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Home My WebLink About212-1527. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU D-19C Permanently Pull LTP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-152 50-029-20707-03-00 341J ADL 0028285 10851 Surface Intermediate Liner Liner Liner 9019 2665 6197 2615 282 2114 9828 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 9024 37 - 2702 34 - 6231 6079 - 8694 8528 - 8810 8737 - 10851 2500 37 - 2702 34 - 6084 5943 - 8516 8352 - 8630 8558 - 9019 8788 2670 4760 5410 7500 10530 9828, 10104, 10576 5380 6870 7240 8430 10160 9600 - 10805 4-1/2" 12.6# 13Cr80 32 - 85329030 - 9019 Conductor 80 20" x 30" 38 - 118 38 - 118 4-1/2" Baker S-3 Packer No SSSV Installed 8461, 8285 Date: Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com (907) 564-5026 PRUDHOE BAY 12/19/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.12.04 13:45:18 - 09'00' Torin Roschinger (4662) 325-739 By Grace Christianson at 3:10 pm, Dec 04, 2025 J.Lau 12/8/25 10-404 DSR-12/5/25SFD 12/10/2025JLC 12/10/2025 12/10/25 Page 1 of 2 Well:D-19C LTP Removal Well Name:D-19C API Number:50-029-20707-03 Current Status:Offline Operable Pad:D PAD Reg. Approval Reqd?10-403,10-404 Regulatory Contact:Abbie Barker Job Type:LTP Pull First Call Engineer:Finn Oestgaard Phone:(907) 350-8420 Second Call Engineer:Brenden Swensen Phone:(907) 748-8581 Current Bottom Hole Pressure:3,300 psi (Estimated based on average Ivishak BHP) MPSP:2,500 psi (Estimated from BHP- .1psi/ft gas gradient+ safety factor) Max Dev:98 deg @ 9,555 MD Min ID:2.36 @ 8,731 MD Background: D-19C is a horizontal zone 2 producer drilled in 2012. The well has multiple stages of plug and perfs throughout the life of the well, shifting the offtake point closer to the heel. A liner top packer has been traditionally used to isolate the liner lap from gas production. Recent analysis of historical fluid sampling showed that when the well was flowing with a suspected leaking LTP, the oil API was 41.2. With the updated IOR calculation for crediting for higher API fluids, the subsurface team has elected to flow the well without a LTP and capture the lighter end hydrocarbons. LTP History: 2/28/21 Eline could not pass LTP w/ 1.69 logging tools 3/25/21 Slickline attempted to fish LTP & it parted. Spent 6 days of fishing lower section unsuccessfully. 4/21/21 Slickline fished baited sub with braided line for 2 days unsuccessfully. 4/28/21 Coil attempted to fish with no movement 8/14/21 Coil attempted to fish lower section, parted bait sub (LIH). Drifted through LTP with 2 DJN. Attempted to mill lower section of LTP w/ 3.80 5 bladed junk mill, made 3 of progress (unable to get deeper than deployment sleeve) 8/24/21 Coil attempted to mill inside the deployment sleeve w/ 2.93 tapered nose mill, unsuccessfully. 11/7/21 SL drifted LTP @ pulled caliper. 4/4/22 SL attempts to retrieve FISH @ 8,788 for 2 days unsuccessfully, then sets 2 trip LTP. Objective: Pull LTP & set flow through sub. Procedure: Slickline 1. Pull upper section of LTP 2. Pull lower section of LTP 3. Set flow through sub in X nipple @ 8,494 Operations 1. POP & obtain well fluids sample for API Density. Page 2 of 2 Well:D-19C LTP Removal Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: December 4, 2025Subject: Changes to Approved Sundry Procedure for Well D-19CSundry #: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.Step Page Date Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date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y Samantha Carlisle at 7:18 am, Apr 14, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV $&7,9,7<'$7(6800$5< :(//6,21$55,9$/ SDWFKWEJOLQHU 5$1-8672 6/081$%/(72/$7&+),6+ 5$1.- [%/%-8672 6/0:25.(''2:172 6/081$%/(72/$7&+ 0$'(08/7,3/(3803%$,/(55816 6/0%$,/(56)8//2) 58%%(5/,.(68%67$1&( 6$1' :65&217,18('21 :65&217,18(')520 %$,/('6$1'<6&+022)520 6/072 6/00(7$/0$5.621 %$,/(5%27720 5$1.- [67(0%586+$1'-86&+$6('),6+)520 6/072 6/081$%/(72/$7&+ 5$13803%$,/(572 6/0:25.('72 6/0aJDOORQRI UXEEHU\VDQG\PDWHULDOUHFRYHUHG $77(037('72/$7&+),6+# 6/0QROXFNVWLOOHYLGHQFHRIILOO [3803%$,/(55816386+('),6+'2:172 6/0a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perator Name:2. Development Exploratory Service 5 Permit to Drill Number:212-152 6.50-029-20707-03-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10851 9828 9024 8461 8788 8285 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" x 30" 38 - 118 38 - 118 Surface 2665 13-3/8" 37 - 2702 37 - 2702 5380 2670 Intermediate 6197 9-5/8" 34 - 6231 34 - 6084 6870 4760 Liner 2615 7" 6079 - 8694 5943 - 8516 7240 5410 Liner 282 4-1/2" 8528 - 8810 8352 - 8630 8430 7500 Perforation Depth: Measured depth: 9600 - 10805 feet True vertical depth:9030 - 9019 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 31 - 8532 31- 8351 8461 8285Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Hydro Set Packer Liner 2114 8737 - 10851 8558 - 9019 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 95420356445244014 Well Not Online Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Noel Nocas Noel.Nocas@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5278 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9019 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Pull / Fish LTP Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028285 PBU D-19C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 3-1/2" x 3-3/16" x 2-7/8" 9828, 10104, 10576 By Samantha Carlisle at 9:06 am, Aug 30, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.08.30 07:48:59 -08'00' Stan Golis (880) DSR-8/30/21MGR01SEP2021 RBDMS HEW 8/30/2021 SFD 8/30/2021 ACTIVITY DATE SUMMARY 3/24/2021 ***WELL S/I ON ARRIVAL***(patch tbg / liner)*** PULLED LTP FROM 8731' MD AND HUNG UP IN GLM #1 @ 8373' MD. ***JOB CONTINUED ON 3/25/2021*** 3/25/2021 ***JOB CONTINUED FROM 3/24/21***(LTP) PULLED SEPERATED LTP (3' OF FLOW CUT 45 KBP PACKER) ATTEMPTED TO FISH ELEMENTS AND HALF SLIP(1.75" X 1.5") ***JOB CONTINUED ON 3/26/21*** 3/26/2021 ***JOB CONTINUED FROM 3/25/21*** ATTEMPTED TO PULL PARTED LTP FROM 8731' SLM. REOCVERED FLOW CUT 45KB PACKER PEICES JARRED FOR ONE HOUR ONE ITCO BOWEN SPEAR IN SEAL ASSEMBLY ***JOB CONTINUED ON 3/27/21*** 3/27/2021 ***JOB CONTINUED FROM 3/26/21*** JARRED ON SEPERATED LTP @ 8731' MD FOR 3.25 HOURS(NO MOVEMENT) SWAP OVER TO .160 WIRE ***JOB CONTINUED ON 3/28/21*** 3/28/2021 T/I/O = 2410/1120/80. Temp = SI. WHPs (post bleed). ALP = 1880 psi, SI @ CV. TP increased 10 psi, IAP increased 260 psi from 3/23/21. SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:00 3/28/2021 ***JOB CONTINUED FROM 3/27/21*** FISHED ON PARTED LTP FOR 3.25 HOURS WITH .160 WIRE. NO MOVEMENT. ***JOB CONTINUED ON 3/29/21*** 3/29/2021 ***JOB CONTINUED FROM 3/28/21*** ATTEMPTED TO FISH SEPERATED LTP. JAR FOR 2 HOURS .160 WIRE. 4" BAIT-SUB, SPEAR ASSEMBLY LEFT ENGAGED TO SEAL ASSBY @ 8713' SLM(see log). ***WELL LEFT S/I, DSO INFORMED OF STATUS*** 4/19/2021 T/I/O = 2400/1470/60. Temp = SI. Bleed IAP (eval TxIA). ALP = 880 psi, SI @ CV. IA FL @ 5270' (sta # 4 SO). Bled IAP to OT to 170 psi in 3 hrs. TP decreased 10 psi, IA FL unchanged. Monitored for 30 min. IAP increased 10 psi. Final WHPs = 2390/180/60. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:59 4/19/2021 T/I/O = 2400/2010/50. Temp = SI. Bleed IAP to 200 psi (Eval TxIA). ALP = 860 psi, SI @ CV and lateral. IA FL @ 5270' (#4 SO, 282 bbls). Bled IAP to OT from 2010 psi to 1440 psi in 1 hr. TP decreased 10 psi, IA FL unchanged. Monitored during RD. IAP increased 10 psi. Final WHPs = 2390/1450/50. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:45 4/20/2021 T/I/O= 2400/250/50. LRS unit 72 Assist Slickline (PATCH TUBING / LINER). Pumped 5 bbls of 60/40 Meoh, 210 bbls of 1% SKL water and 38 bbls of diesel into the TBG. Final T/I/O= 0/250/70. 4/21/2021 ***WELL S/I ON ARRIVAL*** (patch tbg / liner) LATCHED BAITED ASSEMBLY @ 8,696' BLM, JAR FROM 8,000# - 9,000# FOR 5 HOURS. ***WSR CONTINUED ON 4/22/21*** Daily Report of Well Operations PBU D-19C Daily Report of Well Operations PBU D-19C 4/21/2021 Assist Slickline w/ Load and Kill (PATCH TUBING / LINER) Pumped 2 bbls 60/40 meth, 240 bbls 120* 2%KCL, 2 bbls 60/40 meth and 38 bbls DSL down Tbg for load. SL in control of well per LRS departure. IA,OA=OTG 4/22/2021 ***WSR CONTINUED FROM 4/21/21*** (patch tbg / liner) LATCHED BAITED ASSEMBLY @ 8,696' BLM, JAR AT 9,000# FOR 4:15 HOURS (9:15 total). (No Recovery, No Movement) ***JOB COMPLETE, WELL LEFT S/I*** 4/25/2021 T/I/O = 2470/360/60. Temp = SI. WHPs (Post bleed). AL SI @ casing valve (1470 psi). The TP increased 80 psi, IAP increased 180 psi and the OAP remained unchanged since 04-19-21. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:10 4/28/2021 CTU #6 1.75" CT Job Objective: Fish LTP MIRU, MU BOT fishing BHA with Hipptripper. ***Job Continued on WSR 4/29/21*** 4/29/2021 CTU #6 1.75" CT Continue RIH with BOT fishing BHA. Latch fish at 8,735'. Work through 50 cycles on pipe alternating between jarring and hipptripper. Attempt to pump off fish, coil appears to have ice plug between reel and injector. Wrap reel and coil from reel to injector, spot heaters. Pressure up coil to 2000 psi and monitor. Ice plug released, online down coil with 60/40 MEOH 1 bpm. POOH and found 3 dogs on GS missing. Contacted OE and decision made to go forward with second fishing run. MU BOT jar/weight bar BHA and RIH. ***Job Continued on WSR 4/30/2021*** 4/29/2021 Temp=S/I Assist CTU. Drove to location to assist CTU. CTU got free. Unit not needed. 4/30/2021 CTU #6 1.75" CT Job Objective: Fish LTP Continue RIH with BOT weight bar/Jar BHA. Perform 25 Jar licks with the well offline. Stack well out with AL gas and POP to LP. Well stabilized, continue jarring on fish @ 8,720' ctm. Completed 50 cycles jarring 52k, pu weight 30k. No movement on fish. Pump off fish, POOH w/BHA. Spot check pipe, .113" wall thickness at 5,740'. On surface w/BHA. Blow down reel w/N2, RDMO CTU6. ***Job completed, fish not recovered*** 4/30/2021 Temp= 40* (Post CTU) Pumped 3 bbls 60/40, 26 bbls crude, 5 bbls 60/40, 37 bbls crude and 5 bbls 60/40 down FL. Flowline pressured up to 1500 psi. SV WV SSV closed. MV IA OA= open. Tags hung. DSO notified. 5/7/2021 T/I/O = 2400/1920/40. Temp = SI. Bleed IAP (mitigate TxIA). ALP = 1890 psi, SI @ CV. IA FL @ 5270' (sta # 4 SO). Bled IAP to OT to 180 psi in 3 hrs. TP decreased 10 psi. Monitored for 30 min. IAP increased 10 psi, IA FL unchanged. Final WHPs = 2390/190/40. ALP = 1500 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00 5/9/2021 T/I/O = 2400/1130/40. Temp = SI. WHPs (post bleed). ALP = 1130 psi, SI @ CV. IAP increased 940 psi from 5/7/21 SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00 Daily Report of Well Operations PBU D-19C 5/11/2021 T/I/O = 2400/2020/40. Temp = SI. Bleed IAP (Ops request). ALP 2020 psi, SI @ CV. Treecap ring gasket weeping gas, WS torqued flange to 1191 psi. PT good. IA FL @ 5270 (sta # 4 SO). Bled IAP to OT to 370 psi in 2 hrs 30 min. TP decreased 10 psi. Monitored for 30 min. IAP increased 10 psi, IA FL unchanged. Final WHPs = 2390/380/40. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:30 5/13/2021 ***WELL S/I ON ARRIVAL*** (gaslift integrity) SET 4-1/2" SLIPSTOP CATCHER @ 5,324' SLM. PULLED BK-OGLV FROM ST# 4 @ 5,270' MD. PULLED RK-GLV FROM ST# 5 @ 3,729' MD. SET RK-DGLV IN ST# 5 @ 3,729' MD. T-BIRD LOADED IA w/ 338 bbls CRUDE. SET RK-DGLV IN ST# 4 @ 5,720' MD. PULLED EMPTY 4-1/2" SLIPSTOP CATCHER FROM 5,324' SLM. T-BIRD PERFORMED PASSING MIT-IA TO 3,000psi. ***T-BIRD ON WELL UPON DEPARTURE (f/p flowline)*** 5/13/2021 T/I/O= 2400/2400/0 Assist Slickline (Gas Lift) Loaded IA w/ 2 bbl 60/40 methanol spear followed by 338 bbls 90* crude. MIT-IA to 3300 psi ***PASSED*** (see log for details) Freeze protected flowline w/ a 3 bbl 60/40 methanol spear, 30 bbl crude, 2 bbl 60/40 methanol tail (DSO request) Tags/AFE sign hung on IA/MV/W V. FWHP= 1900/450/50 SV/WV/SSV= C MV=O IA/OA=OTG. Well shut in upon departure. 8/14/2021 CTU #9 w/2" CT Job Objective: Fish LTP MIRU CTU, MU BOT fishing BHA. RIH and latch fish at 8,720' CTMD. Perform 24 jar licks and came free. POOH, on surface w/G-spear, no fish. C/O 4" Hydraulic G- Spear to more aggressive serated dogs. RIH w/BOT fishing BHA. Tag up at 8,715' ctm, unable to latch, no overpull. Jet on top of fish and hit several jar licks down, no friction bites or overpulls. Baited spear assembly possibly came apart. Pooh w/BHA to inspect. ***Job in Progress*** 8/15/2021 CTU #9 w/2" CT Job Objective: Fish LTP Continue Pooh w/fishing BHA. On surface w/tools. Recovered 4.5" bait sub, 3/4" SR box threads stripped on bottom of bait sub. Discussed plan forward w/OE. Make up drift BHA = 2" DJN. RIH 50' past previous jarring depth to confirm remaining spear assembly is below LTP. POOH and perform weekly BOP test. Cut 40' of 2" pipe. Make up BOT milling BHA & RIH. W ork through hydrate plug 1,870', continue RIH w/milling BHA = 3.80" 5 bladed junk mill. ***Job in Progress*** 8/16/2021 CTU #9 w/2" CT Job Objective: Fish LTP Continue RIH w/milling BHA. Milled remaining liner top packer (2.84') down to top of deployment sleeve with 3.80" 5 bladed junk mill. Start mill depth = 8,710.8' ctm, final mill depth = 8,713.8' ctm. Pull to surface with milling BHA. Day crew member tested positive for COVID, freeze protect well and shut down unit. ***Job in Progress*** Daily Report of Well Operations PBU D-19C 8/23/2021 CTU #9 w/2.0" CT Job Objective: Fish LTP Resume operations post COVID shut down. Lay down BOT milling BHA and perform 7 day BOP test. MU BOT milling BHA, stab on well and pressure test. Pop off well, install cap on BOPs, and secure unit for the night. ***Job in Progress*** 8/24/2021 CTU #9 w/2.0" CT Job Objective: Fish LTP RIH with BOT milling BHA. Tag top of LTP seals assy at 8716.5' CTMD. Attempt to mill for 3 hours and had frequent stalls, little motor work and no progress. Disscued with OE and wells foreman and decided to POOH and RDMO. FP well with 38bbls of diesel. ******Fish Left in Hole -SL weight bar, brush and itco spear pushed to 8788' CTMD**** ***Job Complete*** STATE OF ALASKA • 4110 ALASKA OIL AND GAS CONSERVATION COMI•ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing El Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: jGtGIDP El 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 212-152 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20707-03-00 7. Property Designation(Lease Number): ADL 0028285 8. Well Name and Number: PBU D-19C 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 10851 feet Plugs measured See Attachment feet true vertical 9019 feet Junk measured feet MAY 0 4 2016 Effective Depth: measured 9828 feet Packer measured 8465 feet true vertical 9024 feet Packer true vertical 8289 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse:/ Structural Conductor 80 20"x 30" 38-118 38-118 Surface 2663 13-3/8"72#L-80 37-2700 37-2700 4930 2670 Intermediate 6197 9-5/8"47#L-80 34-6231 34-6084 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9600-9660 feet feet 9900-9930 feet 9930-9960 feet 10160-10190 feet 10190-10220 feet 10220-10250 feet 10250-10280 feet 10280-10310 feet 10310-10340 feet 10605-10805 feet True vertical depth: 9030-9029 feet feet 9023-9023 feet 9023-9023 feet 9027-9028 feet 9028-9030 feet 9030-9030 feet 9030-9031 feet 9031-9030 feet 9030-9028 feet 9023-9019 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 32-8532 32-8355 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Hydro Set Packer 8465 8289 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED JUN 2 12016 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 476 36845 -476 796 895 Subsequent to operation: 575 4277 216 416 190 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 2 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ 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 / /_ Phone +1 907 564 4424 Date 5/4/16 Form 10-404 Revised 5/2015 V'TL 5-1 Q RBDMS u- 10j 2016 Submit Original Only • • Plugs Attachement PBU D-19C SW Name Date MD Description D-19C 03/31/2016 9828 2-7/8" CIBP D-19C 06/30/2015 10104 2-7/8"WFD CIBP D-19C 08/06/2013 10576 2-7/8" WFD CIBP • • d 0. O O O O O O co I• O O M O Lo CO N Cf) O N 'Cr I� U 1' 00000 00 N- 174 co N- M O N- M • O CO N C0 V CO f- CO CO co O O O CO C7) O) O O CO N CO N L) f— O co CO CO O O co N CO CO CO CO O) 0) CO Cl I- N- CO CO CO O) co I- V co O N N CO CO CO 0) CO to CO CD CO O O CO CO O) G) 0 0 CDN N CO ' N O M O CA M I� N CO CO CO co LO -C • N CO O CO CO O CO V Cl CO U < "CrNN- NCO r CO N- V CO CO CO 6) LU N C) I CO CO M O L I- I,- CO CO CO O CO CO 0) . M W O O \ a CD O L- O co O aLO - J M JO J CO = G1 OM N *k J I N • O U \0 CO N N - N N Po N CO co1.0' N M N O co NCO V 4 t O t!) O C)O CO ap, LO O O J O N CO N N O N- CO W c "U Z c W W W W W W pp O D H Z Z Z Z Z J U Cn Z J J J J J I- • 0 t / k E $ G Om / co // (33 w . 2 5 I e 2 » E 7 \ 2 c as o 0 \ \ R / c t a) � Do \ 09 bC) E / / \ E ° O = C / � / ® » o » - / / § E as < / -\k 2 ..tc:DE \ 0 L. 7 b 52 / \ \ O F- 0 / _ ? % % b 9 L.) bg % _c) c CDe- eN £ a N b e 3 RD -- / / .- & \ o a > > F o 0 \ )N. CNJ k \ 0- Ein" la' 2 E -, c a) o + 0) 0C » ° 2 < / / / e >, C 0 U o I / \ . co I .g $ CO _1 p o 4 C Q LJ C / / k / W �/ / ƒ / / \ k \ / -� ° 7 Ct .. \ co/ 2 n C / » c® , » c 9 / E _ > a J E ® t \ E / 3 / t 9 y (DO Z E 9 y I e I U2 _ CD � D @ OO < / \ / \ OE /E \ \ / ƒ 2 / c 2 \ / \ / / / > 7I ® = / A .4- < • i 6"CAN —SIC NOTES:WELL ANGLE>70°@ 9325'. WE_LfEAD= MCEVOY D-1 9 G ***4-1/2"CHROME TBG&LNR*** 'ACTUATOR= BAKER C INTIAL KB.ELEV= 76.4' BF.Bi_EV= 42.95' 2 ' ' 1....._W2128' 1-1-4-1/2"HES X NP,D=3.813" 1 KOP= 4250' 30"CONDUCTOR? - -100 Max Angle= 98°§9555' _ GAS LIFT MANDRELS Datum MD= 9092 ST MD TVD DEV TYPE VLV LTCH PORT DATE Datum TVD= 8800'SS 6 2988 2988 1 MMGM OW RK 0 09/20/01 �13-3/8"CSG,72#,L-80 BTRS, .._7_.. 5 3729 3729 0 MMGM DOME RK 16 12/20/12 D- 12.34 "� -�2702�_._.1 4 5270 5199 24 KBG2 SO BK 20 12/20/12 9-5/8"X 7"BKR ZXP PKR H 6079' 3 6600 6441 5 KBG2 Y BK 0 09/20/01 R w/6'TACK,D=6.151" WY 7635 7470 7 KBG2 DMY BK 0 09/20/01 9-5/8"X 7"BKR FLEX-LOCK - 6092' 1 8373 8198 9 KBG2 DMY BK 0 09/20/01 HY D LNR HGR,ID=6.151" 9-5/8"MLLOUT WINDOW(0-198) 6231'-6247' 9-5/8"CSG,47#,L-80,ID=8.681' - -6231' ' 1 8440' =-3.813" J Minimum ID =2.36" @ 8731' 4-112" KB L N R TOP PACKER ® XI 8461' -17"x 4-1/2"BKR S-3 PKR D=3 875" I I -8494'_-1-4-1/2"HES X NP,D=3.813' ' ' 8515' --+4-1/2"HES XN N8P,MILLED TO 3.80"(12/02/12) 4-1/2"TBG 12.6#,13CR-80 VAM ACE, --{ 8527' ' .-. 8527' H4-1/2"WLEG,D=3.958" 0152 bpf,D=3.958" \� 8528' 47"X 5"BKR ZXP LTP w/6'TIEgK,D=4.408" TOP OF 4-1/2"LNR 4 8628' .-... "-.-***-----"`i \ 8541' -17"X 5"BKR HMC LNR HGR,D=4.410" 7"LNR,26#,L-80 M-BTC,.0383 bpf,C)=6.276" -j 8694' A L 8548' H5"X 4-1/2"XO SUB,D=3.940" 3-1/2"LNR,9.2#,L-80 STL,.0087 bpf,ID=2.992" J- 8791' 4-112"LNR,12.6#,13CR-80 VAM ACE, -1 8810 C 8731' -j4-1/2"BKR 45KB LIP,D=2.36"(12/10/12) .0152 bpf,D=3.958" 8737' H3.70"DEPLOYMENT SL V,D=3.00' 4-1/2"BKR KB WHIPSTOCK- (12/0371"2)-- 8810' 8758' -13-1/2"HES X NIP,ID=2.812" (W/RA TAG @ 8811) 6. 8791' H3-1/2"X 3-3/16"X0,D=2.786" r• 3-1/4"LNR,6.6#,L-80 TCI,.0079 bpf,D=2.850" -J 9655' \ 1:'i 4-1/2"MILOUT WINDOW(D-19C) 8810'-8819' PERFORATION SUMMARY REF LOG:SLB MCS ON 12/09/12 ANGLE AT TOP PERF:93°Q 9600' 9655' -13-3/16"X 2-7/8"X0,D=2.377" Note:Refer to Production DB for historical perf data - 9828' 2-7/8'WFD CEP(03/31/16) SEE SFF INTERVAL Opn/Sgz SHOT SQZ ' I 2" 6 9600-9660 0 04/01/16 , 2" 6 9900-9930 C 07/01/15 10104' 42-7/8"WFD CEP(06/30/15) 2" 6 9930-9960 C 06/30/15 ; 2" 6 10160-10190 C 08/28114 ' 2" 6 10190-10220 C 08/27/14 ' 2" 6 10220-10310 C 08/07/13 ' 2" 6 10310-10340 C 08/27/14 10576' -12-7/8"VVFD CEP(08/06/13) 2" 6 10605-10805 C 12/09/12 i PBTD 4 10813' 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,ID=2.441" - 10851' 40, DATE REV BY COMMENTS . DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/12/82 RIG A-3 INITIAL COMPLETION 09/04/14 CRR/114) ADPERFS(08/27-28/14) WELL D-19C 06111/96 PAB CTS SIDETRACK(0-1294) 09/23/14 JMD SCHEMATIC CORRECTIONS PERMIT No:P121520 09/20/01 D-14 SIDETRACK(D-19B) 07/29/15 I i WJMD SET CIBFYADPERFS(06/30-07/01/15) All Pb: 50-029-20707-03 12/10/12 NORDIC1 CTD SIDETRACK(D-19C) 04/05/16 TTR/JMD SET CBP/ADPERFS(03/31-04/01/16) SEC 23,TUN,R13E,1881'FNL 8 1692'FEL 01/07/13 CRR/PJC FINAL DRLG CORRECTIONS 04/19/16 TLWJMD CORRECTED CEP DEPTH 08/27/13 JJUJMD SET CEP/ADPERFS(08/06-07/13) BP Exploration(Alaska) : x1 STATE OF ALASKA ;�)i 3z L ALASKA OIL AND GAS CONSERVATION COMMI, V 15 • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Ak O G C C Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 :. Plug for Redd' 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: CI/3 P El 2 Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 212-152 3. Address: P O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20707-03-00 7. Property Designation(Lease Number): ADL 0028285 8. Well Name and Number: PBU D-19C 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10851 feet Plugs measured See Attachment feet true vertical_ 9019 feet Junk measured feet Effective Depth: measured 10104 feet Packer measured See Attachment feet true vertical 9024 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 37-117 37-117 0 0 Surface 2663 13-3/8"72#L-80 37-2700 37-2700 4930 2670 Intermediate 6198 9-5/8"47#L-80 33-6231 33-6084 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9900-9930 feet 9930-9960 feet 10160-10190 feet 10190 10220 feet 10220-10250 feet 10250-10280 10280-10310 feet 10310-10340 feet 10605-10805 feet True vertical depth: 9023-9023 feet 9023-9023 feet 9027-9028 feet 9028-9030 feet 9030-9030 feet 9030-9031 9031-9030 feet 9030-9028 feet 9023-9019 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 32-8532 32-8355 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: cc c 13. Representative Daily Average Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 326 25045 0 460 763 Subsequent to operation: 699 26440 0 1380 813 14.Attachments:(required per 20 AAC 25 070 25 071,8 25 283) 15.Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development Q( Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 121 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O.Exempt: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature J J n,.,1 Cdr Phone +1 907 564 4424 Date 7/31/15 Form 10-404 Revised 5/201_5_ l y v r L q /7-Ji Q/3- �� RBDM b t nginVy 1 4 2015 Plugs Attachement PBU D-19C SW Name Date MD Description D-19C 06/30/2015 10104 2-7/8"WFD CIBP D-19C 08/07/2013 10576 2-7/8"WFD CIBP m Y U Y 0 Q J o a) a) U aix 02 °- o Q� 2 - H Caci� NY Xa`) `a) a) N Y Y Y N N N a) mmm - - C CO N N (V d F- 0 N N < •— CO In CO V O CA Q) N c') O) : I ) 00 c) Ll) co N M to Qin 00 00 co RI a C cv v co e - N CO LO CY) CO CO N- V O Nr CO CO co a CecLcLce C.YYYY >+000U Q Q Q Q m rn rn rn rn 0000 w • a) O CD O C (NI• Pc.-0 [t O O V M co r CO• •t CO CO O O CO r r O VCOOMO) O) LC) r,, O 00 a— Cr) N IO N- O LO CO CO O O CO N000000OO) a) cc 1.0 CO CO O) N- CO Tr in O N N M Cr) M O) M LO CD O M LO CO CO CO 0) CD N_ OCD O N CD ' N O M0, O) L co M I� N CO 00 r- CD O LC) N CO CO CO 00 Cr) CO CU i i I I i I i Q• C) — O NCO r N- f- M O M M O) LC) N CM M M CD CO0 OD CO 0)) CO • • CO O O CO O co O O 120 LA r .I CO J J c0 I 000C') • ccnN # J N 4t N X N- N- 4t CD " CD CD • .• (1) b 0\0 N N _ = _DO N CV N M p C7 CV � M i 4 — co co O CO O) - C CO O C CO CO — CD OO LO CD LL) a1 N CO N N a0 N- CO J W Q C 0 0 U W W ea 00u_ CeCLCLa CLZ Z W W W W W W Q 0 H Z Z Z Z Z D Cn Z J J J J J I— a i � / ` 2 o S = a_ / 22 � - A 0 a 6 CU ± 70 ca ) U) Q o o £ o_ - .o " —_ - -0 0 0 -0 0 0 ` 2 L @ m kkk2t C)0 \ \ 7 ' $ e $ 82/ k • 2 0 © co 2 0 999 � � 2 o d a) ¢ E R E / ga � � = � U, c ± c6 to 0 �._ o E : � �Z0-C �� 2 CD ® 10 O 2 \- • § o 8 CO 03 < $ k _, 2 k o 0 / E@ 03 2 -0 G —/ 0 E O � E a o = a O f@ 1 o Q © E / 2 6 E 2 1- ~ k - 0- o q n \ 7 O @ - � � 2 ; � 5 � ¢ k0 � 2 \ 2 / � p a / Ea@ � � I -690 fo`.g % © c C/) o o � c _ « q .� = cEw . co 7r22o ¥ ao g) (n n 4- LL = o -J o C a 6 -I `- S > £ & 520 © -0 O ® \ a 0% o re 0co o / t cm >, m I ± [ E 2 � cc m - _o g - _o� ® ® 3CI o� � * - 0 11115 eMt o D 0) w : CO 0 e o 2 a@ � 0 = m % m _ « Z ai _ . � -02 G ® 7 \ o » • 7 f $ k 80)N- co- -c c O Q § $ 0 0 0 m 0 - -b % .$ 0 % \ g 2 e ,, CL I : \ \ g E.- Q a / / cc- 0 o § ca 2 * / 0 $ 0 .E* / / k 0 _ O » o = : 0 0_ D 0 = , m m m , w I— < m m in 1 i- \ 220 ,- - 0 _ _ - - , \ 6 R « TREE_ . 6"CNV IWE LU-EAD= MCEVOY D-19 C S. Of NOTES:WELL ANGLE>70°@ 9325'. ACTUATOR= BAKER C "'4-1/2"CHROME TBG&LNR••' NfTIAL KB_ELEV= 76 4' [1 BF ELEV= 42 95' / ' ' { 2128' H4-1/2'HES X NP,D=3.813" 1 KOP= 4250' 30"CONDUCTOR? J— —100 Max Angle= 98'@ 9555' Datum MD= 9092 Datum TVD= 8800'SS GAS LFT MANDRELS 13-3/8'CSG,72#,L-80 BTRS,D= 12 347" H 2707 ST NO ND DEV TYPE VLV LTCH PORT DATE 6 2988 2988 1 MGM DWI RK 0 09/20/01 i5 3729 3729 0 MGM DONE RK 16 12/20/12 9-5/8"X 7'BKR ZXP PKRH 6079' 4 5270 5199 24 KBG2 SO BK 20 12/20/12 w!6'TRACK,D=6.151" � 3 6600 6441 5 KBG2 CRAY BK 0 09/20/01 9-5/8'X 7 BKR FLEX-LOCK —i 6092' ■ 2 7635 7470 7 KBG2 DMY BK 0 09/20/01 HY D LNR HGR D=6 151" 1 8373 8198 9 KBG2 DMY BK 0 09/20/01 9-5/8'CSG,47#,L-80,D=8 681" —1 ^-6231' 9-5/8'MLLOUT WINDOW(D-19B) 6231'-6247' Minimum ID =2.36" @ 8731' 4-1/2" KB LNR TOP PACKER I ' 8440' —i4-1/2"HES XNP,D=3813" C 848' H7"X 4-1/2"BKR S-3 R(R,D=3 875' I I 1 8494' ]—{4-112'HES X NP,D=3.813' 1 I 8515' --14-1/2"HES XN MP,MLLED TO 3.80'(12/02/12) 4-1/2"TBG 12.6#,13CR-80 VAM ACE, H 8527' • N.-. . 8527' I--14-1/2"WLEG,D=3.958"1 0152 bpi,ID=3.958" I i v 8528' _17'X 5'BKR ZXP LIP w/6'TEBK,D=4.408" I TOP OF 4-1/2'LNR H 8628' 8541' H7"X 5"BKR HMC LNR HGR,D=4 410' 7'LNR,26#,L-80 M-BTC,.0383 bpf.D=6.276' H 8694' 8648' H5"X 4-112'XO SUB,D=3.940" 3-1/2"LNR,9.2#,L-80 STL,.0087 bpf.D=2 992' —1 8791' 4-12"LNR,12.6#,13CR-80 VA ACE, — —8810 ►� 8731' �4-1/2'BKR45KB LIP,D=2.36"(12/10/12) 0152 bpf,D=3 958" I 8737' —13.70'DEPLOYMENT SLV,D=3.00" o 4-12'BKR KB W-IPSTOCK(12/03/12) --i 8810' i I 8758' H3-1/2"HES X NP,ID=2.812" (W/RA TAG @ 8811) 3-1/4'LNR,6 6#,L-80 TCI,.0079 bpi,D=2.850" H 9655' / 8791' I-13-1/2"X 3-3/16'XO,D=2.786' k e, k 4-112'MLLOUT WINDOW(D-19C) 8810'-8819' PERFORATION S11J RY 14 REF LOG:SLB MNL ON 12/09/12 ANGLE AT TOP PERF 91'@ 9900' I Note:Refer to Production DB for historical pert data 96 ' H3-3116"X 2-718"XO,D=2 377' I SEE SPF NTE RVAL Opn/Sqz SHOT SOZ 2' 6 9900-9930 0 07/01/15 ! 10104' H2-7/8'WFD CEP(06/30/15) 2' 6 9930-9960 0 06/30/15 I 2" 6 10160- 10190 C 08/28/14 i 2" 6 10190- 10220 C 0827/14 Ii 2' 6 10220- 10310 C 08/07/13 2' 6 10310-10340 C 0827/14 10576' -2-7/8'WFD CEP(08106/13) 2' 6 10605-10805 C 12/09/12 1 PBTD 10813' ►� 2-7/8'LNR,6 5#,L-80 STL, .0058 bpf,ID=2 441" H 10851' s DATE REV BY COMNB'TTS DATE REV BY COMENTS FRUDHOE BAY UNIT 05/12/82 FIG A-3 INTIAL COMPLETION 09/04/14 CRR/AU ADPERFS(08/27-28/14) WELL D-19C 06/11/96 PAB CTS SI(ETRACK(D-129A) 09/23/14 JM) SCHEMATIC CORRECTIONS FIT Nb 2121520 09/20/01 0-14 SIDETRACK(D-19B) 07/29/15 TTR/JMD SET aBFTADPE RFS(06/30-07/01/15) AR No 50-029-20707-03 12/10/12 NORDIC1 CTD SIDETRACK(D-19C) SEC 23,T11 N,R13E,1881'FNL&1692'FEL 01/07/13 CRR/PJC FNAL DRLG CORRECTIONS 08/27/13 JJUJMD SET CBF ADR32FS(08/06-07/13) BP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable b direct inspection of the file. ca_ Jc5 .b Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: Col Items: pps: rayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: 7//lit. BY: ..0Maria Date: l/ ` /s/ n410 Project Proofing BY: Maria Date:Ia /7 //L /sl N// Scanning Preparation a, x 30 = IP 0 + 3 = TOTAL PAGES (03 (Count does not include cover sheet) BY: MEP Date: ` /s/ Production Scanning ((9 Stage 1 Page Count from Scanned File: 1 (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: V YES NO BY: dIM Date: `a//7 `4 /s/ VI1'P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o a 11 M N Q0 t r Z Z , Z c. w a rii a Z c J m >- >- > N m o NN O + I 1 I `N N 9 5 >- O L >. h I co a O J a ` c �o as 71) Z Z Z + aoZ a L O E cOn U U 'O r :c :? Z U a m Q O n- a a m d d 2, 1" c m c N p O co S o CO aLL ;7; U U m c E lb Z 0 o c o o U Z E y 11 - o dl a oa) as. Z`Z o O : c Q Q Y a E Z U-_ as / Z (Z _ 0 zv_; E ai N m o U a) a) 0 E E >- >- >- v O 0 E co Cr) 2 U 2 a U f0 /a) o 0 ii O0 � m co r Z c N N M M a"' ) •�•' co CL P¢ as > N N N N E N Q W N N (! CO N Z y a Ce O ii T-. N-- M O) li N CO a CO iL E X ! cc c c 0 • vi co V cop O U O O O O 'a E ° Z co / '_ U W C Qcr o coocoN N o▪ o co IV a O o 0 0 -o a .E a To J CC _ us 1 c • o UO - lm CL 1Z1 cN 0 ) i o) a) v- O N a lE as I Ii U as /Z J " I z° r >- Q %cn - a ) o J co a m ~Z N Z O)�ap 0 8 1 i) co CO = N g J 2 U m• c l C O I J y Z:: 0 II . CO Q / CO � UU on To J N N C o d E 1- E - O as I CC .�1°. •c 0) U I 1 0 CO I co y c- 4 co ill Q CL C 0 vi c L.= o co .c acli \ Q c ZI ▪ L O 121 Z o 2 a2i -6 E U J 0 2 2 I 1 I Z7 II M 7 7 (n () O) c E m o o c c l o o Z I o 4c„ i) /� ` 6co) 6 Z Z E p } Jç jQ J �- O L N N w min r N N N C / 'O‘C71 1— w m cc j 0 r O W O Z N N d W O O d �_ U EE Z N Ce CI I' co Z c .-) a i3 0 a N Zto H m 0 w Ce Z W J IU U U r a 7 0 I E ca •a E p fa d - - O E o E E a 0 I 3 -1G -- w J w z U o U' 0 1 U / 777 STATE OF ALASKA RECEIVED A KA OIL AND GAS CONSERVATION COMMISSION SEP 2 5 ?014 REPORT OF SUNDRY WELL OPERATIONS a_ 1 Operations Abandon U Repair Well U Plug Perforations U Perforate U OtheI CCC Performed Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4 Well Class Before Work 5 Permit to Dnll Number Name BP Exploration(Alaska),Inc Developments Exploratory ❑ 212-152-0 3 Address P 0 Box 196612 Stratigraphic❑ Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-20707-03-00 7 Property Designation(Lease Number) 8.Well Name and Number ADL0028285 PBU D-19C 9 Logs(List logs and submit electronic and pnnted data per 20AAC25 071) 10.Field/Pool(s). PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary Total Depth measured 10851 feet Plugs measured 10576 feet true vertical 9019.46 feet Junk measured None feet Effective Depth measured 10576 feet Packer measured See Attachment feet true vertical 9024 79 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 36.97-116.97 35-110 0 0 Surface 2663 1 13-3/8"72#L-80 36 67-2699 77 8352 11 -8352 94 4930 2670 Intermediate 6197.53 9-5/8"47#L-80 33.47-6231 8063 48-8508.86 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10160-10190 feet 10190-10220 feet 10220-10250 feet 10250-10280 feet 10280-10310 feet 10310-10340 feet 10605-10805 feet True Vertical depth 9026.66-9028.39 feet 9028.39-9029 59 feet 9029 59-9030 45 feet 9030 45-9030 64 feet 9030.64-9029 8 feet 9029 8-9027 81 feet 9023 32-9019.39 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 31 63-8531 91 8370.3-8371 13 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary. Intervals treated(measured) Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 297 19862 0 0 421 Subsequent to operation 401 24765 1727 1100 232 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run ExploratorL❑ Developments Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil U Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCJ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt. N/A Contact Nita Summerhays Email Nita.Summerhays@bp.com Printed Name Nita Summerhays Title Petrotechnical Data Engineer :ignatur- %/Ji ,�//i�; i�/ �� `_ Phone 564-4035 Date 9/24/2014 V" I°/z 3/19 RBE MS SEP 26 203 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028285 I :; . col 7= -.- •• ••lec ive: £ •pe MIRU. RU memory gr/ccl inside 2.2"carrier w/2.25"JSN. Begin loading down CTBS (10bbI meth spear)and 1%KCL w/SL. RIH after WHP knocked down to 1000psi. Tagged PBTD 10,568'CTM, breakover, wait 5min on top of plug to get corrected PBTD, log up to 10,400', paint white flag (5min stop) log up to 9000' at 45fpm. POOH. 8/26/2014 ***Job continued on 8-27-14 WSR*** CTU#8 1.5"coil CV=24.4bbl Objective:Add pert LD PDS GR/CCL (+8' correction). PT MHA. MU 30' of SLB 2.0" PJHMX Guns (OAL: 38.61' MOD: 2.13"). RIH. Troubleshoot injector noise. Correct depth at flag to 10405.17' (TOP SHOT). PUH. Pump ball to seat w/ 1% slick KCL + safelube. PERFORATED 10310'-10340'w/2.0" SLB 2006 PJHMX at 6 SPF and 60 deg Phz. POOH. LD spent guns. Repair injector. PT MHA. MU 30' of SLB 2.0" PJHMX Guns (OAL: 38.61' MOD: 2.13"). RIH. PERFORATED 10190'-10220'w/2.0" SLB 2006 PJHMX at 6 SPF and 60 deg Phz. POOH. LD spent guns, ball recovered. MU 30' of SLB 2.0" PJHMX Guns (OAL: 38.61' MOD: 2.13"). RIH. 8/27/2014 ***Job continued on 8-28-14 WSR*** CTU#8 1.5"coil CV=24.4bbl Objective:Add pert RIH w/30'of SLB 2.0" PJHMX Guns (OAL: 38.61' MOD: 2.13"). RIH. PERFORATED 10160'-10190'w/2.0"SLB 2006 PJHMX at 6 SPF and 60 deg Phz. POOH. LD spent guns, ball recovered. Freeze protect tubing 38 bbls 50/50 McOH. RDMOL. 8/28/2014 ***Job complete*** FLUIDS PUMPED BBLS 20 50/50 METH 280 1% KCL W/SAFELUBE 300 TOTAL CI) 0. O O Q � (0 DD Rs N IU c) r•-- - v10N— co U y QQQQ • O O O N- co Cfl N- co co co N O O) NI- co co r co V co M V '— O) N N CO CO CO O) O) CO x— CO O) CO N LO 1"-- Lo �Ln — O — (N (") M M 00 O) N 00 CO 00 CO CO• CO 10 U) 00 01 M M (Ni O co oD CO M 6) CO N M O co O N co co co 00 N CO CO CO CO C w ti MOM � CO CD (-0 CO N CO O) CO (N O) co O) 11) M O) CO (O CO 00 I� CO O CO I— CO CO O) '— N 00 m ina , Q (NO N_ M Ln CO CO V co ('7 N (O CO CO • N COCOO 00 00 N M CO CO () CO O) 1▪7 C - � QCI O co sCO O O CO 0 ' C00U 0 J cop CO J J J J co O CN (() N y J •Cl) N X V *k COCfl N- CO U _ CO N o‘i00 CV CO CO M LC) ' N M M V V r C) CD C C CD (1) J J LU Q CO0 LU tnD2 vU V Z W LU W UJ W W c 01— Z Z Z Z Z J D U Z J J J J J (/) Packers and SSV's Attachment ADL0028285 SW Name Type MD TVD Depscription D-19C PACKER 6087.14 5873.73 7" Baker ZXP PKR/HGR D-19C PACKER 8465.44 8213.23 4-1/2" Baker S-3 Hydro Set Packer D-19C PACKER 8535.98 8283.1 4-1/2" Baker ZXP Mech Set LT Packer D-19C PACKER 8732 8476.9 4-1/2" Baker KB Top Packer TREE= 6'CNV IMELU-EAD= MCEVOY D 19 C SAFETY NOTES:WELL ANGLE>70°@ 9325'. ACRWIOR= BAKER "'4-12"CHROME TBG& LNR'"• NT1AL KB.ELEV= 76.4' BF.ELEV= 42.95' ' r { 2128' —14-1/2"HES x NP,D=3.8131 KOP= 4250 30'CONDUCTOR?— -100 Max Angle= 98"@ 9555' Datum MD= 9092' Datum ND= 8800'SS 4GAS LFT MANDRELS 13-3/8"CSG, 72#,L-80 BTRS,D=12.347" H 2707 ST M) ND DEV TYPE VLV LTCB PORT DATE 6 2988 2988 1 !MGM MY RK 0 09/20/01 5 3729 3729 0 MMGM DOME RK 16 12/20/12 9-5/8'X 7"BKR ZXP R(R H 6079' 4 5270 5199 24 KBG2 SO BK 20 12/20/12 w/6'TEBACK,ID=6.151' 3 6600 6441 5 KBG2 EMI BK 0 09/20/01 2 7635 7470 7 KBG2 DMY BK 0 09/20/01 9-5/8'X 7"BKR FLEX-LOCK H 6092' J HYD LNR I#GRD=6.151' 1 8373 8198, 9 KBG2 DAY BK 0 09/20/01 9-5/8'CSG,47#,L-80,D=8.681' — -6231' 9-5/8"MLLOUT WNDOW(10-198) 6231'-6247' Minimum ID = 2.36" @ 8731' 1 4-1/2" KB LNR TOP PACKERI u 8440' —4-1/2"HES XNP,D=3.813" Z 8461' --17"X 4-1/2"BKR S-3 PKR D=3 875" ' 1F 8494' H4-1/2'HES X NP,D=3.813' ' I 8515' - 4-12'FES XN NP,MLL®TO 3.80'(12/02/12) 4-1/2'TBG 12.6#, 13CR-80 VAM ACE, H 8527' • \ WD 8627' H4-1/2" LEG, =3.958' .0152 bpi,D=3.958" 8528' 4 7"X 5"BKR ZXP LTP w/6'nEBK 0=4.408' TOP OF 4-1/2'LNR H 8628' *1 8541' -{7'X 5'BKR HMC LNR HGR 0=4.410' 8548' H5"X 4-1/2"XO SUB.D=3.940" 7"LNR,26#,L-80 M-BTC,.0383 bpf,D=6.276' —1 8694' ] A , 3-1/2"LNR 9.2#,L-80 STL,.0087 bpf, D=2.992" -i 8791' C8731' —�4-1/2'BKR 45KB LTP,D=2.36'(12/10/12) 8737' H 3.70'DEPLOYMENT SLV,D=3.00" 4-1/2"LNR 12.6#,13CR-80 VAM ACE, — -8810 .0152 bpf,D=3.958" 8758' H3-1/2"HES X MR D=2.812" ' 4-1/2'BKR KB WHIPSTOCK(12/03/12) H 8810' 8791' —3-1/2'X 3-3/16"XO,D=2.786' (WI RA TAG @ 8811) C • - 3-1/4"LNR,6.6#,L-80 TCI,.0079 bpf,D=2.850" — 9655' ' - 4-1/2'MLLOUT WINDOW(D-19C) 8810'-8819' ti F$2FORATION SLM4 RY REF LOG:SLB MCAL ON 12/09/12 ANGLE AT TOP PERF.86'@ 10160' 9655' -13-3116"X 2-7/8"XO,D=2.377" Note:Refer to Roduction DB for historical perf data SCE SFS INTERVAL Opn/Sqz 1 SHOT SQZ 2' 6 10160- 10190 0 08/28/14 7 6 10190- 10220 0 08/27/14 2' 6 10220- 10310 0 08/07/13 2' 6 10310- 10340 0 08/27/14 10576' —12-718'WFD CEP(08/06/13) 2" 6 10605- 10805 C 12/09/12 PBTD H 10813' 12-718"LNR 6.5#,L-80 STL,.0058 bpf,ID=2.441" — 10851' DTE ' FEV BY 1 COM ENTS DTE REV BY COW/UNITS FRUCHOE BAY UNIT 05112/82 RIG A-3 41NTIAL COMPLETION 09/04/14 CRP/AD ADFERFS(08/27-28/14) _ WELL D-19C 06111/96 PAB CTS SIDETRACK(D-129A) 09/23/14 JMD SC1-6NATIC CORRECTIONS PEF1 T Pb:2121520 09/20/01 0-14 SIDETRACK(D-198) AR Pb: 50-029-20707-03 12/10/12 NORDIC1 CTD SIDETRACK(0-19C) SEC 23,T11N,R13E, 1881'Ft•L& 1692'FEL 01/07/13 CRR/PJC MAL DRLG CORRECTIONS 08/27/131 JJUJMD SET CIBRADPERFS(08/06-07/13) BP Exploration(Alaska) AL" Cr./ # ti Lo �. i•-•53 8 Ln . a) 0 co i` s . 0 0 0 0 0 0 0 0 0 0 0 0 D 0 0 0 0 0 s3 in 000000000000000000 U < ('I P P P P P P P P P P P P P P P P P P 1--i r 1 ,1 1 N H ..r-1 • '..� 0 L1J co LL, 0 d 8 WJ P P P P P C� P P P P P P C� P P P . P m pO Yr. (U c-_-) u ,� ID N U N = E-I r9 U) w tp 4- }- km 012 u) to no CD o Al r® 0,6 kY' ` N Ln ^ r Q.) „� y ny`�l r CO r r CO CO CO CO r P P CO M +�+ N LPr M W' + ''i iLt YL G �_ C C C i P Q. �' C �' C. P ,- 1....._. N cu �+ os r-I= o �~ � `� 7 7 3 7 j f4 3 3 7 3 7 3 d 7 •3 3 ^\ `J ^ '-1 .moi I- fl O M B. M Y- - OO M AO . CO. e. O CO an � ^ft .� 00 al �� M f�1 f�9 C�4 O CV f�9 P CO P X CT- `� r —/11"s:gy r •9;firfli )...._ ►_ 2 2 M UJ w w a D' LL (n LL LL (n (n LL LL. LAI W W �I OC w W OC J G a CL 0 G. CL a m C.9,„. CL a -I a a a s IX 0 0 0 0 0 0 w 0O O 0 00 -1O Lu a w w w (n w 0 () w w iZ w w U U w 4- Ln E PI e` O Ul Ln CA Ai Q ® CC 1.-- (-. e 4!5 41.7 GS i `,: �e , TM co et ,� O O i® co oo P O I''e P LD O �.� di SD 0 P co co co N O M P O O O co O O O O O O O O O O Q, —.- O ® O ® O ® G O Oi O, O o ® 0 0 0 o0 ') Q CO o ,.....^,- y� LL NJ 1 ® 1 ti s CI iil 5 X. a� L_ X ) o MN o `rte. O < n )t (n a <CUJ u) -) W ‹ 0 <( 0 'j -a MN d- .-t et J et 0 in P LL J e4 er P C.) N9 -I A L -9 J LL ` 4J p a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 `1 c iii S- o p crQ 1 co z IN y g al v ai `® c�co CC �t `> c cw cif o ® \ v G os a :u ® N w ® co w CO 0 o ch 1 9 O w III (-) tF5 ais '1 ..........-, 1 X a co RECEIVED STATE OF ALASKA AL„oKA OIL AND GAS CONSERVATION COMMIk„iON AUG 2 9 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1 Operations Abandon U Repair Well U Plug Perforations Li Perforate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown] Stimulate-Other ❑ Re-enter Suspended Well❑ 2 Operator 4.Well Class Before Work- 5.Permit to Drill Number: Name BP Exploration(Alaska),Inc Development Exploratory ❑ 212-152-0 3 Address P.O Box 196612 Stratigraphic❑ Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-20707-03-00 • 7 Property Designation(Lease Number): 8 Well Name and Number ADL0028285 . PBU D-19C • 9 Logs(List logs and submit electronic and pnnted data per 20AAC25.071) 10 Field/Pool(s) To Be Submitted PRUDHOE BAY,PRUDHOE OIL ' 11 Present Well Condition Summary Total Depth measured 10851 feet , Plugs measured 10576 feet true vertical 9019 46 feet Junk measured None feet Effective Depth measured 10576 feet Packer measured See Attachment feet true vertical 9024.79 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20”x 30" 33-113 33-113 0 0 Surface 2668 13-3/8"72#L-80 32-2700 32-2699 92 4930 2670 Intermediate None None None None None None Production 6200 9-5/8"47#L-80 31-6231 31-6083.57 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10220-10250 feet 10250-10280 feet 10280-10310 feet 10605-10805 feet True Vertical depth 9029 59-9030.45 feet 9030 45-9030.64 feet 9030.64-9029.8 feet 9023.32-9019.39 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 27-8527 27-8350 63 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary Intervals treated(measured) Treatment descnptions 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. 630 37225 0 0 930 Subsequent to operation: 511 26521 27 0 1127 14.Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory❑ Development❑✓ - Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work: Oil U' Gas LJ WDSPQJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUcJ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt N/A Contact Nita Summerhays Email Nita.Summerhayst BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician Signature =/-s��/' i' Phone 564-4035 Date 8/28/2013 I/14:: `r RBDMS SEP - 5 ///a7/3 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028285 CTU#8 1.75"CT. Objective: Drift, PPR , ,AdPerf 8/4/2013 MIRU. «<In Progress>>> CTU#8 1.75"CT. Objective: Drift, PPROF, CIBP, AdPerf <<<Continued from 08/04/13>>> MIRU. RIH w/2.25" DJN drift. Tag TD at 10,793'CTM. Per previous log correction tag is deeper than desired depth of 10,805'ELM. PU 40' to 10,753'CTM and paint white/yellow flag. POOH. LD drift, MU logging BHA. RIH with SLB PPROF + GHOST(max OD = 1.93", OAL = 31.7'). Log 40, 60, 80 fpm up passes. SI well between passes. Perform stop counts at 10778', 10615, 10550'CTM. Log jewelry 8/5/2013 tie-in log up from 10,780 to 8,300'CTM. POOH. Good data. «<In Progress>>> CTU#8 1.75"CT. Objective: Drift, PPROF, CIBP, AdPerf <<<Continued from 08/05/13>>> Spear in 6 bbls 60/40, Kill well w/220 bbls of 1% KCI. RIH w/WFD 2-7/8" CIBP. Correct depth at flag to SLB Mem CNL dated 12/08/13. RIH. PU and set WFD 2- 7/8" CIBP at 10576.2' mid-element(10575.75' top of plug). Tag CIBP. POOH. Cut 100' of coil, change packoffs. MU Gun#1: 30' of 2.0" perf guns. RIH. Tag CIBP and correct to 10575' (btm shot). Perforate from 10,280' to 10,310'. POOH. MU Gun#2: 8/6/2013 30' of 2.0" perf guns. Currently RIH. <<<Continued on 08/07/13>>> C . Objective: Drift, PPROF, CIBP, AdPerf «<Continued from 08/06/13>>> Continue RIH with Gun#2 (30' of 2.0" perf guns). Tag CIBP and correct to 10575' (btm shot). Perforate from 10,250' to 10,280'. POOH. LD Spent guns. PT MHA. MU Gun #3 (30' of 2.0" pert guns). Tag CIBP, correct to 10575 (btm shot). Perforate 8/7/2013 10220' to 10250'. POOH. RDMO«<Job Complete>>> FLUIDS PUMPED BBLS 435 1% SLICK KCL WITH SAFELUBE 10 60/40 METH 40 50/50 METH 485 TOTAL m a 0 0 0 0 ca 0 � N-; c0 �(Ot0o O N- N N- U II) O O O O O O 1 M O ~ CO CO ' O O CO O NI- co m co CO CO CO x— CO I- N CO O CO O Nr LO O) CO • N O) O) CO 0) 0 N CO O t0 O CO 0 0 0 CO CO CO O) 0) CO N CO H N CO CO c- (fl N CO 0 CO 1- CO N O N N- CO in t1) (y M CO (N1 CO O CO 0 CO CO CO O 4.0 CD M N NCc) coin O I� O Lc) O co O • O_ (0 O N CV CC)CO00 6) CO N CO t.) C in 0 < N a0 N- N CO Co M N M O) LO N 1— a) (V CO LO N- CO CO CO N C c co co co O c • J QL O 0 0 0 0 oOL- OCO CO _ J J J J M C 0 *k a) co u "! N N *k � N X co • , - O _ CO _ - N CO • N r LO ' N M 0-) N 4 L LO 40 CO 0 a)O 0) to O) O CO co C co co CO O N CO toa) O CO N CO J z O O w D DUCE MOCCCCCCCC � tuiz U z w w w w O m O z_ z_ z_ z_ ct D D U J J J J 0- Cn � U N o_ 0 N J c N O u) Q O U >, to = X C (n N Y Y ca co 00 Co = N N 0 4 4 V 4-1 }I ct N N O) 00 > N eco cn O cl, -a Q V CO C) rLX) co co a cc cc YO. Y >+UU Q Q 0 d Z a) a) 6 6 U, TRIS= 6"CNV W ELL ANGLE> WELLHEAD= MCEVOY v D -1 9 C SA 4-1/2NOCHRO E TBG& LNR***0°@ 9325'. ACA.I4TOR=` BAKER C M1AL KB.E-EV= 76.4' � BF.E EV= 42.95' ' ' I 2128' 1-14---1-/-7 HES X NP,D=3.813" KOP= 4250' 30"CONDUCTOR? —I —100 Max Angle= 98°@ 9555' Datum MD= 9097 Datum TVD= 8800'SS 4GAS LFT MANDRELS 13-3/8"CSG,72#,L-80 BTRS,D=12.347" —I 2707 ST MD ND DEV TYPE VLV LTCH FORT DATE 6 2988 2988 1 MMGM DMY RK 0 09/20/01 5 3729 3729 0 MMGM DOME RK 16 12/20/12 9-5/8'X 7"BKR ZXP PKR —I 6079' I. 4 5270 5199 24 KBG2 SO BK 20 12/20/12 w I6'TACK,D=6.151" 3 6600 6441 5 KBG2 DMY BK 0 09/20/01 2 7635 7470 7 KBG2 DMY BK 0 09/20/01 9-5/8"X 7"BKR FLEX-LOCK —{ 6092' HY D LNR HGR D=6.151' 1 8373 8198 9 KBG2 CMY BK 0 09/20/01 9-5/8"CSG,47#,L-80,D=8.681" H —6231' 9-5/8"MLLOUT WINDOW(D-198) 6231'-6247' Minimum ID = 2.36" @ 8731' 4-1/2" KB LNR TOP PACKER ` i - 8440' —I4-to"FES XNP,D=3.813" \ I 8461' H7"X 4-1/2"BKR S-3 PKR,D=3.875" ' ' r_ 8494' 1--14-1/2'FES X NP,D=3.813" ' ' 8515' H4-1/2"FES XN NP,PALLED TO 3.80"(12/02/12) 8527' - 4-1/2"WLEG,D=3.958" TOP OF 4-1/2"LNR --I 8528' I \ = 8528' _17"X 5"BKRD ZXP LTP w/6'TN�K, =4.408" 4-1/2"TBG 12.6#,13CR-80 VAM ACE, — 8527 \ .0152 bpf,D=3.958" \ 8541' 7"X 5"BKR HMC LNR HGR,0 4.410" 8648' H5"X 4-1/2"XO SUB,D=3.940" 7"LNR 26#,L-80 BTC,.0383 bpf,D=6.276' --I 8692' I , C8731' H4-1/2"BKR 45KB LTP,D=2.36'(12/10/12) 8737' —13.70"DEPLOY MBNT SLV,D=3.00" 3-1/2"LNR,9.2#,L-80 STL,.0087 bpf,D=2.992" H 8791' 8758' 3-1/2"FES X NP,D=2.812" 4-1/2"LNR,12.6#,13CR-80 VAM TOP, —I —8810 —I 8791' --I3-1/2"X 3-3/16'XO,D=2.786" .0152 bpf,D=3.958" 4-112"BKR KB WHIPSTOCK(12/03/12) — 8810' { 4-1/2'MLLOUT WINDOW(D-19C) 8810'-8819' (W/RA TAG@8811) 3-1/4"LNR,6.6#,L-80 TCI,.0079 bpf,D=2.850' —I 9655* PERFORATION SUMMARY . 9655' H3-3/16-X 2-7/8"XO,D=2.377' RE=LOG:SLB MOW ON 12/09/12 ANGLE AT TOP PERE:88'@ 10220' 10576' H 2-7/8"VVFD CEP(08/06/13) Note:Refer to Production DB for historical perf data SIZE SEE I1TH VAL Opn/Sqz SHOT SQZ 2' 6 10220-10310 0 08/07/13 2" 6 10605- 10805 C 12/09/12 PBTD —1 10813' 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,D=2.441" —I 10851' .A DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 05/12/82 RIG A-3 INITIAL COMPLETION 01/05/13 PJC DRAWING REFORMAT WELL: D-19C 06/11/96 PAB CTS SIDETRACK(D-129A) 01/07/13 CRR/PJC FINAL DRLG CORRECTIONS PERMT No: 2121520 09/20/01 D-14 SIDETRACK(D-19B) 08/27/13 JJUJND SET CBPADPEFFS(08/06-07/13 API No: 50-029-20707-03 12/10/12 NORDIC 1 CTD SIDETRACK(019C) SE:23,T11 N,R13E, 1881'FNL&1692'FE- 12/26/12 ?/JMD DRLG DRAFT CORRECTIONS r 12/27/12 DLW/JMD GLV CIO(12/20/12) BP Exploration(Alaska) p LOGGED . 1 12013 R �..9 1a, ra ��. .M K BENDER � ..r7 f,-� ,,� BAKER PRINT DISTRIBUTION LIS' G o 5 2013BAKER HUGHES AOGCC COMPANY BP Exploration(Alaska)Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 20 WELLS RUN NUMBER ' 2_ fS Z. (mandatory) 2- S 5 FIELD Prudhoe Bay BH SALESMAN Jesse Salyer (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: TODAYS DATE: 7/30/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: BP Exploration(Alaska)Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY D FIELD FINAL (digital, 1 ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #UI-I-i-iN I S #OF COPIES #OF COPIES V V V V 1 BP Exploration(Alaska)Inc. I 3 I 1 I Petrotechnical Data Center LR2-I 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I I 1 I I Attn Ricky Elgarico PO Box 100360 Anchorage,Alaska 99510 3 ExxonMobil,Alaska I I 1 1 I I Attu Lynda M.Yaskell and/or Leonardo Elias 3700 Centerpointe Dr. Suite 600 Anchorage,Alaska 99503 4 State of Alaska-AOGCC — I I 1 I 1 I I Christine Shartzer 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas I I I 1 I I I Attn:Scan Clifton 550 W.7th Aye,Suite 800 Anchorage,Alaska 99501 TOTALS FOR THIS PAGE: 0 5 5 0 0 0 TOTALS FOR ALL PAGES: #REF! #REF! #REF! #REF! #REF! #REF! RECEIVED STATE OF ALASKA JAN 0 8 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOO'Q`OGCC C la. Well Status: ®Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 1b. Well Class 20AAC 25 105 20AAC 25110 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. 12/10/2012 212-152 • 3. Address: 6 Date Spudded: 13. API Number P.O. Box 196612,Anchorage,Alaska 99519-6612 12/4/2012 50-029-20707-03-00 • 4a. Location of Well(Governmental Section): 7 Date T.D. Reached' 14 Well Name and Number: Surface: 12/6/2012 PBU D-19C 1880' FNL, 1692' FEL, Sec.23,T11N, R13E, UM • 8 KB(ft above MSL): 76.42' 15. Field/Pool(s) Top of Productive Horizon: 1649' FNL, 2143' FEL, Sec.23,T11N, R13E, UM GL(ft above MSL): 41.45' Prudhoe Bay/Prudhoe Bay - Total Depth. 9. Plug Back Depth(MD+TVD) 429'FNL,2910' FEL, Sec.23,T11N, R13E, UM 10813' 9019' 4b. Location of Well(State Base Plane Coordinates,NAD: 10 Total Depth(MD+TVD) 16 Property Designation: Surface: x- 653467• y- 5959108 Zone- ASP4 10851' 9019' • ADL 028285 TPI: x- 653011 y- 5959330 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit. Total Depth.x- 652217 y- 5960535 Zone- ASP4 None 18.Directional Survey' Yes 0 No 19.Water depth,if offshore. 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25 050) N/A ft MSL 1900'(Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25 071): 22.Re-Drill/Lateral Top Window MD/TVD: MWD/GR/RES,GR/CCL/MCNL 8810' 8630' 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP 'BOTTOM SIZE CEMENTING RECORD PULLED 20"x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2702' Surface 2702' 17-1/2" 3549 cu ft Permafrost II 9-5/8" 47# L-80 Surface 6231' Surface 6084' 12-1/4" 1177 cu ft Class'G', 130 cu ft PF'C' 7" 26# L-80 6079' 8694' 5943' 8516' 8-1/2" 230 cu ft Class'G' 4-1/2" 12.6# 13Cr80 8528' 8810' 8352' 8630' 6-1/8" 270 cu ft Class'G' 3-1/2"x3-1/4"x2-7/8" 92#/62#/65# L-80 8731' 10851' 8552' 9019' 4-1/4" 138 sx Class'G' 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/ (MD+TVD of Top&Bottom;Perforation Size and Number): TVD) 2"Gun Diameter,6 spf 4-1/2", 12.6#, 13Cr80 8527' 8461'/8285' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 10605'-10805' 9023'-9019' WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No �s i DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED if 2500' Freeze Protect w/50 Bbls of Diesel 1 :171,0 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production Yet N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF. WATER-BBL: CHOKE SIZE: GAS-OIL RATIO' Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF' WATER-BBL: OIL GRAVITY-API(CORR): Press 24-Hour Rate 28 CORE DATA Conventional Core(s)Acquired? 0 Yes ®No . Sidewall Core(s)Acquired? 0 Yes 0 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 RBDAAS JAN 0 91013 6 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit Original Oply "� 29. GEOLOGIC MARKERS(List all formations ar rkers encounter 30. FORMATION TESTS NAME iviD TVD Well Tested? ,J Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. CGL/Zone 3 8973' 8784' None Base of CGL/Zone 2C 9055' 8849' 23SB/Zone 2B 9149' 8916' 22TS 9225' 8963' 21 TS /Zone 2A 9306' 9008' Formation at Total Depth: 21 TS/Zone 2A 9306' 9008' 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. David Johnston,564-5985 Email: David.Johnston@bp.com Printed Name: Jo stuTitle: Drilling Technologist flq� Signature: /� Phone 5644091 Date: , IN 145 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 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071 Form 10-407 Revised 10/2012 Submit Original Only 1 ItL= 6"CNV �ELLHEAD= MCEVOY SAFE. . NOTES:WELL ANGLE>70°@ 9325'. ACTUATOR= BAKER C J MD DRAFT D-1 9C "'4-1/2"CHROME TBG&LNR=*; KB.ELE.V= 76.4' BE ELEV= 42.95' KOP= 4250' Max Angle= 98°@ 9555' ' ' 2128' H4-1/2"HES X NMS,ID=3.813" Datum Mf)= 9092' Datum ND= 8800'SS 13-3/8"CSG,72#, L-80 BTRS,ID=12.347" H 2707 GAS UFC Ma,rJOR�s ST MD 'IVO DEV TYPE VLV LTCH PORT DATE 6 2988 2988 1 MGM DMY RK 0 09/20/01 Minimum ID = 2.377" @ 9655' 5 3729 3729 0 MMGM DOME RK 16 12/20/12 3-1/4" X 2-7/8" XO 4 5270 5199 24 KBG2 SO BK 20 12/20/12 3 6600 6441 5 KBG2 DMY BK 0 09/20/01 2 7635 7470 7 KBG2 DMY BK 0 09/20/01 9-5/8"X 7"BKR ZXP PKR -{ 6079' 1 8373 8198 9 KBG2 DMY BK 0 09/20/01 w/6'TEf3ACK,ID=6.151" / - 9-5/8"X 7"BKR FLEX-LOCK - 6092' LNR HGR,D=6.151" 9-5/8"CSG,47#,L-80,ID=8.681" -6231' 9-5/8"MILLOUT WNDOW(D-19B) 6231'-6247' it" ' r 8440' J-14-1/2"HES X NIP,ID=3.813" S 8461' -17"X 4-112"BKR S-3 PKR, D=3.875" I I 8494' -I 4-1/2"HES X NIP,ID=3.813" I I 8515' -4-1/2"HES XN NIP, MLLED TO 3.80"(12/02/12) 4-1/2"TBG 12.6#,13CR-80, H 852T 0152 bpf,ID=3.958" \i ., 1 8527' -{4-1/2"WLEG,ID=3.958" 7"LNR,26#,L-80,.0383 bpf,ID=6.276" H 8694' 8528' 7"X 4-1/2'BKR ZXPLTP w/6'TIEBACK,ID=4.408" PERFORATION SUMMARY 8541' 7"X 4-112"'BKR HMC LNR REF LOG:BHI MWD RESISTIVITY ON 12/08/12 , HGR 0=4.410" ANGLE AT TOP FERE:93°@ 10605' 8548' --14-112"XO SUB,ID=3.940" Nate:Refer to Production DB for historical perf data 0 SEE SPF KTERVAL SHOT DATE SQZ • 8731' -14-1(2"BKR 45KB LTP,0=???(12/10/12) 2" 6 10605- 10805 0 12/09/12 • 8737' H3.70"DEPLOYMENT SLV,0=3.00" 8758' -13-1/2"HES X NP,10=2.812" 3-1/2"LNR,9.2#,L-80 STL, .0087 bpf,ID=2.992" - 879V i 8791' -13-1/2"X 3-3/16"XO,0=2.786' 4-1/2"BKR KB WHIPSTOCK(12/03/12) H 8810" �� 4-1/2"MLLOUT WINDOW(D-19C) 8810'-8819' 4-1/2'LNR, 12.6#,13CR-80 VAM TOP, - 8810' .0152 bpf,ND=3.958" 9655' H3-3/16"X 2-7/8"XO,D=2.377" RA TAG(DA 1E277) - 8815' 3-1/4"LNR,6.2#,L-80 TCM, .0079 bpi,D=2.850" H 9655' I PBTD -1 10813' I ICM 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,0=2.441" -1 10851' DATE REV BY COMIVENTS DATE REV BY COM VENTS PRUDHOEBAY MIT 05/12/82 ORIGINAL COMPLETION WELL D-19C 06/11/96 PAB SIDETRACK COMPLETION C17'b1ATNo:r2121520 09/20/01 CH/KAK RIG SIDETRACK API No: 50-029-20707-03 12/10/12 NORDIC1 CTD SIDETRACK(I3-19C) SEC 23,T11N,R13E, 1881'FNL&1692'FEL 12/26/12 ?/JMD DRLG DRAFT CORRECTIONS 12/27/12 DLW/JMD GLV GO(12/20/12) BP Exploration(Alaska) EMI BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PBD Pad D-19 - Slot 19 D-19C Survey: MWD Survey Report - Geographic 11 December, 2012 MEI BAKER n„,maaa. HUGHES Survey Report-Geographic :,mmrr,: ''p INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-19-Slot 19 Project: Prudhoe Bay ND Reference: Mean Sea Level Site: PB D Pad MD Reference: D-19B:@ 76.42ft(D-19B:) Well: D-19 North Reference: True Wellbore: D-19C Survey Calculation Method: Minimum Curvature Design: D-19C Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB D Pad,TR-11-13 . Site Position: Northing: 5,955,590.34ft Latitude: 70°17'8.492 N From: Map Easting: 652,165.06ft Longitude: 148°46'6.32 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.16 ° Well D-19 API No 500292070700 Well Position +NI-S 0.00 ft Northing: 5,959,108.00 ft Latitude: 70° 17'42.823 N +E/-W 0.00 ft Easting: 653,467.00 ft Longitude: 148°45'26.30 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 41.50ft Wellbore D-19C API No 500292070703 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2012 12/1/2012 20.65 81.01 57,628 Design D-19C Audit Notes: Version: Phase: ACTUAL Tie On Depth: 8,795.43 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (ft) (ft) (ft) (°) -40.50 0.00 0.00 319.95 Survey Program Date: 12/11/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 97.72 6,197.72 GYRODATA(D-19) GYD-CT-CMS Gyrodata cont.casing m/s 6,231.00 8,795.43 D-19B MWD Sperry(D-19B) MWD MWD-Standard 8,806.00 10,851.00 MWD(D-19C) MWD MWD-Standard 12/11/2012 2:48:41PM Page 2 COMPASS 2003.16 Build 73 BAKER -09pd HUGHES Survey Report-Geographic : by INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-19-Slot 19 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB D Pad MD Reference: D-19B:@ 76.42ft(D-19B:) Well: D-19 North Reference: True Wellbore: D-19C Survey Calculation Method: Minimum Curvature Design: D-19C Database: EDM.16-ANC Prod-WH24P Survey Measured TVD Below Map Map Depth Inclination Azimuth System +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 8,795.43 12.43 342.83 8,539.26 155.32 -696.14 5,959,249.07 652,767.88 70° 17'44.351 N 148°45'46.59 W TIP 8,806.00 12.94 340.09 8,549.57 157.52 -696.88 5,959,251.25 652,767.10 70° 17'44.372 N 148°45'46.61 W KOP 8,844.86 10.71 24.04 8,587.68 164.92 -696.89 5,959,258.65 652,766.94 70° 17'44.445 N 148°45'46.61 W 8,874.86 14.81 56.87 8,616.97 169.57 -692.54 5,959,263.39 652,771.20 70° 17'44.491 N 148°45'46.49 W 8,894.85 16.02 70.28 8,636.25 171.90 -687.80 5,959,265.81 652,775.89 70° 17'44.514 N 148°45'46.35 W 8,926.41 20.55 94.58 8,666.25 172.93 -678.16 5,959,267.04 652,785.50 70°17'44.524 N 148°45'46.07 W 8,956.68 27.80 101.16 8,693.85 171.14 -665.92 5,959,265.50 652,797.77 70°17'44.506 N 148°45'45.71 W 8,986.27 35.99 109.28 8,718.96 166.92 -650.91 5,959,261.59 652,812.86 70°17'44.465 N 148°45'45.27 W 9,015.06 39.72 121.37 8,741.72 159.33 -635.04 5,959,254.32 652,828.88 70°17'44.390 N 148°45'44.81 W 9,050.03 40.10 109.82 8,768.58 149.68 -614.88 5,959,245.08 652,849.24 70°17'44.295 N 148°45'44.22 W 9,076.16 42.89 99.21 8,788.18 145.40 -598.16 5,959,241.14 652,866.04 70°17'44.253 N 148°45'43.73 W 9,105.14 44.74 87.40 8,809.12 144.28 -578.20 5,959,240.43 652,886.01 70°17'44.242 N 148°45'43.15 W 9,135.14 46.61 74.66 8,830.13 147.65 -557.10 5,959,244.23 652,907.05 70°17'44.275 N 148°45'42.54 W 9,165.04 49.59 64.47 8,850.13 155.44 -536.31 5,959,252.45 652,927.66 70°17'44.352 N 148°45'41.93 W 9,195.52 53.24 54.48 8,869.16 167.56 -515.86 5,959,264.98 652,947.86 70°17'44.471 N 148°45'41.34 W 9,225.14 55.79 45.56 8,886.38 183.05 -497.44 5,959,280.85 652,965.97 70°17'44.623 N 148°45'40.80 W 9,256.74 53.00 48.12 8,904.77 200.63 -478.71 5,959,298.80 652,984.33 70°17'44.796 N 148°45'40.25 W 9,291.78 57.89 39.04 8,924.67 221.54 -458.90 5,959,320.11 653,003.70 70°17'45.002 N 148°45'39.68 W 9,316.96 62.50 32.25 8,937.19 239.29 -446.21 5,959,338.12 653,016.03 70° 17'45.177 N 148°45'39.31 W 9,346.57 68.48 26.81 8,949.48 262.73 -432.97 5,959,361.81 653,028.79 70°17'45.407 N 148°45'38.92 W 9,375.46 75.18 19.32 8,958 50 287.96 -422.26 5,959,387.26 653,038.98 70°17'45.655 N 148°45'38.61 W 9,409.04 81.55 9.98 8,965.28 319.73 -413.99 5,959,419.19 653,046.60 70°17'45.968 N 148°45'38.37 W 9,435.20 87.20 1.84 8,967.85 345.60 -411.32 5,959,445.10 653,048.74 70°17'46.222 N 148°45'38.29 W 9,465.22 92.18 351.99 8,968.01 375.53 -412.93 5,959,474.99 653,046.52 70°17'46.516 N 148°45'38.34 W 9,495.34 97.64 343.72 8,965.43 404.83 -419.23 5,959,504.16 653,039.62 70°17'46.805 N 148°45'38.52 W 9,525.25 96.19 334.70 8,961.82 432.56 -429.76 5,959,531.66 653,028.53 70°17'47.077 N 148°45'38.83 W 9,555.03 97.50 325.55 8,958.26 458.17 -444.47 5,959,556.97 653,013.30 70°17'47.329 N 148°45'39.26 W 9,584.98 95.72 318.22 8,954.81 481.56 -462.82 5,959,579.97 652,994.48 70°17'47.559 N 148°45'39.79 W 9,617.07 90.86 308.69 8,952.97 503.55 -486.05 5,959,601.49 652,970.81 70° 17'47.776 N 148°45'40.47 W 9,645.42 90.28 300.78 8,952.68 519.69 -509.33 5,959,617.15 652,947.21 70° 17'47.934 N 148°45'41.15 W 9,675.22 91.35 292.21 8,952.26 532.97 -535.97 5,959,629.88 652,920.30 70°17'48.065 N 148°45'41.92 W' 9,710.00 97.15 295.39 8,949.68 546.96 -567.69 5,959,643.22 652,888.31 70°17'48.202 N 148°45'42.85 W 9,738.24 88.25 303.18 8,948.35 560.74 -592.24 5,959,656.49 652,863.48 70° 17'48.338 N 148°45'43.56 W 9,766.72 90.40 311.72 8,948.69 578.04 -614.83 5,959,673.33 652,840.54 70°17'48.508 N 148°45'44.22 W 9,799.67 90.52 315.67 8,948.42 600.80 -638.65 5,959,695.59 652,816.27 70°17'48.732 N 148°45'44.92 W 9,828.44 91.72 319.45 8,947.86 622.02 -658.05 5,959,716.41 652,796.43 70°17'48.941 N 148°45'45.48 W 9,864.16 91.11 323.99 8,946.98 650.04 -680.17 5,959,743.98 652,773.75 70°17'49.216 N 148°45'46.13 W 9,896.80 90.74 327.68 8,946.45 677.04 -698.49 5,959,770.59 652,754.88 70°17'49.482 N 148°45'46.66 W' 9,935.63 89.35 331.98 8,946.42 710.60 -718.00 5,959,803.75 652,734.69 70° 17'49.812 N 148°45'47.23 W 9,966.93 90.74 335.94 8,946.39 738.72 -731.74 5,959,831.57 652,720.38 70°17'50.088 N 148°45'47.63 W 10,003.63 91.60 340.14 8,945.64 772.74 -745.46 5,959,865.31 652,705.97 70° 17'50.423 N 148°45'48.03 W 10,035.19 89.66 340.94 8,945.30 802.50 -755.97 5,959,894.84 652,694.86 70° 17'50.715 N 148°45'48.34 W 10,063.70 88.31 338.52 8,945.80 829.23 -765.85 5,959,921.37 652,684.44 70°17'50.978 N 148°45'48.62 W 10,102.75 88.07 334.51 8,947.04 865.02 -781.40 5,959,956.83 652,668.16 70° 17'51.330 N 148°45'49.08 W 10,132.30 86.37 330.76 8,948.47 891.23 -794.96 5,959,982.75 652,654.07 70° 17'51.588 N 148°45'49.47 W 10,156.79 86.31 328.65 8,950.03 912.33 -807.29 5,960,003.60 652,641.31 70° 17'51.796 N 148°45'49.83 W 10,188.64 86.96 324.56 8,951.90 938.87 -824.79 5,960,029.77 652,623.28 70°17'52.057 N 148°45'50.34 W 10,216.68 88.25 323.17 8,953.08 961.50 -841.31 5,960,052.05 652,606.30 70°17'52.279 N 148°45'50.82 W 10,246.86 88.43 322.20 8,953.95 985.49 -859.59 5,960,075.66 652,587.53 70°17'52.515 N 148°45'51.36 W 10,276.99 90.43 320.46 8,954.25 1,009.01 -878.42 5,960,098.79 652,568.23 70° 17'52.746 N 148°45'51.91 W 10,307.12 92.40 318.24 8,953.51 1,031.86 -898.04 5,960,121.24 652,548.15 70° 17'52.971 N 148°45'52.48 W 10,337.04 94.79 316.32 8,951.63 1,053.80 -918.29 5,960,142.75 652,527.45 70°17'53.187 N 148°45'53.07 W 10,367.96 89.82 313.87 8,950.39 1,075.67 -940.09 5,960,164.17 652,505.21 70°17'53.402 N 148°45'53.70 W 12/11/2012 2:48:41PM Page 3 COMPASS 2003.16 Build 73 /$1 oa BAKER HUGHES Survey Report-Geographic ` :.'p INTEQ "tea«o*' Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-19-Slot 19 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB D Pad MD Reference: D-19B:@ 76.42ft(D-19B:) Well: D-19 North Reference: True Wellbore: D-19C Survey Calculation Method: Minimum Curvature Design: D-19C Database: EDM.16-ANC Prod-WH24P Survey Measured ND Below Map Map Depth Inclination Azimuth System +N/-S +E/-W Northing Easting (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 10,396.83 86.26 310.05 8,951.37 1,094.96 -961.54 5,960,183.02 652,483.37 70° 17'53.591 N 148°45'54.33 W 10,426.68 89.17 308.82 8,952.56 1,113.90 -984.57 5,960,201.48 652,459.96 70° 17'53.778 N 148°45'55.00 W 10,456.66 89.42 306.12 8,952.93 1,132.13 -1,008.36 5,960,219.23 652,435.80 70° 17'53.957 N 148°45'55.69 W 10,486.61 92.86 306.90 8,952.34 1,149.95 -1,032.43 5,960,236.55 652,411.38 70° 17'54.132 N 148°45'56.40 W 10,509.72 94.37 309.88 8,950.88 1,164.27 -1,050.50 5,960,250.49 652,393.02 70° 17'54.273 N 148°45'56.92 W 10,537.72 91.41 313.31 8,949.47 1,182.83 -1,071.41 5,960,268.62 652,371.74 70°17'54.456 N 148°45'57.53 W 10,566.75 91.69 316.70 8,948.68 1,203.35 -1,091.93 5,960,288.71 652,350.81 70°17'54.657 N 148°45'58.13 W. 10,599.04 93.44 320.29 8,947.24 1,227.50 -1,113.30 5,960,312.42 652,328.95 70°17'54.895 N 148°45'58.75 W 10,626.80 91.63 323.40 8,946.01 1,249.30 -1,130.43 5,960,333.87 652,311.38 70°17'55.109 N 148°45'59.25 W 10,656.58 91.78 326.28 8,945.12 1,273.64 -1,147.57 5,960,357.85 652,293.75 70°17'55.349 N 148°45'59.75 W 10,686.46 91.35 326.46 8,944.31 1,298.51 -1,164.11 5,960,382.37 652,276.71 70°17'55.593 N 148°46'0.24 W 10,716.52 90.52 333.01 8,943.82 1,324.45 -1,179.25 5,960,408.00 652,261.04 70°17'55.848 N 148°46'0.68 W 10,746.77 90.46 337.15 8,943.56 1,351.88 -1,191.99 5,960,435.16 652,247.74 70° 17'56.118 N 148°46'1.05 W 10,776.74 90.74 341.07 8,943.24 1,379.87 -1,202.68 5,960,462.93 652,236.49 70°17'56.393 N 148°46'1.36 W 10,799.22 90.43 344.13 8,943.01 1,401.32 -1,209.40 5,960,484.23 652,229.33 70° 17'56.604 N 148°46'1.56 W 10,851.00 89.50 351.00 8,943.04 1,451.85 -1,220.54 5,960,534.53 652,217.16 70°17'57.101 N 148°46'1.88 W TD-2 7/8" 12/11/2012 2:48:41PM Page 4 COMPASS 2003.16 Build 73 „ , ....,. North America-ALASKA-BP Page 1 of 11 Operation Summary Report Common Well Name: D-19 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 12/1/2012 End Date: X3-012WL-C.DRILL(2,273,392.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 1 Spud Date/Time:4/24/1982 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/1/2012 10:00 - 11:30 1.50 MOB P PRE RIG DOWN. PREPAIR TO MOVE.ARRANGE SECURITY FOR ESCORT. 11:30 - 15:15 3.75 MOB P PRE MOVE RIG FROM E PAD TO D PAD. 15:15 - 18:00 2.75 1 MOB P PRE WELLS GROUP REMOVING TAPPED FLANGE ON BLOCK"T”ON TREE AND REPLACE BLIND FLANGE. LINE UP RIG WITH WELL. PJSM. BACK RIG OVER WELL AND SET DOWN. 18:00 - 19:00 1.00 MOB P PRE RIG MOVED OVER WELL AND READY TO TAKE ON FLUIDS AND NU BOP.ACCEPT RIG AT 18.00HRS PACK SNOW AROUND CELLAR,SPOT SAT OFFICE AND OUTSIDE EQUIPMENT. RIG UP CELLAR EQUIPMENT(I.E.CAGES AND DRIP PANS). 19:00 - 19:30 0.50 RIGU P PRE RU AND ESTABLISH WELL BARRIERS. INSTALL PRESSURE-GAUGE TO MONITOR PRESSURE IN TREE CAVITY. 19:30 - 22:00 2.50 RIGU P PRE NIPPLE DOWN TREE CAP AND NIPPLE UP BOP. INSTALL HOT TUB AND GRATINGS. CONFIRM TREE BOLTS ARE MARKED. 22:00 - 00:00 2.00 RIGU P PRE COMMENCE GREASING CHOKE AND ALL :VALVES ON RIGFLOOR, IN SHAKER ROOM, REEL HOUSE AND PIPESHED. SUCCESSFULLY MAG-TEST CABLE. 12/2/2012 00:00 - 00:30 0.50 RIGU P PRE FINISH GREASING. 00:30 - 01:30 1.00 RIGU P PRE RIG UP TT AND PRESSURE-TEST HARDLINE. INSTALL STAIRS TO RIG AND SPOT EQUIPMENT AROUND RIG. 01:30 - 02:45 1.25 RIGU P PRE FLUID PACK STACK AND MGS.DRAIN MGS. 02:45 - 03:10 0.42 RIGU P PRE CONDUCT RIG EVACUATION DRILL. HOLD AAR:GOOD RESPONSE BY CREWS, BUT IT WAS MENTIONED THAT THE AUDIBLE ALARM WAS NOT WELL HEARD INSIDE THE OPS CAB. 03:10 - 03:30 0.33 RIGU P PRE HOLD PRE-SPUD MEETING WITH ALL — — CREWS. 03:30 - 04:30 1.00 BOPSUR P PRE PERFORM FULL BODY SHELL TEST TO 250PSI LOW AND 4,500PSI HIGH.ACHIEVE GOOD TEST. PERFORM ACCUMULATOR DRAWDOWN TEST. -STARTING ACCUMULATOR PRESSURE= 3,000 PSI -FINAL PRESSURE AFTER FUNCTIONING ALL PREVENTERS AND HCR=2,100 PSI -10 SEC TO BUILD 200 PSI,99 SEC TO FULL PRESSURE. -3 NITROGEN BACKUP BOTTLES WITH 2,000 PSI. Printed 12/26/2012 10:48:38AM ,. ,- North America -ALASKA- BP i Page 2 of 11 r Operation Summary Report Common Well Name: D-19 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 12/1/2012 1 End Date: X3-012WL-C:DRILL(2,273,392.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time:4/24/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum: D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 11:45 7.25 BOPSUR P PRE CONDUCT BOPE PRESSURE AND FUNCTION-TEST PER NORDIC PROCEDURE AOGCC REGS&DWOP POLICY.INSTALL 2-3/8 X 3-1/2"TEST JOINT AND PERFORM n PRESSURE-TEST TO 250PS1/5MINS AND 3,500PSI/5MIN ON FOLLOWING ITEMS: -ANNULAR BAG #1 RAM-BLIND SHEARS -#2 RAM-2-3/8"COMBIS(2-3/8"TEST JOINT) -#3 RAM-2-3/8"x 3-1/2"VBR(2-3/8"TEST JOINT) -#4 RAM-2-3/8"COMBIS(2-3/8"TEST JOINT) 'ALL RAMS CLOSED WITHIN LESS THAN SECONDS.ALSO TESTED HCR AND ALL VALVES ON KILL AND CHOKE LINE AS WELL AS KILL AND CHOKE MANIFOLDS. SUCCESSFULLY TESTED ALL VISUAL AND AUDIBLE GAS ALARMS.SEE ATTACHED CHARTS. FUNCTION ALL RAMS FROM OPS CAB AND -DRILLER'S STATION -WITNESS OF THE BOP TEST WAS WAIVED BY JOHN CRISP(AOGCC),BUT WITNESSED BY BP WSL&NORDIC TOOLPUSHER. 11:45 - 14:00 2.25 BOPSUR P PRE PUMP 40 BBL FRESH WATER INTO COIL FOR SLACK MANAGEMENT. STAB INJECTOR ON WELL. PUMP E-LINE SLACK BACK. TEST INNER REEL VALVE 250 PSI LOW AND 3500 PSI HIGH. SLOW LEAK IN VALVE.CHANGE VALVE AND RE TEST. 14:00 - 15:00 1.00 BOPSUR P PRE DISCONNECT INJECTOR FROM WELL. CUT 310'OF COIL. END OF E-LINE NOT FOUND. STAB INJECTOR ONTO WELL. PUMP FORWARD TO LOCATE E-LINE END. MAKE UP SLB COIL CONNECTOR PULL TEST TO 35K AND PRESURE TEST TO 4000 PSI TEST PACK OFF TO 4000 PSL 15:00 - 17:15 2.25 BOPSUR P PRE MAKE UP BAKER UPPER QUICK CONNECT _ WITH DFCV. CONNECT INJECTOR TO LUBRICATOR. PUMP 60 BBL AT 3 GPM WITH 1241 PSI TO PUMP E-LINE FORWARD. TEST BAKER CHECK VALVES. DID NOT HOLD. REMOVE INJECTOR. CHANGE BOTH BPVS. RE TEST BAKER DFCV. REMOVE INJECTOR FROM WELL AND STAND BACK.CIRCULATE AT MINIMUM RATE. INSTALL NIGHT CAP ON LUBRICATOR. PRESSURE TEST LUBRICATOR AND NIGHT CAP TO 250 PSI LOW AND 3500 PSI HIGH. 17:15 - 17:45 0.50 BOPSUR P PRE RIG EVACUATION DRILL. CREW AND ALL THIRD PARY PERSONEL RESPOND. AAR CARRIED OUT.GOOD DRILL. Printed 12/26/2012 10:48:38AM North America-ALASKA- BP • Page 3 of 11 ,r=M Operation Summary Report Common Well Name: D-19 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 12/1/2012 End Date: X3-012WL-C:DRILL(2,273,392.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time:4/24/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:45 - 18:15 0.50 BOPSUR P PRE OPEN UP WELL-OPEN UP TREE VALVES, SEE NO PRESSURE.OPEN UP CHOKE, OBSERVE NOW FLOW(OPSI WHP). 18:15 - 18:45 0.50 BOPSUR P PRE FLOWCHECK WELL FOR 30MINS. 18:45 - 19:45 1.00 STWHIP P WEXIT HOLD PJSM BEFORE MU MILLING-BHA (BHA#1). 19:45 - 20:20 0.58 STWHIP P WEXIT MU BHA#1 WITH 2-7/8"EXTREME MUD MOTOR AND 3.80"WINDOW MILL(3.80" NO-GO/3.81"GO)AND STRING REAMER (3.79"NO-GO/3.80"GO). 20:20 - 20:45 0.42 STWHIP P WEXIT STAB ON INJECTOR AND PRESSURE-TEST QTS TO 300PSV5MINS AND 3,500PS1/5MINS. 20:45 - 22:30 1.75 STWHIP P WEXIT RIH AT 88FT/MIN WITH WINDOW MILLING BHA 'PUMPING KCL OFF THE TRUCK. MM-IN:0.38BPM/MM-OUT:0.89BPM, MM-IN: 8.28BPM/MM-OUT:7.14PPG (FREEZE-PROTECT FROM WELL). 22:30 - 23:10 0.67 STWHIP • P WEXIT SLOW DOWN TO 100FT/HR AND COMMENCE LOGGING FOR TIE-IN PASS ONWARDS FROM 8,730'. MM-IN:0.95BPM/MM-OUT:0.97BPM, MM-IN: 8.28BPM/MM-OUT:7.62PPG-RETURNS -TAKES LONG TO CLEAR UP. 23:10 - 23:15 0.08 STWHIP P WEXIT LOG DOWN TO 8,780'.STOP AND APPLY+1 FT CORRECTION. CONTINUE RIH SLOWLY. 23:15 - 23:45 0.50 STWHIP P WEXIT TAG TOP OF WHIPSTOCK AT 8,811'. PU TO 8786,OPEN EDC AND LINE UP TO 8.5PPG DRILL MUD. PVT=297BBLS, MM-IN:2.73BPM/MM-OUT: 2.74BPM, MM-IN: 8.48BPM(MUD)/MM-OUT: 8.37PPG(KCL). 23:45 - 00:00 0.25 STWHIP P WEXIT DRILL MUD AT THE MILL.TAKE SLOW PUMP RATES. 12/3/2012 00:00 - 00:15 0.25 STWHIP P WEXIT DRY-TAG TOP OF WHIPSTOCK AT 8,810.6'.PU AND BRING PUMPS ONLINE. RUN BACK IN TO 8,807'AND START TIME-MILLING AT 1'/HR ONWARDS FROM 8,809'.FREE SPIN: 1,963PSI AT 2.7BPM / WOB:0.40K LBS. 00:15 - 00:50 0.58 STWHIP P WEXIT AT 8,810'FIND PINCH POINT/TOP OF WHIPSTOCK. OBSERVE AN INCREASE IN MOTORWORK OF -250PS1. CIRC PRESSURE 2,219PS1 / WOB:0.21K LBS / PUMPRATE:2.7BPM. 00:50 - 01:00 0.17 STWHIP P WEXIT NOTICE INCREASE IN CIRC-PRESSURE UP TO-2,500PSI(DRILL MUD NOW ALL THE WAY i b ROUND),HOWEVER MOTORWORK DOES NOT SEEM TO CHANGE BUT REMAINS AT 300PSI. PU,TAKE NEW FREESPIN:2,520PS1 AT 2.70BPM. 01:00 - 03:00 2.00 STWHIP P WEXIT RESTART TIME-MILLING AND SLOWLY RIH. CIRC PRESSURE:2,540PS1 / WOB:0.6K LBS / PUMPRATE:2.7BPM. /(1.A;itira Printed 12/26/2012 10:48:38AM North America -ALASKA- BP Page 4 .fl Operation Summary Report A�'3.','�"W r»'4.""J�dna l-a+Y3+•46 Y' i%:wei5wm"d5ixF av r'6.� ° .,"'�"rts�^. Common Well Name: D-19 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 12/1/2012 End Date: X3-012WL-C:DRILL(2,273,392.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.:NORDIC 1 Spud Date/Time:4/24/1982 12.00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:D-19B: @76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 18:00 15.00 STWHIP P WEXIT NOTICE 1ST STALL.PU UP AND CONTINUE MILLING OPS. CIRC PRESSURE:2,600-2,900 PSI / WOB:3- 4K LBS / PUMPRATE:2.7 BPM. MILLING-PROGRESS IS FAIRLY SLOW.HAVE TO STOP 6 MIN/10TH FOOT TIME-MILLING INTERVALS TO ALLOW MILL TO DRILL OFF. -CONTINUE MILLING. AT 8814.9'MILLING PROGRESS SLOWS TO 10 MIN/10TH FOOT.INCREASED WOB TO 4120-4260 AT 8816.8'MILLING PROGRESS INCREASED TO 6-8 MIN/10TH FOOT.WOB 4260 AT 8818.3"MILLING PROGRESS SLOWED TO A STOP AND THE MOTOR STALLED. PICK UP OFF BOTTOM TO 8810'.SLOWLY WORK MILL BACK DOWN. PUMP AT 2.9 GPM WITH 2501 PSI FREE SPIN. SLOWLY TAG UP ON BOTTOM RESUME MILLING AT 3 GBM WITH 2840 PSI 4150 WEIGHT ON BIT. MILL TO BOTTOM OF WHIPSTOCK TRAY. TOP OF WINDOW AT 8810'BOTTOM OF .WINDOW AT 8819' MILL PENETRATE OPEN HOLE AT 8819'.MILL AT 2.9 GPM WITH 2780 PSI 2800 WOB MILL RAT HOLE.FIRST SAMPLE CAUGHT AT 8819.6'SHOWED 35%FORMATION 18:00 - 21:50 3.83 STWHIP P WEXIT COMPLETE MILLING RATHOLE TO 8,829'. 21:50 - 23:30 1.67 STWHIP P WEXIT PICK UP AND PERFORM 3 UP/3 DOWN REAMING PASSES BETWEEN 8,829'TO 8,807'. SEE A LITTLE MOTORWORK INITIALLY, BUT NOT THEREAFTER.WINDOW IS CLEAN. 23:30 - 23:45 0.25 STWHIP P WEXIT PERFORM DRY DRIFT,NO ISSUES. 23:45 - 00:00 0.25 STWHIP P WEXIT FLOWCHECK WELL FOR 5MINS,ACHIEVE GOOD NO FLOW. 12/4/2012 00:00 - 01:30 1.50 STWHIP P WEXIT POOH WITH BHA#1TO SURFACE. 01:30 - 01:40 0.17 STWHIP P WEXIT "JOG"BACK IN HOLE TO 200FT AND FLOWCHECK WELL.OBTAIN GOOD NO FLOW. 01:40 - 02:20 0.67 STWHIP P WEXIT LD BHA#1. MILL GRADED AT 3.8"GO AND 3.79"NO GO. STRING MILL 3.79"GO AND 3.77"NO GO 02:20 - 02:45 0.42 DRILL P PROD1 MU BHA#2. 02:45 - 03:20 0.58 DRILL P PROD1 STAB ON INJECTOR AND PRESSURE-TETS QTS TO 300PSI/5MINS AND 3,500PSI/5MINS. 03:20 - 05:00 1.67 DRILL P PROD1 COMMENCE RIH. PVT=260BBLS. 05:00 - 06:15 1.25 DRILL P PROD1 RUN PRIMARY TIE-IN LOG FROM 8,680'AND 8,811'AT 10OFT/HR.CLOSE EDC 06:15 - 06:30 0.25 DRILL P PROD1 RIH.TAG BOTTOM AT 8826'. RECORD SLOW PUMP RATES. Printed 12/26/2012 10:48:38AM North America -ALASKA- BP • • Page 5 of 11 Operation Summary Report Common Well Name. D-19 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 12/1/2012 End Date: X3-012WL-C:DRILL(2,273,392.00) Project: Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time:4/24/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 09:15 2.75 DRILL P PROD1 DRILL AHEAD IN ZONE 4.TO 8850' ROP=15 FPH,WOB=.16-.17 K LBS,CIRC • PRESSURE=3018 PSI AT 3.25 BPM. MM IN=3.25 BPM / MM OUT=3.01 BPM MW IN=8.6 PPG / MW OUT=8.59 PPG / ECD=10.1 PPG PVT=300 BBL, LOSSES 0. IA=2 PSI / OA=12 PSI RA TAG AT 8815' 09:15 - 10:30 1.25 DRILL P PROD1 DRILL AHEAD IN ZONE 4.TO 8870' ROP=11 FPH,WOB=.7-.9 K LBS,CIRC PRESSURE=2596 PSI AT 2.73 BPM. MM IN=2.72 BPM / MM OUT=2.55 BPM MW IN=8.58 PPG / MW OUT=8.59 PPG / ECD=9.95 PPG PVT=298 BBL, LOSSES 0. IA=2 PSI / OA=16 PSI 10:30 - 15:00 4.50 DRILL P PROD1 DRILL AHEAD IN ZONE 4. ROP=31 FPH,WOB=1.5 K LBS,CIRC PRESSURE=2611 PSI AT 2.82 BPM. MM IN=2.82 BPM / MM OUT=2.57 BPM MW IN=8.59 PPG / MW OUT=8.58 PPG / ECD=9.97 PPG PVT=306 BBL, LOSSES 0. START CENTRIFUGE,A LITTLE AIR IN THE MUD. IA=2 PSI / OA=17 PSI 15:00 - 18:00 3.00 DRILL P PROD1 DRILL AHEAD IN ZONE 4/3 SLOW RATTY DRILLING EASY TO STALL ROP=23 FPH,WOB=1.65 K,CIRC PRESSURE =2761 PSI AT 2.63 BPM. MM IN=64 BPM / MM OUT=2.61 BPM MW IN=8.61 PPG / MW OUT=8.61 PPG / ECD= 10.02 PPG PVT=301 BBL,IA=4 PSI / OA=20 PSI 18:00 - 20:30 2.50 DRILL P PROD1 DRILL AHEAD IN ZONE 3.DRILL PROCESS IS SLOW,BUT STEADY. ROP=20-30 FPH,WOB=3.0 K,CIRC PRESSURE=3,010 PSI AT 2.8 BPM MM IN=2.9 BPM / MM OUT=2.9 BPM(NO LOSSES) ECD=10.09 PPG,PVT=331 BBLS, IA=5 PSI / OA=21 PSI _RECORD SLOW PUMP RATES.BOTH PUMPS. 20:30 - 21:20 0.83 DRILL P PROD1 DRILL AHEAD,SEE IMPROVEMENT IN ROP TO 50-60FT/HR WHEN DRILLING SAND. PVT=329 BBLS, NO LOSSES. 21:20 - 21:40 0.33 DRILL P PROD1 AT 9,073'HIT LOSS ZONE(FAULT?).SEE IMMEDIATELY 100%LOSSES.PICK UP TO CHECK PUW AND NOTICE SLIGHTLY HIGHER PUW THAN EXPECTED(40K LBS INSTEAD OF 32K LBS).PERFORM A WIPERTRIP TO WINDOW. 21:40 - 22:00 0.33 DRILL P PROD1 RUN BACK IN HOLE AFTER WIPER TO WINDOW. MM IN=2.86 BPM / MM OUT=0.56 BPM / LOSSES=2.3 BPM / PVT=292 BBLS Printed 12/26/2012 10:48:38AM North America -ALASKA- BP • Page 6 of,, Operation Summary Report , Common Well Name: D-19 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 12/1/2012 End Date: X3-012WL-C:DRILL(2,273,392.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time:4/24/1982 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:D-19B:©76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) (ft) _ 22:00 - 22:20 0.33 DRILL P PROD1 DRILL AHEAD WITH LOSSES AT 40-60FT/HR. CIRC PRESSURE=2,800-3,000 PSI AT 2.7 BPM. MM IN=2.96 BPM / MM OUT=1.85 BPM / LOSSES=1.11 BPM ECD=9.89 PPG,PVT=262 BBLS,IA=4 PSI / OA=24 PSI 22:20 - 22:40 0.33 DRILL P PROD1 DRILL TO 9,101'WITHOUT INDICATION THAT LOSSES ARE GETTING ANY BETTER.TO COMPLY WITH 300 BBLS-RULE(STILL HAVE >300 BBLS KWF INCLD RIG WATER),DECIDE TO PULL INTO WINDOW UNTIL NEW MUD ARRIVES ON LOCATION. 22:40 - 00:00 1.33 DRILL N DPRB 9,101.00 PROD1 PULL BACK IN WINDOW AND CIRC AT MINIMUM RATE JUST TO KEEP THE HOLE FULL, MM IN=1.0 BPM / MM OUT=0.1 BPM WAIT FOR FLUID TRUCKS TO ARRIVE. 12/5/2012 00:00 - 03:15 3.25 DRILL N DPRB 9,101.00 PROD1 CONTINUE WAITING FOR FLUID TRUCKS TO ARRIVE ON LOCATION. MM IN=1.0 BPM / MM OUT=0.31 BPM ******CONDUCT COMPLEX KICK WHILE DRILLING DRILL""" FOR THIS DRILL, DRILLER CALLED VIA THE RADIO THAT HE HAD DISCOVERED A LEAK AT THE KOOMEY UNIT.CORRECTLY MOTORMAN AND CREWS MUSTERED AT THE KOOMEY WITHIN 1 MINUTE. THE WSL THEN PROCEEDED BY GIVING THE MOTORMAN DIFFERENT LEAK-LOCATION ON THE KOOMEY AND HOW HE WOULD ISOLATE AND CONTROL THE LEAK.THEREAFTER,THE WSL DISCUSSED THE RISK OF HYDRAULIC FLUID DRIPPING FROM LEVEL 2 DOWN INTO THE MOTOR ROOM ON LEVEL 1. OBVIOUS MAIN RISK IS THAT HYDRAULIC OIL COULD DRIP ON A HOT SURFACE AND THUS IGNITE. WSL CONCLUDED THE DRILL AND THANKED CREW FOR THEIR GOOD RESPONSE. 03:15 - 03:30 0.25 DRILL N DPRB 9,101.00 PROD1 TRUCK ARRIVE ON LOCATION,LOAD MUD INTO PITS. • MM IN= 1.0 BPM / MM OUT=0.44 BPM RUN BACK TO WINDOW,CLOSE EDC AND CONTINUE RUNNING BACK TO BOTTOM. INREASE PUMPRATE AND SEE MM IN=2.82 BPM / MM OUT=2.10 BPM 03:30 - 05:15 1.75 DRILL P PROD1 DRILL AHEAD IN ZONE 2.CLEAN SAND FROM 8975'. STILL WITH LOSSES:MM IN=2.9 BPM / MM OUT=2.15 BPM / LOSSES=0.75 BPM ROP=51 FPH,WOB=1.81 K LBS,CIRC PRESSURE=2,864 PSI AT 2.85 BPM, FREESPIN=2,750 PSI MW IN=8.57 PPG / MW OUT=8.64 PPG / ECD=9.88 PPG 05:15 - 07:20 2.08 DRILL P PROD1 DRILLING AHEAD WITH LOSSES OF RANGING BETWEEN 0.4-0.6BPM. GR CONTINUES TO INDICATE GOOD SANDS (30DEG API), ROP=6OFT/HR. 07:20 - 07:40 0.33 DRILL P PROD1 WIPER TO WINDOW AND TIE IN Printed 12/26/2012 10:48:38AM North America -ALASKA- BP Page 7 of 11 Operation Summary Report Common Well Name: D-19 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 12/1/2012 End Date: X3-012WL-C:DRILL(2,273,392.00) Project: Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time:4/24/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum: D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:40 - 07:45 0.08 DRILL P PROD1 TIE IN 07:45 - 08:05 0.33 DRILL P PROD1 CORRECT DEPTH+8'AND RIH 08:05 - 09:30 1.42 DRILL P PROD1 BACK ON BOTTOM DRILLING OBTAIN SLOW PUMP RATES LOAD PITS WITH-100 BBLS OF MUD 09:30 - 10:15 0.75 DRILL P PROD1 PU OFF BOTTOM TO PUMP UP GEO SAMPLES `LOOKING FOR HOT 10:15 - 10:25 0.17 DRILL P PROD1 WE ARE-20'DEEP IN THE MHO,SAMPLE FROM 8950'(TVD)HAS MHO.CURRENTLY WE ARE-20'DEEP IN AT 86°.PROJECTED LANDING OF THE BUILD IS-100 DEEPER AT 9750'. DISCUSS WITH ODE TO ENSURE THE ASSET IS OK GIVING UP-100'IN THE BUILD. ODE SAYS WE ARE OK TO CONTINUE DRILLING AHEAD 10:25 - 11:00 0.58 DRILL P PROD1 DRILL AHEAD IN ZONE 2 FREE SPIN AT 2.82 BPM=2747 PSI ROP=90 FPH,WOB=2.60 K,CIRC PRESSURE =2996 PSI MM IN=2.83 BPM / MM OUT=2.61 BPM LOSS RATE=0.22 BPM OR 13.2 BPH MW IN=8.63 PPG / MW OUT=8.61 PPG / , ECD=9.93 PPG PVT=308 BBL,IA=1 PSI / OA=20 PSI 11:00 - 11:40 0.67 DRILL P PROD1 DRILL AHEAD IN ZONE 2 FREE SPIN AT 2.82 BPM=2747 PSI ROP=80 FPH,WOB=2.61 K,CIRC PRESSURE =3076 PSI MM IN=2.83 BPM / MM OUT=2.64 BPM LOSS RATE=0.19 BPM OR 11.4 BPH MW IN=8.63 PPG / MW OUT=8.64 PPG / ECD=10.02 PPG PVT=301 BBL, IA=2 PSI / OA= 18 PSI 11:40 - 13:00 1.33 DRILL P PROD1 BHA WIPER TO CHECK PARAMETERS LOOKS GGOD CONTINUE DRILLING AHEAD 13:00 - 14:10 1.17 DRILL P PROD1 CONTINUE DRILLING AHEAD LOSSES ARE STABLE AT 0.2 BPM 14:10 - 14:50 0.67 DRILL P PROD1 CONTINUE DRILLING AHEAD ROP=75 FPH,WOB=1.5 K,CIRC PRESSURE =2831 PSI LOSS RATE=0.19 BPM OR 11.4 BPH ECD= 10.02 PPG IA=2 PSI / OA=20 PSI 14:50 - 15:50 1.00 DRILL P PROD1 CONTINUE DRILLING AHEAD ROP=60 FPH,WOB=2.8 K,CIRC PRESSURE =3036 PSI LOSS RATE=0.21 BPM OR 12.6 BPH ECD= 10.00 PPG IA=2 PSI / OA=22 PSI 15:50 - 16:05 0.25 DRILL P PROD1 BUILD LANDED AT 9,760'. PICK UP TO 9,650'TO CLEAR THE OH OF CUTTINGS THEN RIH TO FLOW CHECK WELL TO POOH 16:05 - 16:10 0.08 DRILL P PROD1 FLOW CHECK WELL 16:10 - 16:45 0.58 DRILL P PROD1 GOOD NO FLOW,POOH FOR LATERAL BHA 16:45 16:55 0.17 DRILL P 1 PROD1 8825'JOG BACK IN HOLE 100' 16:55 - 17:00 0.08 DRILL P PROD1 FLOW CHECK AT 8,788'. 17:00 - 18:45 1.75 DRILL P PROD1 POOH Printed 12/26/2012 10:48:38AM North America ALASKA BP Page . • Operation Summary Report Common Wet Name: D-19 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 12/1/2012 End Date. X3-012WL-C:DRILL(2,273,392.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 1 Spud Date/Time.4/24/1982 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:45 - 19:00 0.25 DRILL P PROD1 FLOW CHECK WELL 19:00 - 19:30 0.50 DRILL P PROD1 GOOD NO FLOW, LD BHA#2. GRADE BIT AS 4-2-BT-A-X-I-ER-BHA 19:30 - 20:30 1.00 DRILL P PROD1 FILL HOLE,TAKES-2.5 BBLS. SERVICE GOOSE NECK.CHANGE TOP ROLLER. 20:30 - 21:10 0.67 DRILL P PROD1 MAKE UP BHA#3 WITH 4-1/4"HYCALOG HELIOS BIT AND 3 1/8"ULTRA LOW SPEED MOTOR SET AT 1.52 DEG 21:10 - 21:30 0.33 DRILL P PROD1 STAB ON INJECTOR AND PRESSURE TEST QTS TO 300 PSI AND 3500 PSI BOTH TESTS 5 MINUTES. 21:30 - 23:00 1.50 DRILL P PROD1 RIH WITH BHA#3 23:00 - 23:45 0.75 DRILL P PROD1 RIH TO 8,793'AND CLOSE EDC. COMMENCE LOGGING FOR TIE-IN AND APPLY-2FT DEPTH CORRECTION. 23:45 - 00.00 0.25 DRILL P PROD1 PU TO 8,500'AND CONDUCT CCL-LOGGING OPERATIONS. *****CONDUCTED KICK WHILE DRILLING DRILL***** DRILLER CONDUCTED A KICK WHILE -DRILLING DRILL.CREW RESPONDED IMMEDIATELY AND CORRECTLY. 12/6/2012 00:00 - 00:20 0.33 DRILL P PROD1 RUN CCL LOG FROM 8500'TO 8800' 00:20 - 00:45 0.42 DRILL P PROD1 RIH TO BOTTOM 00:45 - 02:15 1.50 DRILL P PROD1 TAKE WEIGHT AT 9410'SECOND CROSSING OF FIRST FAULT(LOST ZONE).WORK COIL UP AFTER SEEING TIGHT HOLE.RIH TO 9550' AND POH TO 9400'TO REAM SECTION. REPEAT REAM SECTION TWICE. MANAGE TO GET ALL THE WAY DOWN TO BOTTOM WITHOUT ANY FURTHER ISSUES. 02:15 - 04:20 2.08 DRILL P PROD1 PERFROM MAD-PASS LOGGING FROM BOTTOM TO WINDOW.WHILE LOGGING, NOTICED: - A FEW-10K LBS OVERPULLS BETWEEN 9,400'-9.600' - AND A NEAR STALL(PRESSURE-SPIKE)AT 9,550'(WHILE PUMPING AT 2.84BPM AND LOGGING UPWARS AT 10FT/MIN). MM IN=2.84 BPM, MM-OUT=2.47BPM, LOSSES=0.4-0 5BPM 04:20 - 05:10 0.83 DRILL P PROD1 LOG UP TO 8,850',THEN TURN AROUND AND RIH. 05:10 - 06:40 1.50 DRILL P PROD1 COMMENCE DRILLING LATERAL SECTION AHEAD FROM 9,670'. ROP=97 FPH,WOB= 1.73 K LBS, CIRC PRESSURE=3,171 PSI AT 2.94 BPM. MM IN=2.94 BPM / MM OUT=2.65 BPM / LOSSES=0.3-0.5 BPM MW IN=8.58 PPG / MW OUT=8.63 PPG / ECD= 10.09 PPG PVT=269 BBL,IA=4 PSI / OA= 17 PSI OBTAIN SLOW PUMP RATES 06:40 - 06:50 0.17 DRILL P PROD1 DRILLED 150'PU FORA BHA WIPER,IF EVERYTHING LOOKS OK CONTINUE DRILLING Printed 12/26/2012 10:48:38AM s• - North America -ALASKA- BP Page 9 of Operation Summary Report • "Agiatik.- . Common Well Name: D-19 AFE No Event Type. RE-ENTER-ONSHORE(RON) Start Date: 12/1/2012 End Date X3-012WL-C:DRILL(2,273,392 00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.. NORDIC 1 ' Spud Date/Time.4/24/1982 12.00.00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:50 - 07.30 0.67 DRILL P PROD1 WEIGHT&PRESSURE LOOK OK,CONTINUE DRILLING ROP=150 FPH,WOB=2.38 K LBS,CIRC PRESSURE=3292 PSI AT 2.87 BPM. MM IN=2.88 BPM / MM OUT=2.68 BPM / LOSSES=0.2 BPM MW IN=8.60 PPG / MW OUT=8.67 PPG / ECD=10.15 PPG PVT=244 BBL,IA=4 PSI / OA=17 PSI 07:30 - 07:50 0.33 DRILL P PROD1 ***COMPLEX KICK WHILE DRILLING DRILL*** SIMULATED A KWD DRILL, CTS DRILLER PU OFF BOTTOM SHUT DOWN HIS PUMPED AND CONTINUED TO SEE FLOW. HE ATTEMPTED TO SHUT IN THE WELL WITH HIS HCR FROM THE OPS CAB BUT SAID IT FAILED.THE NORDIC DRILL THEN SAID HE TRIED TO CLOSE THE HCR FROM THE FLOOR AND THAT FAILED.THE MOTOR MAN CALLED OVER THE RADIO AND SAID HE CLOSED THE VALVE MANUALLY BUT THAT DID NOT WORK AS WELL.THE FLOOR HAND(WITHOUT ANY INSTRUCTIONS)CALLED OVER THE RADIO AND SAID HE WAS SHUTTING THE WELL IN WITH THE 3-1/8 MANUAL VALVE ON THE CHOKE AND THE WELL WAS SHUT IN. EXCELLENT RESPONSE FROM THE CREW, WITH EVERY ATTEMPT THAT FAILED TO SHUT THE WELL EACH POSITION KNEW WHAT TO WITHOUT BEING TOLD WHAT TO DO ALL THE WAY DOWN TO THE FLOOR HAND WHO SHUT THE WELL IN WITH THE MANUAL VALVE WHEN ALL HYDRAULIC& MANUAL ATTEMPTS FAILED 07:50 - 08:00 0.17 DRILL P PROD1 CONTINUE DRILLING AHEAD 08:00 - 08:50 0.83 DRILL P PROD1 WIPER TO WINDOW PVT=231 BBLS 9690TO 9613'HAD 5-10K OVER PULLS WITH MOTOR WORK. RIH AND PULLED BACK THROUGH CLEAN 9570'TO 9540'A LITTLE MOTOR WORK BUT NO WT INCREASE 08:50 - 09:05 0.25 DRILL P PROD1 TIE IN 09:05 - 09:45 0.67 DRILL P PROD1 CORRECT DEPTH+4'AND RIH 09:45 - 10:35 0.83 DRILL P PROD1 CONTINUE DRILLING AHEAD ROP=150 FPH,WOB=1.87 K LBS,FREE SPIN=3000 PSI AT 2.98 BPM. MM IN=2.98 BPM / MM OUT=2.75 BPM / LOSSES=0.25 BPM MW IN=8.61 PPG / MW OUT=8.67 PPG / ECD=10.17 PPG PVT=320 BBL,IA=5 PSI / OA=18 PSI 10100'START DRILLING DOWN TO 8951'TVD LOOKING FOR HOT Printed 12/26/2012 10:48:38AM North America -ALASKA- BP Page 10 of 11 Operation Summary Report Common Well Name: D-19 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 12/1/2012 End Date: X3-012WL-C:DRILL(2,273,392.00) Project: Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time:4/24/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:35 - 10:50 0.25 DRILL P PROD1 CONTINUE DRILLING AHEAD FAST ROP NEEDED TO DRILL IF WE LOOSE MOTOR WORK IT STACKS OUT ROP=150 FPH,WOB=1.55 K LBS,FREE SPIN=3000 PSI AT 2.98 BPM. MM IN=2.98 BPM / MM OUT=2.75 BPM / LOSSES=0.25 BPM MW IN=8.61 PPG / MW OUT=8.67 PPG / ECD=10.17 PPG PVT=320 BBL,IA=5 PSI / OA=18 PSI 10:50 - 11:30 0.67 DRILL P PROD1 STOP DRILLING TO CIRC SAMPLES UP 11:30 - 11:55 0.42 DRILL P PROD1 ALL SAMPLES OUT,WO GEO TO DETERMINE IF WE ARE IN THE HOT 11:55 - 12:25 0.50 DRILL P PROD1 THE LAST SAMPLE FROM 10190'HAS HOT IN IT,TURN UP AND HOLD 8949 TVD-3'ABOVE THE HOT 12:25 - 13:00 0.58 DRILL P PROD1 CONTINUE DRILLING AHEAD ROP=122 FPH,WOB=2.87 K LBS, FREE SPIN=3140 PSI AT 3.0 BPM. MM IN=3.00 BPM / MM OUT=2.80 BPM / LOSSES=0.20 BPM MW IN=8.63 PPG / MW OUT=8.64 PPG / .ECD=10.25 PPG PVT=295 BBL,IA=5 PSI / OA=21 PSI 13:00 - 13:30 0.50 DRILL P PROD1 500'FROM TD,CALL IN BHCT OF 146°FOR CMT PILOT TEST ROP=120 FPH,WOB=2.70 K LBS,FREE SPIN=3140 PSI AT 3.0 BPM. MM IN=2.95 BPM / MM OUT=2.86 BPM / LOSSES=0.15 BPM MW IN=8.65 PPG / MW OUT=8.65 PPG / ECD=10.28 PPG PVT=289 BBL,IA=5 PSI / OA=21 PSI 13:30 - 14:20 0.83 DRILL P PROD1 WIPER TO WINDOW&TIE IN PVT=286 BBLS 14:20 - 14:40 0.33 DRILL P PROD1 LOG TIE IN 14:40 - 15:10 0.50 DRILL P PROD1 CORRECT DEPTH+2'AND RIH 15:10 - 15:20 0.17 DRILL P PROD1 OBTAIN SPR'S 15:20 - 15:45 0.42 DRILL P PROD1 2-3'BEFORE TAGGING BOTTOM LOSSES ARE INCREASING CONTINUE DRILLING AHEAD ROP=150 FPH,WOB=2.28 K LBS,FREE SPIN=3050 PSI AT 2.90 BPM. MM IN=2.90 BPM / MM OUT=2.38 BPM / LOSSES=0.60 BPM MW IN=8.65 PPG / MW OUT=8.63 PPG / ECD=10.20 PPG PVT=257 BBL,IA=6 PSI / OA=21 PSI 15:45 - 16:15 0.50 DRILL P PROD1 DRILLED 50'AND RETURNS ARE BACK TO -0.2 BPM LOSS RATE 16:15 - 16:45 0.50 DRILL P PROD1 CONTINUE DRILLING AHEAD ROP=115 FPH,WOB=2.25 K LBS, FREE SPIN=3050 PSI AT 2.90 BPM. MM IN=2.83 BPM / MM OUT=2.71 BPM / LOSSES=0.10 BPM MW IN=8.65 PPG / MW OUT=8.70 PPG / ECD=10.36 PPG PVT=310 BBL,IA=6 PSI / OA=21 PSI Printed 12/26/2012 10:48:38AM North America -ALASKA- BP • Page 11 of 11 Operation Summary Report Common Well Name: D-19 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 12/1/2012 End Date: X3-012WL-C:DRILL(2,273,392.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time:4/24/1982 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI Active Datum: D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) (ft) _ 16:45 - 16:55 0.17 DRILL P PROD1 DRILLED 150',PU TO CHECK PARAMETERS. IF ALL IS GOOD,CONTINUE DRILLING AHEAD FOR ANOTHER 150' 16:55 - 17:20 0.42 DRILL P PROD1 PARAMETERS LOOK GOOD, CONTINUE DRILLING 17:20 - 18:25 1.08 DRILL P PROD1 CONTINUE DRILLING AHEAD FREE SPIN= 3050 PSI AT 2.90 BPM. ROP=97 FPH,WOB=2.44 K LBS,CIRC PRESSURE=3417 PSI AT 2.80 BPM. MM IN=2.82 BPM / MM OUT=2.48 BPM / LOSSES=0.34 BPM MW IN=8.67 PPG / MW OUT=8.71 PPG / ECD=10.32 PPG PVT=289 BBL,IA=7 PSI / OA=22 PSI 10518'LOOKS LIKE WE CROSSED ANOTHER FAULT,BIG DROP IN RESISTIVITY AND INCREASE IN WOB 18:25 - 19:50 1.42 DRILL P PROD1 WIPER TO WINDOW PVT=271 BBLS TIE IN AT RA MARKER.APPLY+1'DEPTH • CORRECTION. 19:50 - 21:00 1.17 DRILL P PROD1 RIH TO BOTTOM, NO PROBLEMS. 21:00 - 23:30 2.50 DRILL P PROW CONTINUE DRILLING AHEAD FREE SPIN= 3060 PSI AT 2.90 BPM. ROP=70-110 FPH,WOB=1.7-2.3 K LBS, CIRC PRESSURE=3400-3600 PSI AT 2.80 BPM. MM IN=2.8 BPM / MM OUT=2.6 BPM / LOSSES=0.2 BPM -(D MW IN=8.68 PPG / MW OUT=8.72 PPG / ECD=10.38 PPG PVT=202 BBL,IA=9 PSI / OA=21 PSI TD WELL AT 10,850' DRILL IN MOSTLY CLEAN SAND AT 30 API. 23:30 - 00:00 0.50 DRILL P PROD1 PICK UP FOR FINAL WIPER-TRIP TO WINDOW. 12/7/2012 00:00 - 00:45 0.75 DRILL P PROD1 COMPLETE FINAL WIPER-TRIP TO WINDOW. NO ISSUES ON WAY OUT. 00:45 - 01:10 0.42 DRILL P PROD1 TIE-IN TO RA-TAG.APPLY DEPTH-CORRECTION OF+3FT. 01:10 - 02:20 1.17 DRILL P PROD1 RUN BACK TO TD.LINE UP AND PUMP LINER RUNNING PILL INTO COIL. 02:20 - 02:30 0.17 DRILL P PROD1 TAG AND RE-TAG TD AT 10,851'. CONDUCT FLOWCHECK AT TD.ACHIEVE GOOD NO-FLOW. 02:30 - 03:15 0.75 DRILL P PROD1 COMMENCE POOH, LAYING IN 33BBLS LINER RUNNING PILL(CLEAN MUD). 03:15 - 03:30 0.25 DRILL P PROD1 PULL UP TO 8,771'AND FLOWCHECK WELL. 03:30 - 05:15 1.75 DRILL P PROD1 CONTIUNE POOH. PAINT TD-FLAG AT 8,400' EOP(8,486.41'BIT DEPTH)AND WINDOW-FLAG AT 6,400'EOP(6,386.41'BIT DEPTH). 05:15 - 05:30 0.25 DRILL P PROD1 PULL TO SURFACE,THEN JOG BACK IN HOLE TO 200'.PERFORM 5MINS FLOWCHECK. ACHIEVE GOOD NO-FLOW. 05:30 - 06:00 0.50 DRILL P PROD1 POP OFF INJECTOR AND LD BHA#3.GRADE BIT 6-2-RO-N-X-I-BT-TD. Printed 12/26/2012 10:48:38AM Page'1,, -OperationSummary Report Common Well Name: D-19 AFE No Event Type:COM-ONSHORE(CON) Start Date: 12/7/2012 End Date: 12/10/2012 X3-012WL-C:DRILL(1,154,761.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 1 Spud Date/Time:4/24/1982 12:00:00AM Rig Release: 12/10/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/7/2012 06:00 - 06:45 0.75 CASING P RUNPRD PREP TO RUN LINER 06:45 - 07:00 0.25 CASING P RUNPRD PJSM TO PUMP SLACK OUT 07:00 - 08:00 1.00 CASING P RUNPRD MU 2 JTS OF PH6 STAB INJECTOR ON THE WELL LOAD COIL WITH 50 BBLS OF FRESH WATER TO PUMP SLACK OUT 08:00 - 09:00 1.00 CASING P RUNPRD -PUMPE OUT 253'OF WIRE RU CUTTER TO CUT 100'OF COIL FOR CHROME MGMT 09:00 - 0930 0.50 CASING P RUNPRD CUT 100',RD CUTTER 09:30 - 0945 0.25 CASING P • RUNPRD HOLD PJSM TO MU UPPER QTS AND BTT MHA FOR LINER 09:45 - 10:40 0.92 CASING P RUNPRD MU THE QTS AND INSTALL THE BTT MHA PULL TEST CTC TO 36K. GOOD PULL TEST PT TO 3500 PSI,GOOD PT 10:40 - 11:30 0.83 CASING P RUNPRD STAB ON WELL TO PUMP 3/4"DRIFT BALL BALL IS CONFIRMED ROLLING 11:30 - 11:45 0.25 CASING P RUNPRD BALL LANDED IN THE NOZZLE CLOSE THE SWAB VALVE TO PT THE LUBRICATOR CONNECTION • 11:45 - 13:15 1.50 CASING P RUNPRD GOOD LOW&HIGH PT ON LUBRICATOR -OPEN SWAB AGAINST A CLOSED CHOKE TO CHECK FOR PRESSURE NO PRESSURE OPEN THE CHOKE TO CHECK FOR FLOW NO FLOW, FILL HOLE HOLE IS FULL, REMOVE INJECTOR AND SET ON LEGS 13:15 - 13:40 0.42 CASING P RUNPRD PJSM TO MU LINER 13:40 - 15:00 1.33 CASING - P RUNPRD MU LINER DRIFTING 1ST 5 CO)4NECTIONS FOR EACH SIZE OF LINER 15:00 - 15:15 0.25 CASING P RUNPRD 35 JTS RAN FILL LINER 15:15 - 15:55 0.67 CASING P RUNPRD CONTINUE RUNNING LINER 15:55 - 16:05 0.17 CASING P RUNPRD ****VALVE DRILL WHILE RUNNING LINER**** GREAT RESPONSE FROM CREW,SAFETY JOINT WAS PICKED UP AND LOWERED ACROSS THE BOP,UPPER COMBIS CLOSED AND FOSV CLOSED IN 2MIN.ALL PERSONNEL REPORTED FROM THEIR POSITIONS&KOOMEY PSI INCREASED TO HIGH SIDE THEN WELL WAS SIMULATED TO BE SHUT IN,IN 2-1/2 MIN.DISCUSSED DRILL WITH CREW THEN RD THE SAFETY JOINT 16:05 - 18:00 1.92 CASING P RUNPRD CONTINUE RUNNING LINER 18:00 - 18:15 0.25 CASING P RUNPRD ALL LINER&PH6 RAN,MU SAFETY JOINT FOR CHANGE OUT. 18:15 - 19:30 1.25 CASING P RUNPRD FINISH MU BHA#4.STAB ON INJECTOR AND PRESSURE-TEST QTS TO 300 PSI/5 MINS AND 3,500 PSI/5 MINS. 19:30 - 19:50 0.33 CASING P RUNPRD INSTALL UTIM(ULTRA-SONIC TUBING INTEGRITY MEASURMENT)TO COIL. 19:50 - 21:30 1.67 CASING P RUNPRD RIH WITH LINER. Printed 1/8/2013 11:56:30AM North America-ALASKA- BP Ill Page 2 of 8 Operation Summary Report Common Well Name: D-19 AFE No Event Type: COM-ONSHORE(CON) Start Date: 12/7/2012 End Date: 12/10/2012 X3-012WL-C:DRILL(1,154,761.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time:4/24/1982 12.00:OOAM Rig Release: 12/10/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 - 21:40 0.17 CASING P RUNPRD SEE WINDOW-FLAG AT 8,615.27'-SHOULD BE AT 8,611.27'(6,300'+100'SAFETY-100' CUT CT+2,311.27'BHA-LENGTH).CORRECT DEPTH BY-4.39'. CONFIRM PUW WITH 34K LBS CT-WEIGHT. 21:40 - 22:15 0.58 CASING P RUNPRD CONTINUE RIH. 22:15 - 22:50 0.58 CASING P RUNPRD RUN LINER TO TD.TAG TD AT 10,851'. PU AND SEE BREAKOVER AT 10,830'/52K LBS PUW. 22:50 - 23:20 0.50 CASING P RUNPRD DROP 5/8"BALL AND CIRCULATE TO SEAT WITH 39BBLS. PRESSURE-UP TO 4,300PSI AND RELEASE FROM LINER. PU 6 FT TO CONFIRM RUNNING TOOLS ARE FREE;PUW=34K LBS.SIT DOWN AND STACK BACK 10K LBS AT 10,850'. 23:20 - 00:00 0.67 CASING P RUNPRD DISPLACE WELL TO KCL. 12/8/2012 00:00 - 02:20 2.33 CASING P. RUNPRD CONTINUE DISPLACING WELL TO KCL. MM-IN=1.93BPM/MM-OUT=1.81 BPM MM-IN=8.29BPM/MM-OUT=8.38BPM 02:20 - 02:40 0.33 CASING -P RUNPRD HOLD PJSM WITH SLB CEMENT CREW BEFORE PRESSURE-TESTING.SINCE INNER .REEL VALVE WAS CHANGED OUT IN THE BEGINNING OF THIS WELL,NEED TO PRESSURE-TEST ALL HARDLINE TO 6,000PSI. 02:40 - 03:15 0.58 CASING P RUNPRD BLOW DOWN CEMENTING LINE TO SLB CEMENTERS. PUSH KCL TO CEMENTERS, PRIME CEMENT-PUMPS AND LOAD LVT MINERAL OIL. 03:15 - 04:00 0.75 CASING P RUNPRD FILL LINES WITH 1OBBLS LVT MINERAL OIL FOR FREEZE-PROTECTION. ISOLATE CEMENTERS IN REEL HOUSE AND LINE-UP TO NORDIC PUMPS. DISPLACE MINERAL OIL WITH 16BBLS KCL OVER GOOSENECK FOR FREEZE-PROTECTING COIL. ISOLATE MICROMOTION AND HIGH PRESSURE SCREENS IN REELHOUSE. 04:00 - 05:45 1.75 CASING P RUNPRD COMMENCE PRESSURE-TESTING CEMENT SURFACE LINE AND REEL HOUSE HARDLINE ALL THE WAY TO INNER REEL VALVE. ACHIEVE LOW PRESSURE TEST TO 300 PSI /5 MINS. ATTEMPT HIGH PRESSURE-TEST BUT ALREADY NOTICE PRESSURE-DROP RIGHT AWAY WHEN SHIFTING GEARS ON PUMP. CLOSE VALVE ON CMT STAND-PIPE AND NOTICE PRESSURE-DROP HALT IMMEDIATELY. BLEED OF TEST-PRESSURE AND GREASE VALVES IN REEL HOUSE. RE-START PRESSURE-TEST AND ACHIEVE GOOD HIGH PRESSURE TEST TO 6,000PSI. 05:45 - 06:45 1.00 CASING P RUNPRD READY TO BATCH UP CEMENT AT 05:45AM- AWAIT CREW CHANGE BEFORE PROCEEDING. 06:45 - 07:10 0.42 CASING P RUNPRD ALL CREWS CHANGED OUT HOLD PJSM TO MIX AND PUMP CMT 07:10 - 07:30 0.33 CASING P RUNPRD BATCH CMT Printed 1/8/2013 11:56:30AM • North America -ALASKA- BP Page 3 of 8 Operation Summary Report Common Well Name: D-19 AFE No Event Type: COM-ONSHORE(CON) Start Date: 12/7/2012 End Date: 12/10/2012 'X3-012WL-C:DRILL(1,154,761.00) Project: Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time:4/24/1982 12:00:OOAM Rig Release: 12/10/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum: D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 09:10 1.67 CASING P RUNPRD 07:30 CMT TO WEIGHT 520 PSI @ 1.5 BPM LOSS RATE=0.10 BPM 07:35 SWAP COIL PUMP TO BIO 07:42 SHUT DOWN RIG PUMP AND LINE UP CMT PUMP DOWN THE COIL 07:45 ON LINE WITH CMT PUMP WITH 5 BBLS OF KCL 07:48 ON LINE WITH CMT,ZERO IN MM AT 14.0 PPG DENSITY 08:03 SHUT DOWN PUMP 28.7 BBLS AWAY. LINE UP TO GIVE BIO TO CMT TRUCK 08:06 ONLINE WITH RIG PUMP TO DISPLACE Osf CMT WITH BIOZAN 08:10 CAUGHT CMT AT 36 BBLS AWAY lam' 08:17 52.2 BBLS AWAY REDUCE RATE TO 1.5 BPM AS TO NOT SLAM SELRT WITH CMT 08:20 INCREASE RATE TO 2.0 BPM TO KEEP UP WITH CMT 08:26 69.0 BBLS AWAY CMT AT THE SHOE, ZERO OUT MM AND TAKE RETURNS TO PIT #2 08:31 81.8 BBLS AWAY,SHUT DOWN THE PUMP TO LAUNCH PEE WEE DART AND SIDE EXHAUST 08:32 PU TO UP WT+13' (OUT MM AT 12.5 BBLS) 08:33 STOP AT 10828', RIH SET BACK DOWN PUMP PEE WEE DART ON SEAT 08:37 PEE WEE DART ON SEAT (IN MM AT 83.2 BBLS OUT MM AT 13.1 BBLS) 08:40 PU TO PRESSURE DROP ON COIL AND SIDE EXHAUST 2 BBLS OF CMT AND 3 BBLS OF BIOZAN 08:43 5 BBLS PUMPED,OPEN BAKER CHOKE AND STACK WT BACK DOWN 08:44 RESET PUMP TRIPS BACK TO 4500 PSI 08:45 ZERO IN MM AND PRESSURE UP TO SHEAR LWP 08:46 LWP SHEARED AT 3400 PSI. DISPLACE LWP AT 2.5 BPM 08:48 LOSS RATE INCREASED TO 0.7 BPM AFTER SHEARING PLUG, REDUCE RATE STILL LOOSING 0.7 08:51 12.9 AWAY REDUCE RATE TO BUMP PLUG 08:52 PLUG BUMPED AT 14.0 BBLS OUT MM AT 27.0 BBLS&HOLD TO VERIFY PLUG IS SET 08:54 SHUT DOWN ALL CHARGE PUMPS(27.4 BBLS GAIN IN PIT-5 BBLS=22.4 BBLS) 08:56 BLEED OFF COIL PRESSURE TO CHECK FLOATS 09:01 GOOD NO FLOW ON THE FLOATS, CLOSE THE BAKER CHOKE AND PRESSURE UP TO 700 PSI 09:04 PU TO PRESSURE DROP AND PUMP 5 BBLS OF BIOZAN AT 0.5 BPM 24.9 BBLS OF CMT BEHIND PIPE,17.74 BBLS • NEEDED TO COVER TOL 12.5 BBLS BEFORE SIDE EXHAUST 9.1 BBLS AFTER SIDE EXHAUST Printed 1/8/2013 11:56:30AM North America-ALASKA- BP ' Page 4 of 8 Operation Summary Report Common Well Name: D-19 AFE No Event Type:COM-ONSHORE(CON) Start Date: 12/7/2012 End Date: 12/10/2012 X3-012WL-C:DRILL(1,154,761.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time:4/24/1982 12:00:OOAM Rig Release: 12/10/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum: D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:10 - 10:55 1.75 CASING P RUNPRD 5 BBLS OF BIO PUMPED, POOH MAINTAINING 0.5 BPM OUT RATE 10:55 - 11:20 0.42 CASING P RUNPRD FLOW CHECK WELL&HOLD PJSM GOOD NO FLOW,PUMP TO CHECK FOR LOSSES,WELL TOOK-0.50 BBLS IN 5 MIN TAG UP, REMOVE INJECTOR AND SET ON LEGS 11:20 - 12:10 0.83 CASING P RUNPRD PULL LINER RUNNING BHA 12:10 - 12:30 0.33 CASING P RUNPRD BHA OOH AND 5/8"BALL RECOVERED FROM TOOL OFF LOAD SELRT AND PREP FLOOR TO MU CLEAN OUT/LOGGING BHA 12:30 - 12:35 0.08 CASING P RUNPRD HOLD PJSM TO LOAD LOGGING TOOL AND SOURCE KEG ON RIG 12:35 - 12:40 0.08 EVAL P OTHCMP LOAD LOGGING TOOL AND SOURCE KEG ON RIG 12:40 - 13:00 0.33 EVAL P OTHCMP HOLD PJSM TO MU CLEAN OUT BHA 13:00 - 16:25 3.42 EVAL P OTHCMP MU CLEANOUT/LOGGING BHA PUMPING EVERY 10 STANDS 16:25 - 16:40 0.25 EVAL P OTHCMP PU INJECTOR AND MU TO THE BHA 16:40 - 17:00 0.33 EVAL P OTHCMP TEST THE QTS 17:00 - 20:00 3.00 EVAL P OTHCMP RIH WITH 2.3"MILL AND SLB MEMORY LOG BHA WITH CNL-GR-CCL. MILL AND WASH OUT CONTAMINATED CEMENT LOG DOWN AT 30 FPM TREAT RETURNS WITH CITRIC ACID FOR PH CONTROL TAG BAKER LATCH COLLAR AT 10,808' 20:00 - 23:15 3.25 EVAL P OTHCMP POH LOG AT 60 FPM. LAY PERF PILL IN LINER. PAINT FLAG ON COIL FOR TCP GUN DEPTH VERIFICATION FLOW CHECK AT 200' CONDUCT FIRE DRILL. _CONDUCT KICK WHILE TRIPPING DRILL 23:15 - 23:30 0.25 EVAL P OTHCMP DISCONNECT STINGER AND SATND BACK RIG UP TO POH 23:30 - 00:00 0.50 EVAL P OTHCMP POH LAY DOWN TOOLS AND 2 JTS 2 2/8"PH6 TUBING. DROP 1/2"BALL TO OPEN THE CIRC SUB PRESSURE UP TO 2200 PSI. OPEN CIERC SUB.CONFIRM CURCULATION. 12/9/2012 00:00 - 02:15 2.25 EVAL P OTHCMP POH WITH CLEAN OUT/LOGGING TOOLS. STAND BACK 1 1/4"CS HYD WORK STRING_ 02:15 - 02:30 0.25 EVAL P OTHCMP PJSM WITH CREW AND THIRD PARTY CNTRACTOR ON HANDLING NUCLEAR SOURCE. 02:30 - 03:30 1.00 EVAL P OTHCMP POH TO LOGGING TOOLS. LAY DOWN NUCLEAR SOURCE AND SECURE. LAY DOWN LOGGING TOOLS. LAY DOWN MUD MOTOR AND MILL. MILL REUSABLE. 03:30 - 04:30 1.00 PERFOB P OTHCMP PICK UP INJECTOR.CONNECT BOP JETTING TOOL. STAB INJECTOR ON TO WELL.TEST QTS Printed 1/8/2013 11.56.30AM North America -ALASKA- BP Operation Summary Report Common Well Name:0-19 AFE No Event Type: COM-ONSHORE (CON) Start Date: 12/7/2012 End Date: 12/10/2012 IX3-012WL-C:DRILL(1,154,761.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 1 Spud Date/Time:4/24/1982 12.00:00AM Rig Release: 12/10/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum: D-19B: @76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 05:15 0.75 PERFOB P t OTHCMP JET WASH BOP. REMOVE INJECTOR AND STAND BACK. VALVE CREW GREASE TREE AND FUNCTION VALVES. 05:15 - 05:45 0.50 PERFOB P OTHCMP FUNCTION ALL BOP COMPONENTS FROM DRILLERS STATION WITH TEST JOINT IN STACK. -VISUALLY CONFIRM FUNCTIONS. 05:45 - 06:30 0.75 PERFOB P OTHCMP RIG UP TO PERFORM LINER TOP TEST. 06:30 - 06:45 0.25 PERFOB P OTHCMP LINER LAP TEST FAILED LOW PT.FAILED TO ACHIEVE 250 PSI. 06:45 - 07:00 0.25 PERFOB P OTHCMP CREW CHANGE COMPLETED ATTEMPT LAP TEST AGAIN,OPEN WHITEY TO ENSURE WELL BORE IS FLUID PACKED AND WELL IS ON A VAC CALL WTL WITH RESULTS.PERMISSION TO PROCEED WITH PICKING UP PERF GUNS 07:00 - 08:00 1.00 PERFOB ` P OTHCMP LOAD TCP EQUIPMENT ON RIG AND PREP RIG FLOOR TO MU PERF GUNS 08:00 - 08:20 0.33 PERFOB P OTHCMP PJSM TO MU PERF GUNS 08:20 - 09:10 0.83 PERFOB P OTHCMP MU PERF GUN BHA 09:10 - 10:35 1.42 PERFOB P OTHCMP MU FIRING HEAD. PICK UP 36 STANDS OF 1 1/4"CS HYDRIL 10:35 - 11:15 0.67 PERFOB P OTHCMP BHA RAN,PU INJECTOR AND MU TO THE BHA TEST THE QTS 11:15 - 11:45 0.50 PERFOB P OTHCMP RIH WITH GUNS 11:45 - 12:00 0.25 PERFOB P OTHCMP *****MGS DRILL***** SIMULATE GETTING LOW LEVEL GAS BACK AT THE SHAKER WHILE RIH STOPPED RIH AND SHUT DOWN PUMP,NO FLOW,LINE UP TO CHOKE&MGS AND COME ONLINE WITH PUMP.RETURNS GOING THROUGH OUT MM NOT SHOWING ANY GAS. CONTINUE FLOW THROUGH MGS AND CONTINUE RIH.NO GAS SEEN THE REST OF THE WAY IN THE HOLE.DISCUSS CIRCULATING 1.5 VOLUMES FROM BOTTOM TO ENSURE WELLBORE IS CLEAN THEN ROUTE RETURNS THROUGH NORMAL FLOW PATH 12:00 - 12:15 0.25 PERFOB P OTHCMP NOTA DRILL COME ONLINE WITH PUMP AND OUT DENSITY DROPPED TO 7.8 PPG AND 8.2 PPG. SHUT DOWN PUMP AND CHECK FOR FLOW. GOOD 5 MIN NO FLOW.COME ONLINE WITH PUMP AND WE ARE GETTING A LOT OF GREASE BACK ACROSS THE SHAKER FROM WHEN THE TREE VALVES WERE SERVICED BEFORE CREW CHANGE.CONTINUE CIRCULATING TO CLEAR GREASE FROM RETURNS AND DENSITY IS STABLE. 12:15 - 13:15 1.00 PERFOB P OTHCMP CONTINUE RIH 13:15 - 13:40 0.42 PERFOB P OTHCMP STOP AT(EOP FLAG OF 8161') 10711.6'AND CORRECT DEPTH TO 10719.37'(BHA= 2558.4')TCP SETTING UP SHOT DETECTION Printed 1/8/2013 11:56:30AM North America-ALASKA- BP Page 6 of 8 Operation Summary Report Common Well Name D-19 AFE No Event Type: COM-ONSHORE(CON) —Start Date. 12/7/2012 End Date: 12/10/2012 {X3-012WL-C:DRILL(1,154,761 00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time:4/24/1982 12.00.00AM Rig Release 12/10/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:40 - 13:45 0.08 PERFOB P OTHCMP TAG PBTD AT 10817.7'CORRECTED PBTD IS 10,812.9'.PUTOUPWT UP WT =35K,RIH TO TAG THE PU TO 35K (10,814.9')THEN STOP AND CORRECT DEPTH TO 10,812.9' 13:45 - 13:54 0.15 PERFOB P OTHCMP PU TO 10,807 TO ESTABLISH RATES& PRESSURES 0.30 BPM=180 PSI 1.50 BPM=1560 PSI 13:54 - 14:07 0.22 PERFOB P OTHCMP START PUMP FOR E-FIRE SEQUENCE PVT= 251 BBLS FIRE E-FIRE.CLEAR INDICATION THAT GUNS FIRED. PERF INTERVAL 10,605'TO 10,805'(200') POWER JET 2006 HMX,6.5, 6 SPF WITH 60 DEG PHASING. 14:07 - 15:05 0.97 PERFOB P OTHCMP PU SLOWLY AND GUNS FIRED ON DEPTH, NOTICABLE CHANGE IN WT AND LOSS OF COIL PRESSURE,CLOSE CHOKE TO MAINTAIN 200-300 PSI WHP AND POOH. 15:05 - 15:15 0.17 PERFOB P OTHCMP STOP AT 8700'TO FLOW CHECK WELL 15:15 - 16:05 0.83 PERFOB P OTHCMP GOOD NO FLOW CHECK,LOST 7 BBLS -TRIPPING TO TOL 16:05 - 16:20 0.25 PERFOB P OTHCMP PJSM TO PULL PERF BHA 16:20 - 16:25 0.08 PERFOB P OTHCMP FLOW CHECK WELL 16:25 - 16:40 0.25 PERFOB P OTHCMP TAG UP AND REMOVE INJECTOR AND STAND BACK 16:40 - 21:00 4.33 PERFOB P OTHCMP RIG UP TO POH WITH TCP GUN BHA. PULL 1 1/4"CS HYDRIL. PVT=192 BBLS LAY DOWN BHA. LAY DOWN 2"GUNS.ALL GUNS FIRED. 21:00 - 23:00 2.00 PERFOB P OTHCMP RIG DOWN TCP RUNNING TOOLS. CLEAR RIG FLOOR. WELL TAKING 2 BBL PER HOUR. REMOVE FIRED 2"TCP GUNS FROM THE PIPE SHED. 23:00 - 23:30 0.50 DHB P OTHCMP PICK UP BAKER"45 KB"LINER TOP PACKER AND 4"RUNNING TOOL BHA. 23:30 - 00:00 0.50 DHB P OTHCMP PICK UP INJECTOR.MAKE UP OTC AND TEST. RIH WITH LINER TOP PACKER AT 70 FPM 12/10/2012 00:00 - 01:30 1.50 DHB P OTHCMP RIH WITH BAKER"45KB"LINER TOP PACKER. TAG TOP OF LINER AT 8737' 01:30 - 02:15 0.75 DHB P OTHCMP STING INTO TOP OF LINER.CONFIRM WITH PRESSURE INCREASE. PICK UP OUT OF LINER TOP TO 8737'. POSITION VALVE ON COIL TO DROP BALL. DROP 5/8"BALL AND PUMP DOWN AT.55 BPM WITH 60 PSI. BALL ON SEAT. SET DOWN 8000 LBS.PICK UP TO STRING WEIGHT. Printed 1/8/2013 11:56:30AM North America-ALASKA- BP Page 7 of 8 Operation Summary Report Common Well Name: D-19 AFE No Event Type:COM-ONSHORE(CON) Start Date: 12/7/2012 I End Date: 12/10/2012 X3-012WL-C:DRILL(1,154,761.00) Project: Prudhoe Bay Site:PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time:4/24/1982 12:00:00AM [Rig Release: 12/10/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum: D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:15 - 03:30 1.25 DHB P OTHCMP PRESSURE UP TO 4600 PSI TO SET LINER TOP PACKER AND SHEAR RUNNING TOOL. ESTABLISH CIRCULATION DOWN COIL UP ANNULUS AT 1.0 BPM WITH 168 PSI. OPEN KILL LINE,PUMP DOWN ANNULUS AND ATTEMPT TO PRESSURE TEST LINER TOP PACKER.FAILED AT 1445 PSI. SWAP VALVES TO CIRCULATE DOWN COIL TO PREVENT FREEZING. SET DOWN 8000 LBS ON LTP. REPEAT TEST.PRESSURE UP ANNULUS TO 2400 PSI. • ACHIEVE GOOD TEST WITHIN THE 10 MINUTE LIMIT.(SEE ATTACHED PRESSURE CHART) PICK UP FREE FROM LTP RUNNING TOOL. ESTABLISH CIRCULATION DOWN COIL. 03:30 - 06:00 2.50 DHB P OTHCMP POH WITH LINER PACKER RUNNING TOOL AT 100 FPM CIRCULATING AT 1.4 BPM WITH 267 PSI. FLOW CHECK WELL AT 200' REMOVE INJECTOR AND LAY DOWN BHA. 06:00 - 06:25 0.42 DHB P OTHCMP MU NOZZLE BHA WITH DBPV 06:25 - 07:00 0.58 REST P POST _RN TO FREEZE PROTECT WELL FROM 2500' WITH DIESEL 07:00 - 07:40 0.67 REST P POST PUMP 50 BBL WARM 80 DEG DIESEL FROM LRS TRUCK 07:40 - 08:15 0.58 REST P POST POOH LAYING IN DIESEL FROM 2500' 08:15 - 08:45 0.50 REST P POST OOH WITH GOOD DIESEL AT SURFACE REMOVE INJECTOR AND LD NOZZLE BHA 08:45 - 09:05 0.33 DHB P POST PJSM WITH VALVE CREW TO LOAD BPV LUBRICATOR ON THE THE RIG 09:05 - 09:45 0.67 DHB P POST LOAD LUBRICATOR ON THE RIG 09:45 - 10:00 0.25 DHB P OTHCMP FLUID PACK STACK WITH NEAT METHANOL AND PRESSURE TEST BPV LUBRICATOR 10:00 - 10:20 0.33 DHB P POST MASTER AND SET BPV �. BPV SET,CLOSE MASTER SWAB AND SSV 10:20 - 10:55 0.58 DHB P POST LOAD OUT VALVE CREW EQUIPMENT 10:55 - 11:20 0.42 DHB P POST HOLD PJSM TO PU INJECTOR,REVERSE A FEW BBLS OF NEAT METH IN COIL THEN BLOW BACK WITH AIR 11:20 - 12:00 0.67 DHB P POST PU INJECTOR AND MU TO THE LUBRICATOR CANT USE PUMP#1 TO REVERSE AMBIENT METH BECAUSE IT HAS CERAMIC PLUNGERS,GO THE LONG WAY 12:00 - 12:45 0.75 DHB P POST BLOW BACK COIL WITH AIR 12:45 - 13:00 0.25 DHB P POST PU INJECTOR AND SET ON LEGS 13:00 - 13:20 0.33 DHB P POST PERFORM LEAK TIGHT TEST PER WELL PLAN TO OPEN BOP DOORS TO INSPECT RAMS 13:20 - 17:30 4.17 BOPSUR P POST GOOD LEAK TIGHT TEST AND FLOW CHECK, MONITOR CAVITY FROM WING VALVE USING THE IA PRESSURE SENSOR LOCK OUT TAG OUT ACCUMULLATOR OPEN BOP DOORS INSPECT ALL RAMS. 17:30 - 20:00 2.50 BOPSUR P POST CLEAN PITS AND OFF LOAD FLUID. Printed 1/8/2013 11:56:30AM • North America -ALASKA- BP �=9 ° Operation Summary Report Common Well Name. D-19 AFE No Event Type:COM-ONSHORE(CON) Start Date: 12/7/2012 End Date: 12/10/2012 X3-012WL-C:DRILL(1,154,761.00) Project:Prudhoe Bay Site: PB D Pad Rig Na ne/No.: NORDIC 1 Spud Date/time:4/24/1982 12:00:00AM Rig Release: 12/10/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum: D-19B:@76.42ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 00:00 4.00 BOPSUR P POST NIPPLE DOWN BOP.LIFT BOP TO BELOW RIG FLOOR AND SECURE. NIPPLE DOWN RISER EXTENSION. REMOVE ADAPTOR FLANGE FROM TREE FILL TREE WITH METHANOL. INSTALL TREE CAP AND TEST SAME TO 250 PSI LOW AND 3500 PSI HIGH.SEE ATTACHED CHART. RIG RELEASED AT 24:00 HRS MONDAY 10 DECEMBER 2012 Printed 1/8/2013 11:56:30AM ZA2-- 52 7--24'1 az1 Letter of Transmittal r' ut— Date:BAK= December 20, 2012 MOHO To: I From: State of Alaska AOGCC Baker Hughes INTEQ 333 W. 7th Ave., Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Bill Michaelson Please find enclosed the directional survey data for the following well(s): 18-•27EPB 1, 18-27EPB2, 18-27E 06- 16A D-29A E-108 _ I P-19LIPB1, P-19L1 P-12BL1 W-02B Z-07B Enclosed for each well(s): 2 hardcopy prints of directional survey reports 1 compact disk containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LI22-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: fit41-) , State of Alaska AOGCC DATE: A l2At { OF y/T� 11111 gw\�� • THE STATE Alaska Oil and Gas 1)1 =_ of Conservation Commission ALASKA tax _ " V *h GOVERNOR SEAN PARNELL 333 West Seventh Avenue O�"^^j�D Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-19C BP Exploration (Alaska), Inc. Permit No: 212-152 Surface Location: 1880' FNL, 1692' FEL, SEC. 23, T11N, R13E, UM Bottomhole Location: 505' FNL, 2932' FEL, SEC. 23, T11N, R13E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, C(:.tv Cathy/P. Foerster Chair DATED this )2 day of October, 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', )IL AND GAS CONSERVATION COMMI, )N PERMIT TO DRILL QC i 0 4 201? 20 AAC 25.005 1 a.Type of work: lb.Proposed Well Class: 1c. =6 posed for: P 0Development Oil• ❑Service-Winj ®Single Zone ❑Drill 0 Redrill • 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 oalseelaPgas Hydrates ❑Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas 2. Operator Name: 5.Bond: 0 Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 • PBU D-19C • 3. Address: 6. Proposed Depth. 12. Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 10865' • TVD 8953'ss • Prudhoe Bay/Prudhoe Bay 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Surface: ADL 028285 • 1880' FNL, 1692' FEL, Sec.23,T11N, R13E, UM • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1584' FNL, 2571' FEL, Sec. 23,T11N, R13E, UM November 15,2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 505' FNL, 2932' FEL, Sec.23,T11N, R13E, UM 2560 23800' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 76.42' • feet 15.Distance to Nearest Well Open Surface. x- 653467 • y-5959108 • Zone- ASP4 GL Elevation above MSL: 41.45' feet to Same Pool: 698' 16.Deviated Wells. Kickoff Depth: 8802' • feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 98 degrees Downhole. 3222 • Surface: 2342 • 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) 4-1/4" 3-112"x3-1/4"x2-7/8" 93#/66*/47* L-80 STL/TC-II 2125' 8740' 8485'ss 10865' 8953'ss 150 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth TVD (ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 10230' 9033' None 10140' 9033' None Casing 1 Length Size Cement Volume ) MD TVD Conductor/Structural 110' 20"x 30" 8 cu yds Concrete 110' 110' Surface 2702' 13-3/8" 3549 cu ft Permafrost II 2702' 2702' Intermediate 6231' 9-5/8" 1177 cu ft Class'G', 130 cu ft PF'C' 6231' 6084' Production Liner 2615' _ 7" 230 cu ft Class'G' 6079'-8694' 5943'-8516' Liner 1699' 4-1/2" 270 cu ft Class'G' 8528'- 10227' 8352'-9033' Perforation Depth MD(ft)• 9270'- 10100' Perforation Depth ND(ft). 9009'-9034' 20.Attachments: 0 Property Plat ®BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 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 David Johnston,564-5985 Printed Name Joh /(40; Title Engineering Team Leader _ Prepared By Name/Number Signature �jt\ Phone 564-4711 Date f Q l �Z Joe Lastufka,564-4091 Commission Use Only / Permit To D,"'// API Number. Permit Ap r val te: See cover letter for Number: 21'2— 6 S 50-029-20707-03-00 gt� \1, 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: [3/ Other. A. s5-00 QST a)1" -7-;-;14-- Samples Req'd: ❑xes LvJ thNo Mud Log Req'd: 0 Yes W(No / H2S Measures' gYes 0 No Directional Survey Req'd: [ Yes 0 No ORIGINAL ,..0THE APPROVED BYCOMMISSION Date /C' �Z -/L L , L-7 / 79e--4---- 1�LA....___. COMCOMISSIMIONER Form 10-401 Revised 07/2009 This permit is valid for 24 months from the date of appproy I(20 AAC 25.005(9)) Submit In Duplicate, 11/ qty /b-/2'/Z_ 'i To: Alaska Oil & Gas Conservation Commission . From: David E. Johnston ► - bp CTD Engineer Date: October 4, 2012 Re: D-19C Permit to Drill Request • Approval is requested for a permit to drill a CTD sidetrack from well D-19B. CTD Drill and Complete D-19C program: Rig Start Date: November 15t11, 2012 Pre-Rig Work: (scheduled to begin October 15, 2012) 1. S Set Dummy GLV's (Done 7/17/2012) 2. F MIT- IA to 3,000 psi, MIT-OA to 2,000 psi (passed 7/17/2012) 3. W Cycle LDS; PPPOT- T to 5,000 psi (Passed 7/16/2012) 4. S Dummy WS Drift to deviation or 9,000' MD (28° Inc) 5. C Mill XN nipple at 8,529' to 3.80" St4- 6. E Set 4-1/2" KB Packer Whipstock at 8,802' MD 7. V Set TWC and PT MV, SV, WV o• 8. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange 9. 0 Remove wellhouse, level pad Rig Work: (scheduled to begin November 15th, 2012) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 3.80" window at 8,802' and 10' of rathole. • 3. Drill Build: 4.125" OH, 8,802 ft. to 9,655 ft. for 853' (25 deg/100 planned) 4. Drill Lateral: 4.125" OH, 9,655 ft. to 10,865 ft. for 1,210' (12 deg/100 planned) with . resistivity kt, 5. Run 3-1/4" x 2-7/8" liner leaving TOL at 8,740' MD. 6. Pump primary cement leaving TOC at 8,740' MD, 22 bbls of 15.8 ppg liner cmt planned PTD 7. Cleanout liner and run MCNL/GR/CCL log. • 8. Test liner lap to 2,400 psi. I-TP ;. 41..14.Q . 9. Stage perforate liner toe per asset instructions (-200') 10. Freeze protect well, set BPV, RDMO Post-Rig Work: 1. Re-install wellhouse, flowline and pull BPV. 2. Set 4-1/z" liner top packer, and test to 3,000 psi (If liner lap test fails) 3. Generic GLV's Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.5 ppg PowerVis for milling window and drilling (668 psi over-balance). Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.25" Liner Program: • 3-1/2", 9.3#, L-80, STL Solid Liner 8,740' MD — 8,800' MD • 3-1/4", 6.6#, L-80, TC-Il Solid Liner 8,800' MD — 9,700' MD • 2-7/8", 4.7#, L-80-80, STL Solid Liner 9,700' MD — 10,865' MD • A minimum of 31 bbls of 15.8 ppg cement will be used for liner cementing. (TOC 12,535' MD) • The primary barrier for this operation: a minimum EMW of 9.0 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 98°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property— 23,800'. • Distance to nearest well within pool — 698' Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • • Cased hole GR/CCL/MCNL logs will be run. Perforating: • SWS 2", 6 spf, perf guns, 1-1/4" CSH work string, & 2-3/8" PH6 • The primary barrier for this operation: a minimum EMW of 8.5 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti-Collision Failures • None . Hazards • The maximum recorded H2S level on D Pad was 50 ppm on well D-15A on 1/2/2005. • Reservoir Pressure • The reservoir pressure on D-19C is expected to be 3,222 psi at 8,800' TVDSS. 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N7.0 0!5-14-) rn N C o' m N N I Frill BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PBD Pad 0-19 D-19C Plan 8 Travelling Cylinder Report 18 September, 2012 Qbp • /GI/ BAKER ;`"'°� HUGHES Travelling Cylinder Report I�h' INTEQ �,`k`4� Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-19-Slot 19 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB D Pad MD Reference: D-19B:@ 76.42ft(D-19B:) Site Error: 0.00ft North Reference: True Reference Well: D-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore D-19C Database: EDM .16-ANC Prod-WH24P Reference Design: Plan 8 Offset TVD Reference: Offset Datum Reference Plan 8 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 8,795.43 to 10,865.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,282.91ft Error Surface: Elliptical Conic Survey Tool Program Date 9/18/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 97.72 6,197.72 GYRODATA(D-19) GYD-CT-CMS Gyrodata cont.casing m/s 6,231.00 8,795.43 D-19B MWD Sperry(D-19B) MWD MWD-Standard 8,795.43 10,865.00 Plan 8(D-19C) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 8,691.73 8,437.06 DRILLING LINER 1 7.000 8.500 8,528.65 8,275.85 PRODUCTION CASING 1 4.500 8.500 10,865.00 8,952.80 2 7/8" 2.875 4.125 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/18/2012 4:12:24PM Page 2 of 20 COMPASS 2003.16 Build 73 BAKER HUGHES Travelling Cylinder Report y aea.` uP INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-19-Slot 19 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB D Pad MD Reference: D-19B:@ 76.42ft(D-19B:) Site Error: 0.00ft North Reference: True Reference Well: D-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore D-19C Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 8 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB D Pad D-06-D-06-D-06 10,200.00 9,300.00 668.07 319.74 353.92 Pass-Major Risk D-06-D-06A-D-06A 10,250.00 9,275.00 492.24 244.85 274.18 Pass-Major Risk D-06-D-06APB1 -D-06APB1 9,712.34 9,400.00 1,040.76 218.93 826.77 Pass-Major Risk D-11 -D-11 -D-11 Out of range D-11 -D-11A-D-11A Out of range D-11 -D-11 B-D-11 B Out of range D-16-D-16-D-16 Out of range D-16-D-16A-D-16A Out of range D-17-D-17-D-17 Out of range D-17-D-17A-D-17A Out of range 0-17-D-17B-D-17B Out of range D-17-D-17B-D-17B wp05 Out of range D-18-D-18-D-18 Out of range D-18-D-18A-D-18A Out of range D-18-D-18A-D-18A wp4 Out of range D-18-D-18B-D-18A Out of range D-19-D-19-D-19 8,800.00 8,900.00 962.94 73.52 910.36 Pass-Major Risk D-19-D-19A-D-19A 8,800.00 8,900.00 962.92 73.52 910.35 Pass-Major Risk D-19-D-19B-D-19B 8,800.00 8,800.00 0.00 0.47 -0.43 FAIL-Major Risk D-20-D-20-D-20 Out of range D-21 -D-21 -D-21 Out of range D-22-D-22-D-22 Out of range D-22-D-22A-D-22A Out of range D-22-D-22APB1 -D-22APB1 Out of range D-22-D-22B-D-22B Out of range D-22-D-22B-D-22B WP-05 Out of range D-22-D-22C-D-22C 10,848.63 9,275.00 111.33 130.84 48.96 Pass-Major Risk D-23-D-23-D-23 Out of range D-23-D-23A-D-23A Out of range D-26-D-26-D-26 Out of range D-26-D-26A-D-26A Out of range D-26-D-26B-D-26B Out of range D-26-D-26B-Plan#6 Out of range D-27-D-27-D-27 Out of range D-27-D-27A-D-27A Out of range D-28-D-28-D-28 Out of range D-28-D-28A-D-28A Out of range D-28-D-28AL1 -D-28AL1 Out of range D-28-D-28B-D-28B Out of range D-28-D-28BPB1 -D-28BPB1 Out of range D-31 -D-31A-D-31A 9,380.00 11,325.00 706.31 107.76 598.97 Pass-Major Risk D-31 -D-31 B-Plan 3 8,987.86 11,467.00 691.34 149.46 564.52 Pass-Major Risk D-31A DIMS-D-31A-D-31A 9,380.00 11,325.00 706.37 107.69 599.11 Pass-Major Risk 0-33_DIMS-D-33-D-33 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/18/2012 4:12:24PM Page 3 of 20 COMPASS 2003.16 Build 73 Gilt BAKER HUGHES Travelling Cylinder Report by I NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-19-Slot 19 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB D Pad MD Reference: D-19B:@ 76.42ft(D-19B:) Site Error: 0.00ft North Reference: True Reference Well: D-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore D-19C Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 8 Offset TVD Reference: Offset Datum Offset Design PB D Pad- D-06-D-06-D-06 Offset Site Error: 0.00ft Survey Program: 103-CB-GYRO-MS Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +EI-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) (ft) (ft) (ft) 9,763.17 8,957.97 8,400.00 8,045.98 10.86 67.27 -24.37 925.78 -232.84 0.47 1,016.63 246.94 874.97 Pass-Major Risk 9,766.39 8,957.97 8,425.00 8,069.55 10.86 67.65 -23.88 933.99 -234.27 0.47 998.00 247.45 853.77 Pass-Major Risk 9,769.53 8,957.96 8,450.00 8,093.13 10.87 68.03 -23.34 942.17 -235.65 0.47 979.64 247.94 832.72 Pass-Major Risk 9,775.00 8,957.95 8,475.00 8,116.73 10.89 68.40 -23.05 950.32 -236.97 0.47 961.55 248.10 811.98 Pass-Major Risk 9,775.00 8,957.95 8,500.00 8,140.34 10.89 68.78 -22.05 958.45 -238.25 0.47 943.74 249.00 791.11 Pass-Major Risk 9,775.00 8,957.95 8,525.00 8,163.95 10.89 69.15 -21.02 966.57 -239.45 0.47 926.28 249.85 770.46 Pass-Major Risk 9,781.45 8,957.94 8,550.00 8,187.57 10.90 69.52 -20.72 974.69 -240.55 0.47 909.15 249.78 750.45 Pass-Major Risk 9,784.26 8,957.94 8,575.00 8,211.19 10.91 69.89 -19.93 982.81 -241.56 0.47 892.41 250.21 730.50 Pass-Major Risk 9,786.99 8,957.93 8,600.00 8,234.82 10.92 70.26 -19.08 990.94 -242.47 0.47 876.09 250.63 710.84 Pass-Major Risk 9,789.65 8,957.93 8,625.00 8,258.45 10.93 70.62 -18.18 999.05 -243.30 0.47 860.18 251.00 691.51 Pass-Major Risk 9,792.24 8,957.92 8,650.00 8,282.11 10.93 70.97 -17.23 1,007.10 -244.07 0.47 844.66 251.36 672.48 Pass-Major Risk 9,800.00 8,957.91 8,675.00 8,305.78 10.96 71.33 -16.85 1,015.09 -244.79 0.47 829.60 250.82 654.33 Pass-Major Risk 9,800.00 8,957.91 8,700.00 8,329.48 10.96 71.69 -15.48 1,023.03 -245.46 0.29 814.93 251.41 635.91 Pass-Major Risk 9,800.00 8,957.91 8,725.00 8,353.17 10.96 72.05 -14.05 1,031.00 -246.03 0.29 800.83 252.15 617.78 Pass-Major Risk 9,800.00 8,957.91 8,750.00 8,376.81 10.96 72.42 -12.57 1,039.12 -246.44 0.29 787.45 252.89 600.26 Pass-Major Risk 9,800.00 8,957.91 8,775.00 8,400.40 10.96 72.78 -11.03 1,047.38 -246.67 0.29 774.83 253.63 583.40 Pass-Major Risk 9,800.00 8,957.91 8,800.00 8,423.95 10.96 73.14 -9.44 1,055.79 -246.74 0.29 763.02 254.37 567.25 Pass-Major Risk 9,808.64 8,957.89 8,825.00 8,447.47 10.98 73.50 -8.81 1,064.25 -246.72 0.29 751.82 253.47 552.81 Pass-Major Risk 9,810.76 8,957.89 8,850.00 8,471.04 10.99 73.86 -7.37 1,072.60 -246.69 0.29 741.24 253.74 538.20 Pass-Major Risk 9,812.83 8,957.89 8,875.00 8,494.64 10.99 74.21 -5.86 1,080.84 -246.67 0.29 731.26 254.01 524.18 Pass-Major Risk 9,814.84 8,957.88 8,900.00 8,518.28 11.00 74.57 -4.31 1,088.98 -246.65 0.29 721.90 254.28 510.82 Pass-Major Risk 9,816.81 8,957.88 8,925.00 8,541.94 11.00 74.92 -2.71 1,097.04 -246.63 0.29 71323 254.51 498.21 Pass-Major Risk 9,825.00 8,957.86 8,950.00 8,565.61 11.03 75.26 -1.81 1,105.09 -246.59 0.29 705.37 253.40 487.59 Pass-Major Risk 9,825.00 8,957.86 8,975.00 8,589.28 11.03 75.60 0.11 1,113.13 -246.53 0.29 698.22 254.00 476.36 Pass-Major Risk 9,825.00 8,957.86 9,000.00 8,612.96 11.03 75.95 2.08 1,121.15 -246.46 0.29 691.89 254.61 466.04 Pass-Major Risk 9,825.00 8,957.86 9,025.00 8,636.63 11.03 76.31 4.08 1,129.20 -246.38 0.29 686.43 255.25 456.68 Pass-Major Risk 9,825.00 8,957.86 9,050.00 8,660.28 11.03 76.67 6.11 1,137.31 -246.32 0.29 681.91 255.89 448.39 Pass-Major Risk 9,825.00 8,957.86 9,075.00 8,683.90 11.03 77.03 8.16 1,145.50 -246.26 0.29 678.33 256.54 441.22 Pass-Major Risk 9,825.00 8,957.86 9,100.00 8,707.49 11.03 77.39 10.23 1,15376 -246.22 0.29 675.73 257.19 435.20 Pass-Major Risk 9,825.00 8,957.86 9,125.00 8,731.08 11.03 77.75 12.32 1,162.05 -246.18 0.29 674.07 257.83 430.33 Pass-Major Risk 10,175.00 8,957.28 9,150.00 8,754.68 14.19 78.12 44.44 1,170.31 -246.13 0.29 671.98 313.56 374.89 Pass-Major Risk 10,175.00 8,957.28 9,175.00 8,778.28 14.19 78.48 46.47 1,178.53 -246.06 0.29 669.14 314.63 368.42 Pass-Major Risk 10,184.68 8,957.26 9,200.00 8,801.90 14.33 78.85 47.35 1,186.72 -245.98 0.29 667.06 315.79 362.92 Pass-Major Risk 10,187.65 8,957.25 9,225.00 8,825.53 14.37 79.20 49.06 1,194.90 -245.89 0.29 665.96 316.82 358.79 Pass-Major Risk 10,19061 8,957.24 9,250.00 8,849.16 14.42 79.56 50.77 1,203.07 -245.81 0.29 665.75 317.83 355.89 Pass-Major Risk,CC 10,200.00 8,957.22 9,275.00 8,872.78 14.55 79.92 51.70 1,211.24 -245.74 0.29 666.52 318.73 354.42 Pass-Major Risk 10,200.00 8,957.22 9,300.00 8,896.41 14.55 80.27 53.76 1,219.41 -245.67 0.29 668.07 319.74 353.92 Pass-Major Risk,ES,SF 10,200.00 8,957.22 9,325.00 8,920.05 14.55 80.62 55.81 1,227.55 -245.59 0.29 670.53 320.72 354.70 Pass-Major Risk 10,200.00 8,957.22 9,350.00 8,943.72 14.55 80.97 57.84 1,235.60 -245.49 0.29 673.89 321.71 356.70 Pass-Major Risk 10,200.00 8,957.22 9,375.00 8,967.42 14.55 81.32 59.85 1,243.56 -245.37 0.29 678.12 322.69 359.91 Pass-Major Risk 10,207.59 8,957.19 9,400.00 8,991.14 14.66 81.67 60.92 1,251.43 -245.21 0.29 683.12 323.46 364.46 Pass-Major Risk 10,210.21 8,957.18 9,425.00 9,014.91 14.70 82.00 62.56 1,259.18 -245.05 0.29 688.95 324.28 370.08 Pass-Major Risk 10,212.76 8,957.17 9,450.00 9,038.74 14.74 82.33 64.19 1,266.75 -244.90 0.29 695.52 325.09 376.75 Pass-Major Risk 10,215.23 8,957.17 9,475.00 9,062.62 14.78 82.66 65.79 1,274.14 -244.75 0.29 702.79 325.88 384.42 Pass-Major Risk 10,225.00 8,957.13 9,500.00 9,086.56 14.92 82.98 66.47 1,281.35 -244.61 0.29 710.85 326.27 393.58 Pass-Major Risk 10,225.00 8,957.13 9,525.00 9,110.54 14.92 83.29 68.29 1,288.42 -244.47 0.29 719.47 327.10 403.07 Pass-Major Risk 10,225.00 8,957.13 9,550.00 9,134.54 14.92 83.60 70.07 1,295.42 -244.30 0.29 728.83 327.93 413.53 Pass-Major Risk 10,225.00 8,957.13 9,575.00 9,158.55 14.92 83.91 71.80 1,302.35 -244.10 0.29 738.90 328.76 424.91 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/18/2012 4:12:24PM Page 4 of 20 COMPASS 2003.16 Build 73 • Nati BAKER by HUGHES Travelling Cylinder Report 0 INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-19-Slot 19 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB D Pad MD Reference: D-19B:@ 76.42ft(D-19B:) Site Error: 0.00ft North Reference: True Reference Well: D-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore D-19C Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 8 Offset TVD Reference: Offset Datum Offset Design PB D Pad- D-06-D-06-D-06 Offset Site Error: 0.00ft Survey Program: 103-CB-GYRO-MS Rule Assigned:Major Risk Offset Well Error: O.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +NI-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ff) (ft) (ft) (ft) (°) (ft) (ft) (ft) (ft) (ft) (ft) 10,225.00 8,957.13 9,600.00 9,182.59 14.92 84.21 73.49 1,309.23 -243.89 0.29 749.67 329.58 437.17 Pass-Major Risk 10,225.00 8,957.13 9,602.64 9,185.13 14.92 84.25 73.66 1,309.96 -243.87 0.29 750.84 329.66 438.52 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/18/2012 4:12:24PM Page 5 of 20 COMPASS 2003.16 Build 73 TREE=" 6"CM/ WELLHEAD= MCEVOY D-1 9B _4-112"CH OMETBG&ANR E>70'@9325' """ 'ACTUATOR= BAKER C KB.ELEV= 76.4' BF.ELEV= 42.95' KOP= 4250' Max Angle= 95°@ 9566' Datum MD= 9076' Datum TV D= 8800'SS I , 2128' H4-1/2"HES X NIP,ID=3,813" 13-3/8"CSG,72#,L-80 BTRS,ID=12.347" H 2702' Minimum ID =3.725" 8515' GAS LIFT MANDRELS ST O TVD DEV TYPE VLV LTCH PORT DATE 4-1/2" HES XN NIPPLE Lii 6 2988 2988 1 M11GM DMY RK 0 09/20101 5 3729 3729 0 MMGM DMY RK 0 07/17/12 4 5270 5199 24 KBG2 DMY BK 0 07/17/12 9-5/8"X 7'BKR ZXP PKR —1 6079' 3 6600 6441 5 KBG2 DMY BK 0 09/20/01 2 7635 7470 7 KBG2 DMY BK 0 09/20/01 w!5 TIEBACK,ID=6.151" 1 8373 8198 9 KBG2 DMY BK 0 09/20/01 9-5M"X 7'BKR FLEX-LOCK H 6092' 1/ LNR HGR,ID=6.151" 9-5/8"MILLOUT VVINDOW(D-19B) 6231'-6247' PERFORATION SUMuMRY 8440' —14-1/2"HES X NIP,ID=3.813" REF LOG:SPERRY-SUN WM RESISTIVTY ON 09/16/01 ANGLE AT TOP PERF:60'@ 9270' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE IPIIIIw—uillIllg 8461' -7"X 4-1/2"BKR S-3 PKR, 2-7/8" 6 9270-9290 0 01/17/10 X // ID=3.875" 2-7/8" 6 9290-9320 0 04/18/08 2-7/8" 6 9325-9350 0 04/20/06 N�1� 2-7/8" 6 9325-9355 0 04/18/08 �111� 8494' -14-12"HES X NIP,ID=3.813" 2-7/8" 6 9380-9410 0 04/18/08 111. 2-1/2" 4 9750-10100 0 09/18/01 �111� g ' 8515' —1412"HES XN NIP,ID=3.725" htt 101/044 1111�111IN11 8527' —14117'WLEG,ID=3.958" 111111111111111 1111111 J1iL 1111k 8528' 7"X 4-1/7'BKR ZXP LTP 1111 1111 w!6'TIEBACK IO=4.408" I 1111 9-5/8"CSG,47#,L-80,ID=8.681" 8758' 'A 1111 L _—� • 11111111 8541' �7"X 4-1/2"BKR HMC LNR 11111111HGR,ID=4.410" 7"LNR,26#,L-80 U4S,.0383 bpf,ID=6.276" —1 9618' I ' 8548' —1412"XO SUB,ID=3.940" 4-12"TBG 12.6#,13CR-80,.0152 bpf,ID=3.958" 8526' I 7"LNR,26#,L-80, .0383 bpf,ID=6.276" 8694' 1 I I PBTD —I 10140' 1-....... , iii 4-1/2"LNR,12.6#,13CR 80 VAM TOP,.0152 bpf,ID=3.958" 10227' a: DATE REV BY COMIVENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05112/82 ORIGINAL COMPLETION 07/29/11 JJU PJC PULL WRP(07/14/11) WELL: D-19B 06/11/96 PAB SIDETRACK COMPLETION 09/20/11 JMO/PJC TREEC/O(09/16/11) P62MTNo: 201-1120 09/20/01 CHIKAK RIG SIDETRACK 11/09/11 CDJ/PJC GLV C/O(10/30/11) API No: 50-029-20707-02 04/26/08 D3MISV SET WRP/ADPERF(04/18/08) 07/19/12 CJN/JM) GLV GO(07/17/12) SEC 23,T11 N.R13E,3400'FSL&1692'FEL 05/06/08 PJC PERF CORRECTIONS 02/02/10 KJB/PJC PERFS(01/17/10) BP Exploration(Alaska) TFC 6"CNV D-1 9 C St 'NOTES:WELL ANGLE>70"@ 9325' "` VIELLHEAD= MCEVOY 4-1/2"CHROME TBG LNR"` ACTUATOR= BAKER C KB.REV= 76.4' Proposed CTD SidetrP-k BF.REV= 42.95' KOP= 4250' Max Angle= 95"@ 9566' Datum MD= —9076' Datum TVD- 8800'SS ' ' [ 2128' —14-1/2"HES X NP,D=3.813" 13-3/8"CSG,72#,L-80 BTRS,ID=12.347" —{ 2702' GAS LFT MANDRELS Minimum ID =3.725" @ 8515' ST ND TVD DEV TYPE VLV LTCH PORT DATE 4-112" HES XN NIPPLE A 6 2988 2988 1 MGM DMY RK 0 09/20/01 5 3729 3729 0 MGM DMY RK 0 07/17/12 4 5270 5199 24 KBG2 DMY BK 0 07/17/12 3 6600 6441 5 KBG2 DMY BK 0 09/20/01 9-5/8"X 7"BKR ZXP PKR —I 6079' 2 7635 7470 7 KBG2 DMY BK 0 09/20/01 w/6'TACK,ID=6.151" / 1 8373 8198 9 KBG2 DMY , BK 0 09/20/01 9-5/8"X 7"BKR FLEX-LOCK H 6092' LNR HGR,D=6.151" 9-5/8"MLLOUT WINDOW(D-19B) 6231'-6247' PERFORATION SU V1ARY 8440' H4-1/2"FES X NP,ID=3.813" REF LOG:SPERRY-SUN MWD RESISTIVTY ON 09/16/01 ANGLE AT TOP PERF:60"@ 9270' Note:Refer to Production DB for historical pert data L8494' —14-1/2"/2"HES X NIP,ID=3.813'I,,N N., SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9270-9290 0 01/17/10 8515' 4-1/2'HES XN NP,0=3.725' 2-7/8" 6 9290-9320 0 04/18/08 �'i t:HES viol 2-7/8" 6 9325-9350 0 04/20/06 X1114 2-7/8" 6 9325-9355 0 04/18/08 .111 8527' H4-1/2"WLEG,ID=3.958" 2-7/8" 6 9380-9410 0 04/18/08 4114 8528' J7'X 4-1/2'BKR ZXP LTP 2-1/2" 4 9750-10100 0 09/18/01 21 ��1i1 B I I w/6'TEBA CK,D=4.408" 'At' 8541' J7'X 4-1/2"BKR HMC LNR I1II HGR,D=4.410" Top of3-1/2"Liner&cement 8740' 9-5/8"CSG,47#,L-80,D=8.681" H 8758' AJ1' ,,,, 1/ 'x2- crossover -9700' 7"LNR,26#,L-80 U4S,.0383 bpf,ID=6.276" —I 9618' 4-112"TBG 12.64,13CR-80,.0152 bpf,ID=3.958' H 8526' 2-7/8"L-80 liner with ID @ 10,865' 7"LNR,264, L-80,.0383 bpf,ID=6.276" H 8694' 4 Top of 4-1/2"KB PKR Whipstock @ 8,802' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/12/82 ORIGINAL COMPLETION 07/29/11 JJU PJC PULL WFRP(07/14/11) WELL: D-19B 06/11/96 PAB SIDETRACK COMPLETION 09/20/11 JMO/PJC TREE C/O(09/16/11) PERAKNo: 201-1120 09/20/01 CHIKAK RIG SIDETRACK 11/09/11 CDJ/PJC GLV C/O(10/30/11) AIR No: 50-029-20707-02 04/26/08 DBIWSV SET WRP/ADPERF(04/18/08) 07/19/12 CJWJMD GLV C/O(07/17/12) SEC 23,T11 N,R13E,3400'FSL&1692'FEL 05/06/08 PJC PERF CORRECTIONS 07/24/2012 JCL CTD Sidetrack 02/02/10 KJB/PJC PERFS(01/17/10) BP Exploration(Alaska) r . C 411 '= .I uTa i mi m * E g 11 a n rc n 41 I- LLa g a « S a 411 � N IONE LL T O a O 7 - = I 41 ! i v . b o I I —\ ; , 1 re:--- ill —•m I I U 6 a` m $ k i i = I 1 — i 1 ° s U 1�4 _ I :i .1- f — a`= sa .s s. 1 C Q III 8 I ° 0 s �U a 11 m CI " II : I ICI J 1 Illi III U. g° 1 2_ I 11 11 Z '� 2 S ® 1111 v III v Q f I U �7 (I I IIZ I Q. O > > W 1 Q 1111 I g S° _ = I11 J § 0 . U I wLL �; U 11 U A A • CS ® III 1=ICI— Ii LU ILE F i 'I11 a a H a a L W m U 11 f 2[ /® El W Y iJ O t 01 1 Z i U O 1401 — ig 1 ___ti ton J I 7.iiii Q U1 m 1T I o I " Z 1 I 11111 a 1 S d 1 U 17 mampaa 1 �� Vin' mossori o� A 1 mo ■■ IIi 1 410 n l� all t1 I 11 11 " � 111 \ I til=U I T 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. TRANSMITTA LETTER CHECKLIST WELL NAME � PTD# 27,12- /J Z k/ Development Service Exploratory Stratigraphic Test Non-Conventional Well /09 FIELD:- e . POOL: -7JG --e— C< Check Box for Appropri, - etter/Paragraphs to be Included in Transm ttal 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. Rev:9/09/2011 III y O 0 N y O a m _ a Tv c . O , . te co,, , ,, , , . , , ' . of > , 0 , , , 1, z' O Q, , E, d N O �' 5 0 ai a�' ,a a ' u, = I o v a d 3 CO 92 >, o. o. , a 3 �, a ° Ell a a 'C N. c• a' of � co a• O o 0, Y �, a $ > 8 a) (p o ..t $y c �) �, 0. 2 o o _ o, a rn E. o o) on E m. w, r O e. 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