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Home My WebLink About214-1207. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU Y-14C OA Squeeze, Wellhead Sealant Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-120 50-029-21832-03-00 13425 Conductor Surface Intermediate Liner Liner 8994 80 2654 5990 4689 3015 13339 20" 13-3/8" 9-5/8" 7" 4-1/2" 9006 36 - 116 36 - 2690 34 - 6024 5870 - 10559 10408 - 13423 36 - 116 36 - 2689 34 - 5735 5615 - 8882 8763 - 8994 None 2260 4760 5410 7500 None 5020 6870 7240 8430 11949 - 13339 4-1/2" 12.6# 13cr85 32 - 10417 9004 - 9006 Structural 4-1/2" HES TNT Perm Packer 10290 8671 Torin Roschinger Operations Manager Oliver Sternicki oliver.sternicki@hilcorp.com (907) 564 4891 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028287 32 - 8770 OA at surface / IC Test void in Wellhead Pump 0.75-gallons of Welllock. Final pressure 2500-psi. / Pump 1/4 cup Greenstick packing. Final Pressure 3500-psi. 84 281 1651 5278 499 888 1370 1664 276 294 323-595 13b. Pools active after work:Prudhoe Oil No SSSV Installed 10290, 8671 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:26 am, Jan 19, 2024 Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2024.01.18 09:07:20 - 09'00' Aras Worthington (4643) ACTIVITY DATE SUMMARY 11/12/2023 T/I/O = SSV/120/30. Temp = SI. Bleed IAP & OAP to 0 psi (Pre Wellock). ALP = 1600 psi, AL SI @ casing valve. IA FL @ near surface. OA cemented to surface. Bled IAP to BT from 120 psi to 0 psi in 2 min, 0.7 bbls. Held open bleed on IA & OA during valve shop removing OA casing valve & installing 2" 1502 hardline. Final WHPs = SSV/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:30 11/14/2023 T/I/O = SSV/60/0. Temp = SI. Wellock OA (repair SC leak). ALP = 1700 psi, SI @ CV. IA FL near surface. Bled IAP to BT from 60 psi to 0 psi in 2 mins (FTS). Pumped ~0.75 gal Wellock into 03:00 OA port. Pressure held @ 2500 psi for 1 hr. OAP dropped off to 300 psi when it was opened to a gauge. Increased OAP to 1500 psi using gas accumulator. IAP increased 20 psi during the day. Final WHPs = SSV/20/1500. SV, SSV, WV = C. MV = O. IA, OA = OTG. 16:30 11/15/2023 T/I/O = SSV/60/1050. Temp = SI. WHPs (eval Wellock). ALP = 1750 psi, SI @ CV. Bubbling in 12:00 & 6:00 flutes. Sniffed 1' & 1" above conductor (0% LELs). Increased OAP to 1750 psi with lift gas. Heater working and in wellhouse with door propped open. Final WHPs = SSV/60/1750. SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:00. 11/16/2023 T/I/O = SSV/60/1050. Temp = SI. WHPs (eval Wellock). ALP = 1750 psi, SI @ CV. Bubbling in 12:00 & 6:00 flutes. Sniffed 1' & 1" above conductor (0% LELs). Increased OAP to 1500 psi with lift gas. Heater was not working, non mobile notified to bring another heater ASAP and place trunk in wellhouse and to leave door open. Final WHPs = SSV/60/1500. SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:30. 11/16/2023 T/I/O = SSV/70/1450. Temp = SI. WHPs (eval Wellock). ALP = 1750 psi, SI @ CV. Bubbling in 12:00 flute. Sniffed 1' & 1" above conductor (0% LELs). Increased OAP to 1500 psi with lift gas. Working heater is staged and wellhouse door propped open. Final WHPs = SSV/70/1500. SV,WV, SSV = C. MV = O. IA, OA = OTG. 12:15 11/18/2023 T/I/O = SSV/60/350. Temp = SI. WHP's (eval wellock). ALP = 1380 psi, SI @ CV. Light bubbling @ 12:00 & 6:00 in conductor. Sniffed 1" and 1 ' acove conductor (0% LEL). Heater is non functioning, called for new heater. Increased pressure on accumulator to 1380 psi. SV, SSV, WV = C. MV = O. IA & OA = OTG. 16:30 11/19/2023 T/I/O = SSV/120/2,000. Temp = SI. WHPs (eval wellock). ALP 1680, SI @ CV. Light bubbling @ 12:00 flute only. Sniffed 1' and 1" above conductor (0% LEL). Dropped IAP to N2 hose/accumulator to 1,500 psi. Wellock samples on location are stiff but not set up yet. Heater is working and wellhouse door propped open. Final WHPs = SSV/120/1500. SV, WV, SSV, MV = C. IA, OA = OTG. 13:00 11/20/2023 T/I/O = SSV/150/1000. Temp = SI. WHPs = (eval well lock). ALP = 1680 psi SI @ CV. Re-Pressured CNG hose back up to 1500 psi, and applied 1500 psi to OAP. Well lock samples are still soft. Heater installed in well house and working with door propped open. Final WHPs = SSV/150/1500. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 11/21/2023 T/I/O = SSV/160/1200. Temp = SI. WHPs (Eval Well Lock). ALP= 1600 psi SI @ CV. Re-Pressured CNG hose and applied 1500 psi to OAP. Small sample is hard and large sample is firm and will not move. Heater insalled in wellhouse and woking with door propped open. Final WHPs = SSV/160/1500. SV, WV, SSV, MV = C. IA, OA = OTG. 15:30 Daily Report of Well Operations PBU Y-14C Daily Report of Well Operations PBU Y-14C 11/22/2023 T/I/O = SSV/160/1300. Temp = SI. WHP (eval Well Lock). ALP = 1600 psi, SI @ CV. Small sample seems to be firming up, large sample still soft to the touch. Heater installed in WH and working, WH door propped open. Final WHPs = SSV/160/1300. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 11/23/2023 T/I/O = SSV/160/1450. Temp = SI. WHPs (eval Well Lock). ALP = 1600 psi, SI @ CV. Both large and small samples have set up. Increased OAP to 1500 psi. Heater insalled in wellhouse, working and door propped open. Final WHPs = SSV/160/1500. SV, WV, SSV, MV = O. IA, OA = OTG. 12:30 11/27/2023 T/I/O = SSV/160/900. Temp = SI. WHP's (eval wellock). ALP = 1550 psi SI @ CV. Both large and small samples of wellock are set up. Bled off accumulator and removed 2" hard line cap, wellock is set up. Removed both hard 90's and comfirmed wellock is cured. Re-installed hard line caps and gauge. Heater is still in well house and operating properly w/ well house door open. SV, WV, SSV = C. MV = O. IA & OA = OTG. 14:00. 12/3/2023 T/I/O = MV/160/0. Temp = SI. Bleed IAP (pre Greenstick). AL = 2000 psi, SI @ CV. Heater working properly. Spray in liner installed in cellar. IA FL @ surface. Bled IAP to BT to 0+ psi, held open bleed for 1.5 hrs (0.2 bbl). No monitor. Final WHPs = MV/0+/0. SV = C. WV, SSV, MV = LOTO. IA, OA = OTG. 05:00 12/3/2023 T/I/O = MV/0+/0. Temp = SI. Greenstick-IC, PPPOT-IC **PASS** (Under Eval). ALP = 2000 psi, AL SI @ casing valve. Used 1/8 of packing gun to re-pack IC void. Pack test void to 3500 psi for 30 min. 1st 15 min lost psi, 2nd 15 min lost 0 psi (PASS). Close in hoke valve. SV, SSV = C. WV, MV = LOTO. IA, OA = OTG. 13:00 12/4/2023 T/I/O=SI/1800/0. Post Wellock. Removed block valve and integral from working side OA, installed gate valve, torqued to specs. Removed integral from companion side OA and installed blind with Alemite fitting. NO VR plug in comp OA. Job Complete. FWP's SI/1800/0 12/9/2023 ***WELL S/I ON ARRIVAL***(pull ttp) EQUALIZE AND PULL 4-1/2" XXN-PLUG IN XN-NIP @ 10,399' MD ***WELL LEFT S/I ON DEPARTURE*** 12/24/2023 T/I/O = 280/1600/0. Temp = 74°. WHPs (eval SC leak). AL online. Spray in liner installed. No bubbling detected in conductor. LEL = 0% from 1' & 1' above flute @ 09:00 position. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:30 12/24/2023 T/I/O = 280/1610/0+. Temp = 95°. WHPs (eval SC leak). AL online. Spray in liner installed. No bubbling detected in conductor. LEL = 0% from 1" & 1' above flute @ the 09:00 position. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:30 12/25/2023 T/I/O = 280/1600/0+. Temp = 85°. WHPs (eval SC leak). AL online. Spray in liner installed. Bubbling in conductor flutes at the 12:00 position. LEL = 0% from 1" & 1' above flute at 12:00 position. SV = C. WV, SSV = O. IA, OA = OTG. 14:30. 12/28/2023 T/I/O = 270/1570/VAC. Temp = 97°. WHPs (eval SC leak). AL online. Spray in liner installed. No bubbling detected in conductor. LEL = 0% from 1" & 1' above flute @ the 09:00 position. IAP decreased 30 psi, OAP went on VAC from 12/25/23. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:30 Daily Report of Well Operations PBU Y-14C 12/30/2023 T/I/O = 290/1560/VAC. Temp = 94°. WHPs (eval SC leak). AL online. Spray in liner installed. Small bubbling at 12:00 position. LEL = 44% from 1" inside conductor & 0% at 1' above conductor @ 12:00 position. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:00 12/31/2023 T/I/O = 290/1560/VAC. Temp = 97°. WHPs (eval SC leak). AL online. Spray in liner installed. No bubbling detected in conductor. LEL = 2.4% inside & 0% 1' above 12:00 flute. WHPs unchanged overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:00 1/14/2024 T/I/O = 300/1560/0. Temp = 72°. WHPs (eval SC leak) sniff cellar for LEL. ALP = 1560 psi, online. No bubbling detected in conductor. Fluid in 9:00 and 12:00 flutes. LEL = 0% inside & 0% 1' above flutes. SV = C. WV, SSV, MV = O. IA, OA = OTG. 00:30 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Tuesday, January 16, 2024 2:58 PM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Oliver Sternicki; Torin Roschinger Subject:OPERABLE: Producer Y-14C (PTD #214120) OA re-pressurization resolved Attachments:Y-14.docx Mr. Regg, Producer Y‐14C (PTD #214120) was put on production 12/19/23 post OA well lock and IC void greenstick treatment. Monitoring during this period has resulted in no surface OA casing pressure and no persistent bubbling that would indicate a surface casing leak. The well is now classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity Sent: Tuesday, December 19, 2023 7:26 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Producer Y‐14C (PTD #2141200) OA Wellock complete Mr. Regg, Producer Y‐14 (PTD #2141200) OA well lock squeeze was completed on 11/27/23 to resolve OA re‐pressurization and bubbling in the conductor. A passing PPPOT‐IC post green stick was completed on 12/03/23 to resolve possible IAxOA through the wellhead. The tubing plug has been removed and operations is ready to put the well on production. The well is now classified as UNDER EVALUATION and on a 28 day clock to evaluate OA re‐pressurization. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. PBU Y-14CPTD 2141200   1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Tuesday, December 19, 2023 7:26 AM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Oliver Sternicki; Torin Roschinger Subject:UNDER EVALUATION: Producer Y-14C (PTD #2141200) OA Wellock complete Mr. Regg, Producer Y‐14 (PTD #2141200) OA well lock squeeze was completed on 11/27/23 to resolve OA re‐pressurization and bubbling in the conductor. A passing PPPOT‐IC post green stick was completed on 12/03/23 to resolve possible IAxOA through the wellhead. The tubing plug has been removed and operations is ready to put the well on production. The well is now classified as UNDER EVALUATION and on a 28 day clock to evaluate OA re‐pressurization. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 4, 2022 10:22 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: Producer Y‐14C (PTD #2141200) Secured with TTP Mr. Regg, Slickline set a TTP on 10/03/22 and a subsequent CMIT‐TxIA passed to 2640 psi. The well will now be classified as NOT OPERABLE and will remain secured while the OE evaluates repair options to remedy the OA re‐pressurization. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: PB Wells Integrity Sent: Sunday, September 18, 2022 9:36 AM CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. PBU Y-14CPTD 2141200 2 To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Producer Y‐14 (PTD #2141200) Sustained OA casing pressure above MOASP Mr. Regg, Producer Y‐14 (PTD #2141200) was reported by operations to have OA pressure over NOL ~1016 psi on 09/17/22 and bubbling in the conductor. At this time, the well is classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Bleed IAP / OAP to 0 psi. OA injectivity test / Leak depth determination using N2 2. Well Integrity / Operations Engineer: Evaluate economics / repair options Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: John Conrad <John.Conrad@hilcorp.com> Sent: Friday, June 24, 2022 1:00 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: RE: OPERABLE: Producer Y‐14 (PTD #2141200) Sustained OA casing pressure above MOASP All, Per the evaluation plan below, Y‐14 OA has remained flat after green stick into the IC void, bleeding while shut in as well as remaining flat/stable after BOL 6/22. The well will now be classified as OPERABLE. Thank you, John Conrad filling in for Andy Ogg Well Site Supervisor Cell: 406‐544‐6684 H: 7436 Alt: Brenton Nicholson Hilcorp North Slope, LLC 3 From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, June 15, 2022 9:28 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer Y‐14 (PTD #2141200) Sustained OA casing pressure above MOASP All, Producer Y‐14 (PTD #2141200) was reported to have OA casing pressure above MOASP on 6/12/2022 after being shut‐in on 06/09/22. The reported pressure was 1032 psi. The Y‐14 OA was cemented to surface during a rotary sidetrack in 2014 to repair a surface casing leak. Additional OA down squeeze jobs have been completed with squeezecrete and twice with wellock to mitigate bubbling the conductor. It is suspected that when the well is shut‐in and cools down, pressure communication between the IA and the OA occurs across the wellhead. The well will be classified as UNDER EVALUATION and is on a 28‐day clock for diagnostics and attempt to repair the OA repressurization. The MOASP excursion requires AOGCC reporting and will be handled by Well Integrity. Plan forward: 1. DHD: Monitor SI BUR 2. DHD: Greenstick IC pack‐off 3. DHD: Monitor SI BUR 4. OPS/ DHD: POP well, monitor for IAxOA comm 5. Well integrity Engineer: Additional diagnostics as needed Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, February 12, 2022 5:19 PM To: Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis 4 <sgolis@hilcorp.com> Subject: OPERABLE: Producer Y‐14 (PTD #2141200) MIT‐T Passed All, Producer Y‐14C (PTD #2141200) passed MIT‐T on 02/12/22 post GLV work during LDL. The passing MIT‐T resolves the previous TxIA communication and verifies the primary well barrier. The well remains secured with a TTP and is now classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, February 9, 2022 6:02 AM To: Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Producer Y‐14 (PTD #2141200) Under Evaluation clock extended 28 days. All, Slickline set different configurations of DGLVs but could not obtain a passing MIT‐T. E‐line has been scheduled to perform a Leak Detect Log but is currently delayed due to inclement weather. The Under Evaluation clock will be extended for 28 more days to allow sufficient time to complete the LDL and perform any follow up diagnostic work. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, January 21, 2022 2:57 PM To: Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator 5 <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer Y‐14 (PTD #2141200) TxIA communication All, Producer Y‐14C (PTD #2141200) was found to have TxIA communication during failed MIT‐T on 01/12/22. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity Sent: Friday, November 26, 2021 8:40 AM To: Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer Y‐14 (PTD #2141200) OA Well Lock Pumped All, Producer Y‐14C (PTD #2141200) was put on production 11/08/21. There has been no OA re‐pressurization or bubbling in the cellar post wellock. The well is now classified as OPERABLE and can remain online. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 6 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, November 4, 2021 7:16 AM To: Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Producer Y‐14 (PTD #2141200) OA Well Lock Pumped All, The OA Well Lock downsqueeze was performed on 10/29/21. Once the Well Lock has cured, the well will be POP’d and monitored for cellar activity. The Under Evaluation has been extended another 28 days. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, October 7, 2021 7:34 AM To: Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Producer Y‐14 (PTD #2141200) Possible SC leak All, Sundry approval has been obtained to pump an OA downsqueeze with Well Lock. The Under Evaluation clock will be extended 28 days to execute the job and perform follow up diagnostics. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC 7 Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: Alaska NS ‐ PB ‐ Field Well Integrity Sent: Thursday, September 9, 2021 3:49 PM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska JMS User <akimsuser@hilcorp.com>; Alaska NS ‐ PB ‐ EOC Specialists <PBEOCSpecialists@hilcorp.com>; Alaska NS ‐ PB ‐ Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; Alaska NS ‐ PB W ‐ GC1 ‐ Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; Alaska NS ‐ PB W ‐ GC1 ‐ Foreman <PBWGC1Foreman@hilcorp.com>; Alaska NS ‐ PB W ‐ GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; Alaska NS ‐ PB W ‐ GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; Alaska NS ‐ PB W ‐ GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; Alaska NS ‐ PB W ‐ GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; Alaska NS ‐ PB W ‐ GC3 ‐ ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com> Subject: UNDER EVALUATION: Producer Y‐14 (PTD #2141200) Possible SC leak All, Producer Y‐14C (PTD #2141200) was found to have slow bubbling in the conductor with LEL readings at 7% on 09/04/21. The well is now classified as UNDER EVLAUTION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Bleed IAP / OAP to 0 psi 2. Well Integrity: Pump wellock into OA 3. Well Integrity: Further diagnostics as needed Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, November 8, 2019 2:38 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Haffener, Jordan <Jordan.Haffener@bp.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO 8 Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Producer Y‐14 (PTD #2141200) Greenstick packing remedied OA repressurization All, Producer Y‐14 (PTD #2141200) was made Under Evaluation on 08/17/19 for anomalous outer annulus repressurization above NOL and a failed TIFL. Primary barrier integrity was confirmed on 09/25/19 and Greenstick packing was pumped into the IC void on 09/28/19. A scheduled OA downsqueeze with Well Lock was put on pending after it appeared the Greenstick job remedied the OA repressurization. On 10/23/19 Slickline pulled the TTP and the well was put on production. Follow up monitors have confirmed the well does not exhibit OA repressurization. The well is now classified as OPERABLE. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 9 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, October 12, 2019 10:57 AM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Haffener, Jordan <Jordan.Haffener@bp.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R 10 <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: UNDER EVALUATION: Producer Y‐14 (PTD #2141200) 28 day Under Evaluation clock extended All, Producer Y‐14 (PTD # 2141200) was made Under Evaluation on 08/14/19 to address sustained OA casing pressure above NOL and TxIA communication. On 09/25/19 Slickline set a TTP, DGLVs and Fullbore performed a passing MIT‐T to 2,710 psi and passing CMIT‐TxIA to 2,661 psi proving the primary barrier has integrity. On 09/28/19 the wellhead technician pumped green stick packing into the wellhead IC void. The initial plan was to perform a Well Lock squeeze after packing the IC void with green stick. However, the Inner Annulus was pressured up with lift gas and it appears the Outer Annulus repressurization has been remedied with the green stick packing. The Under Evaluation clock will be extended to POP the well and monitor for OA repressurization. Plan Forward: 1. Slickline: Pull TTP 2. Operations: Put on production 3. DHD: Monitor 4. DHD (pending): perform OA Well Lock downsqueeze 5. Well Integrity Engineer: Additional diagnostics as needed Please respond if in conflict. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, September 14, 2019 1:41 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Haffener, Jordan <Jordan.Haffener@bp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Oshiro, Joleen <JOLEEN.OSHIRO@bp.com>; Stone, Christopher <Christopher.Stone@bp.com>; Youngmun, Alex <younak@BP.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J 11 <Aras.Worthington@bp.com> Subject: UNDER EVALUATION: Producer Y‐14 (PTD #2141200) 28 day Under Evaluation clock extended All, Producer Y‐14 (PTD # 2141200) was made Under Evaluation on 08/17/19 to address possible TxIA communication before making the well Not Operable and performing a Well Lock downsqueeze on the outer annulus. Efforts to perform a warm TIFL have not been successful because of the pad shutdown. Operations is beginning to bring the pad back online so the Under Evaluation clock will be reset to perform the warm TIFL and any additional diagnostics. Plan Forward: 1. Cameron Well Head Tech: Perform PPPOT‐IC. 2. DHD: warm TIFL. 3. Well Integrity Engineer: Additional diagnostics as needed to remedy any TxIA communication. 4. Well Integrity Engineer: Reclassify as Not Operable. 5. Anchorage Engineers: Evaluate for OA Well Lock downsqueeze to mitigate OA repressurization. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, August 17, 2019 4:05 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Haffener, Jordan <Jordan.Haffener@bp.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: UNDER EVALUATION: Producer Y‐14 (PTD #2141200) sustained OA casing pressure above NOL All, 12 Producer Y‐14 (PTD # 2141200) has a history of IAxOA communication that was remedied by cementing the OA to surface and performing a Well Lock downsqueeze. The well was reported to have anomalous OA casing pressure above NOL on 08/16/19 after it was shut in. DHD bled the OA and IA to mitigate the sustained OA casing pressure, but a fluid level shot indicated inflow into the inner annulus. The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan Forward: 1. Cameron Well Head Tech: Perform PPPOT‐IC. 2. DHD: warm TIFL. 3. Well Integrity Engineer: Additional diagnostics as needed to remedy any TxIA communication. 4. Well Integrity Engineer: Reclassify as Not Operable. 5. Anchorage Engineers: Evaluate for OA Well Lock downsqueeze to mitigate OA repressurization. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 PBU Y-14C Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-120 50-029-21832-03-00 341J ADL 0028287 13425 8994 80 2654 5990 4689 3015 10399 20" 13-3/8" 9-5/8" 7" 4-1/2" 36 - 116 36 - 2690 34 - 6024 5870 - 10559 10408 - 13423 36 - 116 36 - 2689 34 - 5735 5615 - 8882 8763 - 8994 None10399 5020 6870 7240 8430 11949 - 13339 4-1/2" 12.6# 13cr85 32 - 104179004 - 9006 4-1/2" HES TNT Perm Packer No SSSV Installed 10290, 8671 No SSSV Installed Aras Worthington for Torin Roschinger Operations Manager Oliver Sternicki oliver.sternicki@hilcorp.com (907) 564 4891 PRUDHOE BAY 11/13/2023 PRUDHOE OIL PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2023.11.01 11:55:11 - 08'00' Aras Worthington (4643) 8756 By Grace Christianson at 3:34 pm, Nov 01, 2023 323-595 10-404 MGR01NOV23 DSR-11/2/23SFD 11/2/2023*&: Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.11.03 10:45:38 -08'00'11/03/23 RBDMS JSB 110723 OA Squeeze Well: Y-14C Well Name:Y-14C Permit to Drill Number:214-120 Well Type PAL API Number:50-029-21832-03 Job Scope:OA Squeeze Reg.Approval Req’d?Yes Current Status:NotOperable Date Reg. Approval Rec’vd: Estimated Start Date:11/15/2023 Estimated Duration:2days Regulatory Contact:Abbie Barker 907-564-4915 First Call Engineer:Oliver Sternicki 907-564-4891 Brief Well Summary: Y-14C is a gas lifted producer which on 9/17/2022 exceeded OA MOASP to 1016 psi and began exhibiting bubbling in the conductor by surface casing annulus. The OA was fully cemented as part of a rig sidetrack in 2014 to repair a surface casing leak at ~79”. In 2015 conductor bubbling was observed and the well failed a MIT-OA. To repair this an OA downsqueeze with squeezecrete was executed in 2016. Conductor bubbling and OA repressurization were again observed in 2018 and the OA was squeezed with WellLock on 4/14/2019. The OA was most recently retreated with welllock on 10/28/2021. The pressure communication path for the bubbling is suspected to be from the IA to the OA through the IC seals in the wellhead, through the cement top and out the surface casing leak at 79”. A PPPOT-IAC passed to 3500 psi on 9/7/2022 and a CMIT-TxIA passed to 2640 psi on 10/3/2022. Current Status: Y-14C is currently not operable and offline. Scope of Work: Squeeze OA with Well Lock (or similar) to repair surface casing leak. Procedure: Begin Sundry work 1 Valve Shop ND OA GATE VALVE, NU OA INTEGRAL 2 DHD WELL LOCK OR SIMILAR OA SQUEEZE 3 Special Projects A/DHD WITH SQUEEZE 4 DHD GREENSTICK IC VOID 4 DHD POP U/E, MONITOR FOR IAXOA, SC LEAK 5 Valve Shop ND OA INTEGRAL, NU OA GATE VALVE 6DHD RE-SQUEEZE OA WITH WELL LOCK OR SIMILAR IF NECESSARY. Attachments: Wellbore Schematic Sundry Change From OA Squeeze Well: Y-14C OA Squeeze Well: Y-14C Hilcorp North Slope, LLC Hilcorp North Slope, LLC Changes to Approved Work Over Sundry Procedure Date: October 27, 2023 Subject: Changes to Approved Sundry Procedure for Well Y-14C 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 workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Producer Y-14C (PTD #2141200) Secured with TTP Date:Tuesday, October 4, 2022 10:28:18 AM Attachments:image001.png image002.png image003.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 4, 2022 10:22 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: Producer Y-14C (PTD #2141200) Secured with TTP Mr. Regg, Slickline set a TTP on 10/03/22 and a subsequent CMIT-TxIA passed to 2640 psi. The well will now be classified as NOT OPERABLE and will remain secured while the OE evaluates repair options to remedy the OA re-pressurization. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Sunday, September 18, 2022 9:36 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Producer Y-14 (PTD #2141200) Sustained OA casing pressure above MOASP Mr. Regg, Producer Y-14 (PTD #2141200) was reported by operations to have OA pressure over NOL ~1016 psi on 09/17/22 and bubbling in the conductor. At this time, the well is classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Bleed IAP / OAP to 0 psi. OA injectivity test / Leak depth determination using N2 2. Well Integrity / Operations Engineer: Evaluate economics / repair options Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: John Conrad <John.Conrad@hilcorp.com> Sent: Friday, June 24, 2022 1:00 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: RE: OPERABLE: Producer Y-14 (PTD #2141200) Sustained OA casing pressure above MOASP All, Per the evaluation plan below, Y-14 OA has remained flat after green stick into the IC void, bleeding while shut in as well as remaining flat/stable after BOL 6/22. The well will now be classified as OPERABLE. Thank you, John Conrad filling in for Andy Ogg Well Site Supervisor Cell: 406-544-6684 H: 7436 Alt: Brenton Nicholson Hilcorp North Slope, LLC From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, June 15, 2022 9:28 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer Y-14 (PTD #2141200) Sustained OA casing pressure above MOASP All, Producer Y-14 (PTD #2141200) was reported to have OA casing pressure above MOASP on 6/12/2022 after being shut-in on 06/09/22. The reported pressure was 1032 psi. The Y-14 OA was cemented to surface during a rotary sidetrack in 2014 to repair a surface casing leak. Additional OA down squeeze jobs have been completed with squeezecrete and twice with wellock to mitigate bubbling the conductor. It is suspected that when the well is shut-in and cools down, pressure communication between the IA and the OA occurs across the wellhead. The well will be classified as UNDER EVALUATION and is on a 28-day clock for diagnostics and attempt to repair the OA repressurization. The MOASP excursion requires AOGCC reporting and will be handled by Well Integrity. Plan forward: 1. DHD: Monitor SI BUR 2. DHD: Greenstick IC pack-off 3. DHD: Monitor SI BUR 4. OPS/ DHD: POP well, monitor for IAxOA comm 5. Well integrity Engineer: Additional diagnostics as needed Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, February 12, 2022 5:19 PM To: Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer Y-14 (PTD #2141200) MIT-T Passed All, Producer Y-14C (PTD #2141200) passed MIT-T on 02/12/22 post GLV work during LDL. The passing MIT-T resolves the previous TxIA communication and verifies the primary well barrier. The well remains secured with a TTP and is now classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, February 9, 2022 6:02 AM To: Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Producer Y-14 (PTD #2141200) Under Evaluation clock extended 28 days. All, Slickline set different configurations of DGLVs but could not obtain a passing MIT-T. E-line has been scheduled to perform a Leak Detect Log but is currently delayed due to inclement weather. The Under Evaluation clock will be extended for 28 more days to allow sufficient time to complete the LDL and perform any follow up diagnostic work. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, January 21, 2022 2:57 PM To: Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer Y-14 (PTD #2141200) TxIA communication All, Producer Y-14C (PTD #2141200) was found to have TxIA communication during failed MIT-T on 01/12/22. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Friday, November 26, 2021 8:40 AM To: Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer Y-14 (PTD #2141200) OA Well Lock Pumped All, Producer Y-14C (PTD #2141200) was put on production 11/08/21. There has been no OA re-pressurization or bubbling in the cellar post wellock. The well is now classified as OPERABLE and can remain online. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, November 4, 2021 7:16 AM To: Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Producer Y-14 (PTD #2141200) OA Well Lock Pumped All, The OA Well Lock downsqueeze was performed on 10/29/21. Once the Well Lock has cured, the well will be POP’d and monitored for cellar activity. The Under Evaluation has been extended another 28 days. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, October 7, 2021 7:34 AM To: Noel Nocas <Noel.Nocas@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC1 Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; PBW GC1 Foreman <PBWGC1Foreman@hilcorp.com>; PBW GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; PBW GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; PBW GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; PBW GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Producer Y-14 (PTD #2141200) Possible SC leak All, Sundry approval has been obtained to pump an OA downsqueeze with Well Lock. The Under Evaluation clock will be extended 28 days to execute the job and perform follow up diagnostics. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity Sent: Thursday, September 9, 2021 3:49 PM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska JMS User <akimsuser@hilcorp.com>; Alaska NS - PB - EOC Specialists <PBEOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; Alaska NS - PB W - GC1 - Field Lead Operator <PBWGC1FieldLeadOperator@hilcorp.com>; Alaska NS - PB W - GC1 - Foreman <PBWGC1Foreman@hilcorp.com>; Alaska NS - PB W - GC1 Wellpad DG <PBWGC1WellpadDG@hilcorp.com>; Alaska NS - PB W - GC1 Wellpad EK <PBWGC1WellpadEK@hilcorp.com>; Alaska NS - PB W - GC1 Wellpad F <PBWGC1WellpadF@hilcorp.com>; Alaska NS - PB W - GC1 Wellpad YP <PBWGC1WellpadYP@hilcorp.com>; Alaska NS - PB W - GC3 - ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com> Subject: UNDER EVALUATION: Producer Y-14 (PTD #2141200) Possible SC leak All, Producer Y-14C (PTD #2141200) was found to have slow bubbling in the conductor with LEL readings at 7% on 09/04/21. The well is now classified as UNDER EVLAUTION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Bleed IAP / OAP to 0 psi 2. Well Integrity: Pump wellock into OA 3. Well Integrity: Further diagnostics as needed Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, November 8, 2019 2:38 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Haffener, Jordan <Jordan.Haffener@bp.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Producer Y-14 (PTD #2141200) Greenstick packing remedied OA repressurization All, Producer Y-14 (PTD #2141200) was made Under Evaluation on 08/17/19 for anomalous outer annulus repressurization above NOL and a failed TIFL. Primary barrier integrity was confirmed on 09/25/19 and Greenstick packing was pumped into the IC void on 09/28/19. A scheduled OA downsqueeze with Well Lock was put on pending after it appeared the Greenstick job remedied the OA repressurization. On 10/23/19 Slickline pulled the TTP and the well was put on production. Follow up monitors have confirmed the well does not exhibit OA repressurization. The well is now classified as OPERABLE. Please respond with any questions. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, October 12, 2019 10:57 AM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Haffener, Jordan <Jordan.Haffener@bp.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: UNDER EVALUATION: Producer Y-14 (PTD #2141200) 28 day Under Evaluation clock extended All, Producer Y-14 (PTD # 2141200) was made Under Evaluation on 08/14/19 to address sustained OA casing pressure above NOL and TxIA communication. On 09/25/19 Slickline set a TTP, DGLVs and Fullbore performed a passing MIT-T to 2,710 psi and passing CMIT-TxIA to 2,661 psi proving the primary barrier has integrity. On 09/28/19 the wellhead technician pumped green stick packing into the wellhead IC void. The initial plan was to perform a Well Lock squeeze after packing the IC void with green stick. However, the Inner Annulus was pressured up with lift gas and it appears the Outer Annulus repressurization has been remedied with the green stick packing. The Under Evaluation clock will be extended to POP the well and monitor for OA repressurization. Plan Forward: 1. Slickline: Pull TTP 2. Operations: Put on production 3. DHD: Monitor 4. DHD (pending): perform OA Well Lock downsqueeze 5. Well Integrity Engineer: Additional diagnostics as needed Please respond if in conflict. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, September 14, 2019 1:41 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Haffener, Jordan <Jordan.Haffener@bp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Oshiro, Joleen <JOLEEN.OSHIRO@bp.com>; Stone, Christopher <Christopher.Stone@bp.com>; Youngmun, Alex <younak@BP.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: UNDER EVALUATION: Producer Y-14 (PTD #2141200) 28 day Under Evaluation clock extended All, Producer Y-14 (PTD # 2141200) was made Under Evaluation on 08/17/19 to address possible TxIA communication before making the well Not Operable and performing a Well Lock downsqueeze on the outer annulus. Efforts to perform a warm TIFL have not been successful because of the pad shutdown. Operations is beginning to bring the pad back online so the Under Evaluation clock will be reset to perform the warm TIFL and any additional diagnostics. Plan Forward: 1. Cameron Well Head Tech: Perform PPPOT-IC. 2. DHD: warm TIFL. 3. Well Integrity Engineer: Additional diagnostics as needed to remedy any TxIA communication. 4. Well Integrity Engineer: Reclassify as Not Operable. 5. Anchorage Engineers: Evaluate for OA Well Lock downsqueeze to mitigate OA repressurization. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, August 17, 2019 4:05 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Haffener, Jordan <Jordan.Haffener@bp.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: UNDER EVALUATION: Producer Y-14 (PTD #2141200) sustained OA casing pressure above NOL All, Producer Y-14 (PTD # 2141200) has a history of IAxOA communication that was remedied by cementing the OA to surface and performing a Well Lock downsqueeze. The well was reported to have anomalous OA casing pressure above NOL on 08/16/19 after it was shut in. DHD bled the OA and IA to mitigate the sustained OA casing pressure, but a fluid level shot indicated inflow into the inner annulus. The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan Forward: 1. Cameron Well Head Tech: Perform PPPOT-IC. 2. DHD: warm TIFL. 3. Well Integrity Engineer: Additional diagnostics as needed to remedy any TxIA communication. 4. Well Integrity Engineer: Reclassify as Not Operable. 5. Anchorage Engineers: Evaluate for OA Well Lock downsqueeze to mitigate OA repressurization. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 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. 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From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:RE: UNDER EVALUATION: Producer Y-14 (PTD #2141200) Sustained OA casing pressure above MOASP Date:Wednesday, June 15, 2022 10:53:35 AM Attachments:image001.png image002.png Well is PBU Y-14C (PTD 2141200) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, June 15, 2022 9:28 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer Y-14 (PTD #2141200) Sustained OA casing pressure above MOASP Mr. Regg, Producer Y-14 (PTD #2141200) was reported to have OA casing pressure above MOASP on 6/12/2022 after being shut-in on 06/09/22. The reported pressure was 1032 psi. The Y-14 OA was cemented to surface during a rotary sidetrack in 2014 to repair a surface casing leak. Additional OA down squeeze jobs have been completed with squeezecrete and twice with wellock to mitigate bubbling the conductor. It is suspected that when the well is shut-in and cools down, pressure communication between the IA and the OA occurs across the wellhead. The well will be classified as UNDER EVALUATION and is on a 28-day clock for diagnostics and attempt to repair the OA repressurization. Plan forward: 1. DHD: Monitor SI BUR 2. DHD: Greenstick IC pack-off 3. DHD: Monitor SI BUR 4. OPS/ DHD: POP well, monitor for IAxOA comm 5. Well integrity Engineer: Additional diagnostics as needed Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, November 8, 2019 2:38 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Haffener, Jordan <Jordan.Haffener@bp.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Producer Y-14 (PTD #2141200) Greenstick packing remedied OA repressurization All, Producer Y-14 (PTD #2141200) was made Under Evaluation on 08/17/19 for anomalous outer annulus repressurization above NOL and a failed TIFL. Primary barrier integrity was confirmed on 09/25/19 and Greenstick packing was pumped into the IC void on 09/28/19. A scheduled OA downsqueeze with Well Lock was put on pending after it appeared the Greenstick job remedied the OA repressurization. On 10/23/19 Slickline pulled the TTP and the well was put on production. Follow up monitors have confirmed the well does not exhibit OA repressurization. The well is now classified as OPERABLE. Please respond with any questions. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, October 12, 2019 10:57 AM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Haffener, Jordan <Jordan.Haffener@bp.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: UNDER EVALUATION: Producer Y-14 (PTD #2141200) 28 day Under Evaluation clock extended All, Producer Y-14 (PTD # 2141200) was made Under Evaluation on 08/14/19 to address sustained OA casing pressure above NOL and TxIA communication. On 09/25/19 Slickline set a TTP, DGLVs and Fullbore performed a passing MIT-T to 2,710 psi and passing CMIT-TxIA to 2,661 psi proving the primary barrier has integrity. On 09/28/19 the wellhead technician pumped green stick packing into the wellhead IC void. The initial plan was to perform a Well Lock squeeze after packing the IC void with green stick. However, the Inner Annulus was pressured up with lift gas and it appears the Outer Annulus repressurization has been remedied with the green stick packing. The Under Evaluation clock will be extended to POP the well and monitor for OA repressurization. Plan Forward: 1. Slickline: Pull TTP 2. Operations: Put on production 3. DHD: Monitor 4. DHD (pending): perform OA Well Lock downsqueeze 5. Well Integrity Engineer: Additional diagnostics as needed Please respond if in conflict. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, September 14, 2019 1:41 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Haffener, Jordan <Jordan.Haffener@bp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Oshiro, Joleen <JOLEEN.OSHIRO@bp.com>; Stone, Christopher <Christopher.Stone@bp.com>; Youngmun, Alex <younak@BP.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: UNDER EVALUATION: Producer Y-14 (PTD #2141200) 28 day Under Evaluation clock extended All, Producer Y-14 (PTD # 2141200) was made Under Evaluation on 08/17/19 to address possible TxIA communication before making the well Not Operable and performing a Well Lock downsqueeze on the outer annulus. Efforts to perform a warm TIFL have not been successful because of the pad shutdown. Operations is beginning to bring the pad back online so the Under Evaluation clock will be reset to perform the warm TIFL and any additional diagnostics. Plan Forward: 1. Cameron Well Head Tech: Perform PPPOT-IC. 2. DHD: warm TIFL. 3. Well Integrity Engineer: Additional diagnostics as needed to remedy any TxIA communication. 4. Well Integrity Engineer: Reclassify as Not Operable. 5. Anchorage Engineers: Evaluate for OA Well Lock downsqueeze to mitigate OA repressurization. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, August 17, 2019 4:05 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Haffener, Jordan <Jordan.Haffener@bp.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: UNDER EVALUATION: Producer Y-14 (PTD #2141200) sustained OA casing pressure above NOL All, Producer Y-14 (PTD # 2141200) has a history of IAxOA communication that was remedied by cementing the OA to surface and performing a Well Lock downsqueeze. The well was reported to have anomalous OA casing pressure above NOL on 08/16/19 after it was shut in. DHD bled the OA and IA to mitigate the sustained OA casing pressure, but a fluid level shot indicated inflow into the inner annulus. The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan Forward: 1. Cameron Well Head Tech: Perform PPPOT-IC. 2. DHD: warm TIFL. 3. Well Integrity Engineer: Additional diagnostics as needed to remedy any TxIA communication. 4. Well Integrity Engineer: Reclassify as Not Operable. 5. Anchorage Engineers: Evaluate for OA Well Lock downsqueeze to mitigate OA repressurization. Please respond with any questions. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110 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. 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Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU Y-14C OA Downsqueeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-120 50-029-21832-03-00 13425 Conductor Surface Intermediate Liner Liner 8994 80 2654 5990 4689 3015 13339 20" 13-3/8" 9-5/8" 7" 4-1/2" 36 - 116 36 - 2690 34 - 6024 5870 - 10559 10408 - 13423 36 - 116 36 - 2689 34 - 5735 5615 - 8882 8763 - 8994 None 2260 4760 5410 7500 None 5020 6870 7240 8430 11949 - 13339 4-1/2" 12.6# 13cr85 32 - 10417 9004 - 9006 Structural 4-1/2" HES TNT Perm Packer 10290, 8671 Stan Golis Sr. Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028287 No SSSV Installed 32 - 8770 OA at Surface 3/4-gallon of WellLock pumped with 2500-psi squeeze pressure applied. 67 4167 656 1667 277 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: 10290 86719006 321-462 77 3894 778 1526 286 By Samantha Carlisle at 10:18 am, Nov 23, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.11.22 17:20:50 -09'00' Stan Golis (880) DSR-11/23/21MGR29DEC2021SFD 11/29/2021 RBDMS HEW 11/24/2021 ACTIVITY DATE SUMMARY 10/28/2021 T/I/O = 1760/20/0. Temp = SI. Wellock OA (repair SC leak). ALP = 1930 psi, SI @ CV. IA FL @ 4920'. Heater working. Currently holding open OA bleed. Bled IAP to 0 psi. SI OA bleed. Pumped ~1/4 gal Wellock into 9:00 OA port. Pressure held @ 2500 psi for 1 hr. Pumped ~1/2 gal Wellock into 3:00 OA port. Pressure held @ 2500 psi for 1 hr. Final WHPs = 1760/0+/2450. SV, WV = C. SSV, MV = O. IA, OA = OTG. 15:30 11/9/2021 T/I/O = 350/1540/10. Temp = 94°. WHPs (Post Wellock). ALP = 1540 psi, online. Conductor flutes are clean and dry. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:15 Daily Report of Well Operations PBU Y-14C 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name: Authorized Title: Authorized Signature: Date: Contact Name: Contact Email: Contact Phone: COMMISSION USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE COMMISSIONCOMMISSIONER PBU Y-14C OA Downsqueeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-120 50-029-21832-03-00 N/A ADL 0028287 13425 Conductor Surface Intermediate Liner Liner 8994 80 2654 5990 4689 3015 13339 20" 13-3/8" 9-5/8" 7" 4-1/2" 9005 36 - 116 36 - 2690 34 - 6024 5870 - 10559 10408 - 13423 36 - 116 36 - 2689 34 - 6024 5615 - 8882 8763 - 8994 None 2260 4760 5410 7500 None 5020 6870 7240 8430 11949 - 13339 4-1/2" 12.6#13cr85 32 - 104179004 - 9006 Structural 4-1/2" HES TNT Perm Packer No SSSV Installed 10290, 8671 No SSSV Installed Date: Stan Golis Sr. Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY, PRUDHOE OIL 9/23/2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 2722 By Samantha Carlisle at 8:34 am, Sep 10, 2021 321-462 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.09.09 15:26:56 -08'00' Stan Golis (880) 10-404 MGR20SEP2021 SFD 9/10/2021 DSR-9/13/21 dts 9/21/2021 JLC 9/21/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.21 14:54:07 -08'00' RBDMS HEW 9/22/2021 OA WellLock Squeeze Well: Y-14C PTD: 214-120 API: 50-029-21832-03 Well Name:Y-14C Permit to Drill Number:214120 Well Type PAL API Number:50-029-21382-03-00 Job Scope:OA WellLock Squeeze Reg.Approval Req’d?Yes Current Status:Under Eval, Online Date Reg. Approval Rec’vd: Estimated Start Date:09/30/2021 Estimated Duration:2day Regulatory Contact:Mel Rixse First Call Engineer:Oliver Sternicki Second Call Engineer:Noel Nocas Brief Well Summary: Y-14C is a gas lifted producer which on 8/19/2021 began exhibiting bubbling in the conductor by surface casing annulus. The OA was fully cemented as part of a rig sidetrack in 2014 to repair a surface casing leak at ~79”. In 2015, conductor bubbling was observed and the well failed a MIT-OA. To repair this, an OA downsqueeze with squeezecrete was executed in 2016. Conductor bubbling and OA repressurization were again observed in 2018 and the OA was squeezed with WellLock on 4/14/2019. The pressure communication path for the bubbling is suspected to be from the IA to the OA through the IC seals in the wellhead, through the cement top and out the surface casing leak at 79”. On 8/26/2021 the IC void was successfully squeezed with sealant to eliminate the IAxOA communication. Current Status: Y-14C is currently under evaluation and online. Scope of Work: Squeeze OA with Well Lock (or similar) to repair surface casing leak. Procedure: 1 Valve Shop ND OA GATE VALVE, NU OA INTEGRAL 2 DHD WELL LOCK OA SQUEEZE 3 Special Projects A/DHD WELL LOCK SQUEEZE 4 DHD POP U/E, MONITOR FOR SC LEAK, 5 Valve Shop ND OA INTEGRAL, NU OA GATE VALVE 6 DHD RE-SQUEEZE OA WITH WELL LOCK IF NECESSARY. 7. Before POP, MIT-IA or CMIT-IA to 2500 psi. 30 minute charted test. OA WellLock Squeeze Well: Y-14C PTD: 214-120 API: 50-029-21832-03 OA WellLock Squeeze Well: Y-14C PTD: 214-120 API: 50-029-21832-03 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:214-120 6.50-029-21832-03-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13425 13339 9005 10290 None None 8671 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 Surface 2654 13-3/8" 36 - 2690 36 - 2689 5020 2260 Intermediate 5990 9-5/8" 34 - 6024 34 - 5735 6870 4760 Production 4689 7" 5870 - 10559 5615 - 8882 7240 5410 Perforation Depth: Measured depth: 11949 - 13339 feet True vertical depth:9004 - 9006 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.-6# 13cr85 32 - 10417 32 - 8770 10290 8671Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Perm Packer Liner 3015 4-1/2" 10408 -13423 8763 - 8994 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Packed test void with 1/2 cup of green stick packing. Pressure tested to 3500-psi. Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 288159383682 1950 4149 284 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: Oliver Sternicki Oliver.Sternicki@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.4891 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8994 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Wellhead Sealant Operations shutdown Change Approved Program 5 Wellhead IC void Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028287 PBU Y-14C 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 Well Test not available By Samantha Carlisle at 9:46 am, Sep 01, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.08.31 22:59:43 -08'00' Stan Golis (880) RBDMS HEW 9/1/2021 DSR-9/9/21MGR01SEP2021 SFD 9/1/2021 ACTIVITY DATE SUMMARY 8/26/2021 T/I/O = 280/1510/20. Temp = 100°. Green stick IC void. ALP = 1510 psi, AL online. Bubbling in all flutes. IC void @ 1700 psi. Used 1/4 of packing gun full of green stick to pack IC void. Packed test void off to 3500 psi for 30 min test. Lost 500 psi. pressure void back to 3500 psi for 30 min, no loss of psi. Close in hoke valve. Bleed off equipment. No change in bubbling in flutes throughout treating of IC void w/Green stick. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:00 Daily Report of Well Operations PBU Y-14C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS nrr , n gmo r v LVID 1. Operations Performed www Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Oper4ygr(s, t n ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ® Re-enter Susp Well ❑ Other: Wellhead Sealant Z 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development m Exploratory ❑ 5. Permit to Drill Number 214-120 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigraphic ❑ Service ❑ 6. API Number: 50-029-21832-03-00 1 7 Property Designation (Lease Number): ADL 028287 8. Well Name and Number: PBU Y -14C 9. Logs (List logs and submit electronic and panted data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 13425 feet Plugs measured None feet true vertical 8994 feet Junk measured None feet Effective Depth: measured 13339 feet Packer measured 10290 feet true vertical 9006 feet Packer true vertical 8671 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36-116 36-116 Surface 2654 13-3/8" 36-2690 36-2689 5020 2260 Intermediate 5991 '9-5/8" 33-6024 33-5735 6870 4760 Liner 4689 7" 5670 - 10559 5615-8882 7240 5410 Liner 3015 4-1/2" 10408-13423 8763-8994 8430 7500 Perforation Depth: Measured depth: 11949 - 13339 feet True vertical depth: 9004-9005 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6#, 13Cr85 31 -10417 31 -8770 Packers and SSSV (type, measured and 4-1/2' HES TNT Perm Packer 10290 8671 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): OA cemented to surface. Stung into test void 0 psi on void. Monitored for 30 min, no change in void pressure. R/U packing gun on to test void port. Pump 9-1/2 Sticks of (Green Stick) packing. Pack test void off to 3,500 psi for 30 min test. lost 200 psi. Pressure back to 3,500 psi for 30 min. No loss in pressure, Treatment descriptions including volumes used and final pressure: 9-1/2 Sticks of (Green Stick) packing. Final Pressures: OA = 50psi, IA = 1250psi, TBG = 242psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 108 3406 828 1334 222 Subsequent to operation: 84 3375 708 1285 244 14.Attachments: (regwred per20 mac 25,070.25 071, s 25,283) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Prmted and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Worthington, Aras J Contact Name: Worthington, Arae J Authorized Title: Interventions &Integrity Engineer Contact Email: Aras.Worthington@bp.com Authodzed Signature: Date/.;2/p1 �OY47 Contact Phone: +1 907 564 4102 Form 10-004 Revised 04/2017 //L /`' r .213D�'�►y SgDMS,({-awl DEC 1 12019 Submit Original Only Daily Report of Well Operations PBU Y -14C ACTIVITYDATF o1 u..e. ev T/I/O = SSV/870/510. Temp = SI. Assist Ops W/ POP. ALP = 1900 psi, SI @ CV. IA FL @ 3555' (173' above #5 Dome, 190 bbls). OA cemented to surface. Bubbling in conductor at the 3 o'clock position with No LEL's 1 in or 1 ft above. Fluid in conductor is 1/2 inch from the top. Ops POP at 19:50. 9/17/2019 Cont on 9/18/19 WSR T/I/O=SSV/850/500, Temp=Sl. PPPOT-IC (FAIL), eval IAxOA com. PPPOT-IC: Stung into test port (300 psi), bled void to 0 psi. Monitored for 10 min, no change in pressure. Single port, unable to pump through void. Unable to pressure void above 500 psi. LDS 9/17/2019 are torqued to 600 Ib/ft (FAIL). TWO = 300/1290/100. Temp = 90°. TIFL FAILED (Eval TxIA) & bleed OAP to 0 psi (VS assist). ALP = 1290 psi, open @ CV. IA FL @ 10181'(#1 SO, 389 bbls). OA cemented to surface. Bubbling in conductor at the 12 o'clock position has 26% LEL's 1 inch above and 0% LEL's 1 ft above. Bled OAP to BT from 100 psi to 0 psi in <1 min (Gas) and held open for 2 hrs. SI WV, stacked well to 1770/1780/0 in 1 hr 10 min. Bled IAP to OT from 1780 psi to 1060 psi in 1 hr. TP decreased 220 psi, IA FL inflowed 2640' to 7540'. Bled IAP from 1060 psi to 930 psi in 20 min. IA FL inflowed 580' to 6960'. T FL @ 9500'. SI open OA bleed. Monitored for 30 min. TP increased 30 psi, IAP increased 30 psi, IA FL inflowed an additional 580' to 6380', OAP increased 3 psi. Turned well over to Ops. Final WHPs = 1580/960/3. 9/18/2019 SV, WV = C. SSV, MV = 0. IA, OA = OTG. 23:59 Cont from 9/17/19 WSR T/I/O = 240/1660/20. Temp = 760. Assist Ops w/ POP. ALP = 1660 psi, open @ CV. IA FL @ 9630' (551' above #1 SO). OA cemented to surface. Bubbling in conductor at the 12 and 3 o'clock positions has 42% LEL's 1 inch above and 0% LEL's 1 ft above. Fluid in conductor is 1/2 in from the top. Ops POP at 19:50 last night. Monitored WHPs, temp and IA FL. Bled OAP to BT twice (Gas, 1 min). IA FL @ 10181'(#1 SO) at 02:00. Well appears stable. Final WHPs = 200/1150/20. 9/18/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 02:20 T/I/0= 300/1400/23 PRE WELL LOCK. Bleed 23psi off OA, start one hr no flow monitor. RID OA Comp blind & installed integral flange. (VR Profile completly packed off with previous well lock.) Torqued OA Comp flange to 188ft lbs. RID 2" CIW OA valve & install intagral flange. (VR profile completly packed of with well lock on Working side too.) Torqued OA Flange to 188 ft lbs. Installed hardline components on OA & OA Comp with High Temp Viton gaskets. RDMO ***Jab 9/19/2019 Complete*** FWHP =300/1400/0 ***WELL S/I ON ARRIVAL*** (cement squeeze) SET 4-1/2" WHIDDON C -SUB AT 10,387' SLM PULLED BK-S/O AT 10,181' MD...5-3/4" OF VLV FLOW CUT OFF & STILL IN HOLE RAN 1" POCKET POKER TO 10,181' MD...INDICATES POCKET EMPTY & POSSIBLY PUSHED OUT MISSING PORTION OF VLV ***CONT. ON 09/25/19 WSR*** 9/24/2019 *****NOTE: 5-3/4" OF FLOW CUT S/0 FROM 10,181' MD MISSING IN HOLE***** ***CONT. FROM 09/24/19 WSR*** (Cement Squeeze) PULLED BK-LGLV's FROM STA #2 AT 9,358' MD & STA #3 AT 8,162' MD. PULLED RK-LGLV's FROM STA #4 AT 5,758' MD & STA #5 AT 3,728' MD. SET RK-DGLV's IN STA #5 AT 3,728' MD & STA #4 AT 5,758' MD. SET BK-DGLV's IN STA #3 AT 8,162'& STA #2 AT 9,358' MD. LRS LOAD IA W/ 450 BBLS CRUDE SET BK-DGLV IN STA #1 AT 10,181' MD. PULLED 4-1/2" WHIDDON C -SUB AT 10,387' SLM. 9/25/2019 ***CONT. ON 09/26/19 WSR*** Daily Report of Well Operations PBU Y -14C **Continued from 9/25/19** (LRS unit 38- assist HSL) MIT -T **PASSED** to 2710 psi (Max 2750 psi, Target 2500 psi). CMIT-TxIA **PASSED** to 2689/2661 psi (Max 2750 psi, Target 2500 psi) Per SL WSL Nicholson. Loaded TBG with 3 bbls 60/40 meth and 250 bbls crude. Pumped an additional 47 bbls crude down TBG while S -Line brushed and to help set plug. Pumped 3.4 bbls crude down TBG for MIT -T. 1st 15 min TBG lost 22 psi, 2nd 15 min TBG lost 13 psi for a total loss of 35 psi in 30 min. Bled TBGP over to IA. Pumped 6.3 bbls of crude down T/IA for CMIT-TxIA. 2nd 15 min T/IA lost 11/21 psi. 3rd 15 min T/IA lost 10/14 psi for a total loss of 21/35 psi in 30 min. Bled T/IAP, bled back — 8 bbls. RDMO. Hung info tags on IA/WV. Hung AFE sign **FLUID PACKED ANNULUS** on MV. SL in control of 9/26/2019 well upon LRS departure. IA/OA=OTG. FWHP=200/200/10. ***CONT. FROM 09/25/19 WSR*** (Cement Squeeze) LRS LOAD TBG W/ 250 BBLS CRUDE ATTEMPT TO SET PXN PLUG BODY AT 10,399' MD BRUSH AND FLUSH TBG TO XN NIPPLE AT 10,399' MD W/ 3.77" G -RING & 4-1/2" BRUSH SET 4-1/2" PXN PLUG AT 10,399' MD MIT -T & CMIT-TxIA PASSED 9/26/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** T/I/O = 1140/180/300. Temp = SI. Bleed IA & OA to 0 psi (pre wellhead work). ALP = 550 psi, SI @ CV. Flowline pressure = 1140 psi. Called grease crew to service WV. T FL @ surface, IA FL @ surface, OA FL @ cemented. Slight bubbling in conductor @ 3, 6, 9 & 12 o'clock position. No LELs in wellhouse, conductor 1" & V above bubbling. Bled OAP from 300 psi to 0 psi in less than 5 min, all gas. Bled IAP from 180 psi to 0 psi in 10 min, all fluid, returned 0.50 bbls. Monitor for 30 min. TP and IAP unchanged, OAP increased 30 psi. Final WHPs = 1110/0/30. 9/27/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 23:59 T/I/O = SSV/O/O TEMP = SI, (GREEN STICK) DHD bleed IA and OA to 0 psi, holding open bleed. Stung into test void 0 psi on void. Monitored for 30 min, no change in void pressure. R/U packing gun on to test void port. Pump 9-1/2 Sticks of (Green Stick) packing. Pack test void off to 3,500 psi for 30 min test. lost 200 psi. Pressure back to 3,500 psi for 30 min. No loss in pressure, close in HOKE valve bleed down pressure. N/D 9/28/2019 equipment. T/I/O = 1110/0/180. Temp = SI. Hold open bleed (Assist Cameron). ALP @ 550, SI at CV. IA FL @ near surface. OA cemented to surface. Slight bubbling in conductor @ 3, 6, 9 & 12 o'clock positions. No LELs in wellhouse or conductor 1" & 1' above bubbling. Bled OAP to BT from 180 psi to 0 psi in <1 min (gas). Maintained open bleed on IA and OA for Cameron to pump green stick into IC hanger, (see Cameron WSR for details). Final WHPs = 1090/0/0. 9/28/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 13:45 T/I/O = 1030/Vac/180. Temp = Sl. Pressure up IA with AL, Monitor IA x OA (post wellhead repair). ALP @ 1500, SI at CV. IA FL @ near surface. OA cemented to surface. Slight bubbling in conductor @ 3, 6, 9 & 12 o'clock positions. No LELs in wellhouse or conductor 1" & V above bubbling. Increased IAP incrementally to 1500 psi and monitored pressures (see log for details). No increase in OAP while pressuring up the IA. Monitored for 5 hrs. OAP decreased 30 psi during the first 2 hrs and then increased 40 psi in the last 3 hrs. Final WHPs = 1200/1480/190. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:30 9/29/2019 T/I/O = 1130/1450/210. Temp = SI. WHPs (eval IAxOA) post wellhead repair. ALP = 1510 psi, SI @ CV. IA FL @ near surface. OA cemented to surface. Slight bubbling in conductor @ 12 & 3 o'clock positions. No LELs in wellhouse or conductor @ 1" or I' above bubbling. TP decreased 70 psi, IAP decreased 30 psi, OAP increased 20 psi in 9 hrs. 9/30/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 00:40 Daily Report of Well Operations PBU Y-14C TWO = 1130/1410/210. Temp = SI. WHPs (eval IAxOA) post wellhead repair. ALP = 1510 psi, SI @ CV. IA FL @ near surface. OA cemented to surface. Slight bubbling in conductor @ 12 & 3 o'clock positions. No LELs in wellhouse or conductor @ 1" or 1' above bubbling. TP unchanged, IAP decreased 40 psi, OAP unchanged overnight. 10/1/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:55 T/I/O = SSV/1370/190. Temp = SI. WHPs (eval IAxOA) post wellhead repair. ALP = 1500 psi, SI @ CV. IA FL @ near surface. OA cemented to surface. Slight bubbling in conductor @ 12 & 3 o'clock positions. No LELs in wellhouse or conductor @ 1" or 1' above bubbling. IAP decreased 40 psi, OAP decreased 20 psi since last monitor on 10/01/19. 10/3/2019 SV, WV, SSV = C. MV=O. IA, OA = OTG. 01:00 T/I/O = SSW1340/170. Temp = SI. WHPs (eval IAxOA) post wellhead repair. ALP = 1500 psi, SI @ CV. Slight bubbling in conductor @ 12 & 3 o'clock positions. No LELs in wellhouse or conductor @ 1" or 1' above bubbling. IAP decreased 30 psi, OAP decreased 20 psi overnight. 10/4/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:45 T/I/O = SSV/1340/70. Temp = SI. WHPs (eval IAxOA) post wellhead repair. ALP = 1500 psi, SI @ CV. Slight bubbling in conductor @ 12 & 3 o'clock positions. No LELs in wellhouse or conductor @ 1" or V above bubbling. IAP unchanged, OAP decreased 100 psi overnight. 10/5/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 02:30 T/1/0 = SSV/1320/165. Temp = SI. WHPs (eval IAxOA) post wellhead repair. ALP = 1500 psi, SI @ CV. Slight bubbling in conductor @ 12 & 3 o'clock positions. No LELs in wellhouse or conductor @ 1" or V above bubbling. IAP decreased 20 psi, OAP increased 95 psi overnight. 10/5/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 23:00 TWO = SSV/1300/170. Temp = SI. WHPs (eval IAxOA) post wellhead repair. ALP = 1510 psi, SI @ CV. Slight bubbling in conductor @ 12 & 3 o'clock positions. No LELs in wellhouse or conductor @ 1" or V above bubbling. IAP decreased 40 psi, OAP increased 100 psi overnight. 10/7/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 00:55 T/I/O = SSV/1280/160. Temp = SI. WHPs (eval IAxOA) post wellhead repair. ALP = 1490 psi, SI @ CV. Slight bubbling in conductor @ 12 & 3 o'clock positions. No LELs in wellhouse or conductor @ 1" or V above bubbling. IAP decreased 20 psi, OAP increased 10 psi since 10/07/19. 10/9/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 00:40 T/I/O = SSW1260/170. Temp = SI. WHPs (eval IAxOA) post wellhead repair. ALP = 1490 psi, SI @ CV. Slight bubbling in conductor @ 12 & 3 o'clock positions. No LELs in wellhouse or conductor @ 1" or V above bubbling. IAP decreased 20 psi, OAP increased 10 psi since 10/09/19. 10/10/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 03:30 T/I/O = SSV/1260/170. Temp = SI. WHPs (eval IAxOA) post wellhead repair. ALP = 1490 psi, SI @ CV. Slight bubbling in conductor @ 12 & 3 o'clock positions. No LELs in wellhouse or conductor @ 1" or 1' above bubbling. IAP and the OAP unchanged overnight. 10/11/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 01:30 T/1/0 = SSV/1260/180. Temp = SI. WHPs (eval IAxOA) post wellhead repair. ALP = 1460 psi, SI @ CV. Slight bubbling in conductor @ 12 & 3 o'clock positions. No LELs in wellhouse or conductor @ 1" or 1' above bubbling. IAP unchanged and the OAP increased 10 psi overnight. 10/12/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 03:15 T/I/O = SSV/1250/180. Temp = SI. WHPs (eval IAxOA) post wellhead repair. ALP = 1410 psi, SI @ CV. Slight bubbling in conductor @ 12 & 3 o'clock positions. No LELs in wellhouse or conductor @ 1" or 1' above bubbling. IAP decreased 10 psi and the OAP unchanged overnight. 10/13/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 02:30 —WELL S/I ON ARRIVAL***(gas-lift) STBY & MONITOR WIND THAT IS TRENDING UP 10/16/2019 ***CONTINUE ON 10-17-19 WSR*** Daily Report of Well Operations PBU Y -14C CONTINUE FROM 10-16-19 WSR. MONITOR 35+ MPH WINDS ALL DAY. 10/17/2019 CONTINUE ON 10-18-19 WSR. ***CONTINUE FROM 10-17-19 WSR***(weather stby) STBY FOR HIGH WINDS ALL DAY 10/18/2019 ***CONTINUE ON 10-19-19 WSR*** ***CONTINUE ON FROM 10-18-19 WSR*** STBY AND MONITOR 35+ MPH WINDS ALL DAY. 10/19/2019 ***CONTINUE ON 10/20/19 WSR*** ***CONTINUE FROM 10/19/19 WSR*** SET 4-1/2" WHIODON CATCHER SUB ON PXN PRONG @ 10,361' SLM PULLED BK-DGLV FROM STA.#1 @ 10,149' SLM (10,181' MD) PULLED BK-DGLV FROM STA12 @ 9,331' SLM (9,358' MD) PULLED BK-DGLV FROM STA.#3 @ 8,135' SLM (8,162' MD) PULLED RK-DGLV FROM STA.#4 @ 5,732' SLM (5,758' MD) PULLED RK-DGLV FROM STA -#5 @ 3,707' SLM (3,728' MD) 10/20/2019 ***CONTINUE ON 10-21-19 WSR*** ***CONTINUE ON FROM 10-20-19 WSR*** UNPLANNED POWER OUTAGE & INSTRUCTED TO STAND-BY ALL DAY BY DSO 10/21/2019 ***CONTINUE ON 10-22-19 WSR*** ****WELL S/I UPON ARRIVAL, CONT FROM HES 769 AWGRS**** (Cement squeeze) SET STA #2 BK-LGLV @ 9,350" SLM / 9,358' MD 10/22/2019 ****CONT JOB ON 10/23/19**** ***CONTINUE ON FROM 10-21-19 WSR***(gas lift) SET RK-LGLV IN STA.# 5 @ 3,728' MD (16/64", 1694 TRO) SET RK-LGLV IN STA.# 4 @ 5,758' MD (16/64", 1663 TRO) SET BK-LGLV IN STA.# 3 @ 8,162' MD (16/64",1754 TRO) MAKE THREE ATTEMPTS TO SET 1" DOME IN STA.#2 @ 9,358' MD 10/22/2019 ***JOB IS NOT COMPLETE, SLB 4522 WILL BE FINISHING JOB*** ****CONT. JOB FROM 10/22/19**** (Cement squeeze) SET STA #1 BK-DGLV @ 10,176' SLM / 10,181' MD PULLED 4-1/2" WHIDDON CATCHER FROM 10,374' SLM (Empty) PULLED 4-1/2" PXN-PLUG FROM 10,388' SLM / 10,399' MD 10/23/2019 ****WELL LEFT S/I & PAD -OP NOTIFIED OF STATUS UPON DEPARTURE**** T/I/O = 260/1480/200. Temp = 82°. IA FL (Ops request). AL online. Heater installed in wellhouse and working properly. OA CV's removed and 2" block valves installed. IA FL @ 10181' (sta # 1 SO). Small amount of bubbling detected in the conductor @ the 12 o'clock position. LEL = 0%. 10/26/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 05:00 T/I/O = 210/1190/110. Temp = 80*. WHPs (Eval IAxOA). AL online. Heater installed in wellhouse and working properly. TP decreased 50 psi, IAP decreased 290 psi and the OAP decreased 90 psi overnight. Slight bubbling detected in flutes @ the 12 & 3 o'clock position. LEL = 0%. 10/27/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:45 T/I/O = 230/1400/100. Temp = 98*. WHPs (Eval IA x OA) eval wellhead repair. AL open @ casing valve. The TP increased 20 psi, IAP increased 210 psi and the OAP decreased 10 psi overnight. No bubbling in the flutes at this time. 1502 integrals and fittings rigged up to OA. 10/28/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 13:30 T/I/O = 260/1290/90. Temp = 90F. WHPs (eval IAxOA) - post wellhead repair. ALP = 1290 psi, open @ CV. TP increased 30 psi, IAP decreased 110 psi, OAP decreased 10 psi since 10/28. Slight bubbling in the conductor at the 9 o'clock position. No LELs just above bubbling or one foot above bubbling. 1502 integrals and block valves on the OA. 10/30/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 12:30 Daily Report of Well Operations PBU Y-14C TWO = 230/1300/80. Temp = 90F. WHPs (eval IAxOA) - post wellhead repair. ALP = 1290 psi, open @ CV. TP decreased 30 psi, IAP increased 10 psi, OAP decreased 10 psi overnight. Slight bubbling in the conductor at the 9 o'clock position. No LELs just above bubbling or one foot above bubbling. 1502 integrals and block valves on the OA. SV = C. WV, SSV, MV = 0. IA, OA = OTG. 13:00 10/31/2019 T/I/O = 280/1260/70. Temp = 90°. WHPs (post wellhead repair). AL online. OA CVs removed, 2" block valves installed. Small speratic bubbling detected in the 12, 3, and 6 o'clock flutes. 0% LELs @ bubbling or throughout wellhouse. TP increased 50 psi, IAP decreased 40 psi, OAP decreased 10 psi overnight. 11/1/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 22:00 T/I/O = 280/1280/60. Temp = 90°. WHPs (post wellhead repair). AL online. OA CVs removed, 2" block valves installed. Small speratic bubbling detected in the 12, 3, and 6 o'clock flutes. 0% LELs @ bubbling or throughout wellhouse. TP unchanged, IAP increased 20 psi, OAP decreased 10 psi overnight. 11/3/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 00:00 T/l/O = 280/1380/50. Temp = 90°. WHPs (post wellhead repair). ALP = 1380 psi, open @ CV. IAP increased 100 psi, OAP decreased 10 psi overnight. Slight bubbling in the conductor at the 9 o'clock position has 0% LEL's 1 in and 1 ft above. 11/4/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 15:10 T/I/O = 300/1280/50. Temp = 90°. WHPs (post wellhead repair). AL online. IAP decreased 100 psi, OAP unchanged overnight. Slight bubbling in the conductor at the 12 & 9 o'clock position has 0% LEL's @ 1" and 1' above. 11/5/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 14:45 T/I/O = 300/1290/40. Temp = 90°. WHPs (post wellhead repair)k). AL online. IAP increased 10 psi, OAP decreased 10 psi overnight. Slight bubbling in the conductor at the 12, 3 & 9 o'clock position has 0% LEL's @ 1" and V above. 11/6/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 15:30 T/I/O = 260/1250/40. Temp = 90°. WHPs (post wellhead repair). AL online. TP decreased 40 psi, IAP decreased 40 psi overnight. Slight bubbling in the conductor at the 12, 3 & 9 o'clock position has 0% LEL's @ 1" and V above. 11/7/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 13:45 TWO = 290/1260/40. Temp = 85°. WHPs (eval IAxOA). AL online @ 1260 psi. OA cemented to surface. TP increased 30 psi, IAP increased 10 psi and OAP unchanged since 11/07/19. Intermittent bubbling in conductor @ 3, 6, 9 & 12 o'clock positions, 0% LELs @ 1" & V above bubbling. OA CVs removed, 2" block valves installed. 11/9/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 02:30 T/I/O = 290/1260/40. Temp = 85°. WHPs (eval IAxOA). ALP = 1260 psi and open. OA cemented to surface. WHPs unchanged since 11/09/19. Intermittent slow bubbling in conductor @ 3, 6, 9, & 12 o'clock positions. 0% LELs @ 1" & V above bubbles. Block valves installed on OA. 11/9/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 23:00 TWO = 280/1220/30. Temp = 88°. WHPs (Eval IAxOA). ALP = 1220 psi, AL open @ casing valve. TP decreased 10 psi, IAP decreased 40 psi, and OAP decreased 10 psi since 11/09/19. No bubbling in conductor at this time. 11/11/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 09:30 TWO = 230/1230/30. Temp = 86°. WHPs (Eval IAxOA). ALP = 1230 psi, AL open @ casing valve. TP decreased 50 psi, IAP increased 10 psi, and OAP unchanged overnight. No bubbling in conductor at this time. 11/12/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 16:30 T/I/O = 240/1220/40. Temp = 86°. WHPs (eval IAxOA). ALP = 1220 psi, AL open @ casing valve. TP increased 10 psi, IAP decreased 10 psi, and OAP increased 10 psi since 11/12/19. No bubbling in conductor at this time. Integral flanges and quarter turn block valves still on OA. 11/14/2019 ISV = C. WV, SSV, MV = 0. IA, OA = OTG. 11:00 TOPOF4-ir-P 10408" 2" TBG, 12.6#, 13CR-85 VAM TOP, 10417' 52 bnf. D = 3.958" 1 OP OF CHrtENT(1221/14) 1-t_10429- 7- - 10429'7" LNR 26#, L-80 HY D 5631BTC-M, 10559' .0383 bpf. D = 6.276" PERFORATION SLUVARY REFLOG: REALTIMELWDon 12119/14 ANGLEATTOPPERF: 88° @ 11949 Note: Refer to Production DB for historical perf data -PERF S(AMAARY ON PG 2- 1 1 PBTD 13339' 2" LNR, 12.6#, 13 -CR VAM TOP, 13423' 52 bpf, D = 3.958" 10259" 1-14-12" OTIS X NIP, D = 3.813" 10290' 7" X 4-1/2" HES TNT LTP, ID= 10327' 4-12" OTIS X NIP, D = 3.813' 0399' 4-12" HES XN NNPD = 3 725" 10408 _7"XS"BKRHRD-EZXPLTPw 10417 4-1/2" WLEG. D=3.958" 10432 7" X 5" BKR BKR FLEXLOC LNR HGR D = 4.330" 10442 5"X 4-1/2" XO, D = 1900" 11800 RA TAG ON MARKER.IT 12900-�RATAGONMARKERJT DATE REV BY COMMENTS DATE 71REP= 4-1/16" CAN QU ES. ORIGINAL COMPLETION Y 14C SAFETY NOTES: LL 10/31/19 ACTUATOR= BAKERC CTO TOE OUT DRILL (Y-148) A ■ MAX DOGLEG:8.1E @ 122246' **7401/2' CHROME OB. EPB/ = 79.8' DM/JMD FINAL ODE APPROVAL TBG & LNR EPD/JMD GLV C/O (0925/19) REP EPEV = 83.38' BF. BEV = 50AV KOP= 4250' 20" CONN, 116' # 1959' 9-5/8" HES ES CHu1B•IfER Max Angles = 109'(g? 11265' p= " 1996' 4-112" OTIS X AW, D = 3.813" Datum MD = 10561' Datum TVD= 88001SS 9-5/8" CSG, 47#, L-80 VAM TOP HC, D=8.861" 2003• GAS LFT MANDRELS 9-5/8" BOWBJ CSG PATCH, ID= 9.060" 2003' - 2007' ST MD ND DEV TWE VLV LATCH PORT DATE 5 3728 3726 0 MMG DOME RK 16 1023/19 TOC (10/07/88)COPFIRM®w/USIT (11/21/4) 2100• 4 3 5758 8162 5527 7013 39 46 MMG DOME RK KBG-2 DOME BK 16 16 1023/19 1023/19 133/8" CSG, 6871, L-80, D= 12.415" 2686' 2 1 9358 10181 7940 8586 39 38 KBG-2 DOME BK KBG-2 SO BK 16 24 1023/19' 1023/19. 5870' 9-518"X7' BKR HR0.E ZXPN LTP, D=6.170" Minimum ID = 3.725" @ 10399" 4-1/2"XNNIPPLE 5886' 9-5/8"X7"BKR FLEX LOCK LNR HGR,1)=6.190" 9-518"WHFSTOCK (11/30/14) 8024' 9-518" MLLOUT WINDOW (Y -14C) 6024' - 6041' 9-518" CSG, 47#, L-80 NSCC, D= 8.681" -6024' TOPOF4-ir-P 10408" 2" TBG, 12.6#, 13CR-85 VAM TOP, 10417' 52 bnf. D = 3.958" 1 OP OF CHrtENT(1221/14) 1-t_10429- 7- - 10429'7" LNR 26#, L-80 HY D 5631BTC-M, 10559' .0383 bpf. D = 6.276" PERFORATION SLUVARY REFLOG: REALTIMELWDon 12119/14 ANGLEATTOPPERF: 88° @ 11949 Note: Refer to Production DB for historical perf data -PERF S(AMAARY ON PG 2- 1 1 PBTD 13339' 2" LNR, 12.6#, 13 -CR VAM TOP, 13423' 52 bpf, D = 3.958" 10259" 1-14-12" OTIS X NIP, D = 3.813" 10290' 7" X 4-1/2" HES TNT LTP, ID= 10327' 4-12" OTIS X NIP, D = 3.813' 0399' 4-12" HES XN NNPD = 3 725" 10408 _7"XS"BKRHRD-EZXPLTPw 10417 4-1/2" WLEG. D=3.958" 10432 7" X 5" BKR BKR FLEXLOC LNR HGR D = 4.330" 10442 5"X 4-1/2" XO, D = 1900" 11800 RA TAG ON MARKER.IT 12900-�RATAGONMARKERJT DATE REV BY COMMENTS DATE REV BY COMMENTS QU ES. ORIGINAL COMPLETION 10!31/19 LWJMD PULLED PXN PLUG (1023/19) LNDER SIDETRACK (Y -14A) 10/31/19 LGMMD GLV C/O (1023/19)CHA(AK CTO TOE OUT DRILL (Y-148) A D-14 SIDETRACK (Y -14C) DM/JMD FINAL ODE APPROVAL EPD/JMD GLV C/O (0925/19) 10 PRUDHOE BAYUNrr WELL: Y -14C PERMrr No: '2141200 API No: 50-029-21832-03 SEC 34, T1 i N, R1 3E, 492' FNL & 708' BP Exploration (Alaska) TREE= 4-1/16" CNV VyH_LHEAD= MCEVOY ACTUATOR= BA1032C OKB- ELEV = 79.8' REF ELEV = 83.38' BF. ELE\(= 50.16' KOP= 4250' Max Angle = 109' Q 11265' Datum MD= 10561' Datum TVD= 8800'SS PERFORATION SLI MARY REFLOG: REALTFELWDon 12/19/14 ANGLEATTOP PERF: 88 -@11949 - 8°Q11949'Note: Refer to Production DB for historical pert data Note, SIZE SPF WTEWAL Opn/Sqz DATE SOZ 2-7/8" 6 11949 - 12059 O 12/23/14 1227114IDETRACK (Y-140) 2-7/8" 6 12219 - 12314 O 1223/14 10/02/19 DG 9) 2-12" 6 12321 - 12352 O 0828/18 2-1/2" 6 12747 - 12778 O 0827/18 2-12" 6 12830 - 12861 O 0827/18 2-12" 6 12869 - 12898 O 0826/18 2-7/8" 6 13049 - 13229 O 1223/14 2-7/8" 6 13304 - 13339 O 1223/14 Y -14C SAFETY NOTES: WELL ANGLE> 700 Q 10916'. "' MAX DOGLEG: 1B.1° Q 12246""4-12" CHROME TBG & LNR DATE COMMENTS DATE REV BY COMMENTS 10107188RIGINAL COMPLETION 1 Dl31/19 LGJMD PULLED PXN PLUG (1023/19) 11101195 SIDETRACK (Y -14A) 10/31/19 LG/JMD GLVC/O(1023/19) 08107MI TD TOE OUT DRILL (Y -14B) d/JGLVGJ0(09/25/19) 1227114IDETRACK (Y-140) 01/14/15 MAL ODE APPROVAL 10/02/19 DG 9) PRUDHOE BAYUNIT WELL: K74C PERMD No: '2141200 API No: 50-029-21832-03 T11 N, R1 3E. 492' FNL & 706' BP Exploration (Alaska) THE STATE °fALASKA GOVERNOR MIKE. DUNLEAVY Aras Worthington Interventions and Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU Y -14C Permit to Drill Number: 214-120 Sundry Number: 319-403 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W W W.aogcc.alaska.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. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this S day of September, 2019. RBDMSI, 11 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair -Well 0 • Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program. ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other OA WeIILock Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0- 5. Permit to Drill Number: 214-120 ' 3_ Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number 50-029-21832-03-00 7. If perforating: What Regulation or Conservation Order govems well spacing in this pool? 8, Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 21 PBU Y -14C - 9. Property Designation (Lease Number): 10, Field/Pools: ADL 028287 PRUDHOE BAY. PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (it): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13425 • 8994 13339 9006 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 36-116 36-116 Surface 2654 13-3/8" 36-2690 36-1... 5020 2260 Intermediate 5991 9-5/8" 33-6024 33-5735 6870 4760 Liner 4689 7" 5870-10559 5615-8882 7240 5410 Liner 3015 4-1/2" 10408 - 13423 8763 - 6994 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Gretle: Tubing MD (ft): 11949 - 13339 9004. 9005 4-1/2" 12.61E 13Cr85 31 - 10417 Packets and SSSV Type: 4-1/2" HES TNT Perm Packer Packers and SSSV MD (ft) and TVD (ft): 10290 / 8671 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic ® 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ P ry S[ratigrephic ❑ Development 8 Service ❑ 14. Estimated Date for Commencing Operations: September 10, 2019 15, Well Status after proposed work: Oil El WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington, Aras J be deviated from without prior written approval. Authorized Name: Worthington, Area J Contact Email: Area Worthington0bp.com Contact Phone: +1 907 564 4102 Authorized Title: Interventions Integrity Engineer Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. /✓• /t1 10 - L4 O� (/ Plug Integrity 11 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other Post Initial Injection MIT Req'd? Yes ❑ No ❑- / 36DMS.SEP 0 5 2019 Spacing Exception Required? Yes ❑ No Irl Subsequent Form Required: W-46 L% APPROVED BYTHE Approved!C� COMMISSIONER COMMISSION 7/'01 Date: Form 10-403 Revised 04/2017 ORIGINAL kfte0o Submit Form and Approved application is valid for 12 months from the date of approval.`%/� Attachments lin Duplicate by �'t►• Well: Y -14C Y -14C OA WellLock Squeeze Well Interventions Engineer: Aras Worthington (907) 564-4102 Pad Engineer: Jordan Haffener (907) 564-5383 Expected Start Date: September 10t' 2019 History Y -14C is a 2014 RST. With a known SC leak at 79' discovered during drilling screening in April 2014, the rig set a 9-5/8" Vamtop casing patch and cemented the OA to surface to fix a known SC leak. By April 2015, bubbling was being observed in the cellar. In June 2015, An MIT -OA to 1200 psi failed with fluids coming to surface in the conductor. An OA downsqueeze with squeezecrete in February 2016 remedied the SC leak enough to allow for operability. Throughout 2016, 2017 and 2018, bubbling has been observed in the cellar, but with LEL readings below the threshold required for operability, no action was taken. On October 27, 2018 after being SI for facility water handling constraints, OA pressures rose above 1000 psi, exceeding NOL. With rapid bubbling, 20% LEL readings 1' above the flutes (10% LEL 1' above flute is the operable limit) and recurring OA re -pressurization (0 psi to 800 psi in 17 min), the well has progressed from being classified as under evaluation to not operable. A Well Lock OA squeeze was Sundried and performed in April of 2019 successfully as a remedy but the OA resumed re -pressurization in August 2019. The well has since been re-classified as "Under Evaluation" and will most likely go Not -Operable in the next couple weeks. The purpose of this procedure is to remedy the OA re -pressurization by performing an OA downsqueeze with Well Lock as a re -squeeze, combined with IC pack -off sealant treatments since the IC packoffs appear to be leaking as well. Current Status The well is currently shut-in and is classified as "Under -Evaluation" by BP. Objective Squeeze the cemented OA with Well Lock to seal off the OA re -pressurization. Procedure 1. ND OA Gate Valves, NU OA Integrals. 2. Pack the IC void and squeeze with green -stick packing. 3. Squeeze the OA and the IC void with Well lock to 2500 psi. 4. Monitor for —14 days to cure Well Lock. 5. ND OA Integrals, NU OA gate valves. 6. POP well Under -Evaluation and monitor OA for re -pressurization. T14M 4-1/16' CAV VVELLFAD- MCEVOY ACTUATOR = BAKER C OKB. ELEV = 79.8' REF ELEV = 83.38' BF. �E1/ = 50.1(1 20" COFD," 115' KOP = - - - 425(7 #, Max Angle = 109' @ 11266 _ Datum MD= 10561' D Datum ND= 8800'SS 9-5/8" CSG, 47#, L-80-VAM TOP HC, D = 8.861' 2003' 9-5/8' BOWEN CSG PATCH, D = 9.060' 2003'-2007' TOC (10/07/88)CONFIRM®w/USR(11/21/14) 2100' 13-38" CSG, 689, L-80, D = 12.415' 2686' Minimum ID = 3.725" @ 10399- 4-1/2" XN NIPPLE 9-5/8'V*WSTOCK(11/30/14) 6024' 9-5/8' CSG, 47#, L-80 NSCC, D = 8.681'-8024' OF 4-1/2' LNR I4-1/2" TBG, 12.6#, 13CR-85 VAM TOP, n153 Mr in= v agn- 1 10429' 1 7" LNR 26#, L-80 HYD 563/BTC.K .0383 bpf, ID = 6.276" PERFORATION SUI&ARY REFLOG: REALTIWLWDon 12/19/14 ANGLEAT TOP PERF: 880 @ 11949' Nute: Refer to Production DB for historical cert data ^PERF SWWRY ONFG2- 1 1 PBTD 13339' 4-12" LNR 12.6#, 13 -CR VAM TOP, 13423' .0152 bpf, D= 3.958' SAFETY NOTES' WELL ANGLE > 70° @ 10916'. •" Y -14 C MAX DOGLEG: 18.1 e @ 12246' ""4-12" CHROME TBG & LNR r 1959' 9-5/8' FR ES ES CEAWl"E t 1996' 4-12' OTIS X NP. D = 3.813' ST MD ND DEV NPE VLV LATCH PORT DATE 5 3728 3726 0 MMG DOME R( 16 04/27115 4 5758 5527 39 MMG DORE RK 16 04/27115 3 8162 7013 46 KBG-2 DOW BK 16 04127/15 2 9358 7940 39 KBG-2 DOME SK 16 04/27/15 1 10181 8586 38 KBG-2 SO BK 24 04/27115 5870' _J—±!L8" X 7" BKR FR0.E ZXPN LTP, D = 6.170' 58$6' 9-58' X 7" BKR FLED( LOCK LNR FIGR [)=6.190- 9-5/8' =6.190"9-5/8' MLLOUT WINDOW (Y -14C) 6024'-6041' 10259' H4 -i/2" OTIS X NP, D = 3.813' 10290' 7" X 4-1/2' FES TNT LTP, D= 3.856' 10327 10399' a 12" OTIS X NP, D = 3.813- 4-12" FES XN NP, D = 3.725' X 5' BKR HRD-E ZXP L 1 10417 1 10932 i 7- X 5" BKR BKR FL LNR HGR D = 4.33( 10442 5' X 4-12' XO, ID= 1 12900 1 DATEREV BY ODMI&NTS DATE REV BY COM LENTS 10107188 QU6. ORIGINAL COMPLETION 03/03/16 GGJM) ADDED REFELEVV 11101195 LINDER SIDETRACK(Y-14A) 01/04117 JUJM) CORRECTED 13-3/8' CSG WT 08/07101 CWKAK CTD TOE OUT DRILL (Y -14B) 08/29/18 JTCJJMD ADPERFS (08(26-28/18) 1227114 D-14 SIDETRACK(Y-M) 11/08/18 JNJADWI)DED BF& CONDUCTOR Damis 01114/15 OAYJA,D I FINAL ODE APPROVAL 05/04115 TJWJMJ GLV C(O(0427/15) P RUDHOE BAY LUT WELL: Y -14C PERMT W: 2141200 AN ND: 50-029-21832-03 SEC 34, T11 N, R1 3F, 492' FNL & 706' FAL BP Exploration (Alaska) TREE= 4-1116' CMJ WELL/ -FAD= MCEVOYi ACTI,IATOR= BAKER C! ORB. ELEV = --- 79-V REP aEV = 83.38'1 BF. AEV = _ - 50.16'1 KOP= 425(, Max Angle = 109° @ 11269 Datum MD = 10561' Datum TVD = 8800'SS PERFORATION SUMMARY REFLOG: REALTTuELWDon 12!19/14 ANGLE AT TOP PERF: 88° @ 11949 Note: Refer to Production DB for historical peri data SIZE SPF INTERVAL OprVSgz DATE SOz 2-7/8" 6 11949- 12059 O 12123/14 05/04/15 TJWJMD GLV C/O (04/27/15) 2-7/8" 6 12219 - 12314 O 12Y23/14 2-112" 6 12321 - 12352 0 08/28/18 2-112" 6 12747 - 12778 O 08/27118 2-112" 6 12830- 12861 O 08/27/18 2-1/2' 6 12869-12898 0 08Y26118 2-718" 6 13049- 13229 0 12/23/14 2-7/8" 6 13304 - 13339 O 17!23114 Y-1 4C SAFETY NOTES: WELL ANGLE > 70° @ 10916'. "' MAX DOGLEG:18.1- @ 12246' "-4-112- CHROME TBG & LNR DATE REV BY CONVENTS DATE REV BY COMIr64TS 10/07/88 DUES. ORIGINAL COMPLETION 03/03/16 C0JhD ADDED REF E_EV 11101195 UNDER SIDETRACK (Y -14A) 01/04/17 JUJMD CORW=13-3/8" CSG W! 0&07101 CHKAK CTD TOE OUT DRILL (Y -14B) 08129/18 JTC/JIoD ADPERF-S (08126-28118) 12/27114 D.14 SIOETRACK(Y-14C) 11/06/18 &UJhD ADDED BF& CONDLICTOR DEPTHS 01/14/15 DMJM3 FINAL ODEAPPROVAL 05/04/15 TJWJMD GLV C/O (04/27/15) PRIAHOE BAY LINT WELL: Y -14C PERMIT No: '2141200 AH No: 50-029-21832-03 SEC 34, T1IN, R13F- 49Z FW & 706 FWL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAY In on1n 171, 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change A - g Approved Program "�❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: OA Squeeze 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Dnil Number. 214-120 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Strattgraphic ❑ Service ❑ 1 6. API Number: 50-029-21832-03-00 7. Property Designation (Lease Number): ADL 028287 8. Well Name and Number: PBU Y -14C 9. Logs (List logs and submit electronic and panted data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 13425 feet Plugs measured None feet true vertical 8994 feet Junk measured None feet Effective Depth: measured 13339 feet Packer measured 10290 feet true vertical 9006 feet Packer true vertical 8671 feet Casing: Length: Size. MD: TVD: Buret: Collapse: Structural Conductor 80 20" 36-116 36-116 Surface 2654 13-3/8" 36-2690 36-2689 5020 2260 Intermediate 5991 9-5/8" 33-6024 33-5735 6870 4760 Liner 4689 7" 5870-10559 5615-8882 7240 5410 Liner 3015 4-1/2" 10408-13423 8763-8994 8430 7500 Perforation Depth. Measured depth: 11950 - 13340 feet True vertical depft 9004-9005 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr85 31 -10417 31 -8770 Packers and SSSV (type, measured and 4-1/2" HES TNT Perm Packer 10290 8671 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Strap for TOC @ —3" (5 gal void) Filled void & squeezed to 2500 psi with 2.75 gal WeIlLock. 1/8 gallon of water displaced from OA. Continue to bump up to 2500 psi to maintain sqz pressure for 2 hire. Monitor and maintain wellhead temp 60 - 90f until WeIlLock cures. Monitor for 14 days. Sample is setup. Intervals treated (measured): Squeeze the cemented OA to TOC Treatment descriptions including volumes used and final pressure: 2.75 gal WeIlLock Final Pressures: OA = 0 psi, IA = 1648 psi, TBG = 285 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water-Bbi Casing Pressure Tubing Pressure Prior to well operation: 118 2816 753 1774 231 Subsequent to operation: 183 2695 718 1648 285 14.Attachments: (ieguihm per20MC 2507025.071, a 25.285) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-499 Authorized Name: Worthington, Area J Contact Name: Worthington, Area J Authorized Title: Interventions & Integrity Engineer Contact Email: Aras.Worthingbn0bp.com 09 Authorized Signature: Date: '.� Contac Phone: +1 907 564 4102 Farm 10-404 Revised 04/2017 /0t/r1 g3, ^ti9 RBDMS-wJ MAY 3 12019 Submit Original Only Daily Report of Well Operations PBU Y -14C Ar.TIX/ITVrt&TF ci IRARAAMV T/I/O=SSV/390/35. Pre Well Lock. RD 2" OA and companion flange, RU integrals torque to API specs. 188 FT/LBS. RU block valves with 1502 caps. Strap TOC, 9 oclock outlet VR profile half full of cement. 3 oclock outlet 2" deep. ***JOB COMPLETE***. See log for details. Final WHP's 4/8/2019 SSV/30/0. TWO = SSV/350/0. Temp = SI. Steam clean OA pre Wellock treatment. 2" integrals installed on both side outlets of OA casing spool. OA cemented to surface. Initial returns vull of contaminant, began clearing up -5 minutes into steaming OA. Steamed OA until clean returns @ surface. Used heater to dry OA void. Job in progress. Heater in well house, working properly, door ajar. 4/10/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 17:00 Job Scope: WellLock Sqz OA TIO- SSV/390/4. TOC @ -3" (5 gal void) Filled void&seueezed to 2500 osi with 2 75 gal WellLock. 1/8 gallon of water displaced from OA. 4'2" 1502 pup joint on pump -in side to serve as a reservoir for excess WellLock with gas charged hose with 1600 psi for accumulator. Continue to bump up to 2500 psi to maintain sqz pressure for 2 hrs. Monitor and maintain wellhead temp 60 - 90f until Wellock cures. OAP = 1400 psi upon departure. 4/14/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 16:15 T/I/O = SSV/400/930. Temp = SI. WHPs (post Wellock). ALP = 1390 psi, AL SI @ casing valve. WHT = 52*. Adjust heater. WHT = 70° after adjusting heater & monitoring. OAP decreased 670 psi since 02:00 hrs. Sample not set up. Heater working properly. 4/15/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 11:30 TWO = SSV/420/500. Temp = SI. WHPs (post Wellock). ALP = 1370 psi, AL SI @ casing valve. WHT = 38*. Adjust heater. WHT = 85° after adjusting heater & monitoring. OAP decreased 210 psi since 00:20 hrs. Sample not set up. Heater working properly. 4/16/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 13:20 T/I/O = SSV/420/350. Temp = SI. WHPs (post Wellock). ALP = 1370 psi, AL SI @ casing valve. WHIT = 55*. Adjusted heater. WHT = 850 after adjusting heater & monitoring for 30 min. OAP decreased 260 psi since 1:AM. Sample is still not set up. Heater working properly. 4/17/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:00 T/1/0 = SSV/420/200. Temp = SI. WHPs (post Wellock). ALP = 1340 psi, AL SI @ casing valve. Slight bubbling @ the 1:00 flute. WHT = 82*. OAP decreased 60 psi since 00:45 AM. Sample is firm not hard. Heater working properly. 4/18/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 T/1/0 = SSV/420/150. Temp = SI. WHPs (post Wellock). ALP = 1340 psi, AL SI @ casing valve. WHT = 59°. Readjusted the heater hose. OAP decreased 50 psi since last monitor. Sample is set up. Heater working properly. Bubbling activity in the flute at 12 o'clock position no LELs from 1' above. Final WHT = 850- 4/19/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:00 TWO = SSV/420/100. Temp = SI. WHPs (post Wellock). ALP = 1340 psi, AL SI @ casing valve. WHT = 70°. Readjusted the heater hose. OAP decreased 50 psi since last monitor. Sample is set up. Heater working properly. Bubbling activity in the flute at 12 o'clock position no LELs from 1' above. 4/20/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:35 T/l/O = SSV/420/60. Temp = SI. WHPs (post Wellock). ALP = 1340 psi, AL SI @ casing valve. WHT = 72*. Readjusted the heater hose. OAP decreased 40 psi since last monitor. Sample is set up. Heater working properly. Bubbling activity in the flute at 12 o'clock position no LELs from V above. 4/23/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 02:10 T/1/0 = SSV/420/01. Temp = SI. WHPs (post Wellock). ALP = 1340 psi, AL SI @ casing valve. OAP decreased 39 psi since 4/23/19. Sample is set up. Bubbling activity in the flute at 12 o'clock position no LELs from V above. 4/25/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:00 Daily Report of Well Operations PBU Y-14C T/1/0 = SSV/420/01. Temp = SI. WHPs (post Wellock). ALP = 1400 psi, AL SI @ casing valve. WHPs unchanged in 18 hours. Sample is set up. Slow bubbling activity in the flute at 12 o'clock position no LELs from V above. 4/26/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 15:00 TWO = SSV/420/0. Temp = SI. WHPs (post Wellock). ALP = 1400 psi, AL SI @ casing valve. OAP @ 0 psi on both sides of wellhead. Sample is set up. Slow bubbling activity in the flute at 12 o'clock position no LELs from V above. Assist Valve Crew as needed. Integrals removed & OA casing valve installed. 4/28/2019 API Valve Crew in control of well on departure. 1145 hrs. T/I/O = SSV/420/0+. Temp = SI. WHPs (Post Wellock). ALP = 1400 psi, SI @ CV. WHPs unchanged overnight. Slow bubbling activity in the flute @ the 12 o'clock and smaller bubbles @ the 9 o'clock position. LELs = 0% @ bubbling and throughout wellhouse. 4/29/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 11:00 T/I/O = SSV/430/0+. Temp = SI. WHPs (Post Wellock). ALP = 1350 psi, SI @ CV. IAP increased 10 psi since 4/29/19. Slow bubbling in the conductor flutes at the 9 and 12 o'clock positions. No LEL's above bubbling. 5/3/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:10 TWO = SSV/430/0+. Temp = SI. WHP's. (Post wellock). ALP = 1390 psi & SI @ IA casing valve. No change in WHP's overnight. Slow bubbling @ the 12 & 9 O'clock positions, No LEL's detected V above bubbling or anywhere else in the well house. 5/4/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 15:55 T/1/0 = SSV/430/3. Temp = SI. WHP's. (Post wellock). ALP = 1350 psi, AL SI @ casing valve. No change in WHP's overnight. Slow bubbling @ the 12 & 9 O'clock positions, No LEL's detected V above bubbling or anywhere else in the well house. 5/5/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 14:30 TWO = 210/1590/20. Temp = 94°. WHP's. (Post wellock). ALP = 1590 psi and is online. No bubbling in conductor present at this time. 5/24/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 14:00. TWO = 210/1590/20. Temp = 92°. WHPs (Post wellock). ALP = 1590 psi, AL open @ casing valve. No bubbling in conductor at this time. TP, IAP, and OAP unchanged since 05/24/19. 5/26/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 03:45 TAM = 220/1620/20. Temp = 92°. WHPs (Post wellock). ALP = 1620 psi, AL open @ casing valve. ISV No bubbling in conductor at this time. TP increased 10 psi, IAP increased 30 psi, and OAP unchanged since 05/26/19. 5/28/2019 = C. WV, SSV, MV = 0. IA, OA = OTG. 02:30 TREE = 4-1116* CMI [20#;ODND,,. D- WELLHEAD= MCEVOY ACTUATOR= BAKER OKB- ELB/ = 79.8' REF EURf = 83.38' BF. H.EV = SDAV KOP= 425(Y Max Angle = 109' @ 11265 Datum 4/7= 10561' DatumTVD= 8M' SS 9-5/8" CSG, 47#, L-80 VAM TOPHC, D=8.861• 9-5/8" BOWBN CSG PATCH, D= 9.060• , 113-3/6- L-iG. 6M. L-60, D = 12.415• 1� 2686' Minimum ID = 3.725" @ 10399' 4-1/2" XN NIPPLE ¢sr6• vH IPs7oac (11/3o/1a> 6o2s• CSG, 47#, L-80 HeCC, D 7-i.681, H -6024' 4-1/2• TBG, 12.6#, 13CR-85 VAM TOP, H 10417- .0152 bpf, D = 3.958• TOPOFCEM1BNr(12/21/ta) 1042W 7" LNR, 26#, L-80 HYD %3/BTC-M,10559' .0383 bpf, D= 6.276• PERFORATION SIMMARY REFLOG: R=AL TI E LWDon 12/19/14 ANGLEATTOPPERF. 8FP 1-Q 11949' Note: Refer to Production DB for historical pert data WE SPF INF62VAL OWSgz IDATE S(]Z -PEW Sl1MMARY ON PG 2- PBTD .0152 bpf, D = 3.958" Y -14C MAX DOGLEG: 8N1 @12ELL M2446E'"74-1/2'CHROME TBG & LNR 1 1996' 1 ST MD TVD DEV TYPE VLV LATCH FORT DATE 5 3728 3726 0 MMG DOME R( 16 04/27/15 4 5758 5527 39 MMG DOW R< 16 04/27/15 3 8162 7013 46 KBG-2 DOME BK 16 1 04/27/15 2 9358 7940 39 KBG-2 DOME BK 16 04/27/15 1 10181 8586 38 KBG-2 SO &C 24 04/27115 5870' H9 -51W X 7- BKR H O -E ZXPN LTP, D = 6.17 "°w J 9-5/8" X 7" BKR FLEX LOCK LN2 FK3R D = 35/8• MU-0Lfr WIDOW (Y -14C) 6024'-6041- 10259' H4-1/2.OT6 X NP, D = 3.813- 10290' 7" X 4-1/2• FES TNT FTP, D= 14-1/2" HES XN NP. D=3.725" 1 17• X 5• BKR HiflE ZXP LTP w /TEBACK, O = 4340" I 10417 1-j4-1/2• WLEG, D = a95ir ��EiMD TT NO7 LOGGED 10432 H7XI 5" BKR BKR FLEXLOCK DG LN2 HGR D = 4.330" 10442 5• X 4-1Y2" XO, D = 3.900" 11800 RA TAG ON MARKER Jr 12900 --j RA TAG ON MARKER JT DATE RI -V BY COMMENTS DATE I REV BY I COMMENTS 10107/88 OL1E5. ORGINALCOMPLETION 03/03116 GCIJM) ADDED REF a" 111(1195 CINDER SIDETRACK(Y-14A) 01104/17 JUJM) CORRECI®133J8' CSG WT 08107101 CHKAK CTD TOEOtJT DRILL (Y-148) 08/29118 JMJM) ADPERF5 (0&26-28118) 12/27/14 0-14 SIDETRACK(Y-14C) 11/06118 JNJJbD ADDED BF B CONDUCTOR DEPTHS 01/14/15 DMJMJ FNALODEAPR20VAL 05/04/15 TJWJMD GLV CIO (04127/15) Pi2lAFDEBAY LfNiT WELL: Y -14C PERMIT No: '2141200 AN No: 50-029-21832-03 SEC 34, TI 1N, R13E, 492' FN- 8 706' FWL BP Elrpioration (Alaska) TREE= 4-1/16' CNV WE.LFEAD= MCEVOY ACTUATOR= BAKER OKB. AEV = 79.8' IMF AEI = 83.38' BF. ELEV = 50.16' KOP= 4250' Max Angle = 109' @ 11265' Datum M)= 10561' Datum ND= 8800'SS PERFORATION SUMMARY REF LOG: REAL TIME LWD on 12/19114 ANGLE AT TOP PERF: 88° @ 11949' Note: Neter to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE SOZ 6 11949 - 12059 O 12123/14 12/27/14 M14 SIDETRACK (Y.14C) 2-718' 6 12219-12314 O 12123/14 05104/15 TJHJM) GLV CfO (0427115) 2-1/2' 6 12321 - 12352 O 082&18 2-12' 6 12747 - 12778 O 0&27/18 2-12' 6 12830-12861 O 0627/18 2-12' 6 12869-12898 O 0826/18 2-718' 6 13049-13229 O 1223114 2-718' 6 13304 - 13339 O 12/23/14 Y-1 4C SAFETY NOTES: WELL ANGLE > 700 @ 10916*.'** MAX DOGLEG: 18.1° (g 12246'***4-12" CHROME TBG 8 LNR DATE REV BY COMMENTS DATE REV BY I COMMENTS 10/07188 W1ES. OFWANAL COMPLETION 03/03/16 GCOM) ADDED REF ELEV IIMI95 LIIDER SIDETRACK(Y-14A) 01/04/17 JUJM) CORRECTED 13-3/8' CSG WT O8f07101 CHKAK CTD TOE OUT MILL (Y -14B) 08129/18 fTC!JM) AD ERFS (00126-28118) 12/27/14 M14 SIDETRACK (Y.14C) 11106F18 JNJJM) ADDED BF & CONDUCTOR DEFTH6 01114/15 DMJMD FNALODEAFFROVAL 05104/15 TJHJM) GLV CfO (0427115) PRUDHOE BAY UNT WELL: Y -14C PERMIT No: '2141200 AR No: 50-029-21832-03 SEC 34. T11K R13E 492 FTL 8 706' PNL BP Btitloration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Wf Re-enter Susp Well 0 Other:Micro-Annulus Cmt Sqz I1 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 214-120 3. Address: P.O.Box 196612 Anchorage, Development ll Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21832-03-00 7. Property Designation(Lease Number): ADL 0028287 8. Well Name and Number: PBU Y-14C 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 13425 feet Plugs measured feet true vertical 8994 feet Junk measured feet MAR 0 7 2016 Effective Depth: measured 10399 feet Packer measured 10290 feet ��true vertical 8756 feet Packer true vertical 8671.18 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 37-117 37-117 1490 470 Surface 2654 13-3/8"68#L-80 36-2690 36-2689 5020 2260 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11950-12060 feet 12220-12315 feet 13050-13230 feet 13305-13340 feet True vertical depth: 9004-9007 feet feet 9009-9013 feet 9021-9013 feet 9009-9005 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr85 31 -10417 31-8770 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): OA Surface ��''`` F r P 2 `;i y Treatment descriptions including volumes used and final pressure: " /'"' ' 3 28 Gallons SqueezeCrete Cement,2300 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 85 968 704 1372 264 Subsequent to operation: 197 3452 1128 1467 284 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I3 Exploratory ❑ Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-457 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature irb/Xv1, Phone +1 907 564 4424 Date 3/3/16 Form 10-404 Revised 5/2015 �` ii/IIRBDMS i,v MAR 0 9 2016 Submit Original Only "49,t(4‘ • • • w Q p o 0 0 _0 0 0 �a � cococo ov N N- N O 0 O N "Cr d- O N. CO 0 N o 0 0 0 0 0 0 i O) CN N. N. "sr CO N 0 CO CO N V O (0 M N- CO O) 6) O O N V O CO O M CO O N- CO O N- CO O N- N N 10 CO CO CO Cl H Nr In Cr) I� CO CO O N- M a- CO M M O M r Cr) N O CO AFI C M E O O 00 O N N N O u-)N ON CO O M O CO o CY C 1111111 • 0 Q C° � � r` cocoo � co co co O CO p C N • O LC) CL p O O co ca 0000 � UU = J co co •N Nco J �# # CO co - M N N U OC °�° eoao O M 0 0 r N N M O O t D)O IO N CO T- C CO CO O O CO O M J N V M W W Q Q co C OH W 0 0 N o U W W U 0 u Q Ct Z Z W W W W O D H H Z Z D 0cf.) ZZJJI— • • Packers and SSV's Attachment PBU Y-14C SW Name Type MD TVD Depscription Y-14C PACKER 5880.91 5623.61 9-5/8" Baker ZXP Packer Y-14C TBG PACKER 10290.21 8671.18 4-1/2" HES TNT Perm Packer Y-14C PACKER 10418.96 8771.97 5" Baker ZXP Top Packer TREE= 4-i/16"(]W WELLFEAD= KCEVOY 0 Y-1 4C Sy NOTES:WELL ANGLE>70°@ 10916'.*** ACTUATO = BAKER C MAX DOGLEG:18.1°@ 12246'`"4-1/2"CHROME R QKB,REV= 79.8' I I TBG&LNR REf ELEV= 83.38' , . BF B_EV= 50.6' 20'cow, — 110' 1 r_ ...9 1958' —9-5/8"I E..,ES CEMENTER KOP= 4250' __# , • Max Angle= 109°@ 11265' , I 1 1996' —4-1/2'011S X ,NPID 3.813" • 06,.. Datum AC 13= = 10561' Datum TVD= 8800'SS w. rz 9-5/8"CSG,474,L-80 VAM TOP HC,ID=8.861" — ST MD ND DEV TY I VLV LATCH FORT DA 1 E 5 3728 3726 0 MM3 CONE RK 16 04/27/15 9-5/8'BOWEN CSG PATCH,ID=9.060" — 2003'-2007" 11 TOC(10/07/88)CONzRMED w/USIT(1121/14) H 2100' 4 5758 5527 39 MU COME RK 16 04/27/15 3 8162 7013 46 KBG-2 DC'.4E BK 16 04/27/15 13-3/8'CSG,724,L-80,D=12,34T —1 2686' 2 9358 7940 39 KBG-2 COME BK 16 04/27/15 1 10181 8586 38 KBG-2 SO BK 24 04/27/15 Minimum ID = 3.725" @ 10399' \ 5870' —9-5/8'X 7"BKR HRD-EZXPN LTP,ID=8.170" 4-112" I XN NIPPLE 5886' H9-5/8"X 7'BKR FLB.(LOCX LNR HGR,ID=6.190' 9-5/8-VVHFSTOCK(11/30/14) —1 6024' - 9-5/8"CSG 474,L-80 NSCC,D=8.681 I— —60244 , ,-; 1 'Xi-f 9-5/8"ML LOUT WNDOW(Y-14C) 6024'-6041' • I 1---1 10259' —14-1/7 OTIS X NI',ID=3,813" 10290' HT X 4-1/2"FES 1NT LTP,V=3.856' I 1032T I 10399' H4-1/2"I C..,XN NF,D=3.725' 10408 H7'X 5"BKR HRD-E ZXP LTP w/TIEBACK,I)=4.340" I TOP OF 4-1/2"LNR — 10408' 10417 H4-1/2"WLEG,D=3.958" 4-1/7 TBG,12.6#,13CR-85 VAM TOP, 10417" 14 c 41, —RPA)Tr NOT LOGGED .0152 bpf,ID=1958' 4 N, TOP OF CEMENT(12/21/14) —1 10429' e P.4d • ,4 10432 I—7'X 5"BKR BKR FLE)CLOCK DG LNR HGR,ID=4,330" el • '4 % 7"UR 26#,L-80 HY D 563/BTC-M, 1055W /41I 1 '4 0 % 10442 --I5"X 4-1/2"X0,ID=3.900" .0383 bpf,ID=6.276" • 1 4 - % A '4 PERFORATION 11800 —RA TAG ON MA RKBR JT 1 REF LOG: REAL TivE LAD on 12/19/14 ANGLE AT TOP PERF: 88°@ 11949' 1 . Note:Refer to Production 06 for historical perf data j 1 1 . SIZE SPF NTERVAL Opn/Sqz DATE SQZ I I, 2-7/ErP 6 11949-12059 0 12/23/141 ... 12900 —RA TAG ON MARKER Jr 2-7/8"F 6 12219-12314 0 12/23/14 1 q: 4 S. 2-7/8'r 6 13049-13229 0 12/23/14 A II 2-7/8"r 6 13304-13339 0 12/23/14 1 1 1 _ 1 II PBTD — 13339' :', 411.'1, .%/ t° 4-1/2"LNR, 12.6#,13-CR VAM TOP, —I 13423' .0152 bpf,0=1958" DATE RB/BY COMENTS DATE REV BY CONLENTS PRUDHOE BAY INT 10/07188 QUE . ORIGINAL COMPLETION 01/20/15 JLS/JMD GLV C10(01/14/15) WEI_L: Y-14C 11101/95 LANDER-SIDETRACK(Y-14A) 05/04/15 TJ-VJAD GLV C/O(04/27/15) FERMI Pb: '2141200 08/07/01 CI4KAK CT()TOE OUT DRILL (Y-14B) 10/02/15 DJS/JMD SET PXN PLUG(10/01/15) AR No: 50-029-21832-03 12127114 D-14 SIDETRACK(Y-14C) 02/15/16 CJNQM) FULLED PXN PLUG(02/12/16) SEC 34,T11N,R13E,492'FM_&706'FW 12/30/14 JM) DRLG HO CORRECTIONS 03/03/16 GC/JMi ADDED REF REV 01/14/15 OMUkt) F14AL OCE APPROVAL _ BP Exploration(Alaska)k a) • • C)m o w I o o - a) a) (I) © � � sod, 3 ds a) al, i._o o ,..; E 7) .p doors aQ a0O a > o a) Qio E J O 11 CL a) OQ o2 < c co m Q v c o a/ c) (n O C ¢ aO o c0 _cN ._- O rnau o 65 0 •c r .� 0 N c < O c a) .c C)) `. U -a - ... c a .o O E amiVv>) as o 8 •-. i a/ i Yo- - -cos a) O > n EO > M c. co m p 4? a N a) Q p c u) E t > r. � � � a) > � > a) Eo = x E Q /a Z > 00 o)-a o fl co. . 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N •cO = 0 w V J 0 U O II 2 a) p II ...-."' ll O a) � >- p U) ,E3 ai co < � 4-, tC < i < Ory *N- EL u�) 0 a) O0 0 * M O < u, " o c1) z E e3) m * co0mW — c � `t Y Q Y) Q C * Z ' N li c 3 it G Ix * * 0 -Lenv ,v_ a ria) o o__ a) � �11- z < E E � _ > 1- � � > Li 5' 2 0 NQ X W O O a5 a) 6 a) a) a) 'ao0LLZap • < Q .cc>na = 2cccq c) 2U)) U ') F- F- R' NOOOOtL � oc) o � cn � acA N � Z Z p. • o aj O `: - 4*- 2 N -- a00a � � rr > ° ov ° c,, -o c -� U D J �- > 0 7 N N co L.0 t J J W I1 rno 0 ti '� U II U a) cam) > J J z 0 .N M V if Q N ,_- II 0 21it u) Ll Ct : CL CL : UO .CU H F- t4 (� h N0>!) tom - 0 0 0 0 0 O r r r 0 0 0 0 o O N N N N N 3.- n-- N c0 of m , r- N N N N N N N M OF Th. �w\��yj�,S� THE STATE Alaska Oil and Gas 1r�� , of T� 6i. Conservation Commission ri =-;_\ _ Of 333 West Seventh Avenue Tti'• GOVERNOR BILL WALK < R Anchorage, Alaska 99501-3572 Main 907 279 1433 ALAS�'� Fax 907.276 7542 , www aogcc alaska goy Jessica Sayers Well Integrity Engineer r l '"f - I a BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y-14C Sundry Number: 315-457 Dear Ms. Sayers: Enclosed is the approved application for 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. Sincerely, is ',71.4.,_ Cathy P. Foerster ,� ,�,/,� Chair DATED this 4' "day of August, 2015 Encl. RECEDED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION J U L 2 8 2015 APPLICATION FOR SUNDRY APPROVALS 0)s e/ 4-7/5 20 AAC 25 280 //-�� l///'�� 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 ` 'O GPCtbfis shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Progra(�nrt ❑ vY �2c 'Wtt Plug for Redrdl 0 Perforate New Pool 0 .Repair Well M Re-enter Susp Well 0 Other Wi{ell LockCrdcjnnvl"Sm • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 214-120 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development a 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21832-03-00 7 If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No m Will planned perforations require a spacing exception? ❑ PBU Y-14C 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028287 PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft)• Total Depth TVD(ft)' Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13425 8994 1.3339 9006 Casing Length Size MD TVD Burst collapse Structural Conductor 80 20"91.5#H-40 37-117 36-116 1490 470 Surface 2654 13-3/8"68#L-80 36-2690 36-2689 5020 2260 Intermediate 5993 9-5/8"47#L-80 33-6024 33-5735 6870 4760 Production Liner 3015 4-1/2"12.6#13Cr80 10408-13423 8763-8994 8430 7500 Liner 4689 7"26#L-80 5870-10559 5615-8882 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11950-13340 9004 45-9005.48 4-1/2"12.6# 13Cr85 31 -10417 Packers and SSSV Type. See Attachment Packers and SSSV MD(ft)and ND(ft) See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 8 Exploratory 0 Stratigraphic 0 Development ® Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil l! Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval' Date: WINJ 0 GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: Op Shutdown ❑ GSTOR 0 SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sayers,Jessica Email Jessica.Sayers@bp.com Printed Name Sayers,Jessica Title Well Integrity Engineer Signature ; , de Phone +1 907 564 4281 Date -I/2_' I 1 S dCOMMISSION USE ONLY 1 Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 36- 4167 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other Spacing Exception Required? Yes 0 No I I Subsequent Form Required: /O- 4 G 4 APPROVED BYTHE Approved by:247/9014,1,4_,.... COMMISSIONER COMMISSION Date: yr i- e/31/� S-¢-/,s ORIGINAL ,e,�.Ail . -7_ 30•% Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachm t in Duplicate RBDMS AUG 1 4 2015 Packers and SSV's Attachment PBU Y-14C SW Name Type MD TVD Depscription Y-14C PACKER 5880.91 5623.61 9-5/8" Baker ZXP Packer Y-14C PACKER 10290.21 8671.18 4-1/2" HES TNT Perm Packer Y-14C PACKER 10418.96 8771.97 5" Baker ZXP Top Packer It It, le'r It Date: 07-27-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: Y-14 SqueezeCrete/VVellLock MicroOA Squeeze Objective This program is intended to guide the execution of a fully cemented OA, low injectivity, surface casing squeeze repair treatment with SqueezeCrete. This well exhibits bubbling in the conductor when on production and returns fluid to the conductor when pressure tested. As such, it is suspected that the parent leak (leak present prior to fully cementing the OA from surface casing to conductor is the anomaly. SqueezeCrete will be used, followed by a WellLock top job to repair the leak. Well Detail Current Status: Not Operable Previous Test: 07-24-15 MIT-OA to 1200 psi, Fail, Fluid returns to surface 12-25-14 MIT-T to 3500 psi, Pass Integrity Issues: Fully cemented OA; Returns fluid to conductor when pressure tested Last H2S Reading: 04-24-15 22 ppm Well Operation Detail Fluid Density: 14 ppg Equipment: See rig-up diagram Slurry: SqueezeCrete Relevant History: > 05/08/15: MIT-OA Failed > 05/10/15: PPPOT-IC Passed to 3500 psi > 07/24/15: MIT-OA Failed, response in conductor I of 3 Procedure: 1 D Remove blue goo and ice/material in conductor. 2 D Place, Squeezecrete in OA, until clean, 1:1 SqueezeCrete returns are observed. Take returns to a grounded bucket. 3 D Rig up pneumatic pump, and resume pumping operation by squeezing SqueezeCrete into well. Pump until bump (2500 psi max) or until SqueezeCrete returns are observed in the conductor. 4 D Let well cure. 5 D Squeeze WellLock on top of SqueezeCrete, with pneumatic pump (2500 psi max). 6 D MIT-OA to 1200 psi with diesel 2 of 3 1AG_LFEAD- a1/M VOY Y-14C SATT.TYNOTES:WELI.ANC1.E.'70'010916`.". ACTUATOR- BAKER MAX DOGLEG 18.1".12246****LAG"CHROME c>KK a.Fv= r9 a• no, y.31 TOO&LNR BF.ELEV- 50.6' ,-"' :r4 1. KC1P= d250' 20'CORIOLICTF7R, - 1 i 0• ! °+n ...17# ( 1659• I.19-w IES ES CEMENTER • Stu Angle- 109'IS 11265 i� .�l ,,C Datum 113=- 10581' D= cy 1 1 -f� 1986' -14-trd'OTISXNP,13-3,813'-1 I tumTYD' 8800'55 G` .--...........__._._..� S 19-W CSC,474,L-80 V AM TOPHC,1=8881' I..,.1 2003' r'l ..if1.+ ST MD TV!) CH GEf TY FE I VLV LATPORT E I 9-518'804084 CSC PATG-1,D=9-090' 1-1 2003'-2007" // i1 5 3728 3726 0 MMC DOME RK I LAM 16 04127/15 I TOC(1007186)COPFf4I.wA�SIT(111211141 !--- 2100' '�, - 4's 5758 5527 119/1GF6(G DOME 16 04121115 I ` -- 3 i 8162 7013 46 Kt3C>2 DOME BK 16 04/27/15 13-379'CSG,729,L-80.D=12,347• - 26W u[Minimum D■ 3.726"@ 10389' 2 1 9358 79G 40 39 KB2 ODMS BK 16 0427115 ----- 1 10181 8586 38 1,33G-7 SO BK 24 0427715 , 4-112"X N NIPPLE \\\`( 5870'7 19-578'x r BKR F4iOF ZXPN LTP,D=6170' I 19-578'MHIPSTOOt(11130/14) 1 . 6024' L 1 5886' -1 o-548'X r BKR FLEX LOCK LNR-IGF,D=&19on 13-418'CSC,4/it, L a0 14444X1 D a 68E11,4 ..S02,4' 7-_ B-lm'DAMN WNx)W(Y-440)11074'-6641' I, 1 1 ( 10269' 4112"OTBXNP.D•3sir I x I 10290'j-1rX41/2'HES TNT L1P,D-3856• I I 1 t 103217--14•V2'016XM..3)=3.813' I 1 1 I 10366' I 14 Pr its x4Nr,D 3/2 I 10406 1--,7'X 5'SKR 11,414,1 ZXP FTP w 414 BACK.13=4.340' ITOPOF 4-It?'LAP 1-f10408' I \ ^1 10417 1-4.1i. ,M EG 13 3 957'1 4-1'7 TTTG,12.60,13CR-46 u011.4 TOP. I-1 1041— - -- -- --' I ' , ' 41 AK)It W)I t&:(1.:1-. ) t. F1 D=3.95!• ITOP OF CEMENT(12121/14))--, 1429' 10432 './'11"..,-141a14 0104 H FxL UC"'K DG j LNR 11GR.D-4 330" Jj r LAEL 280,1.80 F1YD 563/8TGM - 1 10559' 1E1442 1-15"X 4-1/2"XO,II 3 9001 0383uµd,ri-4..179• .. RRFOlt/19104 SCIMMMFIY s _--j 11800 1 IRA TAC OF.MA RKER JT 1 REF LOG REAL IME LAO on 12/19/14 ANGLEATTOPPI3, 813,40 11949' c Nola_Wee-to Production GB for hil4oncaI pert a4111 SQE SW INTERVAL OpnSat DALE SOZ RA TAG ON MARR JT 1I� 2-7/8'r 6 11949 12069 0 12014 12800 2I/8'r 6 12219-12314 0 1212714 2-718'r 6 13049-13229 0 12/2314 2-778' 6 13304-13339 0 1223714 7' 111 I - . I P9T0 I I 1333W ' t44k 41/YINR1293,13-CRVAMTOP, I 13423' '' 9 ,0132 881,t)•3958' LATE REV BY COMkEMTS DA IE RE1'BY CX)EL 11 -.... , PRUONDE BAY 1.N1 10/07738 QiES- Of6GP1ALCOMPLETION X01120/15 JLSJJ183C,LVGO(01714/15) WR - 3'.14C 11101195 LINDEN SIDETRACK(Y-/4A) ----��--OSX)7115 TJ-3JM)GLV 00(0427/15) PERMIT Hy -2141200 08/07/11 CHKAK CTD TOE OUT DRILL (Y.148) _ AR No. 50-029-21832-03 12127/14 0-14 SIDETRACK(Y-14C) SEC 34,T11N&R13E,492'FHA 706'Mt. 1211/14 .W CeLG 110 CORRECTIONS 01114/15 CliNJOA3 ANAL ODE APFROVAL BP Exploration(Alaska) 3 of 3 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q2� - jcQ Q Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: �' or Items: ❑ Maps: Grayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: a BY: �j Date: 1 - S Is! Project Proofing BY: Date: /s/ Scanning Preparation x 30 = Ica 0 + 7 = TOTAL PAGES 19 (Count does not include cover sheet BY: 410 Date: / /s/ Production Scanning Stage 1 Page Count from Scanned File: 1.9.-F (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES NO BY: te) Date: Lf-//6 /5 Stage 1 If NO in stage 1, page(s) discrepanciewere found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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T- J 11 Z Q U) 3 w Cl) ta 1 G r u) ce g 2 O Z CL IX 0 J a W w V pap o Z _Q w 3 J o a �, 2 o c o Tx O 1n E N E w r V U -C-‘-1 as o J E r, v E °' Q r i I— } a I— ~ C� = N C Q N CO CO N 4 p w O a) a) CO X `° o 0 ‘1Q acm a Q o Q Z E E U S m Z d 0 paj N co W N N I N 1- m O d ;7 y m N = N ` N ] V 0 cNZ c CO o w d n 0 01 Q o 0 c c U J ') a) .a N to Cr .E L a m y E 'a C7 E d E E 0 a M C.) 0 cc p] C) 0 ?-M Hunt, Jennifer L (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Wednesday, February 11, 2015 8:44 AM To: Hunt, Jennifer L (DOA) Subject: PBU Y-14C/ PTD # 214-120 Hi Jennifer, Please reference the following well: Well Name: PBU Y-14C Permit#. 214-120 API #: 50-029-21832-03-00 Date of Test: 2/8/15 Type of Test: IPT (Initial Production Test) Choke Size: 128 Choke Unit. 64ths Production Method: Gas Lift Duration (Hours Tested): 12 Top Reference (Top Perf MD): 11949' Bottom Reference (Bottom Perf MD): 13339' Tubing Flowing (Pressure): 325 Casing Pressure: 1652 Total Test(Rate f/0, W, G): 388/372 /425 24-Hour Rate (0, W, G): 775/ 744/850 Gravity (Oil, API): 26.9 Deg GOR (Gas-Oil Ratio): 1097 This well began Production on• 2/6/2015 Method of Operations on this date: Flowing 1 RBDMO FEB 1 1 2015 RECEIVED STATE OF ALASKA IAN 2 O 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO..GCC 1a. Well Status: . ®Oil 0 Gas ❑SPLUG D Other 0 Abandoned 0 Suspended lb. Well Class 20AAC 25105 20AAC 25 110 0 Exploratory ❑Stratigraphic 0 GINJ 0 WINJ 0 WAG ❑WDSPL 0 Other No.of Completions One '® Development ❑Service 2. Operator Name: 5. Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. .12/26/2014 . 214-120 • 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 • 12/1/2014 • 50-029-21832-03-00 . 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number Surface: • 12/19/2014 PBU Y-14C • 492' FNL, 706' FWL, Sec. 34,T11N, R13E, UM ' 1 8. KB(ft above MSL): 83 38 15. Field/Pool(s) Top of Productive Horizon: 4022' FNL, 825' FEL, Sec. 33, T11N, R13E, UM 1 GL(ft above MSL): 49.6' , Prudhoe Bay/Prudhoe Bay " Total Depth: 9. Plug Back Depth(MD+TVD) 5016' FNL, 2562' FEL, Sec. 33, T11N, R13E, UM 13339' ' 9006' ' 4b. Location of Well(State Base Plane Coordinates, NAD. 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 645503 • y- 5949777 ' Zone- ASP4 .13425' ' 8994' ADL 028287 ' TPI: x- 644048 y- 5946219 Zone- ASP4 11. SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 642332 Y- 5945192 Zone- ASP4 None 18. Directional Surve Y: ®Yes ❑ No ' 19.Water depth, if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD/GR/RES, MWD/GR/RES/NEU/DEN, USIT . 6024' • 5735' • 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" Insulated Conductor 33' 113' 33' 113' 8 yds Concrete 13-3/8" 68# L-80 32' 2686' 32' 2685' 17-1/2" 3723 cu ft Arcticset II and III 9-5/8" 47# L-80 Surface 6024' Surface 5735' 12-1/4" 2116 cu ft Class'G', 864 sx Class'G' 7" 26# L-80 5870' 10559' 5615' 8882' 8-1/2" ,267 sx Class'G' 4-1/2" 12.6# , 13Cr80 10408' 13423' 8763' 8994' 6-1/8" ,362 sx Class'G' 24. Open to production or injection'? ®Yes 0 No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) (MD+TVD of Top&Bottom;Perforation Size and Number): 2-7/8"Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr85 10417' 10290'/8671' ,-', .:�` 1 26. ACID,FRACTURE,CEMENT SQUEEZE, ETC. 11949'-12059' 9004'-9007' (Z'ziagg17 WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ® No • 12219'-12314' 9009'-9013' 13049'-13229' 9021'-9013' rr-.`-- DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 13304'-13339' 9009'-9006' •�i[ 2000' Freeze Protect w/ 138 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OiL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ® No Sidewall Core(s)Acquired? El Yes ® No If Yes to either question, list formations and intervals cored(MD+TVD of top and bottom of each), and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None Form 10-407 Revised 10/2012 CONTINUED O�R_y.ERSE RBDMS . Submit Original Only vT� 3/16115 31'//� JAN 2 2 1015 s,> s-:/.%. ( 29. GEOLOGIC MARKERS(List all formations and r'--'<ers encounter 30. FORMATION TESTS NAME ND Well Tested? es ®No . Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Coleville Mudstone 6209' 5879' None HRZ 8719' 7440' Kingak 8992' 7655' Sag River 10555' 8878' Shublik 10583' 8900' Sadlerochit-Zone 4B 10685' 8979' Zone 4A 10922' 9112' Sadlerochit-Zone 46(Invert) 11282' 9106' Shublik 13386' 8999' Formation at Total Depth: Shublik(From Base) 13386' , 8999' 31.List of Attachment' Summary of Daily Drilling Reports, LOT/FIT Summary,Well Schematic Diagram, Surveys,Cement Report 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Minge,564-4061 Email: David.Minge@bp.com Printed Name Title: Drilling Technologist Joe Lastu . Signature: Phone 564-4091 Date: `iI 1p 115 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8. The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23. Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24• If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval) Item 27. Method of Operation. Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28• Provide a listing of intervals cored and the corresponding formations,and a brief description in this box Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30• Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only TREE= ¢'/,6- / WELY-14C LHEAD= MCFa/OY SAF 407ES:WELL ANGLE>70°@10916'.'** ACTUATOR- BAKER C J M D D�. 'T MAX_ �I..EG:18.1*§12246'***4-12"CHROME oKe.ELEV7s 8 / I TBG&Lt� BF.REV= 50.6' KOP= 4250' 20'CONDUCTOR DUCTOR, —i 110' I 1 1996' —14-1/2"OTIS X NV,D=3.813" Max Angle= 109'@ 11265' Datum MD= 10561' #' b. 1959' 1—.19-5/8"HES FS CEMENTER Datum TVD= 8800'SS D • 9-5/8"CSG,47#,L-80 VAM TOP HG,D=8.861" —{ 2003' 9-5/8"BOWEN CSG PATCH,D=9.060" —{ 2003'-2007' ►r ST MD TVD DEV TYPE VLV LATCH FORT DATE '-� 5 3728 3726 0 MAG 1 RKP 12/25/14 TOC{10/07/88}CONFRMED w/L)S1T(11/21114) — 2100' 4 5758 5527 39 MAG DMY RK 0 12/25/14 3 8162 7013 46 KBG-2 DM' BK 0 12/25/14 13-3/8'CSG,72#,L-80,D=12.347" — 2686' 2 9358 7940 39 KBG-2 DFA/ BK 0 12/25/14 1 10181 8586 38 K136-2 TM BK 0 12/25/14 Minimum ID = 3.725" @ 10399' 0 4-1/2" XN NIPPLE 5870' H9-5/8"X 7"BKR HRD-E ZXPN LIP,D=6.170" 9-5/8"WHPSTOCK(11/30/14) H 6024' 5888' I--9-5/8-X 7"BKR FLEX LOCK LNR HGR,D=6.190" 9-5/8"CSG,47#,L-80 NSCC,D=8.681' H —6024' If 9-5/8'MLLOUT WINDOW(Y-14C) 6024'-6041' ., 10259' H4-1/2'OTIS X NP,D=3.813" 10290' 7"X 4-1/2'HES TNT LTP,D=3.856" TA 10327' 1-14-1/2*OTIS X NP,D=3.813" 10399' H4-112'FES XN NP,13=3.725" 10408 —I7'X 5"BKR HRD-E ZXP LIP w/TIEBACK.13=4.340" 1 TOP OF 4-1/2'LNR H 1040$' ,, � 4-1/2"TBG,12.6#,13CR-85 VAM TOP, 10417' II 10417 —a-1/2'WLEG D=3.95J +. —{E>_MDTTNOT LOC ) 0152bpt,D=3.958" f K 10432 7'X 5"BKR BKR FLEXLOCK DG TOP OF CBNF3YT(12/21/14) -{ 10429' I, ' LFR HGR D=4.330" rill ` rill - 7"LM 26#,L-80 HYD 563/BTC-M, — 10559' A Vj 0383 bpt,p=6.276" y �� 10442 H5"X 4-1/2"XO,D=3.900" , 1 • PERFORATION SUMMARY � • 11800 j---IRA TAG ON MARKER St REF LOG: REAL TINE LW)on 12/19/14 A 4I ANGLE AT TOP FERE: 88°@ 11949' A 1. Note:Fbfer to Production DB for historical perf data 1 1 SIZE SPF INTERVAL Opn/Sgz DATE SQZ A .+� 2-7/8" 6 11949-12059 O 12/23/14 ♦ *4 12900 —RA TAG ON MARKER ST 2-7/8"r 6 12219-12314 0 12/23/14 + 4 40 2-7/8"r 6 13049-13229 0 12/23/14 ♦ Ni 2-7/8"r 6 13304-13339 0 12/23/14 A 111 A PBTD -{ 13339' I� 4• 4-1/2'LNR,12.6#,13-CR VAM TOP, H 13423' ' ��``+ .0152 bpi,D=3.958" • DATE REV BY COFAMENTS DATE FEV BY COMMENTS PRUCHOE BAY UNIT 10/07/88 QUES- ORIGINAL COMPLETION WELL: Y-14C 11/01(95 LIM)BT SIDETRACK(Y-14A) PEFI+1TNo: '2141200 08/07/01 CFIKAK CTD TOE OUT DRILL (Y-14B) API No: 50-029-21832-03 12/27/14 D-14 SIDETRACK(Y-14C) SEC 34,T11N,R13E,492'FTS&706'FINL 12/30/14 At) DRLG HO CORRECTIONS 01/07/15 DA.NLD WBS EDITS BP Exploration(Alaska) BP AMERICA LOT / FIT Summary Well Name: Y-14C Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP) (psi) (ppg) 11/30/14 LOT 6,032.38 5,741.11 9.40 1,200.00 4,003.46 13.42 12/14/14 FIT 10,599.00 8,899.26 8.60 600.00 4,575.78 9.90 Page 1 of 1 North America-ALASKA-BP Page 1 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/17/2014 06:00 - 12:00 6.00 MOB P PRE COMPLETE P&A OPERATION ON WELL#38 -RIG DOWN AND MOVE OFF TO THE SIDE OF LOCATION TO DO SOME PLANNED PRE-WELL WORK FOR UPCOMING SIDETRACK OPERATIONS. -WELDER TO INSTALL 3"KILL LINE IN CELLAR WITH 3"SHOCK HOSE.TO REPLACE 2"LINE -DRILL SITE MAINT PERFORMING PRE-RIG • WORK. -MEET WITH Y-PAD DSO,WELL#6 TO UNLOCK,LOCK WELL#10 AT MASTER OBTAIN WWTP FOR WELL Y-14C:DSO AGREED ON LOCATION OF WSL OFFICE OUT OF RED ZONE OF RIG AND MANIFOLD 'BUILDING. -MADE 24 HR NOTIFICATION FOR UPCOMING INITIAL BOPE TEST FOR WELL 14C. 12:00 - 19:00 7.00 MOB P PRE DRILL SITE MAINT STILL PRE PING Y-14C -INSTALLING PIGGY BACK ANNULUS VALVES &TESTING. LAYING RIG MATS AROUND THE WELL SIMOPS:WELDER FIXING ACCESS COVER TO DRIP PAN AREA ON OFF DRILLERS SIDE 19:00 - 21:30 2.50 MOB P PRE POSITION RIG OVER WELL Y-14C -PJSM. -CONTACT DSO TO WITNESS RIG MOVING OVER WELL. *DSO WAIVE WITNESS RIG MOVING OVER WELL. -FUNCTION TEST ESD ON MOVING SYSTEM BEFORE MOVING RIG OVER WELL. TEST PASS. -POSITION AND CENTER RIG OVER WELL, USING CREEP MODE SYSTEM. -LEVEL AND SHIM RIG. -INSTALL HANDRAILS AND STAIRS AROUND RIG. 21:30 - 22:30 1.00 MOB P PRE SKID RIG FLOOR. -PJSM. -PREPARE AND SKID RIG FLOOR INTO DRILLING POSITION. "SIMOPS: -PJSM WITH RIG CREWAND HARD LINE CREW. -HARDLINE CREW,R/U HARDLINE FROM SKID MANIFOLD TO FLOWBACK TANK. -HARDLINE CREW,PRESSURE TEST HARDLINE FORM SKID MANIFOLD TO FLOWBACK TANK TO 250/4,000 PSI FOR 5 CHARTED MINS EACH-GOOD LEAK TIGHT TEST. 22:30 00:00 1.50 RIGU P PRE RIG UP RIG EQUIPMENT. -R/U RIG FLOOR AND SERVICE LINES. -PREPARE AND SKID OUT CONVEYOR#2. -TAKE ON 120 DEG 8.5 PPG SEAWATER -POSITION AND R/U BREAK TRAILER AND BULK FUEL TANK. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 2 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/18/2014 00:00 - 03:00 3.00 RIGU P PRE RIG UP RIG EQUIPMENT. -R/U RIG FLOOR AND SERVICE LINES. PREPARE AND SKID CONVEYOR#2. SPOT ROCKWASHER. R/U LINES FOR DISPLACEMENT OF FREEZE PROTECT. -R/U COMMUNICATIONS IN WSL OFFICE. *SIMOPS: -PJSM WITH CH2 VAC-TRUCK OPER. -PREPARE MUD PITS AND TAKE ON 120°8.5 PPG SEAWATER *RIG ACCEPTED AT 00:01 03:00 - 04:00 1.00 DHB P PRE PRESSURE TEST TWC -FROM ABOVE AND BELOW-250 LOW&3500 PSI HIGH,5 CHARTED MIN.-GOOD TESTS 04:00 - 05:00 1.00 RIGU P PRE H2S/RIG EVACUATION DRILL -SIMULATED H2S RELEASE,WITH A MAN DOWN LEADING TO RIG EVACUATION, -ALL HANDS RESPONDED ACCORDINGLY- FOLLOWED BY AAR 05:00 - 06:00 1.00 RIGU P PRE RIG DOWN DRY HOLE TREE&ADAPTER FLANGE PJSM FOR N/D OPERATION WITH DDI CREW AND CAMERON-REVIEW HAZARDS AND PROCEDURE FOR RIGGING DOWN. -CLEAN TOP OF HANGER AND REPLACE RING GASKET. -CAMERON TO BLEED CONTROL LINES AND HANGER VOID PRIOR TO N/D.HANGER THREAD-GOOD -INSPECT THREADS AND M/U HANGER XO, 10 TURNS TO LEFT. -REMOVE HANGER XO. -BREAK TREE AND ADAPTER FLANGE AND SEND OUT 06:00 - 15:30 9.50 BOPSUR P PRE NIPPLE UP 13-5/8"BOPE -PJSM FOR NIPPLE UP OPERATIONS: REVIEW DDI PROCEDURE,DISCUSS OUT OF SCOPE WORK FOR REPOSITIONING THE STACK TO BETTER FIT NEW 3"KILL LINE. -RE-CONFIGURE ANCHOR POINTS IN CELLAR AND REMOVE BOP STACK YOKE, •REMOVE ANNULAR AND REPOSITION ON TOP OF THE STACK. -INSTALL YOKE AND-N/U BOPE AND INSTALL RISER. -PJSM FOR N/U BOPE,DISCUSS LIFTING HAZARDS AND DROPPED OBJECTS. 15:30 - 17:30 2.00 BOPSUR P PRE RIG UP BOPE TEST EQUIPMENT - PERFORM TABLE TOP KICK WHILE DRILLING DRILL -H2S DRILL,RIG EVACUATION WITH AAR CONDUCTED POST DRILL. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 3 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UW:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 19:00 1.50 BOPSUR P PRE PRESSURE TEST NEW 3"KILL LINE -PJSM ON TESTING BOPE,WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. - 250 PSI/5000 PSI 5 MIN EA-TEST PASS BODY TEST ON BOP.-TEST PASS -CHECKED FILL ON GAS BUSTER,TOOK 6 BBLS TO FILL 19:00 - 00:00 5.00 BOPSUR P PRE TEST 13-5/8"BOPE -PRESSURE TEST 13-5/8"5M BOPE. -PJSM ON TESTING BOPE,WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT 'RESPONSES. -TEST BOPE AS PER DDI SOP. -TEST ANNULAR PREVENTER WITH 4"TEST JT TO 250/3,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. -TEST BOPE WITH 4", 4-1/2"&9-5/8" TEST JTS TO 250/3,500 PSI FOR 5 CHARTED MINS EACH. -PERFORM ACCUMULATOR DRAW DOWN TEST. ALL TEST PASS BP TEST CRITERIA FOR BOPE TESTING NO FAILURES -TEST ALL GAS ALARMS.TEST PASS -SEE ATTACHED TEST CHARTS *PERFORMED 4 MPL RAM LOCK TESTS:3500 PSI TESTS NOT CHARTED-ALL TESTS PASS -9-5/8"UPPER RAMS,BLIND SHEARS, LOWER VBRS TESTED W/4"&4-1/2"TEST JOINTS - 2 HRS EXTRA TIME TO PERFORM MPL RAM LOCK TESTS JOHN CRISP WAIVED WITNESS 11-18-14 13:00 OA=0 PSI -ZERO LOSSES THIS TOUR Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 4 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/19/2014 00:00 - 03:00 3.00 BOPSUR P PRE TEST 13-5/8"BOPE -PRESSURE TEST 13-5/8"5M BOPE. -PJSM ON TESTING BOPE,WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -TEST BOPE AS PER DDI SOP. -TEST ANNULAR PREVENTER WITH 4"TEST JT TO 250/3,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. -TEST BOPE WITH 4", 4-1/2"&9-5/8" TEST JTS TO 250/3,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS -PERFORM ACCUMULATOR DRAW DOWN 'TEST. TEST PASS. -ALL TEST PASS BP TEST CRITERIA FOR BOPE TESTING -NO FAILURES -TEST ALL GAS ALARMS.TEST PASS -SEE ATTACHED TEST CHARTS I•JOHN CRISP WAIVED WITNESS 11-18-14 13:00 03:00 - 03:30 0.50 BOPSUR P PRE 1RIG DOWN BOPE TEST EQUIPMENT !-CLEAN AND CLEAR RIG FLOOR -MAKE UP X-OVERS FOR SAFETY VALVES 03:30 - 06:00 2.50 PULL P PRE RETRIEVE 4"TYPE"H"TWC -PJSM FOR PICKING UP LUBRICATOR AND PRESSURE TESTING WITH DDI&DSM CREW. REVIEW PROCEDURE AND DISCUSS LIFTING OPERATIONS WITH EMPHASIS ON EXCLUSION ZONE AT THE BEAVER SLIDE. TEST LUBRICATOR AND DUTCH RISER AGAINST TWC -BRING DRILL SITE MAINTENANCE LUBRICATOR TO RIG FLOOR. -MOBILIZE CONTROL LINE SPOOL AND TOOLS TO RIG FLOOR. -PJSM WITH DSM AND DOYON PERSONNEL. -RIG UP AND TEST DUTCH RISER& LUBRICATOR 250/3500 PSI FOR 5 MIN/5 MIN. -RIG DOWN TEST EQUIPMENT. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 5 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task ' Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 12:30 6.50 CLEAN P DECOMP CIRCULATE OUT FREEZE PROTECT WITH 8.5 PPG SEAWATER. PJSM FOR CIRCULATION:ENSURE PROPER LINE UP TO THE FLOW BACK TANK,ENSURE FLOW BACK TANK IS EMPTY,VERYIFY AND TEST LINES AND MANIFOLD TO 250 LOW/ 3500 PSI HIGH-TEST GOOD-LEAK TIGHT -PUMP DOWN THE IA TAKING RETURNS UP THE TUBING OUT TO THE FLOW BACK TANK -5 BPM WITH 1000 PSI PUMP PSI ,TOTAL 60 BBLS PUMPED -SHUT DOWN LINE UP TO CIRCULATE DOWN THE TUBING TAKING RETURNS THROUGH THE IA OUT TO THE FLOW BACK TANK 5 BPM WITH 750 PSI PUMP PRESSURE,MAX 200 PSI DOWN STREAM OUT TO THE FLOW BACK TANK. 8.5 PPG SEAWATER *TOTAL OF 455 BBLS PUMPED -SHUT DOWN AND MONITOR WELL 10 MIN- WELL STATIC. **SIMOPS:SLB MWD'S HOOKING UP SENSORS TO THE MUD MANIFOLD AND STAND PIPE PJSM WITH CREWAND SLB TO ENSURE HAZARDS ARE DISCUSSED AND JOB PLAN REVIEWED. 12:30 - 14:00 1.50 PULL P DECOMP PULL TUBING HANGER -PJSM FOR HANGER PULLING OPERATIONS: W/DDI CREW AND CAMERON REP -CAMERON REP TO BOLDS, PU 4-1/2"LANDING JOINT WITH TDS(XO) MADE UP,RIH AND MAKE UP TO THE HANGER 10 TURNS VERIFIED CORRECT BY CAMERON REP. PULLED HANGER FREE WITH 125K,STRING WEIGHT-120K -CIRCULATE BOTTOMS UP-WITH 10 BPM 390 PSI- -8.5 PPG SEAWATER. -NO GAS OR HYDROCARBONS OBSERVED AT BOTTOMS UP **SIMOPS:RU SLB CONTROL LINE SPOOLER. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 6 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 22:30 8.50 PULL P DECOMP POOH WITH 4-1/2"NSCT COMPLETION TUBING WITH 2 CONTROL LINES PJSM WITH CREWAND SLB. -PULL HANGER TO THE RIG FLOOR AND LAY DOWN.MAKE UP FOSV AND XO. BLOW DOWN TOP DRIVE -POOH F/6,542'MD TO 4,425'-TO THE SSSV.- -SPOOLING THE CONTROL LINES WITH SLB SPOOLER. UP WT 120K,DN WT 110K. TERMINATE THE CONTROL LINES AND LAY DOWN THE SLB SPOOLER. *ENSURE SLIPS ARE COVERED PRIOR TO REMOVING CLAMPS WITH AIR CHISEL. MONITORING TRIP ON THE TRIP TANK- CORRECT HOLE FILL OBSERVED. 'CONTINUE PULLING AND LAYING DOWN 4-1/2"TBG FROM 4,425'TO SURFACE -PUW-95K,SOW-95K MONITOR TRIP OUT ON THE TRIP TANK- CORRECT HOLE FILL OBSERVED. RECOVERED TOTAL 54 STAINLESS STEEL BANDS,1-SSSV&2-GLMS& 4.40'CUT JOINT 'W/5"FLARE-MATCHES UP WITH ORIGINAL COMPLETION TALLY. HELD A KICK WHILE TRIPPING DRILL WHILE PULLING COMPLETION: -CONDUCTED AAR WITH 2 ACTION ITEMS ASSIGNED TO DDI FOR IMPROVEMENT. PHASE 2 WEATHER CALLED AROUND 22:00.- WSL'S AND TP CONDUCTED A HAZARD ASSESSMENT FOR JOURNEY MANAGEMENT FOR CREW CHANGE OUT. RIG HAD ALREADY PREPARED BY TOPPING OFF FUEL AND WATER AT THE RIG 22:30 - 00:00 1.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR -CLEAR RIG FLOOR OF 4-1/2"TUBING HANDLING EQUIPMENT. PREPARE FOR UPCOMING 9-5/8" CLEAN-OUT RUN. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 7 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UW:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth • Phase Description of Operations (hr) (usft) 11/20/2014 00:00 - 04:00 4.00 CLEAN P DECOMP MAKE UP 8-1/2"CLEAN-OUT BHA#1. -PJSM FOR BEAVER SLIDE OPERATIONS AND M/U BHA,WITH RIG CREW AND BAKER REP. -CLEAN AND CLEAR RIG FLOOR OF 4-1/2" HANDLING EQUIPMENT. -MOBE CLEAN-OUT BHA COMPONENTS TO RIG FLOOR. R/U AND INSTALL WEAR BUSHING. *LENGTH=10-1/2", OD=13-1/2", ID=9-1/4" -P/U AND M/U CLEAN-OUT BHA. -8.5"OD TRI CONE BIT -2 X 7"OD BOOT BASKETS -BIT SUB-6-3/8"OD -SMOOTH OD MILL-8.5"OD 6-1/4"BOWEN BUMPER SUB -6-1/4"X-O SUB -(6)6-1/4"DC'S-6-1/4"OD •-RIH WITH CLEAN-OUT BHA AND TAG AT 58' (14'BELOW WELL HEAD)WITH 6-7K DOWN. -ATTEMPT TO WORK THROUGH TIGHT SPOT 2x WITH NO SUCCESS. NOTIFY ODE AND DISCUSSED PLAN FORWARD. '*PLAN FORWARD:POOH AND UD 8-1/2" SMOOTH OD STRING MILL. RIH WITH 8-1/2" CLEAN-OUT BHA#2,WITHOUT 8-1/2"SMOOTH OD STRING MILL. ASSEMBLY COMPONENTS FOR CONTINGENCY BHA CONFIGURATIONS. -POOH AND UD 8-1/2"SMOOTH OD MILL. -M/U CLEAN-OUT BHA#2. -8.5"OD TRI CONE BIT -2 X 7"OD BOOT BASKETS -BIT SUB-6-3/8"OD -6-1/4"BOWEN BUMPER SUB -6-1/4"X-O SUB -(6)6-1/4"DC'S-6-1/4"OD 04:00 - 06:00 2.00 CLEAN P DECOMP RUN IN HOLE WITH 8-1/2"CLEAN-OUT BHA#2. -PJSM FOR RIH,P/U DP FROM PIPE SHED, WITH RIG CREWAND BAKER REP. RIH WITH CLEAN-OUT BHA,P/U 4"DP SINGLES FROM PIPE SHED F/SURFACE'T/ 2,583'. *NO INDICATION OF TIGHT SPOT AT 58'. -MONITOR TRIP ON THE TRIP TANK OBSERVED CORRECT DISPLACEMENT. *PHASE 2 WEATHER- JOURNEY MANAGEMENT FOR WSL AND TP CHANGE OUT- DISCUSSED PLAN- WSL&TP APPROVED. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 8 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 06:00 - 12:00 6.00 CLEAN N WAIT DECOMP OPERATIONS SUSPENDED DUE TO PHASE 3 WEATHER CONDITIONS. -PHASE 2 WEATHER FIELD WIDE;PHASE 3 WEATHER ON Y PAD WITH LEVEL 3 ROAD CONDITIONS AND PAD AND ACCESS ROADS. -HEAVY EQUIPMENT IN ROUTE TO ASSIST WITH RIG TEAM CHANGE OUT. i-CONTINUOUSLY MONITOR WELL,WHILE CIRC ACROSS TOP OF STACK. *WELL STABLE. -CONDUCT TABLE TOP DRILLS: **KICK WHILE DRILLING DRILL,STRIPPING DRILL,CAMP EVAC DRILL,FIRE DRILL IN DOG HOUSE.** *FLUID LOSS LAST 12 HRS=0 BBLS OA PRESSURE=0 PSI 12-00 - 14.00 2.00 CLEAN N WAIT DECOMP OPERATIONS SUSPENDED DUE TO PHASE 3 WEATHER CONDITIONS. -CONTINUOUSLY MONITOR WELL,WHILE CIRC ACROSS TOP OF STACK. *WELL STABLE. HEAVY EQUIPMENT,CLEARING Y-PAD ACCESS ROAD IN PREPARATION FOR RIG CREW CHANGE. -PJSM WITH RIG TEAM AND HEAVY I EQUIPMENT OPERATORS FOR RIG CREW CHANGE IN PHASE 2 WEATHER CONDITIONS WITH ROTARY SUPERINTENDENT APPROVAL -SUCCESSFUL RIG TEAM CHANGE OUT WITH HEAVY EQUIPMENT ESCORT. 14-00 - 16:00 2.00 CLEAN P DECOMP PULL OUT OF HOLE WITH CLEAN-OUT BHA #2. -PJSM WITH RIG CREWAND BAKER REPS. 10 MIN FLOW CHECK. WELL STABLE. ESTABLISH PARAMETERS. *PUW=95K, SOW=95K -POOH WITH CLEAN-OUT BHA,STANDING BACK 4"DP IN DERRICK F/2,583'T/214'. -10 MIN FLOW CHECK FOR NON-SHEARABLES ACROSS BOP STACK WELL STABLE. -POOH AND UD CLEAN-OUT BHA F/214'. 16:00 - 17:30 1.50 CLEAN P DECOMP RUN IN HOLE WITH 8-1/2"CLEAN-OUT BHA#3. PJSM WITH RIG CREWAND BAKER REP. -P/U AND M/U CLEAN-OUT BHA. -8.5"OD TRI CONE BIT -8-3/8"WATERMELON MILL 6-3/8"DBL PIN SUB -2 X 7"OD BOOT BASKETS -BIT SUB-6-3/8"OD -6-1/4"BOWEN BUMPER SUB -6-1/4"OIL JARS -6-1/4"X-O SUB -(6)6-1/4"DC'S-6-1/4"OD -6-1/4"X-O SUB -RIH WITH CLEAN OUT BHA TO 46'. -WORK THROUGH TIGHT SPOT F/46'T/58' WITH 8-3/8"WATERMELON MILL SEVERAL TIMES. *2-4K TO WORK THROUGH TIGHT SPOT. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 9 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations • (hr) (usft) 17:30 - 18:00 0.50 CLEAN P DECOMP PULL OUT OF HOLE WITH 8-1/2"CLEAN-OUT BHA#3 AND MAKE UP 8-1/4"SWAGE BHA#4. -POOH AND L/D CLEAN-OUT BHA#3. -P/U AND M/U 8-1/4"SWAGE BHA#4. 6-3/8"BULL NOSE -8-1/4"SWAGE 6-1/4"BOWEN BUMPER SUB -6-1/4"OIL JARS -6-1/4"X-O SUB -(6)6-1/4"DC'S-6-1/4"OD -6-1/4"X-O SUB 18:00 - 19:00 1.00 CLEAN P • DECOMP RIH WITH 8-1/4"SWAGE BHA#4. RIH WITH SWAGE BHA TO 150'. *NO INDICATION OF TIGHT SPOT AT 58'. '-POOH WITH SWAGE BHA F/150'T/ SURFACE. 19:00 - 22:30 3.50 CLEAN N WAIT DECOMP OPERATIONS SUSPENDED DUE TOY PAD ACCESS ROAD BECOMING IMPASSABLE. 1-CONTINUOUSLY MONITOR WELL,WHILE CIRC ACROSS TOP OF STACK. *WELL STABLE. -HEAVY EQUIPMENT,CLEARING Y-PAD ACCESS ROAD. 22:30 - 00:00 1.50 CLEAN P DECOMP LAY DOWN 8-1/4"SWAGE BHA#4 AND MAKE UP 9-5/8"CLEAN-OUT BHA#5. !-PJSM WITH RIG CREWAND BAKER REP. DISCUSS NON SHEARABLES ACROSS THE STACK.UNDERSTAND BHA LENGTH -L/D SWAGE BHA#4.AS DIRECTED BY BAKER REP -P/U AND M/U CLEAN-OUT BHA#5. -8.5"OD TRI CONE BIT -8-3/8"WATERMELON MILL -6-3/8"DBL PIN SUB -2 X 7"OD BOOT BASKETS -BIT SUB-6-3/8"OD -6-1/4"BOWEN BUMPER SUB -6-1/4"OIL JARS -6-1/4"X-O SUB -(6)6-1/4"DC'S-6-1/4"OD -6-1/4"X-O SUB -RIH WITH 9-5/8"CLEAN-OUT BHA TO 227'. *STILL IMPLIMENTING JOURNEY MANAGEMENT PLAN FOR TRAVEL OFF LOCATION DUE TO SEVERE DRIFTING *FLUID LOSS LAST 12 FIRS=0 BBLS *OA PRESSURE=0 PSI 11/21/2014 00:00 - 03:30 3.50 CLEAN P DECOMP RUN IN HOLE WITH 8-1/2"CLEAN-OUT BHA#5. -RIH WITH 8-1/2"CLEAN-OUT BHA F/227'TO 2,584'ON 4"DP STANDS FROM THE DERRICK -RIH WITH CLEAN-OUT BHA F/2,584',ON 4" DP SINGLES FROM PIPE SHED AND TAG TOP OF 4-1/2"STUB ON DEPTH AT 6,545'. -ESTABLISH PARAMETERS AND OBTAIN SPRs. *PUW=155K,SOW=145K *TRIP MONITORED ON THE TRIP TANK WITH CONTINUOUS HOLE FILL-CORRECT DISPLACEMENT OBSERVED. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 10 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 04:30 1.00 CLEAN P DECOMP CIRCULATE HIGH VIS SWEEP AROUND. I-LINE UP AND PUMP 30 BBL HIGH VIS SWEEP AT 6,500'. -CIRC SWEEP OUT WITH 8.5 PPG SEAWATER AT 640 GPM WITH 2,200 PSI,ROTATING 20 RPM WITH 3K FREE TORQUE AND RECIPROCATE STRING 90'. *OBSERVED DEBRIS AND SCALE AT SHAKERS. CIRCULATE TOTAL 518 BBLS AND SHAKERS CLEANED UP. -10 MIN FLOW CHECK. WELL STABLE. BLOW DOWN TOP DRIVE. INSTALL STRIPPING RUBBER AND AIR SLIPS. 04:30 - 06:30 2.00 CLEAN P DECOMP PULL OUT OF HOLE WITH 8-1/2"CLEAN-OUT BHA#5. -PJSM FOR PULLING OUT.DISCUSS PROPER HOLE FILL AND ACCURATE FLUIDS MANAGEMENT-TRIP SHEETS -POOH WITH CLEAN-OUT BHA,STANDING BACK 4"DP F/6,500'T/300'. *MONITOR TRIP ON TRIP TANK-CORRECT HOLE FILL OBSERVED. 06:30 - 07:30 1.00 CLEAN P DECOMP I LAY DOWN 8-1/2"CLEAN-OUT BHA#5. -PJSM FOR UD BHA WITH RIG CREW AND BAKER REP.-EMPHASIS ON WELL CONTROL WITH NON-SHEARABLES ACROSS BOP STACK. -10 MIN FLOW CHECK FOR NON-SHEARABLES ACROSS BOP STACK. WELL STABLE. -POOH AND UD CLEAN-OUT BHA F/300'. 07:30 - 08:30 1.00 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR. -CLEAN AND CLEAR RIG FLOOR OF CLEAN-OUT BHA. -PREPARE RIG FLOOR FOR E-LINE OPERATIONS. *SIMOPS: -PJSM ON R/U E-LINE UNIT AND EQUIPMENT WITH RIG AND SLB E-LINE CREW. -POSITION SLB E-LINE UNIT AND EQUIPMENT. 08:30 - 12:00 3.50 EVAL P DECOMP RIG UP SCHLUMBERGER E-LINE UNIT AND EQUIPMENT. -PJSM ON E-LINE OPERATIONS AND REVIEW DDI SOP WITH RIG AND SLB E-LINE CREW. -R/U SLB E-LINE EQUIPMENT. **TABLE TOP WELL CONTROL DRILL WITH E-LINE IN THE HOLE.** *FLUID LOSS LAST 12 HRS=0 BBLS *OA PRESSURE=0 PSI Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 11 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UW:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 17:00 5.00 EVAL P DECOMP RUN IN HOLE WITH SLB USIT LOG TOOL STRING. -P/U,M/U AND SURFACE TEST SLB USIT LOG TOOL STRING. -RIH WITH USIT LOG TOOL STRING T/6,480'. -LOG UP F/6,480'T/SURFACE. -REVIEW USIT LOG WITH ODE AND DETERMINE TOC AT 2,100'. *CONTINUOUSLY MONITOR WELL ON TRIP TANK. WELL STABLE. 17:00 - 22:00 5.00 EVAL P DECOMP RUN IN HOLE WITH SLB USIT LOG TOOL STRING. RIH WITH USIT LOG TOOL STRING T/6,480'. -LOG UP F/6,480'T/5,750'AND F/5,300'T/ 4,600'. -POOH WITH E-LINE F/4,600'T/SURFACE. CONTINUOUSLY MONITOR WELL ON TRIP TANK. WELL STABLE. 22:00 - 23:00 1.00 DHB P DECOMP RUN IN HOLE WITH HES 9-5/8"EZSV-B ON SLB E-LINE. -PJSM ON E-LINE OPERATIONS UTILIZING CHARGES,DISCUSSING ISOLATING POWER TO TOP DRIVE,EXCLUSION ZONES,AND COMMUNICATION WHEN ARMING CHARGES VIA GAI TRONICS/HARMONY WITH HES REP, RIG AND SLB E-LINE CREW. -ISOLATE POWER TO TOP DRIVE. M/U 9-5/8"EZSV-B WITH E-LINE SETTING KIT. • -SURFACE TEST E-LINE. 'CONNECTIVITY ISSUES WITH WEIGHT INDICATOR POWER SUPPLY. *CONTINUOUSLY MONITOR WELL ON TRIP TANK. WELL STABLE. *SIMOPS: -REVIEW USIT LOG DATA WITH ODE AND GEO. -DETERMINE SETTING DEPTH OF 9-5/8" EZSV-B AT 6,042'MD AND CUT DEPTH OF 9-5/8"CSG AT 2,000'MD. 23:00 - 00:00 1.00 DHB N SFAL DECOMP TROUBLESHOOT E-LINE CONNECTIVITY ISSUES. -TROUBLESHOOT ISSUES WITH WEIGHT INDICATOR POWER SUPPLY IN E-LINE UNIT. *CONTINUOUSLY MONITOR WELL ON TRIP TANK. WELL STABLE. •FLUID LOSS LAST 12 HRS=0 BBLS *OA PRESSURE=0 PSI 11/22/2014 00:00 - 00:30 0.50 DHB N SFAL DECOMP TROUBLESHOOT E-LINE CONNECTIVITY •ISSUES. -TROUBLESHOOT ISSUES WITH WEIGHT INDICATOR POWER SUPPLY IN E-LINE UNIT. -SURFACE TEST E-LINE TOOL STRING. TEST PASS. *CONTINUOUSLY MONITOR WELL ON TRIP TANK. WELL STABLE. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 12 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 03:30 3.00 DHB P DECOMP RUN AND SET 9-5/8"EZSV-B ON E-LINE. -PJSM ON E-LINE OPERATIONS UTILIZING CHARGES,DISCUSSING ISOLATING POWER TO TOP DRIVE,EXCLUSION ZONES,AND COMMUNICATION WHEN ARMING CHARGES VIA GAI TRONICS/HARMONY WITH HES REP, RIG AND SLB E-LINE CREW. CLEAR AFFECT AREA AND ARM SETTING TOOL. -RIH WITH 9-5/8"EZSV-B ON E-LINE T/6,160' ELM. -LOG AND CORRELATE 9-5/8"EZSV-B ON DEPTH. -SET 9-5/8"EZSV-B WITH TOP AT 6,042'MD. '-VERIFY 9-5/8"EZSV-B SET BY TAGGING WITH SETTING TOOL AT 6,042'MD. *CONTINUOUSLY MONITOR WELL ON TRIP TANK. WELL STABLE. *SIMOPS: RIG CREW WORKING ON DDI MP2's. 03 30 - 05 00 1.50 DHB P DECOMP PULL OUT OF HOLE WITH 9-5/8"EZSV-B SETTING TOOL ON E-LINE. •-POOH WITH E-LINE F/6,042'T/200'. PJSM AND CLEAR AFFECTED AREA FOR E-LINE CHARGES. -POOH WITH E-LINE F/200'. -VERIFY CHARGES SPENT. CONFIRMED. R/D SLB E-LINE UNIT AND EQUIPMENT. 1*CONTINUOUSLY MONITOR WELL ON TRIP TANK. WELL STABLE. 05 00 - 08'30 3.50 DHB P DECOMP RIG UP TO PERFORM MIT ON 9-5/8"CSG AND 9-5/8"EZSV-B AT 6,042'MD. -PJSM ON TESTING 9-5/8"CSG,WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -RIG UP TEST EQUIPMENT AND LINES. -CLOSE BLIND/SHEAR RAMS. -PRESSURE TEST 9-5/8"CSG AND 9-5/8" EZSV-B TO 250 PSI FOR 5 CHARTED MINS. -INCREASE PRESSURE F/250 PSI T/3,600 PSI FOR 30 CHARTED MINS. *PRESSURED UP AT 0.5 BPM *TOOK 6.4 BBLS TO PRESSURE UP TO 3,600 PSI. *20 PSI PRESSURE LOSS 15 MINUTES.10 PSI PRESSURE LOSS SECOND 15 MINUTES. -BLEED OFF ALL PRESSURE. *6.4 BBLS BLED BACK. *PASSING RESULTS PER WELLBORE INTEGRITY TESTING CRITERIA. *VERIFIED COMPETENCY OF MIT WITH WTL AND WAS GRANTED PERMISSION TO !PROCEED WITH OPERATIONS. VERIFY NO PRESSURE. -OPEN BLIND/SHEAR RAMS. -RIG DOWN TEST EQUIPMENT. -BLOW DOWN CHOKE/KILL AND BLEEDER LINES. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 13 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 10:00 1.50 CASING P DECOMP MOBE 8-1/4"MULTI-STRING CUTTER BHA TO RIG FLOOR. -PJSM DISCUSSING BEAVER SLIDE OPERATIONS INCLUDING EXCLUSION ZONES WITH RIG CREW AND BAKER REP. -P/U 8-1/4"MULTI-STRING CUTTER BHA. *DISCUSS WITH ODE CLOSE TOLERANCE OF WHIPSTOCK SETTING DEPTH TO 9 5/8" CASING COLLAR. CHANGE OPERATIONS PLAN TO ELIMINATE FILL ON TOP OF EZSV. -L/D 8-1/4"MULTI-STRING CUTTER BHA. 10:00 - 12:00 2.00 CASING C DECOMP RUN IN HOLE WITH 4"MULE SHOE BHA#6. -P/U,M/U AND RIH WITH 4"MULE SHOE TO 4,847'. **SPILL DRILL." *FLUID LOSS LAST 12 HRS=0 BBLS *OA PRESSURE=0 PSI 12:00 - 12:30 0.50 CASING C DECOMP RIG SERVICE 'I -SERVICE AND INSPECT TOP DRIVE, BLOCKS,DRAW WORKS AND ST-80. 12:30 - 13:30 1.00 CASING C DECOMP RUN IN HOLE WITH 4"MULE SHOE#6. RIH WITH 4"MULE SHOE F/4,847'T/ 6,000'.AND TAG TOP OF 9-5/8"EZSV-B AT 6,048'. -ESTABLISH PARAMETERS. *PUW=135K, SOW=130K -RIH WITH 4"MULE SHOE F/6,000'AND TAG TOP OF 9-5/8"EZSV-B AT 6,048'WITH 10K DOWN. 13:30 - 15:30 2.00 CASING C DECOMP PLACE 10'OF 20/40 RIVER SAND ON TOP OF 9-5/8"EZSV-B. -PJSM. -PULL UP HOLE F/6,048'T/6,018' -R/U SAND HOPPER ON 4"DP WITH SEAWATER ATTACHED TO INLET. -PLACE 10'OF 20/40 RIVER SAND ON TOP OF 9-5/8"EZSV-B SET AT 6,048',THRU 4"DP. *TOP OF SAND AT±6,038'. -PUMP 1-DP VOLUME AT 2 BPM WITH 40 PSI, TO ENSURE 4"DP CLEAN AND CLEAR OF SAND. 15:30 - 18:30 3.00 CASING C DECOMP PULL OUT OF HOLE WITH 4"MULE SHOE BHA #6. -PJSM. -10 MIN FLOW CHECK. WELL STABLE. -ESTABLISH PARAMETERS. *PUW=135K, SOW=130K -POOH WITH 4"MULE SHOE F/6,018'T/ SURFACE. -L/D 4"MULE SHOE BHA. 18:30 - 20:00 1.50 CUT P DECOMP RUN IN HOLE WITH 8-1/4"MULTI-STRING CUTTER BHA#7. -PJSM WITH RIG CREWAND BAKER REP. -P/U,M/U AND RIH WITH 8-1/4"MULTI-STRING CUTTER BHA T/2,005'. Printed 1/6/2015 5:05:21 PM North America-ALASKA-BP Page 14 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 22:00 2.00 CUT P DECOMP CUT 9-5/8"47#L-80 BTC CASING AT 2,005'. -PJSM WITH RIG CREW AND BAKER REP. -ESTABLISH PARAMETERS AND OBTAIN SPRs. *PUW=80K, SOW=80K, RTW=80K, RPM=80 WITH 2-3K FREE TORQUE -LOCATE COLLARS WITH KNIVES AT 1,996' AND 2,036'. -SET KNIVES AT 2,005'. STARTED PUMPS AT 3 BPM WITH 150 PSI,4 BPM WITH 300 PSI,5 BPM WITH 625 PSI,6 BPM WITH 750 PSI,7 BPM WITH 830 PSI, RPM=80 WITH 2-3K TORQUE -AFTER 3.5 MINUTES OF CUTTING, OBSERVED TORQUE DROP OFF TO 0-1 K AND PUMP PRESSURE DROPPED FROM 830 PSI TO 330 PSI,INDICATING 9-5/8"CSG CUT. -CONTINUE CUTTING AT 7 BPM WITH 330 PSI FOR 15 MINS,AS PER WELL PROGRAM TO ENSURE GOOD CUT. 2200 - 23:30 1.50 CUT P DECOMP DISPLACE DEAD CRUDE FREEZE PROTECT FROM 13-3/8"x 9-5/8"ANNULUS. PJSM WITH RIG CREW,BAKER AND MI REP. -CLOSE ANNULAR PREVENTER. PUMP 40 BBL DEEP CLEAN PILL DOWN, FOLLOWED BY 8.5 PPG SEAWATER,DOWN 4" DP TAKING RETURN THRU OA TO THE FLOWBACK TANK AT 2 BPM WITH 80 PSI. -AT 150 BBLS DISPLACED,INCREASE PUMP RATE F/2 BPM T/5 BPM WITH 320 PSI. *PUMP TOTAL OF 203 BBLS AND RETURN CLEANED UP. 23:30 - 00:00 0.50 CUT P DECOMP FLOW CHECK. -10 MIN FLOW CHECK. WELL STABLE. VERIFY NO PRESSURE. -OPEN ANNULAR PREVENTER. -BLOW DOWN CHOKE LINE. *FLUID LOSS LAST 12 HRS=0 BBLS *OA PRESSURE=0 PSI 11/23/2014 00:00 - 00:30 0.50 CUT P DECOMP RIG SERVICE -SERVICE AND INSPECT TOP DRIVE, BLOCKS,DRAW WORKS AND ST-80. 00:30 - 02:00 1.50 CUT P DECOMP PULL OUT OF HOLE WITH 8-1/4" MULTI-STRING CUTTER BHA#7. -PJSM WITH RIG CREW AND BAKER REP. -POOH WITH 8-1/4"MULTI-STRING CUTTER BHA F/2,005'T/SURFACE. -INSPECT AND UD 8-1/4"MULTI-STRING CUTTER BHA. *OBSERVED WEAR ON KNIVES,INDICATING GOOD CUT. 02:00 - 02:30 0.50 WHSUR P DECOMP RETRIEVE WEAR BUSHING. -R/U AND RETRIEVE WEAR BUSHING. -L/D WEAR BUSHING AND RETRIEVAL TOOL. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 15 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 04:30 2.00 CASING P DECOMP SPEAR AND PULL 9-5/8"CASING FREE. -PJSM WITH RIG CREW,BAKER AND CAMERON REPS. -P/U AND M/U SPEAR BHA#8. -6-3/8"BULLNOSE -8-3/8"SPEAR PACK-OFF ASSY -8-1/4"ITCO SPEAR W/8.681 GRAPPLE -6-3/8"SPEAR EXTENSION -10-3/4"STOP SUB -CROSSOVER SUB -ENGAGE 9-5/8"CSG WITH SPEAR BHA, BELOW CSG HANGER AS PER BAKER REP. 'ENGAGE WITH 5K DOWN,PULL 15K OVER, SET DOWN 5K,PULL 25K OVER,SLACK OFF TO NEUTRAL WT. -CAMERON REP,BACK OUT LOWER LDS. -WORK AND PULL 9-5/8"CSG HANGER FREE, AS PER BAKER REP.(DRY STRING WEIGHT=94K,BUOYANCY WT=82K) "9-5/8"CSG HANGER FREE WITH 35K OVER PULL. 04:30 - 06:30 2.00 CASING P DECOMP I CIRCULATE TO CLEAN AND CLEAR WELLBORE OF RESIDUAL DEAD CRUDE FREEZE PROTECT. CIRC 8.5 PPG SEAWATER AT 9 BPM WITH 70 PSI,WHILE RECIPROCATING CSG 60',UNTIL RETURNS CLEANED UP. -10 MIN FLOW CHECK. WELL STABLE. "SIMOPS: -PJSM ON BEEVER SLIDE OPS WITH RIG CREWAND DOYON CASING REP. -MOBE POWER TONGS AND 9-5/8" HANDLING EQUIPMENT TO RIG FLOOR. 06:30 - 08:30 2.00 CASING P DECOMP LAY DOWN 8-1/4"ITCO SPEAR BHA#8 AND RIG UP TO PULL/LAY DOWN 9-5/8"CASING. -PJSM ON BEEVER SLIDE OPS AND PULLING /L/D 9-5/8"CSG WITH RIG CREW,BAKER AND DOYON CSG REPS. L/D 8-1/4"ITCO SPEAR BHA. -BLOW DOWN TOP DRIVE. -M/U X-OVERS AND PREPARE WELL CONTROL EQUIPMENT FOR PULLING 9-5/8" CSG. R/U POWER TONGS AND 9-5/8"HANDLING EQUIPMENT. -CLEAN AND CLEAR RIG FLOOR OF SPEAR BHA. 08:30 - 12:00 3.50 CASING P DECOMP PULL OUT OF HOLE,LAYING DOWN 9-5/8"47# L-80 NSCC CASING. -L/D 9-5/8"CSG HANGER. -POOH,L/D 9-5/8"CSG F/CUT AT 2,005'T/ 1,179'. "AVERAGE BREAK-OUT TORQUE=20-25K FT/LBS "KICK WHILE TRIPPING DRILL,ELEVATED TO COMPLEX DRILL WITH ANNULAR FAILURE. -FOLLOWED BYAAR." FLUID LOSS LAST 12 HRS=0 BBLS •OA PRESSURE=0 PSI Printed 1/6/2015 5:05:21PM Page 46 of 62 North America-ALASKA-BP Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(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 CASING P DECOMP RIG SERVICE -SERVICE AND INSPECT TOP DRIVE, BLOCKS,DRAW WORKS AND ST-80. 12:30 - 15:00 2.50 CASING P DECOMP PULL OUT OF HOLE,LAYING DOWN 9-5/8"47# L-80 NSCC CASING. -PJSM WITH RIG CREWAND DOYON CSG REP. -L/D 9-5/8"CSG HANGER. -POOH,L/D 9-5/8"CSG F/1,179'T/SURFACE. *RECOVERED:50-JTS OF 9-5/8"CSG, 1-CUT JT OF 9-5/8"CSG(9.53'LONG), 16- TURBOLATORS *OBSERVED ECCENTRIC AREA ON FIRST JT OF 9-5/8"CSG BELOW HANGER. 15:00 - 15:30 0.50 CASING P DECOMP CLEAN RIG FLOOR. CLEAN AND CLEAR RIG FLOOR OF POWER TONGS AND 9-5/8"HANDLING EQUIPMENT. 15:30 - 18:30 3.00 CASING P ! DECOMP MAKE UP 12-1/4"DRESS-OFF/13-3/8" SCRAPER BHA#9. -PJSM WITH RIG CREW AND BAKER REP. -P/U,M/U AND RIH WITH 12-1/4"DRESS-OFF BHA AND TAG AT 43'WITH 10K DOWN. ATTEMPT TO WORK PAST 43'SEVERAL TIMES,WITH NO SUCCESS. *DISCUSS PLAN FORWARD WITH ODE. ASSEMBLY COMPONENTS FOR CONTINGENCY BHA CONFIGURATIONS. 18:30 - 21:30 3.00 CASING N DPRB , 42.38 DECOMP MODIFY 12-1/4"DRESS-OFF BHA#9 IN ATTEMPT TO GET PAST TIGHT SPOT. PJSM WITH RIG CREWAND BAKER REP. -REMOVE 13-3/8"CSG SCRAPER FROM BHA. -RIH AND ATTEMPT TO WORK PAST TIGHT SPOT AT 43',SEVERAL TIMES WITH NO SUCCESS. POOH. REMOVE 12-1/4"DRESS-OFF SHOE AND M/U 13-3/8"CSG SCRAPER. -RIH AND ATTEMPT TO WORK 13-3/8"CSG SCRAPER PAST TIGHT SPOT AT 43'SEVERAL TIMES WITH NO SUCCESS. POOH. -L/D 13-3/8"SCRAPER BHA. 21:30 - 00:00 2.50 CASING N DPRB 42.38 DECOMP RUN 12-1/4"WATERMELON MILL BHA#10. -PJSM FOR MILLING OPERATIONS:DISCUSS THE HAZARDS INVOLVED WITH PICKING UP BHA,ENSURE RIG HAND IS AT THE CELLAR AT ALL TIMES MONITORING FOR RETURNS UP THE CONDUCTOR TO THE CELLAR. -P/U,M/U AND RIH WITH 12-1/4" WATERMELON MILL BHAAND TAG AT 43' WITH 7K DOWN. -WASH,REAM AND WORK PAST TIGHT SPOT F/43'T/46.5'. *PUW=60K, SOW=60K,RTW=60K, PUMP RATE=5 BPM WITH 40 PSI, RPM=70 WITH 3-5K TORQUE(FREE TORQUE=1 K), WOB= 3-5K *FLUID LOSS LAST 12 HRS=0 BBLS *OA PRESSURE=0 PSI Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 17 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/24/2014 00:00 01:00 1.00 CASING N DPRB 42.38 DECOMP ATTEMPT TO WORK 12-1/4"WATERMELON MILL BHA#10 PAST OBSTRUCTION IN THE 13-3/8"CASING -WASH,REAM AND WORK PAST TIGHT SPOT F/46.5'T/47'. *PUW=60K, SOW=60K,RTW=60K, PUMP RATE=5 BPM WITH 40 PSI, RPM=70 WITH 3-5K TORQUE(FREE TORQUE=1K), WOM= 3-5K -POOH AND INSPECT 12-1/4"WATERMELON MILL BHA. *OBSERVED 4"OF SLIGHT WEAR ON LEADING EDGE OF WATERMELON MILL. *DURING REAMING OPERATIONS, COMMUNICATION WITH 13-3/8"SURFACE CSG AND CONDUCTOR CSG OBSERVED IN CELLAR,MAINTAIN 100%RETURNS WITH 30%RETURNS BEING CIRCULATED TO THE LINED CELLAR BOX. 01:00 - 04:00 3.00 CASING N DPRB ' 42.38 DECOMP ATTEMPT TO WORK 12-1/4"WATERMELON MILL BHA#10 PAST OBSTRUCTION IN THE 13-3/8"CASING WASH,REAM AND WORK OBSTRUCTION IN THE 13-3/8" F/47'T/48'.TOTAL OF 5'OF PROGRESS MADE FROM FIRST POINT OF THE OBSTRUCTION. *PUW=60K, SOW=60K,RTW=60K, PUMP RATE=3 BPM WITH 20 PSI, RPM=70 WITH 3-5K TORQUE(FREE TORQUE=1K), WOM= 3-5K !*REDUCED PUMP RATE F/5 BPM T/3 BPM,TO KEEP UP WITH RETURNS IN CELLAR. *DURING REAMING OPERATIONS, COMMUNICATION WITH SURFACE CSG AND CONDUCTOR CSG OBSERVED IN LINED I CELLAR,WITH 100%RETURNS OF SEAWATER BEING CIRCULATED. SHUT DOWN MILLING OPERATIONS TO EVALUATE OPERATION: CONTACT ODE 04:00 - 07:00 3.00 CASING N DPRB 42.38 DECOMP LAY DOWN 12-1/4"WATERMELON MILL BHA #10. POOH AND INSPECT 12-1/4"WATERMELON MILL BHA. *OBSERVED MINIMAL CHANGE OF WEAR ON LEADING EDGE OF WATERMELON MILL, FROM PREVIOUS INSPECTION. *DISCUSS PLAN FORWARD WITH ODE&WTL ASSEMBLE TOOL COMPONENTS FOR CONTINGENCY BHA CONFIGURATIONS. *SIMOPS: -ESTABLISH PLAN FOR TAKING RETURNS AT THE CELLAR AND REINTRODUCING THEM BACK TO THE RIG. RIG CREW WORKING ON DDI MP2s AND CLEANING RIG FLOOR,WHILE WAITING ON EQUIPMENT FOR BHA CONTINGENCIES. *CONTINUOUSLY MONITOR WELL VISUALLY AT CELLAR. WELL STABLE. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 18 of 62 Operation Summary Report • Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C-actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:00 - 11:00 4.00 CASING N DPRB 42.38 DECOMP WORK 11-1/2"CASING SWAGE BHA PAST OBSTRUCTION IN 13-3/8"CASING. -P/U,M/U AND RIH WITH 11-1/2"CSG SWAGE. -ESTABLISH PARAMETERS. 'PUW=55K, SOW=55K -RIH WITH 11-1/2"CSG SWAGE BHAAND TAG AT 46'WITH 5K DOWN. WORK 11-1/2"CSG SWAGE F/46'T/55', WITH 5-7K DOWN. PULL UP HOLE F/55'T/46'. '5-6K OVER PULL. WORK 11-1/2"SWAGE F/46'T/55'SEVERAL TIMES. -RIH WITH 11-1/2"SWAGE F/55'T/546'. *NO INDICATIONS OF ANY FURTHER OBSTRUCTIONS. 11:00 12:00 1.00 I CASING N DPRB ' 42.38 DECOMP LAY DOWN 11-1/2"CASING SWAGE BHA. -10 MIN FLOW CHECK. WELL STABLE. -POOH WITH 11-1/2"CSG SWAGE F/546'T/ SURFACE. L/D 11-1/2"CSG SWAGE BHA. 12:00 - 12:30 0.50 CASING P DECOMP RIG SERVICE -SERVICE AND INSPECT TOP DRIVE, BLOCKS,DRAW WORKS AND ST-80. FLUID LOSS LAST 12 HRS=0 BBLS *OA PRESSURE=0 PSI 12:30 - 14:30 2.00 CASING P DECOMP RUN DRESS-OFF MILL BHA#12. -PJSM WITH RIG CREWAND BAKER REP. *COVERED FLUIDS MANAGEMENT AND CIRCULATION TO THE LINED CELLAR BOX. -P/U,M/U AND RIH WITH DRESS-OFF BHA AND TAG TOP OF 9-5/8"CSG STUB AT 1,996'. 14:30 - 16:00 1.50 CASING P DECOMP 'DRESS-OFF 9-5/8"CASING STUB AT 2,005'. -ESTABLISH PARAMETERS AND OBTAIN SPRs. 'PUW=90K, SOW=95K, RTW=95K, RPM=50 WITH 1-2K FREE TORQUE, PUMP RATE=6 BPM WITH 120 PSI -RIH WITH DRESS-OFF MILL BHA F/1,996' AND TAG TOP OF 9-5/8"CSG STUB AT 2,005'. -DRESS-OFF 9-5/8"CSG STUB F/2,005'T/ 2,006'. 'RPM=50 WITH 2-4K TORQUE, PUMP RATE= 6 BPM WITH 120 PSI, WOM=3-5K 16:00 - 17:00 1.00 CASING P DECOMP CIRCULATE. -PUMP 40 BBL DEEP CLEAN PILL AND CIRC SAME OUT AT 6 BPM WITH 120 PSI. -10 MIN FLOW CHECK. WELL STABLE. 17:00 - 18:30 1.50 CASING P DECOMP PULL OUT OF HOLE WITH DRESS-OFF MILL BHA#12. -POOH WITH DRESS-OFF BHA F/2,006'T/ 250'. 18:30 - 20:00 1.50 CASING P DECOMP LAY DOWN DRESS-OFF MILL BHA#12. -10 MIN FLOW CHECK FOR NON-SHEARABLES ACROSS BOP STACK WELL STABLE. -POOH AND L/D DRESS-OFF MILL BHA. -CLEAN AND CLEAR RIG FLOOR OF DRESS-OFF MILL BHA. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 19 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 00:00 4.00 CASING P DECOMP RIG UP TO RUN 9-5/8"47#L-80 VAMTOP CASING PATCH. PJSM WITH RIG CREW,DOYON CASING, HES AND BAKER REPS. -MOBE POWER TONGS AND 9-5/8"RUNNING/ HANDLING EQUIPMENT AND BOW SPRING CENTRALIZERS TO RIG FLOOR. -R/U POWER TONGS,TORQUE-TURN AND 9-5/8"HANDLING EQUIPMENT. -M/U X-OVERS TO FOSV AND R/U SAFETY JT, FOR WELL CONTROL. *FLUID LOSS LAST 12 HRS=0 BBLS *OA PRESSURE=0 PSI 11/25/2014 00:00 - 00:30 0.50 CASING P DECOMP RIG SERVICE SERVICE AND INSPECT TOP DRIVE, BLOCKS,DRAW WORKS AND ST-80. 00:30 - 05:00 4.50 CASING P DECOMP RUN 9-5/8"47#L-80 VAMTOP CASING PATCH. -PJSM WITH RIG CREW,HES,DOYON CASING AND BAKER REPS. -P/U,M/U AND RIH WITH 9-5/8"BOWEN CSG PATCH,9-5/8"47#L-80 CSG PUP JT AND 9-5/8" HES ES-CEMENTER ASSY TO 68'. -P/U,M/U AND RIH WITH 9-5/8"CSG PATCH ASSY F/68'T/1,558'. *SHOE TRACK ASSEMBLY AND FIRST JT OF 9-5/8"CSG BAKER LOCKED. *TORQUE-TURN ALL VAMTOP CONNECTIONS TO 15,900 FT/LBS. *1-FREE FLOATING,9-5/8"x 11-3/4"STRAIGHT VAIN,BOW SPRING CENTRALIZER INSTALLED ON EACH JT. 05:00 - 05:30 0.50 CASING P DECOMP 'MOB CEMENT HEAD AND HANDLING EQUIPMENT TO RIG FLOOR. 05:30 - 06:30 1.00 CASING N RREP 1,557.38 DECOMP CODE 8 TROUBLESHOOT ELECTRICAL CONTROL I UNIT ON PIPE SKATE. -SECURE WELL WITH FOSV. -TROUBLESHOOT ELECTRICAL CONTROL UNIT ON PIPE SKATE. RIG ELECTRICIAN,REPAIR ELECTRICAL CONTROL UNIT ISSUE. Printed 1/6/2015 5:05:21 PM North America-ALASKA-BP Page 20 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 - 09:30 3.00 CASING P DECOMP RUN 9-5/8"47#L-80 VAMTOP CASING PATCH. -P/U,M/U AND RIH WITH 9-5/8"CSG PATCH ASSY F/1,558'T/1,963'. -M/U 9-5/8"VAMTOP x 4"XT-39 X-OVER FOR LANDING JT. -OBTAIN PARAMETERS. *PUW=130K, SOW=135K IN 8.5 PPG SEAWATER. -RIH F/1,963'T/1,998'. -M/U TOP DRIVE. -RIH AND ENGAGE 9-5/8"BOWEN CSG PATCH OVER 9-5/8"STUB AT 2,006',AS PER BAKER 1 REP. '*NO-GO ON 9-5/8"CSG STUB WITH 30K DOWN AND PULL 100K OVER TO ENSURE CSG PATCH SET.(END OF 9-5/8"CSG PATCH AT 2,007'WITH 3'OF SWALLOW) *TORQUE-TURN ALL VAMTOP CONNECTIONS TO 15,900 FT/LBS. *1-FREE FLOATING,9-5/8"x 11-3/4"STRAIGHT VAIN,BOW SPRING CENTRALIZER INSTALLED ON JTS#1-46 *TOTAL CENTRALIZER=46 09:30 - 10:30 1.00 CASING P DECOMP RIG UP HES QUICK LATCH CEMENT HEAD. PJSM WITH RIG CREW,BAKER AND HES REPS. -P/U AND M/U X-OVER AND HES QUICK LATCH CEMENT HEAD. *SIMOPS: -POSITION SLB CEMENT UNIT AND EQUIPMENT. 10:30 - 11:30 1.00 CASING P DECOMP TEST 9-5/8"BOWEN CASING PATCH AND SHEAR HES ES-CEMENTER OPEN. -PJSM WITH BAKER AND HES REPS. PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. PRESSURE TEST 9-5/8"CSG PATCH TO 250 PSI FOR 5 CHARTED MINS AND 1,000 PSI FOR 10 CHARTED MINS. TEST PASS. *2.0 BBLS TO PRESSURE UP TO 1,000 PSI. -PULL 100K OVER TO TEST CSG PATCH(230K ON WT INDICATOR) -SHEAR ES-CEMENTER OPEN:INCREASE PRESSURE F/1,000 PSI T/2,580 PSI AND OBSERVED ES-CEMENTER SHEAR OPEN. *CONFIRMED ES-CEMENTER SHEAR WITH VISUAL INDICATION IN CELLAR. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 21 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 13:00 1.50 CEMT P DECOMP PRESSURE TEST SLB CEMENT EQUIPMENT AND LINES. -PJSM WITH HES,SLB AND BAKER REPS. PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -PUMP 5 BBLS OF FRESH WATER TO PURGE CEMENT LINES. -FUNCTION TEST OVERPRESSURE PROTECTION DEVICES. 'WSL VERIFIED PUMP TRIPS FUNCTION PROPERLY ON BOTH HEADS. -PRESSURE TEST CEMENT EQUIPMENT AND LINES TO 250/4,000 PSI FOR 5 CHARTED MINS EACH. TEST PASS. -POSITION AND R/U VAC-TRUCKS FOR RETURNS IN LINED CELLAR. 13:00 - 14:30 1.50 CONDHL P DECOMP CIRCULATE. -CIRC 290 BBLS OF 120°8.5 PPG SEAWATER AT 5 BPM WITH 100 PSI,TO WARM WELLBORE. 14:30 - 17:00 2.50 CASING P DECOMP CEMENT 9-5/8"CASING PATCH. -LINE UP CEMENT UNIT TO WELL. MIX AND PUMP 180 BBLS OF 15.8 PPG CLASS G CEMENT WITH GASBLOKAND ADDITIVES. 'YIELD=1.17 CUFT/SK , -SHUT DOWN CEMENT UNIT. .-LAUNCH ES-CEMENTER CLOSER PLUG. -SLB CEMENTERS,KICK OUT CLOSER PLUG WITH 5 BBLS FRESH WATER. -SHUT DOWN CEMENT UNIT. -LINE UP RIG PUMPS TO DISPLACE CMT. DISPLACE CMT WITH 8.5 PPG SEAWATER AT 5 BPM WITH 70 PSI. 1-DISPLACE CMT WITH 8.5 PPG SEAWATER AT 5 BPM WITH 580 PSI. *CMT RETURNS TO SURFACE AT70 BBLS DISPLACED. -SLOWED PUMP TO 2 BPM WITH 700 PSI,AT 130 BBLS DISPLACED. -SLOWED PUMP TO 0.5 BPM WITH 680 PSI, AT 135 BBLS DISPLACED. ,-BUMPED PLUG ON SCHEDULE AT 138 BBLS TOTAL DISPLACEMENT. *FINAL DISPLACEMENT PRESSURE=680 PSI. *BUMPED PLUG AND CLOSE ES CEMENTER WITH 1,900 PSI. HELD FOR 5 MINS. -BLED OFF PRESSURE AND CHECK FLOATS. FLOATS HELD. -CEMENT IN PLACE WITH PLUG BUMPED AT 16:00 HRS ON 11/25/2014. 'UCA RESULTS: 500 PSI COMPRESSIVE STRENGTH AT 20 HRS:01 MINS. -R/D SLB CMT LINES AND EQUIPMENT. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 22 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 20:00 3.00 WHSUR P DECOMP INSTALL 9-5/8"EMERGENCY SLIPS. -PJSM WITH RIG CREW AND CAMERON REPS. I -VOID BOP STACK OF FLUID. SPLIT BOP STACK AT CASING HEAD FLANGE. -CENTER 9-5/8"CSG. -CAMERON REPS,INSTALL EMERGENCY CSG SLIP AND ENERGIZE WITH 70K. 20:00 - 23:00 3.00 CASING P DECOMP CUT AND LAY DOWN EXCESS 9-5/8"CASING. -PJSM WITH RIG CREW AND CAMERON REPS. -VOID 9-5/8"CSG OF FLUID. -CAMERON REPS,R/U WACH'S CUTTER AND CUT EXCESS 9-5/8"CSG. -UD HES SLIP LOCK CEMENT HEAD,X-OVER, 4'9-5/8"PUP JT,AND 9-5/8"CUT JT(35.09' LONG). "6.37'OF JT#47 LEFT IN WELL. 23:00 - 00:00 1.00 I WHSUR P DECOMP I INSTALL NEW MCEVOY SSH TUBING HEAD. . -N/D OLD TUBING HEAD AND REMOVE FROM ' 'CELLAR. 11/26/2014 00:00 - 04:30 4.50 WHSUR P DECOMP INSTALL NEW MCEVOY SSH TUBING HEAD. -CONTINUE N/D OLD TUBING HEAD AND REMOVE FROM CELLAR. I -N/U NEW MCEVOY SSH TUBING HEAD WITH ' YBT SECONDARY SEAL. � -INSTALL DOUBLE ANNULUS VALVES ON ',, L NEW TUBING SPOOL. -CAMERON REP RILDS,TORQUE LDS TO 500 FT-LBS,TORQUE GLAND NUTS TO 450 FT-LBS -PUMP PLASTIC INTO VOID BETWEEN PRIMARY SEAL AND SECONDARY YBT SEAL. -PRESSURE TEST TO 3500 PSI,FAILED. I -RE-TORQUE LDS AND GLAND NUTS. -RE-LOCATE PLASTIC SEALANT PUMP TO SECONDARY OUTLET ON TUBING SPOOL, ATTEMPT TO PUMP ADDITIONAL SEALANT INTO SPOOL. ABLE TO PUMP VERY SMALL AMOUNT. -ATTEMPT PRESSURE TEST,OBSERVE I PRESSURE BLEED OFF AT 1500-1800 PSI DOWN 0 PSI. •CONTACT DRLG.SUPT.AND ODE AND INFORM OF FAILED TEST. 04:30 - 09:00 4.50 WHSUR N SFAL -0.62 DECOMP N/D TUBING SPOOL -PJSM FOR N/D SPOOL. -N/D NEW TUBING SPOOL TO INSPECT PRIMARY SEAL. I -BOLDS AND REMOVE PRIMARY SEAL FROM EMERGENCY SLIPS,OBSERVE DAMAGE ON PRIMARY SEAL. -INSTALL NEW PRIMARY SEAL AND N/U TUBING SPOOL. -CAMERON REP RILDS,TORQUE LDS TO 500 FT-LBS,TORQUE GLAND NUTS TO 450 FT-LBS. I -INJECT NEW PLASTIC PACKING. ' -PRESSURE TEST VOID TO 250/3500 PSI FOR 5 MIN EACH,TEST GOOD. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 23 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT ' NPT Depth Phase Description of Operations I (hr) (usft) 09:00 - 11:30 2.50 BOPSUR P DECOMP N/U BOPE -PJSM FOR N/U OF BOPE,DISCUSS HAZARDS CONCERNING TORQUE WRENCH ' AND WORKING OVERHEAD. N/U BOPE. NO CHANGE TO RKB MEASUREMENTS. 11:30 - 13:30 2.00 BOPSUR 1 P DECOMP CHANGE OUT RAMS i -PJSM FOR REMOVING RAMS. DISCUSS ISOLATING ENERGY SOURCES. ' -REMOVE 9-5/8"RAMS,INSTALL 7"RAMS. 13:30 - 15:00 1.50 BOPSUR P DECOMP PRESSURE TEST BOPE -PJSM FOR TESTING BOPE,DISCUSS HIGH PRESSURE HAZARDS,INSTALL WHIP CHECKS. -R/U TEST MANIFOLD AND HOSES. -M/U WELL CONTROL VALVES FOR TESTING. TEST SLB MWD DRILL LINK EQUIPMENT I FOR 1/2 HR.PRIOR TO BEGINNING ACTUAL BOPE TEST. 15:00 - 18:00 3.00 BOPSUR P DECOMP PRESSURE TEST BOPE -FILL CHOKE MANIFOLD AND MGS,6 BBLS .TO FILL. -INSTALL TEST PLUG AND PERFORM BODY i I PRESSURE TEST,TEST PLUG LEAKING. -PULL TEST PLUG,CLEAN OFF AND RIH,RUN IN 4 EACH LDS AND TORQUE. , *D1 DRILL,CRT 2 MIN 0 SEC. 18:00 - 00:00 6.00 BOPSUR 1 P DECOMP PRESSURE TEST BOPE ' -TEST BOPE WITH 4",4-1/2",AND 7"TEST JOINTS. -PRESSURE TEST TO 250/3500 PSI FOR 5 MIN EACH,NO FAILURES. -PERFORM MPL TEST ON UPPER AND LOWER PIPE RAMS. TEST PLUG BEGAN LEAKING DURING TEST, RUN IN REMAINING LDS AND TORQUE. ABLE TO CONTINUE TESTING WITH NO FURTHER LEAKS. 11/27/2014 00:00 - 03:00 3.00 BOPSUR P 1 DECOMP CONTINUE PRESSURE TEST BOPE -TEST BOPE WITH 4",4-1/2",AND 7"TEST JOINTS. -PRESSURE TEST TO 250/3500 PSI FOR 5 MIN EACH,NO FAILURES. -PERFORM MPL TEST ON BLIND RAMS. -R/D TEST EQUIPMENT. ' I -BOLDS AND PULL TEST PLUG. -BLOW DOWN CHOKE,KILL,AND BLEEDER LINES. 03:00 - 03:30 0.50 WHSUR P DECOMP P/U WEAR RING AND RIH,RILDS. M/U SAFETY JOINT. -WEAR RING ID 9.25" 03:30 - 09:00 5.50 CLEAN P DECOMP M/U 8-1/2"CLEAN OUT BHA#13 -PJSM WITH BAKER REP AND RIG CREW. 1 -CLEAR FLOOR AND BRING BHA COMPONENTS TO RIG FLOOR. -M/U BHA PER BAKER REP. -P/U BHA#13 F/SURFACE T/893'. Printed 1/6/2015 5:05:21 PM North America-ALASKA-BP Page 24 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date j From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 10:30 1.50 CLEAN P DECOMP RIH ON ELEVATORS -RIH WITH 8.5"DRILLING BHA FROM 893'MD TO 1,841'MD -RIH ON ELEVATORS PICKING UP 4"DP 'SINGLES -FILL PIPE EVERY 1,000'MD 10:30 - 14:00 3.50 CLEAN P DECOMP DRILL ES CEMENTER -WASH DOWN WITH NO ROTATION F/1841'T/ 1905',TAG CEMENT AT 1905' -500 GPM,870 PSI -WASH DOWN WITH NO ROTATION F/1905'T/ 1936' -630 GPM,1300 PSI -RECIPROCATE PIPE F/1936'T/1841'AND CLEAN UP WELL BORE -WASH DOWN F/1936'T/1946',TAG PLUG AT 1946' -DRILL ES CEMENTER FROM 1946'MD TO 1948'MD -500 GPM, 850 PSI ON,850 PSI OFF -70 RPM,3.5K TORQUE ON,2.0K TORQUE OFF,WOB 5-6K PU 115K,SO 115K,ROT 115K SEA WATER:8.5 PPG IN,8.5 PPG OUT SPR'S AT 1841'MD -MUD PUMP#1,20 SPM-20 PSI,30 SPM-70 PSI -MUD PUMP#2,20 SPM-20 PSI,30 SPM-70 PSI 114:00 - 14:30 0.50 i CLEAN P DECOMP CIRCULATE BOTTOMS UP -CBU 1X -610 GPM,1300 PSI -NO ROTATION,NO PIPE RECIPROCATION -OBSERVED ALUMINUM AT BOTTOMS UP 14:30 - 00:00 9.50 CLEAN N RREP 1,947.38 DECOMP CODE 8 -TROUBLE SHOOT TOP DRIVE ELECTRICAL SERVICE LOOP CONNECTION -MONITOR WELL ON TRIP TANK WHILE CIRCULATING ACROSS TOP OF HOLE 11/28/2014 00:00 - 06:00 6.00 CLEAN N RREP 1,947.38 DECOMP CODE 8 -TROUBLE SHOOT TOP DRIVE ELECTRICAL SERVICE LOOP CONNECTION -MONITOR WELL ON TRIP TANK WHILE CIRCULATING ACROSS TOP OF HOLE -REPLACE BAD PINS ON TOP DRIVE POWER SUPPLY CABLE -FUNCTION TEST TOP DRIVE,VERIFY WORKING PROPERLY TO RESUME OPS Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 25 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 08:30 2.50 CLEAN P DECOMP DRILL DRILL ES CEMENTER -PJSM -P/U SINGLES FROM SHED THAT WERE LAID DOWN TO REPAIR TOP DRIVE -WASH DOWN F/1936'T/1948' -500 GPM,880 PSI,80 RPM,TQ 3K -PU 112K,SO 112K,ROT 112K,WOB 3K -DRILL ES CEMENTER AND CEMENT STRINGERS F/1948'MD T/2010'MD 630 GPM, 1330 PSI -80 RPM,6K TORQUE ON,OK TORQUE OFF, WOB 2-3K •-PU 112K,SO 112K,ROT 112K SEA WATER:8.5 PPG IN,8.5 PPG OUT 08:30 - 09:00 0.50 CLEAN P DECOMP •CIRCULATE BOTTOMS UP -CBU IX -630 GPM,1330 PSI NO ROTATION,NO PIPE RECIPROCATION -OBSERVED ALUMINUM AT BOTTOMS UP 09:00 - 09:30 0.50 CLEAN P DECOMP RIH WITH 8-1/2"CLEANOUT BHA#13 -WASH DOWN F/2010'T/2031' -96 GPM, 60 PSI -NO ROTATION,OBSERVE NO WOB,HOLE 'APPEARED CLEAN -RIH F/2031'T/2126' 09:30 - 10:00 0.50 CLEAN P DECOMP CIRCULATE HI-VIS SWEEP -CIRCULATE 30 BBL HI-VIS SWEEP SURFACE TO SURFACE -630 GPM,1330 PSI -50 RPM,1K TORQUE,WOB OK 10:00 - 10:30 0.50 CLEAN P DECOMP POOH -PULL BACK UP THROUGH HOLE TO VERIFY CLEAN -MONITOR WELL FOR 10 MINUTES,STATIC -POOH ON ELEVATORS F/2126'MD T/1936' MD OBSERVED NO OVERPULL OR TIGHT HOLE 10:30 - 15:30 5.00 CLEAN P DECOMP RIH -RIH WITH 8-1/2"CLEANOUT BHA#13 F/1936' T/5733' -RIH PICKING UP 4"DP SINGLES FROM PIPE SHED -RIH WITH 8-1/2"CLEANOUT BHA#13 F/5733' T/5922'OUT OF DERRICK 15:30 - 17:00 1.50 CLEAN P DECOMP RIH -WASH DN F/5922'T/6024',TAG CEMENT 'STRINGER AT 6024' -24 GPM,15 PSI -40 RPM,3-4K TORQUE,5K WOB -PU 177K,SO 150K,ROT 166K -CONTINUE WASHING DOWN,TAG SAND AT 6031' -DRY DRILL 20 MINUTES -40 RPM,4-6K TORQUE,8K WOB -VERIFY ON TOP OF SAND, INCREASE PUMP TO 210 GPM,OBSERVE WOB FALL OFF -POOH 30'AND SHUT DOWN PUMPS,SLACK OFF AND TAG AT 6033' SPR'S TAKEN AT 5922' Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 26 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 18:30 1.50 CLEAN P DECOMP CIRCULATE BOTTOMS UP RACK BACK 1 STAND IN DERRICK -CBU 1.5X'S -630 GPM,2100 PSI NO ROTATION,NO PIPE RECIPROCATION -OBSERVED SMALL AMOUNT OF SAND AND CEMENT AT BOTTOMS UP 18:30 - 20:30 2.00 CLEAN P DECOMP CUT AND SLIP -PJSM -B/D TOP DRIVE CUT AND SLIP 60'OF DRILLING LINE -SERVICE TOP DRIVE,CALIBRATE BLOCK HEIGHT -MONITOR WELL ON TRIP TANK,CIRCULATE ACROSS TOP OF HOLE 20 30 - 23:00 2.50 CLEAN P DECOMP POOH -PJSM -SEA WATER 8.5 PPG IN,8.5 PPG OUT -POOH ON ELEVATORS FROM 5938'MD TO 924'MD -PU 177K,SO 150K AT 5938'MD -OBSERVED NO TIGHT HOLE AT 23:00 - 00:00 1.00 , CLEAN P DECOMP UD 8-1/2"CLEANOUT BHA#13 -PJSM FOR HANDLING BHA WITH BAKER REP AND RIG CREW -MONITOR WELL FOR 20 MINUTES,STATIC C/O 4"ELEVATORS,INSTALL 5"ELEVATORS -STAND BACK 5"HWDP,1 STAND OF 6-1/4" DRILL COLLARS 11/29/2014 00:00 00:30 0.50 CLEAN P i DECOMP SERVICE RIG 00:30 02:00 1.50 CLEAN P DECOMP UD 8-1/2"CLEANOUT BHA#13 PJSM FOR CLEANING OUT BOOT BASKETS -MONITOR WELL FOR 10 MINUTES,STATIC -STAND BACK 6-1/4"DRILL COLLARS -CLEANOUT BOOT BASKETS,SMALL AMOUNT OF SAND AND CEMENT,TWO CUPS OF ES CEMENTER DEBRIS(BRASS AND ALUMINUM),PICTURES INCLUDED 02:00 - 05:30 3.50 CLEAN P DECOMP P/U RCJB CLEANOUT BHA#14 -PJSM WITH BAKER AND RIG CREW SEND 8-1/2"CLEANOUT BHA#13 COMPONENTS OFF FLOOR -BRING RCJB CLEANOUT BHA#14 COMPONENTS TO FLOOR -M/U RCJB CLEANOUT BHA#14 F/SURFACE T/882' 05:30 - 08:00 2.50 CLEAN P DECOMP RIH -RIH WITH RCJB CLEANOUT BHA#14F/ SURFACE T/2200'MD -RIH ON ELEVATORS OUT OF DERRICK -RIH F/882'T/5914' -FILL PIPE EVERY 20 STDS MONITOR HOLE FILL ON TRIP TANK Printed 1/6/2015 5.05:21PM North America-ALASKA-BP Page 27 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 09:30 1.50 CLEAN P DECOMP WASH DOWN TO TOP OF EZSV -RIH F/5914'T/6009' -OBTAIN PUMP PRESSURES 126 GPM,120 PSI,210 GPM 330 PSI,294 GPM,620 PSI -SHUT PUMPS DOWN DROP BALL,STAGE PUMPS UP TO 7 BPM -CIRCULATING PRESSURE INCREASED TO 790 PSI WITH BALL ON SEAT AND THEN DROPPED BACK TO 620 PSI '-INCREASE PUMP RATE TO 420 GPM,1500 PSI -SHUT PUMPS OFF AND RIH,TAG @ 6034', STACK 5K WOB -P/U AND WASH DOWN F/6034'T/6046' -420 GPM,1500 PSI ON,1500 PSI OFF -PU 180K,SO 153K,ROT 165K -40 RPM,3K TQ ON,3K TQ OFF -SHUT DOWN ROTARY,INCREASE PUMP RATE 504 GPM,2450 PSI -P/U AND S/O TO 6046'TO VERIFY TOP OF EZSV,4X'S 09 30 - 10:30 1.00 CLEAN P DECOMP [CIRCULATE PUMP 30 BBL HI-VIS SWEEP SURFACE TO SURFACE -500 GPM,2450 PSI -20 RPM,3K TQ -OBSERVE GOOD SAND RETURNS WITH SOME ALUMINUM SHAVINGS AT BUS 1030 - 12:00 1.50 CLEAN P DECOMP PRESSURE TEST CASING -PJSM,REVIEW PRESSURE CROSSCHECKLIST -TEST 250 PSI FOR 5 MIN,3650 PSI 30 MIN, TEST GOOD -6.8 BBLS PUMPED,6.5 BBLS BLED BACK INFORM WTL OF TEST RESULTS,RECEIVE APPROVAL TO PROCEED 12:D0 - 12:30 0.50 CLEAN P DECOMP BLOW DOWN -R/D TESTING EQUIPMENT B/D CHOKE AND KILL LINES 12:30 - 15:00 2.50 CLEAN P DECOMP POOH -PJSM FOR POOH -P/U SINGLE OFF SKATE,S/O AND TAG EZSV AT 6046' -MONITOR WELL FOR 10 MINUTES,STATIC -POOH F/6046'T/913' 15:JO - 17:00 2.00 CLEAN P DECOMP UD BHA -PJSM WITH CREW AND BAKER REP -MONITOR WELL PRIOR TO PULLING BHA THROUGH BOPE,STATIC -STAND BACK 5"HWDP AND 3 STANDS OF 6-1/4"DC -B/D AND LAY DOWN BOOT BASKETS AND RCJB. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 28 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 18:30 1.50 CLEAN P DECOMP UD BHA PJSM WITH CREW AND BAKER REP, HANDLING BHA COMPONENTS,DISCUSS HAND SAFETY AND HAMMER USE WHEN CLEANING BOOT BASKETS -RECOVER ES CEMENTER OPERATING SLEEVE IN RCJB CLOSE BLINDS -CLEAR FLOOR AND BRING BHA COMPONENTS FOR WHIPSTOCK TO FLOOR 18:30 - 22:00 3.50 WHIP P WEXIT P/U WHIPSTOCK BHA PJSM WITH CREW BAKER AND SLB REPS, DISCUSS HANDLING WHIPSTOCK,PLAN FOR BUILDING BHA WITH MINIMAL XO'S • REQUIRED FOR FOSV AND SAFETY JOINT -P/U MWD,XO'S,WHIPSTOCK -WSL AND BAKER REP VERIFY NUMBER OF SHEAR SCREWS,3 EA.TOTAL,REMOVE SET SCREWAND GIVE TO WSL,REVIEWAND SIGN WHIPSTOCK CHECKLIST -SCRIBE AND MEASURE RAMP OFFSET FROM TOOLFACE -M/U 3 STANDS 6-1/4"DRILL COLLARS,AND •5"HWDP 122:00 - 00:00 2.00 WHIP P WEXIT RIH -RIH WITH WHIPSTOCK F/949'T/1804' -SHALLOW TEST MWD AT 1804' -STAGE PUMPS 150 GPM-140 PSI,400 GPM- • 430 PSI,475 GPM-650 PSI -UNABLE TO GET A SURVEY -REDUCE PULSATION DAMPENER PRESSURE TO 450 PSI,REPLACE BAD SENSOR ON MANIFOLD 11/30/2014 00:00 - 00:30 0.50 WHIP P WEXIT SHALLOW TEST MWD -TEST MEASURE WHILE DRILLING TOOLS AT 1,804'-GOOD SURVEY -CIRCULATE 450 GPM -SHUT DOWN PUMPS AND BLOW DOWN TOP • DRIVE 00:30 - 05:00 4.50 WHIP P WEXIT RIH ON ELEVATORS -RIH WITH WHIPSTOCK F/1804'T/5887' -90 SECONDS/STAND MAX RUNNING SPEED -BREAK CIRCULATION EVERY 20 STANDS, 126 GPM,90 PSI -MONITOR HOLE FILL ON TRIP TANK 05:00 - 06:00 1.00 WHIP P WEXIT I SET WHIPSTOCK -CIRC 450 GPM,ORIENTATE RAMP 60 DEGREES LEFT PU 185K,SO 155K • RIH F/5,887'T/6,053' -SHUT DOWN PUMPS -RIH F/6,035'T/6,045',STACK 5K WOB AT •6045' -SLACK OFF AND SHEAR ANCHOR WITH 18K WOB,S/O TO 20K WOB -P/U 10K OVERPULL TO 195K TO CONFIRM • ANCHOR SET -SLACK OFF AND SHEAR BOLTS WITH 50K WOB Printed 1/6/2015 5:05:21PM North America-ALASKA-BP #'age 29 of Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 07:30 1.50 WHIP P WEXIT DISPLACE WELL. '-DISPLACE 8.5 PPG SEAWATER WITH 9.4 PPG LSND MILLING FLUID -PUMP 40 BBLS 9.4 PPG LSND HIGH VIS SPACER -459 GPM,817 PSI -PUMP 438 BBLS 9.4 PPG LSND -459 GPM,817 PSI 07:30 - 08:00 0.50 WHIP P WEXIT SPACE OUT TO MILL WINDOW -POOH ON ELEVATORS F/6020'T/5960' -RACK BACK 1 STAND -PICK UP SINGLE FROM PIPESHED TO SPACE OUT FOR MILLING WINDOW -RIH F/5960'T/5992' 08:00 - 08:30 0.50 STWHIP P WEXIT RIH,OBTAIN PARAMETERS -RIH F/5992'T/6024',TAG WHIPSTOCK -420 GPM,940 PSI ON,940 PSI OFF -70 RPM,3K TORQUE OFF -PU 180K,SO 155K,ROT 167K -P/U TO SERVICE RIG STWHIP P WEXIT RIG SERVICE 08:30 09:00 0.50 09:00 - 09:30 0.50 STWHIP N RREP 6,044.38 WEXIT 'CHANGE OUT POP OFF ON MUD PUMP#2. 09:30 - 20:00 10.50 STWHIP P WEXIT MILL WINDOW -MILL F/6024'T/6060' -580 GPM,1570 PSI ON,1570 PSI OFF -100 RPM,4-5K TO ON,3-4K TQ OFF -PU 180K,SO 155K,ROT 167K 20:00 - 21:30 1.50 1 STWHIP P WEXIT I CBU -CIRCULATE HI-VIS SWEEP SURFACE TO SURFACE -590 GPM,1590 PSI NO INCREASE IN RETURNS OBSERVED AT BUS SPRS TAKEN AT 6019'MD,5742'TVD 21:30 - 00:00 2.50 STWHIP P WEXIT LOT -L/D SINGLE TO GET BACK ON EVEN STANDS -RIG UP AND PERFORM LOT -MUD WEIGHT:9.4 PPG,5742'TVD,6033'MD -PUMP 4.1 BBLS TO 1200 PSI,BLEED BACK 2.5 BBLS -LOT EMW=13.4 PPG -R/D TEST EQUIPMENT AND BLOW DOWN 12/1/2014 00:00 - 03:30 3.50 STWHIP P WEXIT 1POOH F/5982'MD T/1044'MD PJSM FOR POOH -PUMP 30 BBL 10.4 PPB DRY JOB -MONITOR WELL FOR 10 MINUTES,STATIC -MUD WEIGHT 9.4 PPG IN,9.4 PPG OUT -POOH ON ELEVATORS F/5982'MD T/1044' MD -PU 170K,SO 155KAT 5982'MD 03:30 - 07:00 3.50 STWHIP P WEXIT L/D WHIPSTOCK BHA PJSM FOR L/D BHA -MONITOR WELL FOR 10 MINUTES,STATIC -L/D BHA F/1044'T/SURFACE -RACK BACK 3 STANDS OF 5"HWDP,L/D 3 STDS OF 6-1/4"DC'S Printed 1/6/2015 5:05:21 PM North America-ALASKA-BP Page 30 of 62 Operation Summary Report L Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 07:00 - 09:30 2.50 STWHIP P WEXIT UD WINDOW MILLING BHA ' -MOB MILLS AND COMPONENTS OFF FLOOR UPPER STRING MILL IN GAUGE,STARTER 'MILL 3/16"UNDER GAUGE P/U STACK FLUSHING TOOL AND WASH STACK B/D TOP DRIVE 09:30 - 13:30 4.00 STWHIP P • i WEXIT M/U 8-1/2"INTERMEDIATE DRILLING BHA T/ 556' -PJSM FOR P/U DRILLING BHA WITH RIG CREWAND SLB , M/U NEW 8-1/2"SMITH BIT,SLB POWERDRIVE X6,LWD,MWD -M/U NON-MAG STABILIZER,3 JTS NON-MAG FLEX COLLARS,FLOAT SUB -M/U 7 JTS HWDP,HYDRAULIC JARS,4 JTS ' HWDP,XO TO 4"DP 13:30 - 20:00 • 6.50 • STWHIP 1 P WEXIT I RIH WITH 8-1/2 INTERMEDIATE DRILLING ASSEMBLY -PJSM -RIH F/556'MD T/3120'PICKING UP SINGLES I 1 1 i FROM PIPE SHED -RIH F/3120'T/5967'W/STDS •-MONITOR HOLE FILL ON TRIP TANK 20:00 - 20:30 0.50 ' STWHIP P WEXIT OBTAIN BASELINE ECD I I -RIH F/5967'T/6050' CIRCULATE TO ACQUIRE BASELINE ECD, 9.88 PPG -INCREASE PULSATION DAMPENER PRESSURE *PRESSURE WAS REDUCED FOR SHALLOW MWD TEST FOR WHIPSTOCK RUN 20:30 - 00:00 3.50 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE -F/6060'MD TO 6157'MD(5838'TVD) 575 GPM, 2130 PSI ON,2130 PSI OFF -100 RPM,5-11K TORQUE ON,4-5K TORQUE OFF -PU 160K,SO 145K,ROT 150K -ECD:ACTUAL=9.96 PPG,CALC=9.88 PPG -RECORD INCLINATION EVERY 10' -ACTUAL ROTATE TIME=0.84 HRS -ACTUAL SLIDE TIME=0.0 HRS -BACKREAM 60 FT PRIOR TO CONNECTIONS -MUD WEIGHT:9.4+PPG IN,9.4+PPG OUT SPR @ 5963'MD,5687'TVD,9.4 PPG AT 20:30 HRS -MP#1 30 SPM,270 PSI,40 SPM,360 PSI ' -MP#2 30 SPM,270 PSI,40 SPM,360 PSI *STOP DRILLING FOR 1 HOUR,SCREEEN DOWN TO 80 AND 100 MESH SCREENS I*0 BBLS OF 9.4 PPG LSND LOST FOR TOUR Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 31 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date: 12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) • 12/2/2014 00:00 - 01:30 1.50 DRILL P INTI UNABLE TO GET REQUIRED BUILD RATE -SUSPECT TRACKING OF CASING DUE TO LACK OF INCLINATION AT BIT. -CONTACT ODE AND ETL,DISCUSS PLAN FORWARD. MONITOR WELL VIA TRIP TANK,FLOW CHECK WELL FOR 10 MIN,STATIC. -POOH F/6,199'T/6,157'. -STAND BACK 1 STD AND BLOW DOWN TOP DRIVE. POOH F/6157'T/5967'ON ELEVATORS. PU 165K,SO 157K. 01:30 - 09:00 7.50 DRILL P INTI CONTROL DRILL 8-1/2"INTERMEDIATE -M/U TD,WASH DOWN T/6,199'. -DRILL F/6,199'T/6,206'MD(5879'TVD)AT 1'/ HR. -DRILL F/6,206'T/6,218'MD(5888'TVD)AT 10' /HR. 1-511 GPM,1744 PSI ON,1730 PSI OFF. 110 RPM,3K TQ ON,2K TQ OFF. -PU 160K,SO 145K,ROT 150K,WOB 1-2K. '-ECD ACTUAL=9.84 PPG,CALC=9.88 PPG. -ROT TIME 5 HRS,SLIDE TIME 0 HRS. NO BACKREAMING. -MW 9.5 PPG IN,9.5 PPG OUT. -CONTINUE MONITORING INC AT BIT. SPR @ 6208'MD,5,878'TVD,9.5 PPG AT 09:00 HRS -MP#1 30 SPM,250 PSI,40 SPM,300 PSI. -MP#2 30 SPM,240 PSI,40 SPM,300 PSI. 09:)0 - 13:00 4.00 DRILL P INTI POOH F/6,219'MD T/5,967'MD PJSM FOR POOH. -MONITOR WELL FOR 10 MINUTES,STATIC. -POOH F/6,219'T/5,967'. -PUMP 30 BBL 10.7 PPG LSND DRY JOB. -POOH F/5,967'T/587'. -MUD WEIGHT 9.5 PPG IN,9.5 PPG OUT. PU 155K,S0 145K AT 5,967'MD. '0 BBLS OF 9.5 PPG LSND LOST FOR TOUR. 13:00 15:30 2.50 DRILL P INTI UD BHA -PJSM FOR L/D BHA. -MONITOR WELL FOR 10 MINUTES PRIOR TO BHA CROSSING BOPE. -L/D BHA F/587'T/SURFACE. -STAND 5"HWDP BACK. -STAND NM FLEX COLLARS BACK. -L/D STAB,MWD,LWD,FLX COLLAR,RSS. -SEND BHA COMPONENTS OFF FLOOR. GRADE BIT 1-3-CT-G-X-I-BT-BHA 15:30 - 18:00 2.50 DRILL P INTI P/U 8-1/2"INTERMEDIATE DRILLING BHA#3 -PJSM FOR P/U BHA. -F/SURFACE T/554'. -P/U 6-3/4 MOTOR AND DIAL UP TO 1.83. -P/U MWD TOOLS AND FLEX COLLAR. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 32 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 22:00 4.00 DRILL P INTI RIH WITH 8-1/2 INTERMEDIATE DRILLING BHA #3 PJSM FOR RIH. -RIH F/554'MD T/5,776'OUT OF DERRICK. SHALLOW TEST MWD AT 1,503',TEST GOOD. -FILL PIPE EVERY 20 STDS,150 GPM,430 PSI. -B/D TOP DRIVE. 22:00 - 00:00 2.00 DRILL P INTI CUT AND SLIP DRILLING LINE -SERVICE RIG. 12/3/2014 j 00:00 - 01:00 1.00 DRILL 1 P INTI CUT AND SLIP DRILLING LINE -ADJUST BRAKES. 01:00 - 02:00 1.00 DRILL P INTI RIH WITH 8-1/2 INTERMEDIATE DRILLING BHA #3 -PJSM FOR RIH. RIH F/5,776'MD T/5,965'P/U STANDS FROM DERRICK. -BRING PUMPS ON AND ORIENT MOTOR TO 1 150 DEGREES LEFT,AND SHUT PUMPS DOWN. RIH SLOWLY THROUGH WINDOW F/5,963'T/ 6,060'. B/O TOP DRIVE,RIH F/6,060'T/6,158'ON ELEVATORS P/U STANDS FROM DERRICK. -FILL PIPE EVERY 20 STDS,150 GPM,430 PSI. -WASH DOWN F/6,158'T/6,218' -ESTABLISH BENCHMARK ECD AT 9.83 PPG, 457 GPM,1390 PSI. SPR @ 6,196'MD,5,868'ND,9.5 PPG LSND AT 12:00 HRS -MP#1 30 SPM,220 PSI,40 SPM,300 PSI -MP#2 30 SPM,220 PSI,40 SPM,300 PSI 02:00 - 12-00 10.00 DRILL P INTI CONTROL DRILL 8-1/2"INTERMEDIATE -F/6,218'T/6,350'MD,(6,022'TVD). -TRENCH F/6,200'T/6,219'ORIENTED 150 DEGREES LEFT,462 GPM,1430 PSI. -CONTROL DRILL F/6,218'T/6,227'MD AT 5'/ HR,462 GPM,1430 PSI,1K WOB. -CONTROL DRILL F/6,227'T/6,237'MD AT 10'/ HR,462 GPM,1430 PSI,1K WOB. -CONTROL DRILL F/6,237'T/6,250'MD AT 20'/ HR,462 GPM,1430 PSI,1K WOB -CONTROL DRILL F/6,250'T/6,288'MD AT 30'/ HR,462 GPM,1430 PSI,1K WOB -DRILL F/6,288'T/6,350'MD -550 GPM,1880 PSI ON,1830 PSI OFF. -40 RPM,4K TQ ON,3K TO OFF. PU 165K,SO 150K,ROT 160K,WOB 1K. ECD ACTUAL 9.83 PPG,CALC 9.88 PPG. -SURVEY EVERY 30'. -ACTUAL ROTATE TIME 0.67 HRS. -ACTUAL SLIDE TIME 6.03 HRS. -JAR HRS 14.3 HRS. -MW 9.5 PPG IN,9.5 PPG OUT. 1*0 BBLS OF 9.5 PPG LSND LOST DURING TOUR Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 33 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 23:30 11.50 DRILL P INTI DRILL8-1/2"INTERMEDIATE -F/6,350'T/6,700'MD,(6,256'TVD). -580 GPM,2400 PSI ON,2200 PSI OFF. 40 RPM,4-5K TQ ON,3-4K TQ OFF. -PU 165K,SO 150K,ROT 155K,WOB 20-30K. -ECD ACTUAL 9.91 PPG,CALC 9.89 PPG. -SURVEY EVERY 30'. -ACTUAL ROTATE TIME 3.26 HRS. -ACTUAL SLIDE TIME 4.20 HRS. -JAR HRS 21.76 HRS. MW 9.5 PPG IN,9.5 PPG OUT. SPR @ 6,691'MD,6,256'TVD,9.5 PPG LSND AT 23:30 HRS •-MP#1 30 SPM,250 PSI,40 SPM,330 PSI -MP#2 30 SPM,250 PSI,40 SPM,330 PSI 23:30 - 00:00 0.50 DRILL P INTI CBU -PUMP HI-VIS SWEEP SURFACE TO SURFACE. -590 GPM,2300 PSI. • -40 RPM,RECIPROCATE PIPE 90'. '-REDUCE PUMP RATE TO 420 GPM ON DOWN STROKE. 0 BBLS OF 9.5 PPG LSND LOST DURING TOUR 12/4/2014 00:30 - 01:00 1.00 DRILL P INTI CONTINUE CBU PUMP HI-VIS SWEEP SURFACE TO SURFACE. -500 GPM,1780 PSI. -40 RPM,1-2K TORQUE,RECIPROCATE PIPE 90'. -REDUCE PUMP RATE TO 420 GPM ON DOWN STROKE. -OBTAIN SPR'S. SPR @ 6,658'MD,6,223'TVD,9.5 PPG LSND AT 01:00 HRS -MP#1 30 SPM,250 PSI,40 SPM,350 PSI -MP#2 30 SPM,240 PSI,40 SPM,340 PSI 01:00 - 02:30 1.50 DRILL P INTI POOH -PJSM FOR POOH -MONITOR WELL FOR 10 MINUTES,STATIC MUD WEIGHT,9.5 PPG IN,9.5 PPG OUT • -POOH ON ELEVATORS F/6,629'MD T/6,313' MD -PU 168K,SO 150KAT 6,619'MD. -M/U TOP DRIVE AND ORIENT 150 DEGREES LEFT AT 6,218'. -WORK STRING F/6,218'T/6,313'WITH PUMP OFF. -ORIENT TO HIGH SIDE. -WORK STRING F/6,218'T/6,313'WITH PUMP OFF,NO TIGHT SPOTS. -POOH F/6,313 T/6,155'MD. -PU 155K,SO 145KAT 6,155'MD. 02:30 - 03:00 0.50 DRILL P INTI PUMP DRY JOB. -PUMP 28 BBLS 10.55 PPG LSND DRY JOB -PUMP 12 BBLS 9.5 PPG LSND MUD. -131 GPM,400 PSI. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 34 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UW:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 05:30 2.50 DRILL P INTI POOH MONITOR WELL FOR 10 MINUTES,STATIC MUD WEIGHT,9.5 PPG IN,9.5 PPG OUT. -POOH ON ELEVATORS F/6,155'T/649'MD. -P/U 155K,S/O 145KAT 6,155'MD. -NO OVERPULL AT WINDOW,6,024'MD. 05:30 - 09:00 ' 3.50 DRILL P INTI LAY DOWN 8-1/2"INTERMEDIATE DRILLING BHA#3. -PJSM W/SLB REP AND DOYON PERSONNEL. STAND BACK 5"HWDP AND JARS. STAND BACK FLEX COLLARS. -LAY DOWN MWD,LWD,NM STABILIZER. -AAR HELD ON BREAKING APART AND LAYING DOWN BHA. 09:00 - 10:00 1.00 DRILL P INTI BRING 8-1/2"INTERMEDIATE DRILLING BHA #4 TO RIG FLOOR. -PJSM W/SLB REP AND DDI PERSONNEL. 10:00 - 10:30 0.50 BOPSUR P INTI WEEKLY BOPE FUNCTION CHECK/TEST. -PJSM, CALIBRATE BLOCK HEIGHT WITH SLB. -FUNCTION CHECK ON HCR CHOKE,HCR KILL AND BLIND SHEAR RAMS,GOOD TEST. BLOW DOWN CHOKE AND KILL LINES. 10:30 - 13:30 3.00 DRILL N WAIT INTI P/U 8-1/2"INTERMEDIATE DRILLING BHA#4 -PJSM,MAKE UP BIT FLOW RESTRICTOR. -FLOW RESTRICTOR DAMAGED AS IT WAS BEING PLACED IN RSS. -SLB REP NOTIFIED AND REPLACED. -L/D FLEX COLLAR RECEIVER PD TO PIPE SHED AND INSPECT. -P/U FLEX COLLAR RECEIVER PD AND M/U BIT. -CLOSE BLIND RAMS. 13:30 - 16:00 2.50 DRILL P INTI MAKE UP 8-1/2"INTERMEDIATE DRILLING BHA #4. -CHECK WELL FOR PRESSURE AND OPEN RAMS. -BLOW DOWN CHOKE LINE. -M/U BHA F/SURFACE T/555' -M/U FLEX COLLARS,5"HWDP AND JARS •AND CROSSOVER TO 4"DP. 16:00 - 18:30 2.50 DRILL P INTI RIH WITH 8-1/2"INTERMEDIATE DRILLING BHA#4 -PJSM. -RIH W/8-1/2"DRILLING BHA F/555'T/3,404' MD. -RIH ON ELEVATORS WITH 4"DP. -BREAK TO CIRCULATE EVERY 2000'MD WITH 550 GPM WITH 1300 PSI. `PERFORM WEEKLY BOPE FUNCTION TEST 2-7/8"X 5"VBR'S,7"FIXED BORE RAMS AND ANNULAR ELEMENT ON FIRST STAND OF DP, GOOD TEST. 18:30 - 19:00 0.50 DRILL P INTI RIG SERVICE. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 35 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(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 INTI RIH WITH 8-1/2"INTERMEDIATE DRILLING BHA#4 RIH F/3,404'T/6,533' SPR @ 5,840'MD,5,592'TVD,9.5 PPG LSND AT 01:00 HRS 1-MP#1 30 SPM,230 PSI,40 SPM,310 PSI -MP#2 30 SPM,230 PSI,40 SPM,300 PSI 21:30 - 00:00 2.50 DRILL P INTI TIE IN LOG WITH NEW LWD TOOL -LOG F/6,536'T/6,700'WITH NEW LWD. -575 GPM,2520 PSI. PU 165K,SO 150K. -WEIGHT UP F/9.5 PPG T/9.7 PPG,CBU 2X'S. -OBTAIN BENCHMARK ECD'S WITH NEW MW. 12/5/2014 00:00 - 12:00 12.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE -F/6,700'T/7,673'MD,TVD 6,709' -575 GPM,3020 PSI ON,2980 PSI OFF. -120 RPM,5-7K TQ ON,3-4K TQ OFF. -PU 174K,SO 147K,ROT 157K,WOB 15K. -ECD ACTUAL 10.83 PPG,CALC 10.35 PPG. -SURVEY EVERY 90'. -ACTUAL ROTATE TIME 6.28 HRS. -ACTUAL SLIDE TIME 0.0 HRS. JAR HRS 28.08 HRS. -BACKREAM 90',WHEN ECD INCREASED BY 0.5 PPG -MW 9.9 PPG IN,9.9 PPG OUT. SPR @ 6,703'MD,6,249'TVD,9.7 PPG LSND AT 00:01 HRS -MP#1 30 SPM,200 PSI,40 SPM,280 PSI -MP#2 30 SPM,200 PSI,40 SPM,280 PSI SPR @ 6,916'MD,6,371'TVD,9.9 PPG LSND AT 01:00 HRS -MP#1 30 SPM,250 PSI,40 SPM,340 PSI -MP#2 30 SPM,240 PSI,40 SPM,340 PSI SPR @ 7,376'MD,6,573'TVD,9.9 PPG LSND AT 07:45 HRS -MP#1 30 SPM,300 PSI,40 SPM,400 PSI -MP#2 30 SPM,300 PSI,40 SPM,400 PSI •0 BBLS 9.9 PPG LSND FLUID LOST DURING TOUR. 220 BBLS WATER ADDED TO SYSTEM. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 36 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 23:00 11.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE -F/7,673"T/8,530'MD,TVD 7,288' - 550 GPM,3340 PSI ON,3300 PSI OFF. - 120 RPM,5K TQ ON,4K TO OFF. -PU 190K,SO 160K,ROT 167K,WOB 15K. -ECD ACTUAL 11.24 PPG,CALC 10.72 PPG. -SURVEY EVERY 90'. ACTUAL ROTATE TIME 7.95 HRS. -ACTUAL SLIDE TIME 0.0 HRS. -JARS 36 HRS. -NO BACKREAMING -WEIGHT MUD SYSTEM TO 10.3 PPG PRIOR TO PENETRATING CM1 -MW 10.3 PPG IN,10.3 PPG OUT. SPR @ 7,767'MD,6,760'TVD,9.9 PPG LSND AT 12:45 HRS -MP#1 30 SPM,310 PSI,40 SPM,420 PSI -MP#2 30 SPM,310 PSI,40 SPM,420 PSI SPR @ 8,337'MD,7,139'TVD,10.3 PPG LSND 1AT19:57HRS -MP#1 30 SPM,390 PSI,40 SPM,520 PSI -MP#2 30 SPM,390 PSI,40 SPM,520 PSI *0 BBLS 9.9 PPG LSND FLUID LOST DURING TOUR. — F— *220 BBLS WATER ADDED TO SYSTEM. 23:00 - 00:00 1.00 DRILL N SFAL 8,530.00 ' INT1 CBU 1X'S -300 GPM,1200 PSI -REPAIR SWAB AND LINER ON MUD PUMP#1 12/6/2014 00:00 - 01:00 1.00 DRILL N SFAL 8,530.00 INTI CBU 1X'S -300 GPM,1200 PSI REPAIR SWAB AND LINER ON MUD PUMP#1 01:00 - 12:00 11.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE -Fl 8,530'T/9,560'MD,TVD 8,100'. -550 GPM,3600 PSI ON,3550 PSI OFF. -120 RPM,7K TQ ON,5K TQ OFF. -PU 220K,SO 168K,ROT 170K,WOB 10K. -ECD ACTUAL 11.26 PPG,CALC 10.84 PPG. -SURVEY EVERY 93'. -ACTUAL ROTATE TIME 8.47 HRS. -ACTUAL SLIDE TIME 0 HRS. -JARS 42.75 HRS. -MW 10.3 PPG IN,10.5 PPG OUT. *0 BBLS FLUID LOST DURING TOUR. *OBTAIN SPR'S. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 37 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code • NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 00:00 12.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE F/9,560'T/10,331'MD,TVD 8,709'. 547 GPM,3770 PSI ON,3740 PSI OFF. -120 RPM,7-8K TQ ON,7K TQ OFF. -PU 226K,SO 173K,ROT 189K,WOB 6-9K. -ECD ACTUAL 11.16 PPG,CALC 10.65 PPG. SURVEY EVERY-90'. ACTUAL ROTATE TIME 6.75 HRS. -ACTUAL SLIDE TIME 0 HRS. -JARS 51.25 HRS. MW 10.3 PPG IN,10.3+PPG OUT. *0 BBLS FLUID LOST DURING TOUR. •OBTAIN SPR'S. `PUMPED SWEEP AT 10,100',25%INCREASE IN CUTTINGS 12/7/2014 0000 - 03:00 3.00 DRILL P • INTI DRILL 8-1/2"INTERMEDIATE -F/10,331 T/10,561'MD,TVD 8,883'. - 550 GPM, 3800 PSI ON, 3700 PSI OFF. - 120 RPM,8K TQ ON,5.5K TQ OFF. -PU 255K,SO 165K,ROT 185K,WOB 12K. •-ECD ACTUAL 11.22 PPG,CALC 10.7 PPG. -SURVEY EVERY 90' -ACTUAL ROTATE TIME 2.3 HRS. -ACTUAL SLIDE TIME 0 HRS. -JARS 55.13 HRS. -MW 10.3 PPG IN, 10.4 PPG OUT. •OBSERVE REVERSE DRILLING BREAK AT 10,554'MD. OBSERVE GAMMA RAY SIGNATURE AT 10,561'MD. 03:00 - 04:00 1.00 DRILL P INTI CBU X 1 -550 GPM,3800 PSI. -60 RPM,7K TORQUE. -SLOW PUMPS TO 400 GPM ON DOWN STROKE. -RECIPROCATE PIPE 30'. •OBSERVE GLAUCONITE IN SAMPLES AT BUS. 04:30 - 07:30 3.50 DRILL P INTI CBU 2X -L/D TWO SINGLES TO INCREASE PIPE RECIPROCATION. -550 GPM,3715 PSI. -75 RPM,7K TORQUE. -SLOW PUMPS TO 400 GPM ON DOWN STROKE. -RECIPROCATE PIPE 90'. 07.:30 - 10:30 3.00 DRILL P INTI PUMP OUT OF HOLE. -MONITOR WELL FOR 10 MINUTES,STATIC. -PICK UP 2 SINGLES OF DRILL PIPE. -PUMP OUT OF HOLE F/10,561'T/8,719'. -85 GPM,300 PSI. -PU 250 K,SO 167K. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 38 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor.DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual 83.38usft(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 DRILL P INTI POOH ON ELEVATORS. ;-BLOW DOWN TOP DRIVE. -POOH ON ELEVATORS F/8,719'T/7,105'. -TIGHT HOLE ENCOUNTERED AT 8,435', 8,245',7,770'AND 7,200'. -WORKED DRILL STRING THOUGH TIGHT AREAS TWO TIMES. *0 BBLS FLUID LOST DURING TOUR. '`OBTAIN SPR'S. 12:00 - 13:30 1.50 DRILL P INTI POOH ON ELEVATORS. POOH ON ELEVATORS F/7,105'T/5,967'. -PU 175K,SO 140K. I-TIGHT HOLE ENCOUNTERED AT 6,240'AND 6,160'W/25-30K OVERKILL. *SPILL DRILL HELD-RESPONSE TIME 1:40. 13:30 - 15:30 2.00 DRILL P INTI SLIP AND CUT DRILL LINE. -PJSM. INSTALL 4"FOSV 1 JOINT BELOW. -SERVICE RIG. -SLIP AND CUT 59'OF DRILLING LINE. I � REVIEW WELL BORE FLUID MONITORING SOP 6.5. 15:30 - 19:30 4.00 DRILL P INT' RIH WITH 8-1/2"DRILLING BHA. -CALIBRATE BLOCK HEIGHT WITH RIG AND SLB. -RIH F/5,967'T/9,619'MD. -BREAK CIRCULATION EVERY 1000'MD 168 GPM,780 PSI. Printed 1/6/2015 5:05:21PM North America ALASKA-BP Page 39 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 00:00 4.50 DRILL N STUC 9,619.00 INTI WORK DRILL STRING AND CIRCULATE. -OBSERVE STRING TAKING WEIGHT AT 9,504' PU TO 9,479'AND M/U TD. -M/U TD AND WASH DOWN 168 GPM,800 PSI T/9,574'. -PU WT 225K,SO WT 155K. -STAGE PUMP UP WHILE WASHING DOWN, 168 GPM-850 PSI,294 GPM-1630 PSI,420 GPM-2450. OBSERVE STRING TAKING WEIGHT(25K),AT 9,620'MD. 10.7 PPG MW OUT,OBSERVED IN PITS,32 BBLS LOST OVER SHAKERS,REDUCE PUMP RATE TO SAVE MUD. -OBSERVE PACK OFF WHILE RECIPROCATING PIPE,PRESSURE INCREASED TO 2750 PSI. -S/O WITH STRING AND REDUCE PUMP RATE TO 70 GPM,PRESSURE DROPPED TO 2040 PSI. UNABLE TO PICK UP OR SLACK OFF,BUT STILL ABLE TO PUMP AT 70 GPM. WORK DRILL STRING SEVERAL TIMES,AS FOLLOWS' ' SO TO 125K,PU TO 250K,SO TO 100K,PU TO 250K,SO TO 100K,PU TO 275K. -PSI DECREASED TO 70 GPM,1920 PSI,STILL UNABLE TO MOVE STRING. -MW IN ACTIVE SYSTEM INCREASED TO 10.7 PPG WHILE CIRCULATING. -SHUT DOWN PUMPS TO CONDITION SURFACE SYSTEM TO WELL PLAN PARAMETERS. -WORK STRING WITHOUT PUMPS FOR 30 MINUTES,WHILE TREATING SURFACE SYSTEM. -BRING PUMP ON,84 GPM 230 PSI. -SLOWLY STAGE UP PUMP 126 GPM-370 PSI,168 GPM-600 PSI,189 GPM-750 PSI, 210 GPM- 890 PSI,231 GPM-1020 PSI,250 GPM-1150 PSI. -PLACE 14K RIGHT HANDED TORQUE IN DRILL STRING AND WORK TO BOTTOM. -SLOW PUMPS FROM 250 GPM TO 84 GPM WHILE ATTEMPTING TO FREE PIPE. -WORK TORQUE DOWN SEVERAL TIMES,PU 260K,SO 125K.,UNABLE TO FREE PIPE. -SHUT PUMPS OFF WHILE ATTEMPTING TO FREE PIPE. -WORK TORQUE DOWN SEVERAL TIMES,PU 260K,SO 125K.,PIPE CAME FREE AT 23:03. -RECIPROCATE PIPE WITH 40 RPM,STAGE PUMPS UP 126 GPM-370 PSI AND 168 GPM- 710 PSI. -WORK STAND F/9,669'T/9,574',30 RPM,5-6K TQ. *INFORMED ODE AND DRLG SUPT.OF PACK OFF AND DEVELOPED PLAN FORWARD ONCE FREEING PIPE. *32 BBLS FLUID LOST OVER SHAKERS DURING TOUR. 40 BBLS WATER ADDED TO SYSTEM. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 40 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/8/2014 00:00 - 05:30 5.50 DRILL P INTI WASH AND REAM -F/9,669'T/10,235. -STAGE PUMPS UP FROM 84 GPM 430 PSI, TO 256 GPM 1070 PSI. -40-50 RPM,8-12K TQ. -BRING NEW 10.3 PPG MUD INTO PITS AND BLEED INTO ACTIVE SYSTEM AT 10,045. 05:30 - 12:00 6.50 DRILL P INTI WASH AND REAM -F/10,235 T/10,428'. -EXPERIENCE PACK OFF AT 10,260'. WORK TO FREE PIPE,MAX PU 265K,MAX SO 100K. -WORK RIGHT HANDED TORQUE TO BIT TO FREE PIPE. STAGE PUMPS UP FROM 42 GPM 430 PSI, TO 262 GPM 1300 PSI. -60-110 RPM,8-9K TQ,ROT WT 187K. 0 BBLS FLUID LOST DURING TOUR. 12:00 - 15:00 3.00 DRILL P INTI WASH AND REAM F/10,428'T/10,561'. -EXPERIENCE PACK OFF AT 10,523'. -WORK RIGHT HANDED TQ TO BIT TO FREE PIPE. -MAX PU 263K,MAX SO 190K.. -STAGE PUMPS UP FROM 200 GPM 940 PSI, TO 448 GPM 2600 PSI. -60-120 RPM,7-9K TQ,ROT WT 190K. 15:00 17:00 2.00 DRILL P INTI CIRCULATE AND CONDITION -CBU 3X'S -550 GPM,3510 PSI. 120 RPM,7-8K TORQUE. -RECIPROCATE PIPE 90'AT 4 FT/MIN. -OBSERVE SHALE,VERY FINE SHALE,AND SILT AT BUS,NO SIGNIFICANT AMOUNT OF SPLINTERS. ONE SMALL SPLINTER OBSERVED PER HANDFUL OF SHALE. COMMUNICATE WITH ODE,ANCHORAGE GEO,AND ETL. INCREASE MW TO 10.7 PPG. 17:00 - 21:00 4.00 DRILL P INTI CIRCULATE AND CONDITION -INCREASE MW FROM 10.3 PPG TO 10.7 PPG. -550 GPM,3420-3560 PSI. -120 RPM,7-8K TORQUE. -RECIPROCATE PIPE 90'AT 4 FT/MIN. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 41 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) . Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 00:00 3.00 DRILL P INTI PUMP OUT OF HOLE. -PJSM FOR PUMPING OUT OF HOLE, DISCUSS WATCHING HANDS AND FINGERS AROUND MUD BUCKET. NORMALLY USE A KATCH KAN. TAKE TIME TO DO IT SAFELY WORKING WITH NEW PIECE OF EQUIPMENT. -MONITOR WELL FOR 10 MINUTES,STATIC. PUMP OUT OF HOLE F/10,561'T/8,625'. -120 GPM,370 PSI. PU 205 K,SO 140K,AT 8,625'. OBSERVED 20-25K OVERPULLAT 10,330', 10,000', 9,435'.. OBSERVE 45K OVERPULLAT 9,288',RIH AND ' WORK STAND THROUGH TIGHT SPOTS. ' *GET SPR'SAT 10,536'. *ZERO LOSSES FOR TOUR. 2.00 DRILL INTI POOH ON ELEVATORS. P i 12/9/2014 00:00 - 02:00 i -MONITOR WELL FOR 10 MINUTES,STATIC. -BLOW DOWN TOP DRIVE. -POOH ON ELEVATORS F/8,625 T/6,915. -OVERPULL INCREASED FROM 20K TO 25-35K,PIPE PULLED DRY WITH STRING AT 1 6,916'. -MONITOR WELL FOR 5 MINUTES,STATIC. 02:00 - 02:30 0.50 DRILL PINTI RIH. -RIH F/6,916'T/7,390'. -RIH 5 STANDS ON ELEVATORS DUE TO LAST TWO STANDS PULLING DRY. -ABLE TO GET TO 7,390'WITHOUT WASHING DOWN. 02:30 - 03:30 1.00 DRILL P INTI CIRCULATE BOTTOM UP. -M/U TOP DRIVE. -STAGE PUMPS UP 126 GPM,350 PSI TO 500 GPM,2950 PSI. -60-120 RPM,3-5K TQ. -PU 175K,SO 145K,ROT 165K. -OBSERVE APPROXIMATELY 10 BBLS OF 10.9 PPG MUD IN RETURNS AT BUS. -OBSERVE 85%FINELY GROUND KINGAK, AND 15%SILT IN RETURNS AT BUS. -SHAKERS CLEANED 30 BBLS AFTER BUS, SHUT DOWN PUMPS. -MONITOR WELL FOR 10 MINUTES,STATIC 03:30 - 04:00 0.50 DRILL P INTI PUMP OUT OF HOLE. -PUMP OUT OF HOLE F/7,390'T/6,916' -ATTEMPT TO POOH ON ELEVATORS, OBSERVE 20-30K OVERPULL. -PUMP 5 STANDS OUT OF THE HOLE 126 GPM,350 PSI. 04:00 - 05:00 1.00 DRILL P INTI 'POOH TO WINDOW. -MONITOR WELL FOR 10 MINUTES,STATIC. -MW 10.7 PPG IN,10.7 PPG OUT. -PULL OUT ON ELEVATORS F/6,919'T/5,967'. PU 175K,S0 145K. 05:00 - 05:30 0.50 DRILL P INTI SERVICE RIG. -SERVICE DRAW WORKS, TOP DRIVE, BLOCKS,CROWN&ST-80. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 42 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 08:00 2.50 DRILL P INTI RIH ON ELEVATORS. -PJSM AND REVIEW DDI SOP FOR TRIPPING PIPE. -MONITOR WELL FOR 10 MINUTES,STATIC. -RIH F/5,967'T/10,428'MD. FILLING PIPE EVERY 2,000'. MAKE UP TOP DRIVE AND WASH F/10,428'T/ TD AT 10,561'MD. MONITORED TRIP IN THE HOLE ON THE TRIP TANK-HOLE DISPLACEMENT CORRECT. -NO LOSSES TO FORMATION OBSERVED ON THE TRIP IN. 08:00 - 11:00 3.00 DRILL P i INTI CIRCULATE AND CONDITION. -STAGE PUMPS UP TO 500 GPM,WITH 3300 PSI AND 120 RPM'S. -PU 250K,SO 185K,ROT 195K,7-8K TQ. MW 10.7 PPG IN/OUT. SPOT 40 BBLS OF 40 PPB DRILLAHEAD PILL AT BIT. -MONITOR WELL PRIOR TO PULLING OFF BOTTOM-WELL STATIC. 11:70 - 14:00 3.00 DRILL P INTI PUMP OUT OF HOLE. PJSM FOR PUMPING OUT OF HOLE. MONITOR WELL FOR 10 MINUTES,STATIC. -SPOT 40 BBLS OF 40 PPB DRILL AHEAD PILL ON BOTTOM AT 2 BPM W/250 PSI.WHILE PULLING F/10,561'T/10,468'. -PUMP REMAINING DRILLAHEAD PILL BEFORE MAKING CONNECTION AT 10,468'AT 2 BPM W/250 PSI. CONTINUE PUMPING OUT OF HOLE F/ 10,468'T/10,427'. -LAY DOWN ONE SINGLE AND 10'PUP JOINT USED TO RECIPROCATE FULL STAND ON BOTTOM. I-PUMP OUT OF HOLE F/10,427'T/8,625'. -126 GPM,320 PSI. -PU 175 K,SO 135K,AT 8,625'. *OBSERVED 10K TO 20K OVERPULLS AT 10,392',10,362',10,322',10,015',AND 9,589". *OVERPULL OBSERVED AT 9,370'OVER 20K, WIPED AND OBSERVED 5K OVER ON UP STROKE AFTER WIPING. 14:00 - 15:30 1.50 DRILL P INTI POOH ON ELEVATORS. -MONITOR WELL FOR 10 MINUTES,STATIC. -BLOW DOWN TOP DRIVE AND LINE UP TRIP TANK. -POOH ON ELEVATORS F/8,625'T/7,011'. -PU 165K,SO 135K. -OBSERVED OVERPULL OF 25K TO 30K OVERPULL AT 6,900'AND 7,475'WIPED BOTH SPOTS CLEAN WITH 5K OVERPULL ON BOTH SPOTS HAD NO INDICATION ON DOWN STROKE OBSERVED. -PIPE CAME DRY AT 7,011',RUN BACK INTO HOLE FROM F/7,011'T/7,295'. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 43 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 16:00 0.50 DRILL P INTI CIRCULATE BOTTOMS UP. -M/U TOP DRIVE. -STAGE PUMPS UP 126 GPM,450 PSI TO 500 GPM,2730 PSI. -120 RPM,3-5K TQ. CBU WHILE RECIPROCATING AND ROTATING F/7,295'T/7,200'UNTIL SHAKERS CLEAN. SILT OBSERVED AT BOTTOMS UP. 16:00 - 20:00 4.00 DRILL P INTI POOH ON ELEVATORS. -BLOW DOWN TOP DRIVE AND LINE UP TRIP TANK. -POOH ON ELEVATORS F/7,295'T/5,967'. -PU 155K,S0 125K AT 5,967'. M/U TOP DRIVE. -PUMP DRY JOB AND LINE UP TRIP TANK. -POOH ON ELEVATORS F/5,967'T/555'. -MONITOR TRIP VIA THE TRIP TANK WELL TAKING CALCULATED PIPE DISPLACEMENT VOLUME 20:00 - 22:00 2.00 DRILL P INTI LAY DOWN 8-1/2"BHA.#4 -PJSM,REVIEW DDI SOP ON LAYING DOWN BHA. -DISCUSS DROPS AND IDENTIFY EXCLUSION ZONES. -LAY DOWN BHA,5"HWDP,JARS,NM FLEX COLLARS,LWD,MWD,RSS AND BIT. - BIT GRADE 1-1-BT-X-I-CT-TD -BIT AND STABILIZERS ALL IN GAUGE 22:00 00:00 2.00 CASING P INTI CLEAN AND SERVICE RIG. -RECALIBRATE MWD BLOCK HEIGHT. -CLEAN BIT FOR GRADING. -CLEAN RIG FLOOR OF ALL TOOLS NOT NEEDED. -BRING CASING TOOLS TO RIG FLOOR. 12/10/2014 00:00 - 02:30 2.50 CASING P INTI RIG UP TO RIH W/7"26#L-80 HYDRIL 563 INTERMEDIATE LINER. -PJSM WITH DDI CSG HAND&DDI PERSONNEL. -BEAVER SLIDE OPERATIONS. -P/U&R/U HYDRAULIC CASING TONGS AND HANDLING EQUIPMENT. -M/U FLOOR SAFETY VALVE WITH PROPER CROSSOVER AND ASSEMBLE SAFETY JOINT WITH 7"LIFTER. RIG UP FILL LINE. 02:30 - 03:00 0.50 CASING P INTI PRE JOB SAFETY MEETING TO RIH. -PJSM W/BAKER REP,DDI CSG REP AND DDI PERSONNEL TO RIH. -REVIEW NON SHEARABLES ACROSS THE STACK AND CONTINGENCY PLAN. -ENSURE PROPER XO TO 7"CASING IS MADE UP TO A FULL OPEN SAFETY VALVE. -REVIEW DROPPED OBJECTS AND PROPER USE OF EXCLUSION ZONES. 03:00 - 06:00 3.00 CASING P INTI RIH W/7"26#L-80 HYDRIL 563 F/SURFACE T/ 1,900' - MAKE UP AND BAKERLOK SHOE TRACK -RIH WITH 3 JT'S 7",26# VTHC LINER TO 128' MD,CHECK FLOATS-GOOD -PULL OUT OF HOLE 80'&RUN BACK IN TO VERIFY FLOATS PROPER FUNCTION. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 44 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 06:30 0.50 CASING P INTI KICK WHILE TRIPPNG DRILL WHILE RUNNING CASING DRILL. -MADE UP 7"CASING XO WITH TIW AND SIMULATED SHUTTING IN THE WELL. -AFTER ACTION REVIEW. 06:30 - 12:00 5.50 CASING I P INTI RIH W/7"26#L-80 HYDRIL 563 F/1,900'T/ 4,699' -USING JET LUBE SEAL GUARD THREAD COMPOUND -FILL EVERY 10 JOINTS. -TORQUE TURN ALL CONNECTIONS TO 9,880 FT-LBS. -TOTAL OF 44 CENTRALIZERS RAN,3 ON SHOE TRACK AND 41 FREE FLOATING 7-1/8"B 8-1/4"SPLIT RIB HYDROFORM ON 7"LINER. -RUN IN THE HOLE 60 FT/MIN FROM 0,TO 4,699' -MAKE UP BAKER PACKER HRD-EZXPN LTP: BAKER REP MIXED AND POURED PAL MIX VERIFY CORRECT SET SCREWS FOR SETTING HANGER AND LTP CONTINUE RIH R/4,699'T/5,933'.ON 4"DP STANDS FROM THE DERRICK '-DRILLER AND MOTOR MAN TO VERIFY CORRECT ELEVATOR SIZE PRIOR TO RUNNING IN THE HOLE ON DP 12:00 - 13:00 1.00 CASING ' P INTI CIRCULATE BOTTOMS UP. -STAGE PUMPS UP. I -126 GPM THEN 294 GPM. AFTER PSI STABALIZED RETURNS STARTED TO DECREASE. *10 BBLS LOSS DETECTED.-SHUT DOWN PUMPS. *MUD WEIGHT 10.7 PPG IN AND 10.7 PPG OUT -PUW=160K,SOW=152K WITH PUMPS ON. -PUW=175K,SOW=165K WITH PUMPS OFF. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 45 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual j83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 21:00 8.00 CASING P INTI RIH W/7"26#L-80 HYDRIL 563 F/5,933'TO 10,559'MD -RIH ON 4"DP STANDS FROM THE DERRICK -BREAK CIRCULATION EVERY 500'AT 126 GPM FOR 5 MINS. OBTAIN PUW&SOWS EVERY 500'UNTIL 8,402'MD. RIH AT 60 FT/MIN AS PER PROGRAM FROM SURF TO THE WINDOW,REDUCED SPEED FROM 60 FT/MIN AT 9 5/8" WINDOW,RIH AT 20 FT/MIN FROM WINDOWN TO THE SHOE PUW=200K,SOW=163K AT 7,927'. -MONITORING TRIP ON TRIP TANK-PUSHING FLUIDAWAY-ESTIMATED 17-25 BPH LOSING CIRCULATE ABOVE THE WINDOWN AT 84 GPM,200 PSI AT 6,503'-NO RETURNS. PUW=187K, SOW=165KAT 6,978'. -126 GPM,300 PSI-NO RETURNS. -PUW=197K,SOW=162K AT 7,453'. 126 GPM,400 PSI.-10%RETURNS. PUW=197K,SOW=162K AT 7,927'. 126 GPM,420 PSI. -PUW=200K,SOW=163KAT WASH DOWN FROM 8,402'MD TO 8,687'MD. PICK UP 15'PUP AND 2 SINGLE OF 4"DRILL PIPE. RIH F/10,490'MD TO 10,561'MD(ON DEPTH) -ROTATE CEMENT HEAD AND HOOK UP CIRCULATION LINES. -RIG UP SNUB LINE FOR SWIVEL AND MAKE UP TO TOP DRIVE. WASH DOWN LAST 30'TO BOTTOM FROM -RIH 84 GPM,400 PSI TO FILL PIPE,SLOW PUMP RATE TO 21 GPM,390 PSI. 24 HR NOTIFICATION GIVEN TO THE STATE AT 19:45 VIA WEB SITE NOTIFICATION. -CONFIRM TAG ON BOTTOM AT 10,561'MD WITH 15K DOWN X 2,-PRESSURE INCREASED TO 580 PSI. - PICK UP TO 215K(LAST PUW ABOVE THE HRZ)PLUS TWO FEET -LINER SET SET AT 10,559'AS PER THE TALLY- -LTP AT 5,870'MD MUD WEIGHT 10.7 PPG IN,10.7 PPG OUT. *TOTAL MUD LOSSES WHILE CIRCULATING& RIH=215 BBLS. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 46 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 00:00 3.00 CASING P INTI CIRCULATE AND CONDITION MUD FOR CEMENT OPERATIONS. --WORK PIPE STRETCH WITHOUT MOVING SHOE OUT OF THE SAG. 1-ESTABLISH CIRCULATION. -29 GPM W/360 PSI. -42 GPM W/360 PSI. -66 GPM W/450 PSI. -84 GPM W/480 PSI. -105 GPM W/540 PSI-DLR 48 BBLS PER !HOUR -126 GPM W/580 PSI. 1-147 GPM W1680PSI. -168 GPM W/700 PSI. -189 GPM W/770 PSI. -210 GPM W/830 PSI-DLR 70 BBLS PER HOUR. -231 GPM W/930 PSI. `AT 340 BBLS TOTAL PUMPED DLR REDUCED TO ZERO BPH. TOTAL OF X 2.5 BOTTOMS UP CIRCULATED PRIOR TO MIDNIGHT. TOTAL LOSSES WHILE CIRCULATING AND 'CONDITIONING-160 BBLS TOTAL FOR TOWER 375 BBLS. -R/U SLB CEMENTERS. 12/11/2014 00:00 - 02:00 2.00 CASING P INTI CIRCULATE AND CONDITION MUD FOR CEMENT OPERATIONS. -ESTABLISH CIRCULATION. -CIRCULATE 214 GPM W/ICP 730 PSI. -FCP- 690 *TOTAL OF 4.5 BOTTOMS UP CIRCULATED PRIOR TO CEMENT JOB. -WORK PIPE STRETCH WITHOUT MOVING SHOE OUT OF THE SAG. -LOWER RHEOLOGY-YP-18,MW-10.6 IN PPG,10.8 PPG OUT SHUT DOWN PUMPS AND MONITOR WELL BORE. -WELL SLIGHTLY FLOWING AFTER NORMAL 10 BBL FLOW BACK. -SHUT IN WELL WITH ANNULAR PREVENTER TO MONITOR PRESSURES. -TOTAL LOSS DURING CIRCULATION-160 BBLS. SIM OPS-R/U SLB CEMENTERS. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 47 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release: 12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 06:00 4.00 CASING N DPRB INTI MAKE NOTIFICATIONS FOR WELL SHUT IN AS I PER BP FLOW CHART. MONITOR WELLBORE: *PSI IN CHOKE AT 30,PSI ON DRILL PIPE 30. 1-1/2 BBL GAIN TO PITS. -MONITOR WELL:WITH DELEGATED RIG PERSON TAKING DP&IA-PRESSURE I READINGS EVERY MIN. ESTABLISH PLAN WITH ROTARY SUPT AND ROTARY TL FOR SUSPECTED WELLBORE ' I BREATHING. -REVIEW BP SOP FOR WELLBORE ' BREATHING AND AGREE ON PLAN TO CONFIRM SUSPECTED WELLBORE BREATHING.-BLEED BACK AGREED NUMBER OF BARRELS THROUGH CHOKE TO TRIP TANK WHILE MONITORING AND RECORDING. -FIRST BARREL 13 MIN 20 SEC. -SECOND BARREL 33 MIN 40 SEC. -NEXT 1/4 BARREL 58 MINS.-CONFIRMED • WELLBORE BEATHING EVENT. APPROVED BY WELL OPS MANAGER TO OPEN ANNULAR PREVENTER AND START I 'CIRCULATION FOR CEMENT JOB. 06:00 - 09:00 3.00 CASING P INTI CIRCULATE AND CONDITION MUD FOR CEMENT OPERATIONS. -STAGE PUMPS UP IN.5 BBLS INCREMENTS. -ESTABLISH CIRCULATION. ' -CIRCULATE.5 BPM W/ICP 730 PSI. -FCP- 240 PSI AFTER 5 BBLS PUMPED. -STAGE PUMPS UP TO 5 BPM-FCP-640 PSI. -CBUX1. • 09:00 - 10:30 1.50 1 CASING P ? INT1 CEMENT 7"INT LINER -OBTAIN APPROVAL FROM TOWN TO PROCEED WITH CEMENT JOB WITH 7"LINER SHOE AT 10,559'. ' -PJSM WITH DOYON CREW,BP, SCHLUMBERGER PRIOR TO CEMENT JOB. REVIEWED CEMENTING PRESSURE CROSS • CHECK LIST. -PRESSURE TEST HARD LINES WITH FRESH WATER-250 PSI LOW AND 4500 HIGH. -5 CHARTED MINUTES EACH.GOOD LEAK TIGHT TEST. -SET AND VERIFY TRIP SETS FUNCTION PROPERLY DURING PRESSURE TEST-WSL WITNESS TRIP SETS FUNCTION AT 1000 PSI AND 4000 PSI. -BLOW DOWN CEMENT LINE BACK TO SLB. -SET TRIP SETS ON PUMP AT 2000 PSI. -LINE UP AND CIRCULATE THROUGH CEMENT HEAD WHILE SLB BATCH MIX. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 48 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UW:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 12:30 2.00 CASING P INTI CEMENT 7"INT LINER -PUMP FROM CEMENTERS: -30 BBL 12.0 PPG MUD PUSH W/1.5 PPB CEMNET. -55.2 BBL 15.8 PPG CEMENT W/1'5 PPB CEMNET. -DROP DP WIPER DART. -SLB PUMP 10 BBL WATER,CONFIRM TATTLE TAIL INDICATOR ON CEMENT HEAD DART RELEASED. -DISPLACE WITH RIG: -SWAP TO RIG PUMP FOR DISPLACEMENT. -FOLLOW CEMCADE PUMP SCHEDULE. -OBSERVED DP WIPER DART LATCH LWP AT 47.4 BBL. ✓ -BUMP PLUG WITH 222 BBL -3 BBL LOST AFTER CMT EXIT SHOE. -CIP:12:17 12:30 - 14:00 1.50 CASING P INTI SET LINER HAND AND LINER TOP PACKER. -SET HANGER WITH 4,340-PSI. S/O TO SET HANGER WITH 50K DOWN. CHECK FLOAT EQUIPMENT:NO FLOW. P/U TO EXPOSE DOGS. -S/O TO ZXP PACKER WITH 60K DOWN. 14:00 - 19:30 5.50 CASING P INTI POOH WITH LINER RUNNING TOOL F/5,870' TO SURFACE. -MONITOR WELL FOR 10 MIN:STATIC. -B/D TOP DRIVE. -POOH STANDING BACK 4"DP IN DERRICK. -UD RUNNING TOOL. MONITOR WELL VIA TRIP TANK. -SERVICE BREAK LINER RUNNING TOOL. -CLEAN AND CLEAR RIG FLOOR. -REMOVE WEAR RING AND INSTALL TEST PLUG. 19:30 - 23:00 3.50 BOPSUR P INTI CHANGE OUT UPPER RAMS TO 3-1/2"X 6" VBRS. REMOVE 7"FIXED RAMS. INSTALL 3-1/2"X 6"VBRS. 23:00 - 00:00 1.00 BOPSUR P INTI TEST BOPE EQUIPMENT -TEST BOPE TO 250 PSI LOW,3,500 PSI HIGH FOR 5 CHARTED MINUTES EACH. -CONDUCT SHELL TEST WITH 4"TEST JOINT. -TEST 5"FOSV. -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHART. -TEST WAIVED BY AOGCC REP MATT HERRERA. HELD WELL KILL DRILL WITH CRT OF 02:45. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 49 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/12/2014 00:00 - 06:00 6.00 BOPSUR P INTI CONT TEST BOPE EQUIPMENT -TEST BOPE TO 250 PSI LOW,3,500 PSI HIGH FOR 5 CHARTED MINUTES EACH. -TEST WITH 2-7/8",4"&4-1/2"TEST JOINTS. -TEST ANNULAR PREVENTER WITH 2-7/8" TEST JOINT. -PERFORM ACCUMULATOR DRAW DOWN TEST. -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHART. TEST WAIVED BYAOGCC REP MATT HERRERA. 24 HOURS OF NOTIFICATION GIVEN TO THE STATE PRIOR TO TEST 06:00 - 08:00 2.00 BOPSUR P INTI 'TEST ANNULAR PREVENTOR ON BOPE. -RIG UP 2-7/8"TEST JOINT. -TEST ANNULAR PREVENTOR 250 PSI LOW- GOOD. TEST 3500 PSI HIGH-NO PASS,LEAK PSI BY 3200. -FUNCTION ANNULAR PREVENTOR AND RETEST. -STILL LEAKING PSI ON HIGH TEST AT 3200 PSI. -TEST BLINDS,CHOKE VALVES AND MANUEL DRAW DOWN CHOKE AND HYDRALIC DRAW DOWN. -TEST BOTTOM RAMS WITH 2-7/8"X 5" VARIABLE RAMS WITH 2-7/8"TEST JOINT. 08-00 - 18:00 10.00 BOPSUR N RREP ' INTI CHANGE OUT ANNULAR PREVENTOR ELEMENT. PJSM W/DDI PERSONNEL. -AGREE ON PLAN FORWARD FOR CHANGING OUT ANNULAR ELEMENT WITH OPS SUPT. AND WTL. -INSTALL FILL LINE ON IA WITH DOUBLE CHECK VALVE CONFIGURATION WITH CIRCULATION ACROSS THE TOP OF WELLBORE ISOLATED TO PIT#3.(PRIMARY BARRIER) -PULL TEST PLUG. -SHUT TESTED BLIND SHEAR RAMS. (SECONDARY BARRIER) -RIG DOWN CROSSOVERS USED FOR TESTING AND FOSVS. -PULL FLOW LINE,PITCHER NIPPLE AND ADAPTER FLANGE OFF ANNULAR PREVENTOR. -VERIFY MUD WEIGHTS EVERY 30 MINS. -REMOVE OLD ANNULAR. -INSTALL NEWANNULAR. INSTALL ADAPTER FLANGE PITCHER NIPPLE AND FLOW LINE. 'IR4886770 FOR FAILED ANNULAR ELEMENT. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 50 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 20:30 2.50 BOPSUR P INTI TEST ANNULAR PREVENTOR. -FLOW CHECK 10 MINS-WELL STATIC. '-OPEN BLIND SHEAR RAMS. -INSTALL TEST PLUG. -TEST ANNULAR PREVENTOR WITH 2-7/8" TEST JOINT. -TEST AND CHART TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINS EACH-TESTS GOOD. 'WITNESS WAIVED BY AOGCC REP MATT HERRERA. 20:30 - 21:30 1.00 WHSUR P INTI INSTALL WEAR RING. -PULL TEST PLUG. -INSTALL WEAR RING. I D=9-1/4" 21:30 - 23:00 1.50 CASING P INTI PRESSURE TEST 7"X 9-5/8"LTP AND 7" CASING -CEMENT HAS REACHED 500 PSI COMPRESSIVE STRENGTH AT 13:49 HRS ON 12/12/2014. -PJSM FOR TESTING THE LTP AND 7"LINER: REVIEW THE PRESSURE CROSS CHECK CHECKLIST,DISCUSS PROPER LINE UP FOR 'PRESSURE FLOW&VERIFIED. -PT 7"LINER AND LINER LAP TO 250 PSI LOW FOR 5 MINS-GOOD. PT 7"LINER AND LINER LAP TO 3500 PSI HIGH FOR 30 MINS-GOOD. -PUMPED 7.5 BBLS TO REACH PRESSURE AND BLED BACK 7 BBLS. TEST RESULTS SCANNED AND UPLOADED -RECIEVED ATP FROM ROTARY TEAM LEAD- JIM WILLINGHAM -PRESSURE TEST RESULTS MEET BP REQUIREMENTS FOR PASSING CRITERIA 23:00 - 00:00 1.00 CEMT P INTI PICK UP 6-1/8"PRODUCTION ARCHER RSS BHA#5 -HOLD PJSM FOR PICKING UP BHA -PICK UP 4.75"ARCHER BHA W/ IMPULSE AND ADN-4,PER SLB DD MONITOR WELL DISPLACEMENT VIA TT 12/13/2014 00:00 - 02:30 2.50 CASING P INTI PICK UP 6-1/8"PRODUCTION ARCHER RSS BHA#5. -HOLD PJSM FOR PICKING UP BHA. -PICK UP 4.75"ARCHER BHA W/ IMPULSE AND ADN-4,PER SLB DD. -PJSM FOR LOADING SOURCE-REVIEW SLB PROCEDURE FOR RADIOACTIVE SOURCE LOADING. -LOAD R/A SOURCE IN ADN TOOL. -MAKE UP DRILLING BHA TO 182'MD AS DIRECTED BY THE SLB DD. -RIH ON 4"DP F/182'TO 1,610'MD. -SURFACE TEST ARCHER TOOL(SLB PROCEDURE) AT 1610'MD WITH 202 GPM, 950 PSI.-GOOD TEST -MONITOR WELL DISPLACEMENT VIA TT HOLE DISPLACEMENT CORRECT. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 51 of 62 Operation Summary Report Common Well Name.Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 08:00 5.50 CASING P INTI RIH ON 4"XT39 DP FROM THE DERRICK W/ ARCHER BHA FROM 1610'MD TO 2,937'MD. -MW-10.6 PPG LSND IN/OUT. -FILLING PIPE EVERY 15 STANDS AND CIRCULATING AT 240 GPM,1400 PSI.FOR 8 MIN EACH TIME PER SLB SOP FOR RUNNING ARCHER. P/U AND RIH WITH 4"HWDP&4-3/4"JARS FROM 2,937'TO 3,206'MD. CONTINUE RIH F/DERRICK FROM 3,206'MD TO 10,420'MD. -MONITOR WELL DISPLACEMENT VIA TT- HOLE DISPLACEMENT CORRECT. -FILLING PIPE EVERY 15 STANDS WITH 210 GPM,CIRCULATE FOR 8 MIN AT 210 GPM W/ 1276 PSI-PER SLB SOP FOR RUNNING ARCHER. 08:00 - 08:30 0.50 CASING P INTI LOCATE TOC ABOVE 7"INTERMEDIATE LANDING COLLAR. -M/U TOP DRIVE AND OBTAIN PARAMETERS. PUW 225K,SOW 183K. -CIRCULATE AT 200 GPM W/1200 PSI. -WASH DOWN F/10,420'AND TAG TOC AT 10,429'W/10K WOB TWICE. POOH T/10,420'SHUT DOWN PUMPS, BREAK OUT TOP DRIVE AND STAND BACK STAND OF DRILL PIPE. 08:30 - 10:00 1.50 CASING P INTI CIRCULATE WHILE BUILDING SPACER PILL FOR DISPLACEMENT OF 8.5 PPG POWERPRO. -M/U TOP DRIVE AND CBU AT 227 GPM W/ 2027 PSI WITH 10.6 PPG LSND. 10:00 - 13:00 3.00 CASING P INTI DISPLACE WELL TO 8.5 PPG POWERPRO. -PJSM AND REVIEW DDI FLUID MANAGEMENT POLICY WITH PERSONNEL INVOLVED IN DISPLACEMENT. -PUMP 38 BBLS 8.5 PPG 250 VIS SPACER PILL AT 200 GPM W/2130 PSI. -AFTER 151 BBLS PUMPED AND SPACER PILL OUT OF BIT BROUGHT RATE UP TO 265 GPM W/2670 PSI.ICP. -668 BBLS PUMPED AND GOOD 8.5 PPG POWER PRO IN/OUT SHUT DOWN PUMPS WITH A FCP OF 1640 PSI. -MONITOR WELL FOR TEN MINUTES,STATIC. -BREAK OUT AND BLOW DOWN TOP DRIVE. *TABLETOP SPILL DRILL WITH C CREW. 13:00 - 13:30 0.50 CASING P INTI PERFORM NEGATIVE TEST ON 7"LINER LAP. -MONITOR WELL VIA TT AND CONFIRM MANUAL STRAP OF 36.5 BBLS. -AFTER 30 MINS.OF MONITORING WITH NO GAIN CONFIRM MANUAL STRAP OF 36.5 BBLS. *SIMOPS CONDUCT SAFETY MEETING AND REVIEW DDI SOP ON SLIP AND CUTTING DRILLING LINE. *SIMOPS CLEAN PITS OF RESIDUAL 10.6 PPG LSND. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. WWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 15:30 2.00 CASING P INTI SLIP AND CUT DRILLING LINE AS PER SOP. SIMOPS CONTINUE CLEANING PITS TO FILL WITH 8.5 PPG POWERPRO. SIMOPS CONFIRM AT 14:15 HOURS NO GAIN IN TT WITH MANUAL STRAP OF 36.5 BBLS. CONTACT ROTARY WTLAND OBTAIN ATP ON RESULTS OF NEGATIVE TEST RESULTS OF 7"LINER LAP. 15:30 - 16:00 0.50 CASING P INTI RIG SERVICE. -INSPECT AND GREASE ST-80,TOP DRIVE, DRAW WORKS. SIM OPS-CONT.TO CLEAN PITS FOR NEW I MUD. 16.00 21:30 5.50 CASING P INTI WASH AND REAM LANDING COLLAR/SHOE TRACK -TAG CEMENT AT 10,429'MD WASH AND I REAM DOWN I-BY DRILLING TALLY DEPTHS: -TAG INSERT COLLAR ON DEPTH AT 10,474' MD -TAG FLOAT COLLAR ON DEPTH 10,515'MD 1-TAG FLOAT SHOE&DRILL REMAINDER OF TRACK AND 24'OF NEW HOLE F/10,561'MD T/10,585' -220-250 GPM,1450-1730 PSI ON -40-70 RPM,5-7K TORQUE ON,3K TORQUE OFF. -PU=210K,SO=170K,ROT WT=187K,WOB= 5-10K. -MUD WEIGHT 8.6 PPG IN,8.6 PPG OUT. OBTAIN SPR'S AT 10,420'. 21:30 - 23:00 1.50 CASING P INTI CIRCULATE BOTTOMS UP PRIOR TO FIT. -250 GPM,1700 PSI,60 RPM, - RECIPROCATE FULL STAND. SHUT DOWN WITH 8.6 PPG IN/OUT -NO LOSSES -8.6 PPG MW,IN/OUT -MONITOR WELL FOR 10 MIN-WELL STATIC 23:00 - 00:00 1.00 CASING P INTI PERFORM FITTEST AT 10,559'MD/8,881'TVD WITH 8.6 PPG MUD -PULL UP INTO THE 7"CASING SHOE -PJSM FOR FIT TEST-REVIEW DDI SOP- DISCUSS AND VERIFY LINE UP,VERIFY PRESSURE CROSS CHECK -R/U EQUIPMENT TO PERFORM FIT TEST -R/U CHART RECORDER,SWING,TEE, SENSATOR -FLUID PACK SENSATOR LINE -CHECK CHART RECORDER AND ENSURE WORKING PROPERLY -FLUID PACK TUBING AND KILL LINE -PUMP 1.2 BBLS&PRESSURE UP TO 620 PSI, SHUT IN AND MONITOR -OBSERVE A CONTINUOUS 10 PSI BLEED OFF EVERY 30 SEC.FOR 10 MIN-PRESSURE DROPPED FROM 620 TO 400 RECORD FOR AN ADDITIONAL 5 MIN PER BP SOP FOR FIT TESTING. -SHUT DOWN TEST&BLEED BACK-1/4 BBL -PREPARE TO RE-TEST ZERO BBL LOSSES FOR TOUR. Printed 1/6/2015 5:05:21 PM North America-ALASKA-BP Page 53 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/14/2014 00:00 - 03:00 3.00 CASING P INTI FIT TEST INSPECT ALL SURFACE EQUIPMENT AND OBSERVE FOR LEAKS. -BLEED OFF LINES. -RU ON STUMP WITH TEST MANIFOLD TO ELIMINATE CHOKE LEAK POSSIBILITY RETEST FOR THE LEAK OFF -PUMP 13 STROKES TO PSI UP TO 640 PSI UP. HOLD PRESSURE AND OBSERVE THE SAME LEAK OFF RATE-ROUGHLY 10 PSI EVERY 30 SEC -RECORD THE TEST OUT TO 20 MIN WITH THE SAME RESULTS '-PRESSURE FELL OFF FROM 640 PSI TO 270 PSI. BLED OFF AND OBSERVE FOR BLEED BACK OBSERVE ZERO BBLS BLED BACK -SEND TEST RESULTS AND FIT TEST EXCEL SHEET TO ODE FOR REVIEW. INSPECT SURFACE EQUIPMENT AND RECONFIGURE LINE UP ON THE DP TO HELP REDUCE POSSIBILITY OF LEAKS. -RE-TEST WITH EXACT SAME RESULTS CONTACT TOWN ODE,ETL AND ROTARY TOL TO DISCUSS PLAN FORWARD WITH WSL AND ONSITE GE 0 -AFTER REVIEWING THE DATAAND THE CONDITION IT WAS DETERMINED THAT WE HAVE MOST LIKELY DRILLED INTO THE TOP OF THE SHUBLIKAND HAVE MOST LIKELY FRACTURED IT SLIGHTLY.- -RECEIVED THE AUTHORIZATION TO PROCEED 03:00 - 03:30 I 0.50 DRILL P PROD1 BREAKING CIRCULATION WHILE DISCUSSING PLAN FORWARD. -165 GPM,780 GPM, -MW-8.6 PPG IN/OUT -WELL ON SLIGHT LOSSES-LOST 5 BBLS IN 30 MIN -SHUT DOWN AND MONITOR WELL 10 MIN WELL STATIC. MONITOR ADDITIONAL 15 MIN WHILE RIGGING DOWN TEST EQUIPMENT-WELL STATIC -BLOW DOWN CHOKE AND KILL LINES 03:30 - 04:00 0.50 DRILL P PROD1 WASH DOWN FROM 10,515'MD TO 10,585'MD -200 GPM,1070 PSI, PUW-205K,SOW-175K, -SPR'S AT 10,558'MD/8,881'TVD,MW=8.6 PPG MP 1- 30/40 SPM=500/720 PSI MP 2-30/40 SPM=480/730 PSI Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 54 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 06:00 2.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/10,585" MD TO 10,606'MD,8,916'TVD 1-260 GPM,1740 PSI ON BTM,1680'PSI OFF BTM,22%F/O -100 RPM,4-6 K TORQUE,12-13 K WOB -PU=205K,S/O=175K,ROT=185K, 1-ACTUAL ROTATE TIME=1.9 HRS 1-TOTAL BIT HRS=1.9 -TOTAL JAR HRS=1.9 -MW IN=8.6 PPG,MW OUT=8.6 PPG -SURVEYS EVERY 30' -SLIGHT LOSSES WHILE DRILLING AHEAD- 2-3 BPH. -OBSERVE CONNECTIONS WITH NORMAL 10 BBL DRAIN BACK. 06:00 - 08:00 ' 2.00 DRILL N DFAL i PROD1 I DRILLING TROUBLE TIME -UNABLE TO GET DESIRED BUILD OUT OF THE ARCHER MOTOR -TROUBLE SHOOT MOTOR ASSEMBLY- CONDUCT ANTI-JAMMING SIGNALS -PUMP LOW/HIGH VIS SWEEP PER SLB PROCEDURE FOR ANTI JAMMING. -260 GPM 1730 PSI, MW-8.6 PPG IN/OUT I-UNABLE TO GET DESIRED RESULTS FROM TOOL. DECISION MADE TO TRIP FOR NEW ARCHER RSS TOOL. SHOT SURVEY AT 10,606'TO CONFIRM TOOL INCLINATION LOSS -MONITOR WELL ON TRIP TANK WHILE TROUBLE SHOOTING-WELL STATIC-0 LOSSES 08:00 - 15:30 7.50 DRILL ' N DFAL PROD1 POOH WITH 6-1/8"DRILLING BHA FOR FAILED ARCHER TOOL -POOH FROM 10,606'MD TO SURFACE- MONITOR WELL PRIOR TO PULLING OFF BOTTOM-10 MIN-WELL STATIC -PULL 5 STANDS MONITOR FOR SWABBING- NO SWABBING DETECTED -POOH MONITORING HOLE FILL IN TRIP TANK - HOLE SHOWING SIGNS OF SLIGHT SEEPAGE -LOST 3 BBLS ON TRIP OUT -TRIP OUT AT 76 FT/MIN FROM 7"SHOE TO 9-5/8"CASING -FLOW CHECK WELL PRIOR TO PULLING BHA THROUGH THE BOPE -PULL AND LD BHA#5 AS DIRECTED BY SLB DD AND MWD -STAND BACK COLLARS -PJSM FOR PULLING NUCLEAR SOURCE- REVIEW HAZARDS AND MITIGATION'S-MAKE ANNOUNCEMENTS -PULL SOURCE AS PER SLB PROCEDURE -BIT GRADE:0-1-CT-G-X-I-NO-DTF IN GAUGE-WILL RE-RUN Printed 1/6/2015 5:05:21 PM North America-ALASKA-BP Page 55 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 15:30 - 17:00 1.50 DRILL N DFAL PROD1 PU&MU NEWARCHER RSS AND BHA#6 -PU ARCHER AND SURFACE TEST-216 GPM, 625 PSI-GOOD TEST -MAKE UP IMPULSE AND ADN PJSM FOR INSTALLING SOURCE-INSTALL PER SLB PROCEDURE -TROUBLE INSTALLING SOURCE- -SLB TROUBLE SHOOTING REASON FOR FAILED R/A SOURCE INSTALL- 17 00 - 20:00 3.00 DRILL N DFAL PROD1 MAKE UP 6-1/8"BHA#6 LAY DOWN ADN AND PU BACK UP 1-WHILE CHANGING OUT THE ADN,DD NOTICED SOME DEBRIS IN THE IMPULSE TOOL. -DECISION WAS MADE TO LAY DOWN IMPULSE TOOL AND PU BACK UP. -PU&MU BACK UP IMPULSE AND ADN -PJSM FOR LOADING SOURCE-REVIEW SLB PROCEDURE FOR RADIOACTIVE SOURCE LOADING. -LOAD R/A SOURCE IN ADN TOOL. 20:00 - 22:00 2.00 DRILL N DFAL PROD1 ' MAKE UP 6-1/8"DRILLING BHA#6 TO 182'MD AS DIRECTED BY THE SLB DD. RIH ON 4"DP F/182'TO 1,600'MD. -SURFACE TEST ARCHER TOOL(SLB PROCEDURE) AT±1,600'MD WITH 202 GPM, 760 PSI.-GOOD TEST -MONITOR WELL DISPLACEMENT VIA TT- HOLE DISPLACEMENT CORRECT.-NO LOSSES 22.30 - 00:00 2.00 DRILL N DFAL PROD1 RIH ON 4"XT39 DP FROM THE DERRICK W/ ARCHER BHA FROM 1600'MD TO 2,937'MD. -MW-8.6 PPG PWR-PRO IN/OUT. -FILLING PIPE EVERY 15 STANDS AND I CIRCULATING AT 240 GPM,1400 PSI.FOR 8 MIN EACH TIME PER SLB SOP FOR RUNNING ARCHER. -P/U AND RIH WITH 4"HWDP&4-3/4"JARS FROM 2,937'TO 3,206'MD. CONTINUE RIH F/DERRICK FROM 3,206'MD TO 4,742'MD. -MONITOR WELL DISPLACEMENT VIA TT- HOLE DISPLACEMENT CORRECT.-ZERO LOSSES FILLING PIPE EVERY 15 STANDS WITH 210 GPM,CIRCULATE FOR 8 MIN AT 210 GPM W/ 1276 PSI-PER SLB SOP FOR RUNNING ARCHER. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 56 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 •X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT • NPT Depth Phase Description of Operations (hr) (usft) 12/15/2014 00:00 - 04:00 4.00 DRILL N DFAL 10,606.00 PROD1 RIH ON 4"XT39 DP FROM THE DERRICK W/ •ARCHER BHA F/4,742'MD T/10,606'MD(8,935' TVD). -FILLING PIPE EVERY 15 STANDS AND •CIRCULATING AT 240 GPM,1400 PSI.FOR 8 MIN EACH TIME PER SLB SOP FOR RUNNING • ARCHER. -MW-8.6 PPG PWR-PRO IN/OUT. -MONITOR WELL DISPLACEMENT VIA TT- HOLE DISPLACEMENT CORRECT.-ZERO LOSSES. -DOWN LINK TO ARCHER TOOL FOR PREPERATION FOR DRILLING. -WASH&REAM LAST STAND TO BOTTOM- 265 GPM,1700 PSI,100 RPM. MADD PASS 15'FROM 10,591'MD TO 10,606'. I -OBTAIN PARAMETERS. PUW-205,SOW-175,ROT-185. SPR'AT-10,520'. 04:00 - 12:00 8.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/10,606'MD (8,935'TVD),10,836'MD(9,078'TVD). 261 GPM,1830 PSI ON BTM,1770 PSI OFF BTM,22%F/O. 140 RPM,5-8 K TORQUE ON, 4K TORQUE OFF. -PU=215K,S/O=175K,ROT=190K, WOB= 3-5 K. MW IN=8.6 PPG,MW OUT=8.6 PPG. -SURVEYS EVERY-30'. -ACTUAL ROTATE TIME=3.16 HOURS. -JARS TIME=5.06. BIT HOURS=5.06. -BACK REAM 15'PRIOR TO CONNECTIONS. -MUD WEIGHT 8.6 PPG IN,8.6 PPG OUT. -OBSERVE CONNECTIONS WITH NORMAL 10 BBL DRAIN BACK. *AT 10,836'OBSERVED PRESSURE DROP OF 200 PSI.AND MWD TOOL LOSE CONNECTION. *ZERO BBL LOSSES FROM MIDNIGHT TO NOON. 12:00 - 15:00 3.00 DRILL N DFAL 10,833.00 PROD1 ATTEMPT IDENTIFY AND TROUBLE SHOOT MWD SIGNAL ISSUES. PUMP SWEEPS.FOR ANTI JAMMING TROUBLE SHOOTING. -PUMP 35 BBL LOW VIS SWEEP. -PUMP 20 BBL HIGH VIS SWEEP. -8.6 PPG AT 270 GPM W/1560 PSI. -RPM=100K,TORQUE 4K. -MONITOR WELL FOR 10 MINUTES-WELL STATIC. -MUD WEIGHT 8.6 PPG IN,8.6 PPG OUT. 15:00 - 16:00 1.00 DRILL N DFAL 10,833.00 PROD1 POOH ON ELEVATORS F/10,836'MD T/10,375' MD. PU=175K,SO=210KAT 10,836'. -OBTAIN SPR'S AT 10,836'MD,9,078'TVD. -MONITOR WELL FOR 10 MINUTES AT SHOE- WELL STATIC. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 57 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 23:00 7.00 DRILL N DFAL . 10,833.00 PROD1 POOH ON ELEVATORS F/10,375'MD T/190' MD. -PU=205K,S0=167KAT 10,375'MD. -FLOW CHECK BEFORE BRINGING NON SHEARABLES ACROSS THE STACK-WELL STATIC. 23:00 - 00'00 1.00 DRILL N DFAL 10,833.00 PROD1 LAY DOWN DRILLING BHA#6. PJSM W/SLB AND DDI PERSONAL. STAND BACK FLEX COLLARS. -PJSM FOR PULLING NUCLEAR SOURCE- REVIEW HAZARDS AND MITIGATION'S-MAKE ANNOUNCEMENTS. PULL SOURCE AS PER SLB PROCEDURE. 20 BBL LOSS FROM NOON TO MIDNIGHT. 12/16/2014 00:00 - 00:30 0.50 DRILL N DFAL 10,833.00 PROD1 L/D 6-1/8"DRILLING BHA#6. '-L/D MWD TOOL,ARCHER,ADN AND BIT. -BIT GRADE:0-1-CT-G-X-I-NO-DTF. IN GAUGE-WILL RE-RUN. 00:30 - 01:30 1.00 1 DRILL N DFAL j 10,833.00 PROD1 P/U&M/U ARCHER RSS AND M/U BIT. -SURFACE TEST ARCHER RSS-200 GPM, 650 PSI-GOOD TEST. 01:30 03:30 2.00 DRILL N DFAL 10,833.00 PROD1 M/U 6-1/8"BHA#7 T/182'MD AS DIRECTED BY THE SLB DD. -MAKE UP IMPULSE AND ADN. -PJSM FOR INSTALLING SOURCE,REVIEW HAZARDS AND MITIGATION'S-MAKE ,ANNOUNCEMENTS. -INSTALL SOURCE PER SLB PROCEDURE. 03:30 - 04:30 1.00 DRILL N DFAL 10,833.00 PROD1 MAKE UP 6-1/8"DRILLING BHA#7 TO 182'MD AS DIRECTED BY THE SLB DD. RIH ON 4"DP F/182'TO 1,600'MD. -SURFACE TEST ARCHER RSS AS PER SLB PROCEDURE AT 1,576'MD WITH 265 GPM, 1150 PSI.-GOOD TEST -MONITOR WELL DISPLACEMENT VIA TT HOLE DISPLACEMENT CORRECT.-ZERO LOSSES 04:30 - 10:00 5.50 DRILL N DFAL 10,833.00 PROD1 RIH ON 4"XT39 DP FROM THE DERRICK WI ARCHER BHA FROM 1576'MD TO±10,545'MD. -MW-8.6 PPG PWR-PRO IN/OUT. -FILLING PIPE EVERY 15 STANDS AND CIRCULATING AT 240 GPM,1400 PSI.FOR 8 MIN EACH TIME PER SLB SOP FOR RUNNING ARCHER. -P/U AND RIH W/4"HWDP&4-3/4"JARS FROM 2,937'TO 3,206'MD. -CONTINUE RIH W/4"XT39 DP F/DERRICK FROM 3,206'MD TO 10,545'MD. -MONITOR WELL DISPLACEMENT VIA TT- HOLE DISPLACEMENT CORRECT.-ZERO LOSSES. 10:00 - 12:30 2.50 DRILL P PROD1 SLIP AND CUT DRILLING LINE. -PJSM,SLIP AND CUT 59.5'OF DRILL LINE. -SERVICE TOP DRIVE,BLOCKS,CROWN AND ST-80. CALIBRATE BLOCK HEIGHT AND WEIGHT INDICATOR FOR MWD UNIT. *ZERO LOSSES FROM MIDNIGHT TO NOON. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 58 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 14:00 1.50 DRILL N DFAL 10,833.00 PROD1 NEW DIRECTIONAL PLAN BEING FINALIZED IN TOWN -PLAN FORWARD CONFERENCE CALL WITH SLB DIRECTIONAL LEAD AND BP ENGINEERING GROUP 14:00 - 14:30 0.50 DRILL N DFAL 10,833.00 PROD1 TIH FROM±10,545'TO 10,836'MD -WASH LAST STAND DOWN PUW-205K,SOW-174K,ROT-185K -OBTAIN SPR'S -DOWN LINK TO ARCHER TOOL FOR TOOL FACE CORRECTION 14:30 - 00:00 9.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/10,836'MD T/11,090'MD.9,141'TVD -270 GPM,1920 PSI ON 1850 PSI OFF. -100-140 RPM,5-7K TORQUE ON,5K TORQUE OFF. -PU=212K,SO=176K,ROT WT=185K,WOB= 10K. SURVEY EVERY-30'. -BACK REAM 10'PRIOR TO CONNECTIONS. -MUD WEIGHT 8.6 PPG IN,8.7 PPG OUT. -AT 10,945'WELL STARTING LOSING MUD- LOSS RATE BALANCED OUT AT 55 BPH DYNAMIC,5-8 BPH SLR -MADE NOTIFICATIONS TO ODE AND RTL FOR LOSSES GREATER THAN 20 BPH. -STARTED PLAN FOR DRILL AHEAD PILLS TO BE BROUGHT OUT AND SOME BACKGROUND LCM TO BE ADDED. -STARTED ADDING BACKGROUND LCM AT 22:30. - 2 PPB SAFE CARB 40 -DYNAMIC LOSS RATE AT MIDNIGHT AT 60 BPH. 12/17/2014 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/11,090' MD.TO 11,747'MD(9,013'TVD) -270 GPM,1880 PSI ON 1860 PSI OFF. -120 RPM,8.5K TORQUE ON,5.5K TORQUE OFF. -PU=205K,SO=168K,ROT WT=185K,WOB= 3-5K. -SURVEY EVERY-30'. -ACTUAL ROTATE TIME=7.3 HOURS -JAR TIME=16 HOURS. -BACK REAM 15'PRIOR TO CONNECTIONS. -MUD WEIGHT 8.6 PPG IN,8.7 PPG OUT. -CURRENT DYNAMIC LOSS RATE AT 35 BPH. -RUNNING BACKGROUND LCM- 2 PPB SAFE CARB 40 -OBTAIN SPR'S AT 11,337' -PUMPED SWEEP AT 11,428',LOSSES WENT FROM+80 BBLS AN HOUR TO 26 BPH. 401 BBLS LOST FROM MIDNIGHT TO NOON. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 59 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date 11� From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ;- (usft) 12:00 - 00:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/11,747' MD.TO 12,126'MD(9,006'TVD) -270 GPM,1930 PSI ON 1930 PSI OFF. -80 RPM,7K TORQUE ON,5K TORQUE OFF. -PU=212K,SO=170K,ROT WT=185K,WOB= 10K. -SURVEY EVERY-30'. -ACTUAL ROTATE TIME=3.96 HOURS -JAR TIME=19.86 HOURS. -BIT HOURS=19.86 -BACK REAM 15'PRIOR TO CONNECTIONS. MUD WEIGHT 8.6 PPG IN,8.7 PPG OUT. i-OBTAIN SPR'S AT 11,745'(9,008 TVD) DYNAMIC LOSS RATE AT 24 BPH. *303 BBLS LOST FROM NOON TO MIDNIGHT. *BEGAN EXPERIENCING INCONSISTENT TOOL FACE RESPONSE FROM ARCHER TOOL AT 15:00 F/11775'TO 11810'MD -CALLED TOWN TO DISCUSS PLAN FORWARD -DECISION WAS MADE TO DRILL ANOTHER 30'TO SEE IF PROPER BUILD RATES COULD BE ACHIEVED TO KEEP WELL PATH INSIDE OF DRILLER'S POLYGON AS WELL AS DROP INC TO 90 DEG AND 8918'TVDSS BEFORE REACHING PROJECTED FAULT AT 11850'MD -CALL TOWN AGAIN TO PASS ON RESULTS OF PAST 30'OF DRILLING F/11810'TO 11840', DECIDED TO DRILL ANOTHER 20'F/11840'TO 11860' -BASED ON BUILD RATES SEEN, PROJECTIONS SHOWN TO KEEP WELL PATH WITHIN PARAMETERS DESCRIBED ABOVE, CONTINUE TO DRILL AHEAD AS PER DIRECTIONAL PLAN AT 18:00 W/TOOL OPERATING WITHIN NORMAL PARAMETERS 12/18/2014 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/ 12,126' MD TO 12,698'MD(9,046'TVD) -270 GPM,1930 PSI ON 1930 PSI OFF. -100 RPM,6K TORQUE ON,5K TORQUE OFF. -PU=218K,SO=170K,ROT WT=186K,WOB= 3-5K. -ACTUAL ROTATE TIME=6.19 HOURS -JARS TIME=26.05 HOURS. -SURVEY EVERY-30' -BACK REAM 10'PRIOR TO CONNECTIONS. -MUD WEIGHT 8.6 PPG IN,8.7 PPG OUT. -PUMP 30 BBL HIGH VIS SWEEP WITH LCM PILL.-OBSERVED A 5%INCREASE IN FINE SAND RETURNS AT BOTTOMS UP. -OBTAIN SPR'S AT 12,319',9012'TVD. -PUMP 100 BBL OF 35 PPB LCM PILL AT 12,319'TO REDUCE LOSSES,PILL DID NOT HAVE ANY EFFECT ON LOSS RATE.NO INCREASE IN CUTTINGS WITH PILL AT SURFACE. *299 BBLS LOST FROM MIDNIGHT TO NOON. Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 60 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 00:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/ 12,698' MD TO 13,173'MD -270 GPM,2100 PSI ON,2010 PSI OFF. -100 RPM,7.5K TORQUE ON,5K TORQUE OFF. -PU=218K,SO=170K,ROT WT=186K,WOB= 6K. -ACTUAL ROTATE TIME=5.93 HOURS -JARS TIME=31.98 HOURS. -SURVEY EVERY-30'. -BACK REAM 15'PRIOR TO CONNECTIONS. -MUD WEIGHT 8.6 PPG IN,8.6+PPG OUT. -NO SWEEPS PUMPED FROM NOON TO MIDNIGHT OBTAIN SPR'S AT 12,694'MD,9,047'TVD 298 BBLS LOST FROM NOON TO MIDNIGHT 12/19/2014 00:00 - 07:30 7.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/ 13,173' • MD TO 13,425'MD(8,995'TVD) -270 GPM,2070 PSI ON 2050 PSI OFF. -100 RPM,9K TORQUE ON,5.5K TORQUE OFF. -PU=225K,SO=167K,ROT WT=183K,WOB= 10K. -ACTUAL ROTATE TIME=3.29 HRS. -JARS TIME=35.28 HRS. -SURVEY EVERY-30' -BACK REAM 15'PRIOR TO CONNECTIONS. -MUD WEIGHT 8.6 PPG IN,8.6 PPG OUT. -OBTAIN SPR'S AT 13,425'MD. 07:30 - 12:00 , 4.50 DRILL P PROD1 PUMP HIGH VIS SWEEP. -CBU X 3 -270 GPM,2050 PSI. -100 RPM,5K TORQUE -RACK BACK 1 STAND AFTER EACH BOTTOMS UP. *LOSS RATE AT 30 BPH. -FIRST BOTTOMS UP CUTTINGS STILL HEAVY,CLEANED UP BY THE END OF THE THIRD BOTTOMS UP. -MONITOR WELL FOR 10 MINS-WELL STATIC MUD WEIGHT 8.6 PPG IN AND 8.6 PPG OUT. PUMP 40 BBLS OF DRILL AHEAD OF SWEEP AT 13,200'MD.NO NOTICABLE CUTTINGS CAME TO SURFACE. 424 BBLS LOST FROM MIDNIGHT TO NOON. 12:00 - 15:00 3.00 DRILL P PROD1 POOH WITH 6-1/8 DRILLING BHA ON ELEVATORS F/13,267'MD T/10,515'MD. -PU=220K,SO=170KAT 13,267'MD. -POOH ON ELEVATORS,TIGHT SPOT AT 11,030'.10K OVERPULL,WIPED CLEAN 1X -STATIC LOSS RATE 20 BPH. -OBTAIN SPR'S AT 13,267'MD(9,001'TVD). -FLOW CHECK-WELL TAKING FLUID AT 20 BPH. 15:00 - 15:30 0.50 WHSUR P PROD1 WEEKLY FUNCTION TEST ON RAMS AS PER SOP. -FUNCTION TEST VBR'S AND ANNULAR -BLINDS WILL BE FUNCTION TESTED AT EARLIEST POSSIBLE POINT -FUNCTION TEST HCR KILL AND CHOKE Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 61 of 62 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay I Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 17:00 1.50 DRILL P PROD1 CIRCULATE BOTTOMS UP INSIDE 7"SHOE -270 GPM,1830 PSI. -0 RPM,RECIPRICATING PIPE -5%INCREASE IN FINE SANDS AT BU FLOW CHECK-WELL TAKING 20 BPH. 17:00 19:00 2.00 DRILL P PROD1 RIH W/6-1/8"DRILLING BHA ON ELEVATORS F/10,515'MDT/13,425'. -RIH ON ELEVATORS. -PU=210K,S0=175K BREAK CIRCUALTION EVERY 1,500'MD, -260 GPM,1900 PSI. NO TIGHT SPOTS ENCOUNTERED WHILE RUNNING IN THE HOLE. 19:00 - 23:30 4.50 DRILL P PROD1 CIRCULATE AND CONDITION HOLE WITH 2.5 BU AT TD -260 GPM,2030 PSI. -80 RPM,5K TORQUE. -PUMP 30 BBL HIGH VIS SWEEP,8.6 PPG,240 VIS. -5%INCREASE IN FINE SAND SEEN AT BU -WELL ON 25-35 BPH DYNAMIC LOSS RATE FLOW CHECK FOR 10 MINS-STATIC LOSS RATE 18 BPH 23:30 - 00:00 0.50 DRILL P PROD1 POOH W/6-1/8"DRILLING ASSY ON ELEVATORS F/13,425'T/13,363'. -RACK BACK 1 STAND OF DRILL PIPE. PULL 5 STANDS MONITORING FOR SWABBING-NONE OBSERVED -BLOW DOWN TOP DRIVE. -LINE UP TRIP TANK -PUW=220K,SOW=165K. -OBTAIN SPR'S AT 13,410. -MONITOR HOLE FILL FOR TRIP ON TRIP TANK-HOLE TAKING MORE THAN CALCULATED FILL DUE TO LOSSES -MONITORING LOSS TREND FOR CHANGES TO HELP DETECT CHANGING HOLE CONDITIONS *183 BBL LOSS FROM NOON TO MIDNIGHT. 12/20/2014 00:00 04:00 4.00 DRILL P PROD1 POOH ON ELEVATORS F/13,363'MD T/10,515' MD -POOH&RACK BACK 4"DP IN DERRICK -PU=220K,SO=165KAT 13,363'MD. -TIGHT HOLE AT 10,920'MD WITH 10K OVERPULL,WORKED SPOT TWO TIMES AND NO MORE OVERPULL OR WOB OBSERVED. -MONITOR TRIP ON TRIP TANK -MONITOR HOLE FILL FOR TRIP ON TRIP TANK-HOLE TAKING MORE THAN CALCULATED FILL DUE TO LOSSES -MONITORING LOSS TREND FOR CHANGES TO HELP DETECT CHANGING HOLE CONDITIONS -POOH FROM TD TO 7"SHOE AT 66'FT/MIN -MONITOR WELL 10 MINUTES AT 10,500'MD (7"SHOE)-STATIC LOSS RATE AT 18 BPH -POOH FROM 7"SHOE TO 6,000'AT 76' FT/MIN -FLOW CHECK FOR 10 MINS- Printed 1/6/2015 5:05:21 PM North America-ALASKA-BP Page 62 of 62 Operation SummaryReport p p Common Well Name:Y-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/17/2014 End Date:12/20/2014 X3-015RC-C:(9,088,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 04:30 0.50 DRILL P PROD1 PUMP DRY JOB. -28 BBL,9.6 PPG DRY JOB. -PUMP 12 BBLS 8.6 PPG MUD -CIRCULATE 126 GPM W/600 PSI. -FLOW CHECK FOR 10 MINS-LOSS RATE AT 18 BPH. -MUD WEIGHT 8.6 PPG IN AND 8.6 PPG OUT 04:30 - 08:00 3.50 DRILL P PROD1 POOH ON ELEVATORS F/10,515'MD T/3,237' MD. -PU=205K,SO=175K AT 10,515'MD. -FLOW CHECK BEFORE BRINGING NON SHEARABLES ACROSS THE STACK-LOSS RATE AT 18 BPH. 08:00 - 09:00 1.00 DRILL P PROD1 POOH AND LAY DOWN 4"HWDP F/3,237'MD 'T/2,937'MD. FLOWCHECK WELL FOR 10 MINUTES-WELL ON 18 BPH LOSS. -MUD WEIGHT 8.6 PPG IN AND 8.6 PPG OUT. 09:00 - 10:00 1.00 DRILL P PROD1 POOH ON ELEVATORS F/2,937'MD T/468'MD. -PU=95K,SO=95K AT 2,937'MD. 10:00 - 14:00 4.00 DRILL P PROD1 LAY DOWN 6-1/8"DRILLING BHA#7. -PJSM W/DDI PERSONNEL AND SLB MWD ON LAYING DOWN BHA AND SOURCE. -POOH ON ELEVATORS F/468'T/183'MD. -LAY DOWN NON MAG FLEX COLLARS F/183' I MD TO 85'MD. ' I-MOBILIZE SOURCE SHIELD AND REMOVE SOURCE FROM ADN VISION TOOL. -RIG DOWN TUGGER AND MOVE SOURCE ' CONTAINMENT FROM FLOOR. -BREAK AND LAY DOWN SLB TOOLS. BIT GRADE:1-2-CT-G-X-1-ER-TD BIT 1/16"UNDERGUAGE. *FUNCTION TEST BLIND SHEAR RAMS AS PER WEEKLY FUNCTION TEST. —SWITCH TO(CON)COMPLETION EVENT— Printed 1/6/2015 5:05:21PM North America-ALASKA-BP Page 1 of 12 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/20/2014 End Date:12/26/2014 X3-015RC-C:(3,362,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft)- 12/20/2014 14:00 - 15:30 1.50 CASING P RUNPRD CLEAN&CLEAR RIG FLOOR FUNCTION TESTED BLIND SHEAR RAMS TO COMPLETE WEEKLY BOP FUNCTION TEST- -STATIC LOSS RATE-15-17 BPH. RIG UP FOR 4-1/2"PRODUCTION LINER RUN -C/O ELEVATORS.DRILLER VERIFIED CORRECT SIZE&CAPACITY --R/U POWER TONGS,LEAD FLOOR HAND VERIFY CORRECT TONG HEAD SIZE. -RU FILL UP HOSE. -VERIFY PIPE COUNT-CORRECT COUNT IN CASING SHED-WSL VERIFIED HOLD PJSM FOR RUNNING 4-1/2"LINER RIG CREW,DDI CASING,BP,BOT REPS REVIEW DDI PROCEDURE FOR RUNNING LINER -REVIEW PLAN FORWARD --DISCUSS PLAN FOR NON-SHEARABLES ACROSS THE STACK -ENSURE 4.5"VT XO IS AVAIL ON THE FLOOR AND MADE UP TO THE FOSV -ENSURE SHEAR JOINT IS MADE UP AND AVAILABLE 15:30 - 22:00 6.50 CASING P RUNPRD PICK UP AND RIH WITH 4.5"VT 12.6#13CR85 LINER -FROM SURFACE TO 3,538'MD -MAKE UP SHOE TRACK AND BAKER LOCK CONNECTIONS -PUMP 2-3 BBLS THROUGH SHOE TRACK, PICK UP&CHECK FLOATS-FLOATS GOOD WSL VERIFIED. -RUN 4.5"LINER PER TALLY,TIH AT 75-90 FT/MIN -2-5.75"HYDROFORM CENTRALIZERS PER JOINT INSTALLED IN CASING SHED PRIOR TO JOB. -NO CENTRALIZERS 50'EITHER SIDE OF THE 7"SHOE -USE JET LUBE SEAL GUARD ON ALL CONNECTIONS -TORQUE TURN ALL CONNECTIONS TO 4400 FT/LBS -FILLING PIPE ON THE FLY W/FILL UP HOSE- TOPPING OFF EVERY 10 -TAKE PU&SO WEIGHTS EVERY 10 JOINTS 'MONITOR WELL BORE WHILE PICKING UP THE HANGER.-SLR=15 BPH. -WSL AND TP TO VERIFY CORRECT PIPE COUNT IN THE SHED AFTER PICKING UP THE LAST JOINT ON THE TALLY.-COUNT IS CORRECT Printed 1/6/2015 5:05:57PM North America-ALASKA-BP Page 2 of 12 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/20/2014 • End Date:12/26/2014 X3-015RC-C:(3,362,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM 1 Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 • CASING P RUNPRD •PU BAKER LINER HANGER AND ZXP-HD LINER TOP PACKER ASSEMBLY WITH HRD-E RUNNING TOOL -MU BUMPER SUB -PU HANGER WITH 3-1/2"LIFT SUB WITH 4.5" NECK -PUW-87K,SOW-87K • C/O SLIP INSERTS TO 3.5",TURNED OFF HOLE FILL TO DRAIN STACK -MU 4"STAND TO HANGER ASSEMBLY • -BAKER REP MIX AND INSTALL PAL MIX -BREAK CIRCULATION -PUMP 1-1/2"LINER VOLUME,STAGING PUMPS UP TO 3 BPM, -PUMP THROUGH THE HANGER AT 126 GPM, 100 PSI -DLR-18 BPH • TOTAL LOSSES FOR TOUR 135 BBLS 12/21/2014 00:00 - 00:30 0.50 CASING P RUNPRD RIG SERVICE. • -LUBRICATE RIG TOP DRIVE,DRAW WORKS AND ST-80. 00:30 - 10:30 10.00 CASING P RUNPRD •RIH W/4-1/2"12.6#,VT 13CR85 L-80 SOLID LINER ON 4"XT39 DP STANDS FROM • DERRICK TIH F/3,538'MD TO10537'MD. OBTAINING PU&SO WEIGHTS AND FILLING • 'EVERY 10 STANDS. -TIH AT 60-90 FT/MIN -MONITORING DISPLACEMENT ON THE TRIP TANK -SLIGHT LOSSES WHILE RUNNING IN THE HOLE 12-15 BPH,AT 8885'WHEN PACKER REACHED TOP OF 7'LINER LOSS RATE INCREASED REDUCED RUNNING SPEED TO 25'PER MINUTE TO MAINTAIN LOSS RATE. -MW-8.6 PPG IN/OUT 10:30 - 11:30 1.00 CASING P RUNPRD •CIRCULATE 1.5 X LINER VOLUME AT 10537' MD(22)ABOVE THE SHOE. -STAGE UP PUMP IN HALF BARREL INCREMENTS TO FINAL PUMP RATE OF 231 GPM AT 610 PSI. *DYNAMIC LOSS RATE AT 231 GPM 32 BBLS/HR -MAINTAINED RATE OF 231 GPM DUE TO HIGHER LOSS RATES AT HIGHER PUMP RATES. 11:30 - 15:30 4.00 CASING P RUNPRD RIH W/4-1/2"12.6#,VT 13CR85 L-80 SOLID LINER ON 4"XT39 DP STANDS FROM • DERRICK TIH F/10,537"MD TO 13,418'MD. • -OBTAINING PU&SO WEIGHTS AND FILLING EVERY 10 STANDS. -TIH AT 60-90 FT/MIN • -MONITORING DISPLACEMENT ON THE TRIP TANK -SLIGHT LOSSES WHILE RUNNING IN THE HOLE 12-15 BPH- MAINTAINED RUNNING j •SPEED AT 25'PER MINUTE TO MAINTAIN LOSS RATE. -MW-8.6 PPG IN/OUT Printed 1/6/2015 5:05:57PM North America-ALASKA-BP Page 3 of 12 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/20/2014 End Date:12/26/2014 X3-015RC-C:(3,362,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1986 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 16:00 0.50 CASING P RUNPRD RIG UP CEMENT HEAD AND CIRCULATION LINES. 16:00 - 16:30 0.50 CASING P RUNPRD RIH W/4-1/2"12.64/,VT 13CR85 L-80 SOLID LINER ON 4"XT39 DP STANDS FROM DERRICK TIH F/13,418"MD TO 13,425'MD.ON DEPTH AT(TD) -SET DOWN 10K OVER STRING WEIGHT -PICK UP TO UP WEIGHT PLUS TWO FEET TO MARK LINER SETTING DEPTH OF 13,423 MD. 1-UP WEIGHT 225K.-DOWN WEIGHT 160K -MW-8.6 PPG IN/OUT. 16:30 - 21:00 4.50 CASING P RUNPRD CIRCULATE AND CONDITION MUD FOR CEMENT OPERATIONS. -STAGE PUMPS UP SLOWLY.1/2 BBL j INCREMENTS ALLOWING PRESSURE TO STABILIZE -RECIPROCATE PIPE 20'WHILE CIRCULATING -PUW-205K,SOW-160K -ESTABLISH CIRCULATION. 1-CIRCULATE.5 BPM W/ICP 730 PSI. -FCP- 240 PSI AFTER 5 BBLS PUMPED. -STAGE PUMPS UP TO 5 BPM-FCP-950 PSI. -DLR-15-20 BPH -INCREASED CIRCULATION RATE TO 6 BPM, LOSSES INCREASED TO 60-70 BPH. -REDUCED CIRCULATION RATE BACK TO 5 BPM -CONTACTED ODE FOR APPROVAL TO PUMP CEMENT AND DISPLACEMENT AT A LOWER !RATE FROM PLANNED CADE.- -RECEIVED NEW CADE WITH NEW PUMP RATE AND SCHEDULE 1-CIRCULATE TOTAL 3 BOTTOMS UP 21:00 - 21:30 0.50 CEMT P RUNPRD PRE JOB SAFETY MEETING -REVIEW HAZARDS FOR HIGH PRESSURE !TESTING AND PUMPING -REVIEW SLB PLAN FORWARD -DISCUSS LINE UP FOR PRESSURE CROSS CHECK-CHECK LIST -VERIFY PROPER OVERPRESSURE SETTING -WSLAND CEMENTER TO AGREE ON THE USE OF RECENT CADE. 21:30 - 22:00 0.50 CEMT P RUNPRD PRESSURE TEST LINES -PRESSURE TEST 250 LOW/4500 PSI HIGH- GOOD TEST -VERIFY OVERPRESSURE SHUT DOWN EQUIPMENT-AT 1850 PSI LINE UP AND PREPARE TO BATCH MIX CEMENT. START BATCH MIXING MUD PUSH& CEMENT i-SWITCH BACK OVER TO RIG PUMPS TO CONTINUE CIRCULATING -STAGE PUMPS UP SLOWLY ALLOWING FOR PRESSURE TO STABILIZE. -CIRCULATE AT 5 BPM WITH 800 PSI Printed 1/6/2015 5:05 57PM North America-ALASKA-BP Page 4 of 12 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/20/2014 End Date:12/26/2014 X3-015RC-C:(3,362,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 23:30 1.50 CASING P RUNPRD CEMENT 4-1/2"PRODUCTION LINER AS FOLLOWS -PUMP 30 BBLS OF 10 PPG MUD PUSH TOO SPACER AT 5 BPM,406 PSI. -PUMP 75.4 BBLS OF 15.8 PPG CLASS G TAIL AT 5 BPM,EXCESS VOLUME 40%(YIELD 1.17 CU.FT/SK) -SHUT VALVE BELOW THE CEMENT HEAD AND CLEAR THE LINES WITH 5 BBLS OF PERF PILL AND WASH UP TO THE FLOW LINE I AND OUT TO THE ROCK WASHER I-DROP DRILL PIPE WIPER DART. RECIPROCATED PIPE 15 FT AT SURFACE WHILE PUMPING CEMENT AT 5 BPM. -PERFORM DISPLACEMENT WITH CEMENTER PUMPS:FOLLOWING SLB CADE '-152 BBLS DISPLACED AT 5 BPM:ICP 191 PSI 24%RETURN FLOW,FCP 1270 PSI,24% RETURN FLOW -DISPLACEMENT FLUID: -60 BBLS OF 8.6 PPG PER PILL FOLLOWED BY-92 BBLS OF 8.6 PPG FLOW PRO. LATCH UP CONFIRMED WITH 900 PSI INCREASE AT 107.7 BBLS DISPLACED. -REDUCE RATE TO 2 BPM PRIOR TO PLUG BUMP: FINAL CIRCULATING PRESSURE 2000 PSI. -BUMPED PLUG WITH 151.8 BBLS. (CALCULATED) -RECIPROCATE PIPE 15 FT AT SURFACE DURING DISPLACEMENT,STOP RECIPROCATING WHEN CEMENT TURNS CORNER AT SHOE. -RE-SET ELECTRIC OVERPRESSURE CONTROL TO 4700 PSI. -INCREASE PRESSURE TO 2800 PSI,SLACK OFF 70K DOWN,-PRESSURE UP TO 4200 PSI ,S/O 10K MORE TO SET HANGER-BLEED PRESSURE AND CHECK FLOATS-FLOATS HOLDING PU TO CONFIRM RELEASE W/230K-NOT ,RELEASED PRESSURE UP TO 4500 PSI AND REPEAT ABOVE STEPS. -PU 6'TO CONFIRM,RELEASED W/200K PU -TOTAL LOSSES FROM CEMENT EXIT SHOE TO CEMENT IN PLACE:10 BBLS. -CEMENT IN PLACE AT: 23:30 -CEMENT WILL REACH 1000 PSI COMPRESSIVE STRENGTH AT 14:15-12/22 Printed 1/6/2015 5:05:57PM North America-ALASKA-BP Page 5 of 12 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/20/2014 End Date:12/26/2014 X3-015RC-C:(3,362,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No. DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI.500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23.30 - 00:00 0.50 CASING P RUNPRD SET LTP -INCREASE PRESSURE TO 2800 PSI,SLACK OFF 70K DOWN,-PRESSURE UP TO 4200 PSI ,S/O 10K MORE TO SET HANGER-BLEED PRESSURE AND CHECK FLOATS-FLOATS HOLDING PU TO CONFIRM RELEASE W/230K-NOT RELEASED -PRESSURE UP TO 4500 PSI AND REPEAT ABOVE STEPS. PU 6'TO CONFIRM,RELEASED W/200K PU LINER SET AT 13,423'MD: 12/22/2014 00:00 - 01:30 1.50 CASING P RUNPRD 'SET DOWN AND CONFIRM LTP SET -PU TO EXPOSE DOG SUB AND SET DOWN ON THE LINER TOP 50K,20 RPM. -PU TO REMOVE RS PACK-OFF AND CIRCULATE EXCESS CEMENT OFF LINER TOP. PU RUNNING TOOL ABOVE LINER TOP AND MARK NO-GO.POOH FROM 13,385'MD TO 13,322'MD CIRCULATE 1.5 BOTTOMS UP AT 10 BPM. -420 GPM,1390 PSI OBSERVED MUD BACK AT SURFACE AT BOTTOMS UP STROKES 1-ESTIMATED 15-18 BBLS OF EXCESS 1 CEMENT TO SURFACE ON BOTTOMS UP. -CEMENT STRUNG OUT,SHUT DOWN THE PUMPS TO BRING ON MORE 8.6 PPG MUD TIGHT LOCATION-DIFFICULT LOGISTICS FOR MOVING TRUCKS AND TAKING ON FLUIDS 01:30 - 02:00 0.50 CEMT P RUNPRD RIG DOWN CEMENT HEAD AND LINES AND I LAY DOWN -PJSM FOR RIGGING DOWN LINES AND CEMENT HEAD -DISCUSS DROPS HAZARD AND CONTINGENCY PLAN. CEMENT TRUCKS RIGGING DOWN AND MOVING OUT OF THE WAY. 02:00 - 03:00 1.00 CEMT P RUNPRD CONTINUE CIRCULATING OUT EXCESS CEMENT UNTIL CLEAN RETURNS. -250 GPM,610 PSI SIM OPS:CLEAN AND MUD PITS FOR UPCOMING DISPLACEMENT -MOBILIZE TRUCKS IN PLACE FOR SEAWATER DISPLACEMENT. 03:00 - 06:00 3.00 CEMT P RUNPRD SLIP AND CUT DRILLING LINE. 1 -PJSM FOR SLIP AND CUT. *SIM OPS:ORGANIZE TRUCKING FOR SEAWATER SWAP. 06:00 - 08:30 2.50 CEMT P RUNPRD DISPLACE WELL TO WELL TO 8.5 PPG SEAWATER. -345 GPM,880 PSI -NO ROTATION,RECIPROCATE PIPE 30' -PUMP 35 BBL 8.5 PPG HI VIS SPACER PILL 10 MIN FLOW CHECK-WELL STATIC Printed 1/6/2015 5:05'57PM North America-ALASKA-BP Page 6 of 12 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/20/2014 End Date:12/26/2014 X3-015RC-C:(3,362,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:OOAM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) p Phase Description of Operations Date From-To Hrs Task Code NPT NPT Depth ._ (hr) (usft) 08:30 - 12:00 3.50 CEMT P RUNPRD POOH ON ELEVATORS FROM 10,275'TO 7,553' MD -OFF BOTTOM PUW-198K,SOW-175K AT 10,275 MD. -MUD WEIGHT 8.5 PPG IN AND 8.5 PPG OUT. -LAY DOWN 1 4"DRILL PIPE SINGLE ADDED IN THE STRING AT LINER RUN. ',-RACK BACK DRILL PIPE IN DERRICK F/7,522' MD T/4,010'MD. PUW=115K,SOW=115K. *KICK WHILE TRIPPING DRILL-RESPONSE TIME:4 MIN 33 SECS. •OBTAIN SPR'S AT 10,275' ZERO BBL LOST FROM MIDNIGHT TO NOON. 12:00 - 12:30 0.50 CEMT P RUNPRD RIG SERVICE. -LUBRICATE AND INSPECT TOP DRIVE, BLOCKS,DRAW WORKS AND ST-80. 12:30 - 17:00 4.50 CEMT P ' RUNPRD POOH ON ELEVATORS FROM 7,553'TO 3,357' MD. -PUW=115K,SOW=115K. -MUD WEIGHT 8.5 PPG IN AND 8.5 PPG OUT. -LAY DOWN DRILL PIPE FROM 3,357'TO SURFACE. 17:00 - 17:30 0.50 CEMT P RUNPRD .BREAK DOWN PUP AND CROSSOVER FROM CEMENT HEAD. 17:30 - 19:00 1.50 CASING P RUNPRD 1 PRESSURE TEST 4-1/2"LINER. PJSM FOR HIGH PRESSURE OPERATIONS: DISCUSSED PRESSURE CROSS CHECK LIST -VERIFY LINE UP AND DISCUSS PRESSURE LIMITS. 1 PRESSURE TEST 4.5"LNR,LNR TOP PKR, AND 7"CSG -TEST T/250PSI LOW F/5MINS,3500PSI HIGH F/30MINS(GOOD TEST) -85 TOTAL STKS PUMPED=3650PSI,8BBLS 'BLED BACK, -CALL WTL F/APPROVAL(APPROVED T/ MOVE ON) -B/D KILL LINE SIM OPS:MAKE UP SHEAR JOINT FOR PERF GUN RUN 19:00 - 22:00 3.00 PERF P OTHCMP PICK UP SLB PERF GUNS AND HANDLING 1 EQUIPMENT TO RIG FLOOR. -HELD PJSM FOR PICKING UP PERF GUNS -DDI,SLB TCP,BP PRESENT -REVIEW DDI PROCEDURE AND SLB PROCEDURE FOR GUN HANDLING-LIMIT NON ESSENTIAL PERSONAL ON THE RIG FLOOR. -DISCUSS DROPS:ENSURE CORRECT LIFTING EQUIPMENT IS USED AND CORRECT I SIZES ARE VERIFIED BY COMPETENT PEOPLE -DISCUSS NON SHEARABLES-VERIFY CORRECT MAKE UP FOR SHEAR JOINT Printed 1/6/2015 5:05:57PM North America-ALASKA-BP Page 7 of 12 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/20/2014 End Date:12/26/2014 X3-015RC-C:(3,362,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22 00 - 00:00 2.00 i PERF P i OTHCMP RIH WITH PERF GUNS PER THE TCP RUN TALLY -RIH WITH GUNS AND BLANKS TO 325' -CHANGE ELEVATORS FROM 3-1/2"BOTTLE NECK TO 2-7/8"SLIP TYPE -MU TCP FIRING HEAD AND XO TO 2-7/8"HT • PAC RIH WITH GUNS ON 2-7/8"HT PAC FROM 325' TO 1,016'- CHANGE ELEVATORS BACK TO THE 3-1/2" BOTTLE NECK -TABLE TOP WELL CONTROL DRILL WITH PERF GUNS PICKED UP: •AAR:MORE ELABORATION ON THE SEQUENCE OF PICKING UP THE SHEAR JOINT IF NEEDED. -MONITOR TRIP ON TRIP TANK-CORRECT HOLE DISPLACEMENT OBSERVED • 12/23/2014 00:00 - 04:30 4.50 PERF P OTHCMP RIH MAKING UP GUNS AND BLANKS ON 2-7/8" PAC PIPE F/1016'TO 1,444' CREW CHANGE OUT. -HOLD ANOTHER PJSM WITH NEW DDI -CREW,SLB TCP,&BP -DISCUSS DROPS:ENSURE CORRECT LIFTING EQUIPMENT IS USED AND CORRECT • • SIZES ARE VERIFIED BY DRILLER. -DISCUSS NON SHEARABLES-VERIFY CORRECT MAKE UP FOR SHEAR JOINT -CHANGE ELEVATORS BACK TO THE 3-1/2" BOTTLE NECK -MAKE UP XO TO 2-7/8"HT PAC AND RIH ON 2-7/8"HT PAC F/1,444'TO 2,988' 1 -PUW=80K,SOW=85K. -CLEAR FLOOR OF CASING RUNNING TONGS. -MONITOR TRIP ON TRIP TANK-CORRECT HOLE DISPLACEMENT OBSERVED 04:30 - 11:30 7.00 PERF P OTHCMP RIH WITH GUNS ON 4"XT39 DP F/2,988'TO 13,336'MD • RIH ON ELEVATORS PICKING UP 4"DRILL PIPE STANDS. PU-89K,SOW=80K AT 3,020'MD. Printed 1/6/2015 5.05.57PM North America-ALASKA-BP Page 8 of 12 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/20/2014 End Date:12/26/2014 X3-015RC-C:(3,362,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 12:00 0.50 PERF P OTHCMP PERFORATE 4-1/2"LINER. -PJSM WITH SLB AND DDI PERSONNEL ON SETTING OFF THE PERFORATION GUNS. OBTAIN WORKING PARAMETERS,PUW= 210K,SOW=165K. CIRCULATE THROUGH DRILL PIPE TO PURGE AIR OUT OF SYSTEM. -SHUT IN ANNULAR PREVENTER. -CIRCULATE THROUGH CHOKE MANIFOLD TO FILL MUD GAS SEPERATOR. -PRESSURE UP ON DRILL STRING TO 1000 PSI PUMPING 210 GPM. -HOLD PRESSURE THEN BLEED OFF TO 100 PSI. REPEAT SEQUENCE OF PRESSURE/BLEED OFF 4 TIMES AND SET OFF PERFORATION I GUNS AS PER SLB REPS. I-MONITOR FLUID LOSS AS PERFORATING GUNS WENT OFF-IMMEDIATE 1/4 BBL LOSS WITH EACH PERFORATION INTERVAL. 12:00 - 13:30 1.50 PERF P OTHCMP POOH ON ELEVATORS WITH SLB GUNS Fl 13,339'MD T/11,628'MD. -PU=210K,SOW=165K AT 13,339'MD. FLOW CHECK-WELLTAKING 5-10 BPH. 13:30 - 15:30 2.00 PERF P OTHCMP CIRCULATE BOTTOMS UP ABOVE TOP PERFORATIONS. 5 BPM W/1040 PSI. -FLOW CHECK- WELL STATIC 15:30 - 23:00 7.50 I PERF P OTHCMP POOH ON ELEVATORS F/11,628'MD T/3,083' MD. -LAY DOWN DRILL PIPE TO PIPE SHED. -PU=200K,SOW=165K AT 11628'MD. -MONITOR WELL FOR 10 MINUTES-WELL STATIC. -MUD WEIGHT 8.5 PPG IN 8.5 PPG OUT. -OBTAIN SPR'S. *KICK WHILE TRIPPING DRILL. 23:00 - 23:30 0.50 PERF P OTHCMP RIH WITH 18 STANDS OF DRILL PIPE IN DERRICK. -RIH FROM 3,083'TO 4,792'. 23:30 - 00:00 0.50 PERF P OTHCMP POOH ON ELEVATORS FROM 4,792'TO 4,648'. '-LAY DOWN DRILL PIPE TO PIPE SHED. PU=100K,SOW=105K @ 4,648'. 12/24/2014 00:00 - 00:30 0.50 PERF P OTHCMP RIG SERVICE. -LUBRICATE AND INSPECT TOP DRIVE, BLOCKS,DRAW WORKS AND ST-80. 00:30 - 02:00 1.50 PERF P OTHCMP POOH 4"DRILL PIPE ON ELEVATORS FROM 4,348'TO 2,988". -LAY DOWN DRILL PIPE TO PIPE SHED. -MUD WT IN 8.5 PPG,MUD WT OUT 8.5 PPG. 02:00 - 03:00 1.00 PERF P OTHCMP RIG UP RIG FLOOR FOR 2-7/8"PIPE. -PJSM. -MOBILIZE TOOLS AND EQUIPMENT TO RIG FLOOR. 03:00 - 04:30 1.50 PERF P OTHCMP POOH WITH PERF GUN ASSEMBLY. -PJSM. -POOH 2 7/8"PAC PIPE ON ELEVATORS FROM 2,988'TO 1,970" Printed 1/6/2015 5:05:57PM North America-ALASKA-BP Page 9 of 12 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/20/2014 End Date:12/26/2014 X3-015RC-C:(3,362,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:O0AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 09:00 4.50 PERF P OTHCMP POOH AND LAY DOWN PERF GUNS. -PJSM. -MAKE ANNOUNCEMENTS AND CLEAR RIG FLOOR. -PULL LAST JOINT OF 2-7/8"PAC PIPE AND LAY DOWN TO PIPE SHED. -CHANGE OUT ELEVATORS AND SLIPS. -PULL AND LAY DOWN PERF GUNS AND 2-7/8" PAC PIPE FOR SPACE OUT. **ALL SHOTS FIRED ON PERF GUNS. 09:00 - 10:30 1.50 PERF P OTHCMP CLEAN AND CLEAR RIG FLOOR. -RIG DOWN TOOLS AND EQUIPMENT TO PULL PERF GUNS. -LAY DOWN SCHLUMBERGER TOOLS AND EQUIPMENT TO GROUND. -MOBILIZE TOOLS AND EQUIPMENT NEEDED TO RUN 4 1/2"COMPLETIONS TUBING TO RIG FLOOR. 10:30 - 11:00 0.50 WHSUR P RUNCMP PULL WEAR BUSHING. -PJSM BEFORE PULLING BUSHING. 111:00 - 12:00 1.00 RUNCOM I P RUNCMP FLUSH BOP STACK. -PJSM. -RIG UP STACK WASHER AND FLUSH BOP STACK AT 390 GPM WITH 100 RPM©30 PSI. -RIG DOWN STACK WASHER. *SIM-OPS-BRING UP REMAINING 4 1/2" COMPLETIONS HANDLING EQUIPMENT TO RIG FLOOR. 12:00 - 14:00 2.00 RUNCOM P RUNCMP RIG UP FOR RUNNING COMPLETIONS EQUIPMENT. -MAKE DUMMY RUN WITH HANGER WITH CAMERON REP-OK. -MARK DRILL PIPE USED FOR RUNNING HANGER. -MAKE UP PROPER CROSSOVER ON TOP OF ' SAFETY JOINT FOR LIFTING AND CROSSOVER ON BOTTOM OF FOSV. -RIG UP POWER TONGS AND TORQUE-TURN EQUIPMENT TO POWER TONGS. *COMPLETION PIPE COUNT VERIFIED BY DRILLER,WSL AND TOOL PUSHER. 14:00 - 00:00 10.00 RUNCOM P RUNCMP RUN TUBING AS PER TALLY AND PROGRAM. -PJSM. -RUN 4 1/2"12.6#13CR,VAMTOP TUBING WITH ALL ASSOCIATED JEWELRY AS PER PROGRAM AND TALLY. -RAN COMPLETIONS FROM SURFACE TO 6,623'. -USE TORQUE-TURN SERVICES ON ALL CONNECTIONS. -BAKER LOCK EVERY CONNECTION BELOW PACKER. -TORQUE ALL CONNECTION TO OPTIMUM I TORQUE OF 4,400 FT-LBS. -USE JET LUBE SEAL GUARD AS THREAD COMPOUND AND APPLY WITH MUSTACHE BRUSH. -PUW 130K,SOW 120K. *KICK WHILE TRIPPING DRILL TO ENSURE ALL EQUIPMENT READINESS. Printed 1/6/2015 5:05:57PM North America-ALASKA-BP Page 10 of 12 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/20/2014 End Date:12/26/2014 X3-015RC-C:(3,362,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase • Description of Operations (hr) (usft) 12/25/2014 00:00 - 00:30 0.50 RUNCOM P RUNCMP RIG SERVICE. -LUBRICATE AND INSPECT TOP DRIVE, BLOCKS,DRAW WORKS AND ST-80. 00:30 - 06:00 5.50 RUNCOM r P I RUNCMP RUN TUBING AS PER TALLY AND PROGRAM. -PJSM. -RUN 4 1/2"12.6#13CR,VAMTOP TUBING WITH ALL ASSOCIATED JEWELRY AS PER 'PROGRAM AND TALLY. -RAN COMPLETIONS FROM 6,623'TO 10,250" -USE TORQUE-TURN SERVICES ON ALL CONNECTIONS. -TORQUE ALL CONNECTION TO OPTIMUM TORQUE OF 4,400 FT-LBS. -USE JET LUBE SEAL GUARD AS THREAD COMPOUND AND APPLY WITH MUSTACHE BRUSH. -PUW 150K,SOW 138K. -SWAP OUT 3 JOINTS OF EQUAL LENGTH DUE TO POTENTIAL GALLING. MUD WT IN-8.5 PPG,MUD WT OUT-8.5 PPG **SECURED WELL WORK TRANSFER PERMIT •FOR Y-32A WITH PAD OPERATOR. DISCUSSED AND APPROVED PLACEMENT OF OPB,AND WSL OFFICE GREATER THAN 300' FROM BLAST ZONES. 06 00 - 09:00 3.00 RUNCOM P RUNCMP RIH AND LAND HANGER -OBTAIN PARAMETERS,PUW=163K,SOW= 140K. -RIH F/10,303'MD T/10,421'MD AND TAG UP •NO-GO. -CALCULATED SPACEOUT. -LAY DOWN 3 JOINTS OF TUBING. -MAKE UP SPACE OUT PUPS AND ONE FULL JOINT. - MAKE UP HANGER AND LANDING JOINT. -FINAL PUW=170K,SOW=140K(IN 8.5 PPG SEAWATER). RIH AND LAND HANGER. CAMERON REP RUN IN LOCK DOWN SCREWS. -REMOVE LANDING JOINT. •WLEG AT 10416.55'. '-DRILLER,WSL AND TOOL PUSHER VERIFIED AMOUNT OF PIPE LEFT OVER TO BE CORRECT. 09:00 - 11:00 2.00 RUNCOM P RUNCMP RIG UP TO TEST CHOKE SKID AND MUD LINES -250 PSI LOW AND 3500 PSI HIGH FOR 5 MINS EACH-TESTS GOOD. 11:00 - 14.30 3.50 RUNCOM P RUNCMP REVERSE CIRCULATE. -PJSM,CIRCULATE 160 BBLS 120 DEGREE 8.9 PPG BRINE. -168 GPM,630 PSI. -CHASE WITH 196 BBLS 8.9 BRINE WITH CORROSION INHIBITOR. -CHASE WITH 200 BBL OF 120 DEGREE 8.9 BRINE,4 BPM,350 PSI. Printed 1/6/2015 5:05:57PM North America-ALASKA-BP Page 11 of 12 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/20/2014 End Date:12/26/2014 X3-015RC-C:(3,362,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual @83.38usft(above Mean Sea Level) Date ! From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 17:00 2.50 RUNCOM P RUNCMP SET PACKER. -DROP ROLLER STEM ROD TO RHC-M PLUG. -PRESSURE TEST TUBING 250 PSI FOR 5 MINS-TEST GOOD. -PRESSURE UP TO 3560 AND AND SET PACKER,HOLD PRESSURE FOR 30 MINS FOR MIT TEST.TOOK 2.1 BBLS TO PRESSURE UP. -FIRST 15 MINUTE PRESSURE DROPPED TO 3,490 PSI(70 PSI DROP),SECOND 15 MINUTE PRESSURE DROPPED TO 3,480 PSI(10 PSI DROP).-GOOD TEST. PACKER STARTED TO SET AT 1930 PSI. -BLEED TUBING BACK TO 1800 PSI.BLEED BACK 1.0 BBLS PRESSURE UP ANNULUS 250 PSI FOR 5 MINS AND 3500 PSI FOR 30 MINS-TESTS GOOD.TOOK 5.4 BBLS TO PRESSURE UP. -SECURE APPROVAL TO GO WITH PLAN FORWARD FROM WTL ON CALL. -BLEED TUBING PRESSURE AND OBSERVED 'DCK VALVE SHEAR AT 3200 PSI DIFFERENTIAL.BLED OFF TUBING AND IA PRESSURE TO 0 PSI.BLEED BACK 6.3 BBLS (TOTAL OF 7.3 BBLS)BLED BACK. CIRCULATE 5 BBLS BOTH WAYS AT 5 BPM SUCCESSFULLY. *SEE ENCLOSED CHARTS FOR INFORMATION. 17:00 - 21:30 4.50 WHSUR P RUNCMP FREEZE PROTECT. -PJSM WITH LITTLE RED AND DDI PERSONNEL. -RIG UP TO FREEZE PROTECT. -PUMP 138 BBL 80 DEGREE DIESEL DOWN IA AT 2 BPM @ 600 PSI FINAL CIRCULATING PRESSURE. -U-TUBE FOR 1 HOUR. -FLOWCHECK WELL FOR 15 MINUTES—WELL STATIC. *WELL WAS STATIC FOR 1 HR DURING TESTING OF TUBING AND IA. 21:30 - 22:30 1.00 DHB P RUNCMP INSTALL TWO WAY CHECK VALVE. -PJSM. -DRAIN STACK. -RIG UP T-BAR AND INSTALL TWC. 22:30 - 00:00 1.50 DI-IB P RUNCMP TEST TWC FROM BELOW. -TEST TWC FROM BELOW WITH LRS •(DIESEL). -TEST TO 250 PSI LOW(5 MINUTES)/3500 PSI HIGH(30 MINUTES)-GOOD TEST. 12/26/2014 00:00 01:00 1.00 DHB P RUNCMP TEST TWC FROM BELOW WITH LRS. -PASSING TEST ACHIEVED. -BLEED DOWN TEST PRESSURE BACK TO LRS. 01:00 - 02:00 1.00 DHB P RUNCMP TEST TWC FROM ABOVE. -PJSM. -RIG UP TO TEST TWC FROM ABOVE. -TEST TWC FROM ABOVE TO 250 PSI LOW(5 MIN)/3500 PSI HIGH(30 MIN)-GOOD TEST ACHIEVED. -BLEED DOWN TEST PRESSURE. Printed 1/6/2015 5:05:57PM North America-ALASKA-BP Page 12 of 12 Operation Summary Report Common Well Name:Y-14 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/20/2014 End Date:12/26/2014 X3-015RC-C:(3,362,000.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 14 Spud Date/Time:9/20/1988 12:00:00AM Rig Release:12/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292183200 Active datum:Y-14C actual©83.38usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 03:30 1.50 BOPSUR P RUNCMP RIG DOWN LINES ON RIG FLOOR. -SUCK OUT BOP STACK. -BLOW DOWN CELLAR LINES. -BLOW DOWN CHOKE/KILL LINE,HOLE FILL ' I LINES. *SIM-OPS:DISCONNECT WARM UP SHACK AND MUD SHACK TO PREP FOR MOVING. 03:30 - 06:30 3.00 BOPSUR P RUNCMP CHANGE OUT UPPER RAMS. -PJSM. -REMOVE MOUSEHOLE/RISER AND FLOWLINE. , 1-CHANGE OUT UPPER RAMS FROM 3-1/2"X 6" VBR'S TO 7-5/8"FBR'S. 06:30 - 08:30 2.00 BOPSUR P RUNCMP NIPPLE DOWN BOP STACK. -PJSM. 08:30 - 09:00 0.50 WHSUR P RUNCMP MOBE TREE ADAPTER AND TREE INTO CELLAR. ' -PJSM. . -MOVE TREE AND ADAPTER INTO CELLAR. -CAMERON SERVICE HANDS INSPECTED HANGER-GOOD. 09:00 - 12:00 ' 3.00 WHSUR P RUNCMP NIPPLE UP TREE AND ADAPTER TO WELL. -PJSM. -NIPPLE UP TREE AND ADAPTER. -TEST HANGER VOID TO 250 PSI LOW(5 MINUTES),5000 PSI HIGH(30 MINUTES)-GOOD TEST. -SEE ATTACHED CHARTS. ' -TORQUE UP TREE STUDS TO PROPER ' TORQUE. 12:00 - 13:00 1.00 WHSUR P RUNCMP MAKE UP TREE CAP VALVES. -DUMP 2 CANS OF HEET INTO TREE. -FILL TREE WITH DIESEL. 13:00 - 15:00 2.00 WHSUR P RUNCMP TEST TREE WITH DIESEL. -PJSM. -TEST TREE WITH DIESEL TO 250 PSI LOW, 5000 PSI HIGH FOR 5 MINUTES EACH-GOOD TEST. -VOID TREE OF DIESEL. -ADD 4 BOTTLES OF HEET TO TREE. 15:00 - 17:00 2.00 WHSUR P RUNCMP SECURE WELL. -CLEAN CELLAR OF LOOSE ITEMS. -SECURE WELL. -FINAL PRESSURES:TUBING,IA,OA.-O/O/O PSI. **RELEASE RIG FROM Y-14C AT 17:00 HRS 12/26/1024. Printed 1/6/2015 5:05:57PM $ m Oaa . m O $ pp n V Nmq MM. 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SEAN i \RNLI Anchoray eAlaska 99501 3572 Moan 902 279 i 4 i3 F. Ken Allen Engineering Team Leader BP Exploration (Alaska), Inc. Post Office Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y-14C BP Exploration (Alaska), Inc. Permit No: 214-120 Surface Location: 492' FNL, 706' FWL, Sec. 34, T11N, R13E, UM Bottomhole Location: 5013' FNL, 2552' FEL, Sec. 33, T11N, R13E, UM Dear Mr. Allen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, P;)..{_.,4 4,-,-- Cathy P oerster Chair DATED this � day of August, 2014. ,-,:,)t. ],':_:- f-, �. `A y'd k D STATE OF ALASKA ALA: OIL AND GAS CONSERVATION COMM, DN Ali(; 1 1 2014 PERMIT TO DRILL 20 AAC 25.005 A GCC 1 a.Type of work: 1 b.Proposed Well Class: ®Development Oil 0 Service-Winj ®Single Zone • 1 c.Specify if well is proposed for: 0 Drill 0 Lateral 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas ❑Gas Hydrates • ®Redrill 0 Reentry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Geothermal 0 Shale Gas 2 Operator Name: 5.Bond ®Blanket 0 Single Well 11.Well Name and Number: BP Exploration(Alaska) Inc. Bond No 6194193 . PBU Y-14C • 3 Address 6.Proposed Depth. 12.Field/Pool(s) P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 13558'• ND 9001' - Prudhoe Bay/Prudhoe Bay . 4a.Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: ADL 028287 • 492'FNL, 706'FWL, Sec. 34,T11N, R13E, UM Top of Productive Horizon: 8. Land Use Permit. 13.Approximate Spud Date: 3967' FNL, 765' FEL, Sec.33,T11N, R13E, UM October 15,2014 - Total Depth 9 Acres in Property: 14.Distance to Nearest Property: 5013' FNL,2552' FEL, Sec.33,T11N, R13E, UM 2560 11225' - 4b Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 84' • feet 15.Distance to Nearest Well Open Surface. x 645503 • y-5949777 • Zone- ASP4 GL Elevation above MSL• 49.6' - feet to Same Pool• 400' ' 16 Deviated Wells: Kickoff Depth: 6000' feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle. 97 degrees. Downhole: 3883 ' Surface: 3004 ' 18. Casing Program Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 8-1/2" 7" 26# L-80 VT-HC 4940' 5850' 5603' 10790' 8874' 244 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 VamTop 2918' 10640' 8757' 13558' 9001' 367 sx Class'G' 19 PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft). Total Depth ND(ft): Plugs(measured). Effective Depth MD(ft): Effective Depth ND(ft). Junk(measured) 12171' 9038' 9052' 12171' 9038' None Casing Length Size Cement Volume MD ND Conductor/Structural 80' 20" 8 cu yds Concrete 34'- 114' 34'- 114' Surface 2654' 13-3/8" 3723 cu ft Arcticset II and III 38'-2692' 38'-2691' Intermediate 9387' 9-5/8" 2116 cu ft Class'G' 34'-9421' 34'-8325' Production • Liner 1298' 7" 298 cu ft Class'G' 9243'- 10541' 8181'-8979' Liner 893' 4-1/2" Uncemented Slotted Liner 10398'- 11291' 8964'-9000' Perforation Depth MD(ft): off 11300_121798•/Sitd Liner 10532•-11276'i Perforation Depth ND(ft): off 9000 9039 I Sltd Liner 8979'-9000 i 20.Attachments. 0 Property Plat ® BOP Sketch IN Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report ®Drilling Fluid Program 1E20 AAC 25.050 Requirements 21. Verbal Approval. Commission Representative: Date 22.I hereby certify that the foregoing is true and correct: Contact John Rose,564-5271 Printed Name Ken Allen Title Engineering Team Leader Email John.G.Rose@bp com Signature //-------c — Phone 564-4366 Date F/yd 9 Commission Use Only Permit To Drill / API Number. Permit App v l Drate: // See cover letter for Number: �/ �/ 50-029-21832-03-00 �' V I J)`T other requirements: Conditions of Approval. If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas El' Other: 06 p 7'051 3 5U rJ c 5 contained shales: • Samples Req'd ❑Yes g(No Mud Log Req'd: Oyes �No H2S Measures: ©Yes D No Directional Survey Req'd: g Yes 0 No Spacing exception req'd: 0 Yes LQ No inclination-only svy Req'd ❑Yes 13/No P APPROVED BY Q.�/ /(� APPROVED BY 9111-1/2/4---‘—.COMMISSIONER THE COMMISSION Date lJ C ( Form 10-401 Revised 10/20 This ive morEfrom the date of approval(20 AAC 25.0 5(g) Submit Form and Attachments In Duplicate VGA //3//4 ' ` Y//z-/fir, ,SJ 9 ,e- •/Y l N. . • 470 To: Alaska Oil & Gas Conservation Commission From: John Rose, ODE Date: August 7, 2014 Re: Y-14C RST Permit to Drill Doyon 14 is currently scheduled to move to the Y-14C RST in late October of this year to drill an Ivishak Zone 4 producer. This RST includes a significant amount of de-completion work prior to moving forward with the planned 2 — string sidetrack of the well which includes an 8-1/2" hole to the TSGR casing point with a 7" drilling liner and then a 6-1/8" production hole to drill the planned Z4 target sands. With the well TD'ed. a 4-1/2" chrome production liner will be run and cemented and perforated prior to running a 4-1/2" chrome upper completion. The maximum anticipated surface pressure from the Sag/Ivishak with a full column of gas from TD to • surface is 3004 psi (assumes 8.5 ppg as the max pore pressure in the Sag). This well will be drilled using a 5000 psi four preventer BOP stack (3 rams and an annular). The BOP and annular will be tested to 3500 psi. While a detailed operations summary is included with the permit application, please note a brief well summary as indicated below: Rig Operations: 1. MIRU /confirm barriers. 2. ND tree. NU BOPE and test to 250 psi low/3500 psi high. 3. Pull the 4-1/2" tubing from the pre-rig cut. 4. RU e-line and run USIT/CCL/GR. 5. Set CIBP at—6025' MD and test to 3500 psi. 6. Cut and pull the 9-5/8" casing from above TOC and tie-back and cement to surface. 7. NU BOP and test breaks to 3500 psi. 8. MU clean-out BHA and clean-out well to CIBP at 6025' MD. 9. Run 9-5/8" whipstock. (End of Sundry/Beginning of PTD) 10. Mill window in 9-5/8" casing for sidetrack well at—6000' MD plus 20' of new hole and run LOT. 11. MU & RIH with 8-1/2" BHA and drill to the 7" casing point at TSGR. • 12. Run and cement a 7" drilling liner. 13. MU a 6-1/8" BHA and drill the well to the planned well TD. 14. Run and cement a 4-1/2" production liner. 15. Perforate the well on drillpipe. 16. Run a 4-1/2" completion. 17. Secure the well. 18. RDMO well. Post-Rig Work: 1. Pull TWC. 2. Pull ball and rod / RHC plug. 3. Install generic GLM design. 4. Install wellhouse and instrumentation and flowline. 5. Flow-back to separator if needed. 6. Perform negative test on 7" liner top. In addition to a planned well summary, a directional plan and proposed completion diagram is attached to this permit application. If there are any questions concerning the information on this proposed well, please do not hesitate to use the contact information below: Y-14C Page 1 8/7/2014 John Rose Office - 564-5271 Cell - 748-5223 Email - rose11( bp.com Attachments: Well Schematic Directional Plan BOPE Schematic • Y-14C Page 2 8/7/2014 Planned Well Summary Well Y-14C Well Ivishak Target Ivishak Type Producer Objective Z4 " Current Status Rotary Sidetrack Estimated Start Date: 10/15/2014 - Time to Complete: 36 Days Surface Northing Easting Offsets TRS Location 5949777 • 645503 ' 492' FNL /4573' FEL • 11N 13E sec 34 Northing Easting TVDss Offsets TRS KOP 5948832 645423 -5632' 1431' FNL /4672' FEL 11N 13E sec 34 TSGR 5946275 644106 -8786' 3967' FNL / 765' FEL 11N 13E sec 33 BHL 5945194 642341 -8917' 5014' FNL / 2552' FEL 11N 13E sec 33 Planned KOP: 6000' MD/-5627' TVDss • Planned TD: 13,558' MD / -8917' TVDss - Rig: Doyon 14 BF-RT: 34.3 RTE (ref MSI-): 83.9 Directional — Schlumberger P6 KOP: 6000' MD Maximum Hole Angle: -64° in the 8-1/2" intermediate hole -97° in the 6-1/8" production section . Close Approach Wells: Y-11 fails major risk analysis at 12,636' and will be minor risked to allow drill-by. Survey Program: 6000'-6350' inc+trend 6350'- 10,780' MWD+IFR+MS-WOCA 10,780'- 13,558' MWD+IFR+MS-WOCA Nearest Property Line: 11,225 ft • Nearest Well within Pool: 400 ft • Y-14C Page 3 8/6/2014 Formation Tops & Pore Pressure Estimate (SOR) Estimated Minimum Most Likely Maximum Depth Fluid ' GS•{• f hik- Formation Formation Top Pore Pressure Pore Pressure Pore Pressure Uncertainty Type Cre..�( (TVDss) (EMW ppg) (EMW PPM (EMW ppg) (+I-TVD ft) (for sands) ��// UG4 4,021 8.35 8.45 8.70 n/a water UG4A 4,059 8.35 8.45 . 8.70 n/a water UG3 4,318 8.35 9.30 9.50 n/a water � � UG1 4,734 8.35 9.30 9.50 n/a water WS2 5,367 8.35 8.45 9.00 n/a water WS1 5,593 8.35 8.45 9.00 n/a water CM3 5,760 8.35 8.70 9.10 25 water �,} CM2 6,259 8.35 9.00 9.70 V 50 water 9 3 (,i s..".. CM1 7,019 8.35 9.70 - 10.50 ✓ 50 water /Q.3 THRZ 7,348 9.60 9.70 10.50 ,i 50 water LCU 7,575 9.60 9.70 9.90 50 water TJF 7,974 9.60 9.70 9.90 25 water TJE 8,071 9.60 9.70 9.90 25 water TJD 8,380 9.60 9.70 9.90 25 water TJC 8,511 9.60 9.70 9.90 25 water TJB 8,630 9.60 9.70 9.90 25 water /0. TJA 8,705 9.60 9.70 9.90 25 water TSGR 8,786 6.70 8.50 - 9.00 -/ 25 oiUw ater 8-©- TSHU 8,816 6.72 7.30 9.00 . 25 oiUw ater TSAD 8,898 6.72 7.30 9.00 25 oiVwater TSAD 8,920 6.72 7.30 9.00 25 oiVwater 45N 8,928 6.72 7.30 9.00 25 oiVwater 45P 8,931 6.72 7.30 9.00 25 oiUw ater FAULT 1 8,935 6.72 7.30 9.00 25 oiVwater 45N 8,947 6.72 7.30 9.00 25 oiVwater 45N 8,948 6.72 7.30 9.00 25 oiVwater 45P 8,949 6.72 7.30 9.00 25 oiVwater 45N 8,952 6.72 7.30 9.00 25 oiVwater 45P 8,952 6.72 7.30 9.00 25 oiVwater 9- O 45P 8,957 6.72 7.30 9.00 25 oiVw aterr 6¢-/t• "y Y-14C Page 4 8/6/2014 Casing/Tubing Program Hole Casing / Wt/Ft Grade Conn Length Top (ft) Bottom (ft) Size Tbg O.D. (ft) MD/TVDss MD/TVDss 8-1/2" 7" 26# L-80 VT-HC 4940 5850/5516 10,790/8790 6-1/8" 41/2" 12.6# 13Cr-85 VamTop 2918 10,640/8672 13,558/8917 Tubing 41/2" 12.6# 13Cr-85 VamTop 10,645 Surface 10,645/8677 Mud Program Intermediate Mud Properties: LSND 8-1/2" hole section Depth Interval Density PV YP API FL HTHP FL MBT pH (PPg) 6000 (T — 93-9.5 - 10 - 15 18 -25 <8 cc's NC <20 8.5 - 9.5 8537' (TCM M1)1) 8537' (TCM 1)— 10.3 15 -20 18 -25 4-6 cc's <10 cc at <20 8.5 - 9.5 10,790' MD (TSGR) 200 deg F. Production Mud Properties: Water Based Polymer DIF 6-1/8" hole section Density PV YP Low Shear Depth Interval (PPM (cp) (Ib/100ft2) API FL Rate MBT pH Viscosity 8.8—9.0 - 10,790' — 13,558' (as required <8 12 - 18 <12 15000-30000 <4 8.5 - 9.5 for Sag PP) Logging Program 8-1/2" Intermediate: Sample Catchers—as required by Geology Drilling Dir/GR/Res/PWD Open Hole: None Cased Hole: None 6-'/8" Production: Sample Catchers—as required by Geology Drilling: Dir/GR/Res/Neu/Den Open Hole: None Cased Hole: None Y-14C Page 5 8/6/2014 Cement Program Casing Size 7" 26#, L-80 Intermediate Casing Basis: Lead: N/A Lead TOC: N/A Tail: Open hole volume + 40% excess + 80 ft shoe track Tail TOC: 1,500' MD above casing shoe Total Cement Lead N/A Volume: Tail 51 bbls, 283 cuft, 244 sks of 15.8 ppg Class G, Yield: 1.17 ft3/sk Casing Size 4.5" 12.6#, 13Cr-85 Production Liner Basis: Lead: N/A Lead TOC: N/A Tail: Open hole volume + 40% excess + 80 ft shoe track Tail TOC: TOL Total Cement Lead N/A Volume: Tail 76 bbls, 426 cuft, 367 sks of 15.8 ppg Class G, Yield: 1.17 ft3/sk Surface and Anti-Collision Issues Surface: As this well is at the eastern end of the northern well row on Y-Pad, the only adjacent well is the Y- 36 well which is -34' to the west, therefore, as the Y-36 wellhouse lies "outside" of the D-14 footprint there should be no shut-in requirements to move onto this well. (NOTE: D-14 rig personnel must confirm their ability to move onto the Y-14 location with the wellhouse in place on the Y-34 well.) Sub-Surface: Y-11 fails major risk analysis at 12,636'. As this well is currently P&A'ed below the Y-11A and Y-11 B sidetracks, it will be minor risked to allow drill-by. Hydrogen Sulfide Y-Pad is considered an H25 site. Recent H2S data from the pad is as follows: Well Name H2S Level Reading Date Comments Parent Well(if sidetrack) Y-14B 22 ppm 2/24/2014 #1 Closest SHL Well H2S Level Y-36 40 ppm 3/8/2014 #2 Closest SHL Well H2S Level Y-15A 22 ppm 6/21/2011 #1 Closest BHL Well H2S Level Y-21A 135 ppm 3/21/2014 #2 Closest BHL Well H2S Level Y-13A 18 ppm 3/12/2014 #3 Closest BHL Well H2S Level Y-09 18 ppm 7/14/2014 #4 Closest BHL Well H2S Level Y-34A 35 ppm 5/15/2007 Y-33 tested at 160 Max.Recorded H2S on Pad/Facility Y-33 350 ppm 2/23/2011 ppm on 9/4/09.Y 33A tested at 10 ppm 1/20/14 Other Relevant 1-12S Data Y-10B is on MI currently (MI-120 ppm). (H2S alarms from rigs,etc.) Faults Formation Where Encounter Fault MD Intersect TVDss Intersect Throw Direction Uncertainty Lost Circ and Magnitude Potential Fault#1 CM2 7,220.0 -6,285.0 South 20 ft. +/-250 ft. Medium Fault#2 CM2 8,080.0 -6,798.0 North 15 ft. +/-250 ft. Medium Fault#3 Ivishak 12,020.0 -8,936.0 Down West 10 ft +/-250 ft. Low Y-14C Page 6 8/7/2014 Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject - at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal /Contact the GPB Environmental Advisors (659-5893) for guidance. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are 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 during drilling phase and 7 days during sundry operations. 8-1/2" Intermediate Interval Maximum anticipated BHP 3883 psi at @ TSGR at 8786' TVDss (8.5 ppg EMW) " Maximum surface pressure 3004 psi (.10 psi/ft gas gradient to surface) Kick tolerance 25 bbls with 11.4 ppg frac gradient (50 bbls with 12.0 ppg frac gradient) Assumes 10.3 ppg swab kick at TSGR with a 10.3 ppg MW. Planned BOP test pressure Rams test to 3,500 psi/250 psi Annular test to 3,500 psi/250 psi Integrity Test—8-1/2" hole LOT after drilling 20'-50' of new formation below previous shoe 7" Liner Test 3500 psi surface pressure 6-1/8" Production Interval Maximum anticipated BHP 3883 psi at @ TSGR at 8786' TVDss (8.5 ppg EMW) - Maximum surface pressure 3004 psi (.10 psi/ft gas gradient to surface) Infinite with >9.2 ppg frac gradient Kick tolerance Assumes an 8.8 ppg swab kick in the Sag with an 8.8 ppg MW. Planned BOP test pressure Rams test to 3,500 psi/250 psi Annular test to 3,500 psi/250 psi Inte•rity Test—6-1/8" hole FIT after drilling 20'-50' of new hole, target >10 ppg FIT 4-1/2" Liner Test 3500 psi surface pressure Planned completion fluids Sufficient completion fluid density to provide a minimum of 50 psi over- balance with a 6.8 ppg diesel cap to —2100' MD. Y-14C Page 7 8/6/2014 • • RIC FLOOR 33 7'ACL VALVE LEGEND . 2IOU -� I ■ 3 CHOKE 4 20RdJ WAIS 1 I. S D RAYS m. RIND T(P ARE NOMS ACCJMUATOR: 4L SNAFTFR.180 COL.5 STATION R 6146;17R TRIM rx qmR ,VACw HP I �\L SWFFER I -- (- I, , iiiillililr-vzi norm .., . .r )CCUWJJATOR NA41F1' t:><' 4-4 18 BOTTLES.'0 C6LL0N5 EARH �:,4.+al BCP agg ELEM21 I , .TNnt M-i.\Ilf / 4, \ � NI.00EN MGM,6017 r5 I.�/irfFi��(' — m — .- SR°:a' T.,t :'7a.2':^,".:,;'•e �, ._� FST Ceffl'. T": ,w' Y-14C OPERATIONS SUMMARY Pre-Rig Work: 1. Perform a cement P&A of existing production hole by pumping/squeezing a volume of cement equal to the hole volume from the current well TD at 12,171' MD to a minimum of 100' above the top in the well at perf at 10,168' MD (-40 bbls cement / will pressure test the cement plug to 2250 psi to confirm P&A (7" shoe at 8984' TVD)). 2. Tubing punch at 9000' MD and circulate out the IA with seawater. 3. Full-bore DPZ isolation cement plug from 8000' MD to 9000' MD (both side of tubing / —70 bbls cement) leaving seawater and a 2000' diesel cap in well (on both sides of the tubing). 4. Cut tubing at 6500' MD. 5. CMIT-TxIA to 3500 psi, PPPOT-IC to 3500 psi and PPPOT-T to 5000 psi. 6. Function LDS. 7. Install TWC and test to 3500 psi from above/below. 8. Configure annular valves and install DHT. 9. Remove well house. 10. Level the pad and prepare location for rig move. Rig Operations: 1. MI/RU/confirm barriers (CMIT-TxIA to 3500 psi). 2. Nipple down tree. Nipple up BOPE and test to 250 psi low/3500 psi high (9-5/8" rams in upper cavity and 2-7/8" x 5-1/2"VBR's in the lower ram cavity). 3. RU and pull the 4-1/2" 12.6#tubing from the pre-rig jet cut at—6500' MD. 4. PU 8-1/211 clean-out assembly and RIH to clean-out 9-5/8" casing to top tubing stub. 5. RU E-line and RIH w USIT/ CCL/GR and log from the tubing stub to surface to determine: a. KOP shale. b. Cement behind casing at KOP. c. TOC behind the 9-5/8" casing in the OA(est. TOC —2200' MD). d. Casing collar locations. 6. RU E-line and set CIBP at—6025' MD and test to 3500 psi. 7. MU a Baker 9-%" multi-string cutting assembly. Cut the 9-%" casing above the TOC as determined from USIT log. Establish circulation up the OA and pump a casing wash sequence designed to displace the arctic pack and to clean the annulus (OA). POOH, L/D assembly. 8. MU casing spear assembly, BOLDS and unseat the 9-%". 9. Pull the 9-%" casing from the cut. 10. At next BOP test, change the 9-5/8" rams to 7" rams in the upper ram cavity and test to 250 psi low/ 3500 psi high. Y-14C Page 8 8/7/2014 11. RIH with casing scraper and clean-out the 13-%" casing and dress off the 9-%" casing stub. 12. Run new gas-tight 9-5/8", 47#, Hydril 563 casing w/Bowen patch, ECP and ES-cementer. Land patch over the 9-5/8" stub and pull 100K over string wt and fully cement the 9-5/8" casing in place per the wellplan. 13. Continue to hold the 100k over-pull on the 9-5/8" casing until the cement reaches sufficient compressive strength. 14. Split the stack above the casing spool and set the casing on slips. 15. Make Wach's cut the 9-5/8" casing / LD excess casing. 16. Install packoff and NU wellhead to include new tubing spool. 17. Test packoff. 18. NU BOP on the new wellhead and test breaks to 3500 psi. 19. MU clean-out 8-1/2" BHA and drill-out ES Cementer and cleanout to the 9-5/8" CIBP at 6025' MD and test the well to 3500 psi. 20. PU and RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly and 8-1/2" window milling assembly (to include full gauge string mills). RIH to the top-,o#,the CIBP. Orient and set the whipstock. Shear-off the whipstock and displace the well to a x.x ppg LSND milling fluid. 21. Mill a window in the 9-5/8" casing at -6000' MD' to 6016' MDQ'°plus 20' of formation from mid-window. 22. PU into 9-5/8" casing. Perform a FIT. POOH for drilling BHA. 23. MU & RIH with 8-1/2" BHA and PDC bit plus DIR/GR/RES/PWD and drill to the TSAG TD. - 24. Circulate and condition the hole prior to TOH to run a 7" drilling casing. 25. Install 7" rams in upper ram cavity IF not already installed. 26. Run a 7", 26#, L-80 intermediate liner and cement to -1500' MD above the top of the 7" shoe (15.8 ppg class G cement). 27. Change out 7" rams to 2-7/8" x 5-1/2"VBR's and test to 250 psi / 3,500 psi. 28. MU a 6-1/8" RSS BHA with DIR/GR/RES/Den/Neu with a PDC bit and RIH to the 7" landing collar and test the well to 3500 psi (cement to have reached 500 psi compressive strength). 29. Displace well to the planned 8.8 ppg DIF (mud weight to be a minimum of 150 psi over the most likely pore pressure for the Sag currently estimated to be 8.5 ppg) and run negative test on the 7" liner top (30 minute test- no flow). 30. Drill out the 7" shoe plus 20' of formation. Pull into the 7" shoe and perform an FIT. 31. Drill the 6-'/8" production interval as per directional plan to TD. 32. Circulate hole clean, short trip as needed/MAD Pass where required. POOH. 33. MU and RIH to bottom with a 4-1/2", 12.6# liner from TD to 150' liner lap inside the 7" shoe. 34. Fully cement the liner to the TOL with 15.8 ppg Class G Latex cement (bump plug with 9.2 ppg brine perf pill inside the 4-1/2" liner). 35. Set liner top packer and displace well to 9.2 ppg above the liner top (target 50 psi over-balance after freeze protecting well with 6.8 ppg diesel to -2000' TVD). 36. After liner cement reaches 500 psi compressive strength, pressure test the liner/well to 3,500 psi for 30 minutes. 37. RU DPC perf guns, RIH and perforate (cement to have reached a compressive strength of 1000 psi). 38. RU and run 4-1/2", 12.6#, 13CR-85 Vam-Top completion. 39. Space out and make up tubing hanger. 40. Land the tubing hanger, and run in lock down screws. 41. Reverse circulate the well to 9.2 brine surface to surface w/corrosion inhibitor in annulus above the packer (brine density designed to provide a minimum of 50 psi over-balance after freeze protecting the well to -2000' TVD with diesel). 42. Drop ball and rod and set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes (shear the shear valve in upper GLM). 43. Freeze protect the tubing and IA to -2000 TVD with diesel. 44. Set a TWC. 45. ND the BOPE. NU the tree and test to 5,000 psi. 46. Secure the well / RDMO. Post-Riq Work: 1. Pull BPV 2. MIRU slickline. Pull the ball and rod / RHC plug. Install generic GLM design 3. Install well-house and instrumentation and flowline. 4. Perform negative test on the 7" liner top. Y-14C Page 9 8/6/2014 Y-14C Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: A. Intermediate Hole: PP at KOP in WS1 at 8.45 ppg, however, cretaceous injection pressure to 9.3 ppg at top UG3 (while should be isolated with cement job on the existing 9-5/8" casing, will KO with miniuimum 9.3 ppg mud weight). PP to 9.7 ppg at top CM1 (planned weight-up to 10.3 ppg by TCM1).,. B. Production Hole: The pore pressure in the production interval is 7.3 ppg through the Ivishak, however, the highest anticipated pore pressure is 8.5 ppg which is associated with the possible injection pressure into the Sag from the Y-10Bi well. This interval will be drilled with a minimum of 150 psi over-balance utilizing a solids-free DIF (-8.8 ppg mud). II. Lost Circulation/Breathing A. Intermediate Hole: Breathing and/or lost circulation associated with excessive circulating pressures should be considered a possibility on this well. B. Production Hole: Breathing and/or lost circulation is a risk with the single anticipated fault crossing in this interval of the well. If lost circulation becomes a problem, follow the LCM decision tree provided in the drilling program. Utilize good hole cleaning practices to avoid high ECD and prevent pack-off potential which could induce losses. III. Integrity Testing Test Point Test Depth Test type EMW(lb/gal) 9-5/8"Window 20'-50'from the 9-5/8"Window LOT 11.4 ppg minimum(25 bbls) 12.0 ppg target(50 bbls) 7"shoe 20'-50'from the 7"shoe FIT 9.2 ppg minimum(infinite) IV. Hydrogen Sulfide (H2S) A. Y-Pad is not considered an H25 site. Recent H25 data from the pad is as follows: Well Name H2S Level Reading Date Comments Parent Well(if sidetrack) Y-14B 22 ppm 2/24/2014 #1 Closest SHL Well H2S Level Y-36 40 ppm 3/8/2014 #2 Closest SHL Well H2S Level Y-15A 22 ppm 6/21/2011 #1 Closest BHL Well H2S Level Y-21A 135 ppm ✓ 3/21/2014 #2 Closest BHL Well H2S Level Y-13A 18 ppm 3/12/2014 #3 Closest BHL Well H2S Level Y-09 18 ppm 7/14/2014 #4 Closest BHL Well H2S Level Y-34A 35 ppm 5/15/2007 Y-33 tested at 160 Max.Recorded H2S on Pad/Facility Y-33 350 ppm 2/23/2011 ppm on 9/4/09.Y 33A tested at 10 ppm 1/20/14 Other Relevant H2S Data Y-10B is on MI currently(MI—120 ppm). (H2S alarms from rigs,etc.) V. Faults Formation Where Encounter Fault MD Intersect TVDss Intersect Throw Direction Uncertainty Lost Circ and Magnitude Potential Fault#1 CM2 7.210.0 -6,285.0 South 20 ft. +/-250 ft. Medium Fault#2 CM2 8,080.0 -6,798.0 North 15 ft. +/-250 ft. Medium VI. Anti-Collision Issues Y-11 fails major risk analysis at 12,636'. As this well is currently P&A'ed below the Y-11A and Y-11B sidetracks, it will be minor risked to allow drill-by. CONSULT THE Y-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. Y-14C Page 10 8/6/2014 TREE= 4.1/W OW Decomp PLAN WE LFEAD= )CEVOYY_1 4C Y NOTES:WELL ANGLE>70'@ 19319'. ACTLYIICH= AXEL'• URAL KB.ELE 79.8 NOTE: Will cut&pull 9-5/8"casing from BF ELEv- 50.6' casing leak at 79"MD` -2200' MD(TOC in OA)and tie-back with KOP= -- 4250' (now cemented) Bowen patch, ECP and ES-Cementer and Max Anol . 9tre 11377' fully cement the OA to surface with the full tum D 6800'-.-Folie Fully cemented OA DaTV Datum TVD 9-5/8"casing stung above the CIBP"hung* Da Current OA TOC at•2200'MD — 'rl' in the existing casing spool and tested to 3500 psi 1._...13-319'CSG.729,L-60,..6)-12 347' ' ----•*` TOC at-4850'MDQ —Planned ST window at-6000-6016'MD Tubing cut at 6500'M a r ' _9-5/8"CIBP at-6025' MD(base whipstock) Minimum ID=2.37"I§9091' — 4-1/2" BKR KB STRADDLE PKR * !*` ' : ---- 1000'cmt plug f/8000'-9000`MD r � .-M Tubing punch at 9000'MD L3-1/2"TBG,9.38,L-80,.0087 W,10.2.9/2" TI I 9961' 1--I4-1/2'8AKER 100 S114ADCLE FIOZ,O.2.3T 9-518'x r BK12 LMR TOPEKA,D=6.31'H 9243' I 9-sal-X7'FIKRIhRHANGER,ID=8.31-H 9258' l w �� B' 95/ kSG GtLOW',19DOW 9416'-9466' (SEMEN MEL) 9-519'CSG,47$,L-60,13=8.861' 9418' / --- --- , 110025 4-12"HES X RR ID=3.81 r r -112"BKR KB STRADDLE PKR J L 9993° --------"7;/101, Q' '• 16588' 7'X 412'BKR S 3 FUR.D=3 875" I i►i `� 10068' H4-122'HES xPF°D=3.a13'� TOC at 100' above top pert at i 144►;: 10,168' MD to-10,068' MD is4444 ♦/►i 10001' 42"F $XNNP,WEEDTOISO'D I 4 4441, TOP OF 7"L t'R8007' M 111► 'I -.1111►��1� 10 92' 4-102180,12.68-L40_015260,D=3.958', .....:" 1008"' ,44-MYWLEG,D=3-95WI FE FORADON SL99MRY 111411. NFII1� REF LOG BnAUGR(MIMI 102745 * .044.4.1.• I 10868' HO.MD TT LOGGED 03/16196 I .11..111 MIME ATTOP PERE:53°010168 ft' • 11 04•1 i( //►411 . f 10398' !-12X4-1/2 1PNSSPKRO=3.923' NIM:RNer b Reduction OB for historical part dais 11111►1111111 S� SPF M6TVAL OprYSgt SHOT SOZ '(9 54111►1411111 •a •' `: 10410' H4-12'PORI®.R,D=3.91F] 3-34- 6 10168-10198 0 03/15/96 r 4444/414411 4 41444 ;- e 4-1/7 SLED 10532-11276 0 11x1/95 411111.141411 •,:-. 10632' H TOP Cie 4-12'3Lo1 f®LNR I 3.3,4' OH 11300 12171 0 08101 .41:L4i41 •6101' 10641• H r LIIR 298,1-80,o=tier I I 414111m i:, y �111111 ID \--I 1;4.441� 4F•° 10820' H'4-112MLASJT,O=3.08'I r 9.5/6"CSC.47N,L-90,O=8.e81' H 1658? I / .4 1.11► • .' 4-1/2'SLOTTED LNZ DETAL '• 10811' IH 0TC ECP,D=3.96" I 10532'-10614' SLOTTED) * 10849'-10769 Si OTTED - • ' 114' -1TNNorcoSUB, 6136' 10 -11151 SLOT1F3) 16ML 83T03.60'D 11158-11276' SLOT-SD \t• S`, 9 A I4-1)2'SLOTTED LNR 1268.1-60..0152 bpf.D=3 83• 1-I 11278' I ,� 4-11?LN2SHOE,12.68.L-80.13=393' I I 11300' I • 8-"�1r'`'=^°1/11 12171' H 3.75'CPB*HDLE BAREFOOT 101--"-'7' DAM REV BY' (-88114TS DATE REV BY GOISENTS RUDI43EBAY LMT 101071961, Q11E4. ORICQ4AL COMPLETION 0924/04 KCF1TLp K)3 STRAD 1 3-1/7113G WELL V 148 11101/96` LIN DER SIDETRACK 01-14A) 04/07/14 DLW/J043 GLV G0(03/28114) F67981 No'2011010 0807101 CI81(AK CTD TOE OUT DRILL (Y-141) 06/23/14 .Xr1'JRO41/2'VIFDYIIRP(06/21/14) - AR No 50.029.21632-02 II 04/22/01 116W TONS 07/28/14 JCR propose Deca t:4Mon SBC 34,T1 IN,RITE 492 FPL&706'(-WL 11/17/03 11LH OOMkENTCORRECT(Y-14B) — -� 07/24/04 LOKIKAIt'SET0101 KB STRADDIFFKR BP Exploration(Alas kal Y-14C Page 11 8/6/2014 1'414'1 L I-FAD 1.17V OY Y-14C SAFETY NO TES-YY,t: AN.... ACTUATOR PROPOSAL MAXDOGLEG:-13'ra-10809'"*" 10KB 111V= MR, r) r _ RF Fl.EV 50&, II 1 -:::201-30--I--El-7• 1 OP 4250'1 _ 20"CONDUCTOR, 110" .tyg Are- - _II, :c..m1AD= 10178' -2150 ---lq vtvmt;--,:::,kAAA-Nt k-,-i 1 ID= • 0 — . • -2190 .1-49-5/8-HES EXT CSG PO4] 5/F CSG,470,L-80 HY 0563.D=8 asr H --2200 I ..._ -2200' ST ID 'ND GEV TYPE VLV LATCH PORT CATE 19-5.0r BOWEN CSO PATCH,13=9.0-571-r 1 M L.,SW C30,72i l SO,0 -12 5.47* H 2666* 4 -5748 -5520 3 -8400 -7004 . _ .._. .. Minimum ID mi 3125"0 10644' 4-112"OTIS XN NIPPLE Eil is,,29600 -7936 1 -10400 -6660 VWFSTOCX(xxnouria)H -.6000 : -45011()_i-L9-5/13"X r RBI LOO(MGR ID- CSG„470,L-80 NSCC,ID=8.88r H -6000 i.... I Oi 11-112 Hole Fii•NO IT WINIIIIW(YAW.) -111)017--481/V I ir---1 -10600 1-14-1/7'OTE X NP,0.3.817 I S x— -10630 HT x 4-1/2"BKR S-3 R01,13=3 879' 1 1--{ -.10674 I-14-Ur GTE X MP,Ow 3113' I . . -10630 _1-10'F-FS XN MP 83=3725' 1 I I _ TOP OF 4-112-LNR -10113g -10635 -jrIX 5'BKR TESACK.13= • 4-1/2"LNR 12.80,13C948 VAM'MP, -10640 ,:. -10640 -14-1 frY1.1..E.G.ID=3.658• 0152 bpf,ID=3.950 • -0884/5 -17.r4 r."010110-40-c may/cm.iTLSK,D , I 7"DSO.266,L-80 VIUMTOPHC, r -1070S I A 1 -10659 H -x 5'BKR OG FLOC-LOCK HGR 0383 bpl.ID.8276' 6-1m-Hole PERFORATION SUMMARY REF LOGon ›Ce404/14 _ APC4F AT TOP FERF- _.:/0 ' Wm:Refer lo Production CE for hatorical pert data SIZE SPF INTERVAL Oprt/Sqz CATE SQZ I 1-143713-1 -13478 114.16. ••• ir I 4-112'LNR,12 Mk 13CR-___VALI TCP, -I -13558 • 0152 big,V=3,958" DATE REV 3Y comciirs ------T atkm itirEFT COM FRLDHOE BAY UNT 1W07/88 WES. ORIGINAL COMPLETION 0/130/14 JI-I0PJC FROPOSA L TOG UPLATE Nal... Y-14C '11/01/95 LJNOBI SIDETRACK(Y-144) _ 0601/14 XV PJC REV 2-ACOGIJA-PROFOSAL MEW Ny 08/07/01 CHKAK CTD TOE OUT DRILL iii=iii* AR*: 50-029-21832-03 XXDOV14 'SIDETRACK(Y-14C) _ SEC 34„T1114,Rue 4.97 Rt.&706'FAIL 07/09ildPJC LitALD f1-20173SAL I . - 0711 4i1-4-GJRi PIG LIMA TE PROPOSAL BP Exploration(Masks) Y-14C Page 12 8/6/2014 • bp 0 Y-14C(P6)Proposal Geodetic Report Schiumherger (Def Plan) Report Date: July 28,2014-12:12 PM Survey/DLS Computation: Minimum Curvature/Lubinski . Client: BP Vertical Section Azimuth: 270000°(True North) Field: Prudhoe Bay Unit-WOA Vertical Section Origin: 0.000 R 0.000 ft Structure/Slot: Y-PAD/Y-14 �� ND Reference Datum: Rotary Table Borehole:Well: Y-14 TVD Reference 84000 ft above MSL 1 50a02921 3203 Feasibility Ground Elevation: 49.600 49.800 ft above MSL•° Magnetic Declination: lama* ° Survey Name: Y-14C(P8) Total Gravity Field Strength: 1001.9974mgn(9.80665 Based) Survey Date: July 28,2014 Gravity Model: DOX Tort I AHD I DDI I ERD Ratio: 313.214°/7195.386 ft/6.528/0.793 Total Magnetic Field Strength: 57615.297 nT Coordinate Reference System: NAD27 Alaska State Plane,Zone 04,US Feet • Magnetic Dip Angle: 80.970° Location Lat/Long: N 70°16'12.62131",W 148°49'23.65258" Declination Date: November 10,2014 Location Grid N/E Y/X: N 5949777000 BUS,E 645503.000 ftUS Magnetic Declination Model: BGGM 2013 CRS Grid Convergence Angle: 1.1077° North Reference: True North . Grid Scale Factor: 0.99992405 Grid Convergence Used: 00000' Version I Patch: 2.7.1043.0 Total Corr Mag North->True North: 19.4598° Local Coord Referenced To: Well Head r Comments MD Incl A=im True TVDSS ND VSEC NS EW TF DLS Directional Northing Basting (R) (°) (°) (0) (ft) (ft) (0) (ft) (°) (°/1000) Difficulty Index (RUB) (RUS) 0.00 0.00 0.00 -84.00 0.00 0.00 0.00 0.00 OM N/A 0.00 5949777.00 645503.00 4.20 0.00 0.00 -78.80 420 0.00 0.00 0.00 OM 0.00 0.00 5949777.00 845503.00 34.50 0.00 0.00 -49.50 34.50 0.00 0.00 0.00 247.55M 0.00 0.00 5949777.00 845503.00 104.20 0.17 247.55 20.20 104.20 0.10 -0.04 -0.10 23042M 0.24 0.00 5949776.96 845502.91 204.20 0.32 230.42 120.20 204.20 0.45 -0.27 -0.45 232.37M 0.17 0.00 5949778.72 645502.58 304.20 0.38 232.37 220.20 304.20 0.93 -0.85 -0.93 210.78M 0.08 0.00 5949776.33 645502.09 404.20 0.30 210.78 320.20 40420 1.32 -1.08 -1.32 229.05M 0.15 0.00 5949775.89 645501.70 504.20 0.20 229.05 420.19 504.19 1.59 -1.42 -1.59 124.8M 0.13 0.16 5849775.55 645501.44 604.20 0.55 124.80 520.19 604.19 1.33 -1.81 -1.33 99.13M 0.63 0.54 5949775.17 645501.71 704.20 1.58 99.13 620.17 704.17 -0.43 -2.30 043 92,25M 1.11 1.04 5949774.71 645503.47 804.20 2.17 92.25 720.12 804.12 -3.68 -2.60 3.68 101.03M 0.63 1.37 5949774.48 645506.73 904.20 3.83 101.03 819.98 903.98 -8.65 -3.31 8.85 102.93M 1.72 1.79 5949773.86 645511.91 1004.20 4.07 102.93 919.74 1003.74 -15.59 4.74 15.59 101.6M 0.27 2.00 5949772.56 645518.88 1104.20 3.65 101.80 1019.52 1103.52 -22.17 -6.16 22.17 101.2704 0,43 2.16 5949771,25 645525.28 1204.20 3.02 101.27 1119.35 1203.35 -27.87 -7.33 27.87 99,05M 0,63 2.30 5949770.21 645531.00 1304.20 2.82 99,05 1219.22 1303.22 -32.88 -8.23 32.88 88,12M 0,23 2.38 5848769,41 645536.03 1404.20 2.32 89.12 1319.12 1403.12 -37.33 -8.59 37.33 83.53M 0.87 2.47 5949789.14 645540.49 1504,20 1.97 83.53 1419.05 1503.05 -41.07 -8.36 41.07 64.35M 0,41 2.53 5949769.43 64554422 1604.20 1.63 84.35 1519.00 1603.00 -44.19 -803 44.19 86.7M 0.34 2.58 5949789.83 645547.33 1704,20 1.18 86.70 1818.97 1702.97 -46.63 -7.83 46.63 85.3M 0.45 2.62 5949770.07 645549.77 180420 1.02 85.30 1718.95 1802.95 -48.55 -7.70 48.55 87.78M 0.16 2.65 5949770.24 645551.88 1904,20 0.93 87.78 1818.93 1902.93 -50.25 -7.59 50.25 103.25M 0.10 2.67 5949770.38 645553.38 200420 0.85 103.25 1918.92 2002.92 -51.61 -7.89 51.81 114.35M 0.35 2.70 5949770.31 645554.74 2104,20 0.83 114.35 2018.92 2102.92 -52.66 -8.05 52.66 117.OBM 0.13 2.71 5949769.97 645555.80 220420 0.85 117.08 2118.91 2202.91 -53.87 -8.53 53.67 119.38M 0.04 2.72 5949789.51 645558.82 2304.20 0.80 119.38 2218.91 2302.91 -54.83 -9.05 54.83 131.98M 0.08 2.73 5949769.01 645557.79 240420 0.50 131.98 2318.90 2402.90 -55.41 -9.60 55.41 129.03M 0.16 2.75 5949768.48 645558.58 250420 0.82 129.03 2418.90 2502.90 -56.15 -10.23 58.15 120.02M 0.12 2.76 5949767.86 845559.34 260420 0.57 120.02 2518.89 2802.89 -57.00 -10.82 57.00 128.61M 0.11 2.77 5949767.28 645560.20 13-3/8" 269020 0.48 12661 2604.89 268889 -57.66 -11.26 5788 130.3M 0.14 2.78 5949766.86 645560.86 2704.20 0.47 130.30 2618.89 2702.89 -57.75 -11.33 57.75 130.18M 0.14 2.78 5949766.79 845560.95 2804.20 0.42 130.18 2718.88 2802.88 -58.34 -11.84 58.34 149.3M 0.05 2.79 5949766.29 645561.55 2904.20 0.47 149.30 2818.88 2902.88 58.83 -12.43 58.83 154.67M 0.16 2.80 5949765.72 645562.05 SV3 297232 0.49 154.67 288700 2971.00 -59.10 -12.93 59.10 157.03M 0.07 2.81 594976522 645562.33 300420 0.50 157.03 2918.88 3002.88 59.21 -13.18 59.21 155.78M 0.07 2.81 5949764.97 645562.45 310420 0.58 155.78 3018.87 3102.87 59.59 -14.04 59.59 161.5M 0.08 2.82 5949764.11 645562.84 320420 0.80 181.50 3118.87 3202.87 -59.96 -15.00 59.96 161.55M 0.06 2.83 5949763.18 645563.24 SV2 3205.33 0.60 161.55 3120.00 3204.00 -59.97 -15.01 59.97 165.35M 0.07 2.3 5949783.15 645563.24 3304.20 0.85 165.35 3218.86 3302.86 -60.27 -16.05 6027 177.13M 0.07 2.84 5949762.12 645563.57 340420 0.57 177.13 3318.86 3402.86 -60.44 -17.09 60.44 185.45M 0.15 2.85 5949761.08 645563.75 350420 0.55 185.45 3418.85 3502.85 60.42 -18.07 60.42 187.02M 0.08 2.86 5949760.11 645563.75 SV1 356735 0.56 187.02 348200 3568.00 -60.35 -1868 60.35 187.9M 0.03 287 5949759.50 645563.70 360420 057 187.90 3518.85 3602.85 -60.31 -19.04 60.31 187.88M 0.03 2.87 5949759.13 645563.68 3704.20 0.47 187.88 3818.84 3702.84 -60.18 -19.94 60.18 185.42M 0.10 2.88 5949758.23 645563.55 3804.20 0.52 185.42 3718.84 3802.84 -60.08 -20.79 60.08 186.33M 0.05 2.89 5949757.37 645563.47 390420 0.3 186.33 3818.83 3902.83 59.99 -21.71 59.99 185.93M 0.01 2.89 5949758.46 845563.39 4004.20 1.28 185.93 3918.82 4002.82 -59.82 -23.28 59.82 177.23M 0.75 2.93 5949754.89 845563.26 410420 4.60 177.23 4018.88 4102.68 -59.90 -28.39 59.90 177.31M 3.34 3.07 5949749.77 845563.43 UG4 4106.3 4.89 177.31 4021.00 4105.00 -59.91 -28.58 59.9/ 578.28M 4.08 3.08 5949749.58 645563.45 1/03 4144.71 6.24 178.28 4059.00 4143.00 -60.04 -32.22 60.04 179.1M 4.06 3.14 5949745.95 845583.65 420420 8.65 179.10 4117.99 4201.99 -6021 -39.92 6021 8.35R 4.08 3.24 5949738.25 645563.97 430420 12.87 181,87 4216.21 4300.21 -59.97 -58.58 59.97 0.58L 4.25 3.41 5949718.59 845564.08 4404.20 18.17 181.75 4313.00 4397.00 -59.18 -83.64 59.18 1204R 3.30 3.55 5949694.53 645563.78 UG1 4409.41 16.32 181.86 4318.00 4402.00 -59.13 -85.09 5813 11.314 285 3.56 594969307 645563.76 4504.20 18.97 183.58 4408.33 4492.33 -57.74 -113.78 57.74 10.85R 2.85 3.69 5949664.36 645562.92 4604.20 22.33 185.27 4501.89 4585.89 -54.98 -148.93 54.98 1.74L 3.41 3.82 5949629.17 645560.84 4704.20 25.12 185.07 4593.43 4677.43 -51.35 -189.00 51.35 4.2R 2.79 3.93 5949589.04 645557.99 4804.20 28.07 185.53 4682.84 4766.84 -47.21 -233.57 47.21 19.37R 2.96 4.04 5949544.40 845554.71 WS2 486282 3035 18711 4734.00 481800 -44.05 -262.00 44.05 17.99R 4.11 4.11 594951592 645552.10 ' 4904.20 31.97 188.10 4769.41 4853.41 -41.21 -283.22 41.21 17.81R 4.11 4.16 5949494.85 645549.67 5004.20 35.98 190.28 4852.32 4936.32 -32.23 -338.38 32.23 29.91R 4.19 427 5949439.36 845541.77 5104.20 38.48 192.57 4831.94 5015.94 -20.22 -397.64 20.22 3.582 2.88 436 5949379.86 645530.90 5204.20 36.88 192.55 5010.12 5094.12 5.66 -458.51 8.68 154.4L 0.20 442 5949318.74 845518.52 5304.20 38.55 192.45 5088.25 5172.25 6.85 -519.44 -6.85 122.822 0.14 447 5949257.57 645506.19 540420 38.45 192.20 5166.51 525051 20.14 -580.25 -20.14 156.09L 0.18 4.52 5949196.51 645494.08 5504.20 38,38 192.15 5244.87 5328.87 33.24 -640.99 -33.24 171.192 0.08 4.3 5949135.54 645482.18 5604.20 38.30 192.13 5323.30 5407.30 46.29 -701.64 -46.29 6.35R 0.08 4,60 5949074.85 845470.29 WS/ 565994 3846 192.18 5367.00 5451.00 53.57 -735.47 -3.57 8.33R 0.28 4.62 594904069 645463.66 5704.20 38.58 192.18 5401.83 5485.63 59.38 -762.41 -59.38 142.13L 0.28 4,64 5949013.64 645458.38 5804.20 38.50 192.08 5479.84 5563.84 72.47 -823.33 -72.47 4.49L 0.10 4,67 5948952.49 64544646 Tie-In Survey 5904.20 38,90 192.03 5557.89 5841.89 85.53 -884.47 -85.53 902 0.40 4.70 5948891.11 645434.59 Top Whipstock • 6000.00 38.90 191.83 5632.44 5716.44 97.96 -943.33 -97.96 45L 0.13 4,73 5948832.02 645423.30 Base Whipstock 8016.00 40.34 189.84 5644.77 5728.77 99.86 -953.35 -99.86 HS 12.50 4.75 5948821.97 645421 59 Cry4/100 6036.00 40.34 189.84 5860.01 5744.01 102.03 -968.12 -102.03 28.152 0.00 4.76 5948809.17 845419.87 6100.00 42.61 187.88 5707.97 5791.97 108.48 -1008.00 -108.46 28.812 4.00 480 5948787.17 845414.05 CM3 6172.22 45.20 188.02 5760.00 584400 114.50 -105771 -114.50 25.49L 4.00 4.84 5948717 36 645408.98 8200.00 46,20 185.36 5779.40 5863.40 11647 -1077.49 -11847 25.03L 4.00 4.88 5948697.54 645407.39 8300.00 49.85 183.15 5846.27 5930.27 121.94 -1151.82 -121.94 23.55L 4.00 492 5948623.33 645403.35 8400.00 53.54 181.16 5908.25 5992.25 124.88 -1230.01 -124.88 22.32L 4.00 4,97 5948544.90 845401.95 6500.00 57.25 179.36 5985.04 6049.04 125.20 -1312.30 -125.20 21.292 4.00 5.03 5948462.63 845403.20 6600.00 60.99 177.70 6016.36 6100.38 122.98 -1398.07 -122.98 20.44L 4.00 5,08 5948376.92 645407,08 End Cry 8673.87 83.76 176.55 6050.61 6134.81 119.69 -1463.43 -119.89 HS 4.00 5.12 5948311.64 845411.83 8700.00 63.78 178.55 6062.16 8146.16 118.27 -1488.83 -118.27 HS 0.00 5,12 5948288.28 645413,50 6800.00 63.76 176.55 6106.37 819037 112.88 -1576.36 -11288 HS 0.00 5.15 5948198.88 64542063 8900.00 63.76 178.55 8150.58 6234.58 107.48 -1665.89 -107.48 HS 0.00 5.18 5948109.47 845427.75 7000.00 63.76 176.55 6194.79 6278.79 102.08 -175543 -102.08 HS 0.00 5.20 5948020.06 64543488 7100.00 63.76 176.55 8239.00 632300 9668 -1844.96 -9668 HS 0.00 5.23 5947930.66 645442,01 Drilling Office 2.7.1043.0 Prudhoe Bay Unit-WOA\Y-PAD\Y-141PIan Y-14C\Y-14C(P1) 8/4/2014 11:49 AM Page 1 of 2 • Comments MD Mel Asim True TVDSS TVD VSEC NS EW TF DLS Directional Northing Emoting (ft) (°) (°) (ft) (ft) (ft) (ft) (N) (°) (°/100ft) Difficulty Index (SUS) (NUS) CM2 7145.23 83.76 178.55 625900 6343.00 94.24 -188548 -94.24 HS 000 5.24 5947890.22 64544524 7200.00 63.76 176.55 6283.21 8387.21 91.28 -1934.49 -91.28 HS 0.00 5.25 5947841.25 645449.14 Fault 1 7210.00 83.78 176.55 6287.84 6371.64 90.74 -1943.45 -9074 HS 000 5.25 5947832.31 845449.85 7300.00 63.76 17655 6327.43 8411.43 85.88 -2024.03 -85.88 HS 0.00 5,27 5947751.85 845456.27 7400.00 63.76 176.55 6371.84 6455.84 80.48 -2113.56 -80.48 HS 0.00 5,29 5947882.44 645463.40 7500.00 83.76 176.55 6415.85 6499.85 75.08 -2203.10 -75.08 HS 0.00 5.31 5947573.04 645470.53 7600.00 63.76 176.55 8460.06 6544.06 69.68 -2292.83 -69.88 HS 0.00 5,33 5947483.63 845477.65 ' Cry 4/100 7672.68 63.76 176.55 6492.19 8576.19 85.78 -2357.70 65.76 137.58R 0.00 5.35 5947418.65 645482.83 7700.00 62.96 177.38 6504.44 6588.44 64.46 -2382.09 -84.48 137.21R 4.00 5.36 5947394.30 645484.60 7800.00 60.06 180.51 8552.15 8636.15 62.81 -2469.93 -62.81 135.72R 4.00 5,40 5947306.51 645487.95 7900.00 57.23 183.83 6604.19 6688.19 66.01 -2555.24 -88.01 133.99R 4.00 5,43 5947221.16 645486.40 8000.00 54.51 187.37 6660.30 8744,30 74.04 -2637.60 -74.04 132R 4.00 5.47 5947138.67 645479.96 8100.00 51.89 191.14 6720.22 6804.22 86.87 -2716.60 -86.87 129.74R 4.00 5,50 5947059.44 645488.67 8200.00 49.40 195.19 6783.64 8867.84 104.43 -2791.87 -104.43 127.17R 4.00 5.53 5946983.85 645452.57 8300.00 47.06 199.55 6850.27 8934.27 126.64 -2863.03 -126.84 124.27R 4.00 5.56 5948912.28 845431.74 8400.00 44.90 204.23 6919.78 7003.78 153.38 -2928.73 -153.38 121.01R 4.00 5.59 5948845.08 845406.29 8500.00 42.95 209.27 6991.82 7075.52 18454 -2991.66 -184.54 117.38R 4.00 5.62 5948782.56 845376.34 CMI 8536.94 4229 211.22 7019.00 7103.00 197.13 -3013.27 -197.13 115.95R 4.00 5.63 5946760.72 845364.17 8600.00 41.23 214.66 7066.05 7150.05 219.95 -3048.51 -219 95 113.38R 4.00 5.64 5946725.04 845342.04 8700.00 39.79 220.40 7142.10 7226.10 259.45 -3100.01 -259.45 109.01R 4.00 5.87 5946672.80 645303.54 8800.00 36.64 226.47 7219.61 7303.61 30284 -3145.90 -302.84 104.31R 4.00 5.69 5946626.08 845261,05 • 8900.00 37.82 23279 7298.19 7382.19 349.91 -3185.95 -349.91 99.34R 4.00 5.71 5946585.13 845214.77 THRZ 8962.89 37.48 236.88 734800 743200 381.29 -3208.07 -381.29 9611R 4.00 5.72 5946562 41 645183.82 9000.00 37.35 239.31 7377.47 7461.47 400.43 -3219.99 -400.43 94.17R 4.00 5.73 5946550.13 645184.92 9100.00 37.24 245.91 7457.06 7541.06 454.15 -3247.83 -454.15 88.92R 4.00 5.75 5948521.25 845111.75 9200.00 37.50 252.49 7536.57 7620.57 51082 -3289.34 -510.82 83.69R 4.00 5.77 5946498.65 845055.51 LCU 9248.51 37.75 255.64 7575.00 7659.00 539.30 -327747 -839.30 81.19R 4.00 5.78 5946489 98 845027.20 End Cry 928523 38.00 258.00 7603.98 7687.98 56124 -3282.61 -561.24 HS 4.00 579 5948484.42 845005.38 9300.00 38.00 258.00 7615.62 7699.82 570.13 -3284.50 -570.13 HS 0.00 5.79 5946482.35 644998.51 9400.00 38.00 258.00 7694.42 7778.42 830.36 -3297.30 -830.36 HS 0.00 5.80 5948488.39 644936.55 9500.00 3800 258.00 7773.22 7857.22 690.58 -3310.10 690.58 HS 0.00 5,81 5946454.43 844876.59 9600.00 38.00 258.00 785202 7936.02 750.80 -332290 -750.80 HS 0.00 5.81 5948440.47 644818.63 9700.00 38.00 258.00 7930.83 801483 811.02 -3335.70 -81102 HS 0.00 5.82 5946428.51 644756.68 TJF 9754.79 38.00 258.00 7974.00 8058.00 844.01 -3342.71 -844.01 HS 0.00 5.83 594641886 844723.83 9800.00 38.00 258.00 8009.63 8093.63 871.24 -3348.50 671.24 HS 0.00 5.83 5946412.55 644696.72 TJE 987788 38.00 258.00 8071.00 815500 919.14 -3358.47 -918.14 HS 0.00 5.83 5946401.68 844650.02 9900.00 38.00 258.00 8088.43 817243 931.46 -3361.30 -931.46 HS 0.00 584 5948398.59 844836.76 10000.00 3800 258.00 816723 8251.23 991.68 -3374.10 -991.68 HS 0.00 584 5948384.63 644576.80 1010000 38.00 258.00 8246.03 8330.03 1051.90 -3386.90 -1051.90 HS 0.00 5.85 5946370.67 644516.85 1020000 3500 258.00 832483 8408.83 111212 -3399.70 -1112.12 HS 0.00 5.86 5948356.70 644456.89 TJD 10270 01 3800 258.00 8380.00 8464.00 1154.28 -3408.66 -1154.28 HS 0.00 5.86 5946348.93 844414.91 10300.00 38.00 258.00 8403.63 848763 1172.34 -341250 -1172.34 HS 0.00 5.88 5948342.74 644396.93 10400.00 38.00 258.00 8482.43 8566.43 1232.56 -3425.30 -1232.56 HS 0.00 587 5946328.78 644336.97 TJC 10436.25 38 00 258.00 8511.00 859500 1254.39 -342994 -1254.39 HS 0.00 5.87 594632372 844315.24 10500.00 38.00 258.00 8561.23 8845.23 1292.78 -3438.10 -1292.78 HS 0.00 5.88 5948314.62 644277.02 TJB 10587.26 38.00 258.00 8630.00 8714.00 1345.34 -3449.27 -1345.34 HS 0.00 5.88 5946302.64 644224.70 10600.00 38.00 258.00 8640-04 8724.04 1353.01 -3450.90 -1353.01 HS 0.00 588 5946300.86 644217.08 TJA 10682.44 38.00 258.00 870500 8789.00 1402.65 -3461.45 -1402.65 HS 0.00 589 594628935 644167.63 1070000 38.00 258.00 8718.84 8802.84 1413.23 -3463.70 -1413.23 HS 0.00 589 5946286.90 644157.10 TSGR 1078523 38.00 258.00 8788.00 8870.00 146455 -3474.61 -1464.55 HS 0.00 5.89 5946275.00 64410600 Tot 1 Sac 7-Csc 10790.23 38.00 258.00 8789.94 887394 146756 -3475.25 -1467.56 HS 0.00 589 5946274.30 644103.00 1080000 38.00 258.00 8797.84 8881.64 1473.45 -347650 -1473.45 HS 0.00 5.69 594627294 844097.15 Cry 12.75/100 1080023 38.00 258.00 8797.82 8881.82 1473.59 -3476.53 -1473.59 25.04R 0.00 5.89 5946272.91 844097.01 TSHU 1082374 4068 25991 8816.00 890000 5488.25 -347938 -1488.21 23.57R 12.50 5.90 5948289.78 64408244 10900.00 49.54 264.90 8869.79 8953.79 1541.70 -3486.33 -1541.70 20.03R 12.50 594 5946261.79 844029.10 TOAD 1094810 54.98 267.31 689800 8982.00 157605 -348077 -1578.05 18.58R 12.50 5.96 594625885 643992.80 1100000 61.39 269.75 8926.40 9010.40 1623.81 -3489.82 -1623.81 17.27R 12.50 598 5946258.62 643947.08 4591 1100135 81.79 269.89 8928.00 9012.00 1626.76 -3489.93 -1628.78 17.2R 12.50 5.98 5946256.55 643944.13 45P 11009.78 62.56 270.15 8931_00 901500 1832.44 -3489.92 -1632.44 17.088 12.50 5.98 5946256.44 843938.45 11100.00 73.38 273.59 8964.80 9048.80 1715.88 -3487.10 -1715.88 15.78R 12.50 6.02 594625766 643854.98 11200.00 8543 276.98 8983.17 9087.17 1813.56 -3478.01 -1813.56 15.16R 12.50 6.06 5946264.88 643757.15 90• 11237.90 90.00 278.21 8984.88 9068.68 1851.08 -3473.00 -1851.08 15.118 12.50 6.08 5946269.13 643719.54 End Cry 11288.09 93.84 279.20 8983.72 9067.72 1880-90 -3468.44 -1880.90 HS 12.50 6.09 5946273.12 643689.64 11300.00 93.64 279.20 8981.69 9065.69 1912.34 -3463.35 -191234 HS 0.00 6.09 594627760 643658.11 11400.00 93.84 279.20 897534 9059.34 201086 -3447.39 -2010.86 HS 0.00 6.11 5948291.65 843559.31 11500.00 93.64 27920 8968.98 9052.98 2109.37 -3431.44 -2109.37 HS 0.00 8.12 5946305.70 64346052 11600.00 93.64 279.20 8962.63 9046.63 2207.89 -3415.48 -2207.89 HS 0.00 6.13 5946319.74 843361.72 11700.00 9364 279.20 8956.28 9040.28 2306.40 -3399.53 -2306.40 HS 0.00 8.14 5948333.79 64326292 11800.00 93.64 279.20 8949.92 9033.92 2404.92 -3383.58 -2404.92 HS 0.00 8.15 5946347.83 643164.13 11900.00 93.64 279.20 8943.57 9027.57 2503.43 -336762 -2503.43 HS 0.00 6.17 5946381.88 643065.33 Cry 10/100 11954.72 93.84 279.20 8940.09 9024.09 2557.34 -3358.89 -2557.34 93.03L 0.00 8.17 5946369.56 643011.27 12000.00 93.39 274.67 8937.31 9021.31 2602.19 -3353.44 -2602.19 93.311. 10.00 6.19 5946374.15 642988.32 12100.00 92.77 264.67 8931.92 901592 2701.92 -3354.01 -2701.92 93.851_ 10.00 6.22 5946371.65 642866.63 12200.00 9206 254.69 8927.71 9011.71 2800.09 -3371_89 -2800.09 94.271. 10.00 6.25 5946351.88 642768.84 12300.00 91.29 244.72 8924.78 9008.78 2893.72 -3406.52 -2893.72 94.56L 10.00 6.28 5946315.45 64267590 12400.00 90.48 234.75 8923.24 9007.24 2979.96 -3456.85 -2979.98 94.71L 10.00 6.31 5946283.48 642590.65 90" 12457.67 90.00 229.00 8923.00 9007.00 3025.31 -3492.44 -302531 113.621. 10.00 6.32 5946227.00 642546.00 Tat 4 12500.00 88.31 22512 8923.63 9007.63 3056.29 -3521.27 -3056.29 113.561. 10.00 8.34 5946197.58 642515.59 12600.00 8435 21592 8930.05 901405 3121.06 - -3597.03 -3121.06 112.97L 10.00 6.36 5946120.60 642452.30 12700.00 80.53 20659 8943.23 9027.23 3172.45 -3681.64 -3172.45 111.741. 10.00 6.39 5946035.01 642402.56 12800.00 76.97 197.06 8962.77 9046.77 3208.91 -3772.54 -3208.91 109.88L 10.00 8.42 5945943.43 642367.87 End Cry 12811 42 76.59 195.96 8965.38 904938 3212.06 -3783.20 -3212.08 HS 10.00 6.42 5945932.71 642364.92 Cry 10/100 12813.62 76.59 195.96 8965.89 904989 3212.65 -3785.26 -3212.65 35.681. 0.00 8.42 5945930.64 642364.37 12900.00 83.65 190.90 8980.72 9064.72 3232.36 -3867.98 -3232.36 34.81L 10.00 6.44 594584758 642346.27 90' 1297722 90.00 186.50 898500 9069.00 3244.00 -3944.12 -3244.00 41.08L 10.00 6.46 5945771.21 642336.10 Tat 5 13000.00 91.72 185.00 898466 9068.66 324628 -3966.78 -3246.28 41.11. 10.00 6.46 5945748.52 64233426 End Cm 1307484 97.34 180.05 8978.75 9062.75 3249.58 -4041.26 -324958 HS 10.00 648 5945873.99 64233240 13100.00 97.34 180.05 8975.53 9059.53 3249.80 -406621 -324960 HS 0.00 6.48 5945649.05 642332.86 ' 1320000 97.34 180.05 896275 9046.75 324969 -4165.39 -3249.69 HS 0.00 6.49 5945549.89 642334.69 1330000 97.34 180.05 8949.97 9033.97 3249.78 -4264.57 -324978 HS 0.00 6.50 5945450.74 692336.52 13400.00 97.34 180.05 8937.19 9021.19 3249.88 -4363.75 -3249.86 HS 0.00 651 5945351.58 642338.35 1350000 97.34 180.05 892441 9008.41 3249.95 -4462.93 -324995 HS 0.00 6.52 594525243 842340.18 TO • 13557.97 97.34 180.05 8917.00 9001.00 • 325000 -452043 -3250.00 0.00 6.53 5945194.94 642341.24 Survey Type: Out Plan • Drilling Office 2.7.1043.0 Prudhoe Bay Unit-WOA\Y-PAD\Y-14\Plan Y-14C\Y-14C(P1) 8/4/2014 11:49 AM Page 2 of 2 BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Y-14 Project: Prudhoe Bay TVD Reference: Y-14C plan D14 @ 84.00us9(D14 plan) Reference Site: PB Y Pad NV Reference: Y-14C plan D14 @ 84.00usf(D14 plan) Site Error: 0.00usf North Reference: True Reference Well: Y-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00usf Output errors are at 1.00 sigma Reference Wellbore Plan Y-14C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#6 Y-14C Offset TVD Reference: Offset Datum Reference Ran#6 Y-14C Filter type: GLOBAL FILTER APPLIED:Al wellpat s within 200'+100/1000 of reference Interpolation Method: MD Interval 5.00usit Error Model: ISCWSA Depth Range: 5,904.20 to 13,557.97usf Scan Method: Tray.Cylinder North Results Limited by- Maximum center-center distance of 1,552.36ust Error Surface: Elliptical Conic Survey Tool Program Date 7/26/2014 From To (usf) (wfl) Busty(Wellbore) Tool Name Description 10420 5,904.20 Y-14 Srvy 1 OCT-MS(Y-14) GCT-MS Schlumberger GCT mubshot 5,904.20 6,000.00 Plan 66 Y-14C(Plan Y l4C) GCT-MS Schlumberger GCT multishot 6000.00 6,350.00 Plan#6 Y-14C(Plan Y-14C) INC+TREND Inclinometer+known as trend 6,350.00 7,850.00 Plan#6 Y-14C(Plan Y-14C) MWD MWD-Standard 6,350.00 10,780.00 Plan#6 Y-14C(Plan Y-14C) MWD+IFR+MS-WOCA MIND+IFR+Malt Station VV/0 Crustal 10,780.00 12,280.00 Plan#6Y-14C(Plan Y-14C) MWD MWD-Standard 10,780.00 13,557.97 Plan#6 Y-14C(Plan Y-14C) MWD+IFR+MS-WOCA MVO+IFR+Multi Station WlO Crustal 7462014 1222NPM Ps. 2,05 COWN,SS 8000.1 fW6111 • • BP Anticollision Report Company; North America-ALASKA-BP Local Co-or6nate Reference: Weil Y-14 Project: Prudhoe Bay TVD Reference: Y-14C plan 014 @ 84.00usft(D14 plan) Reference Site: PB Y Pad 1010 Reference: Y-14C plan D14 @ 84.00usf(D14 plan) Site Error: 0.00usf North Reference: True Reference Well: Y-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00usk Output errors are at 1.00 sigma Reference Wellbore Wan Y-14C Database: EDM ASK-Alaska PROD-ANCP1 Reference Design: Plan#6 Y-14C Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation MYBeing Site Name Depth Depth Distance (usS) from Plan Offset Well-Wellbore-Design (usf) (usrt) (uslt) (ust) PB Y Pad Y-02-Y-02-Y-02 Out of range V.02-Y-02A-Y-02A Out of range Y-02-Y-02APB1•Y-02AP81 Out of range Y-03-Y-03-Y-03 Out of range V-03-Y-03A-Y-03A Out of range Y-04-Y-04-Y-04 Out of range Y-05-Y-05-Y-05 7,700.00 6.990.00 863.81 581.84 308.45 Pass-Major Risk 1 Y-05-Y-O5A-Y-05A 7.700.00 8,99500 863.46 581.70 308.45 Pass-Major Risk • Y-05-Y-05B-Y-05B 7,700.00 6,995.00 883.46 581.59 308.56 Pass-Major Risk Y-05-Y-05BP81-Y-058P81 7,700.00 6,995.00 863.46 581.70 308.45 Pass-Major Risk Y-06•Y-06-Y•06 Out of range Y-06-Y-084-Y-06A Out of range Y-O6-Y-06AP81-Y-06AP81 Out of range Y-07-Y-07-Y-07 6,300.73 6,305.00 775.57 350.43 426.30 Pass-Major Risk Y-07-Y-07A.Y-07A Out of range Y-07•Y-07AP81-Y-07AP81 Out of range Y-08-Y-08-Y-08 Out of range Y-08-Y-08A-Y-08A Out of range Y-09-Y-09-Y-09 8,600.00 7,530.00 935.68 713.30 577.41 Pass-Major Risk Y-09-Y-09A-Y-09A 8,600.00 7,530.00 935.78 713.12 577.48 Pass-Major Risk • Y•09-Y-09A11-Y-09AL1 8,600.00 7,530.00 935.78 713.23 577.37 Pass-Major Risk Y-09-Y-09AL1-01-Y-09AL1-01 8,600.00 7,530.00 935.78 713.23 577.37 Pass-Major Risk Y-09.Y-OBAPBI-Y-09AP81 8,600.00 7,530.00 935.78 713.12 577.48 Pass-Major Risk Y•10-Y-10-Y-10 Out of range Y-10-Y-1OA-Y-10A Out of range Y-10-Y-106-V-108 13,317.46 11,520.00 429.21 414.38 47.15 Pass-Major Risk Y•10•Y-10BP81-Wan 610 V-108 approved 13,315.27 11,545.00 42942 408.44 54.71 Pass-Major Risk Y-10-Y-10BPMI-Y-1OBP81 13,317.48 11,520.00 429.21 414.48 47.05 Pass-Major Risk Y-10-Y•10BP82-Y-108P82 13,317.48 11,520.00 429.21 414.48 47.05 Pass-Major Risk Y-10-V-108P83-Y-108P83 13,317.46 11,520.00 42921 414.48 47.05 Pass-Major Risk Y-11•Y-11-V•11 12,632.17 9,819.00 179.15 85.22 109.10 Pass-Minor 1/200 Y-11•V-11A-Y•11A 12,382.32 9,820.00 532.58 433.01 102.37 Pass-Major Risk Y-11•Y-118-Y-118 12,350.00 9.696,00 630.36 404.37 249.91 Pass-Major Risk Y-11-V-118P81-Y-118PB1 12,317.21 9,696.00 678.94 391.59 315.21 Pass-Major Risk Y•11-Y.110-Y-11C 12,977.22 10,065.00 1,182,94 496.27 784.11 Pass-Major Risk Y-12-Y-12-Y-12 6,400.00 8.130.00 1.02944 38.5.03 645.86 Pass-Major Risk Y-13-11•13A-Y-13A 10,797.66 11,180.00 754.10 362.88 513.67 Pass-Major Risk Y-13-V-13APBl-Y-13AP81 11,536.33 10.710.00 729.99 205.61 533.02 Pass-Major Risk V-14-V-14-V-14 6,300.00 8,300.00 34.58 . 257.96 -100.81 FAIL-Moja Risk Y•14•Y-14A-Y-14A 6,300.00 6,305.00 34.52 257.89 -100.79 FAIL-Major Risk Y-14-Y-146-Y-146 6,300.00 8,305.00 34.52 257.89 -100.80 FAIL-Major Fffsk Y-16-Y-16-Y-15 Out of range V-18•Y-16-Y-18 Out of range V-17-Y-17A-Y-17A Out of range Y-17-Y-178-Plan 611 Out of range Y•20.Y•20-Y-20 Out of range Y-20-Y-20A-Y-20A Out of range Y-20-Y•20AL1-Y-20AL1 Out of range Y-20-Y-20512-Y-20AL2 Out of range Y-20•Y-20AL2P81-Y-20AL2P81 Out of range Y-21-Y-21-Y-21 13,557.97 9,175.00 1.471.15 449.81 1.173.89 Pass-Major Risk Y•21•Y•21A-Y-21A 13.557.97 9,180.00 1,445.97 444.59 1,151.81 Pass-Major Risk Y-22-Y-22-Y-22 Out of range 712$10/4 12#46PIOF Pege 3 of 5 COMPASS 5000 1 Budd 61 BP Anticallision Report Company, North America-ALASKA-BP Local Co-ortinate Reference: Well Y-14 Project: Prudhoe Bay TVD Reference: Y-14C plan 014 @ 84.00usft(014 plan) Reference Site: PB Y Pad MD Reference: Y-14C plan 014©84.00usft(014 plan) Site En-or: 0.00usft North Reference: True Reference Welt: Y-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Pian Y-14C Database: EDM RSK-Alaska PROD-ANCP1 Reference Design: Plan#6 Y-14C Offset WO Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning. •Site Name Depth Depth Distance (usft) from Wan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB Y Pad Y-22-Y-22A-V-22A Out of range Y-23-Y-23-Y-23 Out of range Y-23-Y-23A-Y-23A Out of range Y-29-Y-23APB1-Y-23APB1 Out of range Y-23-V-23APB2-Y-23APB2 Out of range Y-23-Y-238-Y-23B Out of range Y-24-Y-24-Y-24 Out of range Y-26-Y-26-Y-25 Out of range Y-25-Y-25A-Y-25A Out of range Y-27-Y-27-V-27 Out of range Y-28-Y-28-Y-28 6,055.98 5,865.00 312.51 128.39 193.94 Pass-Maya Risk Y-29-V-29-Y-29 Out of range Y-29-Y-29A-Y-29A Out of range 1-30-1-30-1-30 8,200.00 6,010.00 686.60 241.98 450.98 Pass-Major Risk Y-30-V-3011-Y-3011 8,200.00 6,010.00 686.60 242.01 450.96 Pass-Maya Risk Y-31-1-31-Y-31 Out of range Y32-Y-32.1-32 Out of range Y-32-Y-3211-Y-3211 Out of range Y-33-Y-33-Y-33 Out of range Y-33-Y-33A-Y-33A Out of range Y-33-Y-33APB1-Y-33APB1 Out of range Y-34-Y-34-Y-34 6,300.10 8,110.00 366.11 337.19 36.57 Pass-Major Risk Y-34-Y-34A-Y-34A 6,300.10 6,110.00 386.11 337,17 36.60 Pass-Major Risk Y-35-Y-35-Y-35 8,416.15 5,800.00 1,387.20 394.26 1,054.46 Pass-Moya Risk 1-35-Y-36A-Y-35A 8,409.64 5,790,00 1,388.91 394.28 1,054.17 Pess-Major Risk Y-37-Y-37-Y-37 8,275.61 7,215.00 1,414.16 475.73 1,190.75 Pass-Major Risk V37-V-37A-Y37A 8,275.61 7,215.00 1,414.16 475.32 1,190.77 Pass-Meyer Risk Y-37-Y-37A(delete me)-Y-37A 8,275.61 7,215.00 1,414.18 475.32 1,190.77 Pass-Major Risk Y-37-Y-37AP81-Y-37APB1 8,275.61 7,215.00 1,414.18 475.32 1,190.77 Pass-Mayor Risk Y-39-Y-39-Plan#12 Y-39 Out of range 1-39-V-39-Y-39 Out of range 1-39-Y-39PB1-Y-39PB1 Out of range 7/1198141832411P01 Page 4 of 5 COMPASS 5000.1 ad#81 Project Prudhoe Bay ite PB Y Pad Well Y-14 Wellbore Plan Y-14C Design Plan#6 Y-14C From Colour To MD From 5700'md(300'md above planned KOP)to TD Scan interal 25 ft 0 5700 Scale 1 inch:50ft 5700 6000 Y-11 fails the major risk 6000 6500 Well passes a risk 1:200 rule 6500 7000 See AC summary report for detailes — 7000-"""" 7500 7500 8000 'P 8000 9000 ♦- F• .' 9000 10000 �: i ��-:1}"...:..........: . /_. 10000 11000 i, 930 30 -' 11000 12000 b...., ' 14 12000 13800 " ."----i:.. t AMIN .•;-: - -'7 ilf v,41;...„...i.::::,...,,. 1114 300 • ,: . 044 A. 270tfAlreip , in, 1 fre-:.:.,./. .,_.: „13.7. .• , 1 lir + ,,..07-4004 : ,: ,- i T ,/4*VOA : '---; ' 636L39% ,k IttillfrAdei., 0.•,--A04 .,,,-- i it for,4-400.0e ....% , \ A ; /II AI 0—..if idg*'li. lialt -A 4. 01 4 OW _ s;°.®�a1i� + err. 90 .,,411/11111111 in of , , . ;ate, ..1r'004 ,- r1fi.ri- 210ar ... ‘14,�"1_!2I.ffair � � 150 r 7111M51510.. 180 Azimuth from North[1 vs Centre to Centre Separation[41 ustlinj _, ,066 E '2 .T- , ,c. 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Xrie Check g•az:for E:ppr opriatc Letterr`/ Paragrphs to be included in ransrr9ital Let��r =ECI: OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 MC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( 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 MC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation 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 MC 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 Well Logging also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 MC 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 4/2014 (a N o a N co 25 o co - 7 vi a) c E a 7 N N a) o a L N @I L C N T a) On u) Y L C C w U L!) 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