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Home My WebLink About215-131By Anne Prysunka at 1:37 pm, Jul 22, 2022 MGR07SEP2022 Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/05/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL D-35 (PTD 215-131) Memory Production Profile 08/19/2021 Please include current contact information if different from above. Received By: 10/05/2021 37' (6HW By Abby Bell at 12:14 pm, Oct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y Meredith Guhl at 11:44 am, Sep 30, 2021 RBDMS HEW 10/1/2021 MGR15OCT2021 SFD 10/6/2021DSR-9/30/21 6HW&76%39ZGU\URGZHOORQYDF%OHHGSUHVVXUHRIIRIYRLG$VVLVW1'WUHH JRRGWHVW3XOO7:&ZLWKGU\URGFORVHPDVWHUZHOORQ9DF7XUQRYHUWR:6 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:215-131 6.API Number:50-029-23554-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028284 & 0028285 Property Designation (Lease Number):10. N/A 8. PBU D-35 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 Fracture Stimulate Repair Well Operations shutdown RWO AICD Liner Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12582 Effective Depth MD: 13Cr85 11. 8/1/2021 Commission Representative: 15. Suspended Contact Name: Noel Nocas Contact Email: noel.nocas@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr 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: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8886 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8439, 8277 No SSSV Installed Date: Liner 4030 4-1/2"8552 - 12582 8380 - 8886 8430 7500 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 48 - 3185 48 - 3173 14. Estimated Date for Commencing Operations: BOP Sketch 49 - 172 Structural 7240 Proposal Summary 13. Well Class after proposed work: 4-1/2" HES TNT Perm Packer 9910 - 12403 9046 - 8950 4-1/2" 12.6#8558 Production 11600 9017 11600, 12309 None 49 - 172 9-5/8" 7" Contact Phone:(907)564-5278 Date: 5410 123 20"Conductor 3090 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3137 5750 Intermediate 8668 45 - 8713 45 - 8524 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 2416 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. By Samantha Carlisle at 10:53 am, Jul 07, 2021 321-341 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.07.07 07:02:47 -08'00' Stan Golis (880) 8879 DSR-7/9/21SFD 7/7/2021MGR14JULY21 10-404 SFD 7/7/2021 BOPE test to 3000 psi. Annular to 2500 psi. 12600 JLC 7/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.14 13:14:14 -08'00' RBDMS HEW 7/14/2021 FCO and RWO Liner Install D-35 PTD:2151310 Well Name:D-35 API Number:50-026-23554-00 Current Status:Producing Rig:TBird 1, CTU,EL Estimated Start Date:8/1/2021 Estimated Duration:30 days Reg.Approval Req’std?N/A Date Reg. Approval Rec’vd:N/A Regulatory Contact:Abbie Barker Permit to Drill Number:2140490 First Call Engineer:Noel Nocas (907) 564-5278 (O)(907) 229-9532(M) Second Call Engineer:Wyatt Rivard (907) 777-8547 (O)(509) 670-8001 (M) Post Work Est. Rates:15 MMSCFD, 700 BOPD, 100 BWPD into HP Current Bottom Hole Pressure:3252 psi @ -8,800’ TVDss 7.1 PPGE Maximum Expected BHP:3296 psi @ -8,800’ TVDss 7.2 PPGE Max. Anticipated Surface Pressure:2416psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2410 psi (Taken on 3/19/2020) Min ID:3.725” ID XN @ 8540’ MD Max Angle:94 Deg @ 11,158’ MD Reference Log: Baker RPM 12/31/2015 Brief Well Summary: D-35 is a December 2015 rotary sidetrack that was drilled to access GDWFI and GD reserves in Northwestern D- Pad. The wellbore resembles a drawn-out U-shaped profile - the horizontal portion of the wellbore is in lower Z2B and the toe of the well TD's in Z2C. The well was initially completed and perforated in a Z2Bu oil lens near the toe. In April 2021, 680’ of perforations were added to the horizontal in 6 distinct sections. The GOR trend from these intervals indicates that gas breakthrough may have occurred through one or more perf intervals. Going forward anAutomated Inflow Control Device (AICD) liner will be installed to control/isolate gas production from individual zones while maximizing production from lower GOR intervals. Objective: x Utilize CTU to production log then mill out XN profile and cleanout/drift ahead of liner install. x Utilize Thunderbird – 1 to run 2-3/8” AICD retrofit liner across existing perforations in 4-1/2” production liner. Notes Regarding Wellbore Condition x MIT-T and MIT-IA passed to 3500 psi on rig on 12/12/2015 x MIT-IA passed to 2500psi on 3/19/2020 Sundry Procedure (Approval Required to Proceed) Coil Tubing – PPROF, Mill XN & Drift 1. MIRU Coiled Tubing Unit and spot ancillary equipment. a. Coordinate with PPC and Pad Op to have well tested prior to and during logging job 2. MU GR/CCL/SPIN/Press/Temp and gas hold-up tool. 3. RIH to ~9800' MD. a. Bring well online while RIH for stabilization. Goal is to produce the well as close to possible to actual producing conditions. 4. Once well stable, log down and up passes from ~9800’ to ~11600’ at 40, 60 and 80 fpm. a. Take one pass up to ~8450’ to confirm no gas entry occurring at LTP. 5. Take 5 min stop counts: a. Between perf intervals b. Above and Below top and bottom perforations 215-131 SFD FCO and RWO Liner Install D-35 PTD:2151310 c. And above TOL. d. Appx Depths (MD): 11450’ - 11,180’ – 10,800’ – 10,500’ – 10,300’ – 10,080’ – 9,800’ – 8,500’ 6. POOH and confirm good data. 7. MU 3.8” mill and cleanout BHA. 8. RIH and mill 4-1/2” XN at 8540’ MD to 3.8” ID ahead of 3.67” OD AICD liner install. 9. Once XN milled out, continue 3.8” drift to CIBP set at 11600’ MD. Cleanout as needed, obtain updated tag of CIBP. POOH. a. Confirm liner clean with OE prior to POOH. Essential that a clean dry drift is established 10. RDMO Pre-RWO*Note: Depending on timing of rig move, well kill and BOP installation steps may be performed on rig rather than pre-rig. 11. RU hot oil and PT lines to 3000 psi. 12. Bullhead 280 bbls of 8.4 ppg 1% KCl or equivalent down tubing to the formation. a. Wellbore volume = .0152 bpf x 9910ft = 150 bbls. b. Spear with 10bbl meth if well is cold or has been SI with gas cap 13. Confirm well is dead. Freeze protect tubing as needed with diesel, crude or 60/40. c. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the rig. 14. RD hot oil truck. 15. Clear and level pad area in front of well. Spot rig mats and containment. 16. RD well house and flowlines. Clear and level area around well. 17. Verify 0 psi on the annulus and tubing pressure. 18. Set BPV w/insert (TWC) and test. ND Tree and THA. 19. NU BOPE configured top down: Annular, 2-7/8”x5-1/2” VBRs, Blinds and integral flow cross. a. Note: 2-3/8” AICD Liner is comprised primarily of blast joints (3.063” OD), ported intervals (two- way communication) and swell packers. 2-7/8” x 5-1/2” VBRs will seal across blast joints. A pre- staged 2-7/8” safety joint will be used for sealing during makeup of all other liner components. RWO 20. MIRU Thunderbird 1 workover rig and ancillary equipment 21. Test BOPE to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “Thunderbird # 1 Test Procedure” c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram and Annular on 2-7/8” and 3-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 22. Pull TWC with lubricator. Kill well w/8.4 ppg 1% KCl or equivalent as needed. 23. Maintain hole fill at surface or fill at 30bph minimum throughout operations with KWF (2000’/hr gas migration rate in 4-1/2” liner) 24. PU 2-3/8” AICD liner as detailed on proposed liner tally and run liner with 2-7/8” work string. a. Pickup an open TIW valve, 2-7/8” Safety Joint and XO prior to making up liner. Fluid level in IA expected to be at SO ~5240' MD (almost vertical). Awareness to pressure difference across tubing to annulus of 1750-1800 psi. If communication T->IA, load IA with KWF. FCO and RWO Liner Install D-35 PTD:2151310 b. In the event that well begins to flow while making up blast joints (3.063” OD), an open TIW can be installed and 2-7/8”x5-1/2” VBRs closed on blast joint then TIW closed. c. For all other liner components, (2-3/8” base pipe, swell packers, AICDs, etc.) install safety joint with open TIW, lower safety joint and close pipe rams, close TIW. 25. Tag CIBP for rough depth correction. a. PU and position Liner Top Packer based on proposed liner tally. 26. Rig up Eline for liner depth tie-in. 27. RIH with GR/CCL and confirm liner spaceout with respect to perforation reference log. 28. RDMO Eline 29. Circulate 50 bbls diesel down the work string taking returns up the backside to leave swell packers in hydrocarbon. a. Workstring volume = 9780’ * .0052 bpf = 51 bbls b. 2-3/8” Liner Volume = 1700’ * .0040 bpf = 7 bbls c. 2-3/8”x4-1/2” Annular volume = 1700’ * .0097 bpf = 17 bbls 30. Drop ball and displace with 10 bbls diesel followed by 1% KCL to set Liner Top Packer and release liner 31. POOH with workstring. 32. Bleed tubing pressure back to ~0 psi. Set TWC. 33. RDMO Thunderbird WO Rig and ancillary equipment. Move to next well location. 34. ND BOPE. NU the THA and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 35. Pull TWC. Post-Rig Procedure: 36. RU and bullhead 250 bbls diesel down the tubing into formation to freeze protect and prevent 1% KCL from swapping behind liner and hampering packer swell 37. Leave well SI for a minimum of 14 days prior to putting well on production to allow swell packers to swell. 38. Obtain AOGCC witnessed SVS test within 5 days of putting well online Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Blank RWO MOC Form 5. D-35 Tie-In Log Assure awareness to limits on volume of 6.8 ppg diesel to assure continuous overbalance to reservoir pressure. FCO and RWO Liner Install D-35 PTD:2151310 As-Built Schematic FCO and RWO Liner Install D-35 PTD:2151310 Proposed Schematic FCO and RWO Liner Install D-35 PTD:2151310 FCO and RWO Liner Install D-35 PTD:2151310 FCO and RWO Liner Install D-35 PTD:2151310 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date FCO and RWO Liner Install D-35 PTD:2151310 Tie-In Log FCO and RWO Liner Install D-35 PTD:2151310 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:215-131 6.50-029-23554-00-00 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 12600 11600 9017 8439 None 11600, 12309 8277 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 123 20" 49 - 172 49 - 172 Surface 3137 9-5/8" 48 - 3185 48 - 3173 5750 3090 Intermediate 8668 7" 45 - 8713 45 - 8524 7240 5410 Production Perforation Depth: Measured depth: 9910 - 12403 feet True vertical depth:9046 - 8950 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13cr85 43 - 8558 43 - 8385 8439 8277Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Perm Packer Liner 4030 4-1/2" 8552 - 12582 8380 - 8886 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 11512027132357 132921359 1981 29647 4315 897 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Noel Nocas Noel.Nocas@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5278 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations 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 measured8879 Sundry Number or N/A if C.O. Exempt: 321-077 No SSSV Installed 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 0028284 & ADL 0028285 PBU D-35 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 By Meredith Guhl at 2:32 pm, Apr 19, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.19 13:14:43 -08'00' Stan Golis (880) RBDMS HEW 4/19/2021 SFD 4/19/2021DSR-4/19/21MGR28JUL2021 ACTIVITY DATE SUMMARY 2/21/2021A4:B18 T/I/O = 1170/490/260. Temp = 122°. T FL (SL request). ALP = 2250 psi, SI @ CV. IA FL @ surface. SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:00 2/23/2021 ***WELL FLOWING ON ARRIVAL***(profile modification) SET 4-1/2" WHIDDON ON XN @ 8,540' MD PULLED BK-DGLV'S FROM ST#4 (5,252' MD) & ST#5 (3,493' MD) SET BK-LGLV IN ST#5 (3,493' MD) SET BK-OGLV IN ST#4 (5,252' MD) PULLED 4-1/2" WHIDDON FROM XN @ 8,540' MD ***WELL FLOWING ON DEPATURE*** 3/1/2021 T/I/O = 980/1360/350. Temp = 123*. Bleed IAP (Eval high IAP). AL SI @ casing & pit valves (1350 psi). IA FL @ 5252' (#4, S/O). Bled the IAP from 1360 psi to 500 psi in 30 minutes (#22, production, all gas). Duing the IA bleed the IAP decreased 200 psi. Bled the ALP from 1350 psi to 830 psi in 2 minutes. No change in the IA FL, IAP or ALP in the 30 minute monitor. Grease crew to service AL casing valve. FWPs = 980/500/150. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:00 3/5/2021 T/I/O = 1130/490/100. Temp = 126°. WHPs (post bleed). ALP = 1120 psi, SI @ CV. TP increased 150 psi, IAP decreased 10 psi and OAP decreased 50 psi since 03/01/21. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:30 4/6/2021 CTU#9 2.0" CT. Job Scope: Depth Log, CIBP, Ext Adperf MIRU CTU. Begin Weekly BOP Test. ...Continued on WSR 4-7-21...***CP 4/7/2021 CTU #9 - 2.0" Coil ***Cont. from WSR 4-6-21** Job Objective: Set CIBP, Extended AddPerf Complete weekly BOP test. Make up drift/Log BHA with 3.70" DJN. Tagged corrected PBTD at 12,310'. Logged Read BHA from 12,277' to 9,500'. Flagged pipe @ 11,500' ctm. Good data on log, sent to OE and verified +39' correction. Corrected EOP = 11,487'. Make up Baker CIBP & RIH to flag. Set top of CIBP at 11600' and get a good PT to 1000psi. POOH. ...Job Continued on 4/8/2021.... 4/8/2021 CTU #9 - 2.0" Coil ***Cont. from WSR 4-7-21** Job Objective: Set CIBP, Extended AddPerf Continue POOH with CIBP setting BHA. Deploy gun #1. RIH and perforate interval 11000-11140 and 11260-11400. Paint white/yellow flag at corrected EOP of 10,300'. Bullhead well with 1% KCl w/ safelube. Begin recovering gun #1. ...Job Continued on 4/9/2021.... 4/9/2021 CTU #9 - 2.0" Coil ***Cont. from WSR 4-8-21** Job Objective: Set CIBP, Extended AddPerf Recover perf gun run #1. Issues deploying perf gun run #2, stab on and re-kill and FP well. Swap to using 60/40 in trip tank and continue making up perf gun run #2. RIH with perf gun #2. ...Job Continued on 4/10/2021.... Daily Report of Well Operations PBU D-35 Daily Report of Well Operations PBU D-35 4/10/2021 CTU #9 - 2.0" Coil ***Cont. from WSR 4-7-21** Job Objective: Set CIBP, Extended AddPerf RIH with perf gun #2. Perforate 10,350-10,450 and 10,570-10,670 with SLB 2.875" Powerjet 6spf. Painted red flag with a corrected EOP of 9891.11. POOH and kill well. Retrieve perf gun BHA #2 and Deploy perf gun BHA #3. RIH and tie in to flag, perforate 9910-10010' and 10130-10230'. POOH and kill well and retrieve gun #3. Freeze protect well with 38bbl of diesel. Pad operator notified of well status/waiting on test unit. ...Job Continued on 4/11/2021.... 4/11/2021 CTU #9 - 2.0" Coil ***Cont. from WSR 4-10-21** Job Objective: Set CIBP, Extended AddPerf RDMO. ...Job Complete.... 4/11/2021 LRS Well Test Unit 6. Begin WSR 4/11/21. IL well D-35, OL well D-22. Begin Unit move. Unit Spotted on EOP waiting on OSL. SB. Spot Unit. RU, PT. POP Continue on WSR 4/12/21. 4/12/2021 LRS Well Test Unit 6. Continue WSR from 4/11/21. IL well D-35, OL well D-22. Continue Stabilizing Well, Continue on WSR 4/12/21. 4/13/2021 LRS Well Test Unit 6. Continue WSR from 4/12/21. IL well D-35, OL well D-22. Continue Stabilizing Well, Continue on WSR 4/14/21. 4/14/2021 LRS Well Test Unit 6. Continue WSR from 4/13/21. IL well D-35, OL well D-22. Continue Stabilizing Well, try to divert into WPS, Swap over to HP, Divert into WPS, 2Hr Purge. Begin Piggyback Well Test. Job in Progress. Continue on WSR 4/15/21. 4/15/2021 LRS Well Test Unit 6. Continue WSR from 4/14/21. IL well D-35, OL well D-22. End 8 Hr Piggyback Well Test. BD, RD. Job Complete. End WSR 4/15/21. Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:215-131 6.API Number:50-029-23554-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028284 & 028285 Property Designation (Lease Number):10. 341 8. PBU D-35 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 Extended Perf w CTU Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12600 Effective Depth MD: 13cr85 11. 2/23/2021 Commission Representative: 15. Suspended Contact Name: Noel Nocas Contact Email: noel.nocas@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: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8879 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool 8439, 8278 Date: Liner 4030 4-1/2"8552 - 12582 8380 - 8886 8430 7500 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 48 - 3185 48 - 3173 14. Estimated Date for Commencing Operations: BOP Sketch 49 - 172 Structural 7240 Proposal Summary 13. Well Class after proposed work: 4-1/2" HES TNT Perm Packer 11630 - 12403 8950 - 9015 4-1/2" 12.6#43 - 8558 Production 12309 8976 12309 None 49 - 172 9-5/8" 7" Contact Phone:(907)564-5278 Date: 5410 123 20"Conductor 3090 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 Surface 3137 5750 Intermediate 8668 45 - 8713 45 - 8524 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 2416 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. By Samantha Carlisle at 8:41 am, Feb 10, 2021 321-077 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.02.09 16:55:08 -09'00' DSR-2/10/21SFD 2/10/2021 10-404 MGR11FEB21 Yesn Required? Comm 2/11/21 dts 2/11/2021 JLC 2/11/2021 RBDMS HEW 2/12/2021 Set CIBP and Add Perf D-35 PTD:215-131 Well Name:D-35 Add perf API Number:50-029-23554-00 Current Status:Operable – SI / Cycle Rig:SL/CTU & Surface Deployed TCP Guns / Portable Test unit Estimated Start Date:05/03/2021 Estimated Duration:5days Reg.Approval Req’std?Feb 2021 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:215-131 First Call Engineer:Noel Nocas 907-229-9532 (c) AFE Number:212-00170 IOR 1035 Current Bottom Hole Pressure:3252 psi @ -8,800’ TVDss 7.1 PPGE Maximum Expected BHP:3296 psi @ -8,800’ TVDss 7.2 PPGE Max. Anticipated Surface Pressure:2416psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2410 psi (Taken on 3/19/2020) Min ID:3.725” ID XN @ 8540’ MD Max Angle:94 Deg @ 11,158’ MD Reference Log: Baker RPM 12/31/2015 Brief Well Summary: D-35 is a December 2015 rotary sidetrack that was drilled to access GDWFI and GD reserves in Northwestern D-Pad. The wellbore resembles a drawn-out U-shaped profile - the horizontal portion of the wellbore is in lower Z2B and the toe of the well TD's in Z2C. The well was initially completed in a Z2Bu oil lens near the toe, leaving ~ 2000' of horizontal unperforated . Objective: Since there is considerable lateral to perforate (~2000') and the well is a 4-1/2" monobore, D-35 will eventually be recompleted with AICD’s within a 2-3/8” liner to capitalize on production from the entire lateral without the added risk of premature gas break through. This intervention will add 680’ of perforations over six intervals is the first step, when gas rates start to rise, another intervention is planned to add AICD’s to automatically regulate gas production by perf interval or zone. Attachments: 1. Wellwork Program 2. As-built Schematic 3. Proposed Schematic 4. Coil Tubing BOPE Schematic 5. Equipment Layout Diagram 6. Standing Orders for Open Hole Well Control during Perf Gun Deployment 7. Tie In Log/Perf Sheet add 680’ of perforations over six intervals Set CIBP and Add Perf D-35 PTD:215-131 Wellwork program: Slickline 1. Install GL design for kickoff, if needed Start ofSundry Procedure (Approval Required to Proceed): Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. Bullhead 1.5x Wellbore volume to top perf down the tubing to the formation. (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.)Note: The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 3. MU and RIH with logging tools and dummy gun drift BHA to resemble perf gun. Tag PBTD prior to logging OOH. 4. POOH and confirm good data. 5. Contact OE prior to perforating for final approval of tie-ins. 6. MU and RIH with CIBP. Set at approximately 10,600’MD avoiding collars. 7. Freeze protect tubing as needed. 8. At surface, prepare for deployment of TCP guns. 9. Confirm well is dead. Bleed any pressure off to return tank. Kill well as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. 10. Pickup 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. 11. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below. D-35 Extended Add Perf Intervals MD Top MD Base Interval Length Perf Run Makeup 9,910’10,010’100’320’ total 200’ Guns 120’ blanks10,130’10,230’100’ 10,350’10,450’100’320’ total 200’ guns 120’ blanks10,570’10,670’100’ 11,000’11,140’140’400’ total 280’ guns 120’ blanks 11,260’11,400’140’ Total 680’ perforations 3 Total Runs If wellbore problems are present during logging or setting CIBP, the team may elect to run shorter perf intervals to maximize chances of getting perf guns to depth. 12. RIH with perf gun and tie-in. Pickup and perforate intervals per Perf Schedule above. POOH. a. Note any tubing pressure change in WSR. 13. POOH. Stop at surface to reconfirm well is dead and hole is full. 14. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 15. Repeat steps as necessary for subsequent guns per schedule above. 16. RDMO CTU. 17. RTP or FP well.Well may be kicked off and flowed initially through the portable test separator or flowback tanks to minimize sand and perf debris in flowline/facility. End of Sundry Procedure * Assure fluid column remains overbalanced to expected pore pressures. Assure excess fluids available if needed to keep hole full. Standing orders flow chart included with this sundry request. *See note above regarding kill methods if pressure observed on surface after perforating. Set CIBP and Add Perf D-35 PTD:215-131 As-built Schematic Set CIBP and Add Perf D-35 PTD:215-131 Proposed Schematic Set CIBP and Add Perf D-35 PTD:215-131 Coiled Tubing BOPs Set CIBP and Add Perf D-35 PTD:215-131 Equipment Layout Diagram Set CIBP and Add Perf D-35 PTD:215-131 Standing Orders for Open Hole Well Control during Perf Gun Deployment Standing Orders for Service Coiled Tubing Operations While Deploying Extended Length Perforating BHA WELL BEGINS FLOWING DURING OPEN HOLE DEPLOYMENT Pull BHA above blind/shear rams, and close blind/shears. Space out BHA with safety joint above slip bowl, set hand slips Install safety joint with open TIW Can BHA be pulled above blind/shear rams in a single pick? Pull hand slips YES NO Begin Notifications Close Upper Pipe/Slip Ram Close TIW Close choke valves, monitor and record SIWHP Close choke line. Monitor and record SIWHP Lower safety joint and space out over BOP, set hand slips Begin Notifications Set CIBP and Add Perf D-35 PTD:215-131 D-35 Tie-In Log Set CIBP and Add Perf D-35 PTD:215-131 Set CIBP and Add Perf D-35 PTD:215-131 Set CIBP and Add Perf D-35 PTD:215-131 Set CIBP and Add Perf D-35 PTD:215-131 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: February 9, 2021Subject: Changes to Approved Sundry Procedure for Well D-35Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 1 Winston, Hugh E (CED) From:Carlisle, Samantha J (CED) Sent:Thursday, February 4, 2021 11:13 AM To:Winston, Hugh E (CED) Subject:FW: Cancellation: PBU D-35 (PTD #215-131) Sundry # 320-029 Attachments:D-35 Appr Sundry 1-23-20.pdf From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Thursday, February 4, 2021 11:04 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com> Subject: Cancellation: PBU D‐35 (PTD #215‐131) Sundry # 320‐029 Hello, Please cancel Sundry #320‐029 (copy attached). No work covered by this sundry that requires a 10‐404 has been completed. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564‐4915 Cell: (907)351‐2459 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. RBDMS HEW 2/8/2021 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU D-35 Permit to Drill Number: 215-131 Sundry Number: 320-029 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Q;n,ArPly 4.91 DATED this VIday of January, 2020. RBDMS±46'j JAN 2 4 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 R C" IV pT S I/ 2. 11"Z O 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ yerr, on?„soh owo ❑ Suspend ❑ Perforate 0 ' Other Stimulate ❑ Pull Tubing ❑ C r)frtivL' am ❑ a Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 ' Other AICD Linerw/ Swell 0 , Packers 2. Operator Name: BP Exploration (Alaska), Inc 4, Current Well Class: Exploratory ❑ Development 0. 5. Permit to Drill Number: 215-131 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6, API Number: 50-029-23554-00-00 ' 7. If perforating: CO 341H What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU D-35 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028284'& 028285 PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12600 8879 12309 8976 2372 12309 None Casing Length Size MD TVD Buret Collapse Structural Conductor 123 20" 49-172 49-172 Surface 3137 9-5/8" 48-3185 48-3173 5750 3090 Intermediate 8668 7" 45-8713 45-8524 7240 5410 Production Liner 4030 4-1/2" 1 8552- 12582 8380-8886 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 Tubing Size: Tubing Grade: Tubing MD (ft): 11630 - 12403 8959 - 9014 4-1/2" 12.6# 13Cr85 1 43-8558 Packers and SSSV Type: 4-1/2" HES TNT Perm Packer Packers and SSSV MD (ft) and TVD (ft): 8439, 8277.45 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary ❑ Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 • Service ❑ 14. Estimated Date for Commencing Operations: April 15, 2020 - 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Mclaughlin, Sean M be deviated from without prior written approval. Contact Email: Sean.McLaughlinabp.com Authorized Name: Mclaughliq Sean M Contact Phone: Authorized Title: Engi enng Team Lead -CTD Authonzed Signature: / Date: O 0/-7,IJ COMMISSION USE ONLY Conditions of approval: Notify Commission sothat representative may witness Sundry Number: 3.1 taa Plug Integrity El SOP Test U/ Mechanical Integrity Test ❑ Location Clearance ❑ l/._IU Other:-qd i E5T"t o 35'eePS 3BDMS "" JAN 2 4 2020 Post Initial Injection MIT Req'd? Yes No 0 Spacing E ption Required? Y No L7 Subsequent Form Required: Q _. A16 [ / APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date1 u P10 Form 10-403 Revised 04/2017 ORIGINAL Approved application is valid for 12 months from the date of approval. (N%&T' 2"�ub For and Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Sean McLaughlin,� p CTD Engineer Date: January 20, 2020 Re: D-35 Sundry Approval Request Sundry approval is requested to re -complete D-35 with new perforations and Automated Inflow Control Device (AICD)/Swell packer completion inside the 4-1/2" Liner. History of D-35: D-35 is a December 2015 rotary sidetrack that was drilled to access GDWFI and GD reserves in Northwestern D -Pad. The wellbore resembles a drawn-out U-shaped profile - the horizontal portion of the wellbore is in lower Z213 and the toe of the well TD's in Z2C. The well was initially completed in a Z213u oil lens near the toe, leaving - 2000' of horizontal unperforated. Proposed plan for D-35: Since there is considerable lateral to perforate (2000') and the well is a 4-1/2" monobore D-35 will be recompleted with AICD's within a 2-3/8" liner to capitalize on production from the entire lateral without the added risk of premature gas break through. This intervention will add 680' of perforations over six intervals and install "'40 AICD's to allow access to the remaining stages of perforations. Swell packers will be used to isolate perforation intervals. This retrofit liner is designed to automatically regulate gas production by perf interval or zone. The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed workover is attached for reference. Pre -Rig Work 1. SL Set Dummy GLV's and PT 2. F MIT -IA 1. V Pre -CTD Tree work and pad prep Rig Work (scheduled to begin May 151h, 2020)Wphasing 1. MIRU and test BOPE 250 psi low and 3,500 psi high (M2. Perforate -680' MD with 2-7/8" perf guns, 6 SPF, ran3. Perform 4-1/2" liner clean out run 4. Run 2-3/8" 13Cr, AICD/Swell Packer liner inside 4-1/2 5. Freeze protect well to a min 2,200' TVDss. 6. Close in tree, RDMO. Post -Rig Work: 1. V: Valve & tree work 2. S: Set 45KB + PTSA LTP, install generic GLVs 3. T: Portable test separator flowback. Sean McLaughlin CC: Well File CTD Engineer Joe Lastufka 223-6784 TREE= CNV LLHEAD= FMC TUATOR= BAKERC . ELEV = 88.45' ELEV = 4322' = [Dahmn I SPF 6 = 112' 12600' n MD = 9189' N 11630-11661 D = 9900' 69u 129.4#, A-53, D=19.25" SG, 40#, L-80 HYD 563, D= 8.835" 3185' Minimum ID = 3.726" @ 8640' 4-1/Y' HES XN NIPPLE MATED TOP OF CEMENT(12/02/15) —F-7476- 1.0152 bpf, D = 3.958" CSG, 26#, L-80 TA—MTC 1 8552' 1 8558' D=6276- 8713' D-3 5SAFEi .OTES: WELL ANGLE> 70" @ 9441"" MAX DOGLEG: 19• @ 11692' —CHROME TBG & LNR 2030' 4-1/2" HES X NP, ID = 3.813" n ci ST PERFORATION SUMMARY ND REF LOG: SLB Vision LWD on 12/09/15 TYPE ANGLE AT TOP PERF: 93' @ 11630' Note: Refer to Production DB for kstoriml perfdata SIZE I SPF INTERVAL I OorgSoz SHOT SQZ 2-1/2" 6 11630-11661 O 09/02/79 ' 2-1/2" 6 11990 -12021 0 09/02/19 T 09104/19 72373-12403 C 12/37/15 ' D-3 5SAFEi .OTES: WELL ANGLE> 70" @ 9441"" MAX DOGLEG: 19• @ 11692' —CHROME TBG & LNR 2030' 4-1/2" HES X NP, ID = 3.813" n ci ST MD ND DEV TYPE VLV LATCH SIZE DATE 5 3493 3481 0 KBG2 DOME BK 16 08/04/19 4 5252 5240 1 KBG2 SO BK 20 09104/19 3 6517 6503 8 KBG2 DMY BK 0 12/11/15 2 7574 7499 26 KBG2 DMY BK 0 12/11/15 1 9343 8191 26 KBG2 DMY BK 0 12/11/15 I74��4-72"FESX NP,D=3.873" 7"X4-1/2" HES TNT Rdj D = 3.856' 8476' 4-112" H6 X NP, ID= 3.873" 8540' 4-1/2"I$XNNP,D=3.725" 8552' 7"X5"BKRZ)(PPKRw/FLIXLOCK HGR T133ACK SLV, ID=4.310" 8558' 41/2" WLEG, D=3.958" ELND TT NOT LOGO 8586' S' X 4-1/2" XO, D= 3.920" I 9627' H4-1/2"PUP JOINT w/RA TAG 1 BKR 1 12492' 1 LNR, 12.6#, 13CR-80 hpf, D = 3.958" DATE I REV BY I COMMENTS DATE REV BY COMMENTS 12M3/15 P-273 IORIGINAL COMPLETION 08/31/16JPK/JMD GLV C/O 08/25/16 12/15/15 JMD DRLG HO CORRECTIONS 08107/19 JPK/JMD GLV C/O 08/04/19 12/16/15 JR1JMD FINAL ODE APPROVAL 09/09/19 JCF/JMD SET CBP &ADPERFS 09/02/19 1221/15 JTG/JMD GLV C/O (12119/151 0927/19 DD/JMD ADDED OKB & BF ELEV 01/06/16 ATO/JMD PERFORATIONS 12/31/15 01/13/16 TR/JMD UPDATED CONDUCTOR DEPTH TAG PRUDHOE BAY UNIT WELL: O-35 PERMITNo: '2151310 API No: 50-029-23554-00 T11 N. R13E, 1579' FNL & 169: BP Exploration (Alaska) Davies, Stephen F (CED) From: Mclaughlin, Sean M <Sean.McLaughlin@bp.com> Sent: Wednesday, January 22, 2020 11:26 AM To: Davies, Stephen F (CED) Subject: RE: PBU D-35 (PTD 215-1310; Sundry 320-029) - Question Proposed intervals: Depths (from - to) _ 9,910,-- _ 10,010' _ _ 10,130' 10,230' _ _ 10,350' _ 10,450' _ _ 10,570' _10,670' _ _ 11,000' 11,140' - 11,260' - 11,400' Sean From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Wednesday, January 22, 2020 9:11 AM To: Mclaughlin, Sean M <Sean.McLaughlin@bp.com> Subject: PBU D-35 (PTD 215-1310; Sundry 320-029) - Question Sean, I'm reviewing BP's Sundry Application to add a total of 680' of perforations spread over six intervals to this well. Could you please provide the approximate footages for each of the six planned perforation intervals? I didn't see those footages within the application package. Thank you, Steve Davies AOGCC 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 recipientls). 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. TREE = CNV D= FMC R= BAKERC V = 88.45' = 4322' P SOZ = 112' 12600' = = 9189' 8800' SS Proposed D =1925" SG, 40p, L-80 HVD 563,0=8.635" 31g, Minimum ID = 3.726w'@ 8640' 4-1/2" HES XN NIPPLE ITOPOF4-12" LNR I 4-12" TBG, 12.&1, 13CR86 VAMTOP, 8558' .0152 bpf, D = 3.958" 7 -CSG, 26H, L-80 VAM TOP HC, D=6276" g7j $• PERFORATION SUMMARY REF LOG SLB Vision LWD on 12/09/15 ANGLE AT TOP PERF: 93'@11630' Note: Refer to Production DB for ti ricalperidata SIZE ISPFI INTERVAL OPrdSqz I SHOT SOZ 2-12" 6 11630-11661 O 09102/19 JR/JMD 2-12" 6 11990-12021 O 09102/19 5240 2-7/8" 6 12373-12403 C 12/31/15 08104/19 Perforation Swell packer , 12.610, 13CR-80 VAM TOP HC, D = 3.958" D-35 SAFEI . .OTES: WELL ANGLE> 70" @ 9441— MAX DOGLEG: 19^ @ 11692""CHROME TBG &LNR 2030' 4-12" FES X NP, ID = 3.813" r-ec i =ruwuneo 0 ST MD TVO DEV TWE P-273 5' DATE 5 3493 3461 0 UG -2 JR/JMD 16 08/04/19 4 5252 5240 1 KBG220 PERFORATIONS 12/31/15 08104/19 3 6517 6503 8 KBG2 qDMYBK 0 12/11/15 2 7574 7499 26 KBG2 0 12/11/15 1 8343 8191 26 KBG2 0 12111/15 8412• -14-12" HES X NP, D = 3.813" —"J 7"X4-1/2" H6 TNf RQ; D = 3.856" 8476' 4-1/2" HES X NS? ID = 3.813" """`• _J 4-12" HES XN RP, D = 3.725" 8552' 7"X5"BKR ZXP PKRw/FLEXLOCK HGR TIEBACK SLV, D = 4.310" 8558' 4-12"WLR, D=3.958" ELNDTi NDTLOGG® 8588' S" X 4-12' XO, D = 3.920" Top of liner —9,185' -i 9627' 1I44-12"RJPJONTw/RA TAG 2-3/8" 13Cr HYD511, w/ Blast joints across the preforation interval 10296' 4-12" PUP JONT wIRA TAG Bottom of liner -12,300' DATE REV BY COMMENTS DATE REV BY COMMENTS 12113/15 P-273 ORIGINAL COMPLETION 08(31/16 JPKIJMD GLV C/0 0825/16 12/15/15 JMD DRLG HO CORRECTIONS 08/07/19 JPK/JMD GLV C/O 08/04/19 12/16/15 JR/JMD FINAL ODE APPROVAL 09/09/19 JCF/JMD SET C13P&ADPERFS 09/02/19 12/11/15 JTGIJMD GLV C/O 12/19/15 0927119 DD/JMD ADDED OKB & BF ELEV 01/06/16 ATO/JMD PERFORATIONS 12/31/15 01/13/16 TR/JMD UPDATED CONDUCTOR DEPTH PRUDHOE BAY UNIT WELL: D35 PERMIT No: '2151310 API No: 50-029-23554-00 T11 N, RI3E, 1579' FNL & 169: BP Exploration (Alaska) Well Blghole CDR2-AC 4 Ram BOP Schematic Date 21-Nov-17 Quick Test Sub to Otis -1.1ft ------------.—.—. Top of 7"Otis0.0ft —._._._._._._._. ._._. _._. Distances from top of riser �— —CDR2 Rig's Drip Pan Excluding quick-test sub Top of Annular 7-1/16" 61, Flange X T' Ons Box 6.0 ft Hydril 7 1116" Top of Annular Element 6.7 ft Annular Bottom Annular CL Blind/Shears P lip, Bli.rUsh., CL 2-3/8" Pipe/Slips 10.1 ft 2-3/8' Pipe)Slips e1 e2 w Ba Choke Line Kill Line CL 2-3/8" x 3-1/2" VBRs 12.6 k CL 2-318" Pipe/Slips 13.4ft CL of Top Swab 16.0 ft �— Swab T1 CL of Flow Cross 17.4ft f� Master CL of Master 18.6 ft LDS O IA OA LDS O Ground Level 0 T2 Test Pump Hose Davies, Stephen F (CED) From: Mclaughlin, Sean M <Sean.McLaughlin@bp.com> Sent: Wednesday, January 22, 2020 11:26 AM To: Davies, Stephen F (CED) Subject: RE: PBU D-35 (PTD 215-1310; Sundry 320-029) - Question Proposed intervals: Depths (from - to) 9,910'--- _ 10,010' 10,130' _ _ 10,230' 10,350' __ _10,450' 10,570' _ _10,670' 11,000' 11,140' 11,260' 11,400' Sean From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Wednesday, January 22, 2020 9:11 AM To: Mclaughlin, Sean M <Sean.McLaughlin@bp.com> Subject: PBU D-35 (PTD 215-1310; Sundry 320-029) - Question Sean, I'm reviewing BP's Sundry Application to add a total of 680' of perforations spread over six intervals to this well. Could you please provide the approximate footages for each of the six planned perforation intervals? I didn't see those footages within the application package. Thank you, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or Steve.daviesaa laska.aov. WELL LOG TRANSMITTAL #905937940 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: D-35 Run Date: 9/1/2019 21 41 7 1 3 130 2 October 2, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 D-35 Data in LAS format, Digital Log Image files 50-029-23554-00 RECEIVE OCT 0 7 2019 AOGCC 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com and GANCPDC@USAANC.hou. Date: Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WFI I nPFRATIn?Jc 1. Operations Performed Abandon ❑ Plug Perforations 21 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown _ ❑ Suspend ❑ Perforate m Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set CIBP m 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development m Exploratory ❑ 5. Permit to Dnil Number: 215-131 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-23554-00-00 7. Property Designation (Lease Number): ADL 028284 & 028285 8. Well Name and Number: PBU D-35 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 12600 feet Plugs measured 12309 feet true vertical 8879 feet Junk measured None feet Effective Depth: measured 12309 feet Packer measured 8439 feet true vertical 8976 feet Packer true vertical 8278 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 123 20" 49-172 49-172 Surface 3137 9-5/8" 48-3185 48-3173 5750 3090 Intermediate 8668 7" 45-8713 45-8524 7240 5410 Production Liner 4030 4-1/2" 8552- 12582 8380-8886 8430 7500 Perforation Depth: Measured depth: 11630 - 12403 feet True vertical depth: 9015-8950 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr85 43-8558 43-8385 Packers and SSSV (type, measured and 4-1/2" HES TNT Perm Packer 8439 8278 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 680 59678 4 2014 1090 Subsequent to operation: 1348 26346 720 1243 812 14. Attachments: (required per 20 MC 25.070.25.071, &25.2M) 15. Well Class after work: Daily Report of Well Operations m Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 21 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sun dry Number or N/A if C. 0. Exempt: WA WA Authorized Name: Stone, Christopher Contact Name: Stone, Chnstopher Authorized Title: D & K Pad / GC1 Lead Petroleum Engineer Contact Email: Chnstopher.StonegMbp.com Authorized Signature: Date: 9 Contact Phone: +1 907 564 5518 Form 10-404 Revised 04/2017 I (j �� . RBDMS_P6-Jn.cT n 7 MM0 Submit Onginal Only Daily Report of Well Operations PBU D-35 ACTT V ITV nATF c i uAAA A ev ***WELL FLOWING UPON ARRIVAL*** (profile modification) DRIFTED TO DEVIATION @ 9,430' SLM W/ 10'x 2 7/8" DUMMY GUNS (3.16" omega rings), 2 1/2" SAMPLE BAILER SET 4 1/2" WHIDDON CATCHER IN XN NIP @ 8,540' MD PULLED BK-DGLV'S FROM ST#4 @ 5,252' MD & ST#5 @ 3,493' MD SET BK-LGLV (16/64 ports, 1,500 psi tro), IN ST#5 @ 3,493' MD SET BK-OGLV (20/64 ports) IN ST#4 @ 5,252' MD PULLED EMPTY CATCHER FROM XN NIP @ 8,540' MD 8/4/2019 ***WELL FLOWING ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** CTU #8 - 1.75" Coil, 0.156" wt Job Objective: Drift, RPM, RBT, Set CIBP, AddPerf MIRU CTU. Perform weekly BOP test. Make up 3.70" x 7.3' drift BHA with DJN and RIH. Load well with 1% KCI w/ SafeLube. ...Continued on WSR 8-31-19... 8/30/2019 CTU #8 - 1.75" Coil, 0.156" wt ***Cont. from WSR 8-30-19*** Job Objective: Drift, RPM, RBT, Set CIBP, AddPerf RIH with 3.70" x 7.3' Drift BHA to TD tag of 12468' CTMD. Pick up 50' and paint TD flag at 12418'. POOH keeping hole full down the backside. Make up RPM logging BHA and RIH. Log RPM up pass from 12,462' to 7,950' at 20 fpm. RIH and repeat RPM up pass from 12,462' to 7,950' at 20 fpm. POOH and confirm good data. Change Pack offs and trim coil. Make up HES RBT for cement bond log. 8/31/2019 ...Continued on WSR 9-1-19... CTU #8 - 1.75" Coil, 0.156" wt ***Cont. from WSR 8-31-19*** Job Objective: Drift, RPM, RBT, Set CIBP, AddPerf RIH with HES RBT cement bond log tool. Make 2 logging passes from 12460' up to 7950' painting a tie in flag at 12,200' on the second pass. POOH. RIH w/4-1/2" CIBP and set at 12,310' mid element (12309' top of CIBP). POOH. Make up Perf gun run #1 with 31'x 2.5" PowerJet Omega perf guns, 6 spf, RIH. ...Continued on WSR 9-2-19... 9/1/2019 CTU #8 - 1.75" Coil, 0.156" wt ***Cont. from WSR 9-1-19*** Job Objective: Drift, RPM, RBT, Set CIBP, AddPerf RIH with perf gun run #1 with 31' x 2.5" PowerJet Omega, 6 spf pert gun. Test CIBP to 1000 psi with pipe displacement. Tage CIBP for depth correction and shoot 11990'-12021'. POOH. Shots fired and ball recovered. MU gun #2 and RIH with 31'x 2.5" PowerJet Omega, 6 spf gun. Perforate interval 11,630'- 11,661'. POOH. FP tubing with 38 bbls of 50/50. Shots fired and ball recovered. RDMO 9/2/2019 ** Complete ** TRF£= CIW WELLHEAD= FMC ACTUATOR= BAKER OKB. E_EV = —_ BF. ELEV = 30E KOP= _ Max Angle = 112' @ 12600' Datum MD _ 9169' Datura D= BK 8800' SS 53, D- 19 ,299255'. , SG, 40#, L-80 HYD 563, D = 8.835-]—=31 Minimum ID = 3.7251'@ 8540' 4-112" HES XN NIPPLE I TOP OF 412" LNR I 4-1/2" TBG, 12.6#, 13CR-85 VAM TOP,8558' .0152 bpf, D = 3.958" SG, 26#, L-80 VAM TOP HC, D = 6276" 8713' D-35 SAFETY DOGLEGN6T @ 11692- -CHROME TBG & LNR MAX 2030' 412" HES X NP, ID = 3.813" neat crueunovia ST MD 7VD DEV TYPE VLV LATCH 30E DATE 5 3493 3481 0 KBG-2 DOME BK 16 08/04/19'. 4 5252 5240 1 KBG2 SO BK 20 08/04/19 3 6517 6503 8 KBG2 DMY BK 0 12/11/151 2 7574 7499 26 KBG2 DMY BK 0 12/11/151 1 8343 8191 26 KBG2 DMY BK 0 12/11/151 14-12" HES X NP, D = 3813- 7- X 4-1/2" HES TNT PKR, D = 4-12" HES X NP, D = 3.813- 7" X 5" BKR ZXP PKR w /R TIEBACK SLV, D=4.310" 4-112" WLEG, D = 3.958" BMD TT NOT LOGGED 5"X 4-12" XO. D = 3.920" PERFORATION SUMMARY DATE REV BY COMMENTS 12113/15 P-273 ORIGINAL COMPLETION REF LOG: SLB Vision LWD on 12109/15 JPK/JMD GLV C/O 0825116 12/15/15 JMD ORLGHOCORRECTIONS 08/07119 ANGLE AT TOP PERF: 93'@ 11630' 12/16/15 JWJMD FINALODEAPPROVAL 09109119 9627' 4-12" PUP JOINT w /RA TAG Note: Refer to Pmduclion DB for historical rfdafa 01406/16 ATO/JMD PERFORATIONS 12/31/15 SIZE SPF NTERVAL n5 SHOT SOZ 2-12" 6 11630-11661 O 09/02/19 2-12" 2-7/8" 6 6 11990-12021 12373-12403 O C 09/02/19 12/31/15 10295' 4-12" PUP JOINT w/RA TAG LNR, 12.6#, 131 bpf, D = 3.958" DATE I REV BY I COMMENTS DATE REV BY COMMENTS 12113/15 P-273 ORIGINAL COMPLETION 08/31/16 JPK/JMD GLV C/O 0825116 12/15/15 JMD ORLGHOCORRECTIONS 08/07119 JPKIJMD GLVC/O 08/04/19 12/16/15 JWJMD FINALODEAPPROVAL 09109119 JCF/JMD SETCBP&ADPERFS 09/02/19 1221115 JTG/JMD GLV C/O 12/79/15 01406/16 ATO/JMD PERFORATIONS 12/31/15 01/13/16 TRIJMD UPDATED CONDUCTOR DEPTH 14-12" SKR CBP (09/02/191 HGR PRUDHOE BAY UNIT WELL: 035 PERMIT No: '2151310 API No: 50-029-23554-00 BP Exploration (Alaska) 2151;'11 BA ER 0 3124 HUGHES PRINT DISTRIBUTION LIST a GE company COMPANY BP Exploration Alaska Inc. WELL NAME FIELD Prudhoe Bay Unit COUNTY PRUDHOEBAY BHI DISTRICT Alaska AUTHORIZED BY Frank Schwarzrock EMAIL frank.schwarzrocka�bhgecorn STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION 4 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids .Agatha Reeks & Barbara Glassmaker 900 E. Benson Blvd. Anchorage, Alaska 99508 lem Ise sign and return one copy of this transmittal form to: Exploration (Alaska) Inc. rotechnical Data Center, LR2-1 I E. Benson Blvd. :horage, Alaska 99508 or AKGDMINTERNAL@bp.com LOG TYPE RPM:PNC3D LOG DATE August 31, 2019 TODAYS DATE September 21, 2019 Revision Details: Rev. Requested by: --- FIELD I FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES 19 OF COPIES 4 JJ JJ 2 I ConocoPhillips Alaska Inc. 1 Attn: Ricky Elgarico ATO 3-344 700 G Street 'Anchoragc, AK 99501 3 Exxon Mobil, Alaska ''Attn; Lynda M. Yaskell and/or Lisa Boggs 3201 C Street, Suite 505 Anchorage, AK 99503 4'State of Alaska - AOGCC 1 1 Attn: .Natural Resoureas Technician 11 1333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5iDNR -Division of Oil &Gas *" 1 .kttn: Garret Brown 550 West 7th Avenuc, Suite 1100 Anchorage, Alaska 99501 1 8 RP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 1900 E. 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V m O E E z `° vi _a wTo co 0) J O. c J C D P E CO CL (D c I C _O c O 1 1 H N a E en O co r- 0 C w LO 0 ....... 1 m } £ M N J c� c E OA co ccd ICC M V I. 1nn" co coZ N ' C H II } M o y @ m mCV o Ww 3 I O N N ////�� 2 m .0 a) c ',, w V/ • o c C O c $1 r d O C •E 2U a 1 ICC 6 Z o a a .E caZ11 II I 3 a l n• Q 1 1 N CO 1 M 1 } } N 0 0 0 $ I) ›- 5% 03 1- (0 N i I a 10 Ea O 1 N w O F- 1 3 N O c N i 1 co_ 11 +O aQi 2 W m w CD C O d F `6 V C a)•• 0c C 11 Z c m O v! V .O. Col 0 O J Qi ICO U U a 7 o a a C a 0O • 0E a o y 1 d a m 0 a 0 0 0 a 0 0 r • 215131 26 S 3 0 ■lid MAR 14 2016 PRINT DISTRIBUTION LIST BAKER HUGHES Please sign and return one copy of this transmittal form to: Anci ' COMPANYExp6ration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED WELL NAME D-35 900 E.Benson Blvd. M K`BENDER 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 December 31,2015 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhughes.com TODAYS DATE March 10,2016 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.Box) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #UI-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. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 I 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 I 1 1 I 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 V 4 State of Alaska -AOGCC 0 I 1 1 I 0 I 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 I 1 I 1 i 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 *5*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 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 • • Link, Liz M (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Wednesday, March 02, 2016 3:48 PM To: AOGCC Reporting (DOA sponsored) Subject: PBU D-35 / PTD # 215-131 Follow Up Flag: Follow up Flag Status: Flagged Hello, Please reference the following well: Well Name: PBU D-35 Permit#: 215-131 API #: 50-029-23554-00-00 Date of Test: 2/29/2016 Type of Test: IPT (Initial Production Test) Choke Size: 70 Choke Unit: Production Method: Flowing Duration (Hours Tested): 4 Top Reference (Top Perf MD): 12373' Bottom Reference (Bottom Perf MD): 12403' Tubing Flowing (Pressure): 1180 Casing Pressure: 1360 Total Test Rate (0, G, W): 519 /5190 /67 24-Hour Rate (0, G, W): 3113 / 31138 /402 Gravity (Oil, API): Not Available GOR (Gas-Oil Ratio): 10003 This well began Production on Method of Operations on this date: February 28, 2016 1 RBDMS Lk- OR 0 3 2016 � z16131 � I�VED 26 86 3 Schlumberger FEB 26 2016 Transmittal#: 26FEB16-SPO1 Drilling&Measurements DATA LOGGED at mimic) Log Product Delivery M K.BENDER Customer: BP Exploration Alaska Inc �e Dispatched To: Makana Bender Well No: D-35 Date Dispatched: 26-Feb-16 APIN: 50-029-23554-00-00 Dispatched By: Stephanie Pa cillo Well/ Product Hardcopy Digital Copy E-Delivery Date Delivered To: ansmittal#: 26FEB16-SPO1 AOGCC Makana Bender 7 Total Contents on CD N/A Color Log Prints: 5 VISION*Services 2" MD x x VISION*Services 2'TVDSS x x VISION*Services 5'MD Quadrant Density x x VISION*Services 5'MD x x VISION*Services 5'TVDSS x x Digital Data N/A Contents on CD x Survey 1 Contents on CD ASP Final Survey x x EOW CD 1 Contents on CD Graphics:PDF x Data:DLIS/ASCII x Survey:PDF,XLS x Please sign and email a copy to: Please sign and email a copy to: AlaskaPTSPrintCenterslb.com qancpdcbp.com Alaska PTS Print Center ATTN:Merion Kendall Received By: o_e„..teat M M • • w si- 4e00,-MM m NN^ 0,-00,yy00 to0NCNr Co 0CoC OoC NO ,M0 666m4 ONppV ONNOa At0 M e_ 2.MN MMNO0 0, 04M.0 0 _MNMMO. 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CC0 0 C° NAMO0000mr�AnOQNOO� MOAAOWr ONrM0Aceapp ------ WLL d D _ c)h WODOa) M10O.t+ MOg �N ANr0 togo yWm ON900MQMWAACNO000 0,-NN WOW MmM O 00 -1C0 _ N rrr rrrrr rrrr c W N rig_ 0� U m NW 2 M A0 ANO0 000M.0 NMO0,0,WOONAMW ONO W 7rWW.. OOM00)rMOQND n r LN M46N WOraN L :OWr NaOOO NO0N MOAWOM66M .46. NMMM 'Q<N8SW0O rtOWWW 1NNOWNNN NMWaV N020 y0 mJ ONN NNNNN NNNNN NN8G° 6 Co o M m a . a 3 N o - 8 �m II O 1 o 0 U • • 410 I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIANNCOMM WELMPLETION OR RECOMPLETION REPW AND LOG la. Well Status: Oil Q• Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 0 lb.Well Class: 20AAC 25.105 20AAC 25.110 Development p Exploratory ❑ GINJ 0 WINJ ❑ WAG 0 WDSPL 0 No.of Completions: One - Service 0 Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 12/31/2015 215-131 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 11/23/2015 50-029-23554-00-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 12/8/2015 • IS t) D-35 ' Surface: 3701'FSL,1692'FEL,Sec.23,T11N,R13E,UM 9 KB Ref Elevations 17. Field/Pool(s): 88.45 Top of Productive Interval: 3805'FSL,3050'FEL,Sec.23,T11N,R13E,UM GL 41 - BF PRUDHOE BAY,PRUDHOE OIL Total Depth: 4882'FSL,811'FEL,Sec.22,T11N,R13E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: . 12492'/8920' - ADL 028284&028285 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD) 19. Land Use Permit: Surface:x- 653460 • y- 5959410 - Zone - ASP 4 • 12600'/8879' • 91-32 TPI: x- 652100 y- 5959487 Zone - ASP 4 12. SSSV Depth(MD/TVD): PO Thickness of Permafrost MD/TVD: Total Depth:x- 649038 y- 5960501 Zone - ASP 4 None 1919'/1907' 5. Directional or Inclination Survey: Yes p (attached) No ❑ 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) N/A 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,MWD/GR/RES,MWD/GR/RES/NEU/DEN 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. - PULLED TOP BOTTOM TOP BOTTOM 20" 129.4# A-53 49' 172' 49' 172' 42"x24" 15 cu yds Concrete 9-5/8" 40# L-80 48' 3185' 48' 3173' 12-1/4" 1573 sx LiteCrete,240 sx Class'G' 7" 26# L-80 45' 8713' 45' 8524' 8-3/4" 270 sx Class'G' 4-1/2" 12.6# 13Cr80 8552' 12582' 8380' 8886' 6-1/8" 384 sx Class'G' 24. Open to production or injection? Yes 2 - No ❑ 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): 4-1/2"12.6#13Cr85 8558' 8439'/8278' 2-7/8"Gun Diameter,6 spf 12373'-12403' 8959'-8950' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. • RECEIVED Was hydraulic i)(2 used during r completion?and opri Yes ❑ No 0 COMPLETION Per 20 AAC 25.283(i)(2)attach electronic anprinted DATE information JAN 15 2016 12/31 /r5 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED 2200' Freeze Protect w/75 Bbls Diesel AOGCC 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 �111. 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 W M i1Q SITS1i6 4i i�� RBDMS ,.L- JAN 2 5 2016 r- i, Ci 28. CORE DATA Conventional Core(s) Yes 0 No 0 Sidewall Cores Yes 0 No R If Yes to either question,list formations and interva s cored(MD+TVD of top and bottom of each),and summarize ethology 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 41' 41' Well Tested? Yes 0 No I Permafrost-Base 1960' 1948' If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9170' 8875' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Ugnu 4282' 4270' West Sak 5738' 5725' Colville Mudstone 5935' 5922' • HRZ 7278' 7233' Base of HRZ 7534' 7463' LCU 7551' 7478' Sag River 8714' 8525' Shublik A 8747' 8554' Shublik B 8789' 8591' Shublik C 8813' 8612' Sadlerochit-Zone 4 8832' 8628' CGL-Zone 3 9092' 8820' BASE OF CGL-ZONE 2 9170' 8875' Formation at total depth: Zone 2 9170' 8875' 31. List of Attachments: Summary of Daily Drilling Reports,LOT/FIT Summary,Survey,Cement Reports,As-Built,Well Schematic Diagram 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: Rosenbaum,Jesse E Email: Jesse.Rosenbaum@bp.com Printed Name: Joe Lastuf Title: Drilling Technologist Signature: Phone: +1 907 564 4091 Date: 11 1'.51 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 1 a. 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 TREE= CNV VV _ H LHEAD= FMC • 3 5 ANOTE19" S 1 WELL AGHROME TBG 9 LNR MAX ACTUATOR= BAKER C OKB.ELEV= L BF.ELEV= ' KOP= 20"NNEN SU_TD ' ' 2030' —4-112'HES X NP,D=3.813" Max Angle= 112'@ 12600' GOND, Datum MD= 9189' 129.4#,A-53, Datum TVD= 8800'SS D=19.25" GAS UFT MANDREIS ST MD TVD DEV TYPE VLV LATCH SIZE DTE 9-5/8"CSG,40#,L-80 HY D 563,D=8.835' -r 3185' 5 3493 3481 0 KBG-2 DOME BK 16 12/19/15 4 5252 5240 1 KBG-2 SO BK 20 12/19/15 Minimum ID = 3.725" @ 8540' 3 6517 6503 8 KBG-2 DIN BK 0 12/11/15 4-1/2" HES XN NIPPLE L 2 7574 7499 26 KBG-2 DMY BK 0 12/11/15 1 8343 8191 26 KBG-2 DMY BK 0 12/11/15 ESTIMATED TOP OF COAENT(12/02/15) —{ —7475' .� �-mss' a + ' , 8412' --�4-1/2"HES X NP,D=3.813" _� A8439' —,7'X 4-1/2"HES TNT PKR,D=3.856" li v I I 8475' --14-1/2"HES X NP,D=3.813" At. ,r c f , , A 8540' H4-1/2"HES XN NP,D=3.725" I kms{ - TOP OF 4-112"LNR — 8552' �h 8552' —7"X 5"BKR ZXP PKR w/FLEXLOCK HGR `= ►�� TEBACK SLV,D=4.310" \1$PZ 4-1/2"TBG,12.6#,13CR-85 VAM TOP, — 8558' 8558' H4-1/2-WLEG,D=3.958" .0152 bpf,ID=3.958' '* —{B ND TT NOT LOGGED 7"CSG,26#,L-80 V AM TOP HC,D=6.276" H 8713' . 104 r. � 8586' J--5"X 4-1/2"XO,D=3.920" re 40" � TT' PERFORATION SUMMARY REF LOG: SLB Vision LWDon 12/09/15 `� C ANGLE AT TOP FERE: 107"@ 12373' Note:Refer to Production DB for historical perf data SIZE SFE INTER/AL Opn/Sqz SHOT SQZ ! 2-7/8" 6 12373-12403 0 12/31/15 9627' H4-1/2"PUP JOINT w/RA TAG /*/ "Alr.:** r10295' —14-1/2"PUP JONTw/RA TAG PB —1 12492' t!Pen) , ;7,,%•::,e;:*:48 k 4-1/2"LNR,12.6#,13CR-80 VAM TOP HC, —{ 12582' . ►y .0152 bpf,D=3.95&" DTE REV BY CONVENTS DATE REV BY COMMENTS PRUDHOE BAY INET 12/13/15 P-273 ORIGINAL COMPLETION WELL: D35 12/15/15 JMD DRLG HO CORRECTIONS PERMIT No: '2151310 12/16/15 JR/JMD FINAL ODE APPROVAL API No: 50-029-23554-00 12/21/15 JTG/JMD GLV GO(12119/15) SEC 23,T11N,R13E,1579'FTL&1692'Fa 01/06/16 ATO/JMD PERFORATIONS(12/31/15) 01/13/16 TR/JMD UPDATED CONDUCTOR DEPTH BP Exploration(Alaska) ROAD - 1 SpiNE ', I =ti SEC ,�" I /1 SE o _ --, 15 _, 4 T4, Iy, 13 '•I o_ 7 w t / 7 / — — — — / 1°,� _.. _ _ ,. , THIS PROJECT., ' MOD 93 ;r —fig— O "I MOD 52 I �, 1 1 MO0 23■ MOD 58 • I E 1 E I 28■ I t . , A SEC SEC SEC 24 D-3522 ✓ t MOO MA ` 22 i y . '11_,.. 'z 27 / \. f D—PAD 210 30* I 5 ■ 26 i 25* 1 20a 4 a j _ — 19a 24* SEC SEC SEC 3 a 27 r 26 25 * a 1 ,a i MOD 53 2 i VICINITY MAP 17■ NTS — 1 i 16■ i t`,,rr�1Williii 7 r % Or .`I hi { , _.. ..- ,ij 33■ �`a�l�A'SnS•e...e•.•„�:,/ e, } 6 r •ice 17••• ,�i- ••e"°1„9,�T *14. Ili ,4\ i +,eoa•/l • 01.10 15■ : /,i ��►,0 "` / go 1 14 a i ° mothy F.•�imhart : — 13. jet `,.'•.. 10200 •/ `~4 1 j �14;4 ••• ••• 12■ I lith 101.4- %,� �''>w 11 r ' SURVEYOR'S CERTIFICATE 32 r I HEREBY CERTIFY THAT I AM 10• PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN D PAD 34 • THE STATE OF ALASKA AND THAT THIS AS—BUILT REPRESENTS A SURVEY • MADE BY ME OR UNDER MY DIRECT B�• I SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 16, 2016. NOTES: 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD27. 2. GEODETIC POSITIONS ARE NAD27. 3. HORIZONTAL CONTROL IS BASED ON BPXA D PAD GRAPHIC SCALE LEGEND' MONUMENTS D-2 AND D-4. 0 200 400 800 4 AS-BUILT CONDUCTOR 4. ELEVATIONS ARE D PAD DATUM, M.S.L. I I 5. D-PAD AVERAGE SCALE FACTOR IS: 0.9999269. ( IN FEET ) • EXISTING CONDUCTOR 1 inch =400 ft. 6. REFERENCE FIELD BOOKS: NS15-53, PGS. 21-22; NS16-03 PG. 29. 7. DATES OF SURVEY: OCTOBER 14, 2015; JANUARY 16, 2016. LOCATED WITHIN PROTRACTED SECTION 23, T. 11 N., R. 13 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC TOP OF BASE SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) CELLAR BOX FLANGE EL. OFFSETS Y=5,959,409.84 N 3,792.00 70'17'45.793" 70.2960536" 41.0' 43.22' 3,701' FSL D-35 X= 653,459.78 E 1,373.82 _148'45'26.331" 148.7573142' 1,692' FEL DRAMJACOBS xxiECl¢D:HOLL.AWAYØbp DATE:10/21/15 NG: FRB15 WOO 03 WOA D PAD SHEET. JCB NO.. 01 p1/15/Ie ADDED BASE FLANGE EIEVA7pJ¢MANGO 5ZC CBt11FlIODA1t 04051 0 AS—BUILT CONDUCTOR , 00 10/21/15 ISSUED FOR INFORMATION JJ AAH r = 400' WELL D-35 1 OF 1 NO- DAZE REVISION BY CHK • c� .,. :•_- , INE ROAD `M CC-i ..7 SEC i SEC �� / 15 l4 I3 `�� ri TM!sto.�EcrI".>D �: MOD 93 I – /4111–ii , O el'',MOD 52 I (' I 'i 23■ 28■ G--) M00 58 SEC I j..; SEC 23 SEC L`_ 1 ' 24 0-35Z2� MOD 52A 22 ; f 21• i 30■ 1 D-PAD 26• 5 ■ . 20■ 25■ 4 ■ "- — — — 19■ 24• r 3 • SEC SEC SEC 27 . 26 25 a . 18■ MOD 53 29 U , 1 2 VICINITY MAP 17■ ■ NTS 16■ ,ltMUM{III,,f 7 . � OF q 1 l I 33• ��`b. . •.......4'9• S / ' ' 49Id —1:\ .:11.*i i • 15■ '.' 14. hard Alison a•08 !4; Ili 13■ /,/II, FSS1ONPa 4* �`• 12• �fftgit� nO%%% " ' SURVEYOR'S CERTIFICATE 32■ I HEREBY CERTIFY THAT I AM 10• PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN D PAD 39 T•• HE STATE OF ALASKA AND THAT THIS AS—BUILT REPRESENTS A SURVEY 31■ MADE BY ME OR UNDER MY DIRECT 8 ■ SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF OCTOBER 14, 2015, NOTES: 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD27. 2. GEODETIC POSITIONS ARE NAD27. 3. HORIZONTAL CONTROL IS BASED ON BPXA D PAD GRAPHIC SCALE LEGEND: MONUMENTS D-2 AND D-4. 0 200 400 800 4 AS-BUILT CONDUCTOR 4. ELEVATIONS ARE D PAD DATUM, M.S.L I ' I 5. D-PAD AVERAGE SCALE FACTOR IS: 0.9999269. ( IN FEET ) • EXISTING CONDUCTOR 1 inch =400 ft. 6. REFERENCE FIELD BOOK: NS15-53, PGS. 21-22. 7. DATE OF SURVEY:OCTOBER 14, 2015. LOCATED WITHIN PROTRACTED SECTION 23, T. 11 N., R. 13 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC TOP OF BASE SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) CELLAR BOX FLANGE EL. OFFSETS D-35 Y=5,959,409.84 N 3,792.00 70'17'45.793" 70.2960536' 41.0' N/A 3,701' FSL X= 653,459.78 E 1,373.82 148'45'26.331" 148.7573142' 1,692' FEL DRAWN:*10: JACOBSØbpiORAIM1HOLLAIVAY oAle10/21/i5 e FR815 WOD 03 _-SHEET: NO WOA D PAD AS-BUILT CONDUCTOR _- 00 10/21/lB ISSUED FOR INFORMATION JJ AAM1 OF 1 NO. DATE RFHpOx By a>< i• = 400' WELL D-35 0 0 BP AMERICA '��i LOT/ FIT Summary , , ,,,, Well Name: D-35 Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP) (psi) (ppg) 11/27/15 LOT 3,185.00 3,174.40 9.40 970.00 2,520.10 15.28 12/05/15 FIT 8,713.00 8,525.00 8.40 480.00 4,200.01 9.48 Page 1 of 1 • i North America-ALASKA-BP Page 1 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date.12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/21/2015 12:00 - 21:00 9.00 MOB P PRE MOVE MODULES -PJSM WITH RIG CREW -DISCONNECT UTILITY MODULE/DRILL MODULE INTERCONNECTS -DISCONNECT HYDRAULICS AND AIR FROM UTILITY MODULE -MOVE MUD MODULE FROM PRICE PAD AND STAGE AT D PAD SPLIT UTILITY MODULE FROM DRILL MODULE -POSITION MUD MODULE ON D PAD -REMOVE SCAFFOLD FROM BOP DECK -MOVE UTILITY MODULE AND DRILL MODULE FROM PRICE PAD TO D-PAD 21 00 - 00:00 3.00 MOB P PRE SPOT RIG -LOAD 21.25"RISERS INTO BOP DECK -SPOT DRILL MODULE OVER 0-35 '-LEVEL DRILL MODULE 11/22/2015 00:00 - 03:00 3.00 MOB P PRE MATE MODULES -MATE MUD MODULE TO DRILL MODULE -MATE UTILITY MODULE TO DRILL MODULE -LEVEL MUD MODULE AND UTILITY MODULE CONNECT INTERCONNECTS:ELECTRICAL, WATER,STEAM,AIR,HYDRAULIC AND MUD LINES. 03:00 - 04.00 1.00 MOB P PRE RAISE DERRICK -PJSM WITH RIG CREW -PERFORM DERRICK RAISING CHECKLIST -RAISE DERRICK WITH 491K OFF RACK 04:00 - 05:00 1.00 MOB P PRE SKID RIG FLOOR -PJSM WITH RIG CREW -SKID RIG FLOOR TO DRILLING POSITION -RAISE PIPE CAT -SKID HAUNCH 05 00 - 10:00 5.00 RIGU P PRE RIG UP OPERATIONS -INSTALL TORQUE TUBE PIN -INSTALL MANRIDERS -REMOVE BRIDAL LINES -PIN BLOCKS TO TOP DRIVE -UNPIN FORUM CRANE -INSTALL ROOFTOP WALKWAYS -INSTALL LANDING IN WELL HOUSE -CALIBRATE AMPHION -R/U HIGH PRESSURE STANDPIPE -RIG UP RIG FLOOR EQUIPMENT -INSTALL CUTTINGS CHUTE -SPOT CUTTING BOX -INSTALL 4"VALVES ON CONDUCTOR 10:00 - 11:00 1.00 RIGU P PRE RIG EVAC/PRE SPUD -HELD DIVERTER/RIG EVAC/H2S DRILL WITH GRADY FISHER'S CREW -HELD PRE-SPUD WITH GRADY FISHER'S CREW Printed 1/11/2016 8'53.54AM • North America-ALASKA-BP • Page 2 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. U M:500292355000 Active datum:D-35 actual©88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (usft) 11:00 - 16:30 5.50 RIGU P PRE N/U DIVERTER SYSTEM -N/U HIGH PRESSURE RISERS,AND SURFACE ANNULAR -N/U DIVERTER -TORQUE ALL BOLTS -INSTALL BELL NIPPLE -HOOK UP CONTROL LINE HOSES TO ANNULAR AND KNIFE VALVE -ENERGIZE ACCUMULATOR TEST RIG ESD SYSTEM '**SIMOPS** -LOAD 4"DP,4"HWDP INTO PIPE SHED -WELDING PROJECT IN DERRICK 16:30 - 21:30 5.00 RIGU P PRE FINISH DIVERTER LINE AND FUNCTION TEST DIVERTER -M/U AND TORQUE 2 ADDITIONAL 16" SECTIONS TO DIVERTER LINE -R/U FLOOR EQUIPMENT AND CEMENT LINE '-TAKE ON 8.5 PPG DRILL PLEX TO THE PITS -INSTALL MOUSEHOLES -TEST ALL RIG ALARMS -FUNCTION TEST DIVERTER 30 SECONDS FOR KNIFE VALVE TO OPEN, 40 SECONDS FOR ANNULAR TO CLOSE **SIMOPS** -LOAD 4"DP,4"HWDP INTO PIPE SHED AND SLB BHA IN THE PIPE SHED **ACCEPT RIG AT 17:00 HRS 11/22/2015** -AOGCC REPRESENTATIVE BOB NOBLE WAIVED WITNESS TO DIVERTER TEST 21:30 - 22:30 1.00 RIGU P PRE CALIBRATE PITS -FINISH OFFLOAD DRILLPLEX MUD -QUADCO CALIBRATE PVT'S 22:30 - 23:30 1.00 RIGU P PRED RIG EVAC/PRE SPUD -HELD DIVERTER/RIG EVAC/H2S DRILL WITH HUNDLEY'S CREW -HELD PRE-SPUD WITH HUNDLEYS CREW 23:30 - 00:00 0.50 RIGU P PRE DAILY RIG SERVICE -GREASE SKATE/TOP DRIVE 11/23/2015 00:00 - 03:30 3.50 RIGU P PRE BUILD 4"DP AND 4"HWDP STANDS -BUILD AND STAND BACK 4"DP AND 4"HWDP 03:30 - 06:00 2.50 RIGU P PRE RIG UP TO RUN GYRO PJSM WITH SPERRY,GYRO DATA,PARKER, BP -P/U GYRO TOOLS AND SLB TOOLS WITH TOOL CRANE -R/U SPERRY E-LINE UNIT -R/U GYRO DATA Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP • Page 3 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 1X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual©88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 09:00 3.00 RIGU P PRE MAKE UP 12-1/4"DRILLING MOTOR/UBHO BHA #1 AND WASH DOWN TO BOTTOM OF CONDUCTOR -FILL SURFACE EQUIPMENT WITH DRILLING FLUID -TEST ALL LINES AND CIRCULATING SYSTEM -WALK ALL LINES,NO LEAKS -ORIENT MOTOR AND UBHO SUB AS PER DD AND GYRODATA TAKE GYRO SURVEY IN CONDUCTOR 90' FROM RIG FLOOR JWASH DOWN AND TAG ICE PLUG AT 74' 09:00 - 12:00 3.00 DRILL P SURF DRILL 12-1/4"SURFACE HOLE WITH BHA #1 FROM 74'MD TO 325'MD -450 GPM, 510 PSI ON,510 PSI OFF -40 RPM, 1K TORQUE ON,1K TORQUE OFF P/U=50K,S/O=50K,ROT=50K AT 325'MD -MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT DRILL PLEX -GYRO SURVEY EVERY-90FT -ACTUAL ROTATE TIME:0.65 HRS -ACTUAL SLIDE TIME:0.10 HRS -MAKE UP ADDITIONAL 4"HWDP BHA COMPONENTS WHILE DRILLING AHEAD -WIPE HOLE 60-90 FT PRIOR TO CONNECTIONS,FULL PUMP RATE UP,PUMPS OFF DOWN,30-40'OF FILL ON BOTTOM -PEAGRAVEL GRAVEL AND SMALL QUANTITIES OF WOOD FROM 74'MD. 12:00 - 15:00 3.00 DRILL N SFAL 325.50 SURF AUGER OVERFLOWAT TOP OF CUTTINGS CHUTE -WORK PIPE FULL STAND LENGTH WHILE TROUBLESHOOTING AUGER/CHUTE ISSUES -40GAL DRILLING MUD SPILL.CONTACTED X5700,AND KEY PERSONNEL.TRACTION REPORT 2015-IR-5142061. P/U=50K S/O=50K 15:00 - 20:00 5.00 DRILL P SURF DRILL 12-1/4"SURFACE HOLE WITH MOTOR/UBHO BHA#1 FROM 325'MD TO 681' MD -550 GPM,970 PSI ON,910 PSI OFF 40 RPM, 3K TORQUE ON,1K TORQUE OFF -P/U=55K,S/O=52K,ROT=48K AT 681'MD -MUD WEIGHT:8.6 PPG IN,8.7 PPG OUT DRILL PLEX -GYRO SURVEY EVERY-90FT ACTUAL ROTATE TIME:0.5 HRS ACTUAL SLIDE TIME:0.67 HRS i-WIPE HOLE 60-90 FT PRIOR TO CONNECTIONS,FULL PUMP RATE UP,PUMPS OFF DOWN,30-40'OF FILL ON BOTTOM -PEA GRAVEL FROM 325'-450'MD -1/2"TO 1" GRAVEL FROM 450'MD,GRAVEL DIMINISHED AND CLAY INCREASED IN CUTTINGS TOWARDS END OF INTERVAL. Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP • Page 4 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud DaterTime:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual©88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 21:00 1.00 DRILL P SURF POH ON ELEVATORS WITH MOTOR/UBHO BHA#1 FROM 681'MD TO 50'MD -MUD WEIGHT:8.6 PPG IN,8.7 PPG OUT DRILL PLEX -PU=55K,SO=50KAT 680'MD -SEVERAL TIGHT SPOTS WITH 15-20K OVERPULL.WIPED TIGHT SPOTS AND [CONTINUED POH. MONITOR HOLE 10 MINUTES PRIOR TO PULLING OFF BOTTOM:STATIC -MONITOR HOLE FILL VIA TRIPTANK: PROPER DISPLACEMENT 21:00 - 22:00 1.00 DRILL P SURF LAY DOWN MOTOR/UBHO BHA#1 FROM 50' MD -PJSM WITH SLB DD/MW 1-CLEAN AND CLEAR RIG FLOOR BIT GRADE:1-1-WT-A-E-I-JD-TO 22:00 - 00:00 2.00 DRILL P SURF PICKUP MWD/LWD/MOTOR BHA#2 FROM SURFACE TO 200'MD -PICK UP A NEW HUGHES VM3 MILL TOOTH BIT -PU=60K,SO=60KAT 200'MD -MONITOR HOLE VIA TRIP TANK:PROPER 'DISPLACEMENT 11/24/2015 00:00 - 01:00 1.00 DRILL P SURF CONTINUE MAKING UP BHA#2(MWD,LWD, UBHO,1.5DEG MOTOR)AS PER SLB DD AND MWD FROM 200'TO 298'MD -PU=60K,SO=60K -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 01:00 - 01:30 0.50 DRILL P SURF RIH WITH 12-1/4"BHA#2 FROM 298'MD TO 681'MD -RIH ON ELEVATORS PICKING UP 4"HWDP STANDS FROM DERRICK -WASH DOWN WITH 168GPM,300PSI FROM 560'MD TO TAG ON FILL AT 620'MD 01:30 - 12:00 10.50 DRILL P SURF DRILL 12-1/4"SURFACE HOLE WITH BHA#2 FROM 681'MD TO 1785'(1773'TVD) 1-BASE OF PERMAFROST ESTIMATED TO BE 1,798'MD -550 GPM,1150 PSI ON,1400 PSI OFF -60 RPM, 4K TORQUE ON,3K TORQUE OFF -PU 89K,SO 83K,ROT 81K -GYRO SURVEY EVERY 90'TO SECOND CONSECUTIVELY CLEAN MWD SURVEY AT 834'MD. SWITCH SURVEYS TO MWD AFTER 834'MD •LEAVING GYRO RIGGED UP UNTIL SURVEY PROGRAM DEPTH OF 1,050'MD. -MUD WEIGHT 8.7 IN,8.8 OUT -BACKREAM 3OFT ON CONNECTION -ACTUAL ROTATE TIME=1.36 HRS -ACTUAL SLIDE TIME=0.59 HRS 12:00 - 13:30 1.50 DRILL P SURF CIRCULATE 3X BOTTOMS UP PRIOR TO SHORT TRIP.POH FROM 1,785'MD TO 1,505' MD. -550 GPM,40 RPM,1350 PSI -PU 88K,SO 83K -PULL AND LAY DOWN ONE STAND EVERY 20 MINUTES OF CIRCULATING -MONITOR HOLE FOR 10 MIN PRIOR TO PULLING OFF BOTTOM:STATIC Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP • Page 5 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 14:30 1.00 DRILL P SURF SHORT TRIP FROM BPRM:POH ON ELEVATORS TO TOP OF BHA#2 FROM 1,505' :MD TO 298'MD -MUD WEIGHT 8.8 PPG IN,8.9 PPG OUT 1-PU 85K,SO 82K AT 1,450'MD -MONITOR WELL FOR 10 MINUTES:STATIC -MONITOR HOLE VIA TRIP TANK:PROPER DISPLACEMENT 14:30 - 16:00 1.50 DRILL P SURF SHORT TRIP:RIH ON ELEVATORS WITH BHA #2 FROM 289'MD TO 1,700'MD -MONITOR WELL FOM 10 MINUTES:STATIC -MUD WEIGHT:8.8 PPG IN,8.9 PPG OUT -PU 60K,SO 60K AT 289'MD -WASHED DOWN LAST STAND AND TAGGED BOTTOM ON DEPTH:NO FILL -MONITOR HOLE VIA TRIP TANK:PROPER DISPLACEMENT - 16:00 - 23:30 7.50 DRILL P SURF DRILL 12.25"SURFACE HOLE FROM 1,785'MD TO 3,015'MD(3000'TVD) -650 GPM,2450 PSI ON,2360 PSI OFF -80 RPM,6K TORQUE ON,3K TORQUE OFF -PU 112K,SO 95K,ROT 102K -MWD SURVEY EVERY 90FT ACTUAL ROTATE TIME=4.12 HRS -ACTUAL SLIDE TIME=1.07 HRS 23:30 - 00:00 0.50 DRILL P SURF DAILY RIG SERVICE -LUBRICATE RIG.SERVICE TOP DRIVE BLOCKS,CROWN,AND RIG FLOOR EQUIPMENT. 11/25/2015 00:00 - 01:30 1.50 DRILL P SURF DRILL 12.25"SURFACE HOLE WITH 1.5DEG MOTOR BHA#2 FROM 3,015'MD TO 3,193'MD -650 GPM,2450 PSI ON,2360 PSI OFF -80 RPM,6K TORQUE ON,3K TORQUE OFF -PU 112K,SO 95K,ROT 102K -MWD SURVEY EVERY 90FT -ACTUAL ROTATE TIME=0.85 HRS -ACTUAL SLIDE TIME=0 HRS 01:30 - 03:00 1.50 DRILL P SURF CIRCULATE 3X BOTTOMS UP PRIOR TO SHORT TRIP.POH FROM 3,193'MD TO 2,921' MD. -650 GPM,2250 PSI -80 RPM,3K TORQUE -PULL AND LAY DOWN ONE STAND EVERY 20 MINUTES OF CIRCULATING -MONITOR HOLE FOR 10 MIN PRIOR TO PULLING OFF BOTTOM:STATIC -MONITOR HOLE VIA TRIP TANK:PROPER DISPLACEMENT 03:00 - 05:30 2.50 DRILL P SURF SHORT TRIP:POH ON ELEVATORS WITH BHA #2 FROM 2,921'MD TO 1,787'MD WIPED TIGHT SPOT:15-20K AT 2,080'MD -MUD WEIGHT 8.8 PPG IN,8.9 PPG OUT -MONITOR WELL FOR 10 MINUTES:STATIC -MONITOR HOLE VIA TRIP TANK:PROPER DISPLACEMENT Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP • Page 6 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 06:00 0.50 DRILL P SURF SHORT TRIP:RIH ON ELEVATORS WITH BHA #2 FROM 1,787'MD TO 3,193'MD -WIPED TIGHT SPOT:30K AT 2,100'MD -NO FILL ENCOUNTERED -MUD WEIGHT 8.8 PPG IN,8.9 PPG OUT -MONITOR WELL FOR 10 MINUTES:STATIC -MONITOR HOLE VIA TRIP TANK:PROPER DISPLACEMENT 06:00 - 08:00 2.00 DRILL P SURF CIRCULATE 3X BOTTOMS UP PRIOR TO PULLING OUT OF HOLE.POH FROM 3,193'MD TO 2,918'MD. -650 GPM,2250 PSI -PUMP NUT PLUG SWEEP -MUD WEIGHT 8.9 PPG IN,9.0 PPG OUT -PULL AND LAY DOWN ONE STAND EVERY 30 MINUTES OF CIRCULATING -MONITOR HOLE FOR 10 MIN PRIOR TO PULLING OFF BOTTOM:STATIC -MONITOR HOLE VIA TRIP TANK:PROPER DISPLACEMENT 08:00 - 10:30 2.50 DRILL P SURF POH ON ELEVATORS WITH BHA#2 FROM 2,918'MD TO 297'MD -MONITOR WELL FOR 10 MINUTES:STATIC -MUD WEIGHT 8.9 PPG IN,9.0 PPG OUT -PU WT 109K,SOW"93K @ 2,900' -STAND BACK 4"DP IN DERRICK -MONITOR HOLE VIA TRIP TANK:PROPER DISPLACEMENT 10:30 - 12:00 1.50 DRILL P SURF LAY DOWN 12-1/4"DRILLING BHA#2 FROM 297'MD TO SURFACE -PJSM WITH SLB DD/MWD AND RIG CREW -RACK BACK 5"HWDP,JAR STAND,AND FLEX COLLARS -L/D MWD,STABILIZERS,MUD MOTOR,AND BIT -ALL STABILIZERS IN GAUGE -BIT GRADE:3-1-Wr-A-E-1-RG-TD 12:00 - 13:00 1.00 DRILL P SURF CLEAN AND CLEAR RIG FLOOR -LAY DOWN BHA TOOLS WITH TOOL CRANE 13:00 - 15:30 2.50 CASING i P SURF RIG UP TO RUN 9-5/8"CASING WITH VOLANT TOOL -PJSM WITH DOYON AND RIG CREW -RIG UP 16'BALES WITH 8'EXTENSIONS -INSTALL 9-5/8"CASING ELEVATORS -RIG UP VOLANT TOOL 15:30 - 16:00 0.50 CASING P SURF DAILY RIG SERVICE LUBRICATE RIG.SERVICE RIG FLOOR EQUIPMENT. Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP • Page 7 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 00:00 8.00 CASING P SURF RUN IN HOLE WITH 9-5/8",40#,L-80, HYDRIL 563 SURFACE CASING FROM SURFACE TO 2,803'MD -USE VOLANT TOOL TO MAKE-UP AND FILL -BAKERLOK SHOE TRACK AND CHECK FLOATS:GOOD TEST -USE JETLUBE SEAL GUARD PIPE DOPE TORQUE CONNECTIONS TO 13,000 FT-LBS -RUN 1 CENTRALIZER LOCKED DOWN 5' FROM THE PIN ON JOINT 1 AND 1 CENTRALIZER LOCKED DOWN MID-JOINT ON JOINT 2 -RUN 1 FLOATING CENTRALIZER ON JOINTS 3-54 -RUN IN HOLE AT 45 FT/MIN -BREAK CIRCULATION EVERY 400 FT AT 3 BPM FOR 5 MINUTES —FILL CASING EVERY JOINT RECORD PU/SO WEIGHTS EVERY 10 JOINTS -PU 130K,SO 112K AT 2,803'MD MUD WEIGHT 8.9 PPG IN,9.0 PPG OUT 11/26/2015 00:00 - 01:30 1.50 CASING P SURF RUN IN HOLE WITH 9-5/8",40#,L-80,HYDRIL 563 SURFACE CASING FROM 2,803'MD TO 3,185'MD USE VOLANT TOOL TO MAKE-UP AND FILL -USE JETLUBE SEAL GUARD PIPE DOPE -TORQUE CONNECTIONS TO 13,000 FT-LBS -RUN IN HOLE AT 45 FT/MIN -BREAK CIRCULATION EVERY 400 FT AT 3 BPM FOR 5 MINUTES -FILL CASING EVERY JOINT -RECORD PU/SO WEIGHTS EVERY 10 JOINTS -PU 156K,SO 128KAT 3,185'MD -MUD WEIGHT 8.9 PPG IN,9.0 PPG OUT MAKE UP LANDING JOINT AND WASH TO BOTTOM LOSSES WHILE RUNNING CASING:30 BBLS 01:30 - 03:30 2.00 CASING P SURF STAGE UP PUMPS TO FULL DISPLACEMENT RATE IN 2 BPM INCREMENTS TO 10 BPM -2 BPM,150 PSI,8%RETURN FLOW -4 BPM,155 PSI,10%RETURN FLOW -6 BPM,155 PSI,14%RETURN FLOW -8 BPM,160 PSI,14%RETURN FLOW -10 BPM,170 PSI,16%RETURN FLOW -CONDITION MUD PER MUD ENGINEER -INITIAL PRESSURE AT FULL CEMENTING RATE:160 PSI -FINAL PRESSURE AT FULL CEMENTING RATE:155 PSI -CIRCULATE TOTAL OF 2 BOTTOMS UP -RECIPROCATE PIPE 15 FT AT SURFACE AT 1FT/MIN Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP Page 8 of 26 Operation Summary Report, Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 08:30 5.00 CASING P SURF CEMENT 9-5/8"SURFACE CASING AS FOLLOWS: -PJSM WITH RIG CREW AND SLB CEMENTERS -FILL LINES WITH WATER AND PRESSURE TEST TO 250 PSI LOW,4000 PSI HIGH FOR 5 MINUTES EACH PUMP 100 BBLS OF 10.0 PPG MUDPUSH II SPACER©5 BPM,257 PSI -INSTALL BOTTOM PLUG WITH TEFLON PLUG TOOL AND VOLANT TOOL PUMP 535 BBLS OF 11.0 PPG LITECRETE LEAD CEMENT(300%EXCESS IN PERMAFROST,40%EXCESS BELOW PERMAFROST)AT 5.5 BPM(LEAD WET AT 05:30) PUMP 50 BBLS OF 15.8 PPG CLASS G TAIL (40%EXCESS)AT 5 BPM(TAIL WET AT 07:22) -RECIPROCATE PIPE 15'AT SURFACE WHILE PUMPING.LAND ON RING EVERY 5 CYCLES. 1-INSTALL TOP PLUG WITH TEFLON PLUG !TOOL AND VOLANT TOOL KICK PLUG OUT AND WASH UP WITH 1OBBLS OF WATER USING SLB PUMPS -PERFORM DISPLACEMENT WITH RIG PUMPS AND 9.0 PPG DRILL PLEX MUD PER SLB CADE -RECIPROCATE PIPE IN 15FT STROKES AT 1FT/MIN DURING DISPLACEMENT,LAND HANGER ON LANDING RING EVERY 5 CYCLES AND WHEN MUD PUSH,LEAD CEMENT,AND TAIL CEMENT TURN THE CORNER. -DISPLACE 70 BBLS AT 10 BPM:ICP 360 PSI, FCP 505 PSI -DISPLACE 140 BBLS AT 7 BPM:ICP 285 PSI, FCP 670 PSI -REDUCE RATE TO 2 BPM PRIOR TO PLUG BUMP:FCP 570 PSI -BUMP PLUG AND INCREASE PRESSURE TO 1100 PSI -CHECK FLOATS:HOLDING -TOTAL RIG DISPLACEMENT VOLUME 225.4 BBLS/2,405 STROKES.97.3%PUMP EFFICIENCY -200 BBLS 11.0 PPG LITECRETE CEMENT RETURNED TO SURFACE -CEMENT IN PLACE AT 08:30 Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP • Page 9 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 17:00 8.50 CASING P SURF RIG DOWN FROM CEMENT JOB -BACK OUT AND LAY DOWN LANDING JOINT RIG DOWN SIDE DOOR ELEVATORS AND BAIL EXTENTIONS -BREAK OUT AND LAY DOWN VOLANT TOOL -CLEAN AND CLEAR RIG FLOOR -FLUSH ALL SURFACE LINES AND EQUIPMENT -JET STACK WITH CEMENT CONTAM PILL FUNCTION ANNULAR AND DRAIN STACK TO 4"VALVES ON CONDUCTOR PIPE -DRAIN AND CLEAN CELLAR BOX -DE-ENERGIZE ACCUMULATOR -REMOVE 16"DIVERTER PIPE FROM KNIFE VALVE -DRAIN AIR BOOTS AND REMOVE BELL NIPPLE,FILL LINE,AND TURNBUCKLES FROM ,ANNULAR -DISCONNECT HOSES FROM ANNULAR AND KNIFE VALVE 17:00 - 20:30 3.50 WHSUR P SURF NIPPLE UP FMC SLIM HOLE GEN 5 WELLHEAD -PJSM WITH FMC AND RIG CREW -N/U CASING SPOOL N/U TUBING SPOOL -PRESSURE TEST TO 250 PSI LOWAND 1000 PSI HIGH FOR 10 MINUTES EACH PER FMC REP 20:30 - 00:00 3.50 BOPSUR P SURF NIPPLE UP BOP -PJSM WITH RIG CREW -N/U DOUBLE STUDDED ADAPTOR N/U HIGH PRESSURE RISERS -N/U BOP STACK -INSTALL FLOW NIPPLE 11/27/2015 00:00 03:00 3.00 BOPSUR P SURF COMPLETE WELLHEAD NIPPLE UP AND RIG UP FOR BOP TEST INSTALL SECONDARY WELLHEAD VALVES I AND FLANGES. -INSTALL MOUSEHOLE -M/U TEST JOINT AND TEST PLUG -M/U 4"AND 4.5"FOSV ASSEMBLIES -INSTALL TEST JOINT AND TEST PLUG -FILL STACK AND CHECK FOR LEAKS Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP S Page 10 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (usft) 03:00 - 07:00 4.00 BOPSUR P SURF PRESSURE TEST BOP -TEST BOP ACCORDING TO AOGCC,BP REGULATIONS AND PARKER PROCEDURES PRESSURE TEST BOP UPPER VBR RAMS TO •250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES WITH 7"TEST JOINT -PRESSURE TEST BOP ANNULAR PREVENTOR WITH 4"TO 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH -PRESSURE TEST BOP LOWER VBR RAMS TO 250 PSI LOW,3500 PSI HIGH FOR 5 • MINUTES WITH 4"TEST JOINT -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS TEST WITNESS WAIVED BY AOGCC REP MATT HERRERA -BOP CONFIGURATION FROM TOP TO BOTTOM:ANNULAR PREVENTOR,7"CASING RAMS,BLIND SHEAR RAMS,HCR/KILL LINE, 2-7/8"X 5"VBRS 07:00 - 08:00 1.00 BOPSUR P SURF PJSM RIG DOWN TEST EQUIPMENT • -BLOW DOWN ALL LINES INSTALL 9 7/8"ID WEAR RING MAKE UP 4"SAFETY JOINT BREAK DOWN TEST JOINT 08:00 - 09:00 1.00 DRILL P SURF PJSM CHANGING OUT BAILS CHANGE OUT BAILS FROM CASING BAILS ITO DRILLING BAILS -OPEN HANDLER CLAMP AND INSPECT SAVER SUB(GOOD) 09:00 - 11:30 2.50 DRILL I P SURF PJSM,MAKE UP 8.75"PDX6 RSS BHA#3 AS PER SLB DD AND MWD -SURFACE TO 941'MD MONITOR WELL VIA TRIP TANK(CORRECT DISPLACEMENT) 11:30 - 13:30 2.00 • DRILL P SURF RIH WITH 8.75"RSS DRILLING ASSEMBLY F/ 941'MD TO 2,836'MD -RIH WITH 4"DP ON ELEVATORS PICKING UP SINGLES FROM PIPESHED -MONITOR WELL VIA TRIP TANK (CORRECT DISPLACEMENT) 13:30 - 14:00 0.50 DRILL P SURF RIH WITH 8.75"RSS DRILLING ASSEMBLY F/ 2,836'MD TO 3,175'MD -RIH WITH STANDS FROM DERRICK -MONITOR WELL VIA TRIP TANK (CORRECT DISPLACEMENT) -TAG CEMENT STRINGERS AT 3,010' -OBTAIN SPR'S 14:00 - 15:00 1.00 DRILL P SURF WASH DOWN AND DRILL OUT CEMENT TO 3,060' -PU=102K,SO=95K,ROT=95K -40-80 RPM W/4K TQ ON,2K TQ OFF -500 GPM W 1960 PSI 15:00 - 16:00 1.00 DRILL P SURF PRESSURE TEST 9 5/8"CASING. -CHART TEST ON CHART RECORDER -PASSING TEST.RECEIVED PERMISSION FROM WtL TO PROCEED. -250 PSI LOW FOR 5 MINUTES -3500 PSI HIGH FOR 30 MINUTES -3.2 BBLS TO ACHIEVE PRESSURE • -3.2 BBLS BLED BACK TO TRIP TANK Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP S Page 11 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual©88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 17:30 1.50 DRILL P SURF WASH DOWN AND DRILL OUT FLOAT EQUIPMENT -DRILL OUT FLOAT COLLAR AT 3,095'MD -DRILL OUT HARD CEMENT TO 3,175'MD I LEAVING 10'OF CEMENT IN SHOE TRACK. -PU=102K,SO=97K,ROT=99K -40-80 RPM,5K TQ ON,2K TQ OFF -500 GPM AT 1960 PSI CEMENT,RUBBER,AND ALUMINUM ACROSS SHAKERS 17:30 - 18:30 1.00 DRILL P SURF DISPLACE 9.0 PPG DRILPLEX MUD WITH 9.4 PPG LSND MUD -500 GPM AT 1415 PSI -ROT 80 RPM -RECIPROCATE 90' I-PUMP HIGH VIS SWEEP FOR SPACER FLUID I,-MONITOR WELL FOR 10 MINUTES(STATIC) 18:30 - 19:30 1.00 DRILL P SURF DRILL REMAINDER OF 9-5/8"SHOE TRACK AND 20'OF NEW FORMATION FROM 3,175'MD TO 3,213'MD. -500 GPM,1420 PSI '-80 RPM WITH 4K TORQUE ON,2K TORQUE OFF PU 102K,SO 95K,ROT 95K -CEMENT,RUBBER,AND ALUMINUM ACROSS _ SHAKERS 19:30 - 20:00 0.50 DRILL I P SURF PICK UP INSIDE 9-5/8"CASING SHOE AND CIRCULATE 1 BOTTOMS UP -500 GPM,1420 PSI -80 RPM,2K TORQUE 20:00 - 20:30 0.50 EVAL P SURF PERFORM LOT MUD WEIGHT:9.4 PPG,3,172'TVD,3,185'MD -PUMP 2.8 BBLS TO 970 PSI,BLEED BACK 2.7 BBLS -LOT EMW=15.28 PPG "OBTAIN APPROVAL FROM WTL TO PROCEED 20:30 - 23:30 3.00 DRILL P I INTI DRILL 8-3/4"INTERMEDIATE HOLE WITH PDX6 RSS BHA#3 FROM 3,212'MD TO 3,550'MD -600 GPM,1870 PSI ON,1820 PSI OFF -100 RPM,4K TORQUE ON,2K TORQUE OFF PU 107K,SO 97K,ROT 104K -ECD:ACTUAL=10.16 PPG,CALC=9.90 PPG -SURVEY EVERY 90 FT -WIPE 15 FT PRIOR TO CONNECTIONS -TOUR ACTUAL DRILLING HOURS:1.85 -TOUR ACTUAL JAR TIME=13.87 HRS 23:30 - 00:00 0.50 DRILL P INTI DAILY RIG SERVICE -LUBRICATE RIG.SERVICE TOP DRIVE WASHPIPE,BLOCKS,CROWN,AND RIG FLOOR EQUIPMENT. Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP S Page 12 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release: 12/13/2015 Rig Contractor:PARKER DRILLING CO. I UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/28/2015 00:00 - 12:00 12.00 DRILL P INTI DRILL 8-3/4"INTERMEDIATE HOLE WITH PDX6 RSS BHA#3 FROM 3,550'MD TO 5,195'MD -600 GPM, 2260 PSI ON,2245 PSI OFF -150 RPM,5K TORQUE ON,4K TORQUE OFF -PU 137 K,SO 123K,ROT 131K -ECD:ACTUAL=10.2 PPG,CALC= 9.92PPG -SURVEY EVERY 90 FT MUD WEIGHT:9.4 PPG IN,9.5 PPG OUT -ACTUAL TOUR ROTATE TIME:8.03 HRS PUMPED HIGH VIS SWEEP AT 4,632'MD WITH 20%INCREASE IN CUTTINGS -OBTAIN SPRS AT 4,155'MD AND 5,101'MD, BOTH WITH 9.5 PPG MUD WEIGHT. 12:00 - 21:00 9.00 DRILL P INTI DRILL 8-3/4"INTERMEDIATE HOLE WITH PDX6 RSS BHA#3 FROM 5,195'MD TO 6,237'MD -600 GPM,2880 PSI ON,2820 PSI OFF -190 RPM,6K TORQUE ON,3K TORQUE OFF -PU 147K,SO 135K,ROT 137K -ECD ACTUAL:11.05 PPG -ECD CALCULATED:10.70 PPG -SURVEY EVERY 90 FT -MUD WEIGHT:9.4 PPG IN,9.5 PPG OUT -PUMP WEIGHTED SWEEP AT 5,195'MD WITH r15%INCREASE IN CUTTINGS PUMP HIGH VIS SWEEP AT 6,200'MD WITH 15%INCREASE IN CUTTINGS -INCREASE MUD WEIGHT FROM 9.4 PPG TO 10.2 PPG OVER 3 CIRCULATIONS AT 5,600' MD,PRIOR TO THE TOP OF THE CM3(EST. 5,936'MD). 21 00 - 22:00 1.00 DRILL N SFAL 6,237.00 INTI REPLACE RUBBER ELEMENT IN MUD PUMP #1 PULSATION DAMPENER -BACKGROUND NOISE CAUSING A WEAK MWD SIGNAL INDICATING DAMPENER NEEDING CHANGING.REPLACE DAMPENER RESOLVING MWD SIGNAL ISSUES. -RACK BACK TWO STANDS AND RECIPROCATE PIPE 90FT WHILE PERFORMING MAINTENANCE. -PU 147K,SO 135K -MONITOR WELL FOR 10 MINUTES PRIOR TO PULLING OFF BOTTOM. -MONITOR HOLE FILL WITH TRIP TANK PROPER DISPLACEMENT 22:00 - 00:00 2.00 DRILL P INTI DRILL 8-3/4"INTERMEDIATE HOLE WITH PDX6 RSS BHA#3 FROM 6.237'MD TO 6,426'MD -600 GPM,2930 PSI ON,2905 PSI OFF -190 RPM,6K TORQUE ON,3K TORQUE OFF -PU 148K,SO 136K,ROT 139K -ECD ACTUAL:11.05 PPG -ECD CALCULATED:10.76 PPG -SURVEY EVERY 90 FT -MUD WEIGHT:10.2 PPG IN,10.3 PPG OUT -ACTUAL TOUR ROTATE TIME:7.72 HRS -TOTAL BIT TIME:17.62 HRS Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP • Page 13 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date: 12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT ' NPT Depth , Phase Description of Operations (hr) (usft) 11/29/2015 00:00 - 12:00 12.00 DRILL P INTI DRILL 8-3/4"INTERMEDIATE HOLE WITH PDX6 RSS BHA#3 FROM 6,426'MD TO 7,656'MD -550 GPM, 3098 PSI ON,3040 PSI OFF i-180 RPM,6K TORQUE ON,4K TORQUE OFF -PU 165K,SO 148K,ROT 152K -ECD:ACTUAL=11.37PPG,CALC= 10.80PPG -SURVEY EVERY 90 FT MUD WEIGHT:10.2 PPG IN,10.3 PPG OUT -ACTUAL TOUR ROTATE TIME:8.51 HRS -TOTAL BIT TIME:26.13 HRS -OBTAIN SPRS AT 6,898'MD(7,829'TVD),MW 10.2PPG 12:00 - 23:30 11.50 DRILL P INTI DRILL 8-3/4"INTERMEDIATE HOLE WITH PDX6 RSS BHA#3 FROM 7,656'MD TO 8,530'MD -550 GPM, 3350 PSI ON,3320 PSI OFF -180 RPM,6K TORQUE ON,4K TORQUE OFF -PU 181K,SO 152K,ROT 161K -ECD:ACTUAL=11.23PPG,CALC= 10.91 PPG -SURVEY EVERY 90 FT -MUD WEIGHT:10.3 PPG IN,10.4 PPG OUT -ACTUAL TOUR ROTATE TIME:8.25 HRS TOTAL BIT TIME:34.38 HRS -OBTAIN SPRS AT 7,940'MD(7,829'ND),MW 10.4PPG 23:30 - 00:00 0.50 DRILL P INTI DAILY RIG SERVICE -LUBRICATE RIG.SERVICE RIG FLOOR EQUIPMENT. 11/30/2015 00:00 - 02:00 2.00 DRILL P INTI DRILL 8-3/4"INTERMEDIATE HOLE WITH PDX6 RSS BHA#3 FROM 8,530'MD TO 8,659'MD -550 GPM, 3355 PSI ON,3320 PSI OFF -180 RPM,6.5K TORQUE ON,5K TORQUE OFF -PU 182K,SO 155K,ROT 164K -ECD:ACTUAL=11.11 PPG,CALC= 10.91 PPG -SURVEY EVERY 90 FT -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 02:00 - 03:30 1.50 DRILL P INTI DRILL FROM 8,659'MD TO TD AT 8,716'MD -CONTROL DRILL FROM 8,659'MD TO TSAG AT 8,711'MD. -DRILL 5'ADDITIONAL TO TD AT 8,716'MD -SPACE OUT TO CONTROL DRILL FULL STAND DOWN -6K WOB -550 GPM,3300 PSI ON -180 RPM,5.0 TORQUE ON -ECD:ACTUAL=11.1 PPG,CALC=10.91 -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -REVERSE DRILLING BREAK CONFIRMED -OBTAIN SPRS 8,715'MD(8,526'ND),MUD WEIGHT 10.4 03:30 - 06:00 2.50 DRILL P INTI CIRCULATE 3 BOTTOMS UP -SHAKERS CLEAN -ECD:ACTUAL=10.96PPG,CALC=10.89PPG -550 GPM,3225 PSI -120 RPM,5K TORQUE -RECIPROCATE SOFT -GLAUCONITE AND SAG RIVER SAND CONFIRMED IN 1ST BOTTOM UP SAMPLE Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP • Page 14 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 11:30 5.50 DRILL P INTI PUMP OUT OF HOLE AT 85 GPM TO TOP OF HRZ FROM 8,716'MD TO 7,140'MD -MONITOR WELL FOR 10 MINUTES:STATIC -PULLED SLOWLY DUE TO POTENTIAL PACKOFF PU 177K,SO 132KAT 7,182'MD -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT PULLED 30K OVER STRING WEIGHT AT 7,140'MD 11:30 - 12:00 0.50 DRILL P INTI WORKED TIGHT SPOT AT 7,140'MD -RIH AND STAGE PUMPS UP IN 84GPM INCREMENTS TO 550 GPM ALLOWING PRESSURES TO STABILIZE AT EACH FLOW RATE - 550 GPM,3080 PSI -PUMP THROUGH TIGHTSPOT 12:00 - 12:30 0.50 DRILL P INTI CIRCULATE AND CONDITION MUD -CBU STAGING PUMPS UP TO 550 GPM AT 3005 PSI -120 RPM,RECIPROCATE FULL STAND -MUD WEIGHT:10.4PPG IN,10.4PPG OUT 12:30 - 13:00 0.50 DRILL P j INTI ATTEMPT TO POH ON ELEVATORS FROM 7,140'MD TO 6,850'MD -MONITOR WELL FOR 10 MINUTES=(STATIC) -ENCOUNTERED TIGHT HOLE WITH 30K i OVERPULLAT 6,850'MD -ATTEMPT TO PULL THROUGH 3X WITHOUT SUCCESS PU=177K,S0=132KAT7,140'MD -MONITOR DISPLACEMENT VIA TRIP TANK: PROPER DISPLACEMENT 13:00 - 16:00 3.00 DRILL P INTI BACKREAM OUT OF HOLE FROM 6,850'MD I TO 5,780'MD BRINGING GHOST REAMER TO 9-5/8"SHOE -550 GPM W/2800 PSI -120 RPM W/4-5K TORQUE -PU=158K,SO=139K,ROT=143K AT 6,850' MD -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 16:00 - 16:30 0.50 DRILL P j INTI CIRCULATE AND CONDITION MUD -CBU 1.5X WITH GHOST REAMER INSIDE THE 9 5/8"SHOE -550 GPM W/2715 PSI -120 RPM W/3K TORQUE -MUD WEIGHT:10.4PPG IN,10.4PPG OUT 16:30 - 17:00 0.50 DRILL P INTI POH ON ELEVATORS FROM 5,780'MD 5,576' MD -MONITOR WELL FOR 10 MINUTES:STATIC -NO TIGHT SPOTS ENCOUNTERED -PU=150K,SO=130KAT 5,780'MD -MONITOR DISPLACEMENT VIA TRIP TANK: PROPER DISPLACEMENT 17:00 - 19:00 2.00 DRILL P INTI RIH ON ELEVATORS FROM 5,576'MD TO TD AT 8,716'MD -MONITOR WELL FOR 10 MINUTES:STATIC -90 FT/MIN -PU=185K,SO=155KAT 8,716'MD -FILL PIPE EVERY 20 STANDS -MONITOR DISPLACEMENT VIA TRIP TANK: PROPER DISPLACEMENT -NO INDICATIONS OF TIGHT HOLE -MUD WEIGHT:10.4PPG IN,10.4PPG OUT Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP 411 Page 15 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 'X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations (hr) (usft) _ 19:00 - 22:00 3.00 DRILL P INTI CIRCULATE AND CONDITION MUD -CBU 3X -550 GPM,2715 PSI -120 RPM,3K TORQUE -MUD WEIGHT:10.4PPG IN,10.4PPG OUT 22:00 - 00:00 2.00 DRILL P INTI PUMP OUT OF HOLE TO TOP OF HRZ FROM 8,716'MD TO 7,182'MD -MONITOR WELL FOR 10 MINUTES:STATIC -85 GPM,250 PSI 55 FT/MIN -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -PU 490K,SO 150KAT 8,716'MD -PU 165K,SO 140KAT 7182'MD 12/1/2015 00:00 - 01:30 1.50 DRILL P INTI POH ON ELEVATORS WITH 8-3/4"DRILLING BHA FROM 7,182'MD TO 5,295'MD -MONITOR WELL 10 MINUTES:STATIC -MUD WEIGHT:10.4PPG IN,10.4PPG OUT -PU 138K,SO 128KAT 5,484'MD -MONITOR DISPLACEMENT VIA TRIP TANK PROPER DISPLACEMENT -DRAG PLOT TRENDING RIGHT AT 5,295'MD 01:30 - 02:30 1.00 DRILL P INTI CIRCULATE BOTTOMS UP -342 GPM,886 PSI —MUD WEIGHT:10.4PPG IN,10.4PPG OUT -RECIPROCATE FULL STAND 02:30 - 04:00 1.50 DRILL P INTI PUMP OUT OF HOLE FROM 5,295'MD TO 4,600'MD -OBSERVED STEADY OVER PULL 15 TO 20K OVER PREVIOUS TRIP OUT -MONITOR WELL 10 MINUTES:STATIC -500GPM,2124PSI -PU 124,SO 121 AT 5,100'MD -MUD WEIGHT:10.4PPG IN,10.4PPG OUT 04:00 - 05:00 1.00 DRILL P INTI POH ON ELEVATORS FROM 4,600'MD T/3,185' MD -MONITOR WELL 10 MINUTES:STATIC -PU 120K,SO 117K AT 4,434'MD -MUD WEIGHT:10.4PPG IN,10.4PPG OUT -MONITOR DISPLACEMENT VIA TRIP TANK PROPER DISPLACEMENT 05:00 - 06:00 1.00 DRILL P INTI CIRCULATE BOTTOMS UP 2X -500 GPM AT 1720 PSI -120 RPM,2K TORQUE -LO-VIS SWEEP 30 BBLS -HI-VIS SWEEP 30 BBLS -OBSERVED SHALE AND COALS COMING ACROSS THE SHAKERS 06:00 - 10:00 4.00 DRILL P INTI RIH WITH 8 3/4"DRILLING BHA F/3,120 MD T/ 8,716'MD -PU WT-98K,SO WT=96K AT 3,120'MD RIH WITH 4"DRILL PIPE FROM DERRICK -BREAK CIRCULATION EVERY 20 STANDS -WASH DOWN LAST STAND TO BOTTOM -PU WT=190K,SO WT=148KAT 8,717'MD 10:00 - 12:00 2.00 DRILL P INTI STAGE UP PUMPS TO 550 GPM -CIRCULATE BOTTOMS UP 2X -550 GPM AT 3355 PSI RECIPROCATE PIPE 75' Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP Page 16 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 'X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 12:30 0.50 DRILL P INTI POH ON ELEVATORS F/8,716'MD TO 8,626' MD NO PUMPS -RIH F/8,626'MD TO 8,716'MD NO PUMPS TO VERIFY NO FILL ON BOTTOM -WORK STAND 2 TIMES TO BOTTOM WITH NO FILL -MONITOR WELL FOR 10 MINUTES(STATIC) 12:30 - 14:30 2.00 DRILL P INTI "PUMP OUT OF HOLE AT 55 FPM F/8,716'MDT/ 7,185'MD -85 GPM AT 235 PSI AT 8,500'MD -MUD WT=10.4 PPG IN,10.4 PPG OUT -PU WT=190K,SO WT=150K AT 8,700'MD 14:30 - 18:30 4.00 DRILL P INTI POH ON ELEVATORS AT 60 FPM F/7,185'MD T/3,085'MD PU WT=160K,SO WT=142KAT 7,185'MD -MONITOR DISPLACEMENT VIA TRIP TANK -WIPE ALL TIGHT SPOTS OF 15K OR MORE OVERPULL 18:30 - 19:30 1.00 DRILL P INTI CIRCULATE AND CONDITION MUD WHILE CBU 2X AT 3,085'MD -550 GPM AT 2050 PSI RPM=80,TQ=2K -MONITOR WELL FOR 10 MINUTES AT THE 9 5/8"SHOE(STATIC) 19:30 - 21:30 2.00 DRILL P INTI POH IN CASED HOLE AT 150 FPM F/3,185 MD T/1,000'MD -PU WT=68K,SO WT=60K AT 1,000'MD -MONITOR WELL PRIOR TO PULLING NON SHEARABLES INTO STACK(STATIC) 21:30 - 23:30 2.00 DRILL P INTI PJSM STAND BACK AND LAY DOWN BHA COMPONENTS AS PER SLB DD/MWD -LAY DOWN 4"HWDP NOT NEEDED FOR NEXT BHA -LAY DOWN BHA#3 -CLEAR AND CLEAN FLOOR OF BHA COMPONENTS _ 23:30 - 00:00 0.50 DRILL P INTI SERVICE RIG FLOOR EQUIPMENT 12/2/2015 00:00 - 01:30 1.50 DRILL P INTI PULL WEAR RING -PU RIG UP 7"CASING EQUIPMENT -INSTALL VOLANT CEMENT HEAD AND CRT TOOLS 01:30 - 07:30 6.00 CASING P INTI PJSM RUNNING 7",26#,L-80,VAMTOP CASING F/SURFACE T/3,175' -PICK UP FLOAT EQUIPMENT -CHECK FLOATS(GOOD) -USE JET LUBE SEAL GUARD PIPE DOPE -TORQUE CONNECTIONS TO 11,950 FT-LBS -RUN 37 FLOATING CENTRALIZERS ON JOINTS 1-37 -RUN IN HOLE AT 100 FT/MIN FROM SURFACE'MD TO 3,175"FT MD, -BREAK CIRCULATION EVERY-10 JT AT 3 BPM FOR-3 MINUTES -OBTAIN PU/SO WEIGHTS EVERY-10 STANDS -PU 99K,SO 98K -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -MUD LOSSES WHILE RIH:10.0 BBLS 07:30 - 08:30 1.00 CASING P INTI CBU X2 AT 3,175'MD -STAGE PUMPS UP TO 5 BPM AT 376 PSI -MUD LOSSES WHILE CBU=6 BBLS Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP Page 17 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 12:00 3.50 CASING P INTI RUN 7",26#,L-80, VAMTOP CASING F/3,175' TO 5,000'MD -USE JET LUBE SEAL GUARD PIPE DOPE -TORQUE CONNECTIONS TO 11,950 FT-LBS RUN IN HOLE AT 80 FT/MIN FROM 3,175'MD TO 4,300'FT MD, -REDUCED SPEED TO 60 FT/MIN FROM 4,300'MD TO 5,000'MD BREAK CIRCULATION EVERY-10 JT AT 3 BPM FOR-5 MINUTES OBTAIN PU/SO WEIGHTS EVERY=10 STANDS -PU 138K,SO 135K,AT 5,000'MD MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT MUD LOSSES WHILE RIH:66 BBLS 12:00 - 18:00 6.00 CASING P INTI RUN 7",26#,L-80, VAMTOP CASING F/5,000' TO 8,700'MD -USE JET LUBE SEAL GUARD PIPE DOPE -TORQUE CONNECTIONS TO 11,950 FT-LBS RUN IN HOLE AT 60 FT/MIN FROM 5,000'MD TO 7,215'FT MD, REDUCED SPEED TO 40 FPM F/7,215'MD TO 8,713'MD BREAK CIRCULATION EVERY-10 JT AT 3 BPM FOR-5 MINUTES -OBTAIN PU/SO WEIGHTS EVERY-10 STANDS -PU 138K,SO 135K,AT 5,000'MD -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT —MUD LOSSES WHILE RIH:65 BBLS 18:00 - 19:00 1.00 CASING P INTI MAKE UP LANDING JT AND HANGER AS PER FMC AND DOYON CASING REPS FILL PIPE AND WASH DOWN TO 8,700'MD -TAG UP 15'EARLY WITH 5 K DOWN -STAGE PUPMS UP TO 2 BPM -WASH TO BOTTOM 7'OF FILL ON BOTTOM -RIH TO BOTTOM SETTING HANGER ON SEAT. -PU WT 235K,SO WT 195K 19:00 - 00:00 5.00 CASING P INTI STAGE UP TO CEMENTING RATE IN 0.5 BPM INCREMENTS TO FINAL CIRCULATING RATE OF 1.5 BPM. -@.5 BPM,285 PSI,10%RETURN FLOW, MANUAL STRAP SHOWED LOSSES AT 90% -@ 1 BPM.308 PSI,15%RETURN FLOW, MANUAL STRAP SHOWED LOSSES AT 85% -@ 1.5 BPM 330 PSI,15%RETURN FLOW, MANUAL STRAP SHOWED LOSSES AT 85% MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT MUD LOSSES WHILE CIRCULATING ON BOTTOM 375 BBLS Printed 1/11/2016 8:53:54AM North America-ALASKA-BP • Page 18 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date: 12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/3/2015 00:00 - 05:00 5.00 CEMT P INTI STAGE UP TO CEMENTING RATE IN.5 BPM INCREMENTS TO FINAL CIRCULATING RATE OF 5 BPM. -@ 1 BPM, 317 PSI,1%RETURN FLOW -©1.5 BPM,388 PSI,62%RETURN FLOW, WITH 38%LOSSRATE -@ 2 BPM,424 PSI,50%RETURN FLOW, WITH 50%LOSS RATE -@ 2.5 BPM,456 PSI,50%RETURN FLOW, WITH 50%LOSS RATE -@ 3 BPM,499 PSI,50%RETURN FLOW, WITH 50%LOSS RATE -@ 4 BPM,507 PSI,75%RETURN FLOW, WITH A 25%LOSS RATE -@ 5 BPM,620 PSI,75%RETURN FLOW, WITH A 25%LOSS RATE 05:00 - 06:00 1.00 CEMT P INTI SECURE WELL AND EVACUATE RIG -H2S ALARM SOUNDED, SHUT PUMP DOWN, SHUT IN WELL EVACUATE RIG 06:00 - 07:00 1.00 CEMT P INTI MADE ALL NOTIFICATIONS IN RESPONSE TO H2S ALARM '-RECEIVED PERMISSION TO ENTER THE RIG WITH SCBA'S AND HAND HELD GAS SENSOR -RIG MANAGER AND DRILLER ENTERED AND SWEPT THE RIG -NO INDICATIONS OF H2S WITH HAND HELD SENSORS ALL CLEAR ON THE RIG SWEEP -FAULTY H2S SENSOR HAD GIVEN THE ALARM,SENSOR CHANGED OUT OPERATIONS RESUMED 07:00 - 07:30 0.50 CEMT N DPRB 8,713.00 INTI OBSERVED 172 PSI ON THE CASING PRESSURE GAUGE -MADE NOTIFICATIONS WHILE RECORDING PRESSURES -RECEIVED PERMISSION TO PERFORM AN EXHALE TEST -FILL GAS BUSTER WITH MUD Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP • Page f9 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:OOAM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 17:00 9.50 CEMT N DPRB 8,713.00 INTI PERFORM EXHALE TEST ON THE WELL -@ 07:30 172 PSI ON CHOKE,OPEN CHOKE FOR 5 SECONDS,NO GAIN IN PITS,CHOKE PRESSURE 166 PSI -@ 07:40 170 PSI ON CHOKE,OPEN CHOKE FOR 15 SECONDS,0.25 BBL GAIN IN PITS, CHOKE PRESSURE 154 PSI,TOTAL BLED=.25 BBLS @ 07:55 169 PSI ON CHOKE,OPEN CHOKE FOR 50 SECONDS, 0.40 BBL GAIN IN PITS, CHOKE PRESSURE 126 PSI,TOTAL BLED=.65 BBLS @ 08:10 166 PSI ON CHOKE,OPEN CHOKE 'FOR 58 SECONDS,1.00 BBL GAIN IN PITS, CHOKE PRESSURE 120 PSI,TOTAL BLED= 1.65 BBLS @ 08:25 164 PSI ON CHOKE,OPEN CHOKE 'FOR 48 SECONDS,1.10 BBL GAIN IN PITS, CHOKE PRESSURE 120 PSI,TOTAL BLED=2.7 BBLS @ 09:05 164 PSI ON CHOKE,OPEN CHOKE FOR 52 SECONDS,0.30 BBL GAIN IN PITS, CHOKE PRESSURE 140 PSI,TOTAL BLED=3.0 BBLS -@ 09:25 163 PSI ON CHOKE,OPEN CHOKE FOR 51 SECONDS,0.50 BBL GAIN IN PITS, CHOKE PRESSURE 100 PSI,TOTAL BLED=3.5 BBLS -@ 10:10 162 PSI ON CHOKE,OPEN CHOKE FOR 72 SECONDS,1.10 BBL GAIN IN PITS, CHOKE PRESSURE 108 PSI,TOTAL BLED=4.6 BBLS -@ 10:20 159 PSI ON CHOKE,OPEN CHOKE FOR 83 SECONDS,1.10 BBL GAIN IN PITS, CHOKE PRESSURE 106 PSI,TOTAL BLED=5.7 BBLS -@ 10:35 157 PSI ON CHOKE,OPEN CHOKE FOR 94 SECONDS,2.40 BBL GAIN IN PITS, CHOKE PRESSURE 106 PSI,TOTAL BLED=8.1 BBLS -@ 11:10 158 PSI ON CHOKE,OPEN CHOKE FOR 127 SECONDS,1.34 BBL GAIN IN PITS, CHOKE PRESSURE 110 PSI,TOTAL BLED=9.4 BBLS -@ 11:30 155 PSI ON CHOKE,OPEN CHOKE FOR 169 SECONDS,1.90 BBL GAIN IN PITS, CHOKE PRESSURE 95 PSI,TOTAL BLED=11.3 BBLS -@ 11:52 152 PSI ON CHOKE,OPEN CHOKE FOR 353 SECONDS,5.0 BBL GAIN IN PITS, CHOKE PRESSURE 92 PSI,TOTAL BLED=16.3 BBLS -@ 12:52 148 PSI ON CHOKE,OPEN CHOKE FOR 15 MINUTES,9.0 BBL GAIN IN PITS, CHOKE PRESSURE 66 PSI,TOTAL BLED=25.3 BBLS RECIEVED PERMISSION FROM WOM TO OPEN ANNULAR -OPEN WELL,MONITOR WELL, RECORD RETURN RATE EVERY 10 MINUTES, -14:05 GAIN IN PITS 2.81 BBLS,TOTAL GAIN 28.1 Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP Page 20 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) -14:15 GAIN IN PITS 4.70 BBLS,TOTAL GAIN 32.8 -14:25 GAIN IN PITS 5.10 BBLS,TOTAL GAIN 37.9 -14:35 GAIN IN PITS 3.50 BBLS,TOTAL GAIN 41.4 -14:45 GAIN IN PITS 4.10 BBLS,TOTAL GAIN 145.5 14:55 GAIN IN PITS 2.10 BBLS,TOTAL GAIN 47.6 -15:05 GAIN IN PITS 4.50 BBLS,TOTAL GAIN 52.1 -15:15 GAIN IN PITS 2.60 BBLS,TOTAL GAIN 54.7 -15:25 GAIN IN PITS 2.90 BBLS,TOTAL GAIN 57.6 15:35 GAIN IN PITS 3.10 BBLS,TOTAL GAIN '60.7 16:00 GAIN IN PITS 3.60 BBLS,TOTAL GAIN 64.3 FLUSH MGS WITH FRESH WATER, -BLOW DOWN ALL WELL CONTROL EQUIPMENT I-LINE UP FOR NORMAL OPERATIONS 17:00 - 20:00 3.00 CEMT P INTI 'CIRCULATE AND CONDITION MUD -STAGE UP PUMPS IN.5 BBL INCREMENTS F/ 1 BBL -1.0 BPM AT 275 PSI,0%RETURNS,100% LOSS RATE -1.5 BPM AT 315 PSI,58%RETURNS,42% LOSS RATE -2.0 BPM AT 365 PSI,65%RETURNS,35% LOSS RATE -2.5 BPM AT 420 PSI,76%RETURNS,24% LOSS RATE -3.0 BPM AT 420 PSI,88%RETURNS,12% LOSS RATE -4.0 BPM AT 560 PSI,98%RETURNS,2% LOSS RATE -5.0 BPM AT 625 PSI,100%RETURNS,0% LOSS RATE 20:00 - 20:30 0.50 CEMT P INTI LUBRICATE RIG,SERVICE RIG FLOOR EQUIPMENT 20:30 - 22:30 2.00 CEMT P INTI PUMP LCM PILL -PUMP 40 BBLS OF 35#PER BBL LCM PILL AT 5 BPM -DISPLACE LCM PILL OUTSIDE OF SHOE -SHUT PUMP DOWN LET PILL SOAK WHILE PREPARING TO CEMENT. 22:30 - 00:00 1.50 CEMT P INTI CEMENT 7"INTERMEDIATE CASING -PUMP 30 BBLS OF 12 PPG MUD PUSH,ICP= 550 PSI,FCP=530 PSI, 92%RETURNS -DROP BOTTOM PLUG -PUMP 56.3 BBLS 15.8 GASBLOK SLURRY, ICP=800 PSI,FCP=580 PSI,90%RETURNS -DROP TOP PLUG -PUMP 10 BBLS H2O -DISPLACE WITH RIG PUMP Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP • Page 21 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/4/2015 00:00 - 03:00 3.00 CEMT P INTI CEMENT 7"INTERMEDIATE CASING AS FOLLOWS: RECIPROCATED PIPE 3 FT AT SURFACE WHILE PUMPING CEMENT AT 5 BPM PERFORM DISPLACEMENT WITH RIG PUMPS WAND 10.3 PPG LSND MUD PER SLB CADE - 275 BBLS DISPLACED AT 5 BPM:ICP 235 PSI 100%RETURN FLOW,FCP 265 PSI 100% RETURN FLOW REDUCE RATE TO 3 BPM PRIOR TO PLUG BUMP:FINAL CIRCULATING PRESSURE 967 PSI,100%RETURN FLOW -BUMP PLUG AND INCREASE PRESSURE TO 1400 PSI,CHECK FLOATS-GOOD -TOTAL DISPLACEMENT VOLUME 321 BBLS (MEASURED BY STROKES @ 97%PUMP EFFICIENCY) -RECIPROCATE PIPE 3 FT AT SURFACE DURING DISPLACEMENT, -TOTAL LOSSES FROM CEMENT EXIT SHOE 'TO CEMENT IN PLACE:0 BBLS -TOTAL LOSSES BEFORE CEMENT EXIT SHOE TO CEMENT EXITING SHOE:15 BBLS CEMENT IN PLACE AT 00:4712/04/2015 03:00 - 04:00 1.00 CASING P I INTI PRESSURE TEST 7"CASING PRESSURE TEST 7"CASING 250 PSI LOW FOR 5 MINUTES,3500 PSI HIGH FOR 30 MINUTES -GOOD TEST -CONTACT WTL RECEIVED PERMISSION TO ,PROCEED 04:00 - 09:00 5.00 WHSUR P INTI RIG DOWN CASING EQUIPMENT AND SET PACK OFF -RIG DOWN VOLANT TOOL -LAY DOWN LANDING JOINT -SET 7"PACK OFF W/FMC REP RILDS AND TEST TO 5000 PSI FOR 15 MIN, GOOD TEST *MONITOR BREATHING VIA OA VALVE,39 BBLS BLED BACK FROM TIME CEMENT IN PLACE TO WHEN PACK OFF TESTED 09:00 - 11:00 2.00 WHSUR P INTI FREEZE PROTECT OA -INJECT 28 BBLS,14 PPG MUD,2 BPM,300 PSI -LITTLE RED INJECT 62 BBLS,7.4 PPG DEAD CRUDE,2 BPM,930 PSI,DECREAE RATE TO 1.0 BPM,350 PSI C/O UPPER RAMS TO 2-7/8"X 5-1/2"VBR'S 11:00 - 13:00 2.00 BOPSUB I IINTI TEST BOPE i P -TEST UPPER VBR W/4",4-1/2"TEST JOINT, 250 PSI/3500 PSI,FOR 5 MIN/5 MIN,TEST GOOD -TEST LOWER VBR W/4-1/2"TEST JOINT,250 PSI/3500 PSI,FOR 5 MIN/5 MIN,TEST GOOD -BLOW DOWN TEST EQUIPMENT -LINE UP WELL CONTROL EQUIPMENT -INSTALL 6 7/8"WEAR RING Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP S Page 22 of 26 Operation Summary Report Common Well Name:0-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 15:30 2.50 DRILL P INTI PJSM WITH SLB DD AND MWD -P/U M/U 6 1/8"ARCHER BHA#4 AS PER SLB REP'S -PU WT 45K,SO WT 45K,BHA WT=10K 15:30 - 21:00 5.50 DRILL P INTI RIH WITH 6 1/8"ARCHER DRILLING BHA FROM 180'MD TO 8019'MD -PU WT 150K,SO WT 135K -SHALLOW TEST MWD AT 1500'MD -RIH ON ELEVATORS WITH 4"DP STANDS FROM DERRICK -FILL PIPE AND CIRCULATE EVERY 15 STANDS FOR 8 MIN AS PER SLB -BREAK CIRCULATION EVERY 15 STANDS, 220 GPM,1800 PSI FOR 8 MIN AS PER SLB MONITOR HOLE FILL VIA TRIP TANK 21:00 - 22:00 1.00 DRILL P INTI CUTAND SLIP DRILLING LINE -CUT 75'/9 WRAPS OF LINE -CALIBRATE AMPHION AND SLB DEPTH TRACKERS -CHECK C-O-M 22:00 - 22:30 0.50 DRILL P INTI SERVICE RIG GREASE WASH PIPE PACKING,BLOCKS, CROWN AND RIG FLOOR EQUIPMENT INSPECT SAVER SUB,GOOD '22:30 - 00:00 1.50 DRILL P INTI RIH AND WASH DOWN F/8,019'MDT/8,575' MD -OBTAIN SPR -TAG TOC AT 8,575'MD CEMENT STRINGER -DRILL OUT FLOATS AND LANDING COLLAR AT F/8622'MD T/8,624 MD -230 GPM AT 1900 PSI -60-80 RPM WITH 5K TORQUE -PU WT 160K,SO WT 140K,ROT WT 150K 12/5/2015 00:00 - 01:30 1.50 DRILL P INTI DRILL OUT FLOAT EQUIPMENT AND CEMENT F/8,624'MD T/8,700'MD -249 GPM,2200 PSI ON,2125 PSI OFF -80 RPM,4K TORQUE ON,3K TORQUE OFF -PU WT 166K,SO WT 120K,ROT WT 150K 01:30 - 03:00 1.50 DRILL P INTI DISPLACE WELL FROM 10.4 LSND TO 8.5 PPG FLOPRO -249 GPM,1570 PSI *OBTAIN SPR'S WITH FLOPRO 03:00 - 04:00 1.00 DRILL 7 P INTI DRILL REMAINING SHOE TRACK AND 6-1/8" PRODUCTION HOLE F/8716'" T/8737' -270 GPM, 1825 PSI ON,1790 PSI OFF -80 RPM,3K TORQUE ON,1K TORQUE OFF -PU 167K,SO 142K,ROT 155K 04:00 - 05:00 1.00 DRILL P INTI CIRCULATE AND CONDITION MUD -P/U INTO THE SHOE AT 8713' -CBU 1X,268 GPM,1768 PSI 05:00 - 05:30 0.50 DRILL P INTI RIG UP AND PERFORM FIT -MUD WEIGHT:8.4 PPG,8524'TVD,8713'MD -PUMP 0.65 BBLS TO 480 PSI,BLEED BACK 0.65 BBLS -FIT EMW=9.48 PPG Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP S Page 23 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 12:00 6.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 8737' MD TO 8,790'MD(8,593'TVD) -260 GPM, 1715 PSI ON 1550 PSI OFF -80 RPM,3K TORQUE ON,1K TORQUE OFF -PU 165K,SO 155K,ROT 158K -SURVEY EVERY-30-90 FT -ACTUAL ROTATE TIME=5.75 HRS TOTAL BIT TIME=5.75 HRS -TOTAL JAR TIME=5.75 HRS BACK REAM 10 FT PRIOR TO CONNECTIONS -MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT 12:00 - 23:30 11.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 8790' MD TO 9,150'MD(8,860'TVD) -260 GPM, 1760 PSI ON 1715 PSI OFF 80 RPM,4K TORQUE ON,3K TORQUE OFF -PU 165K,SO 155K,ROT 159K -SURVEY EVERY-30 FT -ACTUAL ROTATE TIME=9.66 HRS -TOTAL BIT TIME=15.41 HRS -TOTAL JAR TIME=15.41 HRS -BACK REAM 15 FT PRIOR TO CONNECTIONS MUD WEIGHT:8.5 PPG IN,8.5 PPG -PUMPED NUT PLUG SWEEP AT 8,800'MD TO -HELP WITH BIT AND LOW ROP ISSUES(NO CHANGES OBSERVED FROM SWEEP) -OBTAIN SPR'S AT 9,150'MD,8,860'TVD,8.5 PPG MW 23:30 - 00:00 0.50 DRILL P PROD1 SERVICE RIG,GREASE BLOCKS, CROWN,WASH PIPE PACKING,RIG FLOOR EQUIPMENT 12/6/2015 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 9,150' MD TO 9,690'MD(9,069 TVD) -264 GPM, 1862 PSI ON 1847 PSI OFF -80 RPM,4K TORQUE ON,3K TORQUE OFF -PU 170K,SO 156K,ROT 161K -SURVEY EVERY-30 FT -ACTUAL ROTATE TIME=9.47 HRS -TOTAL BIT TIME=25.15 HRS -TOTAL JAR TIME=25.15 HRS HRS -BACK REAM 10 FT PRIOR TO CONNECTIONS -MUD WEIGHT:8.5 PPG IN,8.5 PPG 12:00 - 23:30 11.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 9,690' MD TO 10,570'MD(9,069 TVD) -264 GPM, 1862 PSI ON 1847 PSI OFF -80 RPM,4K TORQUE ON,3K TORQUE OFF -PU 172K,SO 152K,ROT 157K -SURVEY EVERY-30 FT -ACTUAL ROTATE TIME=9.19 HRS -TOTAL BIT TIME=34.34 HRS -TOTAL JAR TIME=34.34 HRS HRS -BACK REAM 10 FT PRIOR TO CONNECTIONS -MUD WEIGHT:8.5 PPG IN,8.5 PPG OBTAIN SPR'S AT 9,813'MD,9,055'ND,8.5 MW 23:30 - 00:00 0.50 DRILL P PROD1 SERVICE RIG FLOOR EQUIPMENT Printed 1/11/2016 8:53:54AM 411 North America-ALASKA-BP I Page 24 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8.951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual©88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/7/2015 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 10,570'MD TO 11,324'MD(9,022 tvd) -264 GPM, 2070 PSI ON 2050 PSI OFF -130 RPM,7K TORQUE ON,4K TORQUE OFF -PU 173K,SO 146K,ROT 159K -SURVEY EVERY-30-90 FT '-ACTUAL ROTATE TIME=7.65 HRS TOTAL BIT TIME=41.99 HRS -TOTAL JAR TIME=41.99 HRS HRS -BACK REAM 15 FT PRIOR TO CONNECTIONS -MUD WEIGHT:8.5 PPG IN,8.5 PPG OBTAIN SPR'S AT 11,039'MD,9,031'TVD,MW 8.5 PPG 12:00 - 00:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 11,324'MD TO 11,830'MD(9,010 TVD) -264 GPM, 2115 PSI ON--2080 PSI OFF -100 RPM,7K TORQUE ON,4K TORQUE OFF PU 176K,SO 142K,ROT 158K -SURVEY EVERY-30 FT -ACTUAL ROTATE TIME=9.19 HRS -TOTAL BIT TIME=51.18 HRS -TOTAL JAR TIME=51.18 HRS HRS -BACK REAM 15 FT PRIOR TO CONNECTIONS MUD WEIGHT:8.5 PPG IN,8.5 PPG OBTAIN SPR'S AT 11,795'MD, 9,010'TVD, MW 8.5 PPG 12/8/2015 00:00 - 12:00 12.00 bRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 11,830'MD TO 12,333'MD(8972'TVD) -264 GPM, 2172 PSI ON 2110 PSI OFF -80-130 RPM,7K TORQUE ON,4K TORQUE OFF -PU 180K,SO 145K,ROT 155K -SURVEY EVERY-30-90 FT -ACTUAL ROTATE TIME=10.22 HRS -TOTAL BIT TIME=64.4 HRS -TOTAL JAR TIME=64.4 HRS -BACK REAM 10 FT PRIOR TO CONNECTIONS -MUD WEIGHT:8.6 PPG IN,8.6 PPG -OBTAIN SLOW PUMP RATES AT 12,074'MD (9011'TVD) 12:00 - 19:00 7.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 12,333'MD TO 12,600'MD(8880'TVD) -CALL PRODUCTION HOLE TD AT 12,600'MD (8880'TVD) -265 GPM, 2250 PSI ON, 2200 PSI OFF -100 RPM,7K TORQUE ON,4K TORQUE OFF -PU 180K,SO 145K,ROT 153K -SURVEY EVERY-30-90 FT -ACTUAL ROTATE TIME=5.95 HRS -TOTAL BIT TIME=67.35 HRS 1-TOTAL JAR TIME=67.35 HRS -BACK REAM 10 FT PRIOR TO CONNECTIONS -MUD WEIGHT:8.6 PPG IN,8.6 PPG -8 BPH DYNAMIC LOSS RATE WHILE CIRCULATING -OBTAIN SLOW PUMP RATES AT 12,600'MD (8880'TVD) Printed 1/11/2016 8:53:54AM North America-ALASKA-BP Page 25 of 26 Operation Summary Report Common Well Name:D-35 AFE Na Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date: 12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM I Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual©88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 21:30 2.50 DRILL P PROD1 CIRCULATE AND CONDITION MUD ON BOTTOM FOR SHORT TRIP CIRCULATE 3X BOTTOMS UP 1-265 GPM, 2230 PSI -120 RPM,5K TORQUE -RECIPROCATE 55'MD -8 BPH DYNAMIC LOSS RATE WHILE CIRCULATING MONITOR WELL FOR 10 MINUTES-2 BPH LOSS RATE *OBSERVED 200 PSI PRESSURE DROP AND LOST COMMUNICATION WITH MWD TOOL- DISCUSSED WITH ODE AND DECISION MADE TO PROCEED WITH PLANNED WIPER TRIP. 21:30 - 22:00 0.50 DRILL P PROD1 LUBRICATE AND SERVICE RIG FLOOR EQUIPMENT 22:00 - 00:00 2.00 DRILL P PROD1 POOH WITH 6-1/8"PRODUCTION BHA FOR SHORT TRIP FROM 12,600'MD TO 9626'MD POOH ON ELEVATORS AT 60'-100'/MIN PU 170K,SO 145K -MONITOR WELL ON TRIP TANK-2 BPH LOSS RATE -WIPE TIGHT SPOTS BETWEEN 11,400'MD TO 11,200'MD 12/9/2015 00:00 - 00:30 0.50 DRILL P PROD1 POOH WITH 6-1/8"PRODUCTION BHA FOR SHORT TRIP FROM 9,626'MD TO 8,680'MD -POOH ON ELEVATORS AT 100'/MIN -PU 170K,SO 145K -MONITOR WELL ON TRIP TANK-2 BPH LOSS RATE -MUD WEIGHT:8.6 PPG IN,8.6 PPG 00:30 - 01:30 1.00 DRILL P PROD1 CIRCULATE AND CONDITION MUD AT SHOE -MONITOR WELL FOR 10 MINUTES-2 BPH LOSS RATE -CIRCULATE 1X BOTTOMS UP -253 GPM, 1630 PSI -MUD WEIGHT:8.6 PPG IN,8.6 PPG -2 BPH DYNAMIC LOSS RATE WHILE CIRCULATING -MONITOR WELL FOR 10 MINUTES-2 BPH LOSS RATE -CHECK SAVER SUB-GOOD 01:30 - 04:00 2.50 DRILL P PROD1 TRIP BACK TO BOTTOM WITH 6-1/8" PRODUCTION BHA FROM 8,680'MD TO 12,600' MD -RIH ON ELEVATORS AT 100'/MIN -PU 177K,SO 140K -MONITOR WELL ON TRIP TANK-2 BPH LOSS RATE BREAK CIRCULATION EVERY 2000'MD,264 GPM,1800 PSI -MUD WEIGHT:8.6 PPG IN,8.6 PPG Printed 1/11/2016 8:53:54AM • North America-ALASKA-BP • Page 26 of 26 Operation Summary Report Common Well Name:D-35 AFE No Event Type:DRL-ONSHORE(DON) Start Date:11/21/2015 End Date:12/9/2015 X3-016WL-C:(8,951,342.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. l UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 06:30 2.50 DRILL P PROD1 CIRCULATE AND CONDITION MUD ON BOTTOM FOR LINER RUN -CIRCULATE 3X BOTTOMS UP -265 GPM, 2230 PSI 120 RPM,5K TORQUE -RECIPROCATE 50' -MUD WEIGHT:8.6 PPG IN,8.6 PPG --8 BPH DYNAMIC LOSS RATE WHILE CIRCULATING -MONITOR WELL FOR 10 MINUTES-4 BPH LOSS RATE 06:30 - 08:30 2.00 DRILL P PROD1 POOH WITH 6-1/8"PRODUCTION BHA FROM 12,600'MD TO 8680'MD TO RUN LINER -MONITOR WELL FOR 10 MINUTES-2 BPH LOSS RATE -MUD WEIGHT:8.6 PPG IN,8.6 PPG -POOH ON ELEVATORS AT 60'-100'/MIN -PU 177K,SO 141KAT 12,600'MD -MONITOR WELL ON TRIP TANK-2 BPH LOSS RATE 08:30 - 09:30 1.00 DRILL P I PROD1 CIRCULATE AND CONDITION MUD AT SHOE MONITOR WELL FOR 10 MINUTES-4 BPH LOSS RATE CIRCULATE 1X BOTTOMS UP -253 GPM, 1760 PSI AT 8680'MD -MUD WEIGHT:8.6 PPG IN,8.6 PPG -8 BPH DYNAMIC LOSS RATE WHILE CIRCULATING "CONDUCT CEMENT PLANNING MEETING 09:30 - 13:30 4.00 DRILL P PROD1 POOH WITH 6-1/8"PRODUCTION BHA FROM 8680'MD TO 200'MD TO RUN LINER -MONITOR WELL FOR 10 MINUTES-4 BPH LOSS RATE -MUD WEIGHT:8.6 PPG IN,8.6 PPG -POOH ON ELEVATORS AT 100'-150'/MIN -PU 162K,SO 132K AT 8680'MD -PU 99K,SO 99K AT 4100'MD -PU 40K,SO 40K AT 200'MD -MONITOR WELL ON TRIP TANK-2 BPH LOSS RATE 13:30 - 15:30 2.00 DRILL P PROD1 LAY DOWN 6-1/8"PRODUCTION DRILLING BHA#4 -MONITOR WELL FOR 10 MINUTES-4 BPH LOSS RATE -MUD WEIGHT:8.6 PPG IN,8.6 PPG -CONDUCT PJSM -LAY DOWN BHA#4 PER SLB -BIT GRADE:5-2-CR-N-X-I-BT-TD Printed 1/11/2016 8:53:54AM • • North' Pale 1 of 7 perat d t" `trmmary Ke r% F, Common Well Name:D-35 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/9/2015 End Date:12/13/2015 X3-016WL-C:(2,524,083.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum.D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/9/2015 15:30 - 17:00 1.50 CASING P RUNPRD RIG UP TO RUN 4.5"PRODUCTION LINER -CONDUCT PJSM BRING CASING TONGS AND RUNNING TOOLS TO FLOOR PER DOYON 17:00 - 22:30 5.50 CASING P RUNPRD !RUN IN HOLE WITH 4.5"PRODUCTION LINER TO 3292'MD MAKE UP SHOE TRACK AND CHECK FLOATS BAKER LOK SHOE TRACK AND USE JETLUBE SEAL GUARD FOR CONNECTIONS 1 TORQUE PIPE CONNECTIONS TO 4,440 FT-LBS -FILL CASING EVERY JOINT AND TOP OFF EVERY 10 JTS -PU 78K,SO 78K RUN LINER AT 60 FT/MIN INSIDE 7"CASING ;-MONITOR WELL ON TRIP TANK-2 BPH LOSS RATE -MUD WEIGHT:8.6 PPG IN,8.6 PPG 22:30 - 00:00 1.50 CASING P RUNPRD PICK UP LINER HANGER/PACKER PER BAKER REP -BAKER INSPECT HANGER SLIPS AND 1 SHEAR PINS,CONFIRMED BY WSL -CHANG OUT PS-21 INSERTS -MIX AND INSTALL XAN PLEX PER BAKER RIH WITH 3 STDS HWDP AND 2 DP SPACE OUT PUPS PER RUNNING ORDER TO 4347' MD PU 85K,SO 85K 12/10/2015 00:00 - 03:30 3.50 CASING P RUNPRD RUN IN HOLE WITH 4.5"PRODUCTION LINER ON DP FROM 4347'MD TO 8713'MD -RUN LINER AT 60 FT/MIN INSIDE 7"CASING -MONITOR WELL ON TRIP TANK-2 BPH LOSS RATE -MUD WEIGHT:8.6 PPG IN,8.6 PPG -BREAK CIRCULATION EVERY 1000'MD 03:30 - 04:30 1.00 CASING P ! RUNPRD CIRCULATE AT THE SHOE -CIRCULATE 1.5X LINER PLUS DP VOLUME -STAGE PUMPS UP TO 125 GPM,517 PSI PU 163K,SO 135K WITH PUMPS ON -MUD WEIGHT:8.6 PPG IN,8.6 PPG -6 BPH DYNAMIC LOSS RATE WHILE CIRCULATING 04:30 - 07:00 2.50 CASING P RUNPRD RUN IN OPEN HOLE WITH 4.5"PRODUCTION LINER ON DP FROM 8713'MD TO 12,575'MD RUN LINER AT 50 FT/MIN IN OPEN HOLE -MONITOR WELL ON TRIP TANK-2 BPH LOSS RATE -MUD WEIGHT:8.6 PPG IN,8.6 PPG -PU 163K,SO 135K WITH PUMPS ON -WASH DOWN EVERY 10TH STAND Printed 1/11/2016 8:54'21AM .f l Common Well Name:D-35 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/9/2015 End Date:12/13/2015 X3-016WL-C:(2,524,083.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time.11/23/2015 9:00:OOAM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:00 - 08:00 1.00 CASING N SFAL 12,600.00 RUNPRD PICK UP ONE JOINT DP AND CEMENT HEAD TO RUN TO BOTTOM MAKE UP CEMENT HEAD TO DP SINGLE -MAKE UP CEMENT HEAD AND DP SINGLE TO STUMP -WHILE ATTEMPTING TO MAKE UP TO TOP DRIVE CEMENT HOSE WRAPPED AROUND SINGLE -ROTATE TO THE LEFT TO UNTANGLE CEMENT HOSE -LEFT HAND ROTATION BACKED OUT 15'DP PUP ON TOP OF CEMENT HEAD INSTALL LIFTING CAP IN CEMENT HEAD AND PLACE IN MOUSE HOLE '-MAKE 15'DP PUP TO CEMENT HEAD,MAKE UP TO STUMP AND TORQUE THROUGH CEMENT HEAD '-CEMENT HEAD ASSEMBLY WAS NOT } TORQUED UP FROM MACHINE SHOP 08:00 - 08:30 0.50 CASING P RUNPRD WASH TO BOTTOM -WASH DOWN AND TAG BOTTOM AT 12,600' !MD PU 163K,SO 135K 1-LINE UP ON CEMENT LINE AND ESTABLISH 'CIRCULATION 08:30 - 13:00 4.50 CEMT P RUNPRD STAGE UP PUMPS TO CEMENTING RATE IN 0.5 BPM INCREMENTS TO FINAL CIRCULATING RATE OF 5 BPM. -2.0 BPM,770 PSI,90%RETURN FLOW -3.0 BPM,908 PSI,90%RETURN FLOW 3.5 BPM,963 PSI,100%RETURN FLOW -4.0 BPM,990 PSI,100%RETURN FLOW -4.5 BPM,1080 PSI,100%RETURN FLOW -5.0 BPM,1150 PSI,100%RETURN FLOW -INITIAL PRESSURE AT CEMENTING RATE OF 5.0 BPM, 1150 PSI 1-FINAL PRESSURE AT CEMENTING RATE OF 5.0 BPM, 960 PSI RECIPROCATED PIPE IN 20 FT STROKES -PU 170K,SO 140K -TOTAL OF 4X BOTTOMS UP CIRCULATED -TOTAL FLUID LOST DURING CIRCULATION ,17BBLS 13 00 - 13 30 0.50 CEMT P RUNPRD PRESSURE TEST CEMENT LINES -PJSM-DISCUSSED PRESSURE CROSS CHECKLIST -VERIFIED AND TESTED SLB PRESSURE TRIPS -PRESSURE TEST SLB LINES TO 250 PSI LOW,4500 PSI HIGH FOR 5 MIN EACH Printed 1/11/2016 8:54:21 AM North America-A Operation Summary Report Common Well Name:D-35 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/9/2015 End Date:12/13/2015 X3-016WL-C:(2,524,083.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No..PARKER 273 Spud Date/Time.11/23/2015 9:00.00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 17:00 3.50 CEMT P RUNPRD CEMENT 4-1/2"PRODUCTION LINER AS FOLLOWS: -PJSM PUMP 30 BBLS OF 12 PPG MUDPUSH II SPACER @ 5 BPM,965 PSI ICP,615 PSI FCP WHILE RECIPROCATING 20 FT INCREMENTS -PUMP 80 BBLS OF 15.8 PPG CLASS G I GASBLOK CEMENT @ 5 BPM,EXCESS VOLUME 10%(YIELD 1.17 CU.FT/SK), RECIPROCATING 20 FT,950 PSI ICP,165 PSI FCP -FLUSH LINES AND CEMENT HEAD WITH 8.6 PPG FLOPRO —DROP DRILL PIPE WIPER DART PERFORM DISPLACEMENT WITH SLB PUMPS -80 BBLS OF 8.6 PPG FLOPRO DISPLACED AT 6 BPM,ICP 53 PSI,FCP 570 PSI -SLOW PUMPS TO 3 BPM TO LATCH PLUG, LATCH UP CONFIRMED AT 87.6 BBLS DISPLACED - 52.4 BBLS DISPLACED AT 4 BPM:ICP 1152 PSI,FCP 1129 PSI 7.7 BBLS DISPLACED AT 2 BPM,ICP 1129 PSI,BUMP PLUG AT 1275 PSI AND INCREASE PRESSURE TO 1800 PSI AND HOLD,TOTAL 147.5 BBLS PUMPED -BRING PRESSURE UP TO 3,000 PSI AND HOLD FOR 5 MIN TO SET LINER HANGER -SLACK OFF 50K PLUS LINER WEIGHT DOWN TO CONFIRM HANGER SET. BRING PRESSURE UP TO 4,300 PSI AND HOLD FOR 5 MIN TO RELEASE HRD-E RUNNING TOOL. BLEED OFF PRESSURE TO CHECK FLOATS (HOLDING) -RECIPROCATED PIPE 20'MD DURING DISPLACEMENT UNTIL CEMENT EXITED THE SHOE,THEN COULD NOT MOVE PIPE ANY MORE.LINER WAS SET 20'OFF BOTTOM. TOTAL LOSSES THROUGHOUT JOB=0 BBLS -NO LOSSES OBSERVED AFTER CEMENT EXITED THE SHOE SET BAKER ZXP LINER TOP PACKER -PICK UP 6'TO EXPOSE DOG SUB AND SET DOWN 25K WITH ROTATION AT 15 RPM TO SET PACKER -SAW GOOD SURFACE INDICATION OF SET. CIRCULATE HOLE TO DISPLACE CEMENT OFF TOP OF LINER CIRCULATE AT 5 BPM AND PICKUP ABOVE TOL AND MARK NO-GO DEPTH AS RUNNING TOOL IS REMOVED FROM TIE BACK SLEEVE CIRCULATE OUT CEMENT -INCREASE RATE TO 10 BPM AND DISPLACE WELL TO 8.5 PPG SEAWATER CIRCULATE 2X BOTTOMS UP,1960 PSI ICP AND 1540 PSI FCP 12 BBLS CONTAMINATED CEMENT OBSERVED AT SURFACE Printed 1/11/2016 8:54.21AM North America-ALASKA BP Page 4 of 7 Operation Summary Report; Common Well Name D-35 AFE No Event Type.COM-ONSHORE(CON) Start Date:12/9/2015 End Date.12/13/2015 X3-016WL-C:(2,524,083.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) -RIG DOWN BAKER CEMENT HEAD CEMENT IN PLACE AT 15:00(CEMENT AT 1000 PSI COMP STRENGTH AT 8:00 ON 12/11/2015) FINAL LINER SET DEPTH=12,580'MD LINER TOP AT 8,550'MD 17:00 17:30 0.50 CEMT P RUNPRD SERVICE RIG EQUIPMENT AND PREP TO LAY DOWN 4"DP SINGLES. 17:30 - 00:00 6.50 CASING P RUNPRD PULL OUT OF HOLE WITH LINER RUNNING ASSEMBLY LAYING DOWN SINGLES FROM 8565'MD TO 1600'MD. -PU 155K,SO 150KAT 8500'MD -PU 55K AT 1600'MD -MONITOR WELL ON TRIP TANK-GOOD DISPLACEMENT 12/11/2015 00:00 - 00:30 0.50 CASING P RUNPRD SERVICE RIG EQUIPMENT,ST-80,BLOCKS, TOP DRIVE AND WASH PIPE. 00:30 - 02:30 2.00 CASING P RUNPRD PULL OUT OF HOLE WITH LINER RUNNING ASSEMBLY LAYING DOWN SINGLES FROM 1600'MD TO SURFACE. -PU 55K,SO 55K AT 1600'MD -MONITOR WELL ON TRIP TANK-GOOD DISPLACEMENT -UD HANGER RUNNING TOOL AS PER BAKER REP 02:30 - 03:30 1.00 BOPSUR P RUNPRD PULL WEAR RING,DRAIN STACK,AND RU 4.5" TEST JOINT AND TEST EQUIPMENT. 03:30 - 06:30 3.00 BOPSUR- P RUNPRD TEST BOP EQUIPMENT -PERFORM PJSM -TEST ALL BOPE AS PER AOGCC/BP REQUIREMENTS WITH 4-1/2"TEST JOINT -250-PSI/3500-PSI FOR 5/5 CHARTED MINUTES EACH TEST I-BOP CONFIGURATION FROM TOP TO BOTTOM:ANNULAR PREVENTER,2-7/8"X 5-1/2"VBRS,BLIND SHEAR RAMS,MUD CROSS,2-7/8"X 5-1/2"VBRS -TEST WITNESS WAIVED BY AOGCC INSPECTOR-JOHNNIE HILL 06:30 - 07:00 0.50 BOPSUR P RUNPRD RIG DOWN BOP TEST EQUIPMENT -PULL TEST PLUG -RD TEST JOINT AND EQUIPMENT 07:00 - 08:30 1.50 CASING P RUNPRD LAY DOWN DRILL PIPE FROM DERRICK TO PIPE SHED BREAK DOWN(8)STANDS OF DP AND LAY DOWN SINGLES 08:30 - 10.00 1.50 CASING P RUNPRD PRESSURE TEST 4-1/2"LINER AND LINER TOP PACKER -CLOSE ANNULAR PREVENTER -PRESSURE TEST 4-1/2"PRODUCTION LINER AND LINER TOP TO 250 PSI LOW FOR 5 MIN AND 3500 PSI HIGH FOR 30 MIN EACH(PASS, SEE ATTACHED CHART AND DOCUMENTATION) 10:00 - 10:30 0.50 RUNCOM P RUNCMP RU 4.5"COMPLETION HANDLING EQUIPMENT -RU CASING TONGS PER DOYON Printed 1/11/2016 8:54:21AM ;::::::::: j Common Well Name:D-35 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/9/2015 End Date:12/13/2015 X3-016WL-C:(2,524,083 00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 12:00 1.50 RUNCOM P RUNCMP !RUN 4-1/2"12.6#13CR VAMTOP TUBING !FROM SURFACE -PJSM WITH HALLIBURTON,DOYON CASING, AND RIG CREW -BAKER LOKALL CONNECTIONS BELOW PACKER -USED JET LUBE SEAL GUARD ON ALL PREMIUM CONNECTIONS ABOVE -TORQUE CONNECTIONS TO 4,440 FT-LBS RIH AT 90 FT/MIN MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 12:00 - 14:30 2.50 RUNCOM N SFAL RUNCMP UNABLE TO USE COMPLETION BAKER LOK JOINT AND WLEG JOINT -WAIT FOR REPLACEMENT JOINTS TO ARRIVE ON LOCATION 14:30 - 18:00 3.50 RUNCOM P RUNCMP RUN 4-1/2"12.6#13CR VAMTOP TUBING TO 2420'MD -BAKER LOKALL CONNECTIONS BELOW PACKER USED JET LUBE SEAL GUARD ON ALL PREMIUM CONNECTIONS ABOVE -TORQUE CONNECTIONS TO 4,440 FT-LBS 1-RIH AT 90 FT/MIN -PU 60K,SO 60K -MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 18:00 - 00:00 6.00 RUNCOM N WAIT RUNCMP STAND DOWN OPERATIONS ON LOCATION FOR IMT FIELD WIDE COMMUNICATION OUTAGE -MONITOR WELL VIA TRIP TANK:STATIC 12/12/2015 00:00 - 05:30 5.50 RUNCOM N WAIT RUNCMP STAND DOWN OPERATIONS ON LOCATION FOR IMT FIELD WIDE COMMUNICATION OUTAGE 1-MONITOR WELL VIA TRIP TANK STATIC 05:30 - 13:30 8.00 RUNCOM P RUNCMP RUN 4-1/2"12.6#13CR VAMTOP TUBING FROM 2420'MD TO 8450'MD -USED JET LUBE SEAL GUARD ON ALL PREMIUM CONNECTIONS -TORQUE CONNECTIONS TO 4,440 FT-LBS -RIH AT 90 FT/MIN -PU 60K,SO 60K -MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT -PU 116K,SO 114K AT 7700'MD -PU 126K,SO 122K AT 8450'MD Printed 1/11/2016 8:54:21 AM a- :3a Common Well Name:D-35 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/9/2015 End Date:12/13/2015 X3-016WL-C:(2,524,083.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No..PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual @88.45usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13.30 - 15:00 1.50 RUNCOM P RUNCMP ,SPACE OUT AND LAND 4-1/2",12.6#,VAMTOP COMPLETION ASSEMBLY AS FOLLOWS TAG 30'INTO JOINT 200 -LAY DOWN JOINTS 200,199,198 PICK UP AND RUN A 19.73'PUP FOLLOWED JOINT 198 -UTILIZING A LANDING JOINT,LAND THE TUBING HANGER WITH TUBING IN THE TIEBACK RECEPTACLE.FINAL TUBING DEPTH =8,558'MD -FMC REP RUN IN LOCKDOWN SCREWS AND I GLAND NUTS,TORQUE ALL TO 450 FT-LBS. PARKER 273 RKB TO UPPER LOCKDOWN SCREWS=43.23'MD HES TNT 7"X 4-1/2"PERMANENT PRODUCTION PACKER TOP AT 8,439'MD DCK-2 SHEAR VALVE INSTALLED IN GLM-5 1 WITH TOP OF GLM AT 3,493'MD -'XN'NIPPLE TOP AT 8,540'MD -NOTE:ALL CONNECTIONS BELOW PACKER ARE BAKER-LOK'D 15:00 17:00 2.00 RUNCOM P RUNCMP 'REVERSE CIRCULATE HEATED SEAWATER WITH CORROSION INHIBITOR -R/U TO CIRCULATED DOWN IA WITH RETURNS UP TUBING -REVERSE 130 BBLS OF CLEAN 8.5 PPG SEAWATER AT 4 BPM 350 PSI -REVERSE 92 BBLS OF CORROSION INHIBITED SEAWATER AT 4 BPM,350 PSI,SO THAT FINAL INHIBITED EXTENDS FROM THE PRODUCTION PACKER TO THE GLM-5 DCK-2 SHEAR VALVE. -CHASE WITH 65 BBLS OF SEAWATER AT 4 BPM,350 PSI -CIRCULATE EXTRA 5 BBLS DOWN IA,THEN PUMP 5 BBLS DOWN TUBING TO WASH OFF THE RHC PLUG. 17:00 - 20:00 3.00 RUNCOM P RUNCMP SET HES TNT PACKER AND PRESSURE TEST MAKE UP LANDING JOINT DROP BALL AND ROD TO RHC PLUG IN XN NIPPLE AT 8,540'MD -PULL LANDING JOINT CLOSE BLIND RAMS -PRESSURE TEST 4-1/2"TUBING TO 250 PSI FOR 5 MIN,3500 PSI FOR 30 MIN ON CHART- PASSING TEST -BLEED TUBING PRESSURE TO 1600 PSI -PRESSURE TEST ANNULUS TO 250 PSI FOR 5 MIN,3500 PSI FOR 30 MIN ON CHART- PASSING TEST -RECEIVED APPROVAL FROM WTL KEN SCHNEIDER TO PROCEED BLEED OFF TUBING PRESSURE TO SHEAR DCK VALVE IN GLM-5 AT 3,493'MD. OBSERVE GOOD INDICATION OF DCK VALVE SHEARING -CIRCULATE BOTH WAYS TO CONFIRM GOOD CIRCULATION Printed 1/11/2016 8:54:21AM North America-ALASKA BPS ` Page 7 of 7 Operation Summary Report Common Well Name:0-35 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/9/2015 End Date:12/13/2015 X3-016WL-C:(2,524,083.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:PARKER 273 Spud Date/Time:11/23/2015 9:00:00AM Rig Release:12/13/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292355000 Active datum:D-35 actual(4188.45usft(above Mean Sea Level) Date j From-To Hrs Task ! Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 22:00 2.00 RUNCOM P RUNCMP FREEZE PROTECT 7"X 4-1/2"ANNULUS AND 4-1/2"TUBING -HOLD PJSM FOR PUMPING FREEZE PROTECT PUMP 75 BBLS OF DIESEL AT 2.0 BPM AT 850 PSI DOWN IA -OPEN IA TO TUBING AND ALLOW DIESEL TO U-TUBE FOR 1 HOUR FREEZE PROTECTED TO 2,200'MD 22:00 - 00:00 2.00 WHSUR P RUNCMP INSTALL AND TEST NEW TWC -DRY ROD SET TWC WITH FMC TECH -PRESSURE TEST TWC FROM ABOVE AND BELOW TO 250 PSI AND 3500 PSI FOR 5 MIN EACH 12/13/2015 00:00 - 05:30 5.50 WHSUR P RUNCMP BLOW DOWN LINES AND NIPPLE DOWN BOP -PJSM WITH RIG CREW -BLOW DOWN LINES AND SURFACE EQUIPMENT -PUMP OUT BOP STACK -SET BOP ON TEST STUMP IN CELLAR DECK -LAY DOWN HIGH PRESSURE BOP RISER TO PIPE SHED -EMPTY ALL PITS **SIMOPS:LAY DOWN 4"DRILL PIPE FROM DERRICK WHILE ND BOP AND FLOOR ACTIVITIES ALLOW. **FALSE H2S ALARM WHILE ND BOP- MONITOR WITH HAND HELD H2S SENSOR AND NO TRACE OF H2S 05:30 - 08:30 3.00 WHSUR P RUNCMP NIPPLE UP ADAPTER FLANGE AND TREE PJSM WITH FMC REP AND RIG CREW -NIPPLE UP ADAPTER FLANGE -NIPPLE UP DRY HOLE TREE PER FMC -TEST ADAPTER FLANGE VOID TO 250 PSI 1 FOR 5 MINUTES AND 5000 PSI FOR 15 MINUTES -TEST TREE TO 250 PSI AND 5000 PSI FOR 5 MINUTES EACH -PUMP TEST FLUID OUT OF TREE AND POUR TWO BOTTLES OF HEET ON TWC 08:30 - 12:00 3.50 WHSUR P RUNCMP RIG DOWN AND MOVE OFF -SET TOP DRIVE IN SLIPS,UNPIN BLOCK,PIN BRIDAL LINES,REMOVE TORQUE TUBE PIN, TIE BACK SERVICE LOOPS AND KELLY HOSE, SECURE FORUM CRANE. **RIG RELEASE FROM D-35 AT 12:00 ON 12/13/2015** Printed 1/11/2016 8:54:21AM • S D-35, Well History (Post-Rig Sidetrack) ;ice T/I/O=TWCNac/0. Removed IA TEMP#73 . OA TEMP#29 . Installed Blinds. Torqued and PT'd to API specs. (PASS). Removed DH#06 . Installed upper production tree. Torqued and PT'd to API specs. (PASS). Pulled TWC#430 . Installed tree cap and PT'd to 500 Psi. (PASS). RDMO. Fluid 12/16/2015 Packed Annulas Watch For Thermal Expansion. FWHP =VacNac/0. PULL BALL& ROD FROM 4-1/2" HES RHC-M PLUG BODY AT 8,540' MD. PULL BK-DGLV FROM ST#4 (5,252' MD) & BEK-SHEAR VALVE FROM ST#5 (3,493' MD). SET BK-OGLV AT ST#4 12/18/2015 (5,252' MD). CURRENTLY RIH W/ BK-LGLV TO ST#5 (3,493' MD). SET BK-LGLV AT ST#5 (3,493' MD). PULL EMPTY 4-1/2" HES RHC-M PLUG BODY FROM 8,501' SLM/8,540' MD. DRIFT TO DEVIATION AT 9,476' SLM W/3.50" CENT, 2.50" S-BLR (No sample 12/19/2015 or issues). CTU #8 w/ 1.5" CT(CTV=26.7) Objective- Log RPM, Add Perfs. MIRU, Install and function test BOP, RIH with BOT MHA/JSN 3.25" circulating Slick 1% kcl w/saflube. Tag PBTD @ 12472 do/ 12465 up. Paint flag @ 12515'. Clean out FloPro Mud and circulate hole to 1% KCI w/safelube. 12/29/2015 POOH. FP well. CTU #8 w/ 1.5" CT(CTV=26.7) Objective- Log RPM, Add Perfs. MU Baker Atlas RPM. RIH. Log down from 8600' @ 30 fpm to tag TD 12466', logged 20 fpm TD to 8250'. RBIH to TD and Circ well 12/30/2015 to Diesel, POOH. Sit @ 300' and wait for Baker Atlas hand to get off rig job before pulling to surface. CTU #8 w/ 1.5" CT (CTV=26.7) Objective- Log RPM, Add Perfs. Finish POOH with Baker RPM. Download data. Make (+) 30' correction. TD corrected is 12491.81'. MU 30' of 2-7/8" PJO Perf guns. RIH tag TD and correct to bottom shot, PUH perforate 12373'-12403', POOH, All shots fired. 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G J O m N 8 o wa >.>. m E !! _ U mm p` • • North America - ALASKA - BP Prudhoe Bay PB D Pad D-35 D-35 Plan #5b D-35 Anticollision Summary Report 15 December, 2015 • • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-35 Project: Prudhoe Bay TVD Reference: D-35 actual @ 88.45usft(P273) Reference Site: PB D Pad MD Reference: D-35 actual @ 88.45usft(P273) Site Error: 0.00usft North Reference: True Reference Well: D-35 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore D-35 Database: EDM RSK-Alaska PROD-ANCP1 Reference Design: Plan#5b D-35 Offset TVD Reference: Offset Datum Reference Plan#5b D-35 Filter type: NO GLOBAL FILTER:Using user defined selection&filtering criteria Interpolation Method: MD Interval 25.O0usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 500.00usft Error Surface: Elliptical Conic Survey Program Date 12/10/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 59.00 743.00 D-35 Srvy 1 GYD-GC-SS(D-35) GYD-GC-SS Gyrodata gyro single shots 833.95 3,118.73 D-35 Srvy 2 MWD+IFR+MS-WOCA(D-35) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 3,217.69 8,651.21 D-35 Srvy 3 MWD+IFR+MS-WOCA(D-35) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,732.92 8,732.92 D-35 Srvy 4 INC+TREND(D-35) INC+TREND Inclinometer+known azi trend 8,766.04 12,559.82 D-35 Spry 5 MWD+IFR+MS-WOCA(D-35) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 12/15/2015 1:02:18PM Page 2 of 4 COMPASS 5000.1 Build 61 • 0 BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-35 Project: Prudhoe Bay TVD Reference: D-35 actual©88.45usft(P273) Reference Site: PB D Pad MD Reference: D-35 actual @ 88.45usft(P273) Site Error: 0.00usft North Reference: True Reference Well: D-35 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore D-35 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#5b D-35 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 D Pad D-03-D-03-D-03 4,200.71 4,375.00 484.98 126.49 358.58 Pass-Major Risk D-03-D-03A-D-03A 4,200.71 4,375.00 484.98 126.49 358.58 Pass-Major Risk D-06-D-06-D-06 6,603.28 6,775.00 200.44 172.72 31.16 Pass-Major Risk D-06-D-06A-D-06A 6,602.91 6,775.00 200.40 172.70 31.16 Pass-Major Risk D-06-D-06APB1-D-06APB1 6,602.91 6,775.00 200.40 172.70 31.16 Pass-Major Risk -11- -11-0-1100Out of range D-11-D-11 A-D-11 A Out of range D-11-D-118-D-11 B Out of range D-18-D-18-D-18 883.82 875.00 413.57 13.66 399.91 Pass-Major Risk D-18-D-18A-D-18A 886.70 875.00 413.61 13.71 399.91 Pass-Major Risk D-18-D-18B-D-18B 886.70 875.00 413.61 13.71 399.91 Pass-Major Risk D-19-D-19-D-19 9,547.44 9,425.00 342.03 204.42 137.13 Pass-Major Risk D-19-D-19A-D-19A 9,498.86 9,225.00 432.44 193.74 252.56 Pass-Major Risk D-19-D-19B-D-19B 9,400.82 9,950.00 174.53 180.54 -2.87 FAIL-Major Risk D-19-D-19C-D-19C 8,082.76 8,150.00 300.01 76.28 223.87 Pass-Major Risk D-20-D-20-D-20 519.68 500.00 197.47 12.04 185.43 Pass-Major Risk D-21-D-21-D-21 416.84 400.00 86.12 9.75 76.37 Pass-Major Risk D-22-D-22-D-22 409.48 400.00 33.52 8.31 25.22 Pass-Major Risk D-22-D-22A-D-22A 409.48 400.00 33.52 8.31 25.22 Pass-Major Risk 0-22-D-22APB1-D-22APB1 409.48 400.00 33.52 8.31 25.22 Pass-Major Risk D-22-D-228-D-228 416.15 400.00 33.66 8.42 25.25 Pass-Major Risk D-22-D-22C-D-22C 417.43 400.00 33.69 8.45 25.25 Pass-Major Risk D-23-D-23-D-23 932.26 925.00 126.86 17.36 109.55 Pass-Major Risk D-23-D-23A-D-23A 940.76 925.00 127.08 17.57 109.56 Pass-Major Risk D-26-D-26-D-26 4,167.44 4,175.00 130.99 72.26 59.09 Pass-Major Risk D-26-D-26A-D-26A 4,167.44 4,175.00 130.99 72.26 59.09 Pass-Major Risk D-26-D-26B-D-26B 12,095.81 10,525.00 375.94 611.31 -208.75 FAIL-Major Risk D-27-D-27-D-27 541.24 525.00 30.50 9.51 20.99 Pass-Major Risk D-27-D-27A-D-27A 541.24 525.00 30.50 9.51 20.99 Pass-Major Risk D-28-D-28-D-28 690.75 675.00 79.62 13.40 66.22 Pass-Major Risk D-28-D-28A-D-28A 708.35 700.00 79.95 13.76 66.19 Pass-Major Risk D-28-D-28AL1-D-28AL1 708.35 700.00 79.95 13.76 66.19 Pass-Major Risk D-28-D-28B-D-286 708.35 700.00 79.95 13.76 66.19 Pass-Major Risk D-28-D-28BPB1-D-28BPB1 708.35 700.00 79.95 13.76 66.19 Pass-Major Risk D-31-D-31 B-D-318 Out of range 12/15/2015 1:02:18PM Page 3 of 4 COMPASS 5000.1 Build 61 o NQO-0/JO 0 • 49: a I ' o o a'1`�V 01 1111111,1k4:' ` a cn MI0.i7 .,. ,;;;2 I gliar.....oter,.,. i ..:qs: -5 .. . 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E z2 co m n H N c v (-) C0 o) .- Y o f g c U 0 a) -0 C) J N O U E O Q C "96) N a LL O ❑ E o m U) (0 X m 0 J C N 00 m p CU n I-= O a) 3 0 Ci l J LL Ip- O 2 O co dr o c LL Eo o n 2 , d LL . N 0 Q ❑ _O Z W a Q 0 _ O U 8 _ C N a) O °-_o to To Z. o - co o I Z 0 .- 30 > a o_ o n _c O U _- o U W z z z ''..2 - 0 LL o c -o O Lu o_ F o E m aTi c° 0 -I F Z m L° o o 0 O I ce a) UJ C M CO L y co ❑ 0 O_ N -O N O OZ LL a C O O HEO ..L (7) U U a) JEm W co 3 7. pEt CC 3ZO 0 O_ N 'LO O d 1 N co < 2 -0ai j -o O • dpNN ' N Y• 0_ oO E n cCd N a O EU O .- ^ u! LL N E ap O . - C y C aJ C = = o c U a O 3O U , . E E c> C SS L O) O ,- o_ N a) x N -O ' -O a d a H ) c EmowoE -U a LU O D UH H 0 c (1)) U 0 m U m H S r OF ?Ai • 111 4„)..),',,/,,,, sem THE STATE Alaska Oil and Gas e , of� /` sKA Conservation Commission ll' x =- 333 West Seventh Avenue J -� 7: GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oFALAS�� Fax: 907.276 7542 www.aogcc.alaska.gov Mary Endacott Engineering Team Lead BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-35 BP Exploration(Alaska), Inc. Permit No: 215-131 (revised) Surface Location: 1825' FNL, 1692' FEL, SEC. 23, T11N, R13E, UM Bottomhole Location: 420' FNL, 890' FEL, SEC. 22, T11N, R13E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated August 4, 2015. 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, i°4•(..r4 V--,-...--- Cathy . Foerster Chair DATED this 234 day of October, 2015. STATE OF ALASKA RECEIVED 4110;SKA OIL AND GAS CONSERVATION COMMIS PERMIT TO DRILL r OCT 0 9 2015 20 AAC 25.005 ! /g �� GAGla. Type of Work: lb. Proposed Well Class: Development-Oil I I. Service-Winj 0 Single Zona tc.Specify /or: Drill lI • Lateral 0 Stratigraphic Test 0 Development-Gas 0 Service-Supply 0 Multiple Zone ❑ Colabed Gas 0 Gas Hydrates❑ Redrill ❑ Reentry 0 Exploratory 0 Service-WAG 0 Service-Disp ❑ Geothermal 0 Shale Gas 0 2. Operator Name: 5. Bond Blanket Il Single Well 0 11• Well Name and Number: BP Exploration(Alaska),Inc Bond No. 6194193 PBU D-35 • 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O.Box 196612 Anchorage,AK 99519-6612 MD: 12696' • TVD: 8864'• PRUDHOE BAY,PRUDHOE OIL 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): • ADL 028285&028284 . Surface: 1578'FNL,1692'FEL,Sec.23,T11N,R13E,UM • 8. Land Use Permit: 13. Approximate spud date: Top of Productive Horizon: 1467'FNL,3044'FEL,Sec.23,T11N,R13E,UM November 15,2015 • Total Depth: 420 FNL,890'FEL,Sec.22,T11N,R13E,UM 9. Acres in Property: 2560 14.Distance to Nearest Property: 22700 , 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: . 87.95 feet 15. Distance to Nearest Well Open to Surface:x- 653460 • y- 5959410 ' Zone - ASP 4 GL Elevation above MSL: 41 feet 4 Same Pool: 400 16. Deviated wells: Kickoff Depth: 400 feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 116 degrees Downhole: 3287 ' Surface: 2444 • 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) 42" 20" 91.5# A-53 80' Surface Surface 80' 80' 260 sx Arctic Set(Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 3099' Surface Surface 3099' - 3088' 1442 sx DeepCrete,378 sx Class'G' 8-3/4" 7" 26# L-80 VamTopHC 8715' Surface Surface 8715' • 8522' 228 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 VamTop 4131' 8565' 8388' 12696'. 8864' 427 sx Class'G' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Denth MD(ft)- I Perforation Depth TVD(ft). 20.Attachments Property Plat 0 BOP Sketch RI' Drilling Program Q Time v.Depth Plot 0 Shallow Hazard Analysis 0 Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements Z. Diverter Sketch Li 21.Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and correct. Contact Rosenbaum,Jesse E Email Jesse.Rosenbaum@bp.com Printed Name Mary Endacott Title Engineering Team Lead Signature // l� /L-1,1., Phone +1 907 564 4388 Date f V 1 L, (� � Commission Use Only ^ /c// � Permit to Drill / i royal 116 See cover letter for other Number: �I I / API Number. 50- s ' �1 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: QUp f-r$-f ¢-o u-Oc7/2,- m Sale�eq'd: Yes 0 No ®thMud log req'd: Yes ❑ No fid' 47-14-14.747-14-14.7 LGv✓ l7 lir Vi//7f `C5 H2S measures Yes Y No ❑—/ Directional svy req'd: Yes ia/ No 0 Spacing exception req'd: Yes 0 No (Id Inclination-only svy req'd: Yes ❑ No IF( APPROVED BY Approved by: eti,IPp.t.(46.,,,...., COMMISSIONER THE COMMISSION Date: /o-03-75- / GINAL V'TL /0/ 0//,— ORIGINAL / o/r ORI ,,,,/�/I) ,_---- Form 10-401 Revised 10/2012 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit Form and Attacts in Duplicate • S ti ) * 4 To: Alaska Oil &Gas Conservation Commission From: Jesse Rosenbaum, Drilling Engineer Date: Revision#1 October 41h, 2015 Re: D-35 Permit to Drill-Change in SHL-New PTD Approval of the Permit to Drill for the planned Ivishak Zone 2 producer well D-35 is requested. The well is currently scheduled to be drilled by the Parker 273 in November 2015 as a grassroots well. The planned well has three sections. The surface casing will be set at SV4. The intermediate casing will be set in the top of Sag River formation. The production interval will be completed with a cemented liner and will be perforated by the rig. The maximum anticipated surface pressure from the Sag River with a full column of gas from intermediate TD to surface is 2444 psi (assuming a predicted most likely pore pressure of 7.5 ppg at TD). Parker 273 is equipped with 5k psi rated 4 preventer BOPE stack (3-ram and an annular). The rams and annular will be tested to 3500 psi. The plan for D-35 includes the following: 1. The pre-rig work will include the installation of the conductor, welding of the landing ring, install of the lined cellar box, and prepping of the location for the rig to move over the well. 2. MIRU Parker 273 and function test diverter 3. MU 12-1/4" bent housing motor drilling assembly. Drill to SV3 sands and top set surface casing in a shale in the SV4. 4. Run and 9-5/8"surface casing and cement to surface 5. NU BOPE and Test 6. Drill 8-3/4"to TSGR at-8715 ft. 7. Run 7" Intermediate casing and cement to -1500' above the casing shoe. 8. Drill 6-1/8" production lateral to a planned final TD in the Ivishak 9. Run and cement 4-1/2" production liner. 10. Run 4-1/2" production tubing, sting into liner tie-back sleeve and set production packer 11. RDMO Jesse Rosenbaum Office (907)564-5155 Mobile (406)533-8984 Email Jesse.Rosenbaumbp.com Attachments: Well Bore Schematic Diverter Line Layout Diagram Rev 1 Directional Plan (WP4) Well Head Schematic BOPE Schematic 273 Tree Schematic D-35 PTD 1 10/6/2015 i Planned Well Summary Well D-35 Well Type Producer Target Ivishak Objective Zone 2 API Number: TBD Current Status Grass Roots Well - Conductor will be installed ' Estimated Start Date: 11/15/2015 Time to Complete: 34 Days Surface Northing Easting Offsets TRS Location 5,959,410 653,460 1578.5 FNL 1692 FEL . 11N 13E 23 Northing Easting TVDss Offsets TRS Tgt 1 (Intermediate 5,959,477.14 652,386.82 8,434 1489.5 FNL 2763.6 FEL 11N 13E 23 Casing Point) Productive 5959493.72 652105.7 8789 1467 FNL 3044 FEL 11N 13E23 Interval BHL 5960478.16 648958.54 8776 420 FNL 890 FEL 11N 13E22 Planned KOP: 400' MD/311' TVDss Planned TD: 12,696'MD/8776' TVDss Rig: Parker 273 , GL-RT: 46.95 RTE (ref MSL): 87.95 Directional Plan (P4) KOP: 400' MD Maximum Hole Angle: 26° in the 8-3/4" intermediate section 116° in the 6-1/8" production section Close Approach Wells: D-26, D-26A, and D-26B Survey Program: Surface to 500': Gyro - 500' to TD: MWD+IFR+MS ' Nearest Property Line: 22,700' Nearest Well within Pool: 400' • Formation Tops & Pe Pressure Estimate (SOR) Minimum Most Maximum Q Estimated Pore Likely Pore Fluid rC� Formation Pore 0 Formation Top Pressure Pressure Type / btd (TVDss) (EMW Pressure (EMW (for sands) (Fel) PP9) ppg) PP9) J G1 432 8.4 8.4 8.5 Water .S---7.3 BPRF 1,700 8.4 8.4 8.5 Water SV6 1,747 8.4 8.4 8.5 Water EOCU 2,423 8.4 8.4 8.5 Water SV5 2,449 8.4 8.4 8.5 Water p SV4 2,633 8.4 8.4 8.5 Water 1,01,5 SV3 3,168 8.4 8.4 8.5 Water/Gas? SV2 3,335 8.4 8.4 8.5 Water SV1 3,704 8.4 8.9 • 9.5 Water -'9 fes,e) UG4 4,179 8.4 8.9 9.5 Water UG4A 4,211 8.4 8.9 9.5 Water/ HC? UG3 4,436 8.4 9.2 • 9.5 Water UG1 4,923 8.4 9.2 9.5 Water WS2 5,424 8.4 8.9 9.5 Water WS1 5,635 8.4 8.7 • 9.0 Water CM3 5,837 9.2 9.9 • 10.5 , CM2 6,270 9.2 9.9 10.5 CM1 6,811 9.6 10.1 • 10.5 /o „2, l41_3 THRZ 7,121 9.6 10.0 10.4 TKNG 7,373 9.6 10.0 10.4 - TSGR 8,429 6.9 7.5 • 10.1 Gas .s _ 7 TSHU 8,458 6.9 7.5 10.1 TSAD 8,536 6.9 7.4 7.5 Gas MHO 8,960 6.9 7.0 7.5 MHO/HOT At)� .is". Casing/Tubing Program Hole Liner/ Wt/Ft Grade Conn Length Top Bottom Size Tbg O.D. (ft) MD/TVDss (ft) MD/TVDss (ft) 42" 20" 91.5# A-53 EW 80 Surface 80/-8 12-1/4" 9-5/8" 40# L-80 BTC 3099 Surface 3099/3000 8-3/4" 7" 26# L-80 VaHC°p 8715 Surface 8715/8434 6-1/8" 4 '/2" 12.6# 13Cr-85 Vam Top 4131 8565/8300 12696/8776 Tubing 4 '/2" 12.6# 13Cr-85 Vam Top 8565 Surface 8565/8300 • Mud Program Surface Hole: MMO 12-1/4" hole section Interval Density(ppg) LSYP YP API FL Chloride PH 0'—SV4 8.5-9.3 - 25-50 I 40-80 <15 <1000 mg/I 10.8-11.2 Intermediate Hole: LSND 8-3/4" hole section Interval Density(ppg) PV YP API FL HTHP FL MBT PH SV4- SV1 9.0-9.8 <18 18-26 <8 NC <18 9-10 SV1 - CM1 . 9.9- 10.0 ' <20 18-26 <6 _ NC <18 9-10 CM1 -SGR 10.2- 10.3 - <20 18-26 <4 <10 <20 9-10 Production Hole: Solid Free Drill-in-Fluid 6-1/8" hole section Interval Density(ppg) PV YP API FL LSRV MBT PH Production 8.5-8.7 <12 10-20 <10 >15000 <4 8-9.5 Logging Program 12-1/4" Surface: Drilling: DIR/GR/RES Open/Cased Hole: None 8-3/4" Intermediate: Sample Catchers—as required by Geology Drilling: DIR/GR/RES Open/Cased Hole: None 6-1/8" Production: Drilling: DIR/GR/RES/NEU/DEN Open/Cased Hole: None Cement Program Casing 9-5/8"40#, L-80, BTC Surface Casing Lead: 350% open hole excess through permafrost and 40% excess below permafrost. Port Basis collar used if hole conditions dictate Lead TOC: Surface Tail: 40% open hole excess + 80 ft shoe track Tail TOC: 1000 ft MD above casing shoe Cement Lead 475 bbl, 2667 ft3, 1442 sks of 11.0 ppg DeepCRETE, Yield: 1.85 ft3/sk Tail 78 bbl, 438 ft3, 378 sks of 15.8 ppg Class G, Yield: 1.16 ft3/sk Casing 7" 26#, L-80 VTHC Intermediate Casing Basis Tail: 80' shoe track+Annular volume to 1500' MD above shoe with 30% OH excess. 30% open hole excess+ 80 ft shoe track 1,500 ft MD above casing shoe Cement Tail 47 bbl, 264 ft3, 228 sks 15.8 lb/gal Class G— 1.16 cuft/sk Casing 4-1/2" 12.6# 13Cr-85, VamTop Production Liner Basis 30% open hole excess + 80' shoe track. Excess above TOL to be circulated out. Cement Tail 88 bbl, 495 ft3, 427 sks 15.8 lb/gal Class G— 1.16 cuft/sk S Surface and Anti-Collision Issues Surface Shut-in Wells: No surface shut-in wells are required at surface. Close Approach Shut-in Wells: D-26, D-26A, and D-26B in the production hole interval. D-26 and D-26A have been P&A'd. The well will be shut in at surface. Hydrogen Sulfide D-Pad is not an H2S pad. Faults Formation Where Encounter Fault MD Intersect TVDss Intersect Throw Direction Uncertainty Lost Circ and Magnitude Potential • 2A 9,505.0 8,970.0 25-35'DTW +/-100' Moderate Drilling Waste Disposal _ • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal / Contact the GPB Environmental Advisors(659-5893)f/guidance. Well Control 12-1/4" surface hole will be drilled with a diverter. Subsequent intervals will be drilled with well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. BOP regular test frequency will be 14 days. Except in the event of a significant operational issues that may affect well integrity or pose safety concerns, an extension to the test period should not be requested. Intermediate Interval Maximum anticipated BHP 3287 psi @ SGR at 8429 ft TVDss (7.5 ppg EMW) Maximum surface pressure 2444 psi (3287psi-0.1 psi/ft gas x 8429 ft) Kick tolerance 25 bbl with 12.46 ppg FG, 7.0 ppg PP from SGR with 10.4 ppg MW 50 bbl with 13.59 ppg FG, 7.0 ppg PP from SGR with 10.4 ppg MW Planned BOP test pressure Rams test to 3500 psi/250 psi. Annular test to 3500 psi/250 psi 7" Casing Test 3500 psi surface pressure Integrity Test—8-3/4" hole LOT after drilling 20-50' of new hole Production Interval Maximum anticipated BHP 3287 psi @ SGR at 8429 ft TVDss (7.5 ppg EMW) • Maximum surface pressure 2444 psi (3287psi - 0.1 psi/ft gas x 8429 ft) Kick tolerance Infinite with 9.17 ppg fracture gradient, assuming 7.5 ppg pore pressure in Sag River and 8.6 ppg MW. Planned BOP test pressure Rams test to 3500 psi/250 psi. Annular test to 3500 psi/250 psi Integrity Test—6-1/8" hole FIT after drilling 20-50' of new hole Planned completion fluids 8.5 ppg Sea Water/6.8 ppg Diesel • • Variance Request 1)To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections,the flow paddle will be put back in the flow line(<1,000 ft). Procedures/Safeguards with paddle removed: • Fluid levels will be monitored in the pits for both gains and losses while drilling.Alarms will be set to indicate if gain or loss of more than 15 bbls has occurred. • The well will be monitored for flow when the pumps are off at each connection. • The planned 8.6-9.4 ppg fluid will provide over balance to formation fluid. Pre-Rig Work: 1. Install 20"conductor casing Rig Operation: 1. MIRU Parker 273 2. Nipple up and function test diverter. 3. Drill 12-1/4" surface section to-3100'with GR/RES. 4. Run and cement 9-5/8"40#L-80 BTC surface casing.A TAM port collar may be run at 500'as a contingency for surface cementing. 5. Nipple down diverter, nipple up Casing head and BOP(configured from top to bottom: annular preventer, 7" FBR, blind/shear, mud cross, 3-1/2"x 6"VBR). 6. Pressure test BOP/Annular to 250 psi low/3500 psi high. 7. Drill 20'of new formation and perform LOT. 8. Drill 8-3/4" intermediate section to -8715'with GR/RES. 9. Run and cement 7"26#L-80 Vam Top HC casing. 10. Test 7" casing to 250 psi low/3500 psi high. 11. Inject drilling fluid into the annulus to ensure annulus remains open for freeze protection. 12. Install 9-5/8"x 7"casing pack-off and test. 13. Change 7"casing rams to 2-7/8"x5"VBR and test to 250 psi low/3500 psi high. 14. Freeze protect 9-5/8"x 7"annulus once cement compressive strength reaches 500 psi. 15. Drill 20'of new formation and perform FIT. 16. Drill 6-1/8" production section to -12812'with GR/RES/NUE/DEN. • 17. Run and cement 4-1/2" 12.6#13Cr-85 Vam Top liner. Circulate out excess cement above TOL. 18. Test Liner Top Packer to 250 psi low/3500 psi high. 19. DPC perforate as per geologist. 20. Run 4-1/2" 12.6# 13Cr-85 Vam Top completion and stab into 4-1/2" Liner Top. 21. Drop ball and rod to set the production packer and test tubing to 250 psi low/3500 psi high. Bleed tubing pressure to 2000 psi, and test IA to 250 psi low/3500 psi high. 22. Shear the DCK shear valve. 23. Freeze protect well and install TWC. 24. ND BOPE, NU Tree and test to 250 psi low/5000 psi high. 25. RDMO Post-Rig Work: 1. Pull Ball and rod and RHC plug 2. Kick-off GLV design 3. ASRC flowback • • Proposed Well Schematic TIS= s 4-1116'ACTUATOR D-3.5 Proposed (P4) a KEk aev• BF.E1EV= KODP=NIA s , I�LX.Anp 42? ---__.... 20'CoisccCTOR _ace I T E - s MA PORT COLLAR DOM K2 10340 129.431 X-52156 4 L umTVQp 1 1=0096 I rir r I V "kin WTE � 4 tF-.� 11;L� (9,&V 40e L80 BTG 10,9 835' 3,096" 3 THD THD 2 TBD TBD I Teo TOO, f!4' -1600 15 tt PFYi Clens.6' I 6440' H4-112"HES XNP,O=3.81r I ►��w, 1480' H 1"X 4-1IZ NEB TNT PKR a*3.676" I I l I 1820' 4.112'HESX NP,U=3.813' I 0 1 " 4 6620' H4fi 113'NES XN NIP,V•3.796'I I 6360• —7'X 5`SKR 2XP F1CR 8 Flexleck a 6661' _-iiitnol freer<CK SLY.o•4.1 I4.112.m012 as 130-85 VT.0152 Ng 3.958•H 3584• 8%4' 1—{TOC of Fully GrtiMed Lir I IT CSG,2014t,L-80,VTKC,.03$3bpf,D=6.ver 8114`MD Ort ' 0 6 4 4 9� 1t !a 141/2'Sold LNR,122 Fie 13(7 !O.VI,D=2.997 1-7-12-14-6-1 ek DA TE REV BY OONFA TS u'ft /IV BY C !0.0 I1S Ptudhoe Bay LW 11?16,14 .JFP Proposed Completion 1MB„L:O35 PERI IT No:4 API No: SECSCX PNPXXN RXXE PSI XXXX'FEL XXX' BP Exploration(Alaskal • 0 t . 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Radiu From ,� -` ■ ;rid of £i ec — ' 23 i it _- - - - r- _-__- . 21 ._- .___ 1, 22.5 deg Angle Diverter Section J 4, 40' 16' Diverter Sections ('. / I r 30 II 0 I I I I 1 4a I n ib t 24 a 1 LO 3 R • During the most recent site walkthrough on D-pad, operations found the flowlines behind the rig were too close to meet the AOGCC requirements from the rig to the end of the diverter line. The superintendent noticed the distance discrepancy from the plan and notified the ODE. • This revision reflects the new design where the diverter will face north, away from vehicle traffic (see schematic). • This revision also reflects changes to the surface hole location since the permit was submitted, due to surface kit tie-in opportunity from well D-27. 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's, `-.-4 1,4,5000 140D 120 G4 4 1J16.5000,MOO 40 GM AC To 91116 64,C) —1--- I . y' -�-pp ry�'' i • 4 I/NS-VICO WO 724 GY i_L=E �! _ • igh, ,,,, 1 r d rn 04 4r 0 ma wwwwwgin I, .. 4 tit 6-5°co TREEw''.c o.r 2 Wr 4 Irt6-S000 WING »« 0 .,::::::.:::::—.==......, www.wr es,.,s DM106023OO7 MI= 4-1/16" 1NE1LHEAD= FMC 41°D-35 Proposed/P4) ACTUATOR= KB.B_EV= BF.B_EV= r '` KOP=N/A Max Angle=422 20"CONDUCTOR, -80' °" �, � H9-5/8"TAM PORT COLLAR Datum MD=10340' 129.4#X-52/56 r TBD Datum TVDss=9080' " ----^� -2000' I—4-1/2"HES X NIP,D=3.813" GAS LET MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 4 TBD TBD 4.5"x1" 9-5/8"40#L80 BTC ID=8.835" H 3,098' I 3 TBD TBD 2 TBD TBD 1 TBD TBD Tr? 7211' 1 TOC-1500'15.8 PPG Gass"G" 0.04 M , 8440' H4-1/2"HES X NIP,ID=3.813" AICZI _ : 8480' H7"X 4-1/2"HES TNT PKR D=3.870" 8820' H4-112'HES X NIP,ID=3.813" 8830' H4-1/2"HES XN NIP,ID=3.725" • 8560' 7"X 5"BKR ZXP PKR&Flex lock ="" "1= I } 8561' _W 8w/TIEBACKSLV,ID=4.J 4-1/2"TBG 12.6#13Cr-85 VT.0152 bpf D=3.958" H 8564' ° _ 8564' - TOC of Fully Cemented Liner • 7"CSG,26#,L-80,VT HC,.0383 bpf,D=6.276" H 8714' MD 1 O «4 1110 { ii 4-1/2"Solid LNR, 12.6#, 13Cr-80,VT,D=2.992" -i 12,696' +-14 DATE REV BY COM ENTS DATE REV BY COMMENTS Prudhoe Bay UNIT roposed Completion WELL: PERMIT No: # API No: SECXX TWPXXN RXXE FSL XXXX'FEL XXX' BP Exploration(Alaska) • III N ......... ^ mO)mmLo Nn'mn Mom ON a,co N N N npN O0 pnO O C r Q O p O m 0)_ 03 p r N co r co p O O N)n N p 0)....N r. jO OO O4 OW 6 0) 6 4MOm V• 0 U h N U'0 TO)0mDV 4444 QMNrg W 0N mmr NNNNN.N OOON N NN•g", IT W MMMMc) MM MM co, Moo,MMM ) M MMM 00 MMM CO 0O L000 ON 00 c0 m)0000 LU 01000)0 hh 00 h 00 h d O O O m O0 O O O O O Co m O O 0 to O O O CO CO O O O 10 CO O a. a LU 0 O) Q c O p M 0 0 0 n m n n Q 0) N•-to,c A n p p^0 t o,N 0, M c CO 0 0 0 co 0) m 0 0 0 n n O O Q C) Q N.n co o- N p n 0 n L= 00 0 0) 00000 0O 000 06666 N cp<0 n nn n oD O) 0 0o Q O .c •-°-°-.o 0 0 0 0 0 0 0 000 O Q Q Q Q p Q Q Q Q Q Q Sr Q Q p p p p p p p p p p p p N Z L.N L..'0 N O O O T N 0 0 N 0 O)A cr,0 W 0 0)O)Cr,0)Co O 0)4) Cr,m O)0) O OI O Q7 CO0)0) O) )[]10�[] n al O) T 0)o)0)0) a)0)0)0)O) 0)O)O) N O O)O O c0 O O O O h O h O 10 O )O 0 0 0 0 0 0 0 0 0 0 0 h q X 0 0 0)O N N 0 O))O co r.-O M O) N co,co,p p LO c0 O n n n co 0, C d 0 O N N co, r r CO O r N N M c, Q p p p p p p p n-p p n-p O M M C EOOOr,- r NNM n) M(0 M ch (0(06 6 (0 M cy F)(0 M(00 F O u e a O ‹...c, 0 O O O pO O O O O .0 0 0 0 .,,,c),-.),, 0 0 0 0 0 0 0 0 J O O O c 0 O)O O O h O c O 0 0 c 0 )0 0 0 0 0 0 0 0 0 0 0 0 0 0 O z O r -0.- - 0000 00000 000 Fr �� 2NULCy ("3222 22222 22222 222 Y C --6-- :iim O O r O np O I I- _I -J_ N. 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M N O 1 U, . —N ( N fic • N _ U) 0 - N . - I v 1 N N a _ CO • 0 _ N I N _ O I __.. . —O N M o (h N cUMMco V LO CO 0 - a - 0 ci_00 _N _0 C C C - N� N co CZ CZ CZaaa.a 2 - I — — - Ua)= CDS O+ -,7, �.�o � —.- �I� o w _ - 111II I t 1 I 1 I I 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 I I 1 1 1 1 I 1 1 1 I I I 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 I I I 1 1 1 I 1 1 1 I O O 117 O U) O U) O U) O U) O U) O U) O IN IO CD U) U) 7 P) co N N (uvllsn pi.) uoileaedes aalua3 01 OJlua3 • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan D-35 Project: Prudhoe Bay TVD Reference: D-35 plan @ 87.95usft(P273) Reference Site: PB D Pad MD Reference: D-35 plan @ 87.95usft(P273) Site Error: 0.00usft North Reference: True Reference Well: Plan D-35 Survey Calculation Method: Minimum Curvature Well Error: O.00usft Output errors are at 1.00 sigma Reference Wellbore Plan D-35 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#4 D-35 Offset TVD Reference: Offset Datum Reference Plan#4 D-35 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 5.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,464.95usft Error Surface: Elliptical Conic Survey Tool Program Date 8/27/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 46.95 1,050.00 Plan#4 D-35(Plan D-35) GYD-GC-SS Gyrodata gyro single shots 1.050.00 2,550.00 Plan#4 D-35(Plan D-35) MWD MWD-Standard 1,050.00 3,090.00 Plan#4 D-35(Plan D-35) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 3,090.00 4,590.00 Plan#4 D-35(Plan D-35) MWD MWD-Standard 3,090.00 8,710.00 Plan#4 D-35(Plan D-35) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,710.00 10,210.00 Plan#4 D-35(Plan D-35) MWD MWD-Standard 8,710.00 12,696.45 Plan#4 D-35(Plan D-35) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8/27/2015 3:23:55PM Page 2 of 4 COMPASS 5000.1 Build 61 0 BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan D-35 Project: Prudhoe Bay TVD Reference: D-35 plan @ 87.95usft(P273) Reference Site: PB D Pad MD Reference: D-35 plan @ 87.95usft(P273) Site Error: 0.00usft North Reference: True Reference Well: Plan D-35 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan D-35 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#4 D-35 Offset ND 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 D Pad D-03-D-03-D-03 4,207.52 4,385.00 485.25 126.40 359.01 Pass-Major Risk D-03-D-03A-D-03A 4,207.52 4,385.00 485.25 126.40 359.01 Pass-Major Risk D-06-D-06-D-06 6.604.88 6,780.00 200.61 173.46 30.49 Pass-Major Risk D-06-D-06A-D-06A 6,604.88 6,780.00 200.61 173.46 30.49 Pass-Major Risk D-06-D-O6APB1-D-06APB1 6,604.88 6,780.00 200.61 173.46 30.49 Pass-Major Risk D-07-D-07-D-07 4,816.44 5,090.00 584.60 163.41 421.40 Pass-Major Risk D-07-D-07A-D-07A 4,816.28 5,095.00 584.58 163.49 421.29 Pass-Major Risk D-07-D-07APB1-D-07APB1 4,816.28 5,095.00 584.58 163.49 421.29 Pass-Major Risk D-07-D-07B-D-078 4,818.71 5,095.00 584.98 163.94 421.29 Pass-Major Risk D-11-D-11-D-11 11,209.99 10,650.00 587.52 181.67 405.91 Pass-Major Risk D-11-D-11A-0-11A 10,504.89 10,135.00 730.09 155.80 580.15 Pass-Major Risk D-11-D-118-D-11 B 9,804.30 12,003.00 641.38 170.98 476.23 Pass-Major Risk D-16-D-16-D-16 973.98 970.00 636.93 21.00 615.94 Pass-Major Risk D-16-0-16A-D-16A 972.88 960.00 636.91 20.97 615.94 Pass-Major Risk D-16-D-16B-D-16B 972.88 960.00 636.91 20.81 616.10 Pass-Major Risk D-16-D-16BPB1-D-16BPB1 972.88 960.00 636.91 20.97 615.94 Pass-Major Risk D-17-D-17-D-17 1,035.79 1,030.00 530.37 19.43 510.94 Pass-Major Risk D-17-D-17A-D-17A 1,035.76 1,030.00 530.37 19.43 510.94 Pass-Major Risk 0-17-0-178-0-17B 1,039.06 1,025.00 530.41 19.47 510.94 Pass-Major Risk D-18-D-18-D-18 893.37 885.00 413.82 13.81 400.01 Pass-Major Risk D-18-D-18A-D-18A 896.24 885.00 413.86 13.86 400.01 Pass-Major Risk D-18-D-18B-D-18B 896.24 885.00 413.86 13.86 400.01 Pass-Major Risk D-19-D-19-D-19 9,550.00 9,425.00 342.04 152.32 189.48 Pass-Major Risk D-19-D-19A-D-19A 851.39 845.00 305.71 14.95 290.76 Pass-Major Risk D-19-D-198-D-19B 9,391.20 9,940.00 173.24 122.72 51.91 Pass-Major Risk D-19-D-19C-D-19C 8,086.51 8,155.00 300.02 76.05 224.15 Pass-Major Risk D-20-D-20-D-20 519.24 500.00 197.67 12.04 185.63 Pass-Major Risk D-21-D-21-D-21 416.39 400.00 86.30 9.59 76.72 Pass-Major Risk D-22-D-22-D-22 409.04 400.00 32.99 8.31 24.68 Pass-Major Risk D-22-D-22A-D-22A 409.04 400.00 32.99 8.31 24.68 Pass-Major Risk D-22-D-22APB1-D-22APB1 409.04 400.00 32.99 8.31 24.68 Pass-Major Risk D-22-D-22B-D-22B 410.71 395.00 33.02 8.34 24.68 Pass-Major Risk D-22-D-22C-0-22C 407.00 390.00 32.95 8.27 24.69 Pass-Major Risk D-23-D-23-D-23 931.89 925.00 126.36 17.36 109.04 Pass-Major Risk D-23-D-23A-D-23A 935.43 920.00 126.45 17.45 109.04 Pass-Major Risk D-26-D-26-D-26 4,157.67 4,165.00 131.04 23.73 107.46 Pass-Minor 1/200 D-26-D-26A-D-26A 4,157.67 4,165.00 131.04 23.73 107.46 Pass-Minor 1/200 D-26-D-268-D-26B 4,155.05 4,160.00 130.99 22.83 108.29 Pass-Minor 1/200 D-27-D-27-D-27 545.78 530.00 30.56 9.60 20.97 Pass-Major Risk D-27-D-27A-D-27A 545.79 530.00 30.56 9.44 21.12 Pass-Major Risk D-28-D-28-D-28 705.08 690.00 80.25 13.55 66.70 Pass-Major Risk D-28-D-28A-D-28A 702.94 695.00 80.21 13.51 66.71 Pass-Major Risk D-28-D-28AL1-D-28AL1 702.94 695.00 80.21 13.51 66.71 Pass-Major Risk D-28-D-288-D-28B 702.94 695.00 80.21 13.22 66.99 Pass-Major Risk D-28-D-288P61-D-28BPB1 702.94 695.00 80.21 13.51 66.71 Pass-Major Risk D-31-0-318-0-3113 9,171.12 11,370.00 515.06 165.84 392.04 Pass-Major Risk PB H Pad H-04-H-04B-H-04B 12,663.37 12,694.91 1,397.68 231.01 1,169.51 Pass-Major Risk H-07-H-07-H-07 Out of range H-07-H-07A-H-07A Out of range 8/27/2015 3:23:55PM Page 3 of 4 COMPASS 5000.1 Build 61 • Project: Prudhoe Bay • Site: PB D Pad Well: Plan D-35 Wellbore: Plan D-35 From Colour To MD Design: Plan#4 D-35 47 500 500 --..._.__._. 1000 From Surface to 3100'md (9-5/8") 1000 1500 Scan interal 25 ft 1500 2000 Scale 1 inch : 50ft 2000 2500 Several wells fail the major risk 2500 3300 Wells pass risk base rules See AC summary report for details 3300 3700 3700 4100 _ 0 4100 4700 150 4700 5200 5200 6000 330 t- 30 c) 6000 6500 �' ,r ^a 0 6500 ur 7000 7000 8200 (4.o\F -` 8200 9200 - • — �,� 9200 9500 10' \ 9500 9800 cf - ; •*.o - 9800 12710 4 hA I1N1?,93f�31241I1( \. . �`t 300 i _ t 1�`�!(�'O�.�'1�G�14i!�(Y�"i�i�'i�!�' P�1�1Sit1�6�k�117�1 tciv'. yQ ` ' • ; ,ENK16IEValuHAt1.198tara dw iffeFftkB1'I�I!IIA1EM�l8FfiFi` ` �• 2 �'��----- � 1 --- NIA!189�9'B1B11� L .r : 270 190 I i Q' : : dPCI'a 217,411°4 7 oB TOS }� i81�ai ^O i � I � � 89�fi }Ng) 1081Arfl1EEX8?L� lf6i�i#�t1@q��6�4 i,: ♦41 4♦ 50 '' i / / 240 —'• --- '.. - ." -' - ,- ----- -- - ft.-1,4s,*-....4,...-. ... ,,,,,. . , 120 .r.--...„ -_�o!s..iw.�=�►, .. ...A.. , ...'x-..,5 08}^1. „ ,„, ... . . , . . 1.. . .. ... .. .... .". " . 210 ,..--..... 150 ry 154 180 Azimuth from North[1 vs Centre to Centre Separation [40 usft/in] • Project: Prudhoe Bay • Site: PB D Pad Well: Plan D-35 Wellbore: Plan D-35 From Colour To MD Design: Plan #4 D-35 47 500 500 1000 From 3000'md (9-5/8")to 8800'md (7") 1000 1500 Scan interal 5 ft 1500 2000 Scale 1 inch : 50ft 2000 — "" 2500 Several wells fail the major risk 2500 3300 Wells pass risk base rules See AC summary report for details 3300 3700 //\‘' 3700 4100 _ 041004700 • ��,► ��.. 4700 5200 `��l�i�+Q'4T�®' ®�id�i1t/n►a.� 5200 6000 ,-- 4114.1 vviri ,01,10 PrP• .0 5k 4� + �� /�lO��I��Q�>► 30 6000 6500 330 �`f� ��,� / /1i11�QOo �-. \ �� ...�.:,a.�Ii*.fi ��i� r '®\��. 6500 " 7000 \4411111111.11/0/1 r ' l g�fD ► 7000 8200 ®�� L4h�i �wa�1A%`,11014�ogor� 8200 9200 .�� ' `.. .� I ��.��t6�.. 9200 9500 0s ��-4'+!aliiraO ll1/�,`I►j�:j►!I�Vi �'r< 9500 9800 -��i�®� � � "'. : �.d;®� air i � imirl it VT: i .... 9800 12710 300 : Vimitsotk . ANIONAzollhael gt4111 4TINiswoplAw=.�t tat t .� ®U� X1,104` i -4 ��►%.*- !`j��1►i��ti��. �\iV it ifi ,k,,'14014%i i lefri t 1�g4 9�� d@t►� � 10 Qil �v , j �. �s s� ILC4P4:tiralertrAtrAtglitlArahr-4P;d;11#4 �� ' �a,%'��//� ,` �� ei ''11#,o��li ��0d 1eg11 i * trOVAttieS614511Piir rip 270 : • • •. • % ',. • - j • \\*A4N4144iffeliatilealgOggilii 1, t \�`��y,1 1��_,��►��i>i/%�I�INIr,►� :r••o ..: , .,..1--. . , . . ... . . .. 2 . .... .....:•..... 3i k•14 1 b'ViotWilt Wit t: ��9 itsi!! icor 11 11 jo' 1440.000,00, . . . ., . v.. .. . . 44 50 ``,`, % 10, ®®rd! i tokiofirigrf • 75 \0�0��totr!�� 120 240 \�� O�f��® illipi4,1 \roof .''',,Y4'clatio.-c-.-,..-4*,..„.. ... ii„"i-,N4. 11,.r111\441iViSo-b.N. -, _` • i 1 210 ° u"` oL��Mt" r yi F., ,.i•!� ��I��,�\�\�\\'��- 15 o a,...,...,,,,;,,- III 11 180 Azimuth from North[1 vs Centre to Centre Separation [40 usft/in] • Project: Prudhoe Bay I Site: PB D Pad Well: Plan D-35 Wellbore: Plan D-35 From Colour To MD Design: Plan#4 D-35 47 500 500 1000 From 8700'md(7")to TD 1000 1500 Scan interal 25 ft 1500 2000 Scale 1 inch :50ft 2000 2500 Several wells fail the major risk 2500 3300 Wells pass risk base rules See AC summary report for details 3300 3700 3700 4100 _ 0 4100 4700 4700 5200 5200 6000 6000 6500 330 6500 7000 125 7000 8200 .0 ( " " 8200 9200 • • ` 9200 9500 •I 9500 9800 � fr 9800 12710 �� 60 • 270 ~� 90 0 • 7 240 120 • 1t� 210 150 150 180 Azimuth from North [O]vs Centre to Centre Separation [40 usft/in] • • North America - ALASKA - BP Prudhoe Bay PB D Pad D-35 D-35 Plan #4 D-35 AOGCC pre-job report 200' radius scan Anticollision Summary Report 05 October, 2015 • • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-35 Project: Prudhoe Bay TVD Reference: D-35 plan @ 87.95usft(P273) Reference Site: PB D Pad MD Reference: D-35 plan©87.95usft(P273) Site Error: 0.00usft North Reference: True Reference Well: D-35 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore D-35 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#4 D-35 Offset ND Reference: Offset Datum Reference Plan#4 D-35 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 200.00usft Error Surface: Elliptical Conic Survey Tool Program Date 9/23/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 46.95 1,050.00 Plan#4 D-35(D-35) GYD-GC-SS Gyrodata gyro single shots 1,050.00 2,550.00 Plan#4 D-35(D-35) MWD MWD-Standard 1,050.00 3,090.00 Plan#4 D-35(D-35) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 3,090.00 4,590.00 Plan#4 D-35(D-35) MWD MWD-Standard 3.090.00 8,710.00 Plan#4 D-35(D-35) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,710.00 10,210.00 Plan#4 D-35(D-35) MWD MWD-Standard 8,710.00 12,696.45 Plan#4 D-35(D-35) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 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 D Pad D-06-D-06-D-06 6,578.49 6,750.00 198.58 172.20 30.92 Pass-Major Risk D-06-D-06A-D-06A 6,578.49 6,750.00 198.58 172.20 30.92 Pass-Major Risk D-06-D-O6APB1-D-06APB1 6,578.49 6,750.00 198.58 172.20 30.92 Pass-Major Risk 0-19-D-19B-0-190 9,400.34 9,950.00 174.52 123.54 52.04 Pass-Major Risk D-20-D-20-D-20 519.24 500.00 197.67 12.04 185.63 Pass-Major Risk D-21-D-21-D-21 416.39 400.00 86.30 9.59 76.72 Pass-Major Risk D-22-D-22-D-22 409.04 400.00 32.99 8.31 24.68 Pass-Major Risk D-22-D-22A-D-22A 409.04 400.00 32.99 8.31 24.68 Pass-Major Risk D-22-D-22APB1-D-22APB1 409.04 400.00 32.99 8.31 24.68 Pass-Major Risk D-22-D-22B-D-22B 415.68 400.00 33.12 8.42 24.70 Pass-Major Risk D-22-D-22C-D-22C 416.96 400.00 33.14 8.45 24.71 Pass-Major Risk D-23-D-23-D-23 931.89 925.00 126.36 17.36 109.04 Pass-Major Risk D-23-D-23A-D-23A 940.39 925.00 126.57 17.57 109.04 Pass-Major Risk D-26-D-26-D-26 4,166.97 4,175.00 131.27 71.36 60.30 Pass-Major Risk D-26-D-26A-D-26A 4,166.97 4,175.00 131.27 71.36 60.30 Pass-Major Risk D-26-D-26B-D-26B 4,168.99 4,175.00 131.34 71.34 60.41 Pass-Major Risk D-27-D-27-D-27 540.80 525.00 30.48 9.51 20.97 Pass-Major Risk D-27-D-27A-D-27A 540.81 525.00 30.48 9.35 21.13 Pass-Major Risk D-28-D-28-D-28 714.96 700.00 80.46 13.72 66.74 Pass-Major Risk D-28-D-28A-D-28A 707.88 700.00 80.31 13.60 66.71 Pass-Major Risk D-28-D-28AL1-D-28AL1 707.88 700.00 80.31 13.60 66.71 Pass-Major Risk D-28-D-28B-D-28B 707.88 700.00 80.31 13.32 66.99 Pass-Major Risk D-28-D-28BPB1-D-28BPB1 707.88 700.00 80.31 13.60 66.71 Pass-Major Risk 0-35-D-35-D-35 46.95 46.95 0.00 0.91 -0.91 FAIL-Major Risk 10/5/2015 2:40:31PM Page 2 of 3 COMPASS 5000.1 Build 61 0 0 a 0.. ,•.-t .; 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MIMI •.C°. CD; .1;_-.••••11010..' °. )k i ir OL ,$) fi . 10V• . A ':•0 i . . , ! .2 . . • A . , I r-r.) , 1 , • 7: ,,,A4, i ! •.'`.. o -- e8 f 9 . q, . ,9,9 .11.• — 1 I - I 911• . : , o Lel C\. i ,_ 0 A a 1 i 9 1 . , ,-- . Pr al LO cP .04 Ffir 08/ ... , . tr) cl $ I 1 IN110 o in UPI m I L9 cp _. -—C•1 CD 1 ! I llE11111 c, Lo o cz I! W Pee-arezes a) , I - 1 1 1 Lr) i 1---- . . WA_MIR N . C' „........................7 0 O . ("I , InigrAill —: 0 1 i RpAl , • . . _Lo G-'01,6a 0 • • . c, oe CD ... A i Lo - —r--. . c?Al i ---,- 1-- 8 o I -1- dik_ °6`Ar , cv . i• as co -0'3 co D d) 0 0 a- ,1- 1,:,•'(..Sr? —In -0 I-1 in in c I 1111111 ! 0-3-1001T- 1 ' -r-- ,_, .L:(7) °•- I 0 _0 I I I I I I I I I I - 1 o . .I t 0-43i C . C C C o C(i) o a) . 7,a . . . u„ . . . CD o in LA) o Lo IC) N 0 N 1.0 .- ,- N 0 N. 10 N N to r•-• N N N (uvlisn 009) (+)LpoN/(-)ipos • • ' - r, p . -..� O N D£ AraiO N i d s 0 . azIN l I oo d �' �, o 9Z . " o m °' e 10. 4, c4 0 ' 1 ry 0 6Z n L 0 .„,:... % O r- omMEM� � b�_ Ilii 0 1ll : r 9E f I o o jr bl. E 7 m 9l 9 10.111110 _, _Lo ,•_ 1/11/r 86 Q p Q11 1 I N _ 99 u o W 09 89MEV 0 4a p -_- ----- --._..._ _ ...----..—_;; —o 1 IF o e9, OL -ch 96 i l oo OZZ 02z_O — — yZL o —�n 9b o bL 0 1 `.) ; 1 01 M 8L 8b — 0 m-0 6 cz � D�� -;........... —it m CO c7 M cd 9� �a6 6a O<9c' R0.3 g 061'0/ 15 — N c �i PC'AV P s�0 �,1 0 .9.4.0�� I I I 1 I I ln'r� I I I o 0 0 0 0 0 0 0 0 0 0 0 0 0 o o N N L) o N L7 o IA o N o cn co (ui/idSn 00L) (+)41JON/(-)41nog • • TRANSMITTAL LETTER CHECKLIST WELL NAME: ,� ` ('i ✓�l PTD: l3 1 Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: Y > POOL: d"LG , 1 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 0 41 171 171 • , , CD i d Q o U) N c3 a) O @ O c Q a3 CH , , a) U o a y �. Y co. 2 L11• In f00 .c. �, CO : O: gyp• O po2 . y' QCL 4 . @ . o E O x , o , Q , 2 ; 4M' a , 0. . o as 8 O, .D, m (n' 0' 4' c O v, w c, �. co. o m m rn ° ° m 0 w ' C , Cr; If; N: C. p, W. �. '3. p. V: (0 LL N, O O : 7. ., y. C c U) � �: ° o °.9- 6 o, °rn Q. O. 12, o. E. > o 0) co, E. m, ,_ a a))v Z Q• 0 O, �. 0 a a 7 O. (p O DI c a C. �. - a , m a Lq. o. N. e0. 2 co 03. ° Qy c..), a. _. v. O I , L . 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W- QIE a 0) Q F o a Q U S a a a (1) W a ' CD 0 a (c) L OF T� THE STATE 6 • Alaska Oil an Gas 111111 of Conservation Commission volk2__ GOVERNOR BILL WALKER 333 West Seventh Avenue 11F� Anchorage, Alaska 99501-3572 "'1 Main: 907.279.1433 ®FALASY'� Fax: 907.276.7542 www.aogcc.alaska.gov Mary Endacott Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-35 BP Exploration(Alaska), Inc. Permit No: 215-131 R13E,UM Surface Location: 1825' FNL, 1692' FEL, SEC. 23, T11N, Bottomhole Location: 420' FNL, 890' FEL, SEC. 22, T11N, R13E,UM Dear Ms. Endacott: Enclosed is the approved application for permit to 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, Cathy P. oerster Chair DATED this ay of August, 2015. RECEIVED STATE OF ALASKA .ASKA OIL AND GAS CONSERVATION COMMIS* JUL 2 7 2015 PERMIT TO DRILL 20 AAC 25.005 ��-1� la. Type of Work: 1 b. Proposed Well Class: Development-Oil Iv! • Service-Winj 0 Single Zone • Q 1c.SpebiPu`Y@R i +rrosed for: Drill • Q Lateral 0 Stratigraphic Test 0 Development-Gas 0 Service-Supply 0 Multiple Zone 0 Colabed Gas 0 Gas Hydrates 0 Redrill 0 Reentry ❑ Exploratory 0 Service-WAG 0 Service-Disp 0 Geothermal 0 Shale Gas 0 2. Operator Name: 5. Bond - Blanket 0 Single Well 0 11. Well Name and Number: BP Exploration(Alaska),Inc Bond No. 6194193 • PBU D-35 . 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O.Box 196612 Anchorage,AK 99519-6612 MD: 12706' . TVD: 8864' PRUDHOE BAY/PRUDHOE BAY 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): - •ADL 028285&028284 . Surface: 1825'FNL,1692'FEL,Sec.23,T11N,R13E,UM • 8. Land Use Permit: 13. Approximate spud date: 1556'FNL,2761'FEL,Sec.23,T11N,R13E,UM November 15,2015 Top of Productive Horizon: Total Depth: 420'FNL,890'FEL,Sec.22,T11N,R13E,UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 22700' • 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: 87.95' feet. 15. Distance to Nearest Well Open to Same Pool: Surface:x- 653465 • y- 5959163 • Zone - ASP4 GL Elevation above MSL: 43' feet• 400' 16. Deviated wells: Kickoff Depth: 400' • feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 116 degrees Downhole: 3P87 • Surface: 2444 • 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) 42" 20" 91.5# A-53 EW 80' Surface Surface 80' 80' 260 sx Arctic Set(Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 3099' Surface Surface 3099' 3088' 1442'sx DeepCrete,378 sx Class'C' 8-3/4" 7" 26# L-80 VamTop HC 8715' Surface Surface 8715' 8522' 228 sx Class'G' 6-1/8" . 4-1/2" 12.6# 13Cr85 Vam Top 4141' 8565' 8388' 12706' 8864' 427 sx Class'G' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perfnratinn r)apth Mr)(ft)• I Pprfnratinn I)apth TVI)(ft)• 20.Attachments Property Plat 0 BOP Sketch 0 Drilling Program H Time v.Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch Seabed Report 0 Drilling Fluid Program El 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and correct. Contact Rosenbaum,Jesse E Email Jesse.Rosenbaum@bp.com Printed Name Endacott,Mary Title Engineering Team Leader Signature L--- y . Y,� - '', d ' Phone +1 9075644388 Date 7/i'7/I Commission Use Only Permit to Drill " API Number: " -J�r Pe Approval p� /� See cover letter for other Number: �� / �� 50- requirements: / `��D�t�.r 7�/t.ji' v/ 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: 07 Other:.56/ 7-7-5 f f0 576 G p5/ L • Samplesie5/ Os meurres 12(YesC1d"No 0 Directional svy req'd: Yes No 0 FAr v 2 ?cIG�� 4'V��l't �� Spacing exception req'd: Yes 0 No svy req'd: E1 fi Inclination-only Yes 0 No /6,vo 'dr/'/1/Y13 per ZI A-A-G 2. 633( APPROVED BY Approved by: 915?..-611j--e\------COMMISSIONER THE COMMISSION Date: g!¢-`3-- ORIGI AL ,,,s_ Form 10-401 Revised 10/2012 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit Form and Attachments in Du licat/ ,t- 7l21(/, • i To: Alaska Oil &Gas Conservation Commission From: Jesse Rosenbaum, Drilling Engineer Date: July 24th, 2015 Re: D-35 Permit to Drill Approval of the Permit to Drill for the planned Ivishak Zone 2 producer well D-35 is requested. The well is currently scheduled to be drilled by the Parker 273 in November 2015 as a grassroots • well. The planned well has three sections. The surface casing will be set at SV4. The intermediate casing will be set in the top of Sag River formation. The production interval will be completed with a cemented liner and will be perforated by the rig. The maximum anticipated surface pressure from the Sag River with a full column of gas from intermediate TD to surface is 2444_pL(assuming a predicted most likely pore pressure of 7.5 ppg at TD). Parker 273 is equipped with 5k psi rated 4 preventer BOPE stack (3-ram and an annular). The rams and annular will be tested to 3500 psi. The plan for D-35 includes the following: 1. The pre-rig work will include the installation of the conductor, welding of the landing ring, install of the lined cellar box, and prepping of the location for the rig to move over the well. 2. MIRU Parker 273 and function test diverter 3. MU 12-1/4" bent housing motor drilling assembly. Drill to SV3 sands and top set surface casing in a shale in the SV4. 4. Run and 9-5/8" surface casing and cement to surface 5. NU BOPE and Test 6. Drill 8-3/4"to TSGR at—8715 ft. 7. Run 7" Intermediate casing and cement to—1500' above the casing shoe. 8. Drill 6-1/8" production lateral to a planned final TD in the Ivishak 9. Run and cement 4-1/2" production liner. 10. Run 4-1/2" production tubing, sting into liner tie-back sleeve and set production packer 11. RDMO Jesse Rosenbaum Office (907) 564-5155 Mobile (406) 533-8984 Email Jesse.Rosenbaum@bp.com Attachments: Well Bore Schematic Diverter Line Layout Diagram Directional Plan Well Head Schematic BOPE Schematic 273 Tree Schematic D-35 PTD 1 7/24/2015 • Planned Well Summary Well D-35 • Well Type Producer Target Ivishak Objective Zone 2 - API Number: TBD Current Status Grass Roots Well - Conductor will be installed . Estimated Start Date: 11/15/2015 Time to Complete: 34 Days Surface Northing Easting Offsets TRS Location 5959163 • 653465 . 1825.5 FNL 1692.3 FEL • 11N 13E 23 Northing Easting TVDss Offsets TRS Tgt 1 (Intermediate 5959411.09 652390.35 8430 1556 FNL 2761.4 FEL 11N 13E 23 Casing Point) BHL 5960478.16 648958.54 8776 420 FNL 890 FEL 11N 13E 22 Planned KOP: 400' MD/311' TVDss Planned TD: 12,706' MD/8766' TVDss Rig: Parker 273 GL-RT: 44.95 • RTE (ref MSL): 87.95 • Directional Plan (P3b) KOP: 400' MD Maximum Hole Angle: 26° in the 8-3/4" intermediate section 116° in the 6-1/8" production section Close Approach Wells: D-26, D-26A, and D-26B Survey Program: Surface to 500': Gyro 500' to TD: MWD+IFR+MS Nearest Property Line: 22,700' Nearest Well within Pool: 400' - Formation Tops & *re Pressure Estimate (SOR)i Minimum Most Maximum ik y«u Estimated Likely Pore Pore Fluid Formation Pore41, Formation Top Pressure Pressure Type L (TVDss) (EMW EMW (EMW (for sands) ( ` PPg) PPMPPM G1 432 8.4 8.4 8.5 Water c9, S-- 77:3 BPRF 1,700 8.4 8.4 8.5 Water SV6 1,747 8.4 8.4 8.5 Water EOCU 2,423 8.4 8.4 8.5 Water SV5 2,449 8.4 8.4 8.5 Water SV4 2,633 8.4 8.4 8.5 Water 9 a- -2 SV3 3,168 8.4 8.4 8.5 Water/Gas? SV2 3,335 8.4 8.4 8.5 Water SV1 3,704 8.4 8.9 9.5 Water ,y%,..f? _ io,c, UG4 4,179 8.4 8.9 9.5 Water UG4A 4,211 8.4 8.9 9.5 Water/ HC? UG3 4,436 8.4 9.2 9.5 Water UG1 4,923 8.4 9.2 9.5 Water WS2 5,424 8.4 8.9 9.5 Water WS1 5,635 8.4 8.7 9.0 Water ' CM3 5,837 9.2 9.9 10.5 /O.$ -/0-3 CM2 6,270 9.2 9.9 10.5 . CM1 6,811 9.6 10.1 10.5 THRZ 7,121 9.6 10.0 10.4 TKNG 7,373 9.6 10.0 10.4 TSGR 8,429 6.9 7.5 10.1 Gas A. Ca- 8:7 TSHU 8,458 6.9 7.5 10.1 TSAD 8,536 6.9 7.4 7.5 Gas MHO 8,960 6.9 7.0 7.5 MHO/HOT Ab 7,0-S. (c Casing/Tubing Program Hole Liner/ Wt/Ft Grade Conn Length Top Bottom Size Tbg O.D. (ft) MD/TVDss (ft) MD/TVDss (ft) 42" 20" 91.5# A-53 EW 80 Surface 80/-8 12-1/4" 9-5/8" 40# L-80 BTC 3099 Surface 3099/3000 8-3/4" 7" 26# L-80 VaHC°p 8715 Surface 8715/8434 6-1/8" 4 1/2" 12.6# 13Cr-85 Vam Top 4141 8565/8300 12706/8766 Tubing 4 1/2" 12.6# 13Cr-85 Vam Top 8565 Surface 8565/8300 • Mud Program Surface Hole: MMO 12-1/4" hole section Interval Density (ppg) LSYP YP API FL Chloride PH 0' —SV4 8.5 - 9.3 25-50 40-80 <15 <1000 mg/I 10.8-11.2 Intermediate Hole: LSND 8-3/4" hole section Interval Density (ppg) PV YP API FL HTHP FL MBT PH SV4 -SV1 9.0 -9.8 , <18 18-26 <8 NC <18 9-10 SV1 -CM1 9.9 - 10.0 , <20 18-26 <6 NC <18 9-10 CM1 - SGR 10.2 - 10.3 <20 18-26 <4 <10 <20 9-10 Production Hole: Solid Free Drill-in-Fluid 6-1/8" hole section Interval Density (ppg) PV YP API FL LSRV MBT PH Production 8.5 - 8.7 ° <12 10-20 <10 >15000 <4 8-9.5 Logging Program 12-1/4" Surface: Drilling: DIR/GR/RES Open/Cased Hole: None 8-3/4" Intermediate: Sample Catchers—as required by Geology - Drilling: DIR/GR/RES Open/Cased Hole: None 6-1/8" Production: Drilling: DIR/GR/RES/NEU/DEN J Open/Cased Hole: None Cement Program Casing 9-5/8" 40#, L-80, BTC Surface Casing Lead: 350% open hole excess through permafrost and 40% excess below permafrost. Port Basis collar used if hole conditions dictate Lead TOC: Surface Tail: 40% open hole excess+ 80 ft shoe track Tail TOC: 1000 ft MD above casing shoe Cement Lead 475 bbl, 2667 ft3, 1442 sks of 11.0 ppg DeepCRETE, Yield: 1.85 ft3/sk Tail 78 bbl, 438 ft3, 378 sks of 15.8 ppg Class G, Yield: 1.16 ft3/sk Casing 7" 26#, L-80 VTHC Intermediate Casing Basis Tail: 80' shoe track + Annular volume to 1500' MD above shoe with 30% OH excess. 30% open hole excess + 80 ft shoe track 1,500 ft MD above casing shoe Cement Tail 47 bbl, 264 ft3, 228 sks 15.8 lb/gal Class G — 1.16 cuft/sk Casing 4-1/2" 12.6# 13Cr-85, VamTop Production Liner Basis 30% open hole excess + 80' shoe track. Excess above TOL to be circulated out. Cement Tail 88 bbl, 495 ft3, 427 sks 15.8 lb/gal Class G — 1.16 cuft/sk Surface and Anti-Collision Issues Surface Shut-in Wells: No surface shut-in wells are required. Close Approach Shut-in Wells: D-26, D-26A, and D-26B in the production hole interval. D-26 and D-26A have been P&A'd. The well will be shut in at surface. Hydrogen Sulfide D-Pad is not an H2S pad. Faults Formation Where Encounter Fault MD Intersect TVDss Intersect Throw Direction Uncertainty Lost Circ and Magnitude Potential 2A 9,505.0 8,970.0 25-35'DTW +/-100' Moderate Drilling Waste Disposal • There is no annular injection in this well. - • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal / Contact the GPB Environmental Advisors (659-5893) f/guidance. Well Control 12-1/4" surface hole will be drilled with a diverter. Subsequent intervals will be drilled with well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. BOP regular test frequency will be 14 days. Except in the event of a significant operational issues that may affect well integrity or pose safety concerns, an extension to the test period should not be requested. Intermediate Interval Maximum anticipated BHP _3287 psi @ SGR at 8429 ft TVDss (7.5 ppg EMW) Maximum surface pressure 2444 psi (3287psi -0.1 psi/ft gas x 8429 ft) _ Kick tolerance 25 bbl with 12.46 ppg FG, 7.0 ppg PP from SGR with 10.4 ppg MW 50 bbl with 13.59 ppg FG, 7.0 ppg PP from SGR with 10.4 ppg MW Planned BOP test pressure Rams test to 3500 psi/250 psi. Annular test to 3500 psi/250 psi 7" Casing Test 3500 psi surface pressure Integrity Test—8-3/4" hole LOT after drilling 20-50' of new hole Production Interval Maximum anticipated BHP 3287 psi @ SGR at 8429 ft TVDss (7.5 ppg EMW) Maximum surface pressure 2444 psi (3287psi - 0.1 psi/ft gas x 8429 ft) Kick tolerance Infinite with 9.17 ppg fracture gradient, assuming 7.5 ppg pore pressure in Sag River and 8.6 ppg MW. Planned BOP test pressure Rams test to 3500 psi/250 psi. Annular test to 3500 psi/250 psi Integrity Test—6-1/8" hole FIT after drilling 20-50' of new hole Planned completion fluids 8.5 ppg Sea Water/6.8 ppg Diesel I S Variance Request 1) To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line (<1,000 ft). Procedures/Safeguards with paddle removed: • Fluid levels will be monitored in the pits for both gains and losses while drilling. Alarms will be set to indicate if gain or loss of more than 15 bbls has occurred. • The well will be monitored for flow when the pumps are off at each connection. • The planned 8.6 -9.4 ppg fluid will provide over balance to formation fluid. Pre-Rig Work: 1. Install 20" conductor casing Rig Operation: 1. MIRU Parker 273 2. Nipple up and function test diverter. 3. Drill 12-1/4" surface section to -3100' with GR/RES. 4. Run and cement 9-5/8"40# L-80 BTC surface casing. A TAM port collar may be run at 500' as a contingency for surface cementing. 5. Nipple down diverter, nipple up Casing head and BOP (configured from top to bottom: annular preventer, 7" FBR, blind /shear, mud cross, 3-1/2" x 6"VBR). 6. Pressure test BOP/Annular to 250 psi low/3500 psi high. 7. Drill 20' of new formation and perform LOT. 8. Drill 8-3/4" intermediate section to -8715' with GR/RES. 9. Run and cement 7"26# L-80 Vam Top HC casing. 10. Test 7" casing to 250 psi low/3500 psi high. 11. Inject drilling fluid into the annulus to ensure annulus remains open for freeze protection. 12. Install 9-5/8" x 7" casing pack-off and test. 13. Change 7" casing rams to 2-7/8"x5"VBR and test to 250 psi low/3500 psi high. 14. Freeze protect 9-5/8" x 7" annulus once cement compressive strength reaches 500 psi. 15. Drill 20' of new formation and perform FIT. 16. Drill 6-1/8" production section to -12812' with GR/RES/NUE/DEN. 17. Run and cement 4-1/2" 12.6# 13Cr-85 Vam Top liner. Circulate out excess cement above TOL. 18. Test Liner Top Packer to 250 psi low/3500 psi high. 19. DPC perforate as per geologist. 20. Run 4-1/2" 12.6# 13Cr-85 Vam Top completion and stab into 4-1/2" Liner Top. 21. Drop ball and rod to set the production packer and test tubing to 250 psi low/3500 psi high. 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NNNNN NNNNN (00 N O • tp m m N 0 U_ 0 y O O Z a- 2 io a O t0 � tD 06 m 0 0 0 W 0 H 0 0 H W 0 0 by SChiUMberger Borehole: Well: Field: Structure: D-35(P3b) Plan D-35 SL2 Prudhoe Bay Unit-WOA D-PAD Gravity&Magnetic Parameters Surface Location NAD27 Alaska State Plane,Zone 04,US Feet Miscellaneous Model: 8GGM 2015 Dip:81.036° Date: 31-Dec-2015 Lat: N 7017 43.36 Northing: 59591638US Grid Cons: 1.1699° Slot: (°,4,45,n)su TVD Ref: Rotary Table(87.95ft above MSL) MagDec:19.186° FS: 57529.645nT Gravity FS: 1001.999mgn(9.80665 Based) Lon: W 148 45 26.33 Easting: 853465ftUS Scale Fact: 0.99992675 Plan:0-35(P36) -1000 0 1000 2000 3000 4000 5000 RTE 0 M 0 0 Cry 1.51100 300 MD End Cry 800 MD 1000 ... 1000 Drp 1/100 1700 MD $VS'(1830.95 TVD/_.._.._.._.._.._.._._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.:_.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._ 2000 B"Werm(19i]ss TVfi) .... .. ... 2000 End Cry 2133 MD ��' ::_::_::_::_::_::_:::_:�::_::c::e::.::.::e::.::c::.::_::.::.::c::.::.::.::.::.C�::::::::::ie::e:::::::::::_::_:::e::e::e::e::e::e::.::_::.::.•.:.::o::.::.::e::e::e::e::s nalmrwtor 958'Cs9 3000 3099 MD 3000 SV2.19327951VDj"'_.._.._.._.._.._. .._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.:_.._.._.._.._.._.._.._.._.:_.._.._.._.._.._.._.._.._.:_.._.._.._.._.._.._.._.._.t_.._.._.._.._.._.._.._.._ atilYttibs flair E.4000 4000 O • 0 II 0) (6 Cl, 5000 ...,..... .. 5000 O 350(5511.96 IND)"_.._.._.._.._.._.._.._.._.._.._.._.._...._.._.._.._.._.._.._.._.:_.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.:_.._.._.._.._.._.._.._.._ -N51 1351295Yg-)'_.._.._.._.._.._....._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._:._.._.._.._.._.._.._.._.._ 6000 CM3(924%ND).._.._. 6000 Cry 3'700 8378 MD End Cry 7210 MD _.._.._...._.._:._._ .._.._.._ _.:_.._.. ._.._.._. .._.._.._ _.._.i_. .._.._.._ _.._.._.._.._.._... 7000 CM-1.A558.A3iVU).._.._. ...... .... ........ ......... 7000 THUMtia! 'Nb3'._.._.._.._.._.._.._.._.:.._.._..-.._..:.._.._.._.._.._.._.._.._.:_.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.i_.._.._.._.._.._.._ TJF(7615%WO) • 8000 8000 TJD 33043.95 TND1 ------------ 1915 - Tgt7 12706 MD U.3Tj'jp3g)_.._.._.._.._.._ TJB i93519$lVb)._.._.._.._.._.._._.._..� 9966160.•._.._.._.._.._.._.:_.._.._.._..Y1511YgD.._.._.._.._.._..__. .._.._.._._..7227.._.7227. . TJh(84J0.95ND)._..7227.7227..7227..-9114 ...._.._.._.._.._.._.._.._.._.._.._..7227. i :�� _._.._.._.._.._.._.._..8�.�. ..__.._.._.._qqg-�::=:::�.._.._.._.._.._.._.,_.._.._. 2272._._.._.._.._._.._.._.._.. _.._.._.._.._.._ _..7222._.: ".._.._.._.._.._.._.._.._.._.._.._.._. ._.._.. .._.._.._.._.._.._._._._.._.._.._.._.._.._.._.._.._...._.._._.._.._..__.._.._.._.._ "_._ _._.._.._.._.._.._.._.._ :.^r s.._.._.._.._..7227.7227.... 9000 •'..L....•J.'•.h.�.: 7•," -"::::-::_•:_::_::_ __:.:8::3::s:u:-,D•.ln__a:.m.:c_.:. ...--•-•—• 9000 %70 MD Cry 101100 Cry6/100 Erd Cry 9257 MD T994 End Cry 1088180 10806 MD Cry 6.51100 T18 End Cro 9674 MD 9746 MD Tgl6 12080 MD 12155MD (281080 10744 MD -1000 0 1000 2000 3000 4000 5000 Vertical Section(ft)Azim=287.439°Scale=1:1400(ft)Origin=ON/-S,OE/-W • • o \ o \ i' ( - o : ° \ ;\ 0 -§ ° e; !; \ \ \\ o & _ o - ! !) 01, Cl ° % «I I § ' \ f |}\o ! \@ \§�'-, ; iii / | ! . 2 0 1 in Lt Lt '..; Ti< /- C...-- § § - - \ , !§ I , § ( m , 6 CD , iri o »: § 7 § _ - § - ;! / � \ I Ci. ) ` `:� '.1 ^ i( \ ii ® | ; Eri) / \ k 5,,:l. i . ! | !§ � 0 ii _ co § — I\ !� _ o @ \\ `° �} 1 Lo %to ƒ ` § \ avg . 2 ; E 8 o \ z - [ \\ . . . _ ¥ 01 § ) -, 2 a »( 4 k ! / A co ' !§ !§ !_ Z. \\ NM , ° § _ Mil E-', ; / nclo :a-- § ; f in § § !! § n � ga g ; co E ` er « Will ` - � \ \ 70- of ii \ § \ ° CO I o k ) U00i1.=ales U SN 0 • -- (0 Tr -- O uo co N- N -- O N -- Lc) p , _N N _ O _ a N - O a _ -- _ — i O In o m _.- __...__ O 41 ki _ _ ,...._-- E- al 1=1 ' O - L m c1 . 1 i ,...r--- Doil_ ..:7 a - 0 Mb 0 - 22 m 11 O _ Lc)- 0 Tr N oil O a 0 0 in p co 0 W _C,-., C N -0- C C C N m (SSRSN 2 da.0_CL U 0 - 0 _ O g Lo o,n�� s wI (1.)0 Lo ilk 1 1 I I 1 I I I 1 I I I I I I I I I I I I I I 1 I I I 1 II ! 11 I I I I I I I I I I I I I I 1 I 1 I I I I I I I I I I I I I I I III 1 O o LL1 o LO o o LO o O U) O U) o N- CO CO U) CL) 7 V co co N N r (uI/iisn pi.) uoi eJedes ailueo of anuao I • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan D-35 SL 2 Project: Prudhoe Bay TVD Reference: D-35 plan©87.95usft(rigx) Reference Site: PB D Pad MD Reference: D-35 plan @ 87.95usft(rigx) Site Error: 0.00usft North Reference: True Reference Well: Plan D-35 SL 2 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan D-35 Database: EDM RSK-Alaska PROD-ANCP1 Reference Design: Plan#3b D-35 Offset TVD Reference: Offset Datum Reference Plan#3b D-35 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 5.O0usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,465.90usft Error Surface: Elliptical Conic Survey Tool Program Date 6/16/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 46.95 950.00 Plan#3b D-35(Plan D-35) GYD-GC-SS Gyrodata gyro single shots 950.00 2450.00 Plan#3b D-35(Plan D-35) MWD MWD-Standard 950.00 3,090.00 Plan#3b D-35(Plan D-35) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 3,090.00 4,590.00 Plan#3b D-35(Plan D-35) MWD MWD-Standard 3,090.00 8,710.00 Plan#3b D-35(Plan D-35) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,710.00 10,210.00 Plan#3b D-35(Plan D-35) MWD MWD-Standard 8,710.00 12,705.94 Plan#3b D-35(Plan D-35) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 6/16/2015 11:53.48AM Page 2 of 5 COMPASS 5000.1 Build 61 • • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan D-35 SL 2 Project: Prudhoe Bay ND Reference: D-35 plan @ 87.95usft(rigx) Reference Site: PB D Pad MD Reference: D-35 plan @ 87.95usft(rigx) Site Error: 0.00usft North Reference: True Reference Well: Plan D-35 SL 2 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan D-35 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#3b D-35 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 D Pad D-01-0-01-D-01 5,927.48 6,035.00 804.12 120.07 684.63 Pass-Major Risk D-01-D-01 A-D-01 A 5,927.48 6,035.00 804.12 120.07 684.63 Pass-Major Risk D-03-D-03-D-03 4,009.80 4,125.00 617.10 103.89 513.26 Pass-Major Risk D-03-D-03A-D-03A 4,009.80 4,125.00 617.10 103.89 513.26 Pass-Major Risk D-06-D-06-D-06 6,247.06 6,380.00 327.66 156.27 171.29 Pass-Major Risk D-06-D-06A-D-06A 6,247.06 6,380.00 327.66 156.27 171.29 Pass-Major Risk D-06-D-06APB1-D-06APB1 6,247.06 6,380.00 327.66 156.27 171.29 Pass-Major Risk D-07-D-07-D-07 4,629.02 4,820.00 662.34 132.90 529.57 Pass-Major Risk D-07-D-07A-D-07A 4,628.85 4,825.00 662.32 132.99 529.46 Pass-Major Risk 0-07-D-07APB1-D-07APB1 4,628.85 4,825.00 662.32 132.99 529.46 Pass-Major Risk D-07-D-078-D-078 4,631.51 4,825.00 662.68 133.37 529.46 Pass-Major Risk D-11-0-11-0-11 11,212.58 10,650.00 590.82 182.56 408.31 Pass-Major Risk D-11-D-11 A-D-11 A 10,512.18 10,135.00 730.09 157.55 578.89 Pass-Major Risk O-11-D-11 B-0-11B 9,820.77 12,003.00 642.50 174.02 474.45 Pass-Major Risk O-16-D-16-D-16 737.93 735.00 388.55 15.09 373.46 Pass-Major Risk D-16-D-16A-D-16A 736.85 725.00 388.53 15.07 373.46 Pass-Major Risk D-16-D-16B-D-168 736.85 725.00 388.53 14.91 373.61 Pass-Major Risk D-16-D-16BPB1-D-16BPB1 736.85 725.00 388.53 15.07 373.46 Pass-Major Risk D-17-0-17-0-17 755.09 750.00 283.59 13.98 269.61 Pass-Major Risk D-17-D-17A-D-17A 755.06 750.00 283.59 13.98 269.61 Pass-Major Risk D-17-D-178-0-17B 758.34 745.00 283.66 14.04 269.61 Pass-Major Risk D-18-D-18-D-18 629.82 620.00 166.03 9.81 156.24 Pass-Major Risk D-18-D-18A-D-18A 632.69 620.00 166.07 9.85 156.24 Pass-Major Risk D-18-D-18B-0-188 632.69 620.00 166.07 9.85 156.24 Pass-Major Risk D-19-D-19-D-19 568.57 560.00 56.92 10.00 46.92 Pass-Major Risk D-19-D-19A-D-19A 568.47 560.00 56.92 10.00 46.92 Pass-Major Risk D-19-0-198-0-198 570.84 560.00 56.96 9.93 47.03 Pass-Major Risk D-19-D-19C-D-19C 570.84 560.00 56.96 9.93 47.03 Pass-Major Risk D-20-D-20-D-20 683.89 665.00 47.72 13.18 34.54 Pass-Major Risk D-21-0-21-D-21 937.82 925.00 156.65 20.17 136.48 Pass-Major Risk D-22-D-22-D-22 950.68 945.00 280.88 17.89 263.00 Pass-Major Risk D-22-D-22A-D-22A 950.68 945.00 280.88 17.89 263.00 Pass-Major Risk D-22-D-22APB1-D-22APB1 950.68 945.00 280.88 17.89 263.00 Pass-Major Risk D-22-D-22B-D-22B 947.39 935.00 280.82 17.83 263.00 Pass-Major Risk D-22-D-22C-D-22C 948.66 935.00 280.84 17.85 263.00 Pass-Major Risk D-23-D-23-D-23 1,407.09 1,400.00 366.13 26.72 339.50 Pass-Major Risk D-23-D-23A-D-23A 1,405.66 1,390.00 366.11 26.69 339.50 Pass-Major Risk D-26-D-26-0-26 4,069.12 4,070.00 97.51 21.73 75.80 Pass-Minor 1/200 D-26-D-26A-D-26A 4,069.12 4,070.00 97.51 21.73 75.80 Pass-Minor 1/200 D-26-D-266-D-266 4,066.46 4,065.00 97.45 20.93 76.54 Pass-Minor 1/200 D-27-D-27-D-27 954.32 940.00 217.72 17.92 199.81 Pass-Major ' D-27-D-27A-D-27A 954.33 940.00 217.72 17.76 199.96 Pass-Major Risk D-28-D-28-D-28 4,008.56 3,985.00 342.77 52.74 290.30 Pass-Major Risk D-28-D-28A-D-28A 4,006.40 3,990.00 342.76 52.73 290.30 Pass-Major Risk D-28-0-28AL1-D-28AL1 4,006.40 3,990.00 342.76 52.73 290.30 Pass-Major Risk D-28-D-288-0-286 4,006.40 3,990.00 342.76 52.56 290.47 Pass-Major Risk D-28-D-28BPB1-D-28BPB1 4,006.40 3,990.00 342.76 52.73 290.30 Pass-Major Risk D-31-D-31 B-D-31 B 9,114.78 11,370.00 495.66 169.00 372.87 Pass-Major Risk 6/16/2015 11 53.48AM Page 3 of 5 COMPASS 5000.1 Build 61 • 0 BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan D-35 SL 2 Project: Prudhoe Bay TVD Reference: D-35 plan©87.95usft(rigx) Reference Site: PB D Pad MD Reference: D-35 plan @ 87.95usft(rigx) Site Error: 0.00usft North Reference: True Reference Well: Plan D-35 SL 2 Survey Calculation Method: Minimum Curvature Well Error: 0.O0usft Output errors are at 1.00 sigma Reference Wellbore Plan D-35 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#3b D-35 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 H Pad H-04-H-04B-H-04B 12,670.85 12 694.91 1,397.81 230.10 1,170.71 Pass-Major Risk H-07-H-07-H-07 Out of range H-07-H-07A-H-07A Out of range 1 6/16/2015 11:53:48AM Page 4 of 5 COMPASS 5000.1 Build 61 • • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan D-35 Project: Prudhoe Bay TVD Reference: D-35 plan©87.95usft(rigx) Reference Site: PB D Pad MD Reference: D-35 plan©87.95usft(ngx) Site Error: 0.00usft North Reference: True Reference Well: Plan D-35 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan D-35 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#3b D-35 Offset TVD Reference: Offset Datum Reference Depths are relative to D-35 plan©87.95usft(rigx) Coordinates are relative to.Plan D-35 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:1.17° Ladder Plot 1600- I ! I I I 4bJ r 3 1200- -' - -A'*'4' / j �� _, , „„_„ , ,,,_ _, .2. .., ......t. i 4,1 . , 1 i a. Ill 800- � �.. ��claw� r ' � : r Alikd.4Pir ' A N 400- - -"� - - ' -- -........ 0 o _ r. - ' Via . � J .Jt�- 0 I I lFC; NI)I I I 1 0 2500 5000 7500 10000 12500 15000 D-01,D-01,D-01 V1 -6-Ailt YSEFEt17 1a'1%1ptX7 500 ustD-23,D-23A,D 23A V2 i� ' D-01,D-01 A,D-01 A V3 -X- D-17,D-17A,D-17A 3 -g- D-26,D-26,D-26 V3 U-U.5,U-U3,LYU3 V1 U-1(,U-1/13,U-1/B V13 * U- b,U-2bA,U-2bA V1 -9- D-03,D-03A,D-03A V1 -9- D-18,D-18,D-18 V17 -a- D-26,D-26B,D-26B V6 - ,' D-06,D-06,D-06 V1 - D-18,D-18A,D-18A V11 -t- D-27,D-27,D-27 V1 -"tr. D-06,D-06A,D-06A V3 - - D-18,D-18B,D-18B VO D-27,D-27A,D-27A V3 D-06,D-06APB1,D-06APB1 V5 -a- D-19,0-19,D-19 V6 D-28,D-28,D-28 V2 D-07,D-07,D-07 V3 -e- D-19,D-19A,D-19A V2 -01E- D-28,D-28A,D-28A V0 $ D-07,D-07A,D-07A V2 $ D-19,D-19B,D-19B V2 $- D-28,D-28AL1,D-28AL1 V0 n'.7.,'' D-07,D-07APB1,D-07APB1 VO D-19,D-19C,D-19C VO -0-- D-28,D-28B,D-28B V0 0-07,D-07B,D-07B V1 -9-- D-20,D-20,D-20 V1 $ D-28,D-28BPB1,D-28BPB1 VO -0- D-11,D-11,D-11 V1 $ D-21,D-21,D-21 V1 D31,D-31B,D-31BVO D-11,D-11 A.D-11 A VO -24- D-22,D-22,D-22 V2 -9- H-04,H-04B,H-04B VO 7/27/2015 2:10.•52PM Page 5 of 5 COMPASS 5000.1 Build 61 • Project: Prudhoe Bay • Site: PB D Pad Well: Plan D-35 SL 2 Wellbore: Plan D-35 Design: Plan #3b D-35 From Colour To MD 47 -- 500 From Surface to 3100'md (9-5/8") 500 1000 Scan interal 25 ft 1000 1500 Scale 1 inch : 50ft 1500 2000 All wells pass the major risk 2000 2500 See AC summary report for details 2500 3300 3300 3700 _ 0 3700 4100 :..-� 4100 4700 -- - -- ,::y�vtVtt7f�`I� 4700 5200 330 .. ra,.��..4`4i��w ,4 , 30 5200 7800 • ---- - -- ------ ;�ID��.�10. 7800 8200 12 8200 9200 9500 9800 a�►..4 9500 10• •I+4i��iigi-b,►`��`.�`�: liftettikttiiYilPeVY 9800 12710 300 60 7 !lil•�i•�. iiii41.e!►oo Nit000. +AQo'Ioo.�oo gc, ' �r�� , N`�1to ti�%;:ives� ;. p 6, r r r r ii r ,.... /__. ,./ /.. :,,, ,..,.. ,,,,,-..,:._,., ,./ .../....--...-- ...------.._.___ -,--:,,",,,-,#littlitAlAts's 44 4. 4' tlroArfrilrl7,ilfilt,---, . , , , :: i if i i i , : / ! i / i :: i ,... ,,,. ,....-- --... .•., ••.: ,. ... ., „. ., , , : : , ,( 270 -_. - � t2 jy 90 . • 2 _ Ji_ ♦1t0;r1101v1�ti tffrelafiraiR3r9 '' �'/ ��I�llt,,�f��`- ii? a� � ,�ar�ii�n��GAPAaK • r 24075 - /��t+e+.o:�� >!0:��S�s�4��,�S��120 10� 210 150 150 180 Azimuth from North [°]vs Centre to Centre Separation [40 usft/in] �� Project: Prudhoe Bay �� Site: PB D Pad Well: Plan D-35 SL 2 Wellbore: Plan D-35 Design: Plan #3bD-35 From Colour To MD 47 — mm From 3OOO'md (S'5AI)0o88DU'md (7^) 500 -- 1000 Scan interal 25h 1000 �--- 1500 Scale 1 inch :5O� 1500 2000 All wells pasthe majorisk 2000 2500 D-26/A/B has been risk based at 1:200 See AC summary report for details 2500 3300 3300 3700 _ 3700 4100 o 150 4100 4700 • 4700 5200 5200 7800 09/40 ---*---.1*-- ----,;.,,-- :----'..:.:.-..... _,,_.:"......._.._:___:11-_-..- .i1::::::::;;':......_11. .., , 30 '47.t.11 .101wr vrki4-7*--,_, . ----/------1::::::-..:::::.:,,-..„ 8200 9200 AO 1j 101,-44,MLArAlkirititYIP .---' . .:1111N11.:.''''. i T 9500 9500 9800 9800 12710 4V417 vrif rif r rijimoili.. ,; „,,,,4.44100,10ti,-,,,,_ 7."--7-t.-4414,4„,44,04110111 4741110-ir '..-likoiti 41.. ,...,,..„,. ..., ... ..........- ..,,_-_„Ai.411,,,,,v i r Ti riiiiii.--,,,,... ..,.' At. ...'„./.,,,.>:'.'..,/.../,11/::::':: ,.-'.:':1,--"--- ..--- -- 4*-'_. --*----4.1441._41,,iti,44,4 4#4V41Ailigillitiaiwat•:$ 270 »« 14.7,0*,.:+114VOte,140/ViliklalivOloselp,4114104/V 4*14411k.T4i1914tliklikiliVilligehtl !t.A.Itfra,4_!::It, 44 4 .r l'iols '1, ,s i .4,..,..1.,,,T7,1440. .A,0 210 114 1 it:1 tk Valkil V.IVItArrrkiii, tifilkill.-' iAtst"rirt,'''iliA lit 4110111\I ‘ . 4.44111131/AttilrAt ill III 1 80 Azimuth from North [O]vs Centre to Centre Separation [40 usft/in] 0 Project: Prudhoe Bay • Site: PB D Pad Well: Plan D-35 SL 2 Wellbore: Plan D-35 Design: Plan #3b D-35 From Colour To MD 47 500 From 8700'md(7")to TD 500 1000 Scan interal 25 ft -moo - 1500 Scale 1 inch :50ft 1500 2000 D-26/A/B fails the major risk 2000 2500 D-26/A/B has been risk based at 1:200 See AC summary report for details 2500 3300 3300 3700 _ 0 3700 4100 4100 4700 4700 5200 I� 5200 7800 330, 1Ortirifilfir.:',..: 30 7800 8200 8200 9200 9200 9500 .� 9800 92000 . .. . . . . . . „ . . „. . . .. - . _ " .• .- , .- .__ 300 , . ..., ... ... ��®® ® 60 ,../ :/""-.-/---/.. ,./ ,i: ,•••• ,•:: ,•••/''?.../. ../ ..././..../..--'''' ..---- - ------ .'"''.64414,,.. ‘11%Mill&1111111101.md1111$1001110, . • - ------.• --.. .•.. ''.. :,-.--', .... -.....kizait.iiii.111,Tikikillt- 270 90 5, - 2407 120 10' 12 210 150 ..-- -- - , 1st 180 Azimuth from North [0]vs Centre to Centre Separation [40 usft/in] 11110 11, Proposed Well Schematic - VELLHEAD= MCI 'P rTx? D-35 Proposed BF f;Pi= I kkr An* 421 2.1-6;—CONIXLIOR -se I TB +19 5111:TA MRT il_md CkiINITINO=10340 Us x 82/50 —2000' H4 1..2'1ES KW(0-3 ai3- Donm1VDEs=9080' GAS LII MAFWELs sr IVO DEVI ,r1U1 l'E 4 1130 11304 5%r 3 MO TBD 19-5filr 40S/L80 8TC 0.0.835' Ft 2700" 2 TRO TBD 1 MO TBD ytyr IN 3 « 1 4 8888 F14 wEs x trp LI-3 an- I • —1 8708tINIW3U"' .F.777 14745 1-14 ur I X NP D-3 313- M 5-- 87W 4 1/2HES X N NW -3 722:1 8$2$ r X 5'EIKR zxr MR tGR w MED 4 1(2' i2 Eas I IC,RS V T 052 bpf 9Sit' a-7 8834' 1-*Wrr- ---„,...„ • ?kr! k VT cr1)114,44 1" -77r. \ 8478"MD 8834' H IOC of Ftd Cemented Liner I f 11 FT,/PIY OCYMAIRITS nATF REN BY pructrin Bay LW = di Proposed Con pletion WELL D-35 _ —______ fERMirt * AR HD SEDGX TIAIPMNRXXE FSL MO('Fa>oc(' SP Exploration Was la) Parker 273 BOPE Schematics • = e ri I? i gg RW Y me n i 3 lal = 4 1 8 q' " gl b � " $ � 3 g 11 r, o s� F A R g TRI Cyj �k8 IC s1t Y } Y 3i S E E R 2 Li14 a [.1.--VA e,` = . z"° gtyax I a 6 3 X i 3 I $ a T> R Aaa a6, I �" 1 l \ mj i _ — -------- — wV Fri —1:-J-_-_-_-__-: -- ----T ------ ---- 1 5 V � I I i j €16.o 4Y ti 1 I i I T iihi w L, __ - -....... __ _ I 1 . . :,'1 . .\ i , 1 /I 0 i 11\1 il ' i i r=m\iii gE, , . ti i s i ! ti j J■ i �. .,. r RQ— ---— . 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I -- - - --- - 1411 1TT1 as li; S b `st 4 Iu_, 1 5 � s.g°4 I I I ‘ 11111 '7A,7,'.: fib; tisi f �{� ..:..„:10;4,.;1, h \ g IloilY !!y c. H C `o g i U 3 oi I w u iQ sxw • • Diverter Layout 0-Pad Well 0-35 53 3 leI 9• 5', le"d erter 101,16" 411,0e,16" 5,5'.22 deEyee JT diverterJT diverterff " JTfactng up --- * 0 3 le a ---- 291 21 IT s M." Radius at the end of ° 148' Y6 t the divertv ,15:4:8 12• • I 4 • • Entef E.' V • ,',ELL A WELL INJECTOR DATE 0318,20151 SCALE 1"z 275 1`,1A,r)DATF 701,1 PBU D PAD F','Curren and Service,ffiorynaton please Alias ritip alasia,14s Wellhead Schematic 1 I FIth-SMO r11-11:".E7...%9 (KIT 111111111 1111 MIa IIL ILII II ii ,iic ` 4.,.' r .. —TEST rCoRT II9.15 :a: I .� .i 21W.0 11.94 la TEy7 ”3,11 1 _r;:-=_---__, f1 �� IC L6C1.770/h SCREI*S f •• 1II-�7 ,1 // in ,■ ills 2 Ii5-CCC 1433 120 Ci SCSSv EXIT—// • rr 15_75 1 : `moi. 1 I.3•. N.... .r. 1; �� i `,"ti ":_ Iia FA' t�lr:.-;j I ;� R' I�' %,..11 _ '} 333.25 +.CE Z' - - TEST r PT -�� /'.. I IC LUClI]Rh SCflERS _—11-S3b3:4-541 ■I �J �MMI 111!__– a Ithi- 53 Ref 123 c4 22.TS ra IIf 41,732_,I , i L r2. ;i, III (' 3 .._3 , c r =II;KAT t!41?ER II IE`.:R1,11:m I _ I 3-21.19-1.130 314109TCR Lb4DIh.RING 2 "133.3 2-Mira 9 9/4 C&51hr.R54GC9 .IT2C74 5LIr-I4 LOC 14G RING 4 .155919 :1514:Mill CSSW8LY _ 9 2-lav-r1R :{T.3 T-a14c.man es,EER<T • .4.12 F'-C41.1a r re,t.Il.Nta4.E' ?CP 40 CAS IK 193-315 ''eF.R1'PF air.aV&T - 4 .151953 P.414:.W m:E.sccE74IL1 y 32-'-O4T-5I3 P.@14.IEi tC PTER i'sE.RLr Ic+ 2-_93-17' g rr9 r.-21 r:.51++'.H+ Ep 9 ' co5S' Ca51RG 11 r1 IL13/-CC45 ?QL,.IFFLE I2 7-013-117 T:-21:..5514'„,N.i'E'K 1'33 .h'Str& K I/F 30 :45,1,0 At I::HC?.4GE, AK. — 2f: x li, '_.ib x t t 4 I"2 REFI U1110204x34tl r-- i 12OL110B0696 .,.0 -a112.TL 21.0.491991DITNL wm WIEPalii Mill Ki-3N6 raRSoIeft 0 K 4L. ..K1 I.1.14 KDEAL TICN RELLFE40 San. :.w. f'] .. ....a... ITN..%'PP 0.111 n rw,r�R.. e. '.''9 x 9 -.en X r x 4 I a; r,-.w.d 5«011 FRIFINEMI, 4111111 t rwaw.� .444«w ..,,.....1..,,.....1. II-50Cti =OMpLETION ""' 29-.41/2........,�r- , �ii mar 11•41112 . -,i'' .,. ❑Mlco in6Tll Cr= o�.mo G 'PUCK • • Tree Schematic r 29.91 'PH41/16-sem I 0 r4 1/i5-5D 0 443C, x23 CV c - '\:\ \OS1./..wl '1-.117-'---:I. 1 )---- 111, [ op r I' i y 1 42.25 \ �/��} 101111r 4 u,6-5300 WOG 120 Ov 4_", �1 _.,...4 1/4.5000 MIXT 120 Gv IC 93.12 jF lib 4119 17 frTrt"1 „7/1fc-------r-------'7( „ —4 1rif,5aC0 WO 24 AV 11 _ �` I1 t - l T ti 0 0 .. PR'AV ANS:IpflCi Ntlk K some Govivir} C.° a...eC; _....�.. 4 /16-5000 'FLEE ""..� "° 0 W/ 4 I/16°5400 WING S ' _ e.,Y MP MP.,.an rt • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. S • TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: 2-/S-- (3 V Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: c C tib . POOL: G 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 4110 • El N , O O a) a N N , E , • 5 , : 0 4 p> m a c ' a' • : : I U) O cim' Si E rn Mx , an o N. O. -o 00 0 as a_ , N. O 'V, a> , , c, co L' O 0 a �� a, N. in o O 0" c. .c 0 O04 N v 3. a 2, c Y, No o, 00 � 'O j� .N p� O� p, Zp a; , a .@ O a 1 E, a O U d m ., w a ,n N o �, °� 4 m, a rn' ai a E c' °° U) (a a O -,1 = a) r, 0 a 3' O CO M' a) o f I o >' 0, r' a): p, ay M' E �� y'. 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