKREAM OOH 9,210'MD TO 8,447'MD -555 GPM,3100 PSI -80 RPM,8-9K TQ 02:00 - 02:30 0.50 DRILL P INT2 POOH ON ELEVATORS FROM 8,447'MD TO 8,069'MD -MONITOR DISPLACEMENT VIA TRIP TANK 02:30 - 05:30 3.00 DRILL P INT2 RIH FROM 8,069'MD TO 14,039'MD 05:30 - 12:00 6.50 DRILL- P INT2 WASH AND REAM LAST STAND DOWN FROM 14,039'MD TO 14,114'MD -CIRCULATE WHILE ROTATE AND RECIPROCATING -STAGE PUMP RATES UP T0450 GPM -450 GPM,2850 PSI -80 RPM,23K TQ -PUMP 35 BBL LCM PILL -LOST ALL RETURNS WHILE PUMPING LCM TO BIT -SHUT PUMPS OFF,MONITOR WELL(STATIC) -STAGE PUMPS FROM 250 GPM TO 575 GPM, 3700 PSI -GAINED RETURNS BACK -CIRCULATE WITH ROTATION AND RECIPROCATION-85'STROKES -575 GPM,3700 PSI -120 RPM,23K TQ -LOST 227 BBLS OVER 3 HRS 12:00 - 14:30 2.50 DRILL P INT2 CONTINUE TO ROTATE AND RECIPROCATE FROM 14,114'MD TO 14,032'MD -570 GPM,3600 PSI -120 RPM,25K TQ -PU=315K,SO=170K -ECD=11.68 PPG 14:30 - 17:30 3.00 DRILL P INT2 MONITOR WELL(STATIC),PUMP OOH FROM 14,114'MD TO 12,428'MD'MD -90 GPM 450 PSI -HOLE TAKING CALCULATED FILL -NO TIGHT SPOTS ENCOUNTERED 17:30 - 22:30 5.00 DRILL P INT2 POOH ON ELEVATORS FROM 12,428'MD TO 4,860'MD Printed 3/4/2013 2:44:52PM -: North America ALASKA� -BP Page 36 of 46 v, Operation Sum - •ort Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UW: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 00:00 1.50 DRILL P INT2 BIT INSIDE 9-5/8"SHOEAT4,860' -BREAK CIRCULATION -STAGE PUMPS UP TO 570 GPM,2550 PSI -RECORD INTIAL CIRC PRESSURES -DROP 2.125"BALL AND PUMP 2-3 BPM -BALL ON SEAT -STAGE UP PUMP PRESSURE -500 PSI INCREMENTS UP TO 4,000 PSI -ATTEMPT TO SHIFT WELL COMMANDER CIRC SUB OPEN(UNSUCCESSFUL) -BLEED OFF PRESSURE -MADE ADDITIONAL ATTEMPTS TO SHIFT W.C.OPEN(UNSUCCESSFUL) -BLOW DOWN TOP DRIVE RECIPROCATE AND ROTATE PIPE,ATTEMPT TO OPEN CIRC SUB(UNSUCCESSFUL) NOTIFY ODE AT 23:00-DECISION TO POOH WET 2/3/2013 00:00 - 05:00 5.00 DRILL P INT2 POOH FROM 4,880'MD TO 852'MD MONITOR HOLE FILL VIA TRIP TANK 05:00 - 07:00 2.00 DRILL P INT2 LD 8-3/4"INTERMEDIATE DRILLING BHA#6 -WELL COMMANDER FOUND IN OPEN POSITION,WITH BALL STUCK IN BALL SEAT -BIT GRADE 1-3-WT-T-X-2-CT-TD 07:00 - 08:30 1.50 DRILL P INT2 CLEAN AND CLEAR RIG FLOOR,LD XO'S AND HANDLING EQUIPTS,RETRIEVE WEAR BUSHING 08:30 - 10:00 1.50 CASING_ P INT2 C/O UPPER PIPE RAMS TO 7"CASING RAMS, TEST RAM AND ANNULAR TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MIN EACH W/7"TEST JOINT 10:00 - 12:00 2.00 CASING P INT2 PULL PS-21 AIR SLIPS,CLEAN,INSPECT, GREASE AND LUBE,REINSTALL -PULL STRIP-O-MATIC -RIG UP TO RUN 7"26#VT HC CASING, PERFORM DUMMY RUN W/7"LANDING JT AND FLUTED HGR,LAND AND MARK. 12:00 - 13:00 1.00 CASING P INT2 PU/MU 7"SHOE TRACK,CHECK FLOAT EQUIPT,OK 13:00 - 18:00 5.00 CASING P INT2 RUN 7"26#VT HC CSG TO 1,957'MD(9 5/8" LINER TOP).FILL PIPE EVERY 10 JTS. 18:00 - 19:00 1.00 CASING P INT2 CBU @ 1,957'MD(9 5/8"LINER TOP), -STAGE PUMPS TO 7BPM 100 PSI. 19:00 - 00:00 5.00 CASING P INT2 CONT RIH W/7"26#VT HC CSG TO 4491'MD -FILL PIPE EVERY 10 JTS.AND OBTAIN PICK UP AND SLACK OFF WEIGHTS. -MONITOR RETURNS ON PITS 2&3 2/4/2013 00:00 - 01:00 1.00 CASING P INT2 RIH W/7"L-80 26#VT HC CASING FROM 4491'MD TO 4945'MD. -FILLING PIPE EVERY JOINT RAN AND CIRCULATE 25-BBLS.EVERY 10TH JOINT RAN AT 5.0-BPM. 01:00 - 02:00 1.00 CASING P INT2 CBU @ 4945'MD,RECIP PIPE,STAGE PUMP RATE TO 7 BPM,280 PSI. -LOST TOTAL OF 4 BBLS 02:00 - 09:00 7.00 CASING P INT2 CONT RIH W/7"L-80 26#VT HC CASING F/ 4945'MD TO 8160'MD. -FILLING PIPE EVERY JOINT RAN AND CIRCULATE 25-BBLS.EVERY 10TH JOINT RAN AT 5.0-BPM. Printed 3/4/2013 2:44:52PM • . „ . . North America-ALASKA-BP Page 37 of 46 Operation Sum Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual©96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 13:00 4.00 CASING P INT2 CIRC SURFACE TO SURFACE VOLUME. -RECIP PIPE,3 BPM/330 PSI WHILE SLACK OFF,5 BPM/486 PSI WHILE P/U -RIH W/5 JTS F/8160 TO 8369'DURING CIRC. -INITIAL LOSSES 70 BPH,LOSSES TAPERED TO 3 BPH 13:00 - 13:30 0.50 CASING P INT2 MONITOR WELL FOR FINGERPRINTING WITH 200 JTS.RAN,BLED BACK 12.8 BBL TOTAL. 13:30 - 16:30 3.00 CASING P INT2 CONT RIH W/7"L-80 26#VT HC CASING F/ 8369'MD TO 9440'MD. -FILLING PIPE EVERY JOINT RAN AND CIRCULATE 25-BBLS.EVERY 10TH JOINT RAN AT 5.0-BPM. -FINGERPRINT WELL AFTER 210 JTS.RAN -MONITOR WELL VIA PIT#2 16:30 - 17:30 1.00 CASING P INT2 CIRC OPEN HOLE VOLUME,1800 STKS. -RECIP PIPE,3 BPM/440 PSI WHILE SLACK OFF,5 BPM/475 PSI WHILE P/U LOSSES AT 20 BPH 17:30 - 21:00 3.50 CASING P INT2 CONT RIH W/7"L-80 26#VT HC CASING F/ 9440'MD TO 10,927'MD. -FILLING PIPE EVERY JOINT RAN AND CIRCULATE 25-BBLS.EVERY 10TH JOINT RAN -AT 5.0-BPM. -FINGERPRINT WELL AT 220 JTS.RAN. -MONITOR WELL VIA PIT#2 21:00 - 00:00 3.00 CASING, P INT2 CBU PRIOR TO ENTERING HRZ AND KINGAK -RECIP PIPE,3 BPM/476 PSI WHILE SLACK OFF,5 BPM/490 PSI WHILE P/U -INITIAL LOSSES 60 BPH,LOSSES SLOWED TO 5 BPH -MONITOR WELL FOR FINGERPRINTING 2/5/2013 00:00 - 06:00 6.00 CASING P INT2 CONT RUN 7",26# VTHC CSG FROM 10,968' MD TO 14,109'MD -NO LOSSES -LAND CASING HANGER ON DEPTH AT 14,109'MD 06:00 - 13:00 7.00 CASING P INT2 CIRCULATE AND CONDITION MUD FOR CEMENT -STAGE PUMP TO 5 BPM,600 PSI MADE NOTIFICATION VIA THE WEB PAGE TO AOGCC FOR UPCOMING BOPE TEST -JEFF JONES WAIVED WITNESS 13:00 - 16:00 3.00 CEMT N SFAL INT2 SLB CEMENTING PUMP TRUCK COOLANT VALVE LEAK INTO SECONDARY • CONTAINMENT INSIDE THE UNIT. -SLB MECHANIC CALLED OUT TO REPAIR PRIOR TO CEMENT JOB. Printed 3/4/2013 2:44:52PM "� Worth America :ALASKA-BP Page 38 of 46 ' ' ��. ' tltl'�Illa Re ort Common Well Name:Z-61 I AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194 00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/me:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96 Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 22:00 6.00 CEMT P INT2 HOLD PJSM W/WSL,SLB,TOOLPUSHER, AND 3RD PARTY PERSONNEL CEMENT JOB AS FOLLOWS -PUMP 20 BBLS OF 11PPG MUDPUSH -PT CEMENT LINES TO 250 PSI /4,500 PSI LOW/HIGH FOR 5 CHARTED MINUTES EACH CEMENT PUMPING UNIT: -PUMP 30 BBLS 11 PPG MUD PUSH AT 5 BPM, 850 PSI -DROP BOTTOM PLUG. -PUMP 288.6 BBLS(920.7 SX)OF LITE CRETE 11.5 PPG LITECRETE LEAD CEMENT,YIELD 1.75 CU/FT SK,5 BPM,1LB/BBLS CEMNET ADDTIVE PUMP 22 BBLS(105.5 SX)15.8 PPG CLASS • ''G"TAIL GASBLOK CEMENT,YIELD 1.17 CUFT/SK. 0.5 BPM -DROP TOP PLUG. -SLB TO CHASE PLUG W/10 BBLS OF WATER TO FLUSH CEMENT LINES. SWAP TO RIG FOR DISPLACEMENT, -CALCULATED DISPLACEMENT=536 BBLS -PUMPING AT 7 BPM WITH 775 PSI,WITH 30% FLOW OUT RETURNS -LOST RETURNS PUMPING AT 7 BPM WITH 775 PSI,160 BBLS INTO DISPLACEMENT, -FLUCTUATED PUMP RATES F/2BPM TO 7 BPM WHILE RECIPROCATING PIPE IN ATTEMPT TO RESTABLISH RETURNS -WELL PACKING OFF -CONTINUE DISPLACEMENT -2-6 BPM,815-1800 PSI,WITH 1-3%FLOW OUT RETURNS -PUMP TOTAL OF 536 BBLS OF 10.8 PPG LSND MUD,DISPLACEMENT -SLOW DOWN TO 1.5 BPM PRIOR TO ANTICIPATED BUMP -PLUG DID NOT BUMP ON CALCULATED, STROKES -PUMP ADDITIONAL 1.5 BBLS-HALF THE SHOE TRACK VOLUME- -TOTAL 537.5 BBLS OF DISPLACEMENT -SHUT DOWN PUMPS AND MONITOR WELL, WELL SHOWING SIGNS OF ANTICIPATED BREATHING. CEMENT IN PLACE AT 21:50 HRS TAIL CEMENT REACHES 500 PSI COMPRESSIVE STRENGTH IN 12 HRS 23 MIN TAIL CEMENT WAS BATCHED AT 18:25 LOST 360 BBLS OVER ENTIRE DISPLACEMENT Printed 3/4/2013 2:44:52PM • ,,. , .. North America-ALASKA BPPage 39 of 46 Operation Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UW: Active datum Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 22:00 - 00:00 2.00 CEMT P INT2 TALKED WITH THE TOWN ODE FOR PLAN FORWARD AFTER PLUG NOT BUMPING -MONITORED WELL FOR ANTICIPATED BREATHING._, -SHUT IN WELL AFTER 10 BBLS OF FLOW BACK -MONITORED SICP AT THE SUPER CHOKE -PRESSURE DROPPING FROM 280 PSI TO 210 PSI IN 20 MIN. LINED UP AND TESTED THE FLOATS. `(F,LOATS HOLDING) -RU EQUIPMENT TO INJECT 5 BBLS INTO THE IA -PUMP 0.75 BBLS BEFORE BREAKING OVER AT 480 PSI -PUMP TOTAL OF 5 BBLS IN THE OA 2/6/2013 00:00 - 01:30 1.50 CEMT P INT2 CONTINUE INJECTING IN THE OA -2 BBLS EVERY HOUR. -ICP-430 PSI -FCP-480 PSI 01:30 - 03:30 2.00 CEMT P INT2 OPEN CHOKE AND FINGERPRINT THE WELL FLOW -1 BBL,4MIN 20SEC 1 BBL,16 MIN -1BBL,10MIN -1 BBL, 30 MIN -1 BBL,14 MIN 03:30 - 04:00 0.50 CEMT P INT2 INJECT IN THE OAAT.5 BPM - ICP-380 PSI -FCP-420 PSI TOTAL-2 BBLS 04:00 - 06:30 2.50 CEMT P INT2 OPEN CHOKE AND FINGERPRINT THE WELL FLOW -1 BBL,3 MIN 20 SEC -1 BBL,7 MIN -1 BBL,10 MIN -1 BBL, 23 MIN -1 BBL,31MIN -1 BBLS,33 MIN 06:30 - 07:30 1.00 CEMT P INT2 OPEN WELL,DRAIN STACK&MONITOR IN CELLAR. R/D DOWN VOLANT CASING RUNNING TOOL&LONG BAILS. 07:30 - 09:00 1.50 CEMT P INT2 R/U 7"PACK-OFF RUNNING TOOL&INSTALL CASING PACK-OFF AS PER FMC. -PRESSURE TEST TO 250 LOW/5,000 HIGH (GOOD TEST) -UD RUNNING TOOL 09:00 - 09:30 0.50 CEMT P INT2 M/U TEST PLUG&INSTALL.UD TEST JOINT. 09:30 - 10:00 0.50 CEMT P INT2 R/U 5"PIPE HANDLING EQUIPMENT TO UD 5" DP IN DERRICK 10:00 - 10:30 0.50 CEMT P INT2 INJECT 3 BBLS DOWN OA -ICP=530 -FCP=500 10:30 - 21:00 10.50 CEMT P INT2 UD 5"DP FROM DERRICK INJECT DOWN OA EVERY 1.5-2 HRS -PUMPING 2 BBLS AFTER SEEING BREAKOVER POINT Printed 3/4/2013 2:44:52PM North America-ALASKA-BP gage 40 of 46 Operati+ -. p • ► • 'ort. Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud DateTme:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 21:30 0.50 CEMT P INT2 PUMP 4 BBLS DOWN OAAT 10 SPM. PRESSURE BROKE OVER AT 450 PSI WITH MAX PRESSURE WHILE INJECTING AT 615 PSI. 21:30 - 23:00 1.50 CEMT P INT2 C/O SAVER SUB TO 4"XT-39, -0/0 UPPER BOPE RAMS FROM 7"TO 2-7/8"X 5-1/2"VBR'S 23:00 - 00:00 1.00 CEMT P INT2 P/U 4"&4-1/2"TEST JOINT,MAKE UP 4" FLOOR VALVES,PREP FOR TESTING BOPE 2/7/2013 00:00 - 04:00 4.00 CEMT P INT2 TEST BOPE.TESTED ANNULAR AND RAMS TO 250 PSI LOW/3500 PSI HIGH FOR 5 MIN EACH. ALL TESTS CHARTED. -SEE ATTACHED BOPE TEST SHEETS FOR DETAILS PERFORMED ACCUMULATOR TEST:SYSTEM PRESSURE 3050 PSI: MANIFOLD PRESSURE 1,500-PSI. PRESSURE AFTER CLOSING ALL RAMS AND ANNULAR PREVENTER 1,700 PSI. RECOVERED 1ST 200 PSI-14 SECONDS. FULL RECOVERY IN 106 SECONDS. AVERAGE PRESSURE 6 NITROGEN BOTTLES =1950-PSI. BOP CLOSING TIMES: -ANNULAR PREVENTER=21-SECONDS -UPPER PIPE RAMS=18-SECONDS -LOWER PIPE RAMS=18-SECONDS -BLIND/SHEAR RAMS=22-SECONDS -HCR KILL VALVE=2-SECONDS -HCR CHOKE=2-SECONDS. AOGCC JEFF JONES WAVED WITNESS TO BOPE TEST 04:00 - 04:30 0.50 CEMT P INT2 RIG DOWN TESTING EQUIPMENT -BLOW DOWN CHOKE AND KILL LINES -PULL TEST PLUG -INSTALL WEAR RING 8.875" ID INJECT 3 BBLS DOWN OA -ICP=550 -FCP=500 04:30 - 08:00 3.50 CEMT P INT2 PU&MU 6-1/8"PRODUCTION DRILLING BHA# 7 -6-1/8"HUGHES INSERT BIT -1.5"BENT HOUSING MOTOR -DIR/GR/RES/NEU/DEN -MONITOR WELL VIA TRIP TANK 08:00 - 09:00 1.00 CEMT P INT2 0/0 SLIP INSERTS.P/U 4"DP SINGLES FROM SHED AND RIH FROM 211'MD TO 1,161'MD. -MONITOR WELL VIA TRIP TANK 09:00 - 10:00 1.00 CEMT P INT2 SHALLOW TEST MWD AT 1,161'MD -250 GPM,1,440 PSI,25%F/O(FAILED) -DECISION MADE TO RIH 2,111'MD&RETEST 10:00 - 11:00 1.00 CEMT P INT2 RIH WITH 4"DP SINGLES FROM SHED FROM 1,161'MD TO 2,111'MD -MONITOR WELL VIA TRIP TANK 11:00 - 11:30 0.50 CEMT P INT2 SHALLOW TEST MWDAT2,111'MD -250 GPM,1,460 PSI,25%F/O(GOOD TEST) -MONITOR WELL VIA TRIP TANK Printed 3/4/2013 2:44:52PM • North America-ALASKA-BP Page 41 of 46 Operation Summary Repo Common Well Name:Z-61 AFE No • Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad • Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12.00:OOAM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:30 - 14:00 2.50 CEMT P INT2 CONT RIH WITH 4"DP FROM 2,111'MD TO 3,561'MD. -MONITOR WELL VIA TRIP TANK -CONT INJECT 3 BBLS DOWN 7"ANNULUS EVERY 3 14:00 - 15:00 1.00 CEMT P INT2 TEST 7"CASING -250 PSI LOW FOR 5 MIN/3,500 PSI HIGH FOR 30 MIN,ON CHART(GOOD TEST) -RECIEVED APPROVAL TO PROCEED FROM WELL OPS TL 15:00 - 00:00 9.00 CEMT P INT2 CONT RIH WITH 4"DP FROM 3,561'MD TO 9,329'MD -MONITOR WELL VIA TRIP TANK -PUMP 4 BBL$DOWN OA EVERY 3 HRS 2/8/2013 00:00 - 04 00 4.00 CEMT P INT2 TIH WTH 6-1/8"PRODUCTION BHA ON 4"DP DOUBLES FROM THE SHED SIMOPS: -RU AND FREEZE PROTECT THE OA WTH 144 BBLS OF 80 DEG DIESEL AT 3 BPM. ICP=650 PSI -FCP=1,050 PSI -WILL PUMP ADDITIONAL 66 BBLS OF 80 DEGREE DIESEL WHEN WE RECEIVE MORE .DIESEL. TAG PLUG AT 13,914'MD,113'ABOVE THE LANDING COLLAR -MONITOR WELL VIA TRIP TANK 04:00 - 08:00 4.00 CEMT P INT2 SLIP AND CUT 173'OF DRILL LINE. RECALIBRATE SLB&TOTCO BLOCK HEIGHT. -MONITOR WELL VIA TRIP TANK SPR'S @ 13894'MD,8,627'TVD-MW=10.85 PPG,TIME=04:30 #1 MP-20/30 SPM=1180/1460 PSI #2 MP-20/30 SPM=1200/1470 PSI 08:00 - 09:00 1.00 CEMT P INT2 WASH&REAM FROM 13,914'MD TO 14,020' MD -245 GPM,2,810 PSI -40 RPM,15K TQ 09:00 - 11:00 2.00 DRILL P INT2 DRII L SHOE TRACK&30'OF NEW FORMATION FROM 14,020'MD TO 14,139'MD -345 GPM,2,730 PSI -40 RPM,18KTQ 11:00 - 14:30 3.50 DRILL P INT2 DISPLACE WELL TO 8.5 PPG POWERPRO -247 GPM,2,074 PSI SPR'S:14,105'MD(8,759'TVD)-TIME=14:30, MW=8.5 PPG #1 MP-20/30 SPM=540/700 PSI #2 MP-20/30 SPM=520/690 PSI "\ 14:30 - 15:30 1.00 DRILL P INT2 PERFORM FITAT 14,109'MD,8,762'TVD f -MW8.5PPG �( -FITTO 11.03 PPG EMW -SENT RESULTS TO ODE -ODE APPROVAL TO PROCEED Printed 3/4/2013 2:44:52PM • North America-ALASKA-BP Page 42 of 46 •- ation Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date.2/15/2013 'X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/me:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 - 00:00 8.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 14,139'MD TO 14,228'MD(8,855'ND) -246 GPM,1,740 PSI ON/1,575 PSI OFF -0 RPM,TQ=OK ON/OK OFF -WOB=18-20K ' -MW=8.5 PPG IN/8.5 PPG OUT -P/U=200K,S/O=160K,ROT=K AST=3.95 HRS,ART=.05 HRS,ADT=4 HRS TOTAL BIT HRS=4,TOTAL JAR HRS=4 TOTAL LOSSES FOR LAST 24 HRS=0 BBLS R/U UPON OAAND FINISH FREEZE PROTECTING WITH 66 BBLS OF 80 DEGREE DIESEL. -ICP 980 PSI,FCP 1190 PSI 2/9/2013 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 14,228'MD TO 14,427 MD(8,972'TVD) -245 GPM,1,820 PSI ON/1,670 PSI OFF 40 RPM,TQ-=8-9K ON/7K OFF -WOB=18K -MW=8.6 PPG IN/8.6 PPG OUT -P/U=215K,S/O=153K,ROT=168K AST=6.33 HRS,ART=1.39 HRS,ADT=8.22 HRS TOTAL BIT HRS=14.07,TOTAL JAR HRS= 14.07 TOTAL LOSSES FOR LAST 24 HRS=0 BBLS SPR'S @ 14,265'MD,8,871'TVD-MW=8.6 PPG,TIME=03:00 #1 MP-20/30 SPM=640/780 PSI #2 MP-20/30 SPM=640/780 PSI CH2MHILL SUPER SUCKER DEVELOPED GLYCOL LEAK DUE TO A SPLIT ENGINE COOLANT HOSE. INCIDENT WAS REPORTED TO WSL,5700 AND CH2MHILL MANAGEMENT. CH2MHILL ALSO WROTE AND SUBMITTED TRACTION IR#4350059. 12:00 - 00:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 14,427'MD TO 14,743'MD(9,056'TVD) -245 GPM,1,850 PSI ON/1,747 PSI OFF -40 RPM,TQ=10K ON/9K OFF -WOB=15K -MW=8.6 PPG IN/8.6 PPG OUT -P/U=225K,S/O=150K,ROT=172K AST=4.18 HRS,ART=2.43 HRS,ADT=7.24 HRS TOTAL BIT HRS=21.3,TOTAL JAR HRS=21.3 TOTAL LOSSES FOR LAST 24 HRS=0 BBLS SPR'S @ 14,737'MD,9,056'ND-MW=8.6 PPG,TIME=23:30 #1 MP-20/30 SPM=760/860 PSI #2 MP-20/30 SPM=720/840 PSI Printed 3/4/2013 2:44:52PM • • North America-ALASKA-BP Page 43 of 46 Operamary RepO Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UW: Active datum:Z-61 Actual©96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/10/2013 00:00 - 04:00 4.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE Fl 14,743'MD TO 14,930'MD(9,037'TVD) -245 GPM,1,980 PSI ON/1,760 PSI OFF -60 RPM,TQ=11K ON/9K OFF WOB=16K MW=8.6 PPG IN I 8.6 PPG OUT -P/U=215K,S/O=144K,ROT=153K AST=.91 HRS,ART=1.39 HRS,ADT=2.3 HRS TOTAL BIT HRS=23.9,TOTAL JAR HRS=23.9 TOTAL LOSSES FOR LAST 24 HRS=0 BBLS _ 04:00 - 05:30 1.50 DRILL P PROD1 CIRCULATE BOTTOMS UP WHILE ROT& RECIP FROM 14,930'MD TO 14,840'MD -245 GPM,1,750 PSI -60 RPM,9KTQ MW=8.6 PPG IN/8.6 PPG OUT SPR'S @ 14,930'MD,9,037'TVD-MW=8.6 PPG,TIME=05:30 #1 MP-20/30 SPM=630/780 PSI #2 MP-20/30 SPM=640/790 PSI 05:30 - 06:30 1.00 DRILL P PROD1 POOH ON ELEVATORS FROM 14,930'MD TO 14,649'MD. PUMP OUT FROM 14,649'MD TO 14,078'MD DUE TO SWABBING -3 BPM,750 PSI 06:30 - 07:00 0.50 DRILL P PROD1 MONITOR WELL(STATIC) -PUMP 30 BBL 10.6 PPG SLUG 07:00 - 12:30 5.50 DRILL P PROD1 POOH ON ELEVATORS FROM 14,078'MD TO 306'MD -MONITOR WELL VIA TRIP TANK 12:30 - 13:00 0.50 DRILL --__ P PROD1 -MONITOR WELL WELL FOR 10 MIN BEFORE PULLING BHA THROUGH STACK-WELL STATIC 13:00 - 13:30 0.50 DRILL P PROD1 POOH ON ELEVATORS FROM 306'MD TO 130' MD 13:30 - 14:00 0.50 DRILL P PROD1 PJSM FOR REMOVING NUKE SOURCE. -REMOVE NUKE SOURCE PER SLB SOP FOR HANDLING RADIOACTIVE MATERIALS 14:00 - 15:00 1.00 DRILL P PROD1 LD MOTOR BHA#7 PER SLB DD -REMOVE SOURCE -CLEAN AND CLEAR RIG FLOOR -BIT GRADE:1-1-WT-A-E-I-RG-BHA 15:00 - 15:30 0.50 DRILL P PROD1 CLEAN&CLEAR RIG FLOOR 15:30 - 17:30 2.00 DRILL P PROD1 PJSM ON P/U WIRELINE TOOLS. -EXPEDITE WIRELINE TOOLS TO RIG FLOOR. INSTALL DUTCH RISER. -M/U WIRELINE HEAD 17:30 - 18:30 1.00 DRILL N HMAN 14,930.0 PROD1 LOG TOOL WAS DAMAGED WHILE LOADING IN THE PIPE SHED -TIME WAS SPENT PICKING UP A NEW ONE THAT WAS ALREADY ON LOCATION 18:30 - 22:00 3.50 DRILL P PROD1 M/U WIRELINE TOOLS,RE-SPOT WIRELINE TRUCK&MOVE STABBING BOARD BRACKET TO CLEAR WIRELINE FROM ALL OBJECTS IN DERRICK Printed 3/4/2013 2:44:52PM S North America-ALASKA-BP Page 44 of 46 Operation Summary Repo. Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 00:00 2.00 DRILL P PROD1 RIH WITH SLB USIT TOOL AT 30 FT/MIN MAX RUN SPEED -CCL -GR EDTC -CBL-SONIC -INC -USIT TOTAL 70' 2/11/2013 00:00 - 07:30 7.50 DRILL P PROD1 RIH WITH SLB USIT TOOL TO 14,109'.LOG , FROM 14,109'MD TO 1,650'MD @ 30'/MIN. MONITOR WELL VIA TRIP TANK -CCL -GR EDTC -CBL-SONIC -INC -USIT TOTAL 70' 07:30 - 09:30 2.00 DRILL P PROD1 R/D SLB E-LINE AS PER SLB REP.R/D DUTCH RISER ASSEMBLY. -P/U RA SOURCE SHIELD,XO&BIT 09:30 - 12:00 2.50 DRILL _ P PROD1 PJSM FOR INSERTING NUKE SOURCE AND PICKING UP BHA -M/U BHA#8 AS PER SLB DD -NEAR BIT GR,D&I,AZ -IMPULSE -ADN-475 PU&MU RSS -TEST POWER DRIVE AT 250 GPM,450 PSI (GOOD TEST) -MONITOR WELL VIA TRIP TANK 12:00 - 13:00 1.00 DRILL P PROD1 TIH ON ELEVATORS FROM 193'M DTO 1,143' MD -MONITOR DISPLACEMENT VIA TRIP TANK 13:00 - 13:30 0.50 DRILL P PROD1 SHALLOW TEST BOTTOM HOLE TOOLS (GOOD TEST) -253 GPM, 13:30 - 21:30 8.00 DRILL P PROD1 CONT TIH ON ELEVATORS FROM 1,143'MD TO 14,060'MD -MONITOR DISPLACEMENT VIA TRIP TANK FILL EVERY 20 STANDS 21:30 - 22:30 1.00 DRILL P PROD1 TIN ON ELEVATORS FROM 14,060'MD TO 14,915'MD. -RESHOOT SURVEYS AT 14,341'MD&14,626' MD AS PER SLB MWD 22:30 - 00:00 1.50 DRILL P PROD1 WASH LAST STAND DOWN IN HOLE F/14,820' MD TO 14,925'MD -280 GPM,2,206 PSI ON -80 RPM,TQ=8K ON/7K OFF -P/U WT=210K,S/O Wi=155K,RT WT= 148K SPR'S©14,911'MD,9,036'TVD-MW=8.5 PPG,TIME=23:30 #1 MP-20/30 SPM=560/740 PSI #2 MP-20/30 SPM=600/740 PSI Printed 3/4/2013 2:44:52PM • North America-ALASKA-BP Page 45 of 46 Operation Summary Report Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud DateRme:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-61 Actual©96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/12/2013 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/14,930'MD 9,037 TVD TO 15,766'MD 8,949'TVD -276 GPM,2,180 PSI ON,2150 OFF -120 RPM,TQ=16K ON/10K OFF -MW=8.6 PPG IN/8.6 PPG OUT -P/U=222K,S/0=177K,ROT=15K -ADT-8.05 HRS,TOTAL JAR HRS-32 SPR'S @ 15,476'MD,8,967'TVD-MW=8.6 PPG,TIME=07:30 #1 MP-20/30 SPM=620/800 PSI #2 MP-20/30 SPM=620/800 PSI 12:00 - 00:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/ 15,766', 8,949'TVD TO 16,431'MD 8950'TVD -276 GPM,2,180 PSI ON 2150 OFF -120 RPM,TQ=16KON/10KOFF -MW=8.6 PPG IN/8,6 PPG OUT -P/U=222K,S/O=177K,ROT=15K -ADT-8.05 H.RS,BIT HRS-14.2 TOTAL JAR HRS- 38.15 SPR'S @ 16,146'MD,8,965'TVD-MW=8.6 PPG,TIME=20:30 #1 MP-20/30 SPM=620/780 PSI -#2MP-20/30 SPM=600/760 PSI 2/13/2013 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/ 16,431' MD 8950'TO 17,349'MD 8,973'TVD -285 GPM,2,480 PSI ON,2470 OFF -120 RPM,TQ=15K ON/9K OFF -MW=8.6PPGIN/8.6PPGOUT -P/U=218K,S/O=177K,ROT=173K -ADT-7.98 HRS,TOTAL BIT HRS-22.18,TOTAL JAR HRS-62.1 SPR'S©17,286'MD,8,965'TVD-MW=8.6 PPG,TIME=11:15 #1 MP-20/30 SPM=740/860 PSI #2 MP-20/30 SPM=740/860 PSI / 12:00 - 18:00 6.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/ 17,349' MD 8,973'TVD TO TD OF 17,891'MD,9,013' -285 GPM,2,480 PSI ON,2470 OFF -120 RPM,TO=15K ON/9K OFF -MW=8.6 PPG IN/8.6 PPG OUT -P/U=218K,S/0=177K,ROT=173K -ADT-7.98 HRS,TOTAL BIT HRS-22.18,TOTAL JAR HRS-62.1 -SLIGHT MUD LOSS-—3 BPH SPR'S©17,891'MD,9,013'ND-MW=8.6 PPG,TIME=18:30 #1 MP-20/30 SPM=680/840 PSI #2 MP-20/30 SPM=640/840 PSI DAILY FLUID LOSS-55 BBLS 18:00 - 21:30 3.50 DRILL P PROD1 ROTATE AND RECIPROCATE WHILE CIRCULATING BOTTOMS UP X 2 -17,891'TO 17,764' -300 GPM,2750 PSI,100 RPM,11K TQ 21:30 - 00:00 2.50 DRILL P PROD1 BACK REAM OUT OF THE HOLE F/17,859'TO 15,959' -288 GPM,2420 PSI,120 RPM,13K TQ Printed 3/4/2013 2:44:52PM „w s �. North America-ALASKA-BP Page 46 of 46 p ry Repo O era�� ma Common Well Name:Z-61 AFE No Event Type:DRL-ONSHORE(DON) Start Date:12/29/2012 End Date:2/15/2013 X3-0130L-C:DRILL(11,611,194.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/me:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/14/2013 00:00 - 03:30 3.50 DRILL P PROD1 BACK REAM OUT OF THE HOLE F/15,959'TO 14,050' -288 GPM,2420 PSI,120 RPM,13K TQ 03:30 - 04:30 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP INSIDE THE 7” CASING -285 GPM,2245 PSI,120 RPM -MW=8.6 PPG IN/8.6 PPG OUT 04:30 - 06:00 1.50 DRILL P PROD1 SLIP AND CUT 85'OF DRILL LINE 06:00 - 07:00 1.00 DRILL P PROD1 RIG SERVICE -SERVICE TOP DRIVE AND BLOCKS -CALIBRATE SLB,TOTCO&HION BLOCK HEIGHT 07:00 - 09:00 2.00 DRILL P PROD1 TIH ON ELEVATORS FROM 14,060'MD TO 17,891'MD -MONITORING TRIP VIA THE TRIP TANK MW=8.6 PPG IN/8.6PPG OUT 09:00 - 12:30 3.50 DRILL P PROD1 CIRCULATE AND CONDITION THE MUD -ROTATE AND RECIPROCATE F/17,891'MD TO 17,850'MD -285 GPM,2540 PSI,120 RPM,15K TQ SPR'S @ 17,886'MD,9,004'ND-MW=8.6 PPG,TIME=12:15 #1 MP-20/30 SPM=610/820 PSI #2 MP-20/30 SPM=620/820 PSI MONITOR WELL PRIOR TO PULLING OFF BOTTOM-WELL STATIC 12:30 - 15:30 3.00 DRILL-- P PROD1 POOH ON ELEVATORS FROM 17,891'MD TO THE 7"SHOE AT 14,060' -MONITOR TRIP VIA THE TRIP TANK 15:30 - 17:30 2.00 DRILL P PROD1 DROP 1.76"BALL TO OPEN THE MI WELL COMMANDER -PRESSURE UP TO 2010 PSI AND OBSERVE SHIFT OPEN -ROTATE&RECIPROCATE WHILE CIRCULATING -400 GPM,1615 PSI -PUW-202 K,SOW-149K,ROT -CLOSE CIRC SUB 17:30 - 18:00 0.50 DRILL P PROD1 MONITOR WELL PRIOR TO PULLING OUT OF THE HOLE-WELL STATIC -BLOW DOWN TOP DRIVE -PUMP DRY JOB 18:00 - 00:00 6.00 DRILL P PROD1 POOH WITH DRILLING BHA#8 ON ELEVATORS F/13,960'MD TO 3,327'MD -LD JARS&TWO JOINTS OF HWDP -CONTINUE POOH LAYING DOWN DOUBLES FROM 3,330'TO 1,990' LAYING DOWN DOUBLES TO THE PIPE SHED DAILY FLUID LOSS-23 BBLS 2/15/2013 00:00 - 03:00 3.00 DRILL P PROD1 POOH WITH DRILLING BHA#8 ON ELEVATORS F/3,327'MD TO 330' -PJSM FOR REMOVING THE SOURCE WITH SLB REP AND DDI HANDS -REMOVE SOURCE,BREAKAND LD MWD AND RSS -CLEAN AND CLEAR RIG FLOOR -BIT GRADE:3-1-BT-C-X-I-ER-TD Printed 3/4/2013 2:44:52PM North America-ALASKA-BP Page 1 of 5 Operation Summary Report Aga Common Well Name:Z-61 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/15/2013 End Date:2/20/2013 X3-0130L-C:DRILL(4,023,619.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.Oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/15/2013 03:00 - 11:30 8.50 BOPSUR P RUNPRD CLEAN&CLEAR RIG FLOOR.-TOP DRIVE SERVICE,CROWN INSPECTION-START PU CASING RUNNING EQUIPMENT. -ARRANGE LINER IN RUNNING ORDER -FUNCTION UPPER&LOWER RAMS, CLOSING TIMES 20 SEC EA -FUNCTION ANNULAR,CLOSING TIME-25 SEC 11:30 - 13:00 1.50 CASING P RUNPRD PJSM FOR LINER RUNING OPERATIONS -REEVIEW PLAN FORWARD FOR OPERATION RIH WITH 4-1/2" 12.6#HYDRIL 521 LINER -RIH WITH FLOAT EQUIPMENT,&TEST FLOATS-FLOATS GOOD 13:00 - 21:30 8.50 CASING P RUNPRD RIH WITH 4-1/2",12.6#HYDRIL 521 LINER -RIH AT 30 FT/MIN PER LINER RUNNING DETAIL FROM 96'TO 3,950' .-FILLING EVERY JOINT 21:30 - 23:00 1.50 CASING P RUNPRD M/U HANGER/PACKER ASSEMBLY AS PER BOT REP. MISHEAR JOINT. -MIX AND POUR PAL MIX -CIRC 1.5 X LINER VOLUME-90 BBLS -2.9 BPM,230 PSI -L/D SHEAR JOINT -ZERO LOSSES DURING CIRCULATION 23:00 - 00:00 1.00 CASING P RUNPRD RIH WI DP F/3,950'MD T/7,219 TO 4,075'MD. -FILL PIPE EVERY 10 STNDS -MONITOR DISP VIA PIT 2&3 LOSING-3-4 BPH,WHILE TRIPPING TOTAL LOSSES FOR THE DAY-66 BBLS 2/16/2013 00:00 - 13:00 13.00 CASING P RUNPRD TIH WITH 4-1/2"LINER ON 4"XT-39 DP F/ 4,075'TO 13,917'MD -MONITORING TRIP VIA PIT#2&3 -FILLING THE PIPE EVERY 10 STANDS CIRCULATING AT 13,442' 2.9 BPM,595 PSI -PUW-169K,SOW-129K, CONTINUE RIG F/13,917'TO TO 14,000',D 13:00 - 13:30 0.50 CASING P RUNPRD CIRCULATE AT 14,000' -2.9 BPM,625 PSI, -PUW-185K,SOW-132K,ROT-160K -TORQUE VALUES: 5 RPM-7K,10 RPM-7.2K,20 RPM-7.5K -CIRCULATE TOTAL OF 125 BBLS 13:30 - 18:30 5.00 CASING P RUNPRD TIH WITH 4-1/2"LINER ON 4"DP F/14,000'MD TO 16,844'MD -FILLING EVERY 10 STANDS,MONITORING DISPLACEMENT ON PIT 2 -STARTED TAKING WEIGHT F/16,091'MD TO 16,860' CIRCULATED OPEN HOLE VOLUME F/16,847' MD TO 16,860'MD TO -2 BPM 890 PSI CONTINUE TIH TO 16,940'MD -PUW-200K,SOW-132K 18:30 - 19:00 0.50 CASING P RUNPRD SERVICE RIG AND TROUBLE SHOOT LEAK ON TOP DRIVE 19:00 - 19:30 0.50 CASING N RREP RUNPRD REPAIR HYDRAULIC LEAK ON TOP DRIVE. Printed 3/4/2013 2:45:28PM North America-ALASKA-BP Page 2 of 5 Operation Summary Report Common Well Name:Z-61 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/15/2013 End Date:2/20/2013 X3-0130L-C:DRILL(4,023,619.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 23:00 3.50 CASING P RUNPRD TIH WITH 4-1/2"LINER ON 4"DP F 16,940'MD TO 17,891'MD -TAKING WEIGHT F/17,326'MD TO 17,891'MD - PUW-243K,SOW-110K 23:00 - 00:00 1.00 CASING P RUNPRD PICK UP 2'OFF BOTTOM -STAGE PUMPS UP TO 2.5 BPM WITH 1265 PSI LOSING BETWEEN 4-6 BPH AT 2.5 BPM WITH 1200 PSI 2/17/2013 00:00 - 02:30 2.50 CASING P RUNPRD CIRCULATE FULL BOTTOMS UP WITH CASING ON BOTTOM. -CIRCULATE AT 2.5 BPH,1250 PSI -CIRCULATED UNTILtltUD WAS CLEANED UP. LOSSES AT 2.5 BPH-4-6 BPH, -SLOWED PUMP TO 1.5 BPM,LOSSES DOWN TO ZERO. CONSULTED WITH TOWN ODE TO CONFIRM THE PUMPING QF OBM SPACERS. 02:30 - 03:00 0.50 CASING P RUNPRD PJSM FOR PUMPING SPACERS PER MI PUMPING SCHEDULE. -DISCUSSED MI PROCEDURE AND ROLES AND RESPONSIBILITIES FOR THIRD PARTIES AND DDI CIRCULATED AT 2.5 BPM,1280 PSI WHILE PIT WATCHER SUCKED OUT PITS 1-3. LOSSES RIGHT AT 4.5 BPH -MW IN/OUT,8.6PPG POWERPRO 03:00 - 07:30 4.50 CASING- P RUNPRD PUMPED OBM SPACER PER MI SCHEDULE PUMP 150 BBLS OF 8.6 PPG NACL W/2%KCL, AT 2.0 BPM,WITH 995 PSI -50 BBLS OF LVT BASE OIL -50 BBLS OF 9.6 PPG RHELIANT -127 BBLS OF 8.6 PPG RHELIANT OBM -15 BBL HIGH VIS RHELIANT AND HRP OIL -BREAK PIPE AND DROP 1.75"BALLAND PUMP REMAINDER OF HIGH VIS RHELIANT OPM,20 BBLS -CHASE WITH 8.6 PPG MOBM TO SEAT BALL IN WELLBORE ISOLATION VALVE -2 BPM,1100 PSI.BALL ON SEAT WITH 168 BBLS PUMPED. TOATL FLUID LOSS DURING OBM CIRCULATION-0 BBLS 07:30 - 09:00 1.50 CASING P RUNPRD SET LINER TOP HANGER AND PACKER -PRESSURE UP TO 2850 TO SET HANGER SLIPS,HOLD FOR 5 MIN -BLEED PSI TO 750 SLACK OFF TO 70 K TO VERIFY HANGER SET -PRESSURE UP TO 4000 PSI TO TO RELEASE HRD RUNNING TOOL,PU TO 250 K -HANGER DID NOT SET AND HRD-E TOOL DID NOT RELEASE -PRESSURE UP TO 2900 PSI TO SET HANGER ,SLACK OFF 72 K,CONFIRM HANGER SET -PRESSURE BACK UP TO 4200 PSI TO RELEASE HRD SETTING TOOL -SLACK OFF 30K AND ROTATE TO SET PACKER,PACKER SET AT 28 K. -SLACK OFF 50 K ON PACKER TO CONFIRM SET Printed 3/4/2013 2:45:28PM • • North America-ALASKA-BP Page 3 of 5 Operation Summary Report Common Well Name:Z-61 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/15/2013 End Date:2/20/2013 X3-0130L-C:DRILL(4,023,619.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 10:00 1.00 CASING P RUNPRD RU TO TEST 4-1/2"TBG BY 7"CASING LINER TOP PACKER :250 PSI LOW FOR 5 CHARTED MIN -3500 PSI HIGH FOR 30 CHARTED MIN. -PRESSURE BLED DOWN 60 PSI IN THE FIRST 15 MIN,44 PSI IN THE SECOND 15, -TEST CARRIED OUT ADDITIONAL 15 MIN& BLED DOWN 36 PSI IN THE LAST 15 MIN -FAILED TEST. 10:00 - 11:00 1.00 CASING P RUNPRD ROTATE AT 20 RPM'S,10 TQ,&SET 60 K ON PACKER TO CONFIRM SET 11:00 - 12:30 1.50 CASING P RUNPRD RU ANDRE-TEST LINER TOP PACKER -250 PSI LOW FOR 5 CHARTED MIN -3500 PSI HIGH FOR 30 CHARTED MIN. -LOST 95 PSI THE FIRST 15 MIN&24 PSI THE SECOND 5-GOOD TEST .-SENT RESULTS TO ODE AND ROTARY TEAM LEAD FOR APPROVAL. -RD TEST EQUIPMENT. 12:30 - 15:30 3.00 CASING P RUNPRD PICK UP TO REMOVE RS PACK OFF AND CIRCULATE WELL TO SEAWATER -PUMP 50 BBL VISCOSIFIED SEAWATER&50 BBLS OF SEAWATER/DEEP CLEAN -275 GPM,1040 PSI -P U W-196K,SOW-141K, -CLEAN OUT UNDER SHAKERS 15:30 - 00:00 8.50 CASING. P RUNPRD POOH WITH LINER RUNNING TOOL ON 4"DP, . LAYING DOWN DOUBLES TO THE PIPE SHED -FROM 13,940 MD TO 9,625 MD,MONITORING TRIP DISPLACEMENT VIA THE TRIP TANK -RIH F/9,625'MD TO 10,290'WITH STANDS FROM THE DERRICK -POOH LAYING DOWN SINGLES 2/18/2013 00:00 - 05:00 5.00 CASING P RUNPRD POOH WITH LINER RUNNING TOOL ON 4"DP. -LAYING DOWN SINGLES TO THE PIPE SHED -MONITORING TRIP VIA THE TRIP TANK 05:00 - 06:00 1.00 CASING P RUNPRD OUT OF THE HOLE WITH LINER RUNNING TOOL -VISUAL CONFIRMATION OF DOG SUB SHEAR -LAYDOWN TOOL. -C/O PS21 SPLIPS TO 5'AND PREP TO LAY DOWN 5"DP RACKED BACK IN THE DERRICK 06:00 - 10:30 4.50 CASING P RUNPRD LAY DOWN 15 STANDS OF 5"DP F/THE DERRICK USING THE MOUSE HOLE. -PULL WEAR RING,C/O ELEVATORS&SLIP INSERTS -MAKE DUMMY RUN WITH HANGER,AS DIRECTED BY FMC REP -LAY DOWN HANGER AND LANDING JOINT -RU DDI 4-1/2"TORQUE TURN EQPT -MU SHEAR JOINT WITH XO, DRIFT THE BALL AND ROD THRU -PREP PIPE SHED FOR RUNNING COMPLETION 10:30 - 00:00 13.50 RUNCOM P RUNCMP PJSM FOR RUNNING 4-1/2"VAM TOP COMPLETION -RIH WITH 4-1/2",12.6#,13CR85 VAM TOP COMPLETION FROM SURFACE TO 8,606'MD -MONITORING TRIP VIA THE TRIP TANK Printed 3/4/2013 2:45:28PM • North America-ALASKA-BP Page 4 of 5 z;M . Operation Summary Report Common Well Name:Z-61 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/15/2013 End Date 2/20/2013 X3-0130L-C:DRILL(4,023,619.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/19/2013 00:00 - 07:00 7.00 RUNCOM P RUNCMP -RIH WITH 4-1/2",12.6#,13CR85 VAM TOP COMPLETION FROM 8606'MD TO 13,892'MD, TAG UP ON DEPTH -MONITORING TRIP VIA THE TRIP TANK. 07:00 - 10:30 3.50 RUNCOM P RUNCMP SPACE OUT W/PUP JTS,PU/MU HANGER, DRAIN STACK,LAND HANGER -RUN IN LOCK DOWN SCREWS -RU CIRC LINE AND TEST TO 4,000 PSI,OK 10:30 - 12:30 2.00 RUNCOM P RUNCMP REVERSE CIRC 210 BBL 120 DEGREE 8.5 PPG SW @ 4 BPM/660 PSI FOLLOWED BY -180 BBL 120 DEGREE 8.5 PPG SW TREATED W/CORROSION INHIBITOR FOLLOWED BY -85 BBL 110 DEGREE 8.5 PPG SW 12:30 - 13:00 0.50 RUNCOM P RUNCMP PUMP 5 BBL SW DOWN TBG @ 3 BPM, 272 PSI -DROP 1 7/8"BALL AND ROD 13:00 - 15:30 2.50 RUNCOM P RUNCMP TEST TBG`250 PSI LOW/5 MIN, PRESSURE UP TO 4,000 PSI-SET PKR -CHART PRESSURE FOR 30 MIN,OK -BLEED PSI TO 2,500 PSI TEST IA 250 PSI LOW 5 MIN/4,000 PSI HIGH 30 MIN,Ok 15:30 - 16:00 0.50 RUNCOM P RUNCMP BLEED TBG TO 900 PSI,OBSERVE SHEAR @ 2400 PSI DIFFERENTIAL PRESSURE -PUMP 3 BBL IN IA @ 2 BPM 400 PSI -PUMP 3 BBL IN TBG @ 2 BPM 500 PSI 16:00 - 18:30 2.50 RUNCOM P RUNCMP RD LINES,PULL LDG JT -INSTALL TWC AS PER FMC REP -INSTALL LDG JT TEST 250 PSI LOW/3,500 PSI HIGH,FROM BELOW CHARTED 5/30 MIN OK,FROM ABOVE CHARTED 5/5 MIN,OK -RD TEST EQUIPMENT AND LINES 18:30 - 19:00 0.50 RUNCOM P RUNCMP CLEAR/CLEAN FLOOR -REMOVE 4.5 TBG HANDLING EQUIPMENTS 19:00 - 00:00 5.00 RUNCOM P RUNCMP PJSM,NIPPLE DOWN BOP'S AND MOVE TO TRANSPORT POSITION -SIMOPS=BRING DRY HOLE TREE AND ADAPTER FLANGE TO FLOOR AND MU. 2/20/2013 00:00 - 01:00 1.00 RUNCOM P RUNCMP LD HI-PSI RISER 01:00 - 03:30 2.50 RUNCOM P RUNCMP PREP X-MAS TREE AND MU SAME 03:30 - 05:00 1.50 RUNCOM P RUNCMP TESTADAPTER FLANGE 250 PSI LOW/ CHART 5 MIN,5000 PSI HIGH /10 MIN,OK 05:00 - 08:00 3.00 RUNCOM P RUNCMP TEST TREE W/DIESEL,CHART 250 PSI LOW/ 5 MIN,5000 PSI HIGH/10 MIN,OK 08:00 - 09:30 1.50 RIGD P RUNCMP RU DSM LUBRICATOR AND CHART TEST,250 PSI LOW AND 3500 HIGH/5 MIN, -PULL TWC -RD LUBRICATOR 09:30 - 10:30 1.00 RIGD P RUNCMP RU CIRC LINES -CHART TEST LINES AND INNER IA VALVE 250 PSI LOWAND 3500 HIGH/ 5 MIN,OK 10:30 - 13:30 3.00 RIGD P RUNCMP REVERSE CIRC 70 BBLS 80°DIESEL@ 1.5 BPM/500 PSI - ALLOW DIESEL TO U-TUBE -RD LINES Printed 3/4/2013 2:45.28PM • • North America-ALASKA-BP Page 5 of 5 f-F Operation Summary Report Common Well Name:Z-61 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/15/2013 End Date:2/20/2013 X3-0130L-C:DRILL(4,023,619.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/me:1/2/2013 12:00:00AM Rig Release:2/15/2013 Rig Contractor.DOYON DRILLING INC. UW: Active datum:Z-61 Actual @96.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 16:30 3.00 RIGD P RUNCMP RU DSM LUBRICATOR AND CHART TEST T 250 PSI LOW/3500 HIGH/ 5 MIN,OK -INSTALL BPV -RD DSM LUBRICATOR -INSTALL TREE GAUGE -CHART TEST BPV 250 PSI LOW/5MIN, 3500 PSI HIGH/30 MIN,OK 16:30 - 18:00 1.50 RIGD P RUNCMP DSM INSTALL AND TESTED VR PLUGS IN OA, SECURE WELL. -RIG RELEASE 18:00 HRS Printed 3/4/2013 2:4528PM o _ mmpm� m� � V E2E71 ',5 WWA0 O prnAnn AANPnn AsnPo o .7 . OS. 'gbh W N88888 88888 88888 8888 888 8mwmNw J 44444 4.1444 44444 444.14 .14.14'4 44.1.1.1 44444 44444 4 2 4 9QA8 mm VVL0g .12I p :=2,M22 W gnsN sNx00 s 7 r N N n 4'v2 .S222 -020r rEQNs Al...-1. 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Z Q Z U o 2 V x U Z J Y o i o o N a o m o @. ro E U - tm a o u CD v N 101 411/1 ............. � a Cl o �\,may�J VI VI N .1 X a CO 01 Q (' \`---7 v 7 1111111 P6ut Pi I z L 113U Rel, James B (DOA) Fiom: Madsen, Alan D (PRA) [Alan.Madsen@BP.com] /311'3 Sent: Tuesday, January 29, 2013 8:10 PM r ! To: Schultz, Mikel; DOA AOGCC Prudhoe Bay; Staudinger, Garret; Hefley, G Mike; Allen, Kenneth W; Burnett, Richard D; Cismoski, Doug A; Honas, Kristopher; Kilfoyle, Jeffery A; Mountford, Carl F Subject: Well shut in for exhale test Attachments: Z-61_BOP usage form_1-28-2013.doc Guys, Enclosed in the BOP usage form for the exhale test conducted last night on Doyon 25. «Z-61_ BOP usage form_1-28-2013.doc>> Alan Madsen GPB Rotary Field Superintendent Cell 306-4997 Slope office 659-4618 Anchorage office 564-5780 Those who turn their swords into plows will be ruled by those that don't. 1 11110 S 4. Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Alan Madsen Wellsite Leader Name: Garret Staudinger Contact Number: 907-659-4618 Contact Number: 659-5856 Traction Number: 4340718 Well Location/Name & Rig Name: Well Z-61. Doyon 25 Permit To Drill (PTD) Number: 212-113 Date and Time of Incident: 01/28/2013 20:30 Original Scope of Work: Drill 8-3/4" intermediate hole , Operational Description Leading up to Well Control Event: BOPE Used and Reason: Drilled 8-3/4" intermediate hole from 4,906' to 10,814'. Mud weight in hole was 10.7 ppg with losses at 10 bph. At 10,814' MD, decision made to backream to 9-5/8" shoe due to high ECDs. While backreaming, loss rate increased to 100 bph. After shutting down the pumps at 8,827' MD and monitoring for flow, slow flow was observed. Driller and WSL confirmed well was flowing with pumps o_ff, well was shut in using the fast shut in process as per BP standing orders to the driller. Is a BOPE Test Required after use ( Yes / No): If no, why? Yes. The Annular preventer will be tested when the BHA is out of the hole. 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: Perform Wellbore Breathing Exhale test through the choke. Shut in and observe well for pressure. If confirmed breathing, open up well. CBU with consistent mud weight in and out. Develop plan and get authorization to proceed. Will test Annular preventer after getting out of the hole with the drilling BHA. Additional Comments: After completing the exhale test, it was confirmed to be well bore breathing and normal operations resumed. Full body BOP test performed 1-24-2013. No failed equipment on test. ✓ Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bayCa alaska.gov Email CC List BP WSL Jeff Kilfoyle Wells Team Leader Operations Drilling Engineer-Well File Engineering Team Leader Drilling & Completions Engineer Manager Wells Operations Manager Wells Intervention Manager BOPE Usage Report for AOGCC Rev 1 September 1, 2010 16 c 1110 ili CASING AND LEAK-OFF FRACTURE TESTS Well Name: Z-61 Date: 1/17/2013 Csg Size/Wt/Grade: 13-3/8"#68 L80 Supervisor:Dinger/Knowles Csg Setting Depth: 2,109 TMD 2,031 TVD Mud Weight: 9.2 ppg Leakoff pressure= 380 psi LOT= 12.80 ppg Hole Depth= 2109and Fluid Pumped= 2.0 Bbls Volume Back= 1.0 bbls Estimated Pump Output: r 0.101 Barrels/Stroke LEAK-OFF DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here -> 0 100 -> 0 0 > 2 140 > 4 327 -> 4 180 -> 8 691 -> 6 220 -> 12 1070 -> 8 240 a 16 1270 > 10 272 a y 20 1570 > 12 295 a : 24 1863 -> 14 319 a P 28 2182 -> 16 343 a ' 32 2507 > 18 363 a 1 36 2844 -> 20 380 a 40 3196 -> 22 a 44 3540 -> 24 a 45 3650 1 > 26 a 52 Enter Holding Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here -> 0 -> 0 3645 -> 1 -> 5 3627 > 2 -> 10 3620 1 > 3 -> 15 — 3617 > 4 -> 16 3615 > 5 - -> 17 3614 -> 6 -> 18 3614 -> 7 -> 19 3613 1 > 8 -> 20 3613 -> 9 -> 21 3613 -> 10 -> 22 3611 -> -> 23 3610 > -> 24 3609 > > 4110 —a—LEAK-OFF DATA--II-CASING TEST DATA 4000 3900 3800 3700 3600 3500 3400 - 3300 3200 3100 3000 2900 2800 - 2700 2600 2500 2400 2300 2200 o. 2100 2000 T, 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 - 900 800 700 600 500 400 300 200 1 100 • 0 0 216.51 • Strokes(#of) PTD 212113 Z-61 Surface C ent Status Page 1 of 9 Schwartz, Guy L (DOA) From: Honas, Kristopher[Kristopher.Honas@bp.com] Sent: Thursday, January 17, 2013 4:39 PM To: Schwartz, Guy L (DOA) Subject: RE: PTD 212113 Z-61 Surface Cement Status Guy, A few events happened during this surface hole which indicated this surface hole was washed out. Here are details of the events. 1. Surveys at the base of the conductor showed that the conductor was not vertical but rather pointing towards the Northeast.This caused a shallow anti-collision issue with offset well Z-115. To avoid crossing tolerance lines the BHA was oriented to the low side of the hole and used to trough from 148 ft to 277 ft in an attempt to reduce the inclination of the wellbore building in the direction of Z-115. Initial drilling of this interval indicated the ground was hard/frozen, however, troughing operations from January 2nd at 20:30 hrs to January 3rd at 06:00 hrs (9.5hrs total) melted the shallow gravel and gravel began to run. This is considered a primary reason that the hole was washed out at surface and the 1st and 2nd top jobs did not achieve cement to surface. 2. On January 4th at 23:30 the cuttings tank off load line plugged while drilling ahead at 1080 ft MD. It took 15.5 hrs to unplug the cuttings tank off-load line. Hole washout is directly related to the amount of time the hole is open, so the extra 15.5 hrs of NPT allowed the mud to heat up the permafrost and likely washout the shallow surface interval more than normal. 3. 71 super sucker loads were required to haul off cuttings generated while drilling the Z-61 surface interval.This equates to —4118 bbls. In comparison, the 16" surface hole of Z-115 was only 32 super suckers or—1814 bbls. This definitely indicates that Z-61 has significant washout. 4. The total time from spud to rigging up to run casing was 4.98 days from 1/2/13 at 08:00 to 1/7/13 at 07:30. The average time required to do this hole interval to the planned depth with rig Doyon 25 is only 3.10 days. The excessive time is another indicator for hole washout. In response to expecting hole washout the excess volume during the primary cement job was increased from the standard 250%excess to 500%excess. Here is the operational summary of the Primary Cement Job on January 8th from 16:00 to midnight: CEMENT 13-3/8" SURFACE CASING AS FOLLOWS: - PJSM FOR 13-3/8" CEMENTING WITH SCHLUMBERGER AND CH2MHILL - LINE UP TO SCHLUMBERGER CEMENTERS. -ATTEMPT TO TEST LINES, FLASH FROZE LINE, THAW LINE - PUMP 20-BBLS OF WATER,TEST LINES TO 250/3500 PSI, 5-MINUTES EACH CHARTED, GOOD TEST. - PUMP 104 BBLS OF 11.0- PPG MUDPUSH II.TEST FIELD SAMPLE AS PER PROCEDURE. - DROP BOTTOM PLUG - PUMP 841-BBLS (2511 SX) 11.0-PPG LEAD DEEPCRETE CEMENT. YIELD 1.88 CUFT/SK - PUMP 34-BBLS(164.5 SX) 15.8-PPG CLASS "G" TAIL CEMENT. YIELD 1.16 CUFT/SK - DROP TOP PLUG. KICK OUT PLUG WITH 5-BBLS OF WATER. -SWITCH OVER TO RIG PUMPS FOR DISPLACEMENT - DISPLACE WITH 9.2 PPG DRILPLEX MUD - PUMP AT 8 BPM,WITH 460 PSI - LOSE RETURNS^'82 BBLS INTO DISPLACEMENT - REDUCE RATE TO 2 BPM, 330 PSI TO ESTABLISH RETURNS, UNSUCCESSFUL 1/18/2013 PTD 212113 Z-61 Surface C ent Status Page 2 of 9 -STAGE PUMP RATE UP TO 5 BPM, 570 PSI - REDUCED PUMP RATE TO 2 BPM,470 PSI FOR FINAL 10 BBLS PRIOR TO BUMPING PLUG - PLUG BUMPED AT 295.7 BBLS INTO DISPLACEMENT - 307.7 BBLS CALCULATED DISPLACEMENT - HELD 500 PSI OVER FINAL CIRCULATING RATE - BLEED PRESSURE & CHECK FLOATS, FLOATS HOLDING. TOTAL LOSS WHILE PUMPING CEMENT-174 BBLS TOTAL LOSSES WHILE PUMPING DISPLACEMET- 276 During this primary cement job, the well packed-off 82 bbls into the displacement. It is not known why the pack- off occurred. The rig then ran in the hole on drill pipe and shifted open the TAM Port Collar at 509 ft and attempted to establish circulation. Circulation could not be established on January 9th from 02:30 to 15:00. Partial returns were established at 15:00 hrs and the rig worked until 19:30 restoring 25% returns.Additional efforts to condition the hole and increase returns did not help. The second stage cement job through the port collar was started on January 9th at 19:30. Below is the time summary from the daily drilling reports: PJSM FOR CEMENT JOB WITH RIG CREW, SLB AND THIRD PARTY SUPPRORT. PUMP REMEDIAL JOB THROUGH TAM PORT COLLAR - PJSM ON CMT JOB WITH SLB, DOYON, MI - BLOW AIR THROUGH CEMENT LINE, RU CHART RECORDER - PUMP 10 BBLS OF H2O, TEST STALL - PRESSURE TEST LINES 250/3500 PSI FOR 5/5 CHARTED MIN EACH - PUMP 25 BBLS OF 10 PPG MUDPUSH II AT 2 BPM, 425 PSI -—15% RETURNS - PUMP 312 BBLS OF 11PPG LITECRETE AT 2 BPM, 450 PSI - PUMP PRESSURE FALLING 50 PSI FOR EVERY 90 BBLS PUMPED, REGAINING 50 PSI OVER ADDITIONAL 90 BBLS PUMPED - 15 % RETURNS WHILE PUMPING CEMENT.ALL RETURNS TAKEN TO THE CELLAR. - DISPLACE WITH 6 BBLS OF MUD PUSH - ROTATE SHIFTING TOOL AND CLOSE TAM PORT COLLAR - PRESSURE TO 1500 PSI, CONFIRM PORT IS CLOSED. NO CEMENT RETURNED TO SURFACE, TOTAL OF 47 BBLS OF 9.2 PPG MUD RETURNED TO SURFACE DAILY MUD LOSS= 743 BBLS 312 bbls of cement were pumped through the port collar, however, with only 15% returns during the job,the majority of this cement was injected into formation. After the cement job was completed the formation had been charged due to fluid injection during the cement job and while attempting to establish circulation.The casing x conductor annulus was monitored from January 10th at 00:00 to January 11th 13:30 prior to removing the diverter for the top job due to flow caused by the charged formation. After the Diverter was removed, 1-1/4" pipe was run down the conductor x casing annulus to a depth of 140 ft. This depth was verified by AOGCC representative John Crisp on January 11th at 23:00. The first cement top job was pumped through the 1-1/4" pipe as described in the Daily reports summary below on January 12th from 00:00 to 04:00 1/18/2013 PTD 212113 Z-61 Surface C ent Status � Page 3 of 9 PJSM FOR CEMENT JOB -AOGCC REP.JOHN CRISP- PRESENT FOR JOB -CIRCULATE 9.2 PPG MUD TO CLEAR THE 1-1/4" LINE - PUMPED 10 BBLS OF WATER AHEAD TO HEAT THE LINES,TAKING RETURNS TO THE CUTTINGS TANK - PUMP 196 BBLS, 15.7 PPG ARCTIC SET-1 CEMENT - PUMPED CEMENT AT 1 BPM, PRESSURE RANGE 90-100 PSI - FOR EVERY 1 BBLS CEMENT PUMPED, 1 BBLS OF 9.2 PPG MUD RETURNED AT SURFACE FOR ENTIRE JOB - PUMPED 3 BBLS OF WATER BEHIND TO CLEAR THE HYDRIL PIPE - NO CEMENT TO SURFACE Although full returns were achieved throughout job, cement is believed to have been filling washouts in the wellbore and displacing out drilling mud. Additional cement was blended and sent to the rig for a 2nd cement top job beginning January 12th at 21:00. The time summary from the daily report is shown below. PUMP SECOND TOP JOB TO SURFACE - HOLD PJSM W/SLB, WSL, DDI - PUMP 5 BBLS H2O - PT CEMENTING LINES - 1200 PSI (GOOD) - PUMP 255 BBLS, 10.7 PPG ARCTIC SET LITE CEMENT -2.5 BPM, 250 PSI - PUMP 212 BBLS 15.7 PPG ARCTIC SET-1 - 2.5 BPM,400 PSI - 100% RETURNS- 467 BBLS OF CEMENT PUMPED, 467 BBLS 9.2 PPG MUD RETURNED TO SURFACE - NO INDICATIONS OF CEMENT AT SURFACE While working to load out additional cement, phase 3 weather conditions shut down all travel on the slope.The rig waited on weather conditions to improve from January 13th at 11:00 until January 15th at 10:30. ^'1 bbl was pumped down the 1.25" pipe each hour while waiting to maintain circulation. While waiting on SLB to load out cement, the rig tested BOPE equipment and ran in hole with the drilling BHA to circulate inside the surface casing to prevent freezing. On January 16th at 03:00 the rig was prepared to pump the 3rd top job through the 1.25" pipe at 140 ft. The daily time summary is below: PJSM FOR PUMPING TOP OUT CEMENT JOB PUMP TOP OUT CEMENT JOB#3 - PUMP 5 BBLS H2O TO HEAT LINES TAKING RETURNS TO CUTTINGS TANK - BATCHING 15.8 PPG CLASS G CEMENT - PT CEMENTING LINES - 1200 PSI (GOOD) - PUMP 476 BBLS, 15.8 PPG, 1.16 CUFT/SK, "G" CLASS CEMENT, 2304 SACKS -2.5-3 BPM, 650-1000 PSI - 83 BBLS RETURNED TO SURFACE During this job,full returns were never achieved.The precise reason for this is unknown, however,theories include: cement above the bottom of the 1.25" stinger thickened to a point that it could not be pumped,or a 1/18/2013 PTD 212113 Z-61 Surface C ent Status Page 4 of 9 pack-off due to sloughing gravel may have occurred. In any case, the majority of the cement pumped during this job was injected. Following the cement job,the shallow formation was charged and slight flow was observed and monitored up the conductor x casing annulus.The pH of these returns was higher than the drilling fluid and smelled like cement.This lead to the decision that cement returns to surface could be achieved if another top job was performed using the same 1.25" pipe. While waiting on cement to be loaded out,the rig slipped new drilling line. The 4th top job began on January 16th at 17:30.The time summary is below: PJSM FOR PUMPING TOP OUT CEMENT JOB PUMP TOP OUT CEMENT JOB#4 - PUMP 5 BBLS H2O TO HEAT LINES TAKING RETURNS TO CUTTINGS TANK - BATCHING 15.8 PPG CLASS G CEMENT - PT CEMENTING LINES - 1200 PSI (GOOD) - PUMP 448 BBLS, 15.8 PPG, 1.16 CUFT/SK, "G" CLASS CEMENT, 2468 SACKS - PUMPING AT 1 BPM,450 PSI -84 BBLS RETURNED TO SURFACE DURING CEMENT JOB The results of this top job were the same as the previous job with most of the cement being injected. Based on the results of this top job, it became evident that a second string of 1.25" pipe needed to be run. This was completed late last night and the 5th cement top job was pumped this morning (January 17th). During this job a total of 100 bbls of AS1 at 15.7 ppg were pumped with full returns. Cement reached surface approximately 40 bbls into the job. I can answer any additional question you may have. Please feel free to call or email. Our plan forward will be to drill out of the shoe, perform an LOT, drill to 12.25" TD, run 9-5/8" liner and cement. We will then run a CBL over the 13-3/8" surface casing string. Kris Honas BP Rotary Drilling Engineer Desk: 907-564-4841 Cell: 907-268-0891 Kristopher.Honas@bp.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, January 17, 2013 1:41 PM To: Honas, Kristopher Cc: Allen, Kenneth W; Schultz, Mikel; AK, D&C Rig 25 Well Site Leader; Regg, James B (DOA) Subject: RE: PTD 212113 Z-61 Surface Cement Status Kris, As long as you have cement to surface you have approval to drill out and perform LOT as per the PTD. Assuming that goes as planned once the intermediate 9 5/8" casing is cemented the Commission is still requesting a CBL (USIT)to be run over the 13 3/8" casing to see if we can determine anything what happened during this surface hole section. Additionally, please provide the Commission with an explanation as to what happened (with an operational summary) to cause such a large cement volume to be needed. . Was this expected before cementing started? . ... Flow paddle was removed for first 1000 ft I believe ... were cuttings excessive during surface hole ... thaw bulb issues ? . Mud temperature ? Lost circulation near surface during 3rd and 4th top jobs.? etc. 1/18/2013 PTD 212113 Z-61 Surface Cent Status Page 5 of 9 Cent Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Honas, Kristopher [mailto:Kristopher.Honas@bp.com] Sent: Thursday, January 17, 2013 12:15 PM To: Schwartz, Guy L(DOA) Cc: Allen, Kenneth W; Schultz, Mikel; AK, D&C Rig 25 Well Site Leader Subject: RE: PTD 212113 Z-61 Surface Cement Status Guy, We have achieved cement returns to surface on our 5th top job attempt. Below is a summary of the entire cementing operation for the Z-61 surface hole. Pending any objections, we plan to drill out of the shoe to complete our short 12.25" hole section later this afternoon. We would like to confirm the AOGCC's earlier request for CBL over the 13-3/8" surface interval now that we have achieved cement to surface. Primary Cement Job: 841 bbls of 11.0 ppg DeepCRETE 34 bbls of 15.8 ppg Class G Summary: Lost returns 82 bbls into displacement when pack-off occurred. Second Stage Cement Job: 312 bbls of 11.0 ppg DeepCRETE Summary: Pump through port collar at''509 ft with only^'15% returns during job. 1st Top Job: 196 bbls of 15.7 ppg ArticSet I Summary: 1-1/4" pipe ran to 140 ft,full returns throughout job, but no returns to surface 2nd Top Job: 225 bbls of 10.7 ArticSet Light 212 bbls of 15.7 ArticSet 1 Summary: Pump through same 1-1/4" pipe at 140 ft with full returns but no cement to surface. 3rd Top Job: 476 bbls of 15.8 Class G Summary: Pump through same 1-1/4" pipe at 140 ft with only 17% returns during job, no cement to surface but pH did increase to^'12.5 4th Top Job: 448 bbls of 15.8 Class G Summary: Pump through same 1-1/4" pipe at 140 ft with only 19%returns during job, no cement to surface but pH remained at—12.5 1/18/2013 PTD 212113 Z-61 Surface C ent Status 4116 Page 6 of 9 5th Top Job 100 bbls of 15.7 ppg ArticSet 1 (exact volume to be confirmed on final report from SLB) Summary: Ran a second 1-1/4" pipe down to 87 ft("7ft outside conductor). No difficultly running pipe until tagged up on something hard at 87 ft. Began pumping cement with cement returns to surface after—40 bbls. Continue to pump an additional 60 bbls of cement to improve displacement. Final Summary: A total of 2844 bbls of cement have been pumped. Again, we are looking for confirmation on the requirement for a CBL over the surface casing. We would also like to know if there is any objection to drilling out of the shoe this afternoon to perform a LOT.Thank you, and please call if you would like to discuss any of the cementing operations in further detail. Kris Honas BP Rotary Drilling Engineer Desk: 907-564-4841 Cell: 907-268-0891 Knstopher Honas(a�bp.com From: Schwartz, Guy L(DOA) [mailto:guy.schwartz©alaska.gov] Sent: Wednesday, January 16, 2013 5:18 PM To: Honas, Kristopher Subject: RE: PTD 212113 Z-61 Surface Cement Status Thanks ... I figured the Phase 3 was slowing you down. This must be getting close to a record volume for surface cmt. !! Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Honas, Kristopher [mailto:Kristopher.Honas()bp.com] Sent: Wednesday, January 16, 2013 4:54 PM To: Schwartz, Guy L(DOA) Subject: RE: PTD 212113 Z-61 Surface Cement Status Guy, I know the rig has been keeping the state representatives on the slope up-to-date on the Z-61 surface cement work, but I suspect you would like a brief update too. We have now performed 3 top jobs through 1" pipe run down to 140 ft totaling >1100 bbls of cement. We have not achieved cement to surface, however, we have seen a significant spike in pH and a very small increase in density. We plan to pump an additional 100 bbls of cement late this afternoon. During the last top job we lost the majority of our returns, we believe that cement from the previous top jobs has finally reached a depth above the bottom of the cement stinger, restricting flow. If we do not get cement to surface during the next 100 bbl cement job, then we will run a second 1" pipe to the deepest depth possible and begin pumping cement again with full returns. Phase 3 weather and waiting on cement to be blended and delivered to the rig between jobs has made this a 1/18/2013 PTD 212113 Z-61 Surface C ent Status Page 7 of 9 lengthy process, but we will continue to work to achieve cement to surface. Please let me know if I can answer any questions. Thanks, Kris Honas BP Rotary Drilling Engineer Desk: 907-564-4841 Cell: 907-268-0891 Kristopher.Honas cni bp.com From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, January 10, 2013 8:28 AM To: Honas, Kristopher Cc: Allen, Kenneth W; Schultz, Mikel; AK, D&C Rig 25 Well Site Leader; Regg, James B (DOA) Subject: RE: PTD 212113 Z-61 Surface Cement Status Kris, Thanks for the update. If you tag shallow with washpipe (less than 100') let me know also and be sure to contact the slope inspectors to witness the top job. Call me later today about CBL requirements for the 13 3/8" surface casing... my cell phone will be best. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Honas, Kristopher [mailto:Kristopher.Honas@bp.com] Sent:Thursday, January 10, 2013 7:04 AM To: Schwartz, Guy L (DOA) Cc: Allen, Kenneth W; Schultz, Mikel; AK, D&C Rig 25 Well Site Leader Subject: RE: PTD 212113 Z-61 Surface Cement Status Guy, We were still unable to achieve cement returns to surface last night through the Port Collar.Current plan forward is to run 1" pipe down the conductor to as deep as possible and pumps cement until good returns reach surface.Anticipated start of Top Job will be early this afternoon.After drilling and running the 9-5/8" liner we will run a CBL over the surface casing. I will try to call you today to discuss the results/requirements of the CBL in further detail.Thanks, Kris Honas BP Rotary Drilling Engineer Desk: 907-564-4841 Cell. 907-268-0891 Kristopher.Honas(c�bp.com From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@)alaska.gov] Sent: Wednesday,January 09, 2013 8:11 PM To: Honas, Kristopher Subject: Re: PTD 212113 Z-61 Surface Cement Status Chris, Waiting to drill out the 12 1/4" hole and log both casing strings is fine. Keep me posted on how the port collar job goes. • 1/18/2013 PTD 212113 Z-61 Surface C ent Status Page 8 of 9 Guy Sent from my iPhone On Jan 9, 2013, at 5:15 PM, "Honas, Kristopher" <Kristopher.Honas@bp.com> wrote: Guy, We can do a CBL or USIT. My one question is; would you be willing to allow us to drill the short 12.25" interval down to the Ugnu and run our 9-5/8" liner prior to running the CBL?The UCA time for the 11.0 ppg DeepCRETE cement is pretty significant(58 hrs to 500 psi). As you can see the Liner only covers^'150 ft of the surface shoe and the 12.25" hole will be drilled to a depth shallower than any hydrocarbon zones. This would allow time for the cement to gain compressive strength and provide a much better log. Also the heat of the drilling mud in the next section would help with gaining compressive strength. On a positive note,just before starting our squeeze cement job we broke through the pack-off and have partial returns now. The cement job through the Port Collar will have a chance of bringing cement to surface. We will know by morning if this was successful and a top job is not necessary. Thanks, Kris Honas BP Rotary Drilling Engineer Desk: 907-564-4841 Cell: 907-268-0891 Kristopher Honas@bp.com From: Schwartz, Guy L (DOA) [mailto:quy.schwartz@alaska.gov] Sent: Wednesday, January 09, 2013 4:09 PM To: Honas, Kristopher; Regg, James B (DOA) Cc: Allen, Kenneth W; AK, D&C Rig 25 Well Site Leader; Schultz, Mikel Subject: RE: PTD 212113 Z-61 Surface Cement Status Kris, Based on the information you provided the Commission is requesting a CBL (USIT or CBL)to evaluate the Surface casing cement placement after you finish the top job. Your proposed steps are appropriate considering the circumstances. Call me if you have any questions. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Honas, Kristopher [mailto:Kristopher.Honas@bp.com] Sent: Wednesday, January 09, 2013 12:38 PM To: Schwartz, Guy L(DOA); Regg, James B (DOA) Cc: Allen, Kenneth W; AK, D&C Rig 25 Well Site Leader; Schultz, Mikel Subject: PTD 212113 Z-61 Surface Cement Status • 1/18/2013 PTD 212113 Z-61 Surface C ent Status Page 9 of 9 Jim and Guy, Last night we attempted to cement the 13-3/8" surface casing on well Z-61. 82 bbls into the displacement,the hole packed off and we lost returns. We have opened the Port Collar placed at 507 ft and have not been able to establish circulation. We believe the pack-off is located at "400 ft where some wood and running gravel gave us difficulty while drilling. We believe TOC from the primary cement job is at or above the Port Collar for the following reasons: We pumped a total of 875 bbls of cement. Losses did not occur until 82 bbls into the displacement.This would bring the top of cement to 556 ft prior to losses even when 500% excess volume is assumed for hole washout in the permafrost. If 400%excess volume is assumed for washout,then TOC would have reached 284 ft prior to losses. 400%-500% excess is being conservative considering our general rule of thumb is to plan with 250% excess. Also,the fact that circulation cannot be established above the Port Collar would lead us to believe the hole packed off as cement reached the trouble zone around 400 ft. Our current plan forward is to squeeze cement through the Port Collar, placing a total of 100 additional bbls of cement into the annulus. Following this operation,we plan to run 1" pipe down the conductor x 13-3/8" annulus to as deep a depth as possible to perform a Top Job, we will continue to pump until good cement returns reach surface. Please let me know if I can answer any questions or concerns over our current path forward operations. Thank you, Kris Honas BP Rotary Drilling Engineer Desk: 907-564-4841 Cell: 907-268-0891 Kristopher.Honasbp corn <Z-61 Simple Schematic.pdf 1/18/2013 iii•• -ilTD 212113 Z-61 Surface C ent StatusPage 1 of 6 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, January 17, 2013 1:41 PM To: 'Honas, Kristopher' Cc: Allen, Kenneth W; Schultz, Mikel; AK, D&C Rig 25 Well Site Leader; Regg, James B (DOA) Subject: RE: PTD 212113 Z-61 Surface Cement Status Kris, As long as you have cement to surface you have approval to drill out and perform LOT as per the PTD. Assuming that goes as planned once the intermediate 9 5/8" casing is cemented the Commission is still requesting a CBL (USIT) to be run over the 13 3/8" casing to see if we can determine anything what happened during this surface hole section. Additionally, please provide the Commission with an explanation as to what happened (with an operational summary) to cause such a large cement volume to be needed. . Was this expected before cementing started'? . ... Flow paddle was removed for first 1000 ft I believe ... were cuttings excessive during surface hole ... thaw bulb issues ? . Mud temperature ? Lost circulation near surface during 3rd and 4th top jobs.? etc. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Honas, Kristopher [mailto:Kristopher.Honas@bp.com] Sent: Thursday, January 17, 2013 12:15 PM To: Schwartz, Guy L (DOA) Cc: Allen, Kenneth W; Schultz, Mikel; AK, D&C Rig 25 Well Site Leader Subject: RE: PTD 212113 Z-61 Surface Cement Status Guy, We have achieved cement returns to surface on our 5th top job attempt. Below is a summary of the entire cementing operation for the Z-61 surface hole. Pending any objections, we plan to drill out of the shoe to complete our short 12.25" hole section later this afternoon. We would like to confirm the AOGCC's earlier request for CBL over the 13-3/8" surface interval now that we have achieved cement to surface. Primary Cement Job: 841 bbls of 11.0 ppg DeepCRETE 34 bbls of 15.8 ppg Class G Summary: Lost returns 82 bbls into displacement when pack-off occurred. Second Stage Cement Job: 312 bbls of 11.0 ppg DeepCRETE Summary: Pump through port collar at—509 ft with only "15% returns during job. 1St Top Job: 1/17/2013 PTD 212113 Z-61 Surface ent Status Page 2 of 6 196 bbls of 15.7 ppg ArticSet I Summary: 1-1/4" pipe ran to 140 ft,full returns throughout job, but no returns to surface 2nd Top Job: 225 bbls of 10.7 ArticSet Light 212 bbls of 15.7 ArticSet 1 Summary: Pump through same 1-1/4" pipe at 140 ft with full returns but no cement to surface. 3rd Top Job: 476 bbls of 15.8 Class G Summary: Pump through same 1-1/4" pipe at 140 ft with only 17% returns during job, no cement to surface but pH did increase to"'12.5 4th Top Job: 448 bbls of 15.8 Class G Summary: Pump through same 1-1/4" pipe at 140 ft with only 19%returns during job, no cement to surface but pH remained at"'12.5 5th Top Job ' 100 bbls of 15.7 ppg ArticSet 1 (exact volume to be confirmed on final report from SLB) Summary: Ran a second 1-1/4" pipe down to 87 ft ("7ft outside conductor). No difficultly running pipe until tagged up on something hard at 87 ft. Began pumping cement with cement returns to surface after"'40 bbls. Continue to pump an additional 60 bbls of cement to improve displacement. Final Summary: A total of 2844 bbls of cement have been pumped. Again, we are looking for confirmation on the requirement for a CBL over the surface casing. We would also like to know if there is any objection to drilling out of the shoe this afternoon to perform a LOT.Thank you, and please call if you would like to discuss any of the cementing operations in further detail. Kris Honas BP Rotary Drilling Engineer Desk: 907-564-4841 Cell: 907-268-0891 Kristopher.Honas@bp.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, January 16, 2013 5:18 PM To: Honas, Kristopher Subject: RE: PTD 212113 Z-61 Surface Cement Status Thanks ... I figured the Phase 3 was slowing you down. This must be getting close to a record volume for surface cmt. !! Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 1/17/2013 iTD 212113 Z-61 Surface Cement Status Page 3 of 6 411110 From: Honas, Kristopher [mailto:Kristopher.Honas@ ibp.com] Sent: Wednesday, January 16, 2013 4:54 PM To: Schwartz, Guy L(DOA) Subject: RE: PTD 212113 Z-61 Surface Cement Status Guy, I know the rig has been keeping the state representatives on the slope up-to-date on the Z-61 surface cement work, but I suspect you would like a brief update too. We have now performed 3 top jobs through 1" pipe run down to 140 ft totaling >1100 bbls of cement. We have not achieved cement to surface, however, we have seen a significant spike in pH and a very small increase in density. We plan to pump an additional 100 bbls of cement late this afternoon. During the last top job we lost the majority of our returns, we believe that cement from the previous top jobs has finally reached a depth above the bottom of the cement stinger, restricting flow. If we do not get cement to surface during the next 100 bbl cement job, then we will run a second 1" pipe to the deepest depth possible and begin pumping cement again with full returns. Phase 3 weather and waiting on cement to be blended and delivered to the rig between jobs has made this a lengthy process, but we will continue to work to achieve cement to surface. Please let me know if I can answer any questions. Thanks, Kris Honas BP Rotary Drilling Engineer Desk: 907-564-4841 Cell: 907-268-0891 Kristopher.Honasna bp.corn From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, January 10, 2013 8:28 AM To: Honas, Kristopher Cc: Allen, Kenneth W; Schultz, Mikel; AK, D&C Rig 25 Well Site Leader; Regg, James B (DOA) Subject: RE: PTD 212113 Z-61 Surface Cement Status Kris, Thanks for the update. If you tag shallow with washpipe (less than 100') let me know also and be sure to contact the slope inspectors to witness the top job. Call me later today about CBL requirements for the 13 3/8" surface casing... my cell phone will be best. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Honas, Kristopher [mailto:Kristopher.Honas@bp.com] Sent:Thursday, January 10, 2013 7:04 AM To: Schwartz, Guy L(DOA) Cc: Allen, Kenneth W; Schultz, Mikel; AK, D&C Rig 25 Well Site Leader Subject: RE: PTD 212113 Z-61 Surface Cement Status Guy, 1/17/2013 41` ?ID 212113 Z-61 Surface C ent Status Page 4 of 6 We were still unable to achieve cement returns to surface last night through the Port Collar. Current plan forward is to run 1" pipe down the conductor to as deep as possible and pumps cement until good returns reach surface. Anticipated start of Top Job will be early this afternoon. After drilling and running the 9-5/8" liner we will run a CBL over the surface casing. I will try to call you today to discuss the results/requirements of the CBL in further detail. Thanks, Kris Honas BP Rotary Drilling Engineer Desk. 907-564-4841 Cell: 907-268-0891 Kristopher.Honas(a�bp.com From: Schwartz, Guy L (DOA) [mailto:cJuy.schwartz@alaska.gov] Sent: Wednesday, January 09, 2013 8:11 PM To: Honas, Kristopher Subject: Re: PTD 212113 Z-61 Surface Cement Status Chris, Waiting to drill out the 12 1/4" hole and log both casing strings is fine. Keep me posted on how the port collar job goes. Guy Sent from my iPhone On Jan 9, 2013, at 5:15 PM, "Honas, Kristopher" <Kristopher.Honasgbp.com> wrote: Guy, We can do a CBL or USIT. My one question is; would you be willing to allow us to drill the short 12.25" interval down to the Ugnu and run our 9-5/8" liner prior to running the CBL?The UCA time for the 11.0 ppg DeepCRETE cement is pretty significant (58 hrs to 500 psi).As you can see the Liner only covers—150 ft of the surface shoe and the 12.25" hole will be drilled to a depth shallower than any hydrocarbon zones. This would allow time for the cement to gain compressive strength and provide a much better log. Also the heat of the drilling mud in the next section would help with gaining compressive strength. On a positive note,just before starting our squeeze cement job we broke through the pack-off and have partial returns now.The cement job through the Port Collar will have a chance of bringing cement to surface. We will know by morning if this was successful and a top job is not necessary. Thanks, Kris Honas BP Rotary Drilling Engineer Desk: 907-564-4841 Cell: 907-268-0891 Kristopher.Honas(a�bp.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, January 09, 2013 4:09 PM To: Honas, Kristopher; Regg, James B (DOA) Cc: Allen, Kenneth W; AK, D&C Rig 25 Well Site Leader; Schultz, Mikel Subject: RE: PTD 212113 Z-61 Surface Cement Status 1/17/2013 ` , 1"FD 212113 Z-61 Surface C dient Status + Page 5 of 6 ll Kris, Based on the information you provided the Commission is requesting a CBL (USIT or CBL)to evaluate the Surface casing cement placement after you finish the top job. Your proposed steps are appropriate considering the circumstances. Call me if you have any questions. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Honas, Kristopher [mailto:Kristopher.Honas@bp.com] Sent: Wednesday, January 09, 2013 12:38 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA) Cc: Allen, Kenneth W; AK, D&C Rig 25 Well Site Leader; Schultz, Mikel Subject: PTD 212113 Z-61 Surface Cement Status Jim and Guy, Last night we attempted to cement the 13-3/8" surface casing on well Z-61. 82 bbls into the displacement,the hole packed off and we lost returns. We have opened the Port Collar placed at 507 ft and have not been able to establish circulation. We believe the pack-off is located at—400 ft where some wood and running gravel gave us difficulty while drilling. We believe TOC from the primary cement job is at or above the Port Collar for the following reasons: We pumped a total of 875 bbls of cement. Losses did not occur until 82 bbls into the displacement. This would bring the top of cement to 556 ft prior to losses even when 500% excess volume is assumed for hole washout in the permafrost. If 400%excess volume is assumed for washout,then TOC would have reached 284 ft prior to losses. 400%-500% excess is being conservative considering our general rule of thumb is to plan with 250% excess. Also,the fact that circulation cannot be established above the Port Collar would lead us to believe the hole packed off as cement reached the trouble zone around 400 ft. Our current plan forward is to squeeze cement through the Port Collar, placing a total of 100 additional bbls of cement into the annulus. Following this operation,we plan to run 1" pipe down the conductor x 13-3/8" annulus to as deep a depth as possible to perform a Top Job, we will continue to pump until good cement returns reach surface. Please let me know if I can answer any questions or concerns over our current path forward operations. Thank you, Kris Honas BP Rotary Drilling Engineer Desk: 907-564-4841 1/17/2013 ii „'PTD 212113 Z-61 Surface C int Status -, Page 6 of 6 Cell: 907-268-0891 Kristopher Honas(c�bp.com <Z-61 Simple Schematic.pdf 1/17/2013 sitiA7 /E ti /si PARNELL, GOVERNOR Q ALASKA. OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Ken Allen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z-61 BP Exploration (Alaska), Inc. Permit No: 212-113 Surface Location: 4434' FSL, 2747' FEL, Sec. 19, T11N, R12E, UM Bottomhole Location: 826' FSL, 63' FEL, Sec. 01, T11N, R11E, UM Dear Mr. Allen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, /9 95te./vitz Cathy P Foerster Chair DATED this day of August, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED ALAS. JIL AND GAS CONSERVATION COMM_ JN AUG 6 2012 PERMIT TO DRILL 20 MC 25.005 _ 1 a.Type of work: 1 b Proposed Well Class. ®Development Oil 0 Service-Winj ' ®Single Zone lc. Spe rf "iT`aGe iged for: ®Drill ' 0 Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates 0 Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas 2. Operator Name: 5 Bond: ®Blanket 0 Single Well 11 Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 • PBU Z-61 3. Address. 6. Proposed Depth: 12 Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 17891' • TVD 9032' • Prudhoe Bay/Prudhoe Bay 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Surface. ADL 028262,047450&028240 4434' FSL,2747' FEL, Sec. 19,T11N, R12E, UM • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date. 3847' FSL,2512' FEL, Sec. 07,T11N, R12E, UM November 1, 2012 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property 826' FSL,63' FEL, Sec.01,T11N, R11 E, UM 2560 12300' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10 KB Elevation above MSL. 96.7' feet 15.Distance to Nearest Well Open Surface: x- 599929. y-5959240. Zone- ASP4 GL Elevation above MSL: 55.9' feet to Same Pool: 342' 16 Deviated Wells. Kickoff Depth. 300' feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 97 degrees Downhole: 3543 ' Surface: 2754 ' 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 20" 94# H-40 80' Surface Surface 80' 80' 260 sx Arctic Set(Approx.) 16" 13-3/8" 68# L-80 BTC-M 2638' Surface Surface 2638' 2417' 1692 sx DeepCrete, 309 sx Class'G' 12-1/4" 9-5/8" 40# L-80 BTC-M 2392' 2488' 2313' 4880' 3517' 1050 sx Class'G' 8-3/4" 7" 26# L-80 VamTop 14093' Surface Surface 14093' 8785' 819 sx LiteCrete, 99 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr80 VamTop 3943' 13943' 8662' 17891' 9032' 3a3•ss(-Gferset', Swell Packers s,./c.- 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth TVD (ft). Plugs(measured). Effective Depth MD(ft). Effective Depth ND(ft) Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface _ Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20.Attachments: ®Property Plat ®BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis ®Diverter Sketch 0 Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21 Verbal Approval. Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct Contact Kris Honas,564-4841 Printed Name Ken Allen Title Engineering Team Leader Prepared By Name/Number Signature ..„/ "12.,---- Phone 564-4366 Date?A/2. Joe Lastufka,564-4091 Commission Use Only Permit To Drill API Number: , Permit r val D te: See cover letter for Number: 2.1 Z. I i 1 50-02,6P- 1-7qZ 3` - - I2 other requirements Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales: Ero Other 4-3 S� �S �� GS Samples Req'd: ❑Yes p No Mud Log Req'd: ❑Y's le No - /OG t)r ���� HZS Measures: Yes ❑No Directional Survey Req'd. ©/Yes ❑No get rGmau .4y4c-Ls. 033 C._j p - -fin _ I c.746, f R ED BY THE COMMISSION Date fJ cam/ ,COMMISSIONER Form 10-401 Revised 07/2009 his permit is valid for 24 months from the date of approval(20AC 25.005(9)) Submit In Duplicate ORIGINAL by 0 To: Alaska Oil&Gas Conservation Commission From: Kristopher E. Honas, ODE Date: August 2, 2012 Re: Z-61 Permit to Drill • The Z-61 well is scheduled to be drilled by Doyon 25 in November 2012. The grassroots well is a horizontal producer targeting the Ivishak Zone 4 North of Z-pad. The planned well has four hole sections utilizing the Big Bore hole design. Surface casing will be set shallow in the SV3 to avoid drilling potential . free gas while on diverter. The first intermediate hole section will set a fully cemented liner in the UG3. • The second Intermediate hole is planned as a casing string which top sets the Sag River formation. The . production interval will be completed with a cementless liner using sliding sleeves and swellpackers. The liner is designed to allow selective production along the horizontal lateral to maximize oil recovery and • minimize intervention requirements. The maximum anticipated surface pressure from the Ivishak/Sag with a full column of gas from TD to surface is -2675 psi (assumes 7.85 ppg as max pore pressure). This well will be drilled by Doyon 25 using their 5000 psi four preventer BOP stack (3 rams and an annular). The BOP rams and annular will be tested to 3500 psi. • A detailed operations summary is included with the permit application. Below is a brief summary of planned drilling operations: 1. Move in Doyon 25 and function test diverter. 2. Drill 16"surface hole to-2638 ft MD. • 3. Run 13-3/8"surface casing and cement to surface.' 4. Nipple up BOPE and test. 5. Pressure test surface casing. Drill out shoe and perform LOT. 6. Drill 12-1/4" Intermediate hole#1 to-4880 ft MD. • 7. Run 9-5/8" liner and fully cement.- 8. Positive and negative pressure test Intermediate#1 liner. Drill out the shoe and perform LOT. 9. Drill 8-3/4" intermediate hole to top of the Sag River at-14,093 ft MD. • 10. Run 7"casing and cement to-1000 ft MD below 9-5/8" shoe. Pressure test casing. 11. Drill out of intermediate shoe and perform FIT. 12. Drill 6-1/8" horizontal production hole through Zone 4 of the Ivishak to TD at-17,891 ft MD. • 13. Run a 4-1/2", chrome, production liner with approximately 10 swell packers and 10 sliding sleeves. 14. Pressure test liner top packer to 3500 psi 15. Run 4-1/2"chrome completion tubing. Sting into liner tieback sleeve and set production packer. 16. Pressure test the tubing and the inner annulus to 3500 psi each. 17. Rig down and move off the well. In addition to a planned well summary, a directional plan and proposed completion diagram is attached to the permit application. If there are any questions concerning information on Z-61, please do not hesitate to use the contact information below. Kristopher Honas Office: 907-564-4841 Cell: 907-268-0891 Home: 907-929-4388 Email: Kristopher.Honas@bp.com Z-61 PTD Page 1 8/2/2012 Planned Well Summary WWell Z-61 . Type Oil Producer Objecet tive Ivishak • Current Status Grass Roots Well - Conductor Currently Installed Estimated Start Date: 11/01/2012 • Time to Complete: 49.4 Days Surface Northing Easting Offsets TRS Location 5959240 - 599929 . 846' FNL / 2207' FWL 11N 12E sec 19 - Northing Easting TVDss Offsets TRS Tgt 1 5969080 600045 -8680' 1568' FNL / 2451' FWL 11N 12E sec 7 TSGR Tgt 2 5969214 599992 -8840' 1433' FNL / 2400' FWL 11N 12E sec 7 TSAD BHL 5971440 597500 -8935' 826' FSL /63' FEL 11N 11 E sec 1 Planned KOP: 300' MD/203' TVDss - Planned TD: 17,891' MD/8935' TVDss Rig: Doyon 25 • BF-RT: 40.8' . RTE (ref MSL): 96.7' Directional - Schlumberger P12c KOP: 300' MD Maximum Hole Angle: -64° in the 8-3/4" intermediate section -97° in the 6-1/8" production section Close Approach Wells: Z-19 fails major risk in the production interval. Well has been minor risked at 1/200 allowing 182 ft of deviation from planned wellpath. Z-19 is an abandoned well plugged with cement. Survey Program: Surface to -1100 ft MD = GYD-GC-SS (single shot gyro) • -1100 ft MD to TD = MWD+IFR+MS Nearest Property Line: 12,300 ft Nearest Well within Pool: -900 ft-from Z-30A -342 ft from Z-19 which is an abandoned wellbore Z-61 PTD Page 2 8/2/2012 Formation Tops & Pore Pressure Estimate (SOR) Estimated Depth Fluid Type Most Likely Pore ;6,04Formation Formation Uncertainty (for sand) Pressure 01-- Top (TVDss) (+/-TVD ft) (EMW ppg) (� ) G1 270 +/-30 ft Permafrost 8.40 44 z_ SV6 1030 +/-30 ft Permafrost 8.40 EOCU 1610 +/-30 ft Permafrost 8.40 SV5 1705 +/-30 ft Permafrost 8.40 BPRF 1750 +/-30 ft Permafrost 8.60 _ SV4 1830 +/-30 ft Hydrates? 8.60 9.z-9•Y Fault#1 (HSF) 2100 +/- 150 ft MD 8.60 SV3 2190 +/-30 ft Hydrates? 8.60 _ 13 3/8 Surface Casing 2320 +/-30 ft 8.60 q,2---/,8 SV2 2360 +/-30 ft Hydrates? 8.60 SV1 2720 +/-30 ft HyGadr tes/Free 9.00 UG4 3010 +/-30 ft Coal/Free Gas 9.00 UG4A 3100 +/-30 ft Heavy Oil/Gas? 9.00 - UG3 3380 +/-30 ft Wet 8.70 _ 9 5/8"Inter. Liner 3420 +/-30 ft 8.70 ?,Z-/04 UG1 3850 +/-30 ft Wet 8.70 UG Ma 4225 +/-30 ft Wet 8.70 UG__Mb1 4280 +/-30 ft Wet 8.70 UGMb2 4340 +/-30 ft Wet 8.70 UG__Mc 4420 +/-30 ft Wet 8.70 SB_Na 4485 +/-30 ft Wet 8.70 SB Nb 4510 +/-30 ft Wet 8.70 SB_OA 4665 +/-30 ft Wet 8.45 SB_OBa 4735 +/-30 ft Wet 8.45 SB_OBb 4770 +/-30 ft Wet 8.45 SB_OBc 4825 +/-30 ft Wet 8.45 SB_OBd 4885 +/-30 ft Wet 8.45 SB_OBe 4980 +/-30 ft Oil? 8.70 SB_OBf 5050 +/-30 ft Oil? 8.70 SB_OBf_Base 5100 +/-30 ft Wet 8.70 Fault#2(ZPad Fault) 5280 +/-150 ft MD 8.70 CM-2 (Faulted top) 5280 +/-50 ft No 8.70 _ CM-1 5770 +/-30 ft No 9.50 /V 2-40.'7 TLBK 6110 +/-30 ft No 10.00 /b.740,2 THRZ 6270 +/-30 ft No 10.00 TKLB 6440 +/-30 ft No 10.00 TKC4 6450 +/-30 ft Oil/Gas? 8.20 LCU 6520 +/-30 ft Oil 9.95 TKA5 6600 +/-30 ft Oil 9.95 TMLV 6625 +/-30 ft No 10.00 TKNG 7390 +/-30 ft No 10.00 TJF 7595 +/-30 ft No 10.00 TJE 7860 +/-30 ft No 10.00 TJD 8060 +/-30 ft No 10.00 TJC 8405 +/-30 ft No 10.00 TJB 8530 +/-30 ft No 10.00 TJA 8605 +/-30 ft No 10.00 TSGR 8680 +/-30 ft Gas 7.85 $.C-4-7 Z-61 PTD Page 3 8/2/2012 il-1-1v vuu i C 7" Intermed Csg 8685 +/-30 ft Gas 7.85 0'4 7 TSHU 8715 +/-30 ft Gas/Oil 7.82 TEIL 8810 +/-30 ft Oil 7.76 TSAD (46P) 8840 +/-30 ft Oil 7.76 45N 8880 +/-30 ft Oil 7.76 45P 8885 +/-30 ft Oil 7.76 44N 8905 +/-30 ft Oil/Water 7.76 44P 8910 +/-30 ft Oii/Water 7.76 43N 8920 +/-30 ft Oil/Water 7.76 43P 8922 +/-30 ft Oil/Water 7.76 42N 8935 +/-30 ft Oil/Water 7.76 42P 8945 +/-30 ft Oil/Water 7.76 POWC 8950 +/-30 ft Water 7.78 41N 8975 +/-30 ft Water 7.78 Invert(41N) 8965 +/-30 ft Water 7.78 Invert(42N) 8925 +/-30 ft Oil/Water 7.76 Invert(44N) 8890 +/-30 ft Oil/Water 7.76 Invert(45N) 8880 +/-30 ft Oil 7.76 TSAD Invert* 8853 +/-30 ft Oil 7.76 Revert(45N) 8895 +/-30 ft Oil 7.76 Revert(44N) 8910 +/-30 ft Oil/Water? 7.76 Revert(43N) 8920 +/-30 ft Oil/Water? 7.76 TD(mid-43P) 8935 +/-30 ft Oil/Water? 7.78 Vir Casing/Tubing Program ram �Z Hole Casing/ Wt/Ft Grade Conn Burst Collapse Length Top (ft) Bottom (ft) Size Tbg O.D. : _ (psi) (psi) (ft) MD/TVDss MD/TVDss 20" 94# H-40 - 1530 520 80 Surface 80/16 16" 13-3/8" 68# L-80 BTC-M 5020 2260 2638 Surface 2638/2320 12-1/4" 9-5/8" 40# L-80 BTC-M 5750 3090 2392 2488/2216 4880/3420 (-150' lap) 8-3/4" 7" 26# L-80 VamTop 7,240 5,410 14093 Surface 14093/8688 6-1/8" 4 'Az" 12.6# 13Cr-80 VamTop 8,430 7,500 3943 13943/8565 17891/8935 (-150' lap) 13948/8569 Tubing 4 '/2" 12.6# 13Cr-80 VamTop 8,430 7,500 13948 Surface (-5' into liner TBS) Mud Program Surface Hole Mud Properties: Gel Spud Mud 16" Hole Section Density PV YP API FL Chlorides Funnel Depth IntervalpH Viscosity PPg (cp) Ib/100 ft2 ml/30min mg/I sec/qt Initial 0' -Base Perm 8.8-9.2 • 30-55 50-80 NC- 10 <1000 9-9.5 300in:300out final 250in:300out Initial Perm-Section TD 9.2-9.4 30-55 50-80 <8.0 <1000 9-9.5 225in:300out Final 175in:300out Z-61 PTD Page 4 8/2/2012 Intermediate#1 Mud Properties: LSND 12-1/4" hole section Depth Interval Density PV YP API FL HTHP FL MBT pH (ppg) 2638' —Section TD 9.2-9.8 12 - 18 20 -28 <6 NC <18 9- 10 Intermediate#2 Mud Properties: LSND 8-3/4" hole section Depth Interval Density PV YP API FL HTHP FL MBT pH (ppg) 4880'-10,058' MD 9.2-10.2 - 12 - 18 20-28 <6 NC <18 9- 10 To Top Overpressure 10,058'-10,404' To 500' MD Above 10.2-10.7 . 12 - 18 20 -28 <6 NC 18 -20 9- 10 HRZ 10,404'- Section TD 10.7-10.8 . 12 -22 20-28 <4 <10 <20 9- 10 Production Mud Properties: Water Based Polymer Fluid (PowerPro) 6-1/8" hole section Density PV YP Low Shear Depth IntervalAPI FL Rate MBT pH (PPM (cp) (Ib/100ft2) Viscosity 14,093'-TD 8.5-8.7 <12 10 -20 >10 >15000 <4 8-9.5 Logging Program 16"Surface: Sample Catchers- not required for surface hole Drilling: Dir/GR/Res - Open Hole: None Cased Hole: None 12'/4"Intermediate#1: Sample Catchers- not required for Intermediate hole#1 Drilling: Dir/GR/Res • Open Hole: None Cased Hole: None 8-3/4" Intermediate#2: Sample Catchers—as required by Geology Drilling: Dir/GR/Res Open Hole: None Cased Hole: None 6-'/8" Production: Sample Catchers—as required by Geology Drilling: Dir/GR/Res/Neu/Den Open Hole: None Cased Hole: None Z-61 PTD Page 5 8/2/2012 Cement Program Casing Size 13-3/8" 68#, L-80 Surface Casing Basis: Lead: Open hole volume + 250%excess. Port collar used if hole conditions dictate Lead TOC: Surface Tail: Open hole volume +40% excess + 80 ft shoe track Tail TOC: 500 ft MD above casing shoe Total Cement Lead 560.5 bbls, 3147 cult, 1692 sks of 11.0 ppg DeepCRETE, Yield: 1.86 ft3/sk Volume: Tail 64.4 bbls, 362 cuft, 309 sks of 15.8 ppg Class G, Yield: 117_ft3/sk Casing Size 9-5/8" 40#, L-80 Intermediate#1 Liner Lead: Open hole volume+40%excess + 80 ft shoe track+ 150 ft liner lap+ 200 ft DPxCsg Basis: excess Lead TOC: Liner Top Tail: None Total Cement Lead 216.9 bbls, 1218 cuft, 1.050 sks.of 15.8 ppg Class G, Yield: 1.16 ft3/sk Volume: Tail None Casing Size 7" 26#, L-80 Intermediate#2 Casing -' Basis: Lead: Open hole volume + 30% excess `1 S$� tot"' Lead TOC: 1000 ft MD below 9-5/8" liner shoe Tail: Open hole volume+30% excess+ 80 ft shoe track Tail TOC: 500 ft MD above casing shoe Total Cement Lead 268.5 bbls, 1507 cult, 819 sks_of 11.0 ppg LiteCRETE, Yield: 1.84 ft3/sk Volume: Tail 20.5 bbls, 115 cuft, 99 sks of 15.8 ppg Class G, Yield: 1.16 ft3/sk asing Size 4.5" 12.6#, 'P3Cr-80 Production Liner ti( Lead: Open holevolume + 30% excess + 80 ft shoe track+ 150 ft liner lap+200 ft DPxCsg Basis: excess (✓G Lead TOC: Liner Top :33 Tail: None Total Cement s�°� / Volume: Lead 91 Is, 513 tuft, s\5.8 ppg Class G w/gasblock, Yield: 1.54 ft3/sk ,�� v,, Tail None rK Surface and Anti-Collision Issues Surface Shut-in Wells: No wells required shut-in to move the rig on/off the Z-61 conductor slot. No wells require shut-in for anti-collision issues (Z-19 has been minor risked and is already abandoned). Z-61 PTD Page 6 8/2/2012 Hydrogen Sulfide Z-Pad is considered an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level Z-113 12 ppm 5/10/2012 #2 Closest SHL Well H2S Level Z-65 11 2/3/2012 #1 Closest BHL Well H2S Level Z-30A 14 3/21/2011 #2 Closest BHL Well H2S Level Z-27 16 6/29/2011 Max. Recorded H2S on Pad/Facility Z-100 120 3/2/2010 Faults Formation Fault MD TVD Est.Throw Throw Uncertainty Encountered Intersect Intersect Direction Fault#1 - Highland St. Fault 2,335.0 2,100.0 110 ft. Southwest +/- 100 ft. MD Fault#2 - Z Pad Fault 9,018.0 5,280.0 300 ft. West +/- 100 ft. MD Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal / Contact the GPB Environmental Advisors (659-5893)for guidance. Well Control The 16" surface hole will be drilled with a diverter. The 12-1/4", 8-3/4" and the 6-1/8" hole sections will be drilled with well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. BOP test frequency for Z-61 will be 14 days with function test every 7 days. Except in the event of a significant operational issue that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Intermediate Interval #1 Maximum anticipated BHP 1547 psi at 3420'TVDss (8.7 ppg EMW) Maximum surface pressure 1207 psi (.10 psi/ft gas gradient to surface) from 3420'TVDss (8.7 ppg _ EMW) 25 bbls with 10.7 ppg frac gradient Kick tolerance Assumes a 0.5 ppg kick intensity over the anticipated 8.7 ppg pore pressure at interval TD with a 9.2 ppg MW. Planned BOP test pressure Rams test to 3500 psi/250 psi Annular test to 3500 psi/250 psi 9-5/8" Liner Test 3500 psi surface pressure Integrity Test—12-1/4" LOT after drilling 20'-50' of new formation below previous shoe hole 9-5/8" Casing The upper VBRs will be changed to 9-5/8" rams to accommodate the 9- 5/8" Liner. Z-61 PTD Page 7 8/2/2012 Intermediate Interval #2 Maximum anticipated BHP 3414 psi from the TKA5 at 6600' TVDss (9.95 ppg EMW) Maximum surface pressur 2754 psi (.10 psi/ft gas gradient to surface)from TKA5 at 6600'TVDss (9,95 ppg EMW) 25 bbls with 12.0 ppg frac gradient Kick tolerance Assumes a 0.5 ppg kick intensity over the anticipated 10.0 ppg pore pressure in the TLBK with a 10.7 ppg MW(worst case kick zone for interval). Planned BOP test pressure Rams test to 3500 psi/250 psi Annular test to 3500 psi/250 psi 7" Casing Test 3500 psi surface pressure Integrity Test—8-3/4" hole LOT after drilling 20'-50' of new formation below previous shoe 7" Casing The VBRs will be changed to 7" rams to accommodate the 7" casing string. Production Interval Maximum anticipated BHP 3543 psi @ TSGR at 8680' TVDss (7.85 ppg EMW) Maximum surface pressure`-._2675 psi (.10 psi/ft gas gradient to surface) Infinite with >8.8 ppg frac gradient Kick tolerance Assumes a 0.5 ppg kick intensity over the anticipated 7.85 ppg pore pressure in the Sag/Ivishak with an 8.5 ppg MW. Planned BOP test pressure Rams test to 3500 psi/250 psi Annular test to 3500 psi/250 psi Integrity Test—6-1/8" hole FIT after drilling 20'-50' of new hole, target 12.5 ppg FIT 4-1/2" Liner Top Packer 3500 psi surface pressure Test Planned completion fluids 8.5 ppg Seawater/6.8 ppg Diesel Variance Request To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line (<1000 ft). Procedures/Safeguards with paddle removed: • Fluid levels will be monitored in the pits for both gains and losses while drilling. Alarms will be set to indicate if gain or loss of more than 5 bbls has occurred. • The well will be monitored for flow when the pumps are off at each connection. • Over 50 surface holes have been drilled on Z-pad, including the recent Z-40, Z-50, and Z-115 wells in 2012, providing a high level of confidence in the ability to drill surface hole v on the pad without incident. • The planned 8.8-9.4 ppg fluid will provide over balance to formation fluid. Z-61 PTD Page 8 8/2/2012 Z-61 General Operational Summary Proposed Drilling Rig Operations: 1. MIRU Doyon 25. 2. NU diverter spool & riser. Function test the diverter. 3. Take on Gel Spud Mud in the pits and stand back enough 5" drill pipe in the derrick to TD the surface interval. 4. Make-up a 16" drilling assembly with bent housing motor and UBHO sub. Spud and directionally drill surface hole utilizing gyro surveys until clear of magnetic interference. Trip to pick-up GR/RES and directional tools. Drill to planned TD in the SV3. A wiper trip at base permafrost is not necessary unless hole conditions indicate. 5. Circulate bottoms up until hole is clean and pull out of hole racking back 5" pipe. If backreaming is - required, trip back to TD and make final trip out on elevators. Lay down BHA. 6. Run and cement 13-3/8", 68#, L-80, BTC-M surface casing. A TAM Port collar is optional for poor hole conditions. 7. Nipple down the diverter spool and nipple up/test FMC Big Bore casing and tubing head. Nipple up the BOPE configured from top to bottom with annular preventer, 2-7/8" x 5-1/2" VBR, - blind/shear, mud cross, and 2-7/8" x 5-1/2"VBR. Test rams and annular to 250-psi low/3500 psi high. 8. Pressure test the 13-3/8" casing to 250 psi low/3500 psi high for 5 minutes low/30 minutes high once 500 psi compressive strength has been achieved. 9. Make-up a 12-'A4' drilling assembly with mill tooth bit, DIR/GR/RES, and bent housing motor. Run in hole on 5" drill pipe and drill cement to within 10 ft of shoe. Displace spud mud with a 9.3 ppg LSND. Drill 20 ft of new formation and perform an LOT. Target a minimum 10.7 ppg EMW for a 25 bbl kick tolerance. Continue drilling Intermediate hole#1 to planned casing point in the UG3. 10. Circulate bottoms up until hole is clean and pull out of hole on elevators racking back 5" pipe. If backreaming out of the hole is necessary, trip back to TD and POH on elevators on final trip out of hole. Lay down BHA. 11. Change out upper variable rams to 9-5/8" casing rams and test with 9-5/8" test joint to 250 psi low/3500 psi high. 12. Run and fully cement a 9-5/8", 40#, L-80, BTC-M liner with approximately 150 ft of liner lap inside - the previous shoe. 13. Release running tool and circulate out excess cement. POH and rack back 5" drill pipe. 14. Change out casing rams for 2-7/8 x 5-1/2" variables and test with a 4" and 5" test joint to 250 psi - low/3500 psi high. 15. Perform a positive pressure test on the 9-5/8" liner x 13-3/8" casing to 250 psi low/3500 psi high. Perform a negative pressure test on the 9-5/8" x 13-3/8" liner lap by running a 13-3/8" RTTS and pumping diesel down the drill string to reduce hydrostatic head. 16. Make-up an 8-3/4" drilling assembly with PDC bit, DIR/GR/RES/PWD and bent housing motor. Run in hole on 4" drill pipe to the 9-5/8" casing shoe. Crossover to 5" drill pipe and drill cement to within 10 ft of the 9-5/8" shoe. Condition LSND drilling fluid and verify density is 9.2 ppg. Z-61 PTD Page 9 8/2/2012 �. - 17. Drill 20 ft of new formation and perform an LOT. Target a minimum of 12.0 ppg EMW for a 25 bbl kick tolerance. 18. Drill 8'/" intermediate interval to section TD 5-10 ft MD into the TSGR. Weight up drilling fluid using spike fluid maintaining the following density ranges: SAG g:04-v- • 4800 ft MD— 10,058 ft MD: 9.2—10.2 ppg (Top Overpressure at CM1) • 10,058 ft MD— 10,408 ft MD: 10.2 - 10.7 ppg (500 ft MD above THRZ) • 10,408 ft MD—Section TD: 10.7 - 10.8 ppg (For HRZ& Kingak stability) 19. At TD, circulate bottoms up until hole is clean (minimum 2x) and condition mud for 7"casing. 20. POH while rolling the pumps at 1/2 BPM to top of Kingak to minimize swab. Continue to POH on elevators and lay down BHA (if backreaming to get out of open hole is necessary, trip back to TD and POH on elevators final trip out). 21. Change upper variables to 7"casing rams and test with a 7"test joint to 250 psi low/3500 psi high. 22. Run 7", 26#, L-80, VAM TOP HC casing. Cement the 7" casing to 1000 ft MD below the 9-5/8" casing shoe (ensure this is more than 1000 ft MD above the SB_Na to meet BP requirement for no bond log). 23. Pressure test the 7"casing to 250 psi low/3500 psi high for 5 minutes low/30 minutes high • when the plug bumps. 24. Immediately following the casing pressure test initiate injection down the OA by pumping 5 bbls of drilling fluid to ensure annulus remains open for freeze protection. Continue to pump 3-5 bbls of drilling fluid down the OA every hour until the lead cement reaches 500 psi compressive strength. 25. Install the 7"casing pack-off through the stack and test to 250 psi low/5000 psi high for 5 minutes. 26. Change upper 7" casing rams to 2-7/8"x 5-1/2" VBR rams and test to 250 psi low/3500 psi high. 27. Freeze-protect the 9-%" x 7" annulus, once the tail cement has reached 500 psi compressive strength. 28. Manage 5" drill pipe as required (off line in pipe shed when possible). 29. Make-up a 6-%" drilling BHA with PDC bit, Archer RSS, and DIR/GR/RES/NEU/DEN. RIH with 4" drill pipe and begin drilling cement to within 10 ft of shoe. 30. Displace the well to 8.5 ppg Power-Pro SF fluid prior to fully drilling out shoe track. 31. Drill 20 ft of new formation and perform an FIT to 12.5 ppg. - 32. Drill 6-1/8" hole to planned TD per directional plan. Geo steer as required by rig site geologist. Circulate bottoms up until hole is clean. 33. Backream to the 7" casing shoe. Circulate bottoms up inside the shoe. Trip in hole on elevators to TD. Circulate bottoms up and pull out of hole on elevators. Lay down drilling BHA. 34. Make-up and run 4-1/2" 12.6# 13CR VAM TOP liner with approximately 10 oil swell packers, 10 sliding sleeves, and liner top packer/hanger. 35. Spot .6 Rheliant mineral oil based mud in the liner x open hole annulus. Drop a drill pipe dart behind the required OBM volume and displace with additional OBM to land the liner wiper plug on the landing collar immediately above the anchor swell packer. Z-61 PTD Page 10 8/2/2012 36. When plug bumps, set liner hanger and liner top packer. Prior to pulling the running tool, perform a pressure test on the liner top packer by testing the 7" casing x drill pipe annulus to 250 psi low/ 3500 psi high for 5 min low/30 min high. Following test, displace well above liner top to clean —8.5 ppg seawater. 37. Pull out of hole with 4" drill pipe and lay down liner running tool. 38. Run a 4-W, 12.6#, 13CR, VAMTOP tubing with gas lift mandrels and single i-wire for temperature/pressure gauge. Space out and land the tubing with tubing tail inserted into the liner tieback sleeve. Run in lock down screws. 39. Reverse circulate clean 8.5 ppg corrosion inhibited seawater in the tubing x casing annulus. 40. Drop the ball/rod and land on the RHC-M no-shear seat in the XN-nipple. Set packer and individually test the tubing and annulus to 250 psi low/3500 psi high for 5 min low/30 min high. Record each test.Y 41. Shear the DCK valve in GLM. 42. Install TWC and test from above to 250 psi low/3500 psi high for 5 minutes each and from below to 250 psi low/3500 psi high for 5 minutes/30 minutes. 43. Nipple down the BOPE. Nipple up the adaptor flange and double master valves. Test to 250 psi low/5,000 psi high for 5 minutes each with diesel. 44. Rig-up DSM Lubricator and test. Pull TWC. 45. Rig up circulating lines. Freeze protect the well to—2,000' TVDss and allow diesel to U-tube reaching equilibrium. 46. Install a BPV. 47. Secure the well. Rig down and Move Off. Post Riq 1. Pull BPV. 2. Pull ball and rod/RHC-M with slickline 3. Install gas lift valves as required. 4. Set BPV in toe of well below Baker locating sub. 5. Flowback per ASRC. 6. Install flow lines and wellhouse. Z-61 PTD Page 11 8/2/2012 Z-61 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: A. Surface Hole: No overpressure is expected in the surface hole and hydrates have been a minimal concern on the pad. The Surface casing shoe is planned at a shallow depth in the SV3 to avoid drilling free gas present on the North side of the Highland State Fault while on diverter. Mitigating free gas while on diverter with a shallow surface casing shoe requires a 9-5/8" Intermediate liner to avoid sustained casing pressure in the Outer Annulus during the life of the well. B. Intermediate #1 Hole: The SV1 and Ugnu are expected to be over pressured at 9.0 ppg. A minimum ✓ mud weight of 9.2 ppg will be utilized to provide adequate over balance to potential free gas. The short interval, with minimal TVD change, provides substantial kick tolerance. The Big Bore hole design allows the free gas to be drilled with BOPE installed. C. Intermediate #2 Hole: Pore pressure is anticipated to be over pressured beginning in the CM1 at 5770 TVDss. Drilling fluid density will increase to 10.2 ppg prior to drilling into the CM1 and remain over balanced to predicted pore pressure throughout the interval. A minimum kick tolerance of 25 bbls should be achieved prior to drilling interval. D. Production Hole: The pore pressure in the production interval is anticipated to be under pressured due to offset well production with limited injection support. The highest anticipated pore pressure is ' 7.85 ppg. Expected FIT provides an infinite kick tolerance. The interval will be drilled with a substantial over balance utilizing an 8.5 ppg fluid. II. Lost Circulation/Breathing A. Surface Hole: Lost circulation is considered a moderate concern due to Highland State Fault crossing at 2100 ft TVDss. Mud properties must remain in specification to reduce risk of lost circulation. Z-115 surface hole crossed Highland State Fault in very close proximity with no lost circulation. B. Intermediate #1 Hole: Lost circulation is considered a minimal risk with no fault crossings and reasonable overbalance. Maintain mud properties and hole cleaning to further prevent lost circulation. C. Intermediate #2 Hole: Breathing and/or lost circulation is a possibility due to 1 fault crossing with —300 ft of throw. Breathing is also common in the Colville. Wellbore stability requires a 10.7 — 10.8 ppg drilling fluid, further increasing the risk of lost circulation and breathing. ECD management is critical and fluid properties must remain within specification. If lost circulation becomes a problem, follow the LCM decision tree provided in the drilling program. Utilize good hole cleaning practices to avoid high ECD and prevent pack-off potential which could induce breathing. D. Production Hole: There are no planned fault crossings in the production hole. Remain inside the drillers polygon to avoid drilling too close to bounding faults surrounding the target area. Additionally, be prepared for breathing in the Shublik if fractures exist in the area. This has been an occasional problem across Prudhoe, but is considered a low risk on Z-pad. III. Kick Tolerance/Integrity Testing A. With the planned mud weight, the kick tolerance is 25 bbls with a 10.7 ppg LOT in the first intermediate section and 12.0 ppg LOT in the second intermediate section. The production interval kick tolerance is infinite with an 8.8 ppg FIT. If planned LOT/FIT values are not achieved, do not drill ahead without risk assessment and proper authorization. All kick tolerances are calculated based on a 0.5 ppg kick intensity over likely pore pressure. IV. Integrity Testing Test Point Test Depth Test type EMW(lb/gal) 13-3/8"Shoe 20'-50'from the 13-3/e' Shoe LOT 10.7 ppg minimum(25 bbls) 11.2 ppg target(50 bbls) 9-%"Shoe 20'-50'from the 9-5/8"Shoe LOT 12.0 ppg minimum(25 bbls) 12.8 ppg target(50 bbls) --?%) 7"shoe 20'-50'from the 7"shoe FIT 8.8 ppg minimum(infinite) 12.5 ppg target(infinite) Z-61 PTD Page 12 8/2/2012 V. Hydrogen Sulfide A. As Z-Pad is considered an H2S site, refer to the ADW "Hydrogen Sulfide" SOP for the appropriate operational guidelines. The max recorded H2S readings on the pad were 120 ppm in Z-100 March 2010. Z-113 recorded 12 ppm 5/10/2012 and Z-65 recorded 11 ppm 2/3/2012 (closest wells at surface). VI. Faults MD TVThrow Formation Fault Encountered Intersect Int rsect Est.Throw Direction Uncertainty Fault#1 -Highland State Fault 2,335.0 2,100.0 110 ft. Southwest +/-100 ft.MD Fault#2- Z Pad Fault 9,018.0 5,280.0 300 ft. West +/-100 ft. MD VII. Anti-Collision Issues A. The Z-61 planned well path fails major risk anti-collision with Z-19 in the production interval. Z-19 is a permanently abandoned well with a cement plug in the production hole. Z-19 has been minor risked at 1:200 to pass anti-collision. In the unlikely event that Z-61 hits the abandoned Z-19 wellbore there is no risk to safety or the environment. CONSULT THE Z-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. Z-61 PTD Page 13 8/2/2012 ELLHEAD= 4-1/16 WFMC Z-L . Proposed S. 'NOTES: ***CHROME TBC `** ACTUATOR= Bectric KB. ELEV= 96.7 MSL BF.ELEV= 55.9' MSLLI KOP= 203'TVDss --80' 20"Conductor ------_-------- Max Angle= 97 @ 14887 Datum MD= 14239 I I 2000' H4-1/2"HES X MP, ID=3.813" Datum TVDss= 8800' 2488' 19-5/8"x 13-3/8"BKR ZXPN PKR ) [ &Flexlock Hgr w/Tieback Sleeve 13-3/8"68#L80 BTC-M f—J 2638'ID=12.415" '„ 13760' SLBi-w ire L 9-5/8"40#L80 BTC-Ail ID 8.835'H 4880' 1 5880' Planned TOC 1000 ft below GAS LIFT MANDRELS 9-5/8"shoe ST MD TV D DEV TYPE V LV LA TCH PORT DATE 7 TBD 3500 TBD KBG-2 DUM RK 1" 1 13690' —14-1/2"HES X NO', ID=3.813" 6 TBD 5000 TBD KBG-2 DCK2 RK 1" 5 TBD 6000 TBD KBG-2 DUM RK 1" 13760' 14 5"SGM Single Gauge Mandrel& 3. 4 TBD 6800 TBD KBG-2 DUM RK 1" NDPG-C Sapphire Permanent Gauge 3 TBD 7400 TBD KBG-2 DUM RK 1" 2 TBD 7900 TBD KBG-2 DUM RK 1" ,< >< - 13796' 17"X 4-1/2"HES TNT PKR 1 TBD 8350 TBD KBG-3 DUM RK 1" , ID=3 870" 13866' —{4 112"HES X NP, ID=3.813" 4-1/2"TBG 12.6#13Cr-80 --1 13948' VamTop 0152 bpf 11. 3.95813936' i4-1/2"HES X NIP, ID=3 813" 13943' 7"X 5"BKR ZXP PKR&Flexlock 1 HGR w MEBACK SLV.ID=4.4" 7"CSG 26#L-80 VarnTop HC 14093' .0383 bpf ID 6 276 13948' —I WLEG +9ea: 4-1/2"HES OBM Sw ell Packers @ I I TBD'TBD'TBD'TBD'TBD' 0=14 TBD'TBD'TBD'TBD'TBD' 10-MI 1110-M41 I I I I +10ea: 4-1/2"HES Sliding Sleeve @ ► I► TBD'TBD'TBD TBD' I I TBD'TBD'TBD'TBD' 110-MI 10-M.11 I I Minimum ID = 3.813" I I ►- 4-1/2" X Nipple @ 2000' MD I I I I 4-1/2"CIBP H 17815' Col ►�� I I 17801' -IBHI Locator Sub ID=3.91" 3-1/2"HES ORM Anchor Swell Packer I1-)=2997. 17831' = 17821' -I X0 4-1/2" x 3-1/2"521 4-1/2" 12.6#solid 13G-80 17891' 0 0 17871' -j xo 3-1/2"x 4-1/2"521 Hydril 521 Lnr 0.152 bpf ID=3.958 17881' 14-1/2"Float Collar&Shoe DATE REV BY COMMENTS DATE I REV BY COMMENTS Prudhoe Bay UNIT 06/19/12 KEH Proposed Completion WELL: Z-61 — PERMIT No API No: SECXXTWPXXN RGEXXE FSL XXXX'FEL XXXX' I BP Exploration (Alaska) V- QQ p 0 0= 00000 y Mr..-,-WO NN 0 001.tb000 F°M 00 LL00N 0,-0060,- NN(•V)••-UU) F- e- .C 66600 00066 NNf.)Mtn 0 OtiN RfibOR Rfa;NbY) M Of l0 002000 M 0E 000 0 00 a 00 00000 002002 0M 00002 00 t0 W 00000 00000 000)00 0000M 0 a 00 o 0 n)00 O) 0 d 0 W 880 00000 000(00 000)0)0 00000 °)0)00)0) 0 t0 hf0 0f0 00000 NhhON 00000 bhbbb 0b00h b 2 a r 0 N Or r r b 0 0 r 000v1,-,,. 0 b V 0 r b O f`b •-•-00, b C., 000 W V b V tn0� 0 q O1 mM0 N.-N V 0 NN,,,c0s, 00,0 t0... r 00V 00 NNb0 o N-N0 •- N = „ V V00 . 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Z-61(P12c) End Cry F11#5 11200 W 4n011 11200 111 End Cry Ili Cry8.75/1 Z-61 Geo Polygon Z-61 SGRTyt Z-6195%ddtgt -61 ,#4 9600 •••• 9600 1 Flt I/3 End Cry Cnt2.5/100 Z-61 HRZTgt A End Cry A 8000 Z-6t uphole tgt#2 a 8000 A 2-61 uphole tgt#2 95%drl!,# Cry Cry 2/100 Z End Cry E 0 0 Z-61 uphole tgt#1CO \ Z-61 uphole tgt#195%dr(tgt (II) II CU 6400 .-61 FR02 ° 6400 3 Cm 2/100 C/) V V V 4800 4800 3200 3200 9-5/8" 1 o End Cry 600 4 1600 Cry 2/100 13-3/8" Cry 3/100 End Cry End Cry - Cry 2/100 • 1 FR#1 CCr/2/100 End Cry End Cry Bid 2.25/100 KOP Bld 1/100 0 • a 0 Bld 2/100 RTE -4800 -3200 -1600 0 1600 3200 «< W Scale=1:1600(ft) E >>> a. 0 °� }1 V;PAD I ,N... "'.' ti c---\, 1 -N - GRID C) ti 9 $ a 33 III d* iik''-' -"SPINE R0 B 32 8:•'',' , 7 ■ ■ 31 � W-PAD"' 112 29 Z-PAD8 3,. I' C i( 108 4 II 21 i �- r .. a 1021 A , 3 ■ ri# 7 THIS PROJECT Iq„ 'x 2 ■ 1 6 I I 1031 SPARE-A 6 P-504A .; ® ■ P-5048 n n A •®® A n VICINITY MAP ® NTS 21 • 22 39 ■ 11 0 a 23 12 • ■ 24 13 0 11125 14 In 1111 SLOT 1 `OWAilissa 16 a giff •• Z-100 SLOT +4lb 10-� ;°O F'A(;Qs 17 I �" `�.. ,.. - °:4 I. SURVEYORS CE13TIFICAT� 18 ■ • *°°4"al �` °<* PRlip I OPERLY EBY REGISTERED AY THAT ND MICENSED M 46 • Z-PAD °° °00 TO PRACTICE LAND SURVEYING IN r r HE STATE OF ALASKA AND THAT 20 ■ °°°°°°°°°OOOOOeOiO°° °°.. ..,.r THIS AS-BUILT REPRESENTS A SURVEY 401 ° r MADE BY ME OR UNDER MY DIRECT 55 i 511 �� °°Richard F. Allison ..e.g..: �� DIMENSIIONSNANDDOTHER DETAILS ARE 20266 II SD � s�F ° 10608 ° 4 CORRECT AS OF JULY 02, 2011. 57 SG - 2181 61 S ll'IS �.`*ESS I GNAt-`,c" lib 2151 - 113 11111��1�‘‘‘% 'I 22111 4t $2161 - 2131 • 1Ib I LEGEND 341 f - f 201 - 2171 • AS-BUILT CONDUCTOR 2036 4221 II EXISTING WELL CONDUCTOR NOTES: 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. 2. HORIZONTAL CONTROL IS BASED ON Z PAD CONTROL MONUMENTS MON 2 AND MON 3. 3. VERTICAL CONTROL IS BASED ON Z PAD MONUMENTATION. 4. ELEVATIONS ARE SPX MEAN SEA LEVEL (M.S.L.) DATUM. 5. GEODETIC DATUM IS NAD27. 6. PAD AVERAGE SCALE FACTOR IS 0.999911213. 7. DATES OF SURVEY: JUNE 28-30, JULY 1-2, 2011. 8. REFERENCE FIELD BOOKS: NS11-44 PCS. 1--75; NS11-46 PGS. 1-9. AS-BUILT WELL CONDUCTORS: 34i, 40, 42, 50, 511, 55, 57, 61, 62, 65, 66, 68, 69, 70, 105, 113, 115, 201, 202, 203, 2111, 2121, 2131, 2141, 2151, 2161, 2171, 2181, SD, SG, SL, NK F. RobertDRAM:y BARNHAR7 ,r CHECKED: Øbp hd IDAtE JACOBS jcr Ii, 7/t/11 DRAWING,.r FRB1I WOZ 21 WOA Z-PAD SHEET.a assoc la as NO: WRD PAD EXPANSION BB 7/1/11 ISSUED FOR INFDRUAIION ITS AI SCREE: m' „K"" I" = 200' AS-BUILT WELL CONDUCTORS t aF 3 NO. DATE REVISION BY CHK ammo<ARAM mon LOCATED WITHIN PROTRACTED SEC. 19, T. 11 N., R. 12 E., UMEAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS 5M344 Y= 5,959,100.13 N= 1,179.09 70'17'51.597" 70.2976658' 4,292' 561FSL X= 600,125.84 E= 1,870.12 149'11'20.998" 149.1891661' ' ' 2,552' FEL SL Y= 5,959,100.17 N= 1324.00 70'17'51.616" 70.2976711' 4,294' FSL 40 X= 599,980.94 E= 1870.16 149'11'25.221" 149.1903392' 56.0' 2,697' FEL Y=5,959,239.95 N= 1,126.45 70'17'52.965" 70.2980458' 4,431' FSL JV !P 42 X= 600,178.47 E= 2,009.96 149'11'19.409" 149.1887247', 56'0' 2,497' FEL SA 50 Y= 5,959,100.19 N= 1,473.93 70'17'51.636" 70.2976767' 4,296' FSL X= 599,831.02 E= 1,870.18 _ 149'11'29.591" 149.1915531' 56.2' 2,847' FEL NA 511 Y=5,959,240.04 N= 1,466.46 70'17'53.011" 70.2980586' 559' 4,435' FSL X= 599,838.49 E= 2,010.05 149'11'29.319" 149.1914775' ' 2,837' FEL 'S Y= 5,959,100.12 N= 1,458.95 70'17'51.634" 70.2976761' 4,295' FSL 55 X= 599,846.00 E= 1,870.11 14911'29.155" 149.1914319' 56'1 2,832' FEL /\r �Y`` 57 Y=5,959,240.04 N= 1,421.49 70'17'53.005" 70.2980569' 4,435' FSL X= 599,883.46 E= 2,010.05 149'11'28.009" 149.1911136' 55.9' 2,792' FEL /y 61 Y=5,959,239.97 N= 1,376.44 70'17'52.998" 70.2980550' 4,434' FSL X= 599,928.50 E= 2,009.98 149'11'26.695" 149.1907486' 55.9' 2,747' FEL A/C 62 Y=5,959,239.94 N= 1,436.45 70'17'53.006" 70.2980572' 4,435' FSL X= 599,868.50 E= 2,009.95 149'11'28.445" 149.1912347' 56.0' 2,807' FEL 5g 65 Y= 5,959,100.15 N= 1,398.94 70'17'51.626" 70.2976739' 56 1' 4,295' FSL X= 599,906.01 E= 1,870.14 149'11'27.405" 149.1909458' 2,772' FEL se_ Y= 5,959,100.11 N= 1,443.99 70'17'51.632" 70.2976756' 4,295' FSL 66 X= 599,860.96 E= 1,870.11 149'11'28.719" 149.1913108' 56'2 2,817' FEL 5P 68 Y=5,959,100.23 N= 1,134.00 70'17'51.592" 70.2976644' 55.9' 4,291' FSL X= 600,170.92 E= 1,870.22 149'11'19.683" 149.1888008' 2,507' FEL Y=5,959,239.94 N= 1,301.49 70'17'52.988" 70.2980522' 4,433' FSL >! -r- 69 X= 600,003.45 E= 2,009.95 149'11'24.511" 149.1901419' 56.1' 2,672' FEL s • 70 Y= 5,959,100.10 N= 1,384.02 70'17'51.624" 70.2976733' 56.2' 4,294' FSL X= 599,920.93 E= 1,870.09 149'11'26.971" 149.1908253' 2,757' FEL Y=5,959,100.05 N= 1,163.88 70'17'51.594" 70.2976650' 4,291' FSL sly' 105 X= 600,141.04 E= 1,870.04 149'11'20.554" 149.1890428' S5'9 2,537' FEL 1V113 1 Y=5,959,239.90 N= 1,346.45 70'17'52.994" 70.2980539' 4,434' FSL £7 113 X= 599,958.49 E= 2,009.91 149'11'25.821" 149.1905058' 56'0' 2,717' FEL Al Y=5,959,240.03 N= 1,361.38 70'17'52.997" 70.2980547' 4,434' FSL 115 X 599,943.56 E= 2,010.04 149'11'26.256" 149.1906267' 55.9' 2,732' FEL NOTES_ 1. ALASKA STATE PLANE COORDINATES ARE NA027, ZONE 4. 2. HORIZONTAL CONTROL IS BASED ON Z PAD CONTROL MONUMENTS MON 2 AND MON 3. 3. VERTICAL CONTROL IS BASED ON Z PAD MONUMENTATION. 4. ELEVATIONS ARE BPX MEAN SEA LEVEL (M.S.L.) DATUM. 5. PAD AVERAGE SCALE FACTOR IS 0.999911213. AS—BUILT WELL CONDUCTORS* 341, 40, 42, 50, 511, 55, 57, 61. 62. 65, 66. 68, 69, 70, 105, 113, 115, 201, 202, 203, 2111, 2121, 2131, 2141. 2154, 2161, 2171, 2181, SD, SG, SL, NK DRAMN: F. Robert , BARNHART r �;, )I'. o.Airoicc: JACOBS - bp _.._.....__ .. _. _.... .... �— i��(s; DATE:7 13/11 (;41 F' DRAWING S"EET; g�ap .pper! FRB11 WOZ 21 WOA Z PAD a soca No- WRD PAD EXPANSION SCALE: 2 3 80 7/1/11 ISSUED FOR INFORMATION WE JJ ovmsA�,.vo ew�m SCA HO. DATE aEwslOw BY MIwwn' T MIMED N1YA C I' - 200' AS-BUILT WELL CONDUCTORS LOCATED WITHIN PROTRACTED SEC. 19, T. 11 N., R. 12 E., UMI AT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC GRAVEL SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) PAD ELEV. OFFSETS NAA. Y=5,959,240.18 N= 1,171.46 70'17'52.973" 70.2980481' 4,432' FSL /�!/ 201 X= 600,133.47 E= 2,010.19 149'11'20.721" 149.1890892' 56.6' 2,542' FEL /VgY=5,959,239.94 N= 1,451.46 70'17'53.008" 70.2980578' 4,435' FSL 202 X= 599,853.49 E= 2,009.95 149'11'28.882" 149.1913561' 55.9' 2,822' FEL Y=5,959,100.03 N— 1,148.96 70'17'51.592" 70.2976644' 4, 291' FSL ��' 0203 X= 600,155.96 E= 1,870.02 14911'20.119" 149.1889219' 56.0' 2,522' FEL Y=5,959,100.23 N= 1,308.95 70'17'51.615" 70.2976708' 4,293' FSL S 211i X= 599,995.99 E= 1,870.22 14911'24.783" 149.1902175' 55.9' 2,682' FEL �/C) 2121 Y= 5,959,240.11 N= 1,141.47 70'17'52.969" 70.2980469' 56.4' 4,431' FSL ! f X= 600,163.45 E= 2,010.12 14911'19.847" 149.1888464' 2,512' FEL /.4 L 2131 Y=5,959,240.04 1\1= 1,271.44 701 7'52.985" 70.2980514' 56 1' 4,433' FSL X= 600,033.50 E= 2,010.05 149'11'23.635" 149.1898986' 2,642' FEL fZ, 2141 Y=5,959,100.25 N= 1,293.88 70'17'51.613" 70.2976703' 56 2' 4,293' FSL X= 600,011.06 E= 1,870.24 149'11'24.343" 149.1900953' 2,667' FEL Si1 Y=5,959,100.14 N= 1,354.05 70'17'51.620" 70.2976722' 4,294' FSL (—E 2151 X= 599,950.89 E= 1,870.13 149'11'26.097" 149.1905825' 56.2' 2,727' FEL �V T�- 2161 Y=5,959,240.09 N= 1,316.42 70'17'52.992" 70.2980533' 56.0' 4,433' FSL X= 599,988.52 E= 2,010.10 149'11'24.946" 149.1902628' 2,687' FEL J\A/ 2171 Y=5,959,239.98 N= 1,156.36 70'17'52.970" 70.2980472' 56.2' 4,431' FSL X= 600,148.56 E= 2,009.99 149'11'20.281" 149.1889669' 2,527' FEL Y=5,959,239.98 N= 1,391.46 70'17'53.000" 70.2980556' 4,434' FSL Air 218i X= 599,913.48 E= 2,009.99 149'11'27.133" 149.1908703' 55.9' 2,762' FEL Y= 5,959,100.11 N= 1,429.03 7017'51,630" 70.2976750' FSL SD X= 599,875.92 E= 1,870.10 149'11'28.283" 149.1911897' 56'4' 2,802' FEL Y=5,959,100.09 N= 1,369.02 70'17'51.621" 70.2976725' 4,294' FSL SG X= 599,935.92 E= 1,870.08 149'11'26.533" 149.1907036' 56.2' 2,742' FEL Y= 5,959,100.01 N= 1,279.00 70'17'51.609" 70.2976692' 4,293' FSL SL X= 600,025.94 E= 1,870.00 149'11'23.910" 149.1899750' 56.3' 2,652' FEL Y=5,959,239.85 4= 1,286.54 70'17'52.985" 70.2980514' 4,433' FSL NK X= 600,018.40 E= 2,009.86 149'11'24.075" 149.1900208' 56'0' 2,657' FEL NO'T ,S: 1. ALASKA STATE PLANE COORDINATES ARE NAD27, ZONE 4. 2. HORIZONTAL CONTROL IS BASED ON Z PAD CONTROL MONUMENTS MON 2 AND MON 3. 3. VERTICAL CONTROL IS BASED ON Z PAD MONUMENTAT1ON. 4. ELEVATIONS ARE 8PX MEAN SEA LEVEL (M.S.L.) DATUM. 5. PAO AVERAGE SCALE FACTOR IS 0.999911213. 6. ALPHA NAME DESIGNATIONS REFER TO BPX DRILLING SURFACE SLOT NAME AS—BULLT_WELL CONDUCTORS' 341, 40, 42, 50. 51i, 55, 57, 61, 62, 65, 66, 68, 69, 70, 105, 113, 115. 201. 202, 203, 211i, 212i, 2131. 2141, 2151, 216i, 217i, 2181, SD, SG, SE, NK ORAWN: F. Robert BARNHART i. I0(,• CHECKED:JACOBS bp +/rI4� DATE: � 7/1/11 I -�'?:' �,� DRAWING: plc.: FRBJ1 woz 21 WOA 2—PAD SHEET ®assuc. 'No- WRD PAD EXPANSION 3 Of 3 e0 7/1/11 IMO)FOR 1NFOTGIA710Mil ° "• • SCALE: 0,Int m®we I" . zee' AS—BUILT WELL CONDUCTORS NO. DATE REVISION RY CM waoMs MAMA nm - Co j- 8 LL - Z >. .- Co - o mC.9N —aoo N 70NCs?cv 1nra >N - ni vN c c c 0 20:1 " (t$ —o sk as a a a. N CL - 0 I) —0 N - O - O —O a - • N - 0 0 IA - NO N 0 - v) .- 4 ef ,_ i•_ N N - 0 O pp N N `O Q r —g m N g O) p, f0 N N M O —O 0 0 p —S C7 it o IV ap N N 0 D N N Cr) e cc -8 NI. gi e3 N N $ —8 m N Q U o 8 N 1: i i.., O —O N W J I 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 r I 1 I I I I I I I I 1 I 1 I l I 1 I 1 1 1 1 1 1 1 1 1 r I l I I I I I I I 1 I I I 1 I 1 1 1 1 I I I I I I I 1 I o 0N 0 In o 10 o VI o It) 0 U) 0 10 0 I, 10 1D In 1[) O V M C) N N r 1- (u oL) uogeiedeg aqua3 01 aJ;ua3 Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan Ivi Z-61 (NF)v6 Project: Prudhoe Bay ND Reference: Z-61 plan D25 @ 96.70ft(Doyon 25) Reference Site: PB Z Pad MD Reference: Z-61 plan D25 @ 96.70ft(Doyon 25) Site Error: O.00ft North Reference: True Reference Well: Plan Ivi Z-61 (NF)v6 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan Z-61 Database: EDM.16-ANC Prod-WH24P Reference Design: Plan#12 Z-61 Offset ND Reference: Offset Datum Reference Plan#12 Z-61 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer 'Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA l Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,984.84ft Error Surface: Elliptical Conic Survey Tool Program Date 6/7/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 42.70 1,100.00 Plan#12 Z-61 (Plan Z-61) GYD-GC-SS Gyrodata gyro single shots 1,100.00 2,638.00 Plan#12 Z-61 (Plan Z-61) MWD MWD-Standard 1,100.00 2,638.00 Plan#12 Z-61 (Plan Z-61) MWD+IFR+MS MWD+IFR+Multi Station 2,638.00 4,100.00 Plan#12 Z-61 (Plan Z-61) MWD MWD-Standard 2,638.00 4,813.00 Plan#12 Z-61 (Plan Z-61) MWD+IFR+MS MWD+IFR+Multi Station 4,813.00 6,300.00 Plan#12 Z-61 (Plan Z-61) MWD MWD-Standard 4,813.00 14,093.00 Plan#12 Z-61 (Plan Z-61) MWD+IFR+MS MWD+IFR+Multi Station 14,093.00 15,600.00 Plan#12 Z-61 (Plan Z-61) MWD MWD-Standard 14,093.00 17,891.11 Plan#12 Z-61 (Plan Z-61) MWD+IFR+MS MWD+IFR+Multi Station 6/7/2012 9:15:15PM Page 2 of 4 COMPASS 2003.16 Build 73 Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan Ivi Z-61 (NF)v6 Project: Prudhoe Bay TVD Reference: Z-61 plan D25 @ 96.70ft(Doyon 25) Reference Site: PB Z Pad MD Reference: Z-61 plan D25 @ 96.70ft(Doyon 25) Site Error: 0.00ft North Reference: True Reference Well: Plan Ivi Z-61 (NF)v6 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan Z-61 Database: EDM.16-ANC Prod-WH24P Reference Design: Plan#12 Z-61 Offset ND Reference: Offset Datum Ii Summary I Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan ' Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB Z Pad Plan ivi Z-34(SM)v6-Plan Z-34-Plan#lob Z-32 428.09 425.00 242.79 7.98 234.82 Pass-Major Risk Plan lvi Z-42(NP)v6-Plan Z-42-Plan#6 Z-42 623.00 625.00 251.19 11.09 240.14 Pass-Major Risk Plan lvi Z-51 (NA)v6-Plan Ivi Z-Z51 -Plan#2 Z-f 514.06 500.00 95.71 8.57 87.20 Pass-Major Risk Plan lvi Z-55(SB)v6-Plan Z-55-Plan#4 Z-55 vE 430.22 425.00 163.81 8.06 155.75 Pass-Major Risk Plan lvi Z-57(ND)v6-Plan Z-57-Plan#4 Z-57 vl 638.72 625.00 46.12 11.63 34.49 Pass-Major Risk Plan lvi Z-62(NC)v6-Plan Z-62-Plan#2 Z-62 vl 513.35 500.00 61.84 8.60 53.25 Pass-Major Risk Plan Ivi Z-66(SC)v6-Plan Z-66-Plan#14 Z-66 i 354.86 350.00 155.38 6.65 148.73 Pass-Major Risk Plan Ivi Z-69(NJ)v6-Plan Z-69-Plan#14 Z-69 648.93 650.00 76.19 11.78 64.42 Pass-Major Risk Plan Ivi Z-70(SF)v6-Plan Z-70-Plan#17 Z-70 354.86 350.00 140.70 6.65 134.05 Pass-Major Risk Plan Kup Z-114(27+45)v6-Plan Z-114-Plan#1 10,909.59 12,552.10 370.90 250.45 183.49 Pass-Major Risk Plan Kup Z-118(30.5)v5-Plan Z-118 v5-Plan# 3,177.83 3,525.00 129.76 84.25 75.97 Pass-Major Risk Plan Sch Z-201 (NM)v6-Plan Z-201 -Plan#6 Z-: 761.72 750.00 206.84 13.26 193.58 Pass-Major Risk Plan Sch Z-202(NB)v6-Plan Z-202-Plan#2 Z 339.19 325.00 76.17 6.38 69.80 Pass-Major Risk Plan Sch Z-211 (SJ)v6-Plan Z-211-Plan#5 Z-2 411.45 400.00 156.44 7.69 148.75 Pass-Major Risk Plan Sch Z-212(NO)v6-Plan Z-212-Plan#3 Z-2 439.12 425.00 236.08 8.14 227.95 Pass-Major Risk Plan Sch Z-213(NL)v6-Plan Z-213-Plan#3 Z-2 439.16 425.00 106.23 8.20 98.03 Pass-Major Risk Plan Sch Z-214(SK)v6-Plan Z-214-Plan#2 Z 460.22 450.00 163.96 8.51 155.45 Pass-Major Risk Plan Sch Z-215(SH)v6-Plan Z-215-Plan#2 Z 722.80 725.00 142.21 12.70 129.56 Pass-Major Risk I Plan Sch Z-216(NI)v6-Plan Z-216-Plan#2 Z-2 439.17 425.00 61.06 8.20 52.86 Pass-Major Risk Plan Sch Z-217(NN)v6-Plan Z-217-Plan#3 Z 514.08 500.00 221.78 9.36 212.42 Pass-Major Risk Plan Sch Z-218(NE)v6-Plan Z-218-Plan#2 Z-2 564.08 550.00 16.23 10.15 6.08 Pass-Major Risk Z-100-Z-100-Z-100 1,071.48 1,050.00 302.65 16.70 286.19 Pass-Major Risk 2-113-Z-113-Z-113 42.70 40.70 30.06 1.22 28.84 Pass-Major Risk Z-113-Z-113-Z-113 581.11 575.00 29.47 9.51 19.96 Pass-Major Risk Z-113-Z-113PB1 -Z-113PB1 581.11 575.00 29.47 9.51 19.96 Pass-Major Risk Z-115-Z-115-Plan#19 Z-115 656.43 650.00 17.89 12.46 5.43 Pass-Major Risk 2-115-Z-115-Z-115 42.70 40.80 15.18 1.22 13.96 Pass-Major Risk Z-116-delete me Plan Z-116PB2 do not use-del 2,909.84 2,900.00 391.50 70.62 340.17 Pass-Major Risk 2-116-Z-116-Z-116 2,910.25 2,900.00 391.49 70.47 340.33 Pass-Major Risk Z-116-Z-116PB1 -Z-116PB1 2,910.25 2,900.00 391.49 70.65 340.17 Pass-Major Risk Z-116-Z-116PB2-Z-116PB2 2,910.25 2,900.00 391.49 70.65 340.17 Pass-Major Risk 2-18-Z-18-Z-18 500.00 500.00 252.58 9.21 243.37 Pass-Major Risk Z-19-Z-19-Z-19 1,192.77 1,225.00 196.20 14.00 182.35 Pass-Minor 1/200 Z-19-Z-19A-Z-19A 1,434.01 1,475.00 201.89 38.56 164.19 Pass-Major Risk Z-20-Z-20-Z-20 427.20 425.00 198.79 7.67 191.12 Pass-Major Risk Z-210-Z-210-Z-210 2,229.08 2,475.00 80.49 57.45 36.09 Pass-Major Risk Z-210-Z-210PB1 -Z-21 OPB1 2,229.08 2,475.00 80.49 57.45 36.09 Pass-Major Risk Z-27-Z-27-Z-27 1,050.02 1,050.00 786.50 18.22 768.27 Pass-Major Risk Z-30-Z-30-Z-30 17,216.50 14,970.00 1,087.28 270.24 833.82 Pass-Major Risk Z-30-Z-30A-Z-30A 14,057.77 16,250.00 844.65 388.66 500.93 Pass-Major Risk Z-40-Z-40-Z-40 306.23 300.00 150.78 5.52 145.26 Pass-Major Risk Z-50-Z-50-Z-50 257.04 250.00 171.54 4.82 166.71 Pass-Major Risk Z-65-Z-65-Z-65 380.39 375.00 141.81 6.28 135.53 Pass-Major Risk Z-65-Z-65PB1 -Z-65PB1 380.39 375.00 141.81 6.44 135.38 Pass-Major Risk 6/7/2012 9:15:15PM Page 3 of 4 COMPASS 2003.16 Build 73 Project: Prudhoe Bay From Colour To MD Site: PB Z Pad Well: Plan Ivi Z-61 (NF)v6 43 512 Wellbore: Plan Z-61 Design: Plan #12 Z-61 512 1012 1012 1512 1512 2012 2012 3012 From surface to TD 3012 5012 Scan interval 25 ft 5012 7012 Scale 1 : 50 Minor Risk: Z-19@1:200 7012 10012 0 10012 17892 ��\�\\.`:. ��:�` ? Z-115IPIan#19 Z-115 330 vv ��v • • _ \�\ : # 22114,.1•;,. ._ s `. •w -Z�� 206,3 -r.:1'.0., i- Pian Sch 2-218(OE) art ",, '..k.;"-:',-.:--;.".-__.„'"-!.",,....„,: :.,.„� ._2037 j - / i3v.. \ �," �mg17 147 t �=-� � - \ / /1454 2115• •f ' , 1 G `\ ; t•---:•777-',- 45 •� 300 O,;o F:077 9: • ,. a 191 �, ,f \ 191' \. 60 14,)56, 1 ,-?-, I '229 y, \� 18 }(- / / 1'S' i �, { 2`v7 86- -�.� :4•: Plan Sch 2-216 NI 283 1Sg :`� 121 s4 , �., ♦ 14.i t4A . Z-113/Z-113P1 ( 9 bJ. �.tUw -+r.� = 1!U `�' .' �1' i -1 '� �'r•'S.�. t U• . "ylt,, v 85 - 11'i \ , '''''''''',:::1.';.•,.:4.4:.12:4 ^;:4;;:' r t .. LK w r S. .7•r1 2 `u. �` ' y rt- .Z.210/Z-211 ,144- • . Hk,^Ivi Z-37 tJDI v6/Pian#4 29- S �� 270 — fl ..'-'-.1t., - 4 ; '-'ur —1 _' rY, Y 43--:4*:4_,,,cAt*-1-r-- L-. ���� 90 I 1 7 , F' i rt, .......„ 1, 1_,''.?':' •Y o`G 7772 ti. .. •: .: � - •' 796 821 95 `� Q7 �� 33 5 f 869 'i-' Ivi 51 9.. .%li '-';-,,--4....., 78 if, 89 - s7s 9s5 s� y f 240 ' %it IF+ , `� 101124 120 e4), •N 1' `f4'1 , a, S /�, ,..PI4v +,1 r� . , # �` 1Ar � <, ` C -Ian Sch Z-215(SH)v6/Plan#2 Z-215 v66 21 .- ..;�. Ay.a17., ,� •`1' ► '150 �Z: �-%. m!i;1ln Vie!�4 ', ,rrt �►; 1 ii,-4.--r-%."Sch Z-211 (SJ)v6/P1an#5 Z-211 v6v5 �-.yilfrl ;t�v 75 '- -40/Z-40Z-69(NJ)v6/Plan#14 Z-69 rlan i -70(SF)v6/Pbn#17 Z-70 v6 Travelling Cylinder Azimuth(TFO+AZI)[0] vs Centre to Centre Separation[50 ft/in] Note: For 13-15A RST, BOP stack will be NU on a spacer spool above the existing tubing spool and the diverter as included in this schematic does not apply. I :' I I 4 1 1 E B i I , � 1 ' 4 i'a _9 1 `_;1__'' :1�._1_! _; H--'1 I -- 1 9 11 � e a I -e =e ,L �� — Ii 3t. ' . i r. 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P s x ” --— P 14.4 r. n x mil - i e ;eelf at, .91i d 8 ,. a [�11 141-171714471i111 N �1,l1I1 ;iILt t V �ftlli`�ind �4.0;tht N m3 i m .= I a) m N m U c 0 N O ild o)m LL d.O a te' I— € k.l I O ILII ,. , .... o it H � •l. r,.,,.• p G n,•x•t,. E3 ° al f tet, 13 ' u _ --41 .�..' MT A — �' �tlien m �1161 4,i iii ..•'... Ri�►I ._ IlMiNii1 I� 1 p le fli ',, ' . • — :5 =: Y :.4...„' .Ityl• i i'441.,i1 /!lil viAwAsri .a a _ W «„ V 4• Note: Dimensional information reflected on this drawing are estimated measurements only. 28.63" Est. ■ m i © 0 �0 4-1/16" 5,000 OQ � 0 las MO on tsJt ' 93.38" • Est. WI MIMI huh 4-1/16" 5,000# 50.75" in NNE so Est. 4-1/16" 5,000- • n m 1 1 BP Alaska SK-011583-03 CAMERON Na_ Dnte' Jeanette 4-1-05 # 3- 6610 .� : . Working Preeeurc. • Page 1 of 1 Schwartz, Guy L (DOA) From: Honas, Kristopher[Kristopher.Honas@bp.com] Sent: Thursday, August 16, 2012 2:57 PM To: Schwartz, Guy L(DOA) Subject: RE: Z-61 (PTD 212-113) Guy, You are correct,this is a typo. The production liner will be a solid liner with swell packers and liner top packer for isolation. No cement will be pumped, instead an oil based mud will be spotted in the liner x open hole annulus to assist in swelling the packers as detailed correctly in step 35 (pg 10) of the general operations summary.The Cementing detail on Page 6 contains the error.The 4.5" production liner section should be "N/A" (not applicable) for both lead and tail cement. I apologize for the error. I am not in the office this week. Would you like to strike out the cement detail in the current application or would you prefer that I submit a revised application on Monday when I return to the office?Thank you, Kris Honas BP Rotary Drilling Engineer Desk. 907-564-4841 Cell: 907-268-0891 Kristopher.Honas@bp.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday, August 16, 2012 2:15 PM To: Honas, Kristopher Cc: Davies, Stephen F(DOA) Subject: Z-61 (PTD 212-113) Kris, I think it's a typo but the liner detail for the 4.5 slotted liner& swell packers includes 90 bbls of cement. The way I read it you are displacing the annulus to OBM using a cementing plug that lands in the lower landing collar(BHI sub). Also the schematic shows a CIBP near the shoe .. .when is that being set? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 8/16/2012 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME ��/ � PTD# 2 ( 2_ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD:gq/1�-// ez-e— POOL: l---txc-i�� "" = �r Check Box for Appropriate etter/Paragraphs to be Included in Tra _ ittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name,of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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