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Home My WebLink About215-2167. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU C-21A Replace LTP, Ext Add Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-216 50-029-20753-01-00 11991 Surface Intermediate Production Liner Liner 9016 2636 8451 992 969 3057 10565 13-3/8" 9-5/8" 7" 3-1/2" 2-3/8" 9013 34 - 2670 33 - 8484 7968 - 8960 7991 - 8960 8934 - 11991 34 - 2670 33 - 8359 7882 - 8809 7903 - 8809 8784 - 9016 11840, Unknown 2670 4760 7020 10530 11780 10565, 10600, 11880 5380 6870 8160 10160 11200 10281 - 11879 3-1/2" 9.2# / 5-1/2" 17# x 4-1/2" # 13cr80 / L80 31 - 7861 / 7857 - 8049 9020 - 9005 Conductor 80 20" x 30" 35 - 115 35 - 115 4-1/2" Baker S3 Packer 7884, 7805 7745, 7884 7679, 7805 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028285, 0028305 31 - 7784 / 7780 - 7956 N/A N/A 87 732 11506 3151 44 84 750 500 60 200 324-445 13b. Pools active after work:Prudhoe Oil 5-1/2" Otis Packer 7745, 7679 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed By Grace Christianson at 3:05 pm, Nov 19, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.11.19 14:02:20 - 09'00' Torin Roschinger (4662) DSR-11/21/24WCB 2-11-2025 RBDMS JSB 112724 ACTIVITY DATE SUMMARY 8/10/2024 ***WELL S/I ON ARRIVAL*** RAN 3-1/2'' GS & S/D HIGH @ 50' (hydrates on tools) RAN 2.50'' G-RING TO 2500'SLM w/NO ISSUES DRIFTED TO DREAM CATCHER w/ 3-1/2''BLB, 2.80'' G-RING. PULLED 2.81'' DREAM CACHER FROM 7771'MD (recovered small piece of grapple) ***WELL LEFT S/I ON DEPARTURE*** 9/13/2024 LRS CTU 1, 1.5" .134 WT Blue Coil. Job Objective: Set CIBP and Ext. Adperf MIRU. Pump 1" drift ball and perform weekly BOP test and TIW valve/SJ 250/4000psi - pass. Bump up test CTC against the brass. Make up NS MHA and 1.75" drift BHA. ***Job Continued on 9/14/2024*** 9/14/2024 LRS CTU 1, 1.5" .134 WT Blue Coil. Job Objective: Set CIBP and Ext. Adperf Function tested BOPs upon installation. Load well with 180 bbl of 1% KCL with safelube. RIH with 1.75" drift assembly down to 11015. Bump test H2s and LEL monitors. RIH with naked HES memory GR/CCL to 10700', paint RED flag 10300', POOH. RIH with Northern Solutions 2-3/8" CIBP. Set CIBP at 10600. Stack weight on plug to confirm set. PUH and circ out well. attempt to PT CIBP and the well has a sustained LLR of .5bpm at 925 psi. Relay to OE and decision to set another plug. POOH pumping pipe displacement. ***Job Continued on 9/15/2024*** 9/15/2024 LRS CTU 1, 1.5" .134 WT Blue Coil. Job Objective: Set CIBP and Ext. Adperf Make up and RIH with second 2-3/8" CIBP. Set CIBP at 10565. Circ bottoms up and Re-PT well. LLR=0.5bpm at 1088psi. Job cancelled as per OE for future troubleshooting. Well freeze protected with 23 bbl of diesel. RDMO. ***Job Complete*** 9/29/2024 T/I/O = 2460/760/VAC. Temp = SI. T FL (SL). No AL. T FL inconclusive, unable to see past LTP @ 8923'. SV, WV, SSV = C. MV = O. IA, OA = OTG. 00:30 10/2/2024 *** WELL S/I ON ARRIVAL *** RAN 2-3/8" BRUSH & 1.75" GAUGE RING TO LTP AT 8,923' MD (unable to skip past) RAN 2-3/8" BRUSH & 1.65" GAUGE RING TO 9,000' SLM (work tight spots at 8,912' & 8,922' slm) RAN 2-3/8" BRUSH, 1.75" CENT & BULL NOSE TO 9,000' SLM (all clear) T-BIRD LOADED TBG W/ 88 BBLS CRUDE SET 1.781" RX-PLUG AT 8,932' MD T-BIRD ATTEMPTED MIT-T TO 2000 psi (LLR ~2200 psi at 1 bpm) ***CONTINUE ON 10/3/24 WSR*** 10/2/2024 T/I/O=2401/732/0 Temp=S/I (Assist SL with load and test) Pumped 88 bbls of Crude down the TBG to load well. Further pumped 10 bbls of crude down the TBG to establish a liquid leak rate of .5 bpm at 1785 psi. *********WSR Continued on 10-03-2024******** Daily Report of Well Operations PBU C-21A Set CIBP at 10565Make up and RIH with second 2-3/8" CIBP Daily Report of Well Operations PBU C-21A 10/3/2024 ***WSR Continued from 10-02-2024*** (TFS unit 1 Assist S-Line with LDL) Pumped 109 bbls of Crude down the TBG to assist S-Line with LDL. MIT-T PASSED To 1902 PSI. Pumped 4 BBLS of crude down TBG to reach max applied pressure of 2000 PSI with a target of 1800 PSI. 1st 15 minutes TBG lost 72 PSI. 2nd 15 minutes TBG lost 26 PSI. Total loss of 98 PSI in a 30 minute test. Tags hung on master valve. SL in control of well upon departure. Final WHPS=0/760/0 10/3/2024 ***CONTINUED FROM 10/2/24 WSR*** RAN HES LDL FROM 8,909' - 7,700' SLM PER PROGRAM (leak at LTP) SET 3-1/2" WIDEPAK LTTP AT 8,923' MD T-BIRD PERFORMED PASSING MIT-T TO 2000 psi PULLED 3-1/2" WIDEPAK LTTP AT 8,923' MD PULLED & RESET 1.781" RX PLUG AT 8,932' MD T-BIRD ATTEMPTED MIT-T (pressure rapidly falls off) PULLED 1.781" RX PLUG AT 8,932' MD PULLED 3-1/2" WIDEPAK LTP UP TO 8,822' SLM (fishing neck stripped) ***CONTINUE ON 10/4/24 WSR*** 10/4/2024 ***CONTINUED FROM 10/3/24 WSR*** (Perforating) PULLED 3-1/2" WIDEPAK LTP AT 8,821' SLM (missing 2"x2" piece of fishing neck) RAN 1.75" MAGNET TO DEPLOYMENT SLEEVE AT 8,934' MD (unable to get past - no recovery) RAN 8' x 1.75" & BULLNOSE TO 8,943' SLM (unable to get further - tools stick) RAN 8' x 1.75" & 1.75" MAGNET TO DEVIATION AT 9,194' SLM (work past 8,943' spot - recover two metal chunks) RAN 5' x 1.69" TO 9,197' SLM (no issues - all clear) RAN HES 24 ARM CALIPER FROM 9,223' - 7,900' SLM (good data) RAN 3-1/2" BRUSH, 2.73" CENT & 2.25" BRUSH TO DEPLOYMENT SLEEVE AT 8,934' MD (ring on cent) RAN 3-1/2" LTP PKR DRIFT TO DEPLOYMENT SLEEVE AT 8,934' MD (pins smeared - ring on no-go) ***CONTINUE ON 10/5/24 WSR*** 10/5/2024 T/I/O 195/758/0 Temp S/I A/SL MIT-T PASSED to 2208 psi. (Perforating) Pumped 25.2 bbls of crude to fluid pack and achieve test pressure of 2246 psi. First 15 minutes TBG lost 28 PSI. Second 15 minutes TBG lost 7 PSI for a total loss of 35 PSI in a 30-minute test. Bled down to 500 psi. Pumped 9 BBLS of 60/40 and 112 BBLS of crude down Flowline for freeze protect. Final WHPS=500/756/0 SL in control of well upon departure. Flags and tags hung. DSO notified of departure. 10/5/2024 ***CONTINUED FROM 10/4/24 WSR*** (Perforating) SET NS 350-272 MONO-PAK LTP W/ 2.25" PTSA IN DEPLOYMENT SLEEVE AT 8,934' MD (top of ltp at 8,920' MD) PERFORMED PASSING MIT-T TO 2,000psi PULLED 1.781" RSG FROM LTP AT 8,922' SLM DRIFTED WITH 10' x 1.56" DUMMY GUNS TO DEVIATION AT 9,223' SLM ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** (g) SET NS 350-272 MONO-PAK LTP W / 2.25" PTSA IN DEPLOYMENT SLEEVE AT 8,934' MD Daily Report of Well Operations PBU C-21A 11/13/2024 CTU 1 Job Scope Extended Adperf MIRU Bump test LEL and H2s monitors. Function test BOPs. PT safety Joint. RIH w/drift unable to get past 9296' attempt to clean area no luck. POOH pick up venturi. Looks like possible LTP debris. ******* Continued on 11/14/24 ***** 11/14/2024 CTU #1 Job Scope Extended Adperf Continued from 11/13/24 POOH to PU venturi from BOT. MU BOT BHA and 1.69" Venturi RIH. Tag TOL @ 8916' CTM (8920' MD). Venturi into liner 10 fpm from 9070', 1.3 BPM @3700 psi.. Tag @ 9537', Work past and continue in hole. Tag CIBP @ 10567' CTM (10565' MD). POH @ 90%. No recovery in venturi. RBIH w/ 1.69" MHA, 1.75" x 4' stinger, and 1.76" OD nozzle. OAL 7'. Tag @ 10567' Corr to 10565'. POH circulating to 1% w/ SL, Paint flag @ 10191.5' EOP. Continue POH @ 90%. Swap to 60/40 @ 3600' and FP coil and well from 500'. Flow check well - no flow. Fill across top w/ 60/40 and start trip sheet. PJSM. Start running guns. Well Control Drill. Cont. running guns. Tag plug @ 10565' correct to Bottom shot depth 10563.98. PUH to perf interval shot 10.281' to 10,336' and 10,380' to 10,495' w/ 1.56" Millenniun guns 3.4 Grams 0.23" EHD 8.3" Pen. 60 degree 6 SPF POOH at surface confirm guns fired recovered 1/2" ball confirm no flow Finish undeploying guns. ********** Continued on 11/15/24********** 11/15/2024 CTU #1 Job Scope Extended Adperf * Continued ** All guns undeployed well secured. 43 bbls 60/40 in well for freeze protect. RDMO to C-31 ****** Job Complete ***** perfgg g g@ interval shot 10.281' to 10,336' and 10,380' to 10,495' 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU C-21A Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-216 50-029-20753-01-00 341J ADL 0028285, 0028305 11991 Surface Intermediate Production Liner Liner 9016 2636 8451 992 969 3057 11880 13-3/8" 9-5/8" 7" 3-1/2" 2-3/8" 9005 34 - 2670 33 - 8484 7968 - 8960 7991 - 8960 8934 - 11991 2425 34 - 2670 33 - 8359 7882 - 8809 7903 - 8809 8784 - 9016 11840, Unknown 2670 4760 7020 10530 11780 11880 5380 6870 8160 10160 11200 10662 - 11879 3-1/2" 9.2# / 5-1/2" 17# x 4-1/2" 12.6#13cr80 / L80 31 - 7861 / 7857 - 80499014 - 9005 Conductor 80 20" x 30" 35 - 115 35 - 115 4-1/2" Baker S3 Packer 5-1/2" Otis Packer 7745, 7679 7884, 7805 Date: Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY 8/20/2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov No SSSV Installed By Grace Christianson at 9:05 am, Aug 01, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.01 08:49:22 - 08'00' Torin Roschinger (4662) 324-445 MGR01AUG24 A.Dewhurst 05AUG24 10-404 DSR-8/2/24JLC 8/7/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.08.07 10:52:20 -08'00' 08/07/24 RBDMS JSB 080824 CT Plug and Ext Perf Well: C-21A Well Name:C-21A API Number:50-029-20753-01 Current Status:Operable producer – HGOR Pad:C-Pad Estimated Start Date:8/20/2024 Rig:SL, CT Reg. Approval Req’d?10-403/10-404 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:215216 First Call Engineer:Michael Hibbert Contact:907-903-5990 Current Bottom Hole Pressure:3250 psi Estimated KWF:7.2 ppg Use seawater or 1% KCL MPSP:2425 psi (BHP - .1psi/ft gas gradient + safety factor) Max Dev:96 deg At 9457’ MD Min ID:1.78” 8932’ @ LTP Tie In Log: Baker RPM – 4/4/2016 Brief Well Summary: C-21A has historically been a good performing gravity drainage well. Recently a plug was set in August 2022 and stage 3 perforations were added which performed very well. In September 2024 the plug was milled below the stage 3 perfs. This plug mill was not successful and the well went HGOR very quickly. Objective: CT will isolate all current perforations and then deploy extended perforation guns and shoot 170’ of net charges over a 214’ interval in Zone 1A and Zone 2A. Procedure: Slickline – 1. Pull dreamcatcher from 7,771’. Coiled Tubing Drift and Flag – 1.5” CT 1. MU GR/CCL. a. CT was in the liner fishing NS setting adapter and milling out a plug on 6/30/24 and encountered no issues getting into the liner or tagging across the perforations. 2. RIH beyond plug setting depth. Flag pipe for plug and perf depths and pull correlation log. 3. Correlate with attached log information. a. Correct flag and send to Jeff Nelson and OE for confirmation. Coiled Tubing Plug Set 1. MU 2-3/8” CIBP 2. RIH and set at 10,600’ 3. Tag plug to verify a good set 4. POOH Coil – Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating CT Plug and Ext Perf Well: C-21A bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 5. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 6. Bullhead 1.2x wellbore volume ~106 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 88 bbls b. 3-1/2” Tubing – 7,847’ X .0087 bpf = 69 bbls c. 5-1/2” Liner – 90’ X .0.0232bpf = 2 bbls d. 4-1/2” Liner – 107’ X .0152 bpf = 2 bbls e. 3-1/2” Liner – 932’ X .0087 bpf = 8 bbls f. 2-3/8” Liner – 1739’ X .0039 bpf = 7 bbls 7. At surface, prepare for deployment of TCP guns. 8. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. g.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 10.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 1.56” Millenium guns or similar Perf Interval (tie-in depths) Lengths Total Gun Length Weight of Gun (lbs) Run #1 10,281’ – 10,336’ – gun 10,336’ – 10,380’ –blank 10,380’ – 10,495’ – gun 55’ - loaded 44’ - blank 115’ - loaded 214’~775 lbs (3.62 ppf) 11. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 13. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 14. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 15. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 16. RDMO CTU. Make up PCE. - mgr CT Plug and Ext Perf Well: C-21A 17. Turn well over to Operations POP. Attachments: x Wellbore Schematic x Proposed Schematic x Tie-In Log x BOPE Schematic x Standing Orders x Equipment Layoutdiagram x Sundry Change Form CT Plug and Ext Perf Well: C-21A Current Schematic: CT Plug and Ext Perf Well: C-21A Proposed Wellbore Schematic Proposed Perforations C C C C C C C Plug Set Depth ~10,600’ CT Plug and Ext Perf Well: C-21A Tie-in Log CT Plug and Ext Perf Well: C-21A Perf – 10,281’-10,336’ Blank – 10,336’-10,380’ Perf – 10,380’-10,495’ Plug Set – 10,600’ CT Plug and Ext Perf Well: C-21A BOP Schematic CT Plug and Ext Perf Well: C-21A CT Plug and Ext Perf Well: C-21A CT Plug and Ext Perf Well: C-21A Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Claire Mayfield Subject:20220803 1337 APPROVED Change Add Step to C-21A (PTD 215-216) Extended Adperf Date:Wednesday, August 3, 2022 1:41:32 PM Attachments:Sundry_322-221_042722.pdf Claire, Hilcorp is approved to proceed with changes on Sundry 322-221 as described below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Add Step to C-21A (PTD 215-216) Extended Adperf Hi Mel, As discussed over the phone, on well C-21A (PTD 215-216), we are planning to set a CIBP and conduct an extended adperf that we have under sundry number 322-221. We would like to add a step to the beginning of the procedure to mill the existing CIBP and push it down prior to setting a new CIBP and then perforating. Please let me know if you have any further questions on this change or if we have your approval. Thanks, Claire Mayfield Hilcorp Energy Company Prudhoe Bay West – Operations Engineer Office: (907) 564-4375 Cell: (713) 443-3631 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU C-21A Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-216 50-029-20753-01-00 11991 Surface Intermediate Production Liner Liner 9016 2636 8451 992 969 3057 11880 13-3/8" 9-5/8" 7" 3-1/2" 2-3/8" 9005 34 - 2670 33 - 8484 7968 - 8960 7991 - 8960 8934 - 11991 34 - 2670 33 - 8359 7882 - 8809 7903 - 8809 8784 - 9016 11840, Unknown 2670 4760 7020 10530 11780 11880 5380 6870 8160 10160 11200 10662 - 11879 3-1/2" 9.2# / 5-1/2" 17# x 4-1/2" # 13cr80 / L80 31 - 7861 / 7857 - 8049 9014 - 9005 Conductor 80 20" x 30" 35 - 115 35 - 115 4-1/2" Baker S3 Packer 7884, 7805 7745, 7884 7679, 7805 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028285, 0028305 31 - 7784 / 7780 - N/A N/A 230 267 24077 23953 34 48 650 1450 1110 1040 N/A 13b. Pools active after work:Prudhoe Oil 5-1/2" Otis Packer 7745, 7679 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed By Grace Christianson at 1:46 pm, Jul 08, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.07.08 13:21:17 - 08'00' Torin Roschinger (4662) RBDMS JSB 071124 WCB 9-30-2024 DSR-7/8/24 ACTIVITY DATE SUMMARY 6/30/2024 LRS CTU #1, 1.5" CT 0.134" WT Blue Coil, Job Scope: Fish NS Setting Adapter, Mill CIBP. MIRU LRS CTU #1. M/U Fishing BHA w/hydraulic centralizer & 1.52" taper tap. BH 3 bbl meoh spear followed by 100 bbls of KCI w/Safelube. RIH w/BHA. Tagged 11,240 multiple times, POH. No recovery. No Itco spear option available. MU and RIH w/ YJ 1.69" CTC, Checks, Jar, Dico., Hyd Centralizer, and 1.70" Venturi junk basket. OAL 17.50'. Tag @ 11,242'. PU to 11140' and venturi down to fish 1 bpm @ 4000 psi. Tag fish @ 11240' and recip 30' above fish 3X and hover on fish. SD pump and POH. No recovery in Venturi. ***Cont on 7/1/24*** 7/1/2024 LRS CTU#1 1.5" Blue Coil C-21: FISH NS SETTING ADAPTER, MILL CIBP No recovery with Venturi. No Itco spear option available. MU and RIH w/ YJ 1.69" CTC, Checks, Jar, Disco., Hyd Centralizer, and 1.70" Venturi junk basket. OAL 17.50'. Tag @ 11,242'. PU to 11140' and venturi down to fish 1 bpm @ 4000 psi. Tag fish @ 11240' and recip 30' above fish 3X and hover on fish. SD pump and POH. No recovery in Venturi. RIH w/1.75" magnet. Tag 11,242' x 3 times. Pooh w/BHA, no recovery. M/U & RIH w/1" pocket brush, tagged @ 11,242' 3X. Pooh w/BHA. Recovered NS setting adapter on pocket brush. M/U & RIH w/YJ milling BHA w/Tempress and 1.76" Venturi Burn Shoe. Milled CIBP @ 11,240' ctm and push down to 11,850' ctm (11840' MD) . Pooh w/BHA. CIBP core not recovered - bttm perf @ 11840'. Dream catcher not required. RD and move to F-05. ***Job Complete*** 7/3/2024 ***WELL SHUT IN ON ARRIVAL*** RAN KJ, 3-1/2" BLB, 2.80" GRING SET 3-1/2" DREAM CATCHER @ 7771' MD RAN CHECK SET (pin sheared, good set) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU C-21A Milled CIBP is correctly shown on the WBS below. -WCB g Milled CIBP @ 11,240' ctm and push down to 11,850' ctm (11840' MD) . 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ƐƐƵƌĞŝƐƐĞĞŶŝŵŵĞĚŝĂƚĞůǇĂĨƚĞƌ ƉĞƌĨŽƌĂƚŝŶŐ͕ŝƚǁŝůůĞŝƚŚĞƌďĞŬŝůůĞĚďǇďƵůůŚĞĂĚŝŶŐǁŚŝůĞWKK,ŽƌĐŝƌĐƵůĂƚŝŶŐďŽƚƚŽŵƐƵƉƚŚƌŽƵŐŚƚŚĞ ƐĂŵĞƉŽƌƚƚŚĂƚŽƉĞŶĞĚƚŽƐŚĞĂƌƚŚĞĨŝƌŝŶŐŚĞĂĚ͘ ϭ͘ D/ZhŽŝůĞĚdƵďŝŶŐhŶŝƚǁͬ ϭ͘ϱ͞ ĐŽŝůĂŶĚƐƉŽƚĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞ Ŷƚ͘ Ϯ͘ ĨƚĞƌDhD,ĂŶĚƉƵůů ƚĞƐƚŝŶŐƚŚĞd͕ƚĂŐͲƵƉŽŶƚŚĞdƐƚƌŝƉƉĞƌƚŽĞŶƐƵƌĞ,ĐĂŶŶŽƚƉƵůůƚŚƌŽƵŐŚ ƚŚĞďƌĂƐƐƵƉŽŶWKK,ǁŝƚŚŐƵŶƐ͘ ϯ͘ ZhW'>ĨŽƌ<ŝĐŬŽĨĨ ϰ͘ Dh 'Zͬ>ĂŶĚĚƌŝĨƚ ĨŽƌϮͲϯͬϴ͟Z/W͘ ϱ͘ Z/, ĂŶĚŐĞŶƚůǇƚĂŐ/WĂƚϭϭ͕ϲϴϬ͟ >ŽŐ ƵƉ͕ƐƚŽƉƉŝŶŐƚŽƉĂŝŶƚĨůĂŐ͘ Ă͘ /ĨƉůƵŐŵŽǀĞƐŽƌŝƐƚĂŐŐĞĚŽĨĨĚĞƉƚŚ͕ ǁĞŵĂǇƐĞƚĂŶŽƚŚĞƌƉůƵŐ ď͘ /ĨĂŶŽƚŚĞƌƉůƵŐŝƐƐĞƚΕϭϭ͕ϲϬϬĂǀŽŝĚŝŶŐĐŽůůĂƌƐ͕ǁĞǁŝůůƉĞƌĨŽƌŵϲͲϴŚŽƵƌƚĞƐƚƚŽǀĞƌŝĨǇŐĂƐ ƌĂƚĞƐŝŶƚŚĞƚĞƐƚƐĞƉĂƌĂƚŽƌ ƚŽ ĚĞƚĞƌŵŝŶĞŝĨŶĞǁƉĞƌĨŽƌĂƚŝŽŶƐǁŝůůďĞĂĚĚĞĚ͘ ϲ͘ WKK,͕ĐŽŶĨŝƌŵŐŽŽĚĚĂƚĂ͕ŽďƚĂŝŶĐŽƌƌĞĐƚŝŽŶ͘ ϳ͘ ƵůůŚĞĂĚ ΕϭϱϬ ďďůƐŽĨ ϴ͘ϰƉƉŐ ϭй<ůŽƌ ϴ͘ϱƉƉŐ ƐĞĂǁĂƚĞƌĚŽǁŶƚŚĞƚƵďŝŶŐƚŽƚŚĞĨŽƌŵĂƚŝŽŶ͘ Ă͘ tĞůůďŽƌĞǀŽůƵŵĞƚŽƚŽƉƉĞƌĨс ϴϵďďůƐ Ž ĂĚĚŶĞǁ ƉĞƌĨƐŽ ŝƐŽůĂƚĞĞǆŝƐƚŝŶŐƉĞƌĨŽƌĂƚŝŽŶƐƚ WůƵŐĂŶĚ ĚĚ WĞƌĨ ͲϮϭ Wd͗ϮϭϱͲϮϭϲ ď͘ ϯͲϭͬϮ͟dƵďŝŶŐ ʹ ϳϴϰϳ͛ǆϬ͘ϬϬϴϳďƉĨсϲϴďďůƐ Đ͘ ϰͲϭͬϮ͟dƵďŝŶŐ ʹ ϭϲ͛ǆϬ͘ϬϭϱϮďƉĨсϬ͘ϮϱďďůƐ Ě͘ ϱͲϭͬϮ͟ dƵďŝŶŐ ʹ Ϯϯ͛ǆϬ͘ϬϮϯϮďƉĨсϬ͘ϱďďůƐ Ğ͘ ϰͲϭͬϮ͟ dƵďŝŶŐ ʹ ϭϬϳ͛ǆϬ͘ϬϭϱϮďƉĨсϭ͘ϲďďůƐ Ĩ͘ ϯͲϭͬϮ͟ >ŝŶĞƌ ʹ ϵϯϮ͛ǆϬ͘ϬϬϴϳďƉĨсϴďďůƐ Ő͘ ϮͲϯͬϴ͟>ŝŶĞƌ ʹ Ϯϳϱϳ͛ǆϬ͘ϬϬϯϵďƉĨсϭϭďďůƐ ϴ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘&ƌĞĞǌĞƉƌŽƚĞĐƚƚƵďŝŶŐĂƐŶĞĞĚĞĚ͘ ϵ͘ Dh ϮͲϯͬϴ͟ Z/W ĂŶĚZ/,ĂŶĚĐŽƌƌĞĐƚƚŽĨůĂŐ͘ ϭϬ͘ ŽŶƚĂĐƚK ůĂŝƌĞDĂǇĨŝĞůĚĂƚϳϭϯͲϰϰϯͲϯϲϯϭ Žƌ'ĞŽ :ĞĨĨEĞůƐŽŶ ϯϬϳͲϳϲϬͲϴϬϲϱ ƉƌŝŽƌƚŽƐĞƚƚŝŶŐ ƉůƵŐͬƉĞƌĨŽƌĂƚŝŶŐĨŽƌĨŝŶĂůĂƉƉƌŽǀĂůŽĨƚŝĞͲŝŶƐ ϭϭ͘ ^ĞƚƉůƵŐŵŝĚͲũŽŝŶƚĂƚцϭϭ͕ϮϮϬ͛DĂŶĚƚĞƐƚƚŽϭϬϬϬƉƐŝ͘WKK,͘ ϭϮ͘ ƚƐƵƌĨĂĐĞ͕ƉƌĞƉĂƌĞĨŽƌĚĞƉůŽǇŵĞŶƚŽĨdWŐƵŶƐ͘ ƐƐƵƌĞĞǆĐĞƐƐĨůƵŝĚƐĂǀĂŝůĂďůĞŝĨŶĞĞĚĞĚƚŽŬĞĞƉŚŽůĞ ĨƵůů͘ ϭϯ͘ ŽŶĨŝƌŵ ǁĞůůŝƐĚĞĂĚ͘ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨ ƚŽƌĞƚƵƌŶƐƚĂŶŬ͘<ŝůůǁĞůůǁͬϴ͘ϰƉƉŐ ϭй<ůŽƌ ϴ͘ϱƉƉŐ ƐĞĂǁĂƚĞƌ ĂƐŶĞĞĚĞĚ͘ DĂŝŶƚĂŝŶĐŽŶƚŝŶƵŽƵƐŚŽůĞĨŝůůƚĂŬŝŶŐƌĞƚƵƌŶƐ ƚŽƚĂŶŬ ƵŶƚŝůůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶŝƐ ƌĞĞƐƚĂďůŝƐŚĞĚ͘ &ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽǇŝŶŐƉĞƌĨŐƵŶƐƚŽĞŶƐƵƌĞƚŚĞǁĞůů ƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐĨůŽǁ͘ ϭϰ͘ΎWĞƌĨŽƌŵĚƌŝůůďǇƉŝĐŬŝŶŐƵƉƐĂĨĞƚǇũŽŝŶƚǁŝƚŚd/tǀĂůǀĞĂŶĚƐƉĂĐĞŽƵƚďĞĨŽƌĞDhŐƵŶƐ͘ZĞǀŝĞǁǁĞůů ĐŽŶƚƌŽůƐƚĞƉƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐŵĂŬĞƵƉŽĨdWŐƵŶ ƐƚƌŝŶŐ͘KŶĐĞƚŚĞƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞŚĂǀĞďĞĞŶƐƉĂĐĞĚ ŽƵ ƚ͕ŬĞĞƉƚŚĞƐĂĨĞƚǇũŽŝŶƚͬd/t ǀĂůǀĞ ƌĞĂĚŝůǇĂĐĐĞƐƐŝďůĞŶĞĂƌƚŚĞǁŽƌŬŝŶŐƉůĂƚĨŽƌŵĨŽƌƋƵŝĐŬĚĞƉůŽǇŵĞŶƚŝĨŶĞĐĞƐƐĂƌǇ͘ Ă͘ƚƚŚĞďĞŐŝŶŶŝŶŐŽĨĞĂĐŚũŽď͕ƚŚĞĐƌŽƐƐŽǀĞƌͬƐĂĨĞƚǇũŽŝŶƚŵƵƐƚďĞƉŚǇƐŝĐĂůůǇDhƚŽƚŚĞƉĞƌĨ ŐƵŶƐŽŶĞƚŝŵĞƚŽĐŽŶĨŝƌŵƚŚĞƚŚƌĞĂĚƐĂƌĞĐŽŵƉĂƚŝďůĞ͘ ϭϱ͘ ƌĞĂŬůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂƚYd^ĂŶĚďĞŐŝŶŵĂŬĞƵƉŽĨdWŐƵŶƐ ƉĞƌ dĂďůĞ ϭ͗ ͲϮϭ WƌŽƉŽƐĞĚ ĚͲWĞƌĨ 'ƵŶZƵŶ ďĞůŽǁ͘ ŽŶƐƚĂŶƚůǇŵŽŶŝƚŽƌĨůƵŝĚƌĂƚĞƐƉƵŵƉĞĚŝŶĂŶĚĨůƵŝĚ ƌĞƚƵƌŶƐŽƵƚŽĨƚŚĞǁĞůů͘&ůƵŝĚƐŵĂŶͲ ǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽǇŝŶŐƉĞƌĨŐƵŶƐƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽ ĞǆĐĞƐƐĨůŽǁ͘ 'ƵŶ ZƵŶη WĞƌĨdŽƉ WĞƌĨŽƚƚŽŵ WĞƌĨ >ĞŶŐƚŚ tĞŝŐŚƚŽĨ 'ƵŶƐ;ůďƐͿ ϭ цϭϬ͕ϲϲϮ цϭϬ͕ϴϴϮ цϮϮϬ ϭϭϬϬ dŽƚĂů цϮϮϬ ϭϭϬϬ dĂďůĞ ϭ͗ ͲϮϭ WƌŽƉŽƐĞĚ ĚͲWĞƌĨ 'ƵŶZƵŶ ϭϲ͘ Z/,ǁŝƚŚ'ƵŶZƵŶϭ ĂŶĚ ĐŽƌƌĞůĂƚĞ ƚŽĨůĂŐ͘ ŽŶƚĂĐƚK ůĂŝƌĞDĂǇĨŝĞůĚ ϭ;ϳϭϯͿ ϰϰϯͲϯϲϯϭ ŽƌEŽĞůEŽĐĂƐ Ăƚ ϭ;ϵϬϳͿϵϰϳͲϵϱϯϯƉƌŝŽƌƚŽƉĞƌĨŽƌĂƚŝŶŐĨŽƌĨŝŶĂůĂƉƉƌŽǀĂůŽĨƚŝĞŝŶƐ͘ ϭϳ͘ WĞƌĨŽƌĂƚĞ͘ Ă͘ EŽƚĞĂŶǇƚƵďŝŶŐƉƌĞƐƐƵƌĞĐŚĂŶŐĞŝŶt^Z͘ ϭϴ͘ ĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐ͕Wh,ƚŽƚŽƉŽĨůŝŶĞƌŽƌŝŶƚŽƚƵďŝŶŐƚĂŝůƚŽĞŶƐƵƌĞĚĞďƌŝƐĚŽĞƐŶ͛ƚĨĂůůŝŶŽŶƚŚĞŐƵŶƐĂŶĚ ƐƚŝĐŬƚŚĞ,͘ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚĂŶĚƌĞͲŬŝůůŝĨŶĞĐĞƐƐĂƌǇďĞĨŽƌĞƉƵůůŝŶŐƚŽƐƵƌĨĂĐĞ͘ 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Chmielowski Date: 2021.12.03 09:46:29 -09'00' RBDMS HEW 12/7/2021 WůƵŐĂŶĚ ĚĚ WĞƌĨ ͲϮϭ Wd͗ϮϭϱͲϮϭϲ tĞůůEĂŵĞ͗ͲϮϭ dh WůƵŐΘĚĚ WĞƌĨ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϬϳϱϯͲϬϭ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗WƌŽĚƵĐŝŶŐ ZŝŐ͗dhΘ^ƵƌĨĂĐĞ ĞƉůŽǇĞĚdW'ƵŶƐ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϭϮͬϭϱͬϮϬϮϭ ƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ͗ϯĚĂǇƐ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛ƐƚĚ͍EͬĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗Eͬ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ďďŝĞĂƌŬĞƌ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϭϱͲϮϭϲ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗EŽĞůEŽĐĂƐ ;ϵϬϳͿ ϮϮϵͲϵϱϯϮ;DͿ ;ϵϬϳͿ ϱϲϰͲϱϮϳϴ;ŽͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗:ŽŚŶŽŶĚŝŽ ϲϬϮ͘ϯϳϯ͘Ϭϲϱϵ ;ϵϬϳͿ ϱϲϰϰϲϵϲ &EƵŵďĞƌ͗ϮϭϮͲϬϭϮϰϭ /KZ ϭϯϱ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϯϯϭϬƉƐŝΛϴ͕ϴϬϬ͛dsϳ͘ϯWW'ͮ ;ǀĞƌĂŐĞ/ǀŝƐŚĂŬ,WͿ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W͗ϯϯϭϬƉƐŝΛϴ͕ϴϬϬ͛dsϳ͘ϯWW'ͮ ;ǀĞƌĂŐĞ/ǀŝƐŚĂŬ,WͿ DĂǆ͘ŶƚŝĐŝƉĂƚĞĚ^ƵƌĨĂĐĞ WƌĞƐƐƵƌĞ͗ϮϰϯϬƉƐŝ ;ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚ͘ŐĂƐŐƌĂĚŝĞŶƚͿ >ĂƐƚ ^/ t,W͗ϮϰϬϬ ƉƐŝ ;dĂŬĞŶ ŽŶ ϭϭͬϮϱͬϮϬϭϵͿ DŝŶ/͗ϭ͘ϳϴ͟ / ZE/WĂƚϴϵϯϮ͛D DĂǆŶŐůĞ͗ϵϲ ĞŐΛ ϵϰϱϴ͛ ZĞĨĞƌĞŶĐĞ>ŽŐ͗%+,31&/RJ ĂƚĞĚ ϰͲϰͲϮϬϭϲ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ ϮϬϭϲ ƐŝĚĞƚƌĂĐŬŝŶƚŽϮ͕ͲϮϭ ǁĂƐĐŽŵƉůĞƚĞĚǁŝƚŚ ϭϱϬΖŽĨ ƚŽĞ ƉĞƌĨƐĂŶĚĨůŽǁĞĚĨƵůůƚŝŵĞƵŶƚŝů ůĂƚĞϮϬϭϴ͘dŚĞ ǁĞůů ǁĂƐ ĐǇĐůĞĚďƵƚ ǁĂƐ ŶŽůŽŶŐĞƌĐǇĐůŝŶŐǁĞůůĂŶĚ ǁĂƐ ƌĞĂĚǇĨŽƌŶĞǆƚƐƚĂŐĞŽĨƉĞƌĨƐ͘ dŚĞŶĞǆƚƐƚĂŐĞŽĨ ƉĞƌĨŽƌĂƚŝŽŶƐǁĂƐĂĚĚĞĚŝŶ:ĂŶƵĂƌǇϮϬϮϭ͕ďƵƚƵŶĨŽƌƚƵŶĂƚĞůǇƚŚĞƉƌŽĚƵĐƚŝŽŶƚƌĞŶĚůŽŽŬƐůŝŬĞƚŚĞƌĞǁĂƐ ĐŽŶŶĞĐƚŝŽŶƚŽĂ ƐƵďƐƵƌĨĂĐĞ ĨƌĂĐƚƵƌĞĂŶĚ ƚŚĞǁĞůů ƌĞĂĐŚĞĚD'KZƋƵŝĐŬůǇ͘ dŚĞŐŽĂůŽĨƚŚŝƐƉƌŽŐƌĂŵ ŝƐƚŽŵŽǀĞƚŽ ŶĞǆƚƐƚĂŐĞŽĨƉĞƌĨŽƌĂƚŝŽŶƐƚŽƌĞƚƵƌŶǁĞůůƚŽĞĐŽŶŽŵŝĐ'KZ͘ KďũĞĐƚŝǀĞ͗hƚŝůŝǌĞdh ƚŽ ŝƐŽůĂƚĞĞǆŝƐƚŝŶŐƉĞƌĨŽƌĂƚŝŽŶƐƚŚĞŶ ƐƵƌĨĂĐĞĚĞƉůŽǇdWŐƵŶƐǁŝƚŚdhƚŽ ĂĚĚŶĞǁ ƉĞƌĨƐ ĂŶĚ ŝŵƉƌŽǀĞĨůƵŝĚƌĂƚĞƐ͘ ^ƵŶĚƌǇ WƌŽĐĞĚƵƌĞ ;ƉƉƌŽǀĂůZĞƋƵŝƌĞĚƚŽWƌŽĐĞĞĚͿ͗ EŽƚĞ͗ dŚĞǁĞůůǁŝůů ďĞŬŝůůĞĚ ĂŶĚŵŽŶŝƚŽƌĞĚďĞĨŽƌĞŵĂŬŝŶŐƵƉƚŚĞŝŶŝƚŝĂůƉĞƌĨƐŐƵŶƐ͘dŚŝƐŝƐ ŐĞŶĞƌĂůůǇ ĚŽŶĞ ĚƵƌŝŶŐ ƚŚĞĚƌŝĨƚͬůŽŐŐŝŶŐ ŽƌƉůƵŐƐĞƚ ƌƵŶ͘ dŚŝƐǁŝůůƉƌŽǀŝĚĞŐƵŝĚĂŶĐĞĂƐƚŽǁŚĞƚŚĞƌƚŚĞǁĞůůǁŝůůďĞŬŝůůĞĚďǇďƵůůŚĞĂĚŝŶŐ ŽƌĐŝƌĐƵůĂƚŝŶŐďŽƚƚŽŵƐƵƉƚŚƌŽƵŐŚŽƵƚƚŚĞũŽď͘ /ĨƉƌĞƐƐƵƌĞŝƐƐĞĞŶŝŵŵĞĚŝĂƚĞůǇĂĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐ͕ŝƚǁŝůůĞŝƚŚĞƌďĞ ŬŝůůĞĚďǇďƵůůŚĞĂĚŝŶŐǁŚŝůĞWKK,ŽƌĐŝƌĐƵůĂƚŝŶŐďŽƚƚŽŵƐƵƉƚŚƌŽƵŐŚƚŚĞƐĂŵĞƉŽƌƚƚŚĂƚŽƉĞŶĞĚƚŽƐŚĞĂƌƚŚĞ ĨŝƌŝŶŐŚĞĂĚ͘ ŽŝůdƵďŝŶŐ ϭ͘ D/ZhŽŝůĞĚdƵďŝŶŐhŶŝƚ ǁͬ ϭ͘ϱ͞ ĐŽŝůĂŶĚƐƉŽƚĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚ͘ Ϯ͘ ZhW'>ĨŽƌ<ŝĐŬŽĨĨ ϯ͘ Dh 'Zͬ>ĂŶĚĚƌŝĨƚ ĨŽƌϮͲϯͬϴ͟Z/W͘ ϰ͘ Z/, ĂŶĚŐĞŶƚůǇƚĂŐ/WĂƚϭϭ͕ϲϴϬ͟ >ŽŐ ƵƉ͕ƐƚŽƉƉŝŶŐƚŽƉĂŝŶƚĨůĂŐ͘ Ă͘ /ĨƉůƵŐŵŽǀĞƐŽƌŝƐƚĂŐŐĞĚŽĨĨĚĞƉƚŚǁĞŵĂǇƐĞƚĂŶŽƚŚĞƌƉůƵŐ ď͘ /ĨĂŶŽƚŚĞƌƉůƵŐŝƐƐĞƚΕϭϭ͕ϲϬϬĂǀŽŝĚŝŶŐĐŽůůĂƌƐ͕ǁĞǁŝůůƉĞƌĨŽƌŵϲͲϴŚŽƵƌƚĞƐƚƚŽǀĞƌŝĨǇŐĂƐ ƌĂƚĞƐŝŶƚŚĞ ƚĞƐƚƐĞƉĂƌĂƚŽƌ ƚŽ ĚĞƚĞƌŵŝŶĞŝĨŶĞǁƉĞƌĨŽƌĂƚŝŽŶƐǁŝůůďĞĂĚĚĞĚ͘ ϱ͘ WKK,ĂŶĚĐŽŶĨŝƌŵŐŽŽĚĚĂƚĂ͕ŽďƚĂŝŶĐŽƌƌĞĐƚŝŽŶ͘ ϲ͘ ƵůůŚĞĂĚϭϬϬďďůƐŽĨ ϴ͘ϰƉƉŐ ϭй<ůŽƌ ϴ͘ϱƉƉŐ ƐĞĂǁĂƚĞƌĚŽǁŶƚŚĞƚƵďŝŶŐƚŽƚŚĞĨŽƌŵĂƚŝŽŶ͘ Ă͘ tĞůůďŽƌĞǀŽůƵŵĞс ϴϵϬϬ͛y͘ϬϬϴϳďƉĨ н͘ϬϬϯϵďƉĨǆϮϴϬϬ͛ с Εϴϴ ďďůƐ ϳ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘&ƌĞĞǌĞƉƌŽƚĞĐƚƚƵďŝŶŐĂƐŶĞĞĚĞĚ͘ '/% WůƵŐĂŶĚ ĚĚ WĞƌĨ ͲϮϭ Wd͗ϮϭϱͲϮϭϲ ϴ͘ Dh ϮͲϯͬϴ͟ Z/W ĂŶĚZ/,ĂŶĚĐŽƌƌĞĐƚƚŽĨůĂŐ͘ ϵ͘ ŽŶƚĂĐƚK EŽĞůEŽĐĂƐ Ăƚ ϵϬϳͲϮϮϵͲϵϱϯϮŽƌ:ĞĨĨEĞůƐŽŶ ϯϬϳͲϳϲϬͲϴϬϲϱ ƉƌŝŽƌƚŽƐĞƚƚŝŶŐƉůƵŐͬƉĞƌĨŽƌĂƚŝŶŐ ĨŽƌĨŝŶĂůĂƉƉƌŽǀĂůŽĨ ƚŝĞͲŝŶƐ ϭϬ͘ ^ĞƚƉůƵŐŵŝĚͲũŽŝŶƚĂƚцϭϭ͕ϮϮϬ͛DĂŶĚƚĞƐƚƚŽϭϬϬϬƉƐŝ͘WKK,͘ ϭϭ͘ ƚƐƵƌĨĂĐĞ͕ƉƌĞƉĂƌĞĨŽƌĚĞƉůŽǇŵĞŶƚŽĨdWŐƵŶƐ͘ ƐƐƵƌĞĞǆĐĞƐƐĨůƵŝĚƐĂǀĂŝůĂďůĞŝĨŶĞĞĚĞĚƚŽŬĞĞƉŚŽůĞ ĨƵůů͘ ϭϮ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨ ƚŽƌĞƚƵƌŶƐƚĂŶŬ͘<ŝůůǁĞůůǁͬϴ͘ϰƉƉŐ ϭй<ůŽƌ ϴ͘ϱƉƉŐ ƐĞĂǁĂƚĞƌ ĂƐ ŶĞĞĚĞĚ͘ DĂŝŶƚĂŝŶĐŽŶƚŝŶƵŽƵƐŚŽůĞĨŝůůƚĂŬŝŶŐƌĞƚƵƌŶƐ ƚŽƚĂŶŬ ƵŶƚŝůůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶŝƐ ƌĞĞƐƚĂďůŝƐŚĞĚ͘ ϭϯ͘ WŝĐŬƵƉϭ͘ϱ͟ƐĂĨĞƚǇũŽŝŶƚ ĂŶĚd/tǀĂůǀĞĂŶĚƐƉĂĐĞŽƵƚďĞĨŽƌĞDhŐƵŶƐ͘ ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐǁŝƚŚ ĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐŵĂŬĞƵƉŽĨdWŐƵŶƐƚƌŝŶŐ͘KŶĐĞƚŚĞ ƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞŚĂǀĞďĞĞŶƐƉĂĐĞĚŽƵƚ͕ŬĞĞƉƚŚĞƐĂĨĞƚǇũŽŝŶƚͬd/tǀĂůǀĞƌĞĂĚŝůǇĂĐĐĞƐƐŝďůĞ ŶĞĂƌƚŚĞǁŽƌŬŝŶŐƉůĂƚĨŽƌŵĨŽƌƋƵŝĐŬĚĞƉůŽǇŵĞŶƚŝĨŶĞĐĞƐƐĂƌǇ͘ ϭϰ͘ ƌĞĂŬůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂƚYd^ĂŶĚďĞŐŝŶŵĂŬĞƵƉŽĨdWŐƵŶƐ ƉĞƌ dĂďůĞ ϭ͗ ͲϮϭ WƌŽƉŽƐĞĚ ĚͲWĞƌĨ 'ƵŶZƵŶ ďĞůŽǁ͘ 'ƵŶ ZƵŶη WĞƌĨdŽƉ WĞƌĨŽƚƚŽŵ WĞƌĨ >ĞŶŐƚŚ ϭ цϭϬ͕ϲϲϮ цϭϬ͕ϴϴϮ цϮϮϬ dŽƚĂů цϮϮϬ dĂďůĞ ϭ͗ ͲϮϭ WƌŽƉŽƐĞĚ ĚͲWĞƌĨ 'ƵŶZƵŶ ϭϱ͘ Z/,ǁŝƚŚ'ƵŶZƵŶϭ ĂŶĚ ĐŽƌƌĞůĂƚĞ ƚŽĨůĂŐ͘ ŽŶƚĂĐƚK tǇĂƚƚZŝǀĂƌĚϭ;ϱϬϵͿ ϲϳϬͲϴϬϬϭ ŽƌEŽĞůEŽĐĂƐ Ăƚ ϭ;ϵϬϳͿ ϵϰϳͲϵϱϯϯ ƉƌŝŽƌƚŽƉĞƌĨŽƌĂƚŝŶŐĨŽƌĨŝŶĂůĂƉƉƌŽǀĂůŽĨƚŝĞŝŶƐ͘ ϭϲ͘ WĞƌĨŽƌĂƚĞ͘ Ă͘ EŽƚĞĂŶǇƚƵďŝŶŐƉƌĞƐƐƵƌĞĐŚĂŶŐĞŝŶt^Z͘ ϭϳ͘ WKK,͘^ƚŽƉĂƚƐƵƌĨĂĐĞƚŽƌĞĐŽŶĨŝƌŵǁĞůůĚĞĂĚĂŶĚŚŽůĞĨƵůů͘ ϭϴ͘ ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐďƌĞĂŬĚŽǁŶ ŽĨdWŐƵŶƐƚƌŝŶŐ͘ ϭϵ͘ ZDKdh͘ ϮϬ͘ ZdWŽƌ&WǁĞůů͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůdƵďŝŶŐKW^ĐŚĞŵĂƚŝĐ ϰ͘ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ ϱ͘ 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Development Exploratory Service 5 Permit to Drill Number:215-216 6.50-029-20753-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11991 11680 9001 7745, 7884 Unknown 11680, 11880 7679, 7805 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" x 30" 35 - 115 35 - 115 Surface 2636 13-3/8" 34 - 2670 34 - 2670 5380 2670 Intermediate 8451 9-5/8" 33 - 8484 33 - 8359 6870 4760 Production 992 7" 7968 - 8960 7882 - 8809 8160 7020 Liner 969 3-1/2" 7991 - 8960 7903 - 8809 10160 10530 Perforation Depth: Measured depth: 11282 - 11879 feet True vertical depth:9007 - 9005 feet Tubing (size, grade, measured and true vertical depth) 7745 7679Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S3 Packer Liner 3057 2-3/8" 8934 - 11991 8784 - 9016 11200 11780 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 83620020181 15220747 1620 17640 755 671 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Wyatt Rivard wrivard@hilcorp.com Authorized Name: Authorized Title: Authorized Signature with Date:Contact Phone:(907)777-8547 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9016 Sundry Number or N/A if C.O. Exempt: 320-509 5-1/2" Otis Packer 7884 7805 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Extended Perf w CTU 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 5Perforate 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 028305 & 028285 PBU C-21A 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" 9.2# 13cr80 / 5-1/2" 17# x 4-1/2" 12.6# L80 31 - 7784 / 7780 - 888731 - 7861 / 7857 - 8049 Stan Golis By Samantha Carlisle at 3:11 pm, Feb 01, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.02.01 14:39:43 -09'00' SFD 2/3/2021DSR-2/2/21MGR19FEB2021 RBDMS HEW 2/2/2021 ACTIVITY DATE SUMMARY 1/21/2021 CTU #9 1.50" CT .109" WT Job Scope: Isolate existing perforations w/CIBP and add perf to improve fluid rates. MIRU test BOPE. MU & RIH w/ Baker MHA & SLB logging BHA. Log from 11760 to 11300ft. POH. LD logging BHA +26ft corr. MU CIBP. ...Job in Progress... 1/22/2021 CTU #9 1.50" CT .109" WT Job Scope: Isolate existing perforations w/CIBP and add perf to improve fluid rates. Load well. RIH w/ CIBP. Set at 11680ft. MU & RIH w/ perf guns. Correct depth & perforate from 11,282'-11,360', 11,390'-11532' w/ 1.56" millenium perf guns. POH. Undeploy perf guns. Continue WSR on 1/23/2021 1/23/2021 CTU #9 1.50" CT .109" WT Job Scope: Isolate existing perforations w/CIBP and add perf to improve fluid rates. RDMO. ...Complete... Daily Report of Well Operations PBU C-21A Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:215-216 6.API Number:50-029-20753-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028305 & 028285 Property Designation (Lease Number):10. 341 8. PBU C-21A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations 5 Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11991 Effective Depth MD: 13cr80 / L-80 11. 12/15/2020 Commission Representative: 15. Suspended Contact Name: Wyatt Rivard Contact Email: wrivard@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 5-1/2" Otis Packer Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9016 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool 7745, 7679 7884, 7805 Date: Liner 3057 2-3/8"8934 - 11991 8784 - 9016 11200 11780 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 35 - 115 33 - 8484 33 - 8359 14. Estimated Date for Commencing Operations: BOP Sketch 34 - 2670 Conductor 8160 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Packer 11720 - 11879 9001 - 9005 31 - 7861 / 7857 - 8049 Liner 11880 9005 11880 unknown 34 - 2670 2670 9-5/8" 7" Contact Phone:(907)777-8547 Date: 7020 2636 538013-3/8"Surface 4760 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 80 20" x 30"35 - 115 Intermediate 8451 6870 Production 992 7968 - 8960 7882 - 8809 969 3-1/2" 7991 - 8960 7903 - 8809 10160 10530 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2430 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. Extended Perforating with CTU 3-1/2" 9.2# / 5-1/2" 17# x 4-1/2" 12.6# By Samantha Carlisle at 10:30 am, Dec 02, 2020 320-509 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.12.02 13:02:22 - 06'00' Stan Golis DLB12/02/2020 10-404X 08DEC2020 DSR-12/2/2020 Yesn Required? Comm 12/8/2020 dts 12/8/20 JLC 12/8/2020 RBDMS HEW 12/9/2020 Plug and Add Perf C-21A PTD:215-216 Well Name:C-21A CTU Plug & Add Perf API Number:50-029-20753-01 Current Status:Producing Rig:CTU & Surface Deployed TCP Guns Estimated Start Date:12/15/2020 Estimated Duration:3days Reg.Approval Req’std?N/A Date Reg. Approval Rec’vd:N/A Regulatory Contact:Abbie Barker Permit to Drill Number:215-216 First Call Engineer:Wyatt Rivard (907) 777-8547 (O)(509) 670-8001 (M) Second Call Engineer:Noel Nocas (907) 777-8449 (O)(907) 947-9533 (M) AFE Number:IOR 286 Current Bottom Hole Pressure:3310 psi @ 8,800’ TVD 7.3 PPGE | (Average Ivishak BHP) Maximum Expected BHP:3310 psi @ 8,800’ TVD 7.3 PPGE | (Average Ivishak BHP) Max. Anticipated Surface Pressure:2430psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2400 psi (Taken on 11/25/2019) Min ID:1.78” ID RNIP at 8932’ MD Max Angle:96 Deg @ 9458’ Reference Log:BHI PNC Log Dated 4-4-2016 Brief Well Summary: A 2016 sidetrack into Z2A, C-21A was completed with 150' of toe perfs and flowed full time until late 2018. The well has been cycled since but is no longer cycling well and is ready for next stage of perfs. The goal of this program is to move to next stage of perforations to return well to economic GOR. Objective:Utilize CTU to isolate existing perforations then surface deploy TCP guns with CTU to add new perfs and improve fluid rates. Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging or plug set run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. MIRU Coiled Tubing Unit w/ 1.5“ coil and spot ancillary equipment. 2. MU GR/CCL and drift for 2-3/8” ER CIBP. 3. RIH below target CIBP set depth of ~ 11,670’ MD 4. Log up, stopping to paint flag. 5. POOH and confirm good data, obtain correction. 6. Bullhead 100 bbls of 8.4 ppg 1% KCl or 8.5 ppg seawater down the tubing to the formation. a. Wellbore volume = 8900’ X .0087bpf + .0039bpf x 2800’ = 50 bbls 7. Confirm well is dead. Freeze protect tubing as needed. 8. MU 2-3/8” ER CIBP and RIH and correct to flag. 9. Contact OE Wyatt Rivard 1(509) 670-800 or Noel Nocas at 1(907) 947-9533 prior to setting plug/perforating for final approval of tie-ins 10. Set composite plug mid-joint at ±11,670’ MD and test to 1500 psi. POOH. * Plug and Add Perf C-21A PTD:215-216 11. At surface, prepare for deployment of TCP guns. Assure excess fluids available if needed to keep hole full. 12. Confirm well is dead. Bleed any pressure off to returns tank. Kill well w/8.4 ppg 1% KCl or 8.5 ppg seawater as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. 13. Pickup 1.5” safety joint and TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 14. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per Table 1: C-21A Proposed Ad-Perf Gun Run below. a. A 30 ft gap will be left in the perf interval across a shale as potential future CIBP/isolation Gun Run #Perf Top Perf Bottom Perf Length 1 ±11282 ±11360 ±78 ±11390 ±11532 ±142 Total ±220 Table 1: C-21A Proposed Ad-Perf Gun Run 15. RIH with Gun Run 1 and correlate to flag. Contact OE Wyatt Rivard 1(509) 670-8001 or Noel Nocas at 1(907) 947-9533 prior to perforating for final approval of tie ins. 16. Pickup and perforate intervals per Table 1: C-21A Proposed Ad-Perf Gun Run. POOH. a. Note any tubing pressure change in WSR. 17. POOH. Stop at surface to reconfirm well dead and hole full. 18. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 19. RDMO CTU. 20. RTP or FP well. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Tie In Log/Perf Sheet 7. Rig Work Over Sundry Change Record Standing orders flow chart included with this sundry request. Plug and Add Perf C-21A PTD:215-216 Wellbore Schematic Plug and Add Perf C-21A PTD:215-216 Proposed Schematic Plug and Add Perf C-21A PTD:215-216 Coiled Tubing BOPs Plug and Add Perf C-21A PTD:215-216 Equipment Layout Diagram Plug and Add Perf C-21A PTD:215-216 Standing Orders for Open Hole Well Control during Perf Gun Deployment Plug and Add Perf C-21A PTD:215-216 C-21A Tie-In Log Plug and Add Perf C-21A PTD:215-216 Plug and Add Perf C-21A PTD:215-216 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: December 2, 2020Subject: Changes to Approved Sundry Procedure for Well C-21ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date RE • . 21 52 16 • 27 363 Fait' JUL 07 zUl` PRINT DISTRIBUTION LIST BAKER HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME C-21A 900 E. Benson Blvd. �, �BEND15/201 CO BENDEP Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE April 4,2016 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhughes.com TODAYS DATE July 3,2016 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (las,dlis,PDF,META, SURVEY REPORT CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS 4 OF THIN I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. I Anchorage,Alaska 99508 sc NNED FEB 0 8 2017 2 ConocoPhillips Alaska Inc. 0 1 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 1 1 I 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 *Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 0 0 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:David Itter TOTALS FOR THIS PAGE: 0 4 4 TOTALS FOR ALL PAGES: 0 4 4 0 0 • i ,c) . o . , o N I W I W N o co a o a 0 LL J MCl W_ Wo 0 c NI 31 cl 'I cl W QI L.T. 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C U 2 r NA• U E G C7 a. 0 o I o 0 111111 Link, Liz M (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Wednesday, June 01, 2016 4:54 PM To: AOGCC Reporting (DOA sponsored) Subject: POP PBU C-21A/ PTD # 215-216 Hello, Please reference the following well: Well Name: PBU C-21A Permit#: 215-216 API #: 50-029-20753-01-00 Date of Test: 5/24/16 Type of Test: IPT (Initial Production Test) Choke Size: 95 Choke Unit: Production Method: Flowing Duration (Hours Tested): 6 Top Reference (Top Perf MD): 11720' Bottom Reference (Bottom Perf MD): 11879' Tubing Flowing (Pressure): 260 Casing Pressure: 1680 Total Test Rate (0, G, W): 185/ 1327/46 24-Hour Rate (0, G, W): 741 / 5309/ 183 Gravity(Oil, API): Not Available GOR(Gas-Oil Ratio): 7166 This well began Production on Method of Operations on this date: May 23, 2016 1 RBDMS Ll.- JUN 0 2 2016 STATE OF ALASKA AlIALASKA OIL AND GAS CONSERVATION COMMI N WEL MPLETION OR RECOMPLETION REPAND LOG la. Well Status: Oil p • Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development p Exploratory 0 GINJ ❑ WINJ 0 WAG 0 WDSPL 0 No.of Completions: One • Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 1/6/2016 Itj3''2ot(o 215-216. 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 3/16/2016 50-029-20753-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 3/23/2016 PBU C-21A • Surface: 884'FNL,1523'FEL,Sec.19,T11 N,R14E,UM • 9 KB Ref Elevations 17. Field/Pool(s): 67.5 - Top of Productive Interval: 1391'FNL,2283'FEL,Sec.19,T11N,R14E,UM GL 31.34 . BF 34.6 PRUDHOE BAY,PRUDHOE OIL • Total Depth: 1363'FNL,3'FEL,Sec.24,T11 N,R13E.UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: • 11880'/9005' • ADL 028305&028285 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 663845• y- 5960324 . Zone - ASP 4 . 11991'/9016' • 80-274 TPI: x- 663098 y- 5959801 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 660423 y- 5959770 Zone - ASP 4 None 2080'/2080' 5. Directional or Inclination Survey: Yes II (attached) No 0 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 8960'/8809' 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD/GR/RES,GR/CCL/RPM RECEIVED MAY 0 5 201G 23. CASING,LINER AND CEMENTING RECORD CASING wr.PERGRADE HOLE SIZE AMOUNT SETTING DEPTH MD SETTING DEPTH TVD CEMENTING CC FT. PULLED TOP BOTTOM TOP BOTTOM 20"x 30" 35' 115' 35' 115' 36" 8 cu yds Concrete 13-3/8" 72# L-80 34' 2670' 34' 2670' 17-1/2" 3883 cu ft Arctic Set II 9-5/8" 47# L-80 33' 8484' 33' 8359' 12-1/4" 1136 cu ft Class'G',130 fr Arctic Set I 7" 26# L-80 7968' 8960' 7882' 8809' 8-1/2" 368 cu ft Class'G' 3-1/2" 9.3# L-80 7991' 8960' 7903' 8809' Scab Liner 73 cu ft Class'G' 2-3/8" 4.7# L-80 8925' 11991' 8776' 9016' 3-1/4" 77 sx Class'G' 24. Open to production or injection? Yes 2 • No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 3-1/2"9.2#13Cr80 x 8048' 7755'/7688' 1.56"Gun Diameter,6 spf 5-1/2",17#x4-1/2",12.6#,L-80 7882'/7803' 11720'-11780' 9001'-9000' 11780'-11840' 9000'-9002' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 11849'-11879' 9003'-9005' COMPLETION Was hydraulic fracturing used during completion? Yes 0 No p • DATE Per 20 AAC 25.283(i)(2)attach electronic and printed U/-i'I( - information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L E" 11890' Fish:1.56"Firing Head 11880' Cement Retainer 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):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 ••••* • Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only �/'7z 5`b`it �� 57---;/:,,4- RBDMS LL MAY 0 6 2016 ./.45- 1.4.,,, G 28. CORE DATA • Conventional Core(s) Yes 0 No & • Sidewall Cores 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 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No II Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9123' 8943 separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. 23SB-Zone 2B 8978' 8826' 22TS 9040' 8880' 21TS-ZONE 2A 9123' 8943' Zone 1B 9398' 9024' 21TS-Zone 2A(Invert) 9408' 9024' Formation at total depth: Zone 2A(From Base) 9408' 9024' 31. List of Attachments: Summary of Daily Drilling Reports,Summary of Post-Rig Work,Survey,Cement Report Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Browning,Zachary H Email: Zachary.Browning@bp.com Printed Name: Joe Lastu a IA Title: Drilling Technologist Signature: Phone: +1 907 564 4091 Date:5/3/)(n �� JJ 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. 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 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations 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 15.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 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records 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. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only S Y NOTES:WELL (WELLHEAD= MCEVOY • \„/ -21 A M}�DLS 42.7°@ 8975.**CHROME TBG***30`. ACTUATOR= OKB ELEV= 67.5' I ` - " I 24' -4-1/2"X 3-1/2 XO,D=2.992' REF ELEV- 67.5' BF ELEV= 34.6' /' t 2227 --I3-1/2"HES X NP,D=2.813" KOP= 6800' / Max Angle= 96"@ 9457` Datum MD= 9025' 2599' H9-518"DV FKR Datum ND= 8800'SS GAS LFT MANDRELS 4-iC1"TBG,12.6#,13CRTC11, -i 24' 11 ST MD ND DEV TY FE VLV LATCH FORT DATE 4 3092 3092 1 MMG DOME RK 16 08/27/12: 0152 bpf,ID=3.958" 'I 3 5196 5196 1 AfAG DOME RK 20 08/27/12 13-3/8"CSG,72#,L-80,BTRS,D=12347" - 2670' J1`I 2 6794 6792 9 MMG DM'( RK 0 071201081 1 7665 7606 25 MMG DMY RK 0 07/20/08 Minimum ID = 1.78" @ 8932' I ' 7723' -H3-1/2"HES X MP,13=2.813" R NIPPLE ____- 7744' H3-1/2-X 4-1/2-XO,D=2.950" '-1 7745' -9-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" ,` 7751' --I4-1/2"X 3-1/2'XO,ID=2.950" I ' 7771' -{3-1/2"FES XMP,D=2.813" I ' 7824' -3-1/2"FES BXP XN NMP, LLE) TO 2.80"(03/14/16) 3-1/2"TBG,9.2#,13CRVAM -' 7847' TOP,.0087 bpf,I)=2.992" s"-----------1- _ 7845' H3-1/2"X 4-112"XO,D=2-992" 7857' -15-1/2"TBG STUB(03/06/06) _---------- 7861' -14-1/2"MAJLE SHOE,D=3.958" 5-112"TBG,17#,L-80,0232 bpf,13=4.892' H 7884' I-- 8"x2"x 1/2"SLP SEGMENT f(FOR PHOTOS,SEE - UNKNOW N \ X { 7884' -9-5/8'OTs PKR,D=4.00" RWO FEE 3/15106-COULD BEN 1 OF 2 LOC.) M--�J 7'BOT LNR HGR WI T1 ACK SLV -{ 796$' I�-t ' 1 7965' H4-1/2"OTtS X NP,D=3.813" 7'LW,26#,L-80,.0383 bpf,D=6.276" --j 79$2' '--- r x I 7991' -13.75"BKR DEPLOYMIENT SLV,13=3.00" ' ' 8006' -14-117 OTIS XN NP,D=3.725"(8841N)PIPE) 4-112'TGE,12.6#,L-80,.0152 bpf,D=3.95$' -} 8048' ----i 8049' H4-1/2"WLEG(BGUN)PIP(E) 9-5/8"CSG,47#,L-80,.0732 bpf,D=8.681" H 8484` , } 80427 [a O TT LOGGED 05/04/93 8925' -35 KB NS LTP w/PISA&RNP @ 8932', 1 TOP OF 2-3/8'LNR/CMT(03/28116) --1 8934' , D=1.78"(04/07/16) 3-1/T BKR PACKER WHPSTOCK(01/11/16) -1 $960' -'- 8934• -12.70"DEPLOYNENT SLV,D=1.78" 3-1/2"LNR,9.3#,L-80-JT1,.0087 bpf,ID=2.992" }- -8960' MLLOUT WINDOW(C-21A) 8960'-8970' 7"LNR,29#,L-80,.0371 bpf,D=6.184" -1 -8960' ' 10098' - FIJP JT w/RA TAG PERFORATION SUMMARY ` REF LOG:AS DRL.LED MN)ON 03/24/16 ANGLE AT TOP FERE:90°@ 11720' Note:Refer to Production OB for historical pert data SIZE SFF INTERVAL Opn/Sgz SHOT SQZ O11880'CTM -12-3/8'WFT CMT RETANER(03/28/16) 1.56" 6 11720-11780 0 04/06/16 ( 11890'CTM I-FISH:1.56"FRG I-EAD,10'BLANK GUN, 1.56" 6 11780-11840 0 04/05/16 10'FRED-FRED GUN,BULLNOSE PUSHED 1.56" 6 11849-11879 0 04/04/16 TO 11890'(03/28/16) 1.56" 6 11934-11945 S 03/25/16 03/29/16 PBTD - 11953'- 2-3/8"LNR,4.7#,L-80 TH511/STL,.0039 bpf,D=1.995' -{ 11991' DATE REV BY COMMENTS DATE FEV BY COMMENTS FRUGHOE BAY UNIT 07/12/82 IMTIAL COMPLETION 03/29/16 DM'JMD FINAL ODEAFPROVAL WELL: C-21A 04/04/98 NORDIC 3-1/2"SCAB LNR 03/30/16 ALMYJMD ADDED CMT(03/28/16) FERMI No: 2152160 03!14/06 N3S RWO 04/07/16 JNUJIVD CORRECTED FKR DEPTH PER TALLY AR No: 50-029-20753-01 03/26/16 NORDIC2 CTD(C-21A) 04/25/16 MSS/JM.?SET LTPw/R NP&ADFERFS SEC 19,T11N,R14E,884'FNL&1523'Fa 03/28/16 JMD DREG HO CORRECTIONS 05/02/16 JMJJMD ADDED REF E.EV 03/29/16 ATO/JMD PUSH FISWSET CMT RETAINER BP Exploration(Alaska) • North America-ALASKA-BP Page 1 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING @67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/11/2016 112:00 14:00 2.00 MOB P PRE RIG RELEASED FROM DS 3-21AT 1200 HRS. -CONTINUE WITH PREPARATION FOR MOVING RIG OFF OF 3-21. COMPLETE PREP OF RIG AND SITE. -PJSM FOR MOVING RIG OFF WELL 3-21. DISCUSSION FOCUSED ON: PLACING PHYSICAL BARRIER(12"X12" CHOCK)IN PLACE TO PREVENT THE RIG FROM ROLLING BACK TOWARDS TREE/WELLHEAD. ESD IN CELLAR IS FUNCTION TESTED AND MANNED BY NORDIC FIELD SUPERINTENDENT RADIO COMMUNICATION VERIFIED FOR ALL INDIVIDUALS INVOLVED IN THE MOVE THE AGREED PHYSICAL SIGN "COMMAND"AND RADIO COMMAND TO STOP THE RIG MOVE IS UNDERSTOOD BY ALL 114:00 - 16:00 2.00 MOB P PRE MOVE RIG OFF OF WELL -PLACE PHYSICAL BARRIER(12"X 12" CHOCK)IN PLACE BEHIND WHEEL '-FUNCTION TEST ESD IN CELLAR -TEST RADIO COMMUNICATIONS WITH ALL HANDS -MOVE RIG OFF OF WELLAND TO EDGE OF PAD -PICK UP RIG MATS AND CLEAN UP AROUND WELLAND PAD 16:00 - 00:00 8.00 MOB P PRE MOVE RIG FROM DS 3 TO C PAD.ARRIVE AT GUARD SHACK AT MIDNITE. 3/12/2016 00:00 - 08:30 8.50 MOB P PRE CONTINUE TO MOVE THE RIG FROM GUARD SHACK. WSL VERIFIED PRESSURE OF OA AND IA,0 PSI ON BOTH. -CONDUCT CREW CHANGE,MOVE RIG ONTO ACCESS ROAD. STAGE RIG ON C-PAD. -PJSM FOR PULLING OVER WELL. DISCUSSION FOCUSED ON RIG MOVE CHECKLIST AND WELL PLAN CRITERIA. CREW UNDERSTANDS RADIO COMMUNICATION AND THE AGREED PHYSICAL SIGN"COMMAND"AND RADIO COMMAND TO STOP THE RIG 08:30 - 09:30 1.00 MOB P PRE MOVE RIG OVER WELL. -PLACED PHYSICAL BARRIER(12"X12" CHOCK)IN PLACE TO PREVENT THE RIG FROM ROLLING BACK TOWARDS TREE/ WELLHEAD. -FUNCTION TESTED ESD IN CELLAR BEFORE MOVING RIG AND WAS MANNED BY NORDIC FIELD SUPERINTENDENT WHILE MOVING RIG -CHECKED RADIO COMMUNICATIONS WITH ALL SPOTTERS AND DRIVER RIG ACCEPT AT 0930 HRS 09:30 - 11:00 1.50 MOB P PRE PREPARE FOR RIG OPS: -BUTTON UP CELLAR -STAGE SUPPORT EQUIPMENT -CYCLE SSV AND ALL TREE VALVES IN PREPARATION FOR LEAK TIGHT TEST. NO 1 PRESSURE FROM WELL. Printed 4/25/2016 8:50:09AM *All depths reported in Drillers Depths' • North America-ALASKA-BP 0 Page 2 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING @67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 15:45 4.75 BOPSUR P PRE NU BOP 15:45 - 17:30 1.75 RIGU P PRE INSTALL STUFFING BOX ONTO LUBRICATOR EXTENSION TO BOP. NU GOOSENECK, INSTALLAND MU INJECTOR. 17:30 - 20:30 3.00 RIGU P PRE -VALVE CREW CHECK TORQUE ON BOLTS ON TREE AND GREASE VALVES. -PJSM,PULL TEST GRAPPLE,REMOVE SHIPPING BAR FROM COIL,PULL COIL ACROSS TOP AND STAB INTO INJECTOR.CUT ' GRAPPLE OFF.SECURE COIL IN GOOSENECK.RD STABBING CABLE.RU INJECTOR SIDE PULL BACK CABLE. -CONDUCT PRE-SPUD WITH NIGHT CREW DURING NIGHT PTM 20:30 - 23:30 3.00 RIGU P i PRE GET STACK MEASUREMENTS. SET TEST PLUG. GREASE MUD CROSS. FILL SURFACE LINES,MGS,STACK WITH WATER. 23:30 - 00:00 0.50 BOPSUR P PRE SHELL TEST 300PSI/4500PSI-PASS. TEST BOPE PER NORDIC PROCEDURE / AOGCC/ WELL PROGRAM FROM RIG FLOOR &SLB REMOTE PANEL ALL TESTS INCLUDING ANNULAR ARE BEING TAKEN TO LOW 250 PSI/HIGH 3500PSI FOR 5 CHARTED MINUTES EACH **AOGCC REP JEFF JONES WAIVED WITNESS BY EMAIL ON 03/11/2016 AT 08:13 3/13/2016 00:00 - 03:00 2.00 I BOPSUR P PRE CONTINUE TO TEST BOPE. -ALL TESTS TO LOW 250 PSI/HIGH 3500PSI FOR 5 CHARTED MINUTES EACH. HAVING DIFFICULTY TO GET STABLIZED FLAT-LINE DUE TO COLD,TAKING TIME TO OBTAIN FLAT-LINE. -TEST ALLAUDIBLE AND VISUALALARMS -CONDUCT PRE-SPUD WITH DAY CREW DURING MORNING PTM _ 03:00 - 03:00 0.00 BOPSUR P PRE DAY LIGHT SAVING TIME. 03:00 - 08:00 5.00 BOPSUR P PRE CONTINUE TO TEST BOP PER REQUIREMENTS 08:00 - 11:30 3.50 BOPSUR P PRE INSTALL BOOT ONTO E-LINE. INSTALL COIL CONNECTOR,PRESSURE TEST COIL CONNECTOR AND HIGH PRESSURE SCREEN CONNECTIONS. STAB ON,PRESSURE TEST PACKOFFS AND INNER REEL VALVE TO 250 PSI LOW/3500 PSI HIGH. -OBTAINING GOOD LOW TEST BUT DIFFICULT TO GET FLAT-LINE ON HIGH PRESSURE TEST DUE TO FLUID COOLING OFF AND SHOWING PRESSURE DECREASE. BREAK CIRCULATION TWICE TO AVOID FREEZING COIL. 1- THIRD TEST STABILIZED FOR 5 MINUTE FLAT-LINE AT 3500 PSI. Printed 4/25/2016 8:50:09AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 3 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING©67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 12:00 0.50 RIGU P PRE PJSM FOR CONDUCTING PRESSURE TEST OF PRESSURE BULKHEAD AND REELHOUSE IRON THAT WILL BE USED IN CEMENTING OPERATION. -REVIEW NORDIC PRESSURE TESTING PROCEDURE,BP PRESSURE CROSSCHECK CHECKLIST,AND DHD PRESSURE TESTING PROCEDURE -DISCUSS LOW AND HIGH EXPECTED PRESSURES,WEAK LINKS IN SYSTEM AND HOW TO MITIGATE THEM FROM SEEING PRESSURE,PERSONNEL DUTIES INVOLVED IN TESTING 12:00 - 15:30 3.50 RIGU P PRE CLOSE INNER REEL VALVE,BRING UP TEST PRESSURE OF BULKHEAD TO 250 PSI LOW WITH GOOD TEST. INCREASE PRESSURE FOR HIGH PRESSURE TEST. PRESSURE UP TO 6305 PSI. BLED 15 PSI IN 5 MINUTES TO 6290 PSI FOR GOOD TEST PER CRITERIA IN BP PRACTICE 10-45. -BLEED SYSTEM OFF,RE-ALIGN VALVES TO OPEN INNER REEL VALVE AND BY-PASS MICROMOTION WITH BLEEDER VALVE FOR -TATTLETALE. LOW PRESSURE TEST TO 250 PSI GOOD. BRING PRESSURE UP TO 6307 PSI,BLED TO 6298 PSI FOR GOOD TEST. BLEED DOWN SYSTEM. -MOBILIZE DHD EQUIPMENT OFF RIG [15:30 - 16:00 0.50 RIGU P PRE CONDUCT RIG EVACUATION DRILL WITH DAY CREW. SIMULATE OUT-OF-CONTROL FIRE, EVACUATE RIG. GOOD DRILL FOLLOWED BY AAR. 16:00 - 17:30 1.50 STWHIP P WEXIT PULL BOP TEST PLUG. PJSM ON MAKING UP NOZZLE ASSEMBLY. -MU NOZZLE BHA WITH DUAL BACK PRESSURE VALVES. STAB ON WITH INJECTOR,PRESSURE TEST QUICK TEST SUB. -PJSM ON INITIAL ENTRY,OPEN UP TO WELL WITH TESTED BARRIER,NO PRESSURE ON WELL 17:30 - 19:20 1.83 STWHIP N HMAN WEXIT RIH WITH NOZZLE ASSEMBLY DISPLACING TO FLOW BACK TANK PER NORDIC FLUID MANAGEMENT POLICY.TAG BOTTOM AT 8960FT. 19:20 - 22:50 3.50 STWHIP N HMAN WEXIT PUMP 200BBLS OF 115DEG F 1%KCL TO REMOVE GASEOUS FLUID OUT OF WELL BORE(4 BOTTOMS UP)FOLLOWED BY 9.5PPG POWERPRO AT 2.4BPM/3780PSI. NOTICE HIGHER THAN NORMAL DOWNSTREAM PRESSURE RESULTING IN HIGHER THAN EXPECTED WHP WITH VERY LOW PRESSURE BLEED OFF RESPONSE ON LINE GOING TO TIGER TANK.STOP& DISCUSS-POSSIBLE DEBRIS.NOTICE HIGH PRESSURE NOISE COMING FROM 2"VALVE ON TIGER TANK LINE ON RIG(CH2HILL). BLEED DOWN IA THREE TIMES. 22:50 - 23:00 0.17 STW-IIP N HMAN WEXIT FLOW CHECK-NO FLOW. Printed 4/25/2016 8.50:09AM "All depths reported in Drillers Depths* North America-ALASKA-BP S Page 4 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:OOAM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING©67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 00:00 1.00 STWHIP N HMAN WEXIT POH.PUMP 1.75BPM/3175PSI WHILE POH. NOTICE HIGHER THAN NORMAL CIRC PRESSURE VERSUS EXPECTED RATE. 3/14/2016 00:00 - 00:30 0.50 STWHIP N HMAN WEXIT CONTINUE TO POH WITH NOZZLE BHA.PJSM REGARDING LD NOZZLE BHA. 00:30 - 00:50 0.33 STWHIP N MISC WEXIT POP OFF WELL.LD NOZZLE BHA.LARGE AMOUNT OF CEMENT CHUNKS IN NOZZLE. PLACE INJECTOR OVER BUNG HOLE. REMOVE 2"HARDLINE VALVE FROM RIG. RECOVER LARGE(2.25"x1.75"x0.75")PIECE 'OF LEAD.BUTTON UP HARDLINE. 00:50 - 01:00 0.17 STWHIP N HMAN WEXIT PJSM REGARDING MU XN MILLING BHA. 01:00 - 01:30 0.50 STWHIP N HMAN WEXIT i MU XN MILLING BHA#2.STAB ONTO WELL. 'TEST QTS 250PSI/4000PSI.SET COUNTERS. CIRC 0.25BPM/923PSI. 01:30 - 03:05 1.58 STWHIP N HMAN WEXIT RIH WITH XN MILL BHA.CIRC 0.24BPM/952PSI.WEIGHT CHECK AT 7800FT, RIW 25K,PUW 34K.DRY TAG AT 7826FT. 03:05 - 06:00 2.92 STWHIP N HMAN WEXIT CIRCAT1.23BPM/2500PSI. MILL XN PROFILE AT 7826'. MAINTAIN CIRC RATE OF 1.25 BPM AND 300-400 PSI DIFFERENTIAL PSI. MAKE TOTAL OF THREE PASSES THROUGH XN PROFILE,DRIFT RUN CLEAN DOWN TO 8100' -FLOW CHECK,ALL GOOD 06:00 - 07:30 1.50 STWHIP N HMAN WEXIT POH WITH MILLING BHA. PJSM FOR FLOW CHECK AND HANDLING BHA. FLOW CHECK AT SURFACE,ALL GOOD. POP OFF. 07:30 - 08:00 0.50 STWHIP N HMAN WEXIT LD BHA#2. MILL IN GOOD SHAPE,GAUGE OF 2.80"GO,2.79"NO-GO. 08:00 - 11:15 3.25 STWHIP P WEXIT PUMP 3/4"DRIFT BALL AROUND,CAPTURE BALL. CUT OFF CURRENT COIL CONNECTOR,CUT 274'OF COIL TO OBTAIN •1.75%SLACK. RE-INSTALL CTC COIL CONNECTOR. PUMP SLACK FORWARD. _ 11:15 - 14:00 2.75 STWHIP P WEXIT TEST E-LINE,GOOD TEST. HEAD UP WITH BHI UPPER QUICK CONNECT SUB. PRESSURE TEST CONNECTION,GOOD TEST. INSTALL DUAL FLAPPER CHECK VALVES, STAB ON AND PRESSURE TEST TO 250 PSI LOW/3500 PSI HIGH. 14:00 - 14:30 0.50 STWHIP P WEXIT CONDUCT CREW CHANGEOUT AND SAFETY WALK AROUND OPEN UP WELL TO TESTED BARRIERS. NO PRESSURE,NO FLOW. ALL GOOD,POP OFF WITH INJECTOR AND STAND TO SIDE. 14:30 - 15:15 0.75 STWHIP P WEXIT PJSM ON MAKING UP BHA#3. MU 2.80" DIAMOND SPEED WINDOW MILLAND STRING REAMER ASSEMBLY ONTO.6°BEND MOTOR AND BHI SMART TOOLS. h STAB ON WITH INJECTOR Printed 4/25/2016 8:50:09AM *All depths reported in Drillers Depths* • North America-ALASKA-BP Page 5 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING @67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:15 - 17:15 2.00 STWHIP P WEXIT PRESSURE TEST QUICK TEST SUB WHILE WAITING ON MWD TO SET DEPTH,OPEN EDC. -RIH WITH MILLING BHA#3 -OHI TOOLS ARE ACTING ERRATIC, j POWERING ON AND OFF AT VARYING INTERVALS. BHI PERSONNEL TROUBLESHOOTING ON TRIP IN,CHECKING CABLES. STAGE BHA AT LOGGING DEPTH OF 8640'IN PREPARATION TO CONDUCT PRIMARY DEPTH CONTROL LOGGING RUN,STOP MOVEMENT -MW IN 9.41 PPG,MW OUT 9.41 PPG 17:15 - 17:30 0.25 STWHIP N I WEXIT TROUBLESHOOT POWER AND COMMUNICATION ISSUES.WHIL WAITING, CONDUCT FLOW CHECK DUE TO ANOMALY IN MUD DENSITY READING. NO FLOW. AS SOON AS PUMPS WERE BROUGHT UP TO FULL RATE,DENSITIES WERE GOOD. 17:30 - 19:00 1.50 STWHIP P WEXIT CONTINUE TO RIH.CIRC MIN RATE. 19:00 - 19:45 0.75 STWHIP P WEXIT LOG DOWN FOR TIE-IN FROM 8640'CIRC AT 0.25PSI/1100PSI.PLUS 16FT CORRECTION. 19:45 - 20:00 0.25 STWHIP P WEXIT CONTINUE TO RIH WITH MILLING BHA#3. 20:00 - 00:00 4.00 STWHIP P WEXIT -MILL WINDOW FROM 8959.5FT.DWOB= 0.25-3.02K. 1.62/1.62 BPM IN/OUT 9.49/9.40 PPG AT 3890PSI. IA/OA 125/157 ECD 11.30 BLED DOWN IA FROM 145PSI&OA FROM 445PSI TO OPSI. MILL TO MIDNIGHT DEPTH OF 8962FT. 3/15/2016 00:00 - 03:15 3.25 STWHIP P WEXIT MILL WINDOW FROM 8962.4FT.DWOB 1.8-3.02K. 1.62/1.62 BPM IN/OUT 9.49/9.40 PPG AT 3890PSI. IA/OA 46/271 PSI(BLED IA FROM 175 PSI TO 0 PSI),ECD 11.30 MILL TO DEPTH OF 8965.5FT. *LOSS OF WOB AT 8964.72'.CONTINUE AT 1'/HR AS PER PLAN. 03:15 - 04:10 0.92 STWHIP P WEXIT 'I REAM WINDOW -PUMP 5 BBLS LO-VIS FOLLOWED BY 5 BBLS HI-VIS SWEEP 1-REAM WINDOW AS PLANNED 3 TIMES -PUW 41K,SOW 38K -SHUT DOWN PUMPS AND DRY DRIFT WINDOW AS DRILLED TOOLFACE -SOW 30K,PUW 45K 04:10 06:00 1.83 STWHIP P WEXIT POH WITH MILLING BHA#3 -POH ABOVE WINDOW FLOWCHECK WELL FOR 10 MINUTES-WELL STATIC -OPED EDC -POH WITH MILLING BHA -MM IN/OUT-1.96/1.57 BPM,MW IN/OUT- 9.50/9.36 PPG,PUMP PRESSURE-3620 PSI, PUW 34K FLOWCHECK BEFORE BHA CROSSES BOP STACK-WELL STATIC -POP OFF WITH INJECTOR Printed 4/25/2016 8:50:09AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 6 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING @67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 06:15 0.25 STWHIP P WEXIT BREAK OFF BHA#3,MILL GAUGED AT 2.80 NO GO,STRING REAMER GAUGED OUT AT 2.79 GO,2.78 NO GO. -SEND MOTOR TO BOT TO REMOVE MILL AND BUCK UP NEW MILL FOR NEXT RUN. 06:15 - 07:00 0.75 STWHIP N WEXIT WAIT ON MOTOR AND FAT RADIUS MILL TO RETURN FROM BOT MACHINE SHOP TO BE TORQUED UP 07:00 - 08:00 1.00 STWHIP P WEXIT MOTOR BACK ON LOCATION. CHANGE BEND ON MOTOR TO 2.0°,MU SECOND MILLING BHA#4. STAB ON WITH INJECTOR. 08:00 - 11:30 3.50 STWHIP P WEXIT PRESSURE TEST QUICK TEST SUB WHILE MWD INPUTS BHA INFORMATION AND POWERS ON. -RIH. LOG TIE-IN WITH+2'CORRECTION. RECORD UP AND DOWN WEIGHTS BEFORE MILLING OPERATION. EASE DOWN TO 8965' TO INITIATE MILLING. 11:30 - 18:00 6.50 STWHIP P WEXIT BEGIN MILLING OPERATION ON 7 CASING FROM 8966'. FREE SPIN OF 3580 PSI AT 1.65 BPM. MW IN 9.47 PPG,MW OUT 9.40 PPG,1 TO 1 RETURNS -MILL PER SCHEDULED TIME AND WOB PARAMETERS IN WELL PLAN. MAINTAIN CONSISTENT 1.61 BPM FLOW RATE. -CALCULATED EXIT AT 8969',INDICATIONS OF WOB DROPPING OFF ACCORDINGLY. CIRC PRESSURES REMAINED FAIRLY STEADY AT 3580-3680 PSI UNTIL MILL BEGAN TO CONTACT FORMATION. PRESSURES ROSE TO 3755-3780 PSI AT SAME FLOW RATE. -IA INCREASED FROM 25-140 PSI,OA FROM 70-435 PSI. 18:00 - 19:30 1.50 STWHIP P WEXIT MILL RATHOLE FROM 8972'.FREE SPIN OF 3580 PSI AT 1.65 BPM. -MM IN/OUT-1.61/1.62 BPM,MW IN/OUT- 9.50/9.41 PPG,CIRC PRESSURE 3699 PSI, TEMP IN/OUT 85.7/84.3 DEGREES WOB 2.5-3.8 K,EDC 11.31 PPG, -IA/OA-145/450 PSI.BLEED DOWN IAAND OA TOO PSI. -IA/OA 22/45 PSI -MILL TO 8975'(END OF RATHOLE) 19:30 - 22:50 3.33 STWHIP P WEXIT START REAMING PASSES. PUMP SWEEP -REAM WINDOW AT 45°LEFT /45°RIGHT -NO MOTOR WORK SEEN. -1.61 BPM IN /1.63 BPM OUT -9.48 PPG IN/9.40 PPG OUT 22:50 - 23:40 0.83 STWHIP P WEXIT SHUT PUMPS DOWN DRY DRIFT WINDOW. OPEN EDC. PUMP FINAL PILL TO BIT. 10 BBLS LOVIS /10 BBLS HIVIS 23:40 - 00:00 0.33 STWHIP P WEXIT PERFORM 10 MIN FLOW CHECK. WELL STATIC. POOH 3/16/2016 00:00 - 01:10 1.17 STWHIP P WEXIT POOH WITH WINDOW MILLING BHA 01:10 - 01:20 0.17 STWHIP P WEXIT PERFORM 10 MINUTE FLOW CHECK. WELL STATIC Printed 4/25/2016 8:50:09AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 7 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:OOAM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING @67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:20 - 02:00 0.67 STWHIP P WEXIT 'INJECTOR OFF AT 01:20 STAND-BACK INJECTOR. BLOW DOWN BHA. MILL GAUGED AT 2.80" GO/2.79"NOGO 02:00 - 02:50 0.83 DRILL P PROD1 CONFIGURE BUILD BHA. MAKE UP BHA#5 STAB INJECTOR AT 02:50 02:50 - 05:00 2.17 DRILL P PROD1 PT QTS 300/3500 RIH WITH BHA#5 05:00 - 05:30 0.50 DRILL P PROD1 LOG TIE IN.+1' CLOSE EDC RUN IN HOLE THROUGH WINDOW. 05:30 - 06:30 1.00 DRILL P PROD1 DRILL BUILD SECTION FREE SPIN=3550 PSI AT 1.47 BPM RATE IN=1.47 BPM RATE OUT=1.47 BPM MW IN=9.47 PPG MW OUT=9.41 PPG ECD 11.17 PPG WOB=1 K CIRC PSI=3750 PSI IAP=0 PSI OAP=0 PSI PVT=290 BBLS 06:30 18:00 11.50 DRILL P PROD1 DIFFICULTY INITIATING DRILLING WITH MULTIPLE STALLS EVEN WHEN MOVING SLOWLY AND APPLYING MINIMAL WOB. -VARY WOB AND PICK UP OFTEN TO MAINTAIN DRILLING WITHOUT STALLING MW IN 9.45 PPG,MW OUT 9.40 PPG,ECD OF 11.2 PPG,NO LOSSES TO FORMATION -INITIAL SAMPLE WAS 20%CHERT WITH HIGHLY CEMENTED FORMATION;SECOND SAMPLE FROM 9050'WAS-10%CHERT, AGAIN WITH CEMENTED FORMATION AND SOME INDICATIONS OF SILT/SHALE MIX DIRECTIONAL DRILLER FULLY UNDERSTANDS THAT DRILLING WILL NOT GO LOWER THAN TARGET TVD OF 8956' -INITIAL FREE SPIN OF 3550 PSI AT 1.47 BPM, INCREASED TO 3950 PSI WHEN CIRC RATE WAS BROUGHT UP TO 1.62 BPM -VARIED CIRC RATE FROM 1.47-1.62 BPM THROUGHOUT DAY,3645-4100 PSI CIRC PRESSURE -IA INCREASED TO 180 PSI,BLED DOWN TO 0 PSI,INCREASED TO 80 PSI AT 1800 HRS;OA ROSE SLOWLY THROUGHOUT DAY TO 325 PSI 18:00 - 00:00 6.00 DRILL P PROD1 -VARY WOB AND PICK UP OFTEN TO MAINTAIN DRILLING WITHOUT STALLING -MW IN 9.45 PPG,MW OUT 9.40 PPG,ECD OF 11.13 PPG,NO LOSSES TO FORMATION -SAMPLES STARTING TO SHOW CHERT PERCENTAGE AT-30%. ROP BETWEEN 20-30 FPH WITH MULTIPLE STALLS -CONTINUE DRILLING IN BUILD TO TARGET LANDING AT-8954'TVD 3/17/2016 00:00 - 02:30 2.50 DRILL P PROD1 CONTINUE TO DRILL BUILD MOTORWORK-250#, WOB 1-2K -1.58 BPM IN/1.58 BPM OUT -9.47 PPG IN /9.39 PPG OUT -SAMPLES COMING IN AT 30%CHERT, HEAVILY CEMENTED -IA CLIMBED TO 180#/OA TO 400# BLED BOTH DOWN Printed 4/25/2016 8:50:09AM "All depths reported in Drillers Depths* • North America-ALASKA-BP Page 8 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING @67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 05:30 3.00 DRILL P PROD1 DRILL AHEAD WITH 30%CHERT. CUTTINGS GETTING LARGER AT THE 9260 SAMPLE. PUMPED 10 BBL LO VIS FOLLOWED BY 15 BBL HI VIS. -10%INCREASE IN CUTTINGS CONTINUE DRILLING AHEAD 1.52 BPM IN/1.52 BPM OUT 9.45 PPG IN/9.39 PPG OUT 11.31 PPG ECD 05:30 - 06:30 1.00 DRILL P PROD1 PERFORM 10 MIN DYNAMIC FLOW CHECK. 0.54 BPM IN/0.52 BPM OUT WELL STATIC. PULL TO SURFACE,POP OFF. 06:30 - 07:30 1.00 DRILL P PROD1 STAND INJECTOR BACK. BREAK DOWN BHA. BIT GRADE 2-1-CT. CHANGE BEND IN MOTOR DOWN TO.86°AND MAKE UP HYCALOG 2.74" BY 3.25"BIT ON BHA#6. STAB ON WITH INJECTOR. 07:30 - 11:45 4.25 DRILL P PROD1 PRESSURE TEST QUICK TEST SUB WHILE MWD OPENS EDC AND INPUTS INFORMATION. RIH WITH BHA#6 WITH NO ISSUES. LOG TIE-IN WITH+1 CORRECTION. RUN THROUGH WINDOW AND DOWN TO CURRENT TD. 11:45 - 13:00 1.25 DRILL P PROD1 BACK ON BOTTOM. FREE SPIN OF 3450 PSI 1AT1.5BPM. -DRILL TO 9348'MD,RECEIVE CALL FROM GEO THAT HOT CAME IN 4'TVD EARLIER THAN EXPECTED. REQUESTED TO CONDUCT WIPER WHILE TEAM DISCUSSES PATH FORWARD. 13:00 - 13:30 0.50 DRILL P PROD1 CONDUCT GEO WIPER. -1.51 BPM,3400 PSI, 11.1 ECD -PLAN FORWARD RECEIVED FROM GEO, TURN AROUND TO RUN DOWN 13:30 - 18:00 4.50 DRILL P PROD1 RUN BACK DOWN TO DRILLAHEAD. FREE SPIN OF 3540 PSI AT 1.6 BPM -DRILLAHEAD AT 1.61-16.3 BPM,3610-3750 PSI -PLACING CONSISTENT WOB OF 1.5-2.0 IN ATTEMPT TO MAINTAIN BUILD SEEMS TO WORK FAIRLY WELL,IMMEDIATE CHANGE IN INCLINATION AS SOON AS WEIGHT COMES OFF OF BIT,HAVING TOAPPLYA LOT OF WEIGHT OF UP TO 3.75K -MW IN 9.45,MW OUT 9.40,ECD OF 11.2 PPG, NO LOSSES TO FORMATION IA ROSE TO 35 PSI,OA ROSE TO 85 PSI Printed 4/25/2016 8:50:09AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 9 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING©67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 20:46 2.77 DRILL P PROD1 DRILL LATERAL SECTION 9452'TO 9523' FREE SPIN=3590 PSI AT 1.60 BPM RATE IN=1.61 BPM RATE OUT=1.62 BPM MW IN=9.46 PPG MW OUT=9.41 PPG ECD =11.28 PPG MW TEMP IN=93.6 DEG MW TEMP OUT=90.5 DEG BHT=154 DEG -ROP=60 FPH WOB=2-3 K CIRC PSI= 3590 PSI IAP=43-56 PSI OAP=101-126 PSI PVT=371 BBLS BUILDING INCLINATION TO GET OUT OF 14N. HAD ISSUES COMING UP. BROKE THROUGH AND STARTED BUILDING ANGLE TO QUICKLY. HAVING TO KEEP TOOLFACE POINTED STRAIGHT DOWN.TO GET BACK TO GEO TARGET. SKIPPING OFF STRUCTURE TRYING TO GET BACK DOWN TO TVD. GETTING BEHIND IN TURN DO TO LOWAKO. DISCUSSION-WITH DD. PULL TO DIAL MOTOR UP. 20:46 - 21:00 0.23 DRILL P PRODY PERFORM 10 DYNAMIC FLOW CHECK 0.54 BPM IN/0.52 BPM OUT 9.40 PPG IN/9.40 PPG OUT WELL STATIC 21:00 - 22:50 1.83 DRILL P PROD1 POOH TO SURFACE. PJSM FOR FLOW CHECK AND LAYING DOWN BHA. 22:50 - 23:10 0.33 DRILL P PROD1 PERFORM 10 MIN FLOW CHECK.CLOSE EDC. POWER DOWN. PULL TO SURFACE TAG UP. 23:10 - 23:45 0.58 DRILL P PROD1 INJECTOR OFF AT 23:10. SWAP MOTOR OUT FOR 1.2°AKO. BIT GRADED 1-2-CT INJECTOR ON AT 23:34. PRESSURE TEST QTS WHILE MWD DID TOOL CHECKS 23:45 - 00:00 0.25 DRILL P PROD1 RUN IN HOLE WITH BHA#7 3/18/2016 00:00 - 01:45 1.75 DRILL P PROD1 LOG TIE IN WITH-3'CORRECTION 01:45 - 02:20 0.58 DRILL P PROD1 RIH TO BOTTOM 02:20 - 03:10 0.83 DRILL P PROD1 DRILL LATERAL SECTION 9523'TO 9542' FREE SPIN=3500 PSI AT 1.53 BPM RATE IN=1.56 BPM RATE OUT=1.56 BPM MW IN=9.46 PPG MW OUT=9.39 PPG ECD =11.21 PPG ROP=34FPH WOB=2.9K CIRC PSI= 3347 PSI IAP=0 PSI OAP=0 PSI PVT=366 BBLS GAMMA RAY SIGNATURE SHOWING POSSIBLE 14N COMING UP QUICKER THAN EXPECTED. WELLSITE GEOLOGIST DISCUSSING WITH TOWN GEOLOGY. 03:10 - 03:50 0.67 DRILL P PROD1 PERFORM GEO WIPER/PUMP BOTTOMS UP SAMPLE. SOME MOTOR WORK SEEN WHILE PULLING BY-9,415' Printed 4/25/2016 8:50:09AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 10 of 18 Operation Summary Report Common Well Name:C-21 _ AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING©67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:50 - 06:00 2.17 DRILL P PROD1 CONTINUE TO DRILL AHEAD WITH MULTIPLE STALLS. VERY SLOW TO GET DRILLING INITIATED AT 9551' FREE SPIN=3500 PSI AT 1.53 BPM RATE IN=1.56 BPM RATE OUT=1.56 BPM MW IN=9.46 PPG MW OUT=9.41 PPG ECD =11.20 PPG WOB=2-3K CIRC PSI=3500-3900PSI IAP=0 PSI OAP=40 PSI PVT=366 BBLS 06:00 - 18:00 12.00 DRILL P PROD1 DRILL AHEAD FROM 9525. FREE SPIN OF 3730 PSI AT 1.68 BPM. -DRILL AHEAD IN PRIMARILY SAND FORMATION AND NO DIFFICULTY STEERING -CONDUCT KICK WHILE DRILLING DRILL. SIMULATE DENSITY DROP AND INCREASE IN FLOW ON MONITORS IN COIL TUBING OPERATIONS CAB. NOTIFY NORDIC DRILLER,CREW REACTED ACCORDING TO THE STANDING ORDERS. SIMULATED CONTINUED FLOW WITH PUMPS OFF,CREW SHUT IN. SIMULATED PACKOFF FAILURE, REACTED BY CLOSING ANNULAR ELEMENT. WELL SHUT IN PER STANDING ORDERS IN 3-1/2 MINUTES. CALL ALL CLEAR,CONDUCT AAR. -CONTINUE WITH DRILLING -BLEED IA DOWN FROM 180 PSI TO 0 PSI, BUILT UP TO 60 PSI;OA AT 215 PSI -MW IN 9.45 PPG AND ROSE TO 9.50 PPG, MW OUT 9.41 PPG ROSE TO 9.43 PPG,ECD ROSE FROM 11.1 PPG TO 11.4 PPG,SLIGHT LOSSES TO FORMATION WOB RANGED FROM 1.3-3.6K,ROP FAIRLY CONSISTENT AT-50 FPH 18:00 - 19:38 1.63 DRILL P PROD1 DRILL AHEAD WITH CONSISTENT ROP. SAMPLES COMING UP PRIMARILY SAND. LET DRILL OFF. PERFORM WIPER TRIP TO WINDOW FOR TIE 19:38 - 20:20 0.70 DRILL P PROD1 PERFORM WIPER WITH NO ISSUES TO WINDOW 20:20 - 20:40 0.33 DRILL P PROD1 LOG TIE IN TO RA TAG WITH+8'CORRECTION 20:40 - 21:20 0.67 DRILL P PROD1 RIH TO BOTTOM 21:20 - 22:34 1.23 DRILL P PROD1 DRILL LATERAL FROM 10000'TO 10066' FREE SPIN=3732 PSI AT 1.62 BPM RATE IN=1.63 BPM RATE OUT=1.63 BPM MW IN=9.50 PPG MW OUT=9.43 PPG ECD =11.46 PPG WOB=2-3K CIRC PSI=3500-3900PSI IAP=0 PSI OAP=162 PSI PVT=350 BBLS TOOLS KEEP GETTING PUSHED DOWN. PERFORM SHORT WIPER WHILE PUMPING BOTTOMS UP SAMPLE FOR GEOLOGY 22:34 - 23:45 1.18 DRILL P PROD1 WIPER. SAMPLE FROM 10066' HAS HOT IN IT. DECISION START CLIMBING IN INCLINATION TO GET OUT OF HOT Printed 4/25/2016 8:50:09AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 11 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:O0AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING @67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:45 - 00:00 0.25 DRILL P PROD1 DRILL LATERAL FROM 10066'TO 10070 FREE SPIN=3732 PSI AT 1.62 BPM RATE IN=1.63 BPM RATE OUT=1.63 BPM MW IN=9.50 PPG MW OUT=9.43 PPG ECD =11.46 PPG WOB=2-3K CIRC PSI=3500-3900PSI IAP=60 PSI OAP=214 PSI PVT=347 BBLS 3/19/2016 00:00 - 04:00 4.00 DRILL P PROD1 DRILL LATERAL FROM 10070'TO 10170' FREE SPIN=3732 PSI AT 1.62 BPM RATE IN=1.63 BPM RATE OUT=1.63 BPM MW IN=9.50 PPG MW OUT=9.42 PPG ECD =11.33 PPG WOB=2-3K CIRC PSI=3700-4000PSI IAP=150 PSI OAP=292 PSI PVT=343 BBLS (BLED DOWN IAAND OA TO 0 PSI GEOLOGY MAKING A LOT OF ADJUSTMENTS. GET INSTRUCTION FROM TOWN GEOLOGIST TO HOLD 90°. STRUCTURE IS KEEPING US AT-8951'TVD. I PERFORM SHORT WIPER WHILE GETTING WRITTEN PLAN FROM TOWN GEOLOGY. 04:00 - 05:20 1.33 DRILL P PROD1 400'WIPER ,PUMP UP BOTTOMS UP SAMPLE.GEO ANALYZED. HEAD BACK TO BOTTOM. RECIEVE PLAN FROM TOWN GEOLOGY. PLAN TO TARGET 8948'TVD AT 10317'MD @ 90.5 DEGREES TO TARGET SANDS SEEN AT 10040'. 05:20 - 10:45 5.42 DRILL P PROD1 DRILL LATERAL FROM 10170'TO 10358' FREE SPIN=3750 PSI AT 1.62 BPM RATE IN=1.63 BPM RATE OUT=1.63 BPM MW IN=9.50 PPG MW OUT=9.42 PPG ECD =11.33 PPG WOB=2-3K CIRC PSI=4000-4150 PSI IAP=13 PSI OAP=65 PSI PVT=340 BBLS HAVING DIFFICULTIES GETTING TO TARGET TVD OF 8948'.TRYING TO COME UP,BUT STRUCTURE IS KEEPINT US AT-8951'. KEEPING TOOLFACE UP.GOOD MOTORWORK AND ROP BETWEEN 35-50 FT/HR INDICATES BIT IS STILL IN GOOD SHAPE. TARGETED SAND AT-8951 TVD.ATTEMPTING TO STAY IN THIS SAND. 10:45 - 11:20 0.58 DRILL P PROD1 STILL GOOD MOTORWORK,BUT HAVING TO PUSH ON BIT TO GET WOB. WIPER TRIP TO 9900' PUMP LO-VIS SWEEP FOLLOWED BY HI-VIS SWEEP AROUND-NO SIGNIFICANT CUTTINGS NOTICED ON SHAKERS 11:20 - 14:20 3.00 DRILL P PROD1 DRILL LATERAL FROM 10358'TO 10452' FREE SPIN=3780 PSI AT 1.62 BPM RATE IN=1.62 BPM RATE OUT=1.62 BPM MW IN=9.51 PPG MW OUT=9.41 PPG ECD =11.33 PPG WOB=2.5-3.5K CIRC PSI=3850-4100 PSI IAP=62 PSI OAP=98 PSI PVT=331 BBLS NOTICED SLIGHT SEEPAGE LOSSES-3 BBLS DURING THIS TIME FRAME Printed 4/25/2016 8:50:09AM *All depths reported in Drillers Depths* • North America-ALASKA-BP S Page 12 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA •UWI:500292075300 Active datum:ORIG KELLY BUSHING©67.50usft(above Mean Sea Level) Date From-To Hrs Task Code ! NPT NPT Depth Phase Description of Operations (hr) (usft) 14:20 - 16:15 1.92 DRILL P PROD1 WIPER TRIP TO WINDOW WITH NO ISSUES LOG TIE IN AT RA TAG WITH+13' CORRECTION LOST 4 BBLS DURING THIS WIPER TRIP DUE TO SEEPAGE 16:15 - 21:15 5.00 DRILL P PROD1 DRILL LATERAL FROM 10452'TO 10,630' FREE SPIN=3700 PSI AT 1.60 BPM RATE IN=1.60 BPM,RATE OUT=1.59 BPM ,MW IN= 9.52 PPG,MW OUT 9.46 PPG,ECD= 11.46 PPG WOB=2.0-3.8K,CIRC PSI=3850-4050 PSI IAP=71-114 PSI,OAP=133-151 PSI,PVT= 324-317 BBLS SLIGHT SEEPAGE NOTICED(-1 BBUHR LOSSES) 21:15 - 22:18 1.05 DRILL 1 P PROD1 ATTEMPT TO INITIATE DRILLING. SLIDE • STARTING TO BEAN ISSUE.TAKING HIGH WOB 2.5-3.5 K TO GET VERY MINIMAL MOTOR 1 WORK. PUMP 10 BBLS LOVIS/10 BBLS HI VIS TO TRY TO RULE OUT MUD. ONCE SWEEP ARRIVED. HELPED WITH SLIDE. CONTINUE DRILLING WHILE WAITING ON !MUD. 22:18 - 00:00 1.70 DRILL P PROD1 CONTINUE TO FIGHT SLIDE. NEW MUD ARRIVED. PREPARE FOR MUD SWAP 3/20/2016 00:00 - 04:00 4.00 DRILL P PROD1 DRILL LATERAL FROM 10711'TO 10756 FREE SPIN=3780 PSI AT 1.62 BPM !RATE IN=1.62 BPM RATE OUT=1.62 BPM MW IN=9.51 PPG MW OUT=9.41 PPG ECD =11.33 PPG WOB=2.5-3.5K CIRC PSI=3850-4100 PSI IAP=0 PSI OAP=0 PSI PJSM, SPEAR IN WITH 30 BBLS HI VIS. NEW MUD BEHIND THAT. MADE SEVERAL ATTEMPTS TO INITIATE DRILLING. ALL SIGNS ARE BIT IS WORN OUT. 04:00 - 06:30 2.50 DRILL P PROD1 PERFORM 10 MIN DYNAMIC FLOW CHECK WELL STATIC. WIPER TO WINDOW. POOH TO SURFACE. PJSM FOR FLOW CHECK AND LAYING DOWN BHA. -PULL BHA TO BELOW BOP,FLOW CHECK. ALL GOOD,POP OFF WITH INJECTOR. 06:30 - 07:30 1.00 DRILL P PROD1 SET INJECTOR TO SIDE. BLOW DOWN AND LAY DOWN BHA. BIT GRADE 4-4-BT AND RO. -CONDUCT FUNCTION TEST WITH 2"AND 2-3/8"TEST JOINTS;FUNCTION RAMS AND BAG FROM DRILLER'S CONSOLE ON RIG FLOOR -CLEAN UP FROM FUNCTION TEST Printed 4/25/2016 8.50:09AM *All depths reported in Drillers Depths* North America-ALASKA-BP S Page 13 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING @67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 11:15 3.75 DRILL P PROD1 PJSM ON CUTTING COIL FOR CHROME MANAGEMENT. DISCUSS THE HAZARDS ASSOCIATED WITH USING CUTTER, WORKING WITH MOVING COIL. TEAM UNDERSTANDS WHERE TO POSITION THEMSELVES WHILE CUTTING COIL AND HANDLING CUT PIECES. -CUT 100'OF COIL,BREAK OF PIPE CUTTER. MU LUBRICATOR EXTENSION. —PREPARE COIL END FOR CONECTOR. INSTALL CONNECTOR,PULL TEST TO 35K. CONDUCT MEG TEST AGAINST E-LINE, GOOD TEST. HEAD UP WITH BHI UPPER QUICK CONNECT. PRESSURE TEST DUAL FLOAT VALVES TO 250 PSI LOW/3500 PSI HIGH. 11:15 - 11:45 0.50 DRILL P PROD1 PJSM ON MAKING UP BHA#8. MU LATERAL BHA WITH AGITATOR ONTO BHI XTREME MOTOR WITH 1.15°BEND AND HCC 3.25"BIT. STAB ON WITH INJECTOR. PRESSURE TEST QUICK TEST SUB WHILE MWD INPUTS DATA AND POWERS UP EQUIPMENT. 11:45 - 15:15 3.50 DRILL P PROD1 RIH TO 200',SURFACE TEST AGITATOR AT 1.35 BPM IN 9.45 PPG MUD. GOOD INDICATION THAT AGITATOR IS WORKING. -RIH WITH BHA#8,LOG TIE IN WITH-3' CORRECTION. CONTINUE TO RIH. SLACK OFF WEIGHT IN CASED HOLE 30.4K. SLACK OFF WEIGHT IN OPEN HOLE 26-28K. CIRC PRESSURE OF 2310 AT.85 BPM WHILE RUNNING IN. 15:15 - 18:00 2.75 DRILL P PROD1 I BACK ON BOTTOM. FREE SPIN OF 3660 PSI AT 1.50 BPM. -DRILL AHEAD BEGINNING WITH 1.42 BPM FLOW RATE -THIS ISA RARE INSTANCE OF RUNNING THE AGITATOR SET TO A 9.5 PPG MW WITH THE BAKER XTREME MOTOR(HI-SPEED MOTOR) on 2"COIL TOOLS. TEAM UTILIZED THIS MOTOR DUE TO EXPECTED LOW FLOW RATES BECAUSE OF THE INCREASED PRESSURE LIMITATIONS. INITIAL INDICATIONS ARE THAT ROP IS DOING VERY WELL(100 FPH)WITHOUT THE SEVERE VIBRATIONS SEEN IN THE PAST WHEN USING THE ULTRA LOW SPEED MOTOR COMBINED WITH THE AGITATOR. -OBSERVING THE SAME DIRECTIONAL PERFORMANCE AS THE ULS MOTOR WITH APPROXIMATELY THE SAME WOB AND LOWER FLOW RATE/HIGHER REVOLUTIONS FROM MOTOR -FLOW RATE OF 1.38-1.50 BPM,3620-3865 PSI,WOB RELATIVELY LOWAT 1-2K,ECD OF 11.5 TO 11.6 PPG -MW IN 9.54 PPG,MW OUT 9.50 PPG,NO LOSSES TO FORMATION -IAAND OA STAYED AT 0 PSI DURING THIS DRILLING PHASE Printed 4/25/2016 8:50:09AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 14 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING @67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 22:30 4.50 DRILL P PROD1 DRILL LATERAL FROM 10930'-11121' FREE SPIN=4000 PSI AT 1.53 BPM RATE IN=1.53 BPM RATE OUT=1.53 BPM MW IN=9.56 PPG MW OUT=9.48 PPG ECD =11.67 PPG WOB=2.5-3.5K CIRC PSI=3850-4300 PSI IAP=0 PSI OAP=0 PSI HAVING TO STAY ABOVE 4200#. DOESN'T APPEAR AGITATOR STARTS HELPING TILL WE GET ABOVE 1.54 BPM. START HAVING WEIGHT TRANSFER ISSUES AT 11100' PUMP 10 LO/10 HI SWEEP TO AID IN CUTTINGS REMOVAL 22:30 - 23:00 0.50 DRILL P PROD1 PERFORMED COMPLEX KICK WHILE DRILLING DRILL SCENARIO:SIMULATED FLOW. COIL WAS PICKED OFF BOTTOM.PUMPS OFFLINE. PERFORMED FLOW CHECK. WELL FLOWING. SIMULATED INCREASING PACKOFF PRESSURE. DRILLER SIMULATED CLOSING CHOKE HCR. WSL CALLED HCR DID NOT CLOSE. CREW REACTED APPROPRIATELY -BY CLOSING CM#13. 23:00 - 00:00 1.00 DRILL P PROD1 NOT GETTING ANY WEIGHT TRANSFER. PERFORM LONG WIPER TO WINDOW. 3/21/2016 00:00 - 01:45 1.75 DRILL P PROD1 WIPER TO WINDOW -OPEN EDC. PUMP 10 BBL HIVIS PUMP BOTTOMS UP. CUTTINGS RETURN OF ABOUT-20%INCREASE 01:45 - 02:00 0.25 DRILL P PROD1 CLOSE EDC LOG TIE IN TO RA TAG WITH+16' CORRECTION 02:00 - 03:20 1.33 DRILL P PROD1 RIH TO BOTTOM 03:20 - 06:30 3.17 DRILL P PROD1 DRILL LATERAL FROM 11169'TO 11250 1 FREE SPIN=3680 PSI AT 1.43 BPM RATE IN=1.43 BPM RATE OUT=1.43 BPM MW IN=9.56 PPG MW OUT=9.50 PPG ECD =11.55 PPG WOB=2.5-3.5K CIRC PSI=3850-4300 PSI IAP=0 PSI OAP=0 PSI 06:30 - 08:30 2.00 DRILL P PROD1 j NO MOVEMENT OF PIPE ON PICKUP. PICK UP WAS HEAVY AT-25-30K OVERPULL (NORMAL PICKUP OF 35-40K). MAKE SEVERAL ATTEMPTS TO MOVE PIPE. WORK PIPE,NO LUCK. FOLLOW WELL PLAN FOR DIFFERENTIAL STICKING. Printed 4/25/2016 8:50:09AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 15 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING(4267.5ousft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 13:15 4.75 DRILL P PROD1 CONDUCT WIPER UP TO WINDOW. OVERPULL AND WORK THROUGH SHALE ZONE AT 10,650'TO 10,630'. NO FURTHER ISSUES COMING TO WINDOW. -PULL INTO WINDOW,LOG TIE-IN TO RA TAG WITH+18'CORRECTION. OPEN EDC IN ATTEMPT TO FLUSH TUBING OF CUTTINGS. HAVING VERY HIGH CIRC PRESSURES AT 1.4 BPM. JOG DOWN AT HIGH RUNNING SPEED TO CLEAR TUBING. NEXT PASS UP LOWERED CIRC PRESSURE BY 400 PSI AND ABLE TO INCREASE FLOW RATE TO 2.0 BPM. -CIRCULATE TOTAL OF 4 BOTTOMS UP FROM WINDOW BEFORE SHAKER CLEANED UP. A LOT OF SHARP-GRANULED CUTTINGS AND SHALE CUTTINGS MIXED WITH SMALL AMOUNT OF PEA-SIZE ANGULAR GRAVEL RETURNED. LOG CCL FOR LINER TOP PLACEMENT ON TRIP BACK DOWN -SLACK OFF WEIGHT IN CASED HOLE OF 25-28K,CIRC PRESSURE OF 3980 PSI AT 2.0 BPM WITH EDC OPEN -CLOSE EDC,EXIT WINDOW 13:15 - 14:35 1.33 DRILL P PROD1 RIH WITH FAIRLY STEADY SLACK OFF WEIGHT OF 26-28K,CIRC PRESSURE OF 3750 PSI AT 1.35 BPM. MOTORWORKAND STACKED WEIGHT IN SHALE STRINGER FROM 10,360-390'. ABLE TO MOVE THROUGH. ENGAGE BOTTOM ON DEPTH AT 11,323'. 14:35 - 16:45 2.17 DRILL N DFAL 11,372.00 PROD1 BACK ON BOTTOM. DRILL AHEAD FROM 11,323'. FREE SPIN OF 3790 PSI AT 1.41 BPM. -IMMEDIATE DRILLING REACTION IS FAIRLY GOOD BUT QUICKLY FELL OFF. EXTREMELY DIFFICULT TO GET ANY DRILLING PROGRESS !FROM 11,360'. MAKE SEVERAL ATTEMPTS TO DRILL AHEAD WITH WIPERS,VARYING FLOW AND WOB,ATTEMPTS TO ENGAGE FORMATION. FIND LARGE AMOUNTS OF RUBBER ON SHAKER CHECK. -CONDUCT DYNAMIC FLOW CHECK OFF BOTTOM,ALL GOOD 16:45 - 19:30 2.75 DRILL N DFAL 11,372.00 PROD1 POH FOR BHA INSPECTION AND CHANGE. PERIODIC OVERPRESSURE,MOST LIKELY DUE TO RUBBER CHUNKING AT BIT. 19:30 - 19:50 0.33 DRILL N DFAL 11,372.00 PROD1 PERFORM 10 MIN FLOW CHECK. WELL STATIC. CLOSE EDC SHALLOW TEST AGITATOR, SLOWLY INCREASE RATE TO 2.0 BPM. AGITATOR NOT WORKING. 19:50 - 21:00 1.17 DRILL N DFAL 11,372.00 PROD1 INJECTOR OFF AT 19:50 STAND BACK UPPER SECTION OF COILTRAK LAY DOWN AGITATOR AND MOTOR. BIT GRADED 2-3-BT (2)PLUGGED NOZZLES I MAKE UP 2-3/8"ULS MOTOR WITH 1.2°AKO WITH NEWAGITATOR MAKE UP UPPER COIL TRACK TOOLS INJECTOR ON AT 21:00 Printed 4/25/2016 8:50:09AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP S Page 16 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING©67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 23:10 2.17 DRILL N DFAL 11,372.00 PROD1 PT QTS WHILE MWD CHECKS TOOLS. RIH TO 250'. SHALLOW TEST AGITATOR. AGITATOR WORKING OPEN EDC. CIRCULATE AT 1.55 BPM ON WAY IN HOLE TO HELP CLEAN HOLE. 9.48 PPG IN /9.45 PPG OUT 23:10 - 23:30 0.33 DRILL N DFAL 11,372.00 PROD1 I LOG TIE IN WITH A-8'CORRECTION 23:30 - 00:00 0.50 DRILL N DFAL 11,372.00 PROD1 RIH 3/22/2016 00:00 - 01:30 1.50 DRILL N DFAL 11,372.00 PROD1 RIH TO TD 01:30 05:30 4.00 DRILL P PROD1 DRILL LATERAL FROM 11372'TO 11550' FREE SPIN=3940 PSI AT 1.41 BPM RATE IN=1.41 BPM RATE OUT=1.40 BPM MW IN=9.50 PPG MW OUT=9.48 PPG ECD =11.72 PPG WOB=2.5-3.5K CIRC PSI=3940-4100 PSI IAP=0 PSI OAP=0 PSI 05:30 - 06:00 0.50 DRILL P ' PROD1 PERFORM WIPER TRIP FROM 11550'TO 11200'. PUMP LO-VIS SWEEP FOLLOWED BY HI-VIS SWEEP. NO ISSUES OBSERVED DURING TRIP 06:00 - 12:00 6.00 DRILL P PROD1 BACK ON BOTTOM,DRILL AHEAD 'DIRECTIONALLY FROM 11,575'. FREE SPIN OF 3800 PSI AT 1.41 BPM. -STICK SLIP IS BECOMING AN ISSUE FROM 11,660'. -SAMPLES COMING UP ARE SHOWING 30% CHERT AT 11700' -WIPER UP TO 11350'WHILE GEOLOGY GETS PLAN FORWARD. 12:00 15:00 3.00 DRILL P PROD1 DRILL LATERAL FROM 11575'TO 11,800' FREE SPIN=3940 PSI AT 1.41 BPM RATE IN=1.44 BPM RATE OUT=1.42 BPM MW IN=9.54 PPG MW OUT=9.48 PPG ECD =11.59 PPG WOB=2.5-3.0K CIRC PSI=3940-4200 PSI IAP=0-45 PSI OAP=0-90 PSI -2 BPH SEEPAGE LOSSES 'WEIGHT TRANSFER BECOMING ISSUE. PUMP 10 BBLS LO VIS/10 BBLS HI VIS WIPER TO WINDOW FOR TIE IN/CLEAN UP CUTTINGS IN THE HOLE 15:00 - 17:00 2.00 DRILL P PROD1 WIPER TRIP BACK TO WINDOW. CLEAN PASS THORUGH SHALES,NOTHING SEEN. PULLABOVE WINDOWAND OPEN EDC,PUMP 1.5X BOTTOMS UP 2 BPM WHILE TIE-IN DEPTH FROM 8640 FT. CORRECT+19 FT. 17:00 18:30 1.50 DRILL P PROD1 RUN BACK TO BOTTOM,PUMP 1 BPM WHILE RIH AND MAINTAIN CORRECT TF PASSING THORUGH SHALES. CLEAN PASS TO BOTTOM. STACK WT ONCE AT 10637 FT AND BOUNCE THROUGH. Printed 4/25/2016 8:50:09AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 17 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING @67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 19:50 I 1.33 DRILL P PROD1 TAG BOTTOM AT 11806 FT. DRILL FROM 11806 FT DRILL WITH 2-3K DWOB. SAWTOOTH DRILLING,POOR WT TRANSFER. NO INDICATION OF AGITATOR WORKING. HOLD 135R TF FOR NOW TO REDUCE INC TO 85 DEG,AS PER GEO. 1.35/1.32 BPM WITH FREE SPIN 3800 PSI. DRILL PAST 11850 FT,ROP IMPROVES. 19:50 - 00:00 4.17 DRILL P PROD1 DRILLING AT 11850 FT ROP IS 50-60 FT/HR WITH 2-3K DWOB. PUMP 10 BBLS LO/HI VIS SWEEP AROUND. 3/23/2016 00:00 - 03:20 3.33 DRILL P PROD1 DRILL LATERAL FROM 11932'TO 11990' FREE SPIN=3940 PSI AT 1.38 BPM RATE IN=1.38 BPM RATE OUT=1.36 BPM MW IN=9.53 PPG MW OUT=9.48 PPG ECD =11.72 PPG WOB=2.5-3.5K CIRC PSI=3940-4300 PSI IAP=62 PSI OAP=116 PSI AVERAGING-2 BPH LOSSES AVERAGING 20 FPH. WEIGHT TRANSFER BECOMING ISSUE. SAMPLES SHOW BETWEEN 30-50%CHERT PUMP MULTIPLE LO VIS SWEEPS. 'DISCUSS WITH WELLSITE GEO/BIT IS WORN OUT. DISCUSS WITH ODE. CALL TD AT 11990' UNCORRECTED 03:20 - 05:30 2.17 DRILL P PROD1 WIPER FROM TD AT 25-30 FPM USING CAUTION AROUND SHALES RATE IN=1.41 BPM RATE OUT=1.28 BPM MW IN=9.55 PPG MW OUT=9.48 PPG ECD 11.55 PPG 05:30 - 06:00 0.50 DRILL P PROD1 -WINDOW -OPEN EDC, PUMP BOTTOMS UP WHILE JETTING/TIEING IN TO FORMATION. +17' CORRECTION 06:00 - 07:40 1.67 DRILL P PROD1 CLOSE EDC RUN IN HOLE FOR 2ND WIPER RIH AT 0.8 BPM,MAINTAIN CORRECT TF THROUGH SHALES. TAG BOTTOM AT 11991 FT,CORRECTED DRILLED DEPTH. CLEAN PASS TO BOTTOM. 07:40 - 09:00 1.33 DRILL I P PROD1 PICK UP TO WINDOW FOR SECOND WIPER TRIP.CLEAN PASS TO WINDOW PUMP 1.3 BPM BACK TO WINDOW. 09:00 - 10:50 1.83 DRILL P PROD1 RIH TO BOTTOM,PUMP 0.7 BPM. CLEAN PASS EXCEPT 1 SET DOWN AT 10,620 FT. AT TD,CONDUCT DYNAMIC FLOW CHECK, I GOOD 0.53/0.48 BPM AT 5 FT/MIN POOH. 10:50 - 14:30 3.67 ' DRILL P PROD1 POOH LAY IN LINER PILL WITH NEW DRILLING FLUID. PULL INTO CASED HOLE AND OPEN EDC, PUMP 1.8 BPM WHILE POOH. TIE-IN AND CORRECT DEPTH,+27 FT. FLAG PIPE WHILE POOH,8579 FT EOP,5588 FT EOP. I CONTINUE POOH. RUN BACK THROUGH 5-1/2"CASING SECTION TO CLEAN THIS AREA. Printed 4/25/2016 8:50:09AM `AII depths reported in Drillers Depths* • North America-ALASKA-BP S Page 18 of 18 Operation Summary Report Common Well Name:C-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2016 End Date:3/23/2016 X3-017L6-C:(3,764,930.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING©67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 15:00 0.50 DRILL P PROD1 CONDUCT PJSM WHILE POOH. NEAR SURFACE,10 MIN FLOWCHECK IS GOOD,NO FLOW. CONDUCT SHALLOW HOLE TEST OF AGITATOR,ACTIVATES WEAKLY UP TO 1.4 BPM THEN BETTER AFTER 1.5 BPM. 15:00 - 15:40 0.67 DRILL P PROD1 TAG STRIPPER,INJECTOR OFF AT 15:00. L/D BHA,BIT IS 4-3 RO. MOVE TO CON EVENT FOR NEXT OPERATION. Printed 4/25/2016 8.50:09AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 1 of 4 Operation Summary Report Common Well Name:C-21 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/23/2016 End Date: X3-017L6-C:(1,651,974.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING©67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/23/2016 15:40 - 16:00 0.33 CEMT P RUNPRD PUMP 190 FT OF CABLE SLACK OUT,LEAVES 55 FT ACCORDING TO SLB SPREADSHEET. 16:00 - 17:20 1.33 CEMT P RUNPRD INSTALL BTT CONNECTOR. PULL TEST TO 35K,PT TO 300/3800 PSI, GOOD. 17:20 - 18:00 0.67 CEMT P RUNPRD PUMP 3/4 DRIFT BALL AROUND,CATCH IN NOZZLE AT RIG FLOOR. 18:00 - 00:00 6.00 CEMT P RUNPRD PJSM, WSL/DRILLER/TOOLPUSHER VERIFIED LINER LAY OUT. MAKE UP LINER. DRIFT 1ST 5 CONNECTIONS PER PROGRAM. FILL HOLE EVERY 20 JOINTS. LOSING ABOUT 2 BPH. MADE UP LINER PER APPROVED LINER TALLY. i COUNT REMAINING JOINTS(12 REMAINING 1-STL, 11 TH511) EVERYONE AGREED MAKE UP LINER RUNNING TOOL AT REPORT TIME 3/24/2016 00:00 - 00:15 0.25 CEMT P RUNPRD MAKE UP LINER RUNNING TOOL AND REMAINDER OF BHA STAB INJECTOR. PT QTS BOTH LOW/HI 00:15 - 03:30 3.25 CEMT P RUNPRD -SLOW GOING THROUGH WINDOW 38KUP/25K —RUN TO BOTTOM WITH NO ISSUE. -BOTTOM FLAG AT 11803.45' -8579'-5'PIPE CUT=CEOP OF 8574' +3220.18' =11794.18' -CORRECTION OF-9.27' -WORK LINER TO A SOLID BOTTOM OF 12001' -9.27'=11991'CORRECTED. BREAKOVER 11988'AT 43K 03:30 - 06:00 2.50 CEMT P RUNPRD LOAD AND LAUNCH 5/8"STEEL BALL. BALL OVER GOOSE NECK AT 10.5 BBLS 1.21 BPM IN/1.21 BPM OUT 9.55 PPG IN/9.44 PPG OUT SLOW RATE TO.75 BPM AT 24 BBLS AWAY BALL DID NOT LAND ON TIME. PUMPING PAST DISPLACEMENT JOCKEY RATES AROUND TO GET BALL TO LAND 06:00 - 06:40 0.67 CEMT P RUNPRD BALL LANDS AND SHEARS OUT. NEW UP WT IS 35K. SET BACK DOWN AND CIRCULATE,OBSERVE ANOTHER PRESSURE SPIKE. AFTER PUMPING CALCULATED LINER LINER VOLUME PRESSURE SPIKES AGAIN, APPEARS THAT LWP HAS LANDED IN COLLAR,STILL ABLE TO PUMP PAST IT AT 0.46 BPM/3500 PSI. 06:40 - 09:40 3.00 CEMT N DFAL RUNPRD DISCUSS WITH CTD SI AND ODE,DISCUSS PLAN FORWARD. 09:40 - 11:15 1.58 CEMT P RUNPRD POOH WITH LINER RUNNING TOOLS. 11:15 - 12:00 0.75 CEMT N DFAL RUNPRD UD LINER RUNNING TOOLS,RECOVER 5/8" BALL. TOOLS APPEAR TO HAVE FUNCTIONED NORMALLY. Printed 4/25/2016 8:50:33AM *All depths reported in Drillers Depths* North America-ALASKA-BP • Page 2 of 4 Operation Summary Report Common Well Name:C-21 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/23/2016 End Date: X3-017L6-C:(1,651,974.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING @67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 22:30 10.50 CEMT N DFAL RUNPRD REVIEW PLAN FORWARD WITH ODE,WILL RUN A SINGLE TCP GUN FIRST TO PROVIDE A PATH FOR REMEDIAL CEMENTING. CONTACT TCP ENGINEER ON R-PAD TO ORGANIZE OUR JOB. WAIT ON TCP ENGINEER TO RIG DOWN ON R-PAD AND COME OVER TO OUR RIG. LOAD AND TALLY 1"CSH ONTO RIG. TEAR DOWN OF LINER RUNNING TOOLS AT BTT SHOP REVEALS NOTHING UNUSUAL. 22:30 - 23:30 1.00 CEMT N DFAL RUNPRD SLB TCP ARRIVED FROM OTHER JOB. PJSM, BRING UP PERFORATING BOXES/ 10'GUN/10'SPACER WSL/DRILLER WALK PIPE COUNT 23:30 - 00:00 0.50 CEMT N DFAL RUNPRD PJSM, MAKE UP GUNS AND FIRING HEAD, DISCONNECT, 10 JTS OF 1"CSH. INSTALL MARKER JOINT 3/25/2016 00:00 - 04:00 4.00 CEMT N DFAL RUNPRD CONTINUE MAKING UP 1"HYDRIL BROKE CIRCULATION AFTER 30 JOINTS 0.38 BPM @ 410# NO ISSUE BROKE CIRCULATION AFTER 60 JOINTS 0.38 BPM @ 617#.NO ISSUE BROKE CIRCULATION AFTER 100 JOINTS 0.25 _BPM @ 823#NO ISSUE MAKE UP 2-1/16"CSH WHILE SWAPPING COIL TO 1%SLICK KCL W/0.6%SAFELUBE WSL,DRILLER VERIFIED PIPE COUNT PRIOR TO STABBING INJECTOR 04:00 - 06:30 2.50 CEMT N DFAL RUNPRD PT QTS LOW/HIGH WHILE BLOWING DOWN KILL. RIH WITH PERF BHA SLOW DOWN FOR RESTRICTED DAT DEPLOYMENT SLEEVE. NO ISSUES RUNNING THROUGH 06:30 - 07:00 0.50 CEMT N DEAL RUNPRD AT 10850 FT FLUID OUT DENSITY GOES DOWN TO 8.0 PPG. STOP AND FLOW CHECK WELL FOR 10 MIN. LEL IS ZERO,TRIP SHEET IS-8 BBLS TO THIS POINT. 10 MIN PUMPS OFF FLOW CHECK IS GOOD, NO FLOW. CONTINUE RIH. AFTER SEVERAL MORE MINUTES LEL GOES TO 1%. LINE UP THROUGH MGS. NOTIFY CTD SI. 07:00 - 07:30 0.50 ' CEMT N DFAL RUNPRD PARKAT 11,226 AND CIRCULATE UNTIL RETURNS CLEAN UP. CIRC AT 0.5 BPM/1400 PSI. LIMIT OF 1500 PSI TO PREVENT WASHING E-FIRE SEAT,AS PER TCP. MONITOR PVT WHILE CIRCULATING. 07:30 - 09:30 2.00 CEMT N DFAL RUNPRD RETURNS CLEAN UP,RIH TO BOTTOM. TAG AT 11953 FT,PICK UP AND REPEAT. PICK UP 50 FT AND FLAG PIPE AT 11903 FT. FINISH CIRCULATING KCL WATER AROUND. 09:30 - 10:10 0.67 CEMT N DFAL RUNPRD PJSM WITH CREW FOR FIRING GUNS. TAG BOTTOM AGAIN AND PICK UP TO BREAKOVER+5 FT. PARK AT 11945 FT AND START PUMP SEQUENCE TO ACTIVATE E-FIRE HEAD. Printed 4/25/2016 8:50:33AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 3 of 4 Operation Summary Report Common Well Name:C-21 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/23/2016 End Date: X3-017L6-C:(1,651,974.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor:NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING @67.50usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 10:10 - 11:00 0.83 CEMT N DFAL RUNPRD I GET GOOD SHOT INDICATION FROM ACOUSTICS,ONLY SLIGHT FLUID LOSSES. INCREASE RATE TO 1 BPM,HOLD 250 PSI WHP. KEEP POOH SPEED AROUND 40 FT/MIN WHILE INSIDE LINER. 11:00 - 12:00 1.00 CEMT N DFAL RUNPRD AT 10387 FT GETTING SLIGHTLY GAS CUT RETURNS BACK. LEL GOES TO 5%,LINE UP AGAIN THROUGH MGS,NOTIFY CTD SI. 10 MIN PUMPS OFF FLOW CHECK IS GOOD, NO FLOW. TRIP SHEET IS-2 BBLS TO THIS POINT. PUMP 1 B/U THROUGH MGS 1.2 BPM/4050 PSI. WHILE PUMPING B/U LOSE ABOUT 1000 PSI OF PRESSURE,APPEARS TO BE A WASHOUT IN THE STRING. REDUCE RATE TO 1.07 BPM/2090 PSI. CHECKALL SURFACE LINES ON RIG,GOOD. STILL GETTING PERIODIC GAS CUT RETURNS. 12:00 - 13:40 1.67 CEMT N DFAL RUNPRD SHUT DOWN AFTER 1 B/U,10 MIN PUMPS "OFF FLOWCHECK IS GOOD,NO FLOW. CONTINUE POOH ON MGS,HOLD 250 PSI WHP INSIDE LINER. 10 MIN PUMPS OFF FLOWCHECK AT LINER TOP IS GOOD,NO FLOW. CONTINUE POOH. 13:40 - 14:00 0.33 CEMT N DFAL RUNPRD CONDUCT PJSM WHILE POOH. TRIP SHEET IS-9 BBLS TO THIS POINT. 14:00 - 15:30 1.50 CEMT N DFAL RUNPRD TAG STRIPPER,10 MIN PUMPS OFF FLOWCHECK IS GOOD,NO FLOW. PUT INJECTOR ON LEGS. L/D 2 JTS 2-1/16"CSH,STAND BACK 45 STDS OF 1"CSH TO MARKER PUP. 15:30 - 16:30 1.00 CEMT N DFAL RUNPRD PJSM WITH SLB TCP TO UD PERF GUN. STAND BACK REMAINING 5 STANDS OF CSH. AT THE FIRING HEAD,TOOL IS LOST BELOW THE XO FROM 1.56"FAU DISCONNECT TO SLB TCP THREAD. 16:30 - 18:00 1.50 CEMT N DFAL RUNPRD NOTIFY CTD SI AND ODE,DISCUSS PLAN FORWARD. I VERBAL FROM ODE OF RDMO. OCN#5 ON ITS WAY 18:00 - 00:00 6.00 CEMT N DFAL RUNPRD PJSM, MAKE UP 50 STANDS OF 1"HYDRIL. FLUSH PIPE WITH FRESH WATER. LAY PIPE DOWN SIDEWAY 3/26/2016 00:00 - 01:00 1.00 CONDHL P POST FINISH LAYING DOWN CSH HYDRIL. CLEAR FLOOR AND PICK UP INJECTOR. SPOT IN LRS TANKER/METH PUP. FLUSH MGS WHILE BOOTING CABLE INSTALL NIGHT CAP. CUT AND BOOT CABLE 01:00 - 02:30 1.50 CONDHL P POST PJSM, DISCUSS ROLES DURING FREEZE PROTECT MAKE UP BHA#12 STAB INJECTOR. BLOW KILL LINE DOWN. PT QTS 300#/3500# Printed 4/25/2016 8:50:33AM "All depths reported in Drillers Depths* North America-ALASKA-BP Page 4 of 4 Operation Summary Report Common Well Name:C-21 AFE No Event Type:COM-ONSHORE(CON) IStart Date:3/23/2016 End Date: X3-017L6-C:(1,651,974.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:7/13/1982 12:00:00AM Rig Release:3/26/2016 Rig Contractor.NORDIC CALISTA UWI:500292075300 Active datum:ORIG KELLY BUSHING©67.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 03:45 1.25 CONDHL P POST RIH WITH BHA#12 TO 2500' LAY IN 22 BBLS DIESEL. CAP WITH 1 BBL METHANOL. REEL FULL OF DIESEL TAG UP/CLOSE SWAB VALVE. BLOW STACK +DOWN TO TIGER TANK 03:45 - 04:30 0.75 DEMOB P POST 'BREAK DOWN BHA. PUT INJECTOR ON LEGS. VALVE CREW ARRIVED. SERVICE TREE. 04:30 - 08:30 4.00 BOPSUR P POST PERFORM LEAK TIGHT TEST BEGIN NIPPLE DOWN. REMOVE BOPS AND LIFT UP WITH THE BLOCKS. 08:30 - 10:00 1.50 BOPSUR P POST INSTALL TREE CAP AND TEST. TREE CAP TEST IS GOOD. RELEASE RIG AT 10:00. ALL FURTHER OPERATIONS ON 15-45 REPORT. Printed 4/25/2016 8:50:33AM *All depths reported in Drillers Depths* • C-21A, Well History (Post-Rig Sidetrack) CTU #6 w/1.50" CT Objective: Drift-Push fish to TD/Cmt liner/Perf. MIRU, Packoff changed and 3/26/2016 chains inspected. 6 Hours Standby Rate. 0 Hours Full Rate. 3/27/2016 T/I/O=0/0/0 Temp=SI Assist CTU with DSL flush (CTD SUPPORT) RU/PT, SB for CTU to RIH. CTU #6 w/1.50" CT Objective: Drift-Push fish to TD/Cmt liner/Perf. Pump on unit not working. Swap out tractors. Perform weekly BOP test-pass, function tested BOPs. RIH Baker tempress/1.75" JSN, OAL 13.44' taking returns at surface. 3 Hours of Full Rate. 10.5 Hours of NPT. 10.5 Hours of 3/27/2016 Standby Rate. CTU #6 w/1.50" CT, Vol 23 bbls Objective: Drift-Push fish to TD/Cmt liner. Tag Fish, PUH get wt 11888' Mechanical and 11850' Electronic, confirmed second tag, PUH 15' from top of Fish and Flag pipe Yellow at 11873' M=11835' E. Pumped 3/8" ball shear circ sub, circ well to 105 degf lub 776 diesel at 1.2 bpm with LRS from 11873' Mechanical counter depth. POOH and had gas at bottoms up, pumped lub 776 diesel —3 bpm do bsct not heated for 83 bbls=to top of liner and pressure increased, shut down and monitored ith final pressure 650 psi. Break down tools recover 3/8" ball. MU WFD 2-3/8" cement retainer. RIH. LRS called to re-heat diesel transport. Launch 3/8" ball with 150 degree diesel. Set cement retainer @ 11879'. Stack down 8k over neutral wt to confirm setting. Establish circulation through tubing punch in liner. Getting 1:1 returns with 2500 psi CTP. Gas bubble from behind liner circulated to surface. Did not get all of the gas OOH before running out of diesel. 3/28/2016 Call out more diesel with lube 776. 24 hours of Full Rate. Pumped 5 bbls ambient DSL to return tank to check for flow. Pumped 120* bbls of 100* DSL down coil. Pupmed 84 bbls ambient DSL down Tbg because well came back online. CTU #8 in control of 3/28/2016 well per LRS departure. FHWP's=650/vac/vac. T/I/0=248/0/0 Temp=Sl Assist CTU. Pumped 78.5 bbls of 155*diesel to the CTU down the tbg. 3/28/2016 FWHP=145/0/0. CTU #6 w/1.50" CT, Vol 23 bbls Objective: Drift-Push fish to TD/Cmt liner. LRS heated lub 776 diesel transport. Circulate warm diesel through cement retainer and tubing punch to remove gas from behind 2-3/8" liner and wellbore. Batch up 15.3 ppg cement. Cement wet @ 07:53. Thickening time = 5 hours and 53 minutes. Pump cement job per program. Pump 17 bbl of 15.3 ppg cement into retainer/behind pipe, maintained 1:1 returns during entire cement job. Unsting and lay in 1 bbl on top of retainer. RBIH to right above retainer and start laying in powervis pill. Leave 33 bbl powervis pill on bottom. FP coil with 60/40 methanol. POH pumping 60/40 down CTBS for hole fill. Tag up. Unstab. Recover ball. LD WFD stinger and setting tools. MU SLB slim cleanout BHA with 1.5"JSN. RIH and begin jetting powervis from WCTOC. Jet GLMs and liner tops with powervis. RIH and tag retainer @11875' pump gel sweep and chase to surface wih slick 1% kcl with saflub washing GLMs. 24 3/29/2016 hours of Full Rate. CTU #6 w/1.50" CT, Vol 23 bbls Objective: Drift-Push fish to TD/Cmt liner. POOH washing GLMs and tree. RBIH FP to 2500'with 60/40 Meth SafLub, POOH. Blow reel down. RDMO. 2 Hours of Full 3/30/2016 Rate. 22 Hours of Standby Rate (19 hours NPT for Reel Blowdown if Unit is Ad Hoc). CTU-6 1.50" CT HS80. Objective: Drift/ Log / Perf. MIRU. Pump 1" drift ball through coil and perform BOP test. Perform liner lap test(Failed). RIH w/ 1.75"X 27.85' Drift BHA. Tag PBTD at 11896', PUH and get weight back at 11892'. Flag pipe white at 11862', POOH. MU BKR RPM 4/3/2016 logging tools and RIH. Stand-by hrs: 14/Operating Hrs: 10. CTU-6 1.5"CT HS80. Objective: Drift/ Log / Perf. RIH w/ BKR RPM logging tools. Begin logging RPM down at 30fpm from 8500'to 11894' (PBTD). After slightly tagging PBTD, begin logging RPM up at 20fpm to 8500'. Stopped at previously painted flag —30' off bottom (11872'E) and recorded depths for tie-in. Paint a second yellow flag at 8500' and make jewelry log up to 7500' at 30fpm. POOH. Confirmed good data/-8' correction. (Tie-in using 'Field Print' of the Baker LWD March- 2016). MU & RIH w/ 1.563"x30' HES Millennium HMX perf gun. Unable to pass top of liner at 7991' due to bottom sub of gun. POOH and swap the tapered bullnose out for spherical bullnose. MU and RIH with same perf gun. Tie-in to the flag at 11872'. RIH and confirm cement retainer at 11880'. PUH 1' off cement retainer and shoot 1st perf gun interval from 11879-11849'. POOH. Stand-by 4/4/2016 hrs: 0 /Operating Hrs: 24. • S C-21A, Well History (Post-Rig Sidetrack) CTU-6 1.5"CT HS80. Objective: Drift/ Log/ Perf. POOH w/ 1st perf gun. Cut 50' of pipe and change packoffs. MU & RIH w/2nd 1.563"x30' HES Millennium perf gun (6 spf-60 degree phasing / 8.3" pen., ent hole .23"). Perforate interval 11810-11840'. POOH. MU & RIH w/3rd 1.563"x30' perf gun. Tie-in to cement retainer at 11880' and perforate interval 11780-11810'. Circulate 1% KCI w/ Safelube into well and POOH. MU & RIH w/4th 1.563"x30' perf gun. 4/5/2016 Stand-by hrs: 0/Operating Hrs: 24. CTU-6 1.5"CT HS80. Objective: Drift/ Log / Perf. RIH w/4th 1.563"x30' perf gun. Tie-in using cement retainer at 11880'. PUH and perforate interval 11750-11780'. POOH. MU & RIH w/5th 1.563"x30' perf gun. Tie in using cement retainer at 11,880'. PUH and perforate interval 11,720'- 11750'. POOH. RIH W/2.78" KB LTP with PTSA sub. Finish RIH w/ BOT 35KB LTP & PTSA-stab PTSA seals into deployment sleeve - set down 10K @ 8938' CTM - neutral wgt @ 8932' CTM -200 psi CTP bleed pnt PUH 8930' CTM - PUH 8929' -Cir 5/8" ball 21.7 bbls- Stack 10K down - PUH Neutral 8931' - Set LTP per RP - issues releasing GH running tool. Stand-by hrs: 0/Operating Hrs: 4/6/2016 24. CTU-6 1.5"CT HS80. Objective: Drift/ Log / Perf. RIH w/4th 1.563"x30' perf gun. Tie-in using cement retainer at 11880'. PUH and perforate interval 11750-11780'. POOH. MU & RIH w/5th 1.563"x30' perf gun. Tie in using cement retainer at 11,880'. PUH and perforate interval 11,720'- 4/6/2016 11750'. POOH. RIH W/2.78" KB LTP with PTSA sub. Stand-by hrs: 0/Operating Hrs: 6. CTU-6 1.5"CT HS80 Objective: Drift/ Log / Perf. RIH with 2.78" KB LTP with PTSA and set in deployment sleeve at 8934'. Performed a passing pressure test. Lost 98/47 for a total 145psi in 30 mins. MU & RIH w/2" GS spear and pulled PTSA and check valve. POOH. 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Reference Site: PB C Pad MD Reference: ORIG KELLY BUSHING @ 67.50usft(NABORS 3S) Site Error: 0.00usft North Reference: True Reference Well: C-21 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore C-21A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: C-21A Offset TVD Reference: Offset Datum Reference C-21A Filter type: NO GLOBAL FILTER:Using user defined selection&filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,622.70usft Error Surface: Elliptical Conic I Survey Program Date 3/28/2016 , From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 8,900.00 1 :Camera based gyro multisho(C-21) CB-GYRO-MS Camera based gyro multishot 8,960.00 11,950.82 CTK MWD 3-1/4"(C-21A) MWD MWD-Standard 3/28/2016 4:29:09PM AO0CC O F ESE": IR.E pO R�-' COMPASS 5000,1 Build 61 0 • t „� BP 1"n Anticollision Report BAKER .40 HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-21 Project: Prudhoe Bay TVD Reference: ORIG KELLY BUSHING @ 67.50usft(NABORS 3S) Reference Site: PB C Pad MD Reference: ORIG KELLY BUSHING @ 67.50usft(NABORS 3S) Site Error: 0.00usft North Reference: True Reference Well: C-21 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore C-21A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: C-21A Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB C Pad C-07-C-07-C-07 4,695.74 4,950.00 799.06 157.91 642.68 Pass-Major Risk C-07-C-07A-C-07A 4,695.74 4,950.00 799.06 157.91 642.68 Pass-Major Risk C-08-C-08-C-08 5,095.20 5,375.00 172.82 66.93 106.50 Pass-Major Risk C-08-C-08A-C-08A 5,087.70 5,375.00 172.85 66.64 106.68 Pass-Major Risk C-08-C-08APB1-C-08APB1 5,087.70 5,375.00 172.85 66.64 106.68 Pass-Major Risk C-08-C-08B-C-08B 5,087.70 5,375.00 172.85 66.64 106.68 Pass-Major Risk C-08-C-08BPB1-C-08BPB1 5,087.70 5,375.00 172.85 66.80 106.53 Pass-Major Risk C-08-C-08C-C-08C 5,087.70 5,375.00 172.85 66.80 106.53 Pass-Major Risk C-08-C-08CPB1-C-08CPB1 5,087.70 5,375.00 172.85 66.80 106.53 Pass-Major Risk C-08-C-08CPB2-C-08CPB2 5,087.70 5,375.00 172.85 66.80 106.53 Pass-Major Risk C-09-C-09-C-09 2,826.42 2,825.00 305.23 43.42 261.81 Pass-Major Risk C-09-C-09A-C-09A 2,826.42 2,825.00 305.23 43.42 261.81 Pass-Major Risk C-09-C-09B-C-09B 2,826.42 2,825.00 305.23 43.42 261.81 Pass-Major Risk C-09-C-09BPB1-C-09BPB1 2,826.42 2,825.00 305.23 43.42 261.81 Pass-Major Risk C-10-C-10-C-10 2,377.31 2,375.00 329.06 37.17 291.89 Pass-Major Risk C-10-C-10A-C-10A 2,376.97 2,375.00 329.06 37.06 292.00 Pass-Major Risk C-10-C-10B-C-10B 2,376.97 2,375.00 329.06 37.06 292.00 Pass-Major Risk C-11-C-11-C-11 4,915.64 4,975.00 189.94 88.19 102.05 Pass-Major Risk C-11-C-11A-C-11A 4,915.14 4,975.00 189.92 88.00 102.20 Pass-Major Risk C-12-C-12-C-12 1,879.26 1,875.00 439.71 28.47 411.24 Pass-Major Risk C-12-C-12A-C-12A 1,879.26 1,875.00 439.71 28.47 411.24 Pass-Major Risk C-12-C-12APB1-C-12APB1 1,879.26 1,875.00 439.71 28.47 411.24 Pass-Major Risk C-12-C-12B-C-12B 1,879.26 1,875.00 439.71 28.47 411.24 Pass-Major Risk C-12-C-12C-C-12C 1,879.26 1,875.00 439.71 28.47 411.24 Pass-Major Risk C-12-C-12CPB1-C-12CPB1 1,879.26 1,875.00 439.71 28.47 411.24 Pass-Major Risk C-15-C-15-C-15 10,900.00 9,700.00 580.39 557.22 32.43 Pass-Major Risk C-15-C-15A-C-15A 10,900.00 9,625.00 578.74 541.45 54.67 Pass-Major Risk C-18-C-18-C-18 525.11 525.00 333.67 9.34 324.33 Pass-Major Risk C-18-C-18A-C-18A 525.11 525.00 333.67 9.34 324.33 Pass-Major Risk C-18-C-18B-C-18B 525.11 525.00 333.67 9.34 324.33 Pass-Major Risk C-18-C-18BPB1-C-18BPB1 525.11 525.00 333.67 9.34 324.33 Pass-Major Risk C-19-C-19-C-19 2,396.50 2,400.00 218.19 41.94 176.25 Pass-Major Risk C-19-C-19A-C-19A 2,396.50 2,400.00 218.19 41.94 176.25 Pass-Major Risk C-19-C-19B-C-19B 2,396.50 2,400.00 218.19 41.94 176.25 Pass-Major Risk C-19-C-19BPB1-C-19BPB1 2,396.50 2,400,00 218.19 41.94 176.25 Pass-Major Risk C-19-C-19C-C-19C 4,231.06 4,300.00 163.69 85.96 102.60 Pass-Major Risk C-19-C-19C-Plan#6 C-19C approved 4,295.75 4,375.00 199.11 100.52 134.42 Pass-Major Risk C-20-C-20-C-20 550.11 550.00 112.10 11.04 101.06 Pass-Major Risk C-20-C-20A-C-20A 557.36 550.00 112.29 11.24 101.04 Pass-Major Risk C-20-C-20B-C-20B 557.36 550.00 112.29 11.24 101.04 Pass-Major Risk C-20-C-20C-C-20C 557.36 550.00 112.29 11.24 101.04 Pass-Major Risk C-21-C-21-C-21 8,999.33 9,000.00 4.93 28.82 -23.87 FAIL-Major Risk C-22-C-22-C-22 2,875.00 2,875.00 118.32 46.45 71.90 Pass-Major Risk C-22-C-22A-C-22A 2,879.97 2,875.00 118.42 46.55 71.90 Pass-Major Risk C-33-C-33-C-33 474.86 475.00 352.26 8.24 344.02 Pass-Major Risk C-33-C-33A-C-33A 474.86 475.00 352.26 8.24 344.02 Pass-Major Risk C-33-C-33A-Plan#2 474.86 475.00 352.26 8.24 344.02 Pass-Major Risk C-33-C-33PB1-C-33PB1 474.86 475.00 352.26 8.24 344.02 Pass-Major Risk C-35-C-35-C-35 6,790.06 7,000.00 217.10 146.08 71.86 Pass-Major Risk C-35-C-35A-C-35A 6,790.06 7,000.00 217.10 146.08 71.86 Pass-Major Risk C-35-C-35B-C-35B 6,790.06 7,000.00 217.10 146.08 71.86 Pass-Major Risk C-42-C-42-C-42 2,413.58 2,425.00 450.75 34.92 416.39 Pass-Major Risk C-42-C-42A-C-42A 2,413.58 2,425.00 450.75 34.94 416.39 Pass-Major Risk 3/28/2016 4:29:09PM AD GCC 0 F( sf.__ E p R- COMPASS 5000.1 Build 61 • BP MEI0 • bp Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Wet C-21 Project: Prudhoe Bay TVD Reference: ORIG KELLY BUSHING @ 67.50usft(NABORS 3S) Reference Site: PB C Pad MD Reference: ORIG KELLY BUSHING @ 67.50usft(NABORS 3S) Site Error: 0.O0usft North Reference: True Reference Well: C-21 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore C-21A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: C-21A Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) 3/28/2016 4:29:09PM /A OG CC O F 17 y IE7 REPO � COMPASS 5000.1 Build 61 • • �0.«, B P ra.■ ;)'`, Anticollision Report BAKER.,4HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-21 Project: Prudhoe Bay TVD Reference: ORIG KELLY BUSHING @ 67 50usft(NABORS 3S) Reference Site: PB C Pad MD Reference: ORIG KELLY BUSHING @ 67.50usft(NABORS 3S) Site Error: 0.00usft North Reference: True Reference Well: C-21 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore C-21A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: C-21A Offset TVD Reference: Offset Datum Reference Depths are relative to ORIG KELLY BUSHING @ 67 50usft Coordinates are relative to:C-21 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:1.25° Ladder Plot 1600- L- li 0 I .--, I l4 1 ,3i.4 y l r•.14 I ll.., cal Ir 1200- i- ' iAN T::± -�iIIIJ I O I , jai I��/4 �' Io RAZ VA O ,&'fail, :i _ _ �- J4cow p .5, r I 800 _. 9� !r Ry IiiYii£Sn 4,N�MC, •� y '' d �' _.... •lir'...7. filir VI1 I 2 .1.44•41;,,•: .••1.••11:1,:if...';'‘.' 4142 4444 ..'14.7,. : .ir ' , • a) 4ii 00 U ea,ok,! ♦ 9 e itilig y,4 $ 4 Af I< c lS l4.l �19'T,l9lS91S 29.24 `•"• +an'?° ttra i t, rm __J _I'll a 7 . 1 0 I 1 1 FC�FNf , I I I 0 2000 4000 6000 8000 10000 12000 0-33,C33PB1,G33PB1 V1 C-1k,gaalBreGdl ptn(2000 usWin) 0-19,0-190,0-190V0 0-33,G33A,G33A V3 C-10,0-10A,C-10A V5 0-19,0-190,Plan#6 C-190 approved VO C.-63,1r3JA,man#L v1 l,-1 U,C,-1U,l-1U V9 L-19,C-I9Ijl-' I,U-191:3i'bl Vi C-33,C-33,C-33 V1 $ C-11,0-11 A,C-11 A V4 -9- C-19,C-19A,0-19A V6 C-20,C-20,C-20V2 C-11,0-11,0-11 V1 C-19,0-19B4O-19BV4 -0- C-20,0-20A,C-20AV1 C-12,0-12C,C-12CV0 -0- C-21,0-21,0-21 V1 0-20,0-200,0-20C VO 0-12,0-12CPB1,C-12CPB1 VO 44-- 0-22,C-22A,C-22A V6 0-20,C-20B,0-208 V3 C-12,0-12A,0-12A VO C-22,C-22,0-22 V3 C-07,C-07A,0-07AV4 -I- C-12,0-12B4O-126V0 0-35,0-35B,C-35BV3 C-07,C-07,0-07 V2 0-12,0-12APB1,C-12APB1 VO 0-35,C-35,C-35 V3 C-08,C-08BPB1,C-08BPB1 V3 0-12,C-12,C-12V1 C-35,0-35A,0-35AV1 0-08,C-08CPB2,C-08CPB2 VO -4- C-15,0-15,C-15 V1 0-09,C-09A,C-09A V1 0-08,C-080,C-08C V0 -' C-15,0-15A,C-15A V0 C-09,C-09,0-09 V1 3/28/2016 4.29:09PM AOGcc OFpp E7 REpORT COMPASS 5000.1 Build 61 • 0 CEMENTING REPORT Preflush(Spacer) Type: Fresh Water Density(ppg) 8.3 Volume pumped(BBLs) 5.3bbls Lead Slurry Type: CTD Liner Blend Yield(Ft3/sack): 1.320 Density(ppg) 15.3ppg Volume (BBLs/sacks): 18.1 bbls Mixing/Pumping Rate(bpm): 1 Tail Slurry Type: N/A Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): 1- Post Flush(Spacer) Type: Fresh Water Density(ppg) 8.4 Rate(bpm): 1 Volume: 5.5 L Displacement: Type: Powervis Density(ppg) 8.4 ppg Rate(bpm): 1 bpm Volume(actual/calculated): 17 FCP(psi): N/A Pump used for disp: Coil Pump Plug Bumped? Yes X No Bump press 0 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 100 Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: N/A Liner Cement Job Cement In Place At: 9:11 Date: 3/29/2016 Estimated TOC: TOL,8934'MD Method Used To Determine TOC: Displacement Method Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Lu Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): N Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: w Displacement: co Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No %Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Remarks: • • 215216 27031 rR U RECEIVER) RINT DISTRIBUTION LIST HUGHES 11 Mo Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME C-21A 900 E.Benson Blvd. f/141/2o*M.K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE Marc h 23,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE April 8,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF PRINTS #OF COPIES #OF COPIES #OF COPIES U 1 BP North Slope 1 0 1 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 ECLIVEa Attn:Ricky Elgaricio ATO 3-344 APR y 700 G Street 20)0 Anchorage,AK 99510 AOGC 3 ExxonMobil,Alaska I 1 1 1 I 1 I Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 1 1 I 1 I I Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *5* 0 I 1 1 I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 *5*Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. I I Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Nancy Landi TOTALS FOR THIS PAGE: 0 3 4 5 0 0 TOTALS FOR ALL PAGES: 0 3 4 5 0 0 • • N CN, a "I W > C' MI v kill W 0 vu ,-.1 %.,;,.. liblMO Q gZ W CC 0 CO 1 Q CO Q t Q Q • a) CC it .v > SIM C) E Q a �, cn m � � co,4 o M N /A g ti U N CU 0 t < NC Q D UNI C•1 o w .0 Z a a U U Fr) LL N , a • I al ,I, 0 .--. o �/0 M M > (O pp co ko O i� O 0 N N N N M co p Q� m m N N N M Q Q • V • V u) M Z Z y W . Co o o s n a N.- ^ Z CO O Q ' g o e. '- O 0 0 a ° Z_ Z_ 1 4 2 S a) a c0) 0 ',. w co 3 y c U z D y w 0 m m Z m > o .. J J 0 115 a J = -p ..N W --1 E tn N O y Y Et W & E J O 0 .E c a) a) y '° k 0 W W ` C 0 .0 d "O « L C) y J J U' G) > O 0O -a rt 0 E a a) a M C -6 ) C la d L J J 0 L N w 0 1.7 0) E C ce C w F 0 a N V ca 0 m V 0 C j a N O w a, 0 O N 0 0 .0 O C V 0 Q' 0 Ce >L a 0 O O O a) - ^ O Ti CY J R Z N ❑ y co O O > > 3 y Q N N u7 O O CO O O O Le) CO cr OO co N V M07 O N co co ca. O M N O CO CO W (O C �) a CL N 0. 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E 'r't ' Z N 0 co O co rn m 0) t ms'' Q aD N M � N I Y Ia co co O co 0) U eLo O N in co"= a 1--, op. o 03 rn U T C N 0( mU O O V0, O 0) to p O 0 O 0) O < O o_ 11) L O m N N L 'O 0 !- Q Q 7 O N7 r O O) O 2 m N N N CU O) O) 0 Q) O 0 Z d 0_ U U 0 c m 0 = a0 ao a0 0) : a o 2 v a O _ac v a c UdtHi CDNro O a in 3 0 01• OF 7•4 • 4. //j,, s THE STATE• Alaska Oil and Gas 4v ==>101-40,4 -7,,„ °fLAsKA Conservation Commission 333 West Seventh Avenue kvel, t___ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov John McMullen Engineering Team Lead BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-21A BP Exploration (Alaska), Inc. Permit No: 215-216 Surface Location: 884' FNL, 1523' FEL, SEC. 19, T11N, R14E, UM Bottomhole Location: 1331' FNL, 5215' FWL, SEC. 24, 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 AOGCC 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 AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, icl(„-,(4--- Cath P. Foerster Chair DATED this 21 day of December, 2015. STATE OF ALASKA Yl,L.:.%."it...".i t i...;ta 0 ASKA OIL AND GAS CONSERVATION COMMIS" PERMIT TO DRILL DEC 0 R 7015 20 AAC 25.005 la. Type of Work: lb. Proposed Well Class: Exploratory-Gas ❑ Service-WAG ❑ Service-Disp❑ lc.SpecifyitijkOproposed for Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Oil p• Service-Winj ❑ Single Zone IZI , Colabed Gas ❑ Gas Hydrates❑ Redrill 'J • Reentry 0 Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Geothermal ❑ Shale Gas 0 2. Operator Name: 5. Bond Blanket 0 •Single Well ❑ 11. Well Name and Number: BP Exploration(Alaska),Inc Bond No. 6194193 . PBU C-21A . 3 Address: 12. Field/Pool(s): 6. Proposed Depth: P.O.Box 196612 Anchorage,AK 99519-6612 MD: 11975' • TVD: 8931'ss • PRUDHOE BAY,PRUDHOE • 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): OIL ADL 028305&028285 • Surface: 884'FNL,1523'FEL,Sec.19,T11N,R14E,UM • 8. Land Use Permit: 13. Approximate spud date: 1317'FNL,2121'FEL,Sec.19,T11N,R14E,UM 80-274 January 25,2016 Top of Productive Horizon: Total Depth: 1331'FNL,5215'FWL,Sec.24,T11N,R13E,UM 9. Acres in Property: 2480&2560 . 14.Distance to Nearest Property: 25000 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: • 67.5 feet 15. Distance to Nearest Well Open Surface:x- 663845' y- 5960324 • Zone - ASP 4 GL Elevation above MSL: . 33.1 feet to Same Pool: 615 16. Deviated wells: Kickoff Depth: 8960 • feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 3244 • Surface: 2364 18. Casing Program: Specifications Top-Setting Depth-Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3-1/4" 2-3/8" 4.7# L-80 H511 3045' 8930' 8713'ss 11975' 8931'ss 87 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): I Plugs(measured): I Effect.Depth MD(ft): I Effect.Depth TVD(ft): I Junk(measured): 9282 9119 9130 9130 8973 7913 Casing Length Size Cement Volume MD TVD Conductor/Structural 80 20" 8 cu yds Concrete 35-115 35-115 Surface 2635 13-3/8" 3883 cu ft Arctic Set II 34-2670 34-2670 Intermediate 8452 9-5/8" 1136 cu ft Class'G',130 ft Arctic Set I 33-8484 33-8359 Liner 1312 7" 368 cu ft Class'G' 7968-9280 7882-9117 Liner 1155 3-1/2" 73 cu ft Class'G' 7991 -9146 7903-8988 Perforation Depth MD(ft): 9030-9192 I Perforation Depth TVD(ft): 8876-9032 20.Attachments Property Plat El BOP Sketch ❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements RI 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Browning,Zachary H from without prior written appr.val. Email Zachary.Browning@bp.com Printed Name •. i cM en Title Engineering Team Lead Signatur- Phone +1 907 564 4711 Date L 2-14 /-1. — Commission Use Only Permit to DrillPermit Approval Number: ,•—•/c-Z/(° API Number: 50- 029-20753-01-00 Date: \1\A\/i See cover letter for other T J 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 in shales: Other: 5G f7 7,-c-5 i. fo 35-c'C2 r7 .7 Samples req'd: Yes CI No Il Mud log req'd: Yes CI No 12 4-r)i�(/Jci✓ p6'!ve-✓v trr' te-5/ I. I� fnea(4ires Yes p No ❑ Directional svy req'd: Yes ❑ No 0 Spacing exception req'd: Yes 0 No ❑ Inclination-only svy req'd: Yes ❑ No GI Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date/2 _2(..../,<;" vrt- iz/ /5- O R I O I N A L X72-/K Form 10-401 Revised 11/2015 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit Form and Attachments in Duplicate --."-.44 ._ /z., /- , /s` • To: Alaska Oil &Gas Conservation Commission From: Zach Browning CTD Engineer Date: December 3, 2015 Re: C-21A Permit to Drill Request • Approval is requested for a permit to drill a CTD sidetrack lateral from well C-21 with Coiled Tubing Drilling rig Nordic 2 on or around January 25th, 2016. The C-21A sidetrack will be a dual string exit from the existing 3-1/2" liner x 7" liner. A packer whipstock will be set pre-rig allowing isolation from the parent perforations. The planned well kicks-off in lower Zone 3, builds through the conglomerates and will land and target reserves in Zone 2A/1 B. The proposed sidetrack is a —3015' horizontal Ivishak producer to be completed with a 2-3/8" L-80 solid liner, cemented in place and selectively perforated. The parent perf intervals are below the KOP and will be isolated via the packer WS set pre-rig and the liner cement job or liner top packer.* Rig Work(scheduled to begin January 25th, 2016) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,364 psi). 2. Mill 2.80"window and 10' of rathole. 3. Drill build: 3.25" OH, -366' (25 deg DLS planned). 4. Drill lateral: 3.25" OH, -2650' (12 deg DLS planned). 5. Run 2-3/8" L-80 liner leaving TOL at-8930' MD. 6. Pump primary cement job: 18 bbls, 15.3 ppg Class G, TOC at-8930' MD.* 7. Perform liner lap test. 8. Freeze protect well to a min 2,200'TVDss. 9. Close in tree, RDMO. *Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. Re-install wellhouse, and flowline. 2. Set liner top packer if liner lap test fails.* 3. GR/CCL/RPM log. Perforate —200' based on log interpretation. Mud Program: • • • Milling/drilling: a min EMW of 8.4 ppg KCL with Flovis/Powervis for milling window and drilling (599 psi over-balance). Disposal: • All Class I & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3 at DS 6. • Fluids >1% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. • Fluids with solids that will not pass through 1/4" screen must go to GNI. • Fluids with PH >11 must go to GNI. Hole Size: • 3.25"for the production hole section from 8960' MD to 11,975' MD Liner Program: • 2-3/8", 4.7 lb/ft, H511, L-80 solid liner 8930' MD- 11,975' MD • A minimum of 18 bbls of 15.3 ppg cement will be used for liner cementing (TOC = TOL at-8930' MD). • The primary barrier for this operation: a minimum EMW of 8.4 ppg (599psi over-balance). • 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 91°, inclination at kick off point is 17°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property- 25,000' • Distance to nearest well within pool- 615' (C-15A) Logging: • MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. • Cased hole GR/CCL/RPM logs will be run inside casing. Cased hole logs planned to be obtained post rig. Perforating (Planned to be performed post-rig): • -200' of perforations planned. 1.56" HSD 1606 PJ HMX, 60 deg random phasing, 6 spf, perf guns. Anti-Collision Failures: • None. All offset wells pass BP major risk anti-collision scan criteria. • Abandoned well C-15 has been minor risked 1:10 due to no HSE risk. Hazards: • C-pad is not an H2S pad. • The lost circulation risk in C-21A is considered to be Low. Reservoir Pressure: • The reservoir pressure on C-21A is expected to be 3,244 psi at 8,800' TVDSS (7.09 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,364 psi. • A min EMW of 8.4 ppg for this well will provide 599 psi over-balance to the reservoir. Zach Browning CC: Well File CTD Engineer Joseph Lastufka 564-5220 TREE WELLHEAD= MCEVOY PRO SED C_2 SAS NOTES:�•`CHROME TBG"* ACTUATOR= R OKB ELEV= 67.5' I - ' ' I ` 24' --I4-1/2"X 3-1/2 XO,D=2.992" BF.ELEV= 34.6' KOP= 6800' ' L2222' H3-i/2"HES XMP,0=2.813" Max Angle= _°Q Datum MD= Datum ND= 8800 SS 2599' 9-5/8"DV PKR `i— -- 4-1/2"TBG,12.6#,13CR TCt t, --1 24' GAS LFT MANDRELS 0152 bpf,D=3.958" LST MD TVD DEV TYPE VLV LATCH PORT CATE 4 3092 3092 1 MMG DOME RK 16 08/27/12 [13-3/8"CSG,72#,L-80,BTRS,D=12.347" H 2670' 3 5196 5196 1 MMG DOME RK 20 08/27/12 2 6794 6792 9 MAG MY RK 0 07/20/08 1 7665 7606 25 MMC MY RK 0 07/20/08 Minimum ID =2.75" @ 7824" 3-1/2" HES BXP XN NIPPLE I 7723' H3-1/2"FES XNP,ID=2.813" _____.---I 7744' H3-1/2"X 4-1/2"XO,D=2.950" 7745' —19-518'X 4-1/2"BKR S-3 PKR,D=3.875" 1 7751' H4-1/2"X 3-1/2"XO,D=2.950" ' 7771' —13-1/2-HES X ru',D=2.813" ' 7824' H3-1/2'HES BXPXN NP,D=2.75' 3-112"TBG,9.2#,13CR VAM — 7847_ 7845' H3-1/2"X 4-1/2"XO,D=2.992- TOP,.0087 bpf,0=2.992" 7867' _—I5-1/2"TBG STW(03/06/06) ------- 7861' H4-1/2"MULE SHOE,D=3.958" 5-1/2"TBG,17#,L-80,0232 bpf,0=4.892' —1 7884' I -- 8'x2"x1/2'SLP SEGMENT(FOR PHOTOS,SEE —1 UNKNOWN 7914' H9-5/8"0715 PKR D=4.00" RWO FLE 3/15/06-COULD BE N 1 OF 2 LOC.) �j1 7"BOT LNR HGR WI TACK Sly —I 7968' rt ' _ = 7965' '14-1/2"ORS X tom',D=3.813' 7"LNR,26#,L-80,.0383 bpf,D=6.276" 1 7982' r }C 7991' H3.75"BKR DEPLOYMENT SLV,D=3.00" I ' ' 8006' H4-1/2"OTIS XN NP,D=3725'(BEHIND PIPE)._ 4-1/2"TGB,12.6#,L-80,.0152 bpf,D=3.958' —{ 8048' ` 8049' —14-1/2"W. (SEISM PIPE) 9-5/8"CSG,47#,L-80,.0732 bpf,D=8.681" —{ 8484' r 8042" TT LOGGED 05/04/93 TOP OF 2-3/8"LNR/CMT( / / ) —I —8930' I 8930' H_"DEPLOY MHYT SLV,D " _ xxx'BKR PACKER WHPSTOCK(MMIDD/YY) —I —8960' MLLOUT WINDOW(C-21A) 8960'--8970' 3-112"LNR,9.3#,L-80-JT1,.0087 bpf,0=2.99T H —8960' 7"LNR,29#,L-80,.0371 bpf,D=6.184" —1 —8960' PERFORATION SUMMARY REF LOG: ON_/_/ ANGLE AT TOP FERE: °@_ Note:Refer to Roduction DB for historical pert data TBD --I PUP JT w/RA TAG SIZE SPF INTERVAL Opn/Sgz SHOT SOZ PBTD i [2:379:-LNR,X.X#,L-80 STL,.0039 bpf,D=1.99X" 11975' • •4. DATE REV BY COMMENTS DATE REV BY COIVIVE TS PR,AHOE BAY UNIT 07/12/82 IMTIAL COMPLETION _ \ aL: C-21A 04/04/98 NORDIC 3-1/2"SCAB LMR PERMIT Na: 03/14/06 N3S RWO API No: 50-029-20753-01 XXIXXIXX CTD(C-21A) SEC 19,T11N,R14E,884'FM_8 1523'FEL. 10/29/15 AID BOLT PROPOSE) BP Exploration(Alaska) TREE= 6'x7"C1WFLS j WEL0 (V-^LHEAD- Ml"EVOY ALJ21 SA NATES:***CHROME TBG*** I ACTUATOR= BAKER C ' OKB.ELEV= 67.5' I ' ' 24' —14-1I2"X 3-1/2 XO,D=2.992" 'BF.ELEV= 34.6' KOP= 6800' I I 2222' —13-1/2^HES X NP,D=2.813' Max Angle= 27"@ 7500' I[ tum MD= 9021' Datum ND= 8800'SS 2598' —I9-5/8"DV PKR _ GAS LFT MANDRELS 4-12"TBG,12.6#,13CR TC11, —{ 24' ST MD ND DEV TYPE VLV LATCH PORT DATE 0152 bpf,ID=3.958" / 4 3092 3092 1 MMG DOME RK 16 08/27/12 3 5196 5196 1 MMG DOME RK 20 08/27/12 11-323--/8"CSG,72#,L-80,BTRS,D=12.347' 2669' ((( ID 2 6794 6792 9 MMG DMY RK 0 07/20/08 1 7665 7606 25 MMG DMY RK 0 07/20/08 Minimum ID =2.75" @ 7824" 3-1/2" HES BXP XN NIPPLE I 7723' H3-1/2"HES XFNP,D=2.813" 7744' —13-1/2"X 4-1/2'XO,C=2.950" t 7745' H9-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" 7751' H4-12"X 3-1/2"XO,D=2.950" ' 7771' —4 3-1/2"FES X NP,D=2.813" ' 7824' —13-1/2"HES BXP XN NIP,D=2.75" 3-1/2"TBG,9.2#,13CR VAM H 7847' I---- 1 7845' N3-1/2"X 4-1/2'XO,D=2.992' TOP,.0087 bpf,I)=2.992" III 7867' —{5-1/2'TBG SRU(03/06/06) 7861' —44-1/2"MULE SHOE,D=3.958" 5-1/2"TBG, 17#,L-80,0232 bpf,D=4.892' —{ 7884' 8"x 2"x 1/2"SLE SEGMENT(FOR PHOTOS,SEE —4 UNKNOWN `, rA 7914' 9-5/8"QTc PKR,D=4.061 RWO FLE 3/15/06-COLD BE N 1 OF 2 LOC.) . 7'BOT LNIzt HGRW/T1 ACK SLV —{ 7967' : 7965' —4-1/2"OTIs X ,D=3.813" 7991' H3-3/4"BKRDEPLOY!VENT SLV,D=3.00" 8006' H4-1/2"OPS XN NV,D=3.725"(BENND PIPE) 4-12"TGB,12.6#,L-80,.0152 bpf,C=3.958" —j 8048' 8049' —�4-12"WLEG(BEHIND PIPE) 9-5/8"CSG,47#,L-80,.0732 bpf,D=8.681" 8484'-LL 1.-AI8042� � TT LOGGED 05/04193 3-1/2"LNR,9.3#,L-80-J71,.0087 bpf,D=2.992" —{ 9145' PERFORATION SUMMARY 44 tvvv4,' 8710' ---ICALCL ATEDTOC REF LOG: BRCS BHCA 07/25/82 14141 1444 ANGLE AT TOP PERF:16"Q 9030 444. �$•• 9130' }—3-12"EVOTREV E PLUG(10/02/15) Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 91�� T�G SHOE,D=2.992" 3-318" 4 9027-9030 S 08/22/96 04/04/99 2" 6 9030-9035 C 05/11/14 3-3/8" 4 9046-9134 S 08/22/96 04/04/99 I 2-1/2" 4 9143-9153 C 01/05/01 2-1/2" 4 9153-9173 C 01/05/01 I 2-1/8" 6 9155-9175 C 08/25/99 3-3/8" 6 9165-9192 C 08/31/96 I PBTD 9237' C7"LNR,29#,L-80,.0371 bpf,D'6.184" 1H 9280' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNT ' 07/12/82 INTIAL COMPLETION 05/13/14 JS/JMD ADPERFS(05/11/14) WELL C-21 04/04/99 NORDIC 3-1/2"SCAB LN2 10/08115 NLW/JM)SET EVOTREVE PLUG(10/02/15) PERNIT No:'1820810 03/14/06 N3S RWO AR No: 50-029-20753-00 07/22/08 KB/JIvD GLV GO(07/20/08) SEC 19,T11N,R14E,884'SNL&1523'WEL 08/29/12 DIS/JMD GLV C/O(08/27/12) 03/20/14 RB/JM) IFEECIO(03/18/14) BP Exploration(Alaska) • • Urn IIII WO Z i10 = Q m 0 m a Co t a0 J 0_ Q C, ix c 0) 0C.) v •_ L CD o M a Fin — Q T Q o N • CO d = cu N Q. c '0U _ _ E a o N Nas Z d d 0 0 a CO 0 • MI W co a b14`'11 z co Mini iz O N • N Lc)csi N o O m N ° O Z V) o F 7 a r co co a aU ❑ E- o Z S 0 a o 0 Y > m 2 0> TD r0. 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BP MAI x t. ;.:F Travelling Cylinder Report BAKER oft, HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-21 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB C Pad MD Reference: ORIG KELLY BUSHING @ 67.50usft (NABORS 3S) Site Error: 0.00 usft North Reference: True Reference Well: C-21 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore C-21A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: C-21A WP05 Offset TVD Reference: Offset Datum Reference C-21A WPO5 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,800.00 to 11,975.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,394.21 usft Error Surface: Elliptical Conic Survey Tool Program Date 12/1/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 8,800.00 1 :Camera based gyro multisho(C-21) CB-GYRO-MS Camera based gyro multishot 8,800.00 11,975.00 C-21A WP05(C-21A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 2,669.00 2,601.46 13 3/8" 13.375 17.500 8,484.00 8,291.19 9 5/8" 9.625 12.250 11,975.00 8,931.01 2-3/8" 2.375 4.250 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB C Pad C-04-C-04B-C-04B I I I I CA I Out of range C-04-C-04B-Plan#5 Out of range C-07-C-07-C-07 Out of range C-07-C-07A-C-07A Out of range C-08-C-08-C-08 Out of range C-08-C-08A-C-08A Out of range C-08-C-08APB1-C-08APB1 Out of range C-08-C-08B-C-08B Out of range C-08-C-O8BPB1-C-08BPB1 Out of range C-08-C-08C-C-08C Out of range C-08-C-08CPB1-C-08CPB1 Out of range C-08-C-08CPB2-C-08CPB2 Out of range C-09-C-09-C-09 Out of range C-09-C-09A-C-09A Out of range C-09-C-09B-C-09B Out of range C-09-C-09BPB1-C-09BPB1 Out of range C-10-C-10-C-10 Out of range C-10-C-10B-C-106 Out of range C-11-C-11-C-11 Out of range C-11-C-11A-C-11A 9,140.00 9,350.00 1,392.64 331.31 1,180.97 Pass-Major Risk C-15-C-15-C-15 10,914.51 9,675.00 553.43 15.09 553.15 Pass-Minor 1/10 C-15-C-15A-C-15A 10,925.00 9,650.00 555.41 539.68 31.36 Pass-Major Risk C-16-C-16B-C-16B 8,896.87 11,465.00 959.54 315.44 803.98 Pass-Major Risk C-16-C-16C-C-16C 9,691.05 12,425.00 695.52 314.85 380.68 Pass-Major Risk C-19-C-19C-C-19C Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/1/2015 9 44•33AM Page 2 COMPASS 5000.1 Build 61 0 • ��as�r4 BP MIMI 1 t).) Travelling Cylinder Report BAKER '°".- HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-21 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB C Pad MD Reference: ORIG KELLY BUSHING @ 67.50usft (NABORS 3S) Site Error: 0.00 usft North Reference: True Reference Well: C-21 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore C-21A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: C-21A WP05 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB C Pad C-19-C-19C-Plan#6 C-19C approved Out of range C-21-C-21-C-21 8,950.00 8,950.00 0.00 0.60 -0.57 FAIL-NOERRORS C-22-C-22-C-22 11,750.00 10,075.00 972.48 693.86 278.79 Pass-Major Risk C-22-C-22A-C-22A 10,661.77 10,400.00 721.58 543.34 178.27 Pass-Major Risk C-23-C-23-C-23 Out of range C-23-C-23A-C-23A Out of range C-23-C-23B-C-23B Out of range C-23-C-23C-C-23C Out of range C-23-C-23D-C-23D Out of range C-24-C-24-C-24 Out of range C-24-C-24A-C-24A Out of range C-24-C-24B-C-24B Out of range C-24-C-24BPB1-C-24BPB1 Out of range C-25-C-25-C-25 Out of range C-25-C-25A-C-25A Out of range C-25-C-25B-C-25B Out of range C-26-C-26-C-26 Out of range C-26-C-26A-C-26A Out of range C-35-C-35-C-35 Out of range C-35-C-35A-C-35A Out of range C-35-C-35B-C-35B 10,313.22 10,700.00 1,163.95 318.58 851.44 Pass-Major Risk Offset Design PB C Pad- C-11-C-11A-C-11A Offset Site Error: 0.00 usft Survey Program: 101-BOSS-GYRO,8193-MWD+IFR+MS-WOCA Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth *NIS +EI-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (in) (usft) (usft) (usft) 8,817.42 8,605.44 8,950.00 8,285.31 36.59 87.06 -163.46 -1,752.13 -988.61 5.625 1,376.68 397.92 1,194.55 Pass-Major Risk,CC 8,839.62 8,626.62 8,975.00 8,308.31 36.75 87.06 -163.51 -1,759.88 -994.60 4.375 1,380.16 398.27 1,197.73 Pass-Major Risk 8,861.80 8,647.79 9,000.00 8,331.34 36.91 87.06 -163.57 -1,767.71 -1,000.38 4.375 1,383.69 398.72 1,200.87 Pass-Major Risk 8,883.96 8,668.96 9,025.00 8,354.40 37.07 87.06 -163.63 -1,775.62 -1,005.93 4.375 1,38729 39920 1,203.84 Pass-Major Risk 9,080.00 8,847.81 9,050.00 8,377.48 37.21 87.07 -161.09 -1,783.61 -1,011.26 4.375 1,389.35 376.01 1,200.40 Pass-Major Risk 9,080.00 8,847.81 9,075.00 8,400.59 37.21 87.07 -161.53 -1,791.68 -1,01636 4.375 1,390.23 376.03 1,199.14 Pass-Major Risk 9,087.50 8,853.77 9,100.00 8,423.71 3721 87.07 -161.48 -1,799.85 -1,02123 4.375 1,391.53 371.11 1,199.73 Pass-Major Risk 9,100.00 8,863.48 9,125.00 8,447.10 3721 87.07 -161.13 -1,807.55 -1,025.53 4.375 1,392.56 362.22 1,201.28 Pass-Major Risk 9,100.00 8,863.48 9,150.00 8,470.87 37.21 87.07 -161.70 -1,814.66 -1,028.47 4.375 1,392.92 362.25 1,198.96 Pass-Major Risk 9,100,00 8,863.48 9,175.00 8,494.93 37.21 87.07 -162.34 -1,821.37 -1,029.54 4.375 1,392.87 362.29 1,195.98 Pass-Major Risk 9,111.71 8,872.32 9,200.00 8,51924 3722 87.07 -16224 -1,827.18 -1,029.15 4.375 1,391.87 354.26 1,194.98 Pass-Major Risk 9,120.00 8,878.40 9,225.00 8,543.40 37.22 87.07 -162.43 -1,833.18 -1,026.98 4.375 1,391.16 347.77 1,193.47 Pass-Major Risk 9,120.00 8,878.40 9,250.00 8,567.18 3722 87.07 -163.27 -1,839.70 -1,022.87 4.375 1,391.02 347.82 1,189.72 Pass-Major Risk 9,124.24 8,881.46 9,275.00 8,590.62 37.22 87.07 -163.84 -1,846.38 -1,017.34 4.375 1,391.24 344.29 1,187.67 Pass-Major Risk 9,130.00 8,885.55 9,300.00 8,614.00 37.23 87.08 -164.33 -1,852.74 -1,011.18 4.375 1,391.48 339.24 1,186.32 Pass-Major Risk 9,130.00 8,885.55 9,325.00 8,637.36 37.23 87.08 -165.24 -1,858.87 -1,004.73 4.375 1,391.85 33928 1,182.98 Pass-Major Risk 9,140.00 8,892.44 9,350.00 8,660.72 37.23 87.08 -165.79 -1,865.02 -998.26 4.375 1,392.64 331.31 1,180.97 Pass-Major Risk,ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/1/2015 9:44.:33AM Page 3 COMPASS 5000.1 Build 61 • • IP c Northing(100 u3ft/in) 1111 ki W 956 /96�2 6634„ ¢A65\ / 663409 ...0 gi66330. . -663300 6632... � h-71to 31A -663200 1fs 663100 .Gy11G ..5000. .... -663100 FIF Jg0-J� .500,. gO 663000 J. : -663000 3 dZZ-3/ZZ-0 I 662900 0068 __.-662900 St 66 662800 -662800 o S or A o m z 6627.... .000 _ -662700 Q $w a mo y 662600 -662600 001 31yoi g g m g g s 662500 09, 1s.-6,e p0 -662500 'hi"! 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These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: 7 e- z-7 PTD: Z`c — Z/ Development Service Exploratory Stratigraphic Test _Non-Conventional FIELD: i,z,j - POOL: Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( PH) and API number (50- ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • • N a a U co_ • O Q coa f0 p, c. p C. c. (a m C' Lll � m o m • O a y, o, �, co U. a , c, > m �. a y, v. o a , 4 o co N U c) gyp, • a c0 Q, 3, o o. ca 3. _ -g-. o 2, y �, �, . @. U. 3 a.- w Q I, , o a J, , E. �. co co .o• o. 0a.. m.� q, .. N. � � o. o, M . a E. m. yZ 0 � � a > ,ua E 'EhaN'> 0. a. O. , x-. C, a p rn _, v, a ,• � � � 0 N, 0, E, �' am as ari )mN .c, m ,a2. � O ix: U �, �, � r ° Mv111 (U .co. � co,o asr..° a, . 0a } . cm . . c' aa �, m °m as O E• U• ° o, , O' u_ c `� a 0, U , >' i N' € tn ami. a> �. �. J, p,I. M. y. p �. o. o. p. L V. o. LL. . E. -p. C. y. E. 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