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Home My WebLink About215-1997. 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 09-02A Wellhead Sealant Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-199 50-029-20198-01-00 13622 Conductor Surface Intermediate Liner Liner 8981 80 2691 10699 510 3381 13495 20" 13-3/8" 9-5/8" 7" 3-1/2" x 2-7/8" 8974 36 - 116 35 - 2726 33 - 10732 10222 - 10732 10241 - 13622 36 - 116 35 - 2726 33 - 8851 8450 - 8851 8464 - 8981 None 520 2670 4760 7020 10530 None 1530 5380 6870 8160 10130 10896 - 13545 7" 26# x 5-1/2" 17# x 4-1/2" 12.6# 13CR80 31 - 10278 8950 - 8977 Structural 4-1/2" Baker Model D Packer 10154 8398 Bo York Operations Manager Andy Ogg andrew.ogg@hilcorp.com 907.659.5102 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 0028327 31 - 8493 Wellhead at Surface. IC test voids. Pumped 1-1/3-cup of Liquid greenstick. Hold 3500 psi for 1 hour. 112 Well Test Not Available 1992 5629 1655 1652 225 220 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 10154, 8398 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 12:32 pm, Jun 30, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.06.30 12:26:43 - 08'00' Bo York (1248) JJL 7/21/25 RBDMS JSB 070325 ACTIVITY DATE SUMMARY 6/3/2025 T/I/O = 350/1660/430. Temp = 128°. Greenstick IC void w/liquid greenstick (Eval IAxOA). ALP = 1660 psi, online. No IA companion valve. OA FL @ near surface. Bled OAP to 120 psi in 10 min (FTS), could not hold open bleed due to constant flow of fluid to BT. RU PKG gun to upper IC test port. Pumped 1/3 gun of liquid Green stick into test void and held pressure for 1 hr. RU pkg gun to lower test port. Pumped 1/3 gun of greenstick into lower void. Held 3500 psi for 1 hr to assure good pack. OAP increased 30 psi throughout duration of job. Final WHPs = 350/1660/150 SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:30 Daily Report of Well Operations PBU 09-02A 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 09-02A Greenstick IC test void Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-199 50-029-20198-01-00 13622 Conductor Surface Intermediate Liner Liner 8981 80 2691 10699 494 3381 13495 20" 13-3/8" 9-5/8" 7" 3-1/2" x 2-7/8" 8974 36 - 116 35 - 2726 33 - 10732 10238 - 10732 10241 - 13622 36 - 116 35 - 2726 33 - 8851 8462 - 8851 8464 - 8981 None 520 2670 4760 7020 10530 None 1530 5380 6870 8160 10130 10896 - 13545 7" 26# x 5-1/2" 17# x 4-1/2" 12.6# 13CR80 31 - 10294 8950 - 8977 Structural 4-1/2" Baker Model D, 10170 ,8410 No SSSV 10170 8410 Bo York Sr. Area Operations Manager Dave Wages David.Wages@hilcorp.com (713)380-9836 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 0028327 31 - 8506 Starting Head - IC test void, lower test void Pumped approximately 1 Tbsp Greenstick to 3500 psi for 1 hour. 118 111 248 0 5500 5365 1675 1681 245 255 N/A 13b. Pools active after work:PRUDHOE OIL 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 1:15 pm, Jan 24, 2025 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Date: 2025.01.24 11:43:19 - 09'00' David Bjork (3888) A.Dewhurst 13FEB25 DSR-1/31/25WCB 2-11-2025 RBDMS JSB 012925 Daily Report of Well Operations PBU 09-02A ACTIVITYDATE SUMMARY 12/25/2024 T/I/O = 320/1660/610. Temp = 128°. Greenstick IC void (Eval IAxOA). ALP = 1660 psi, online. No IA companion valve. OA FL @ near surface. Bled OAP to 100 psi in 10 min (FTS). RU PKG gun to upper IC test port. Pumped very small fractional amount of greenstick and held pressure for 1 hr to 3500 psi. RU pkg gun to lower test port. Pumped very small fractional amount of greenstick into lower void and held pressure for 1 hr to 3500 psi assure good pack. 1 tablespoon volume of greenstick pumped total. OAP increased 140 psi through duration of job. Bled OAP to BT to 150 psi (FTS). Monitored for 30 min. OAP increased 40 psi. Final WHPs = 220/1660/190. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:30 p()gppp Pumped very small fractional amount of greenstick and held pressure for 1py g p hr to 3500 psi. RU pkg gun to lower test port. Pumped very small fractionalppgg p py amount of greenstick into lower void and held pressure for 1 hr to 3500 psigp assure good pack. 1 tablespoon volume of greenstick pumped tota 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 09-02A Greenstick IC test void Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-199 50-029-20198-01-00 13622 Conductor Surface Intermediate Liner Liner 8981 80 2691 10699 494 3381 13495 20" 13-3/8" 9-5/8" 7" 3-1/2" x 2-7/8" 8974 36 - 116 35 - 2726 33 - 10732 10238 - 10732 10241 - 13622 36 - 116 35 - 2726 33 - 8851 8462 - 8851 8464 - 8981 None 520 2670 4760 7020 10530 None 1530 5380 6870 8160 10130 10896 - 13545 7" 26# x 5-1/2" 17# x 4-1/2" 12.6# 13CR80 31 - 10294 8950 - 8977 Structural 4-1/2" Baker Model D, 10170 ,8410 No SSSV 10170 8410 Bo York Sr. Area Operations Manager Dave Wages David.Wages@hilcorp.com (713)380-9836 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 0028327 31 - 8506 Starting Head - IC test void Pumped approximately 1/2 cup of Greenstick into test void to final 1860 psi 100 123 472 656 5219 6070 1486 1497 258 241 N/A 13b. Pools active after work:PRUDHOE OIL 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 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.07.19 07:50:03 - 08'00' Bo York (1248) By Grace Christianson at 10:49 am, Jul 19, 2024 A.Dewhurst 13FEB25 WCB 9-30-2024 RBDMS JSB 072524 DSR-7/19/24 ACTIVITYDATE SUMMARY 7/4/2024 T/I/O = 240/1860/550. Temp = 124°. Greenstick IC void (re-treat). AL open @ CV (1860 psi). No IA companion valve. OA FL @ near surface. Bled OAP to production to 240 psi in ~1 min (gas). RU PKG gun to IC test port. Pumped 1/4 gun load of Green stick into test void. Final WHPs = 240/1860/250 SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:00 Daily Report of Well Operations PBU 09-02A Pumped 1/4 gun load of(g ) Green stick into test void. 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 09-02A Greenstick IC test void Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-199 50-029-20198-01-00 13622 Conductor Surface Intermediate Liner Liner 8981 80 2691 10699 494 3381 13495 20" 13-3/8" 9-5/8" 7" 3-1/2" x 2-7/8" 8974 36 - 116 35 - 2726 33 - 10732 10238 - 10732 10241 - 13622 36 - 116 35 - 2726 33 - 8851 8462 - 8851 8464 - 8981 None 520 2670 4760 7020 10530 None 1530 5380 6870 8160 10130 10896 - 13545 7" 26# x 5-1/2" 17# x 4-1/2" 12.6# 13CR80 31 - 10294 8950 - 8977 Structural 4-1/2" Baker Model D, 10170 ,8410 No SSSV 10170 8410 Bo York Sr. Area Operations Manager 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 0028327 31 - 8506 Starting Head - IC test void Pumped approximately 1/4 cup of Greenstick into lower test void to 3500 psi for 1 hour. 101 109 876 9 5614 5483 1672 1678 241 254 N/A 13b. Pools active after work:PRUDHOE OIL 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 Ryan Holt Ryan.Holt@hilcorp.com (907)659- 5102 By Grace Christianson at 11:10 am, Dec 18, 2024 A.Dewhurst 13FEB25 RBDMS JSB 122624 WCB 2-6-2025 DSR-12/20/24 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 09-02A Greenstick IC test void Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-199 50-029-20198-01-00 13622 Conductor Surface Intermediate Liner Liner 8981 80 2691 10699 494 3381 13495 20" 13-3/8" 9-5/8" 7" 3-1/2" x 2-7/8" 8974 36 - 116 35 - 2726 33 - 10732 10238 - 10732 10241 - 13622 36 - 116 35 - 2726 33 - 8851 8462 - 8851 8464 - 8981 None 520 2670 4760 7020 10530 None 1530 5380 6870 8160 10130 10896 - 13545 7" 26# x 5-1/2" 17# x 4-1/2" 12.6# 13CR80 31 - 10294 8950 - 8977 Structural 4-1/2" Baker Model D, 10170 ,8410 No SSSV 10170 8410 Bo York Sr. Area Operations Manager Dave Wages David.Wages@hilcorp.com (713)380-9836 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 0028327 31 - 8506 Starting Head -IC test void Pumped approximately 9 cups of Greenstick into test void to final 3500psi 143 0 719 0 5654 6280 1870 1842 261 247 N/A 13b. Pools active after work:PRUDHOE OIL 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 Samantha Coldiron at 11:07 am, Feb 09, 2024 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.02.09 10:42:02 - 09'00' Eric Dickerman (4002) RBDMS JSB 021324 WCB 2024-06-25 DSR-2/13/24 ACTIVITYDATE SUMMARY 1/9/2024 T/I/O = SSV/1800/500. Temp = SI. Greenstick IC test void, Start OART (eval IAxOA). AL SI @ lateral valve, no IA companion valve. Heater installed on IC test void. IC test void has hoke valve installed. Pumped 1/4 gun of geenstick into test void to 3500 psi. Held pressure for 1 hr, no loss of pressure. IC test void appears to be packed off. Ops POP'd during IC greensticking. Bled OAP from 500 psi to 30 psi in 20 min, gas. Monitor for 1 hr. During monitor OAP increased 50 psi. OART tag hung on OA. Final WHP's = 260/1850/70. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00 1/11/2024 T/I/O = 300/1840/190. Temp = 130°. WHPs (post greenstick OART). ALP = 1840 psi, SI @ LV. SV = C. WV, SSV, MV = O. IA, OA = OTG. 20:30 Daily Report of Well Operations PBU 09-02A Pumped 1/4 gun of geenstick into testgg void to 3500 psi. Held pressure for 1 hr, no loss of pressure. IC test void appears to be packed off. Ops POP'd during IC greensticking 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:PB Wells Integrity To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Oliver Sternicki; Bo York; PB Wells Integrity Subject:OPERABLE: Producer 09-02A (PTD #2151990) OART passed after greenstick re-treatment Date:Wednesday, January 31, 2024 11:03:17 AM Mr. Regg, DHD re-treated the IC-test void on 01/09/24. A follow up OART showed a re-pressurization rate of ~35 psi/day. The re-pressurization is considered to be manageable by periodic bleeds. The well will now be classified back to OPERABLE. 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 <PBWellsIntegrity@hilcorp.com> Sent: Friday, January 5, 2024 10:39 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer 09-02A (PTD #2151990) OA casing pressure above MOASP Mr. Regg, Producer 09-02A (PTD # 2151990) was reported to have OA casing pressure above MOASP on 01/04/24 after the well was shut-in for an unplanned shutdown at FS2. The OA casing pressure was 1,237 psi. The well has a history of unmanageable IAxOA communication that has been remedied by treating the IC-packoff test void with greenstick. The well will now be classified as UNDER EVALUTION and is on the 28-day clock for diagnostics and repair. Plan forward: 1. DHD: Re-treat IC-test with greestick 2. DHD: OART (outer-annulus re-pressurization test) 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. PBU 09-02A PTD 2151990 Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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Development Exploratory Service 5 Permit to Drill Number:215-199 6.50-029-20198-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13622 13581 8979 10170 None None 8410 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 1530 520 Surface 2691 13-3/8" 35 - 2726 35 - 2726 5380 2670 Intermediate 10699 9-5/8" 33 - 10732 33 - 8851 6870 / 8150 4760 / 5080 Production 494 7" 10238 - 10732 8462 - 8851 8160 7020 Perforation Depth: Measured depth: 12551 - 13545 feet True vertical depth:8971 - 8977 feet Tubing (size, grade, measured and true vertical depth)7" 26# x 5-1/2" 17# x 4-1/2" 13Cr80 30 - 10294 10170 8410Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker Model D Packer Liner 3381 3- 1/ 2" x 2- 7/ 8" 10241 - 13622 8464 - 8981 10160 / 10570 10530 / 11160 12. Stimulation or cement squeeze summary: Intervals treated (measured): Pump approximately 2.5 packing guns of Greenstick plastic packing. Final pressure = 5000 psi Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2621330487523 00 0 0 0 0 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: Torin Roschinger torin.roschinger@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(406)570-9630 Treatment descriptions including volumes used and final pressure: 13. Sr 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 Stratigraphic 15. Well Class after work: 5Service 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 measured8981 Sundry Number or N/A if C.O. Exempt: N/A Junk Packer Printed and Electronic Fracture Stimulation Data 5 Wellhead Repair Operations shutdown Change Approved Program 5 Plastic Pack IC Packoff Test 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 Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028327 PBU 09-02A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Meredith Guhl at 10:30 am, Sep 29, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.09.29 08:09:22 -08'00' Bo York SFD 9/29/2021MGR15OCT2021 SFD 9/29/2021 RBDMS HEW 9/30/2021 SFD 9/29/2021 DSR-9/29/21 ACTIVITYDATE SUMMARY 8/6/2021 T/I/O = SSV/700/700. Temp SI. Green stick re-pack IA packoff (IA/ OA eval). Gauge installed on upper ball valve at 700 psi, bleed void 10 min with no pressure drop. Attempt to pump plastic though lower ball valve with little success. Void should communicate though upper & lower ball valves, Schedule IA / OA bleed for another attempt. 8/7/2021 T/I/O = SSV/740/740. Temp = SI. Bleed IAP & OAP to 0+ psi (Pre Greenstick). No IA companion. AL SI @ LV. TBG FL @ 2200' (82 bbls). IA FL @ 9797' (#10 SO, 375 bbls). OA FL @ near surface. Bled IAP to OT from 740 psi to 0 psi in 6 hrs. Bled OAP to BT from 740 psi to 0+ psi (Gas) and held open during WH work. Final WHPs = SSV/0+/0+. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:20 8/7/2021 T/I/O = SSV/0/0. Temp SI. Green stick re-pack IA packoff (IA/ OA eval) RU packing gun to CSG packoff lower test void, attempt to pump plastic though void with returns to upper test port with no success. Remove LDS 90° from test port and attempt to pump green stick from lower test port out LDS port with no success. Hardened Seal tight visible in LDS port, Repack green stick though lower port and hold at 5000 psi, pressure drop to 4000 psi and hold steady, close in ball valve. Rig up plastic pack gun to upper test port and pump approx. ½ volume of green stick to void and hold at 5000 psi with no returns to LDS port and no pressure drop. Close ball valve re-install LDS, secure well RDMO. 8/8/2021 T/I/O = 250/1140/30. Temp = SI. Manwatch to POP (post greenstick). ALP = 1140 psi, online. Upon arrival DSO stacking out well to POP. Ops POP at 02:30. Held open OA bleed during WH work. Pumped 1 load of Greenstick into upper IC test void port, and 1 load of Greenstick into lower IC test void port holding 5000 psi for 30 min, no loss of pressure. Test void appears to be packed off. SI OA bleed, monitored for 1 hr. OAP increased 240 psi. Monitored an additional hr. OAP increased 170 psi. Monitored an additional hr. OAP increased 140 psi. Bled IAP from 550 psi to 0+ psi in 5 min (Gas). Monitored during RD. OAP increased 20 psi. Final WHPs = 250/1690/20. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:50 8/8/2021 T/I/O = 250/1670/360. Temp = 124°. Bleed OAP as needed (Post Greenstick). ALP = 1670 psi, online. No IA companion valve. OAP increased 360 psi in 1 hr and 35 min from last bleed. OAP increased to 900 psi in 5 hrs (~75 to 80 psi every 30 min). Bled OAP to 0 psi, SI bleed and monitored. OAP increased to 545 psi in 1.5 hrs. Contacted DSO to SI well and bled IAP to OT to 690 psi in 1.5 hrs to keep OAP under NOL. Bled OAP to 0 psi. Monitored during RD. IAP unchanged. OAP increased 30 psi. Final WHPs = 250/690/30. SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:59 8/10/2021 T/I/O = SSV/640/630. Temp = SI. MIT-OA FAILED to 1092 psi (Eval IAxOA). No IA companion. AL SI @ LV. OA FL @ near surface. Max applied pressure = 1200 psi. Used 4.2 bbls Diesel to pressure OA to 1200 psi. OAP decreased 309 psi in the 1st 15 min, and 81 psi in the 2nd 15 min for a total of 390 psi in 30 min. Used 0.3 bbls Diesel to pressure OA to 1200 psi. On the 2nd attempt, OAP decreased 63 psi in the 1st 15 min and 41 psi in the 2nd 15 min for a total of 104 psi in 30 min. Pumped into OA for 30 min to establish OA LLR of 0.37 gpm @ 1200 psi. Bled OAP to 630 psi (0.3 bbls). Hung tags. Final WHPs = SSV/640/630. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:50 Daily Report of Well Operations PBU 09-02A Daily Report of Well Operations PBU 09-02A 8/14/2021 T/I/O = 255/635/620. Temp = SI. WHP's (pre Self Mold treatment). AL SI @ lateral valve, no companion valve. OA FL @ 85' (5 bbls) , no OA companion valve. Installed heater on CSG x TBG head connection. 8/15/2021 T/I/O = SSV/640/640. Temp = SI. Bleed IAP to 0 psi (Eval IA x OA). ALP = 640 psi, SI @ LV. No IA companion valve. IA FL @ 9797' (Sta #10, 375 bbls). Bled IAP to OT from 640 psi to 90 psi in 3 hrs. OAP decreased 120 psi during IA bleed. Monitored for 15 min during RD. Whps and IA FL unchanged. Final WHPs = SSV/90/520. SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:45 8/16/2021 T/I/O = SSV/90/420. Temp = SI. Bleed IAP to 0 psi (pre evac OA). IA FL @ 9797' (SO). Bled IAP to OT from 90 psi to 0 psi in 3 hrs. Maintained open bleed for 30 min. OAP decreased 140 psi. SI and monitor for 30 min. WHPs unchanged. Final WHPs = SSV/0/280. SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:45 8/16/2021 T/I/O = SSV/0/0. Temp = SI. Strap fluid in OA (Eval IA x OA). AL SI @ lateral valve, no IA casing valve. Performed a NFT on the OA. Removed the bull plug and strapped the OA FL @ 9'. Soft bottom @ ~39'. SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:10 8/16/2021 T/I/O = SSV/0/280. Temp = SI. Greenstick IC void (INCOMPLETE), evac liquid from OA (eval IAxOA). IA FL @ 9797' (SO). Bled OAP to BT from 280 psi to 0 psi in 25 min, held open bleed on IA & OA. Removed LDS on casing hanger @ the 10:00 position and the 2:00 position. RU PKG gun and injected Self mold (Greenstick) into IC test void from LDS profile (10:00). Worked self mold around test void from 9:00 to 3:00 positions. LDS @ the 4:00 position is broken, unable to verify if plastic is there. Pumped 2 full loads of green stick, will return in the AM for completion. FWHP's = SSV/0/0. SV, WV, SSV = C. MV = O. IA & OA = OTG. 18:30. 8/17/2021 T/I/O = SSV/0/0. Temp = SI. Greenstick IA test void (COMPLETE) ( eval IAxOA). IA FL @ 9797" (SO). AL SI @ lateral valve, no IA companion valve. RU PKG gun to the LDS profile in the 9:00 and 11:00 positions. Verified fresh plastic in the test void from 3:00 position to 9:00 position. Pumped 2 loads of plastic to work around the rest of the hanger void (9-11:00 position). Installed all LDS assemblies and packed plastic, held 5000 psi on gun for 1 hr, no loss in pressure. 8/18/2021 ***WELL S/I ON ARRIVAL***(pt integrity). SET 5-1/2" WHIDDON CATCHER SUB ON XO @ 10,151' MD. PULLED ST #8 RK-LGLV @ 8,840' MD. ***JOB CONTINUED ON 8/19/21 WSR*** 8/19/2021 ***JOB CONTINUED FROM 8/18/21 WSR***(pt integrity). PULLED ST #4 RK-LGLV @ 6,401' MD. PULLED ST #1 RK-LGLV @ 2,998' MD. PULLED ST #10 RK-OGLV @ 10,126' MD. SET ST #1 RK-DGLV @ 2,998' MD. SET ST #4 RK-DGLV @ 6,401' MD. 1 FAILED ATTEMPT TO SET ST #8 RK-DGL @ 8,840' MD. ***JOB CONTINUED ON 8/20/21 WSR*** Daily Report of Well Operations PBU 09-02A 8/20/2021 ***JOB CONTINUED FROM 8/19/21 WSR***pt integrity). RAN POCKET POCKER TO ST #8 8,840' MD. SET ST #8 RK-DGLV @ 8,840' MD. T-BIRD LOADED IA W/ 450 BBLS OF CRUDE. SET ST #10 RK-DGLV @ 9,797' MD. ***JOB CONTINUED ON 8/21/21 WSR, T-BIRD IN CONTROL OF WELL*** 8/20/2021 T/I/O=200/200/0 (TFS unit 2 Assist Slickline Load and Test) Pum ped 2 bbls of 50/50 and 450 bbls of crude down the IA to load. MIT-IA **PASSED** at 2490 psi. Max applied pressure=2500 psi. Target pressure=2250 psi. Pumped 5.5 bbls of crude down the IA to reach test pressure. 1st 15 min IA lost 5 psi. 2nd 15 min IA lost 5 psi. Total loss of 10 psi in 30 min test. Tag hung on IAC & WV. Valve positions= SV,SSV, WV= Colosed. MV= Open IAC, OAC= OTG FWHP= 100/100/150 8/21/2021 ***JOB CONTINUED FROM 8/20/21 WSR***(pt integrity). PULLED EMPTY 5-1/2" WHIDDON C-SUB FROM XO @ 10,151' MD. ***WELL LEFT S/I ON DEPARTURE, JOB COMPLETE*** 8/22/2021 T/I/O = SSV/400/20. Temp = SI. Eval liquid from OA (Eval IA x OA). AL spool removed. OA FL @ near surface. Bled the IAP to 0 psi (1 bbl, all fluid). Lubed a 50' hose into the OA. Used N2 to increase OAP and purge liquid up hose to BT (~3 bbls). Out of ime to rig 1502 fittings down. Bled the OAP to 0 psi. FWPs = SSV/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:30 8/23/2021 T/I/O = SSV/0+/0+. Temp = SI. Rig down hose (Post OA fluid removal). AL spool removed. Performed a NFT - OA. Removed hose from OA and rigged down 1502 fittings. Re-installed 3" flange. FWPs = SSV/0+/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:00 8/24/2021 T/I/O = SSV/Vac/0+. Temp = SI. Apply lift gas to IA in stages (eval IAxOA). AL spool removed. IA FL @ surface. Used lift gas from 09-01 to incrementaly increase IAP from vac to 1380 psi in 5 hrs. OAP unchanged during IAP increase. Left 1380 psi on IA for further eval of IAxOA. Final WHPs = SSV/1380/0+. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 8/26/2021 T/I/O = SSV/1350/7. Temp = SI. WHPs (eval IAxOA). AL disconnected. IAP decreased 30 psi, OAP increased 7 psi from 8/24/21. SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:30 8/29/2021 T/I/O = SSV/1330/8. Temp = SI. WHPs (eval IAxOA). AL disconnected. Integral installed on IA. IAP decreased 20 psi, OAP increased 1 psi from 8/26/21. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 8/30/2021 T/I/O = SSV/1330/9. Temp = SI. WHPs (eval IAxOA). AL disconnected. IAP unchanged, OAP increased 1 psi overnight. SV, WV, SSV = C. MV = O. IA, OA = OTG. 06:00 9/4/2021 ***WELL S/I ON ARRIVAL***(gas lift) SET 5 1/2 WCS ON 4 1/2 XO @ 10151' MD LRS PUMPED 270 BBLS CRUDE TO TUBING. PULLED STA # 4 RK-DMY FROM 6401' MD PULLED STA # 10 RK-DMY FROM 9798' MD ***WSR CONT ON 9/5/21*** 9/4/2021 T/I/O=450/3/20 Assist slickline (GAS LIFT-INTEGRITY) Pumped 270 bbls crude down Tbg to load. FWHP's= 250/0/20 SL in control of well upon LRS departure Daily Report of Well Operations PBU 09-02A 9/5/2021 ***WSR CONT. FROM 9/4/21*** PULLED STA #8 RK-DMY FROM 8840'MD PULLED STA #1 RK-DMY FROM 2998'MD SET STA #1 RK-DOME (16/64" TRO 1654PSI) @ 2998'MD SET STA #4 RK-DOME (20/64" TRO 1757PSI) @ 6401''MD ATTEMPT SET STA #8 RK-DOME (20/64" TRO 1766PSI) @ 8840''MD...POSSIBLE TRASH IN POCKET. ***WSR CONT ON 9/6/21*** 9/6/2021 ***WSR CONT FROM 9/5/21***(gas lift) RAN 1.5" POCKET POKER TO GLM # 8 @ 8840'MD SET RK-LGLV(20/64 - 1766PSI) IN GLM #8 @ 8840' MD. SET RK-OGLV(28/64) IN STA # 10 @ 9797' MD. PULLED EMPTY WCS FROM 10151' MD ***WELL LEFT S/I ON DEPARTURE*** Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:215-199 6.50-029-20198-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13622 13581 8979 10170 None None 8410 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 1530 520 Surface 2691 13-3/8" 35 - 2726 35 - 2726 5380 2670 Intermediate 10699 9-5/8" 33 - 10732 33 - 8851 6870 / 8150 4760 / 5080 Production 494 7" 10238 - 10732 8462 - 8851 8160 7020 Perforation Depth: Measured depth: 12551 - 13545 feet True vertical depth:8971 - 8977 feet Tubing (size, grade, measured and true vertical depth)7" 26# x 5-1/2" 17# x 4-1/2" 13Cr80 30 - 10294 10170 8410Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker Model D Packer Liner 3381 3- 1/ 2" x 2- 7/ 8" 10241 - 13622 8464 - 8981 10160 / 10570 10530 / 11160 12. Stimulation or cement squeeze summary: Intervals treated (measured): Pump approximately 2 packing guns of Greenstick plastic packing. Final pressure = 5000 psi Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2621330487523 00 0 0 0 0 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: Torin Roschinger torin.roschinger@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(406)570-9630 Treatment descriptions including volumes used and final pressure: 13. Sr 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 Stratigraphic 15. Well Class after work: 5Service 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 measured8981 Sundry Number or N/A if C.O. Exempt: N/A Junk Packer Printed and Electronic Fracture Stimulation Data 5 Wellhead Repair Operations shutdown Change Approved Program 5 Plastic Pack IC Packoff Test 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 Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028327 PBU 09-02A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Meredith Guhl at 2:23 pm, Jul 22, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.07.22 13:38:21 -08'00' Bo York MGR30JUL2021 RBDMS HEW 7/22/2021 SFD 7/28/2021DSR-7/22/21 ACTIVITYDATE SUMMARY 7/14/2021 T/I/O = SSV/550/550. Temp = SI. Bleed IAP & OAP to 0 psi (pre Greenstick CSG hanger). AL SI @ lateral valve (550 psi), no companion valve. IA FL @ 9797' (Sta# 10 SO, 375 bbls). OA FL @ near surface (65'). Bled IAP to OT from 550 psi to 60 psi in 3 hrs. Bled OAP from 550 to 70 psi in 3 hrs. SI bleed, monitor for 30 min. IAP remained at 60 psi, OAP increased 10 psi to 80 psi. IA & OA FL's remained unchanged during bleed. FWHP's = SSV/60/80. SV, WV, SSV = C. MV = O. IA & OA = OTG. 18:00. 7/15/2021 T/I/O = SSV/60/120. Temp = SI. Bleed IAP & OAP to 0 psi (Pre Greenstick). No IA companion. AL SI @ lateral. IA FL @ 9797' (#10 SO, 375 bbls). OA FL @ near surface. Bled OAP to BT from 120 psi to 0 psi (Gas) and held open during IA bleed. Bled IAP to OT from 60 psi to 0+ psi in 2 hrs 40 min (Gas). Monitored for 30 min. OAP increased 10 psi. Final WHPs = SSV/0+/10. SV = LOTO O. WV, SSV = C. MV = O. IA, OA = OTG. 11:30 7/17/2021 T/I/O = SSV/0/10. Temp = SI. Greenstick CSG hanger (eval IAxOA). No IA companion valve. AL SI @ lateral valve. IA FL @ 9797' (Sta#10 SO, 373 bbls). OA FL @ near furface. Bled OP to BT from 10 psi to 0 psi in 20 min. 9 5/8" is hung off of a mandrel hanger. RU packing gun tol CSG hanger test void. Pumped 2 loads of Self-mold (Greenstick) packing into hanger test void (approx 4 J sticks equivilant). Held pressure to 5000 psi for 30 min, no loss of pressure. Test void appears to be packed off. FWHP's = SSV/0/0. SV, WV, SSV = C. MV = O. IA & OA = OTG. 17:30. Daily Report of Well Operations PBU 09-02A Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:215-199 6.API Number:50-029-20198-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028327 Property Designation (Lease Number):10. 8. PBU 09-02A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown CTU Extended Addperf Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 13622 Effective Depth MD: 13Cr80 11. 6/1/2021 Commission Representative: 15. Suspended Contact Name: Torin Roschinger Contact Email: Torin.Roschinger@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8981 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool 10170, 8410 Date: Liner 3381 3- 1/ 2" x 2- 7/ 8" 10241 - 13622 8464 - 8981 10160 / 10570 10530 / 11160 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 35 - 2726 35 - 2726 14. Estimated Date for Commencing Operations: BOP Sketch 36 - 116 Structural 6870 / 8150 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker Model D Packer 12551 - 13545 8971 - 8977 7" 26# x 5-1/2" 17# x 4-1/2" 1 30 - 10294 Production 13581 8979 none none 36 - 116 520 13-3/8" 9-5/8" Contact Phone:(406) 570 - 9630 Date: 4760 / 5080 80 153020"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2691 5380 Production 10699 33 - 10732 33 - 8851 494 7"10238 - 10732 8462 - 8851 8160 7020 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2470 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 5-3-21 By Meredith Guhl at 1:52 pm, May 04, 2021 321-228 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.04 13:31:30 -08'00' Bo York MGR14MAY21 10-404 DLB05/04/2021 X DSR-5/5/21 dts 6/2/2021 JLC 6/2/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.02 15:59:34 -08'00' RBDMS HEW 6/4/2021 Z2B Addperfs 09-02A PTD: 215199 Well Name:09-02A Addperfs API Number: 50-029-20198-01 Current Status:Online Producer Rig:Slickline / Coil Estimated Start Date:Q2 2021 Estimated Duration:3 days Regulatory Contact:Carrie Janowski Permit to Drill Number:215199 First Call Engineer:Torin Roschinger (406) 570-9630 (c) Second Call Engineer: AFE Number: IOR 30 Current Bottom Hole Pressure:3332 psi @ 8,800’ TVD 7.3 PPGE | Taken 6/3/15 from 09-02 motherbore Maximum Expected BHP:3350 psi @ 8,800’ TVD 7.4 PPGE | Average Ivishak BHP) Max. Anticipated Surface Pressure:2470psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1000 psi (Taken on 03/29/2019) Min ID:2.377” 3-1/2”x2-7/8” XO @ 10,679’ MD Max Angle:94 Deg @ 12820’ Reference Log: 09-02A Baker GR/MPR - Log Dated 21-Jan-2016 Brief Well Summary: On 09-02A, a coiled tubing sidetrack was completed on Feb 6, 2016 with Nordic 1 to target ~650' of Zone 2B. The toe of the well was perf’d, but the Z2B in the heel was left as a future addperf opportunity. There has been very little intervention in this well other than the initial GL install and a subsequent GL change out for optimization. Current production rate is 117bopd; 5256 bwpd; 0mmscfd of gas; 0 GOR; and 98% WC in April 2021. Objective: The objective of this program is to increase production by shooting 180’ of addperfs in Z2B located in the heel of the well. Slickline 1. MIRU Slickline Unit and spot ancillary equipment. 2. RIH with a 2-1/8” sample bailer to deviation and collect sample if possible. If sample is collected please note in AWGRS and notify OE. Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. Bullhead 364bbls of KWF, 8.4 ppg 1% KCl or seawater down the tubing to the formation. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSL.) a. Wellbore volume to bottom perf = 303 bbls b. 4-1/2x5-1/2x7” Tubing – 2985’ X .0383bpf + 7166’ X .0232bpf + 90’ X .0152bpf = 282 bbls -00 * Z2B Addperfs 09-02A PTD: 215199 c. 3-1/2” Liner – 438’ X .0087bpf = 4 bbls d. 2-7/8” Liner – 2866’ X .0058bpf = 17 bbls (down to btm perf at 13,545’md) 3. MU and RIH with logging tools and drift BHA to resemble 2” dmy gun. Tag PBTD @ 13,581’md and log OOH. 4. POOH and confirm good data. 5. Freeze protect tubing as needed. 6. At surface, prepare for deployment of TCP guns. 7. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, 8.4 ppg 1% KCl or seawater as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. 8.Pickup safety joint and TIW valve and space out before MU guns.Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 9. Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. 09-02A Perf Schedule *2” perf guns were used to calculate gun weights. Perf Interval Perf Length Gun Length Weight of Gun (lbs) 10896-10956’ 11020-11080’ 11105-11165’ 180 269 1507lbs (5.6ppf) 10. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. POOH. a. Note any tubing pressure change in WSR. 11. POOH. Stop at surface to reconfirm well dead and hole full. 12. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 13. RDMO CTU. 14. RTP or FP well. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Mini Log 7. Tie In Log * Standing orders and flow chart included with this sundry. Make up PCE. Z2B Addperfs 09-02A PTD: 215199 Current Wellbore Schematic Proposed Schematic Z2B Addperfs 09-02A PTD: 215199 Z2B Addperfs 09-02A PTD: 215199 Coiled Tubing BOPs Z2B Addperfs 09-02A PTD: 215199 Equipment Layout Diagram Z2B Addperfs 09-02A PTD: 215199 Standing Orders for Open Hole Well Control during Perf Gun Deployment Z2B Addperfs 09-02A PTD: 215199 Mini Log Tie-In Log Z2B Addperfs 09-02A PTD: 215199 Z2B Addperfs 09-02A PTD: 215199 Z2B Addperfs 09-02A PTD: 215199 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:215-199 6.API Number:50-029-20198-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028327 Property Designation (Lease Number):10. 8. PBU 09-02A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown CTU Extended Addperf Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 13622 Effective Depth MD: 13Cr80 11. 6/1/2021 Commission Representative: 15. Suspended Contact Name: Torin Roschinger Contact Email: Torin.Roschinger@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8981 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool 10170, 8410 Date: Liner 3381 3- 1/ 2" x 2- 7/ 8" 10241 - 13622 8464 - 8981 10160 / 10570 10530 / 11160 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 35 - 2726 35 - 2726 14. Estimated Date for Commencing Operations: BOP Sketch 36 - 116 Structural 6870 / 8150 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker Model D Packer 12551 - 13545 8971 - 8977 7" 26# x 5-1/2" 17# x 4-1/2" 1 30 - 10294 Production 13581 8979 none none 36 - 116 520 13-3/8" 9-5/8" Contact Phone:(406) 570 - 9630 Date: 4760 / 5080 80 153020"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2691 5380 Production 10699 33 - 10732 33 - 8851 494 7"10238 - 10732 8462 - 8851 8160 7020 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2470 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 5-3-21 By Meredith Guhl at 1:52 pm, May 04, 2021 321-228 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.04 13:31:30 -08'00' Bo York MGR14MAY21 10-404 DLB05/04/2021 X DSR-5/5/21 dts 5/14/2021 JLC 5/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.14 15:26:45 -08'00' RBDMS HEW 5/17/2021 Z2B Addperfs 09-02A PTD: 215199 Well Name:09-02A Addperfs API Number: 50-029-20198-01 Current Status:Online Producer Rig:Slickline / Coil Estimated Start Date:Q2 2021 Estimated Duration:3 days Regulatory Contact:Carrie Janowski Permit to Drill Number:215199 First Call Engineer:Torin Roschinger (406) 570-9630 (c) Second Call Engineer: AFE Number: IOR 30 Current Bottom Hole Pressure:3332 psi @ 8,800’ TVD 7.3 PPGE | Taken 6/3/15 from 09-02 motherbore Maximum Expected BHP:3350 psi @ 8,800’ TVD 7.4 PPGE | Average Ivishak BHP) Max. Anticipated Surface Pressure:2470psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1000 psi (Taken on 03/29/2019) Min ID:2.377” 3-1/2”x2-7/8” XO @ 10,679’ MD Max Angle:94 Deg @ 12820’ Reference Log: 09-02A Baker GR/MPR - Log Dated 21-Jan-2016 Brief Well Summary: On 09-02A, a coiled tubing sidetrack was completed on Feb 6, 2016 with Nordic 1 to target ~650' of Zone 2B. The toe of the well was perf’d, but the Z2B in the heel was left as a future addperf opportunity. There has been very little intervention in this well other than the initial GL install and a subsequent GL change out for optimization. Current production rate is 117bopd; 5256 bwpd; 0mmscfd of gas; 0 GOR; and 98% WC in April 2021. Objective: The objective of this program is to increase production by shooting 180’ of addperfs in Z2B located in the heel of the well. Slickline 1. MIRU Slickline Unit and spot ancillary equipment. 2. RIH with a 2-1/8” sample bailer to deviation and collect sample if possible. If sample is collected please note in AWGRS and notify OE. Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. Bullhead 364bbls of KWF, 8.4 ppg 1% KCl or seawater down the tubing to the formation. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSL.) a. Wellbore volume to bottom perf = 303 bbls b. 4-1/2x5-1/2x7” Tubing – 2985’ X .0383bpf + 7166’ X .0232bpf + 90’ X .0152bpf = 282 bbls -00 * Z2B Addperfs 09-02A PTD: 215199 c. 3-1/2” Liner – 438’ X .0087bpf = 4 bbls d. 2-7/8” Liner – 2866’ X .0058bpf = 17 bbls (down to btm perf at 13,545’md) 3. MU and RIH with logging tools and drift BHA to resemble 2” dmy gun. Tag PBTD @ 13,581’md and log OOH. 4. POOH and confirm good data. 5. Freeze protect tubing as needed. 6. At surface, prepare for deployment of TCP guns. 7. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, 8.4 ppg 1% KCl or seawater as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. 8.Pickup safety joint and TIW valve and space out before MU guns.Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 9. Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. 09-02A Perf Schedule *2” perf guns were used to calculate gun weights. Perf Interval Perf Length Gun Length Weight of Gun (lbs) 10896-10956’ 11020-11080’ 11105-11165’ 180 269 1507lbs (5.6ppf) 10. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. POOH. a. Note any tubing pressure change in WSR. 11. POOH. Stop at surface to reconfirm well dead and hole full. 12. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 13. RDMO CTU. 14. RTP or FP well. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. 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ILI O m ~ CCOCO CO c CO COCOW E a O I, d COin 1 H y ' dN N CO CO d W .0 — m ' - > E E Z N 7 2 w m Ce p M y Z Q O Q O co w �', C C U U 0 0 0 `o y J o N ,a y na E a. v 0 a O g ° Fc; uN w E E 0 d 0 0 0 0 0 d LL o 8 a) 0 o m d o o d W W w w Z U d o V 0 Q V 0 3 e,-,,VL0 i ill L;;iii STATE OF ALASKA �LASKA OIL AND GAS CONSERVATION COMM MAR 0 2 2016 WELL MPLETION OR RECOMPLETION REP AND LOG �wyQ/�� (/�,�/�►, la. Well Status: Oil 0 • Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 0 lb.Well Cla s�`'*� `-'`°' 20AAC 25.105 20AAC 25.110 Development p Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: One Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 2/6/2016 • . 215-199 • 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 1/23/2016 • 50-029-20198-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 2/2/2016 PBU 09-02A • Surface: 170'FSL,697'FEL,Sec.02,T1ON,R15E,UM ' 9 Ref Elevations KB 54 17. Field/Pool(s): Top of Productive Interval: 1358'FNL,4049'FVVL,Sec.12,T1ON,R15E,UM GL 19.92 BF 20.72 • PRUDHOE BAY,PRUDHOE OIL ' Total Depth: 1916'FNL,3 POC RAIL,Sec.12,T1ON,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: L1. 13581'/8979' ADL 028327 ' 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 717719' y- 5941618 ' Zone - ASP 4 - 13622'/8981' - 74-017 TPI: x- 722509 y- 5940230 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 721577 y- 5939645 Zone - ASP 4 N/A 1900'(Approx.) 5. Directional or Inclination Survey: Yes Ll (attached) No 0 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Vdndow MD/TVD: Submit electronic and printed information per 20 AAC 25.050 None (ft MSL) 10732'/8851' • 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD/GR/RES 23. CASING,LINER AND CEMENTING RECORD CASING wr.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. - PULLED TOP BOTTOM TOP BOTTOM 20" 94# H-40 36' 116' 36' 116' 32" 250 sx Arctic Set Cement 13-3/8" 72# MN-80 35' 2726' 35' 2726' 17-1/2" 4350 sx Arctic Set Cement 9-5/8" 47# S00-95/MN-80 33' 10732' 33' 8851' 12-1/4" 1500 sx Class'G',115 sx Arctic Set Cement 7" 29# 13Cr80 10238' 10732' 8462' 8851' Scab Liner 175 sx Class'G' 3-1/2"x 2-7/8" 9.3#/6.5# 13Cr85 10241' 13622' 8464' 8981' 4-1/4" 240 sx Class'G' 24. Open to production or injection? Yes Q No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 7",26#x 5-1/2",17# 10294' 10170'/8410' 2"Gun Diameter,6 spf x 4-1/2", 12.6#, 13Cr80 12551'-12656' 8971'-8969' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 12770'-12801' 8970'-8969' COMPLETION 12918'-13141' 8963'-8958' DATE Was hydraulic fracturing used during completion? Yes 0 No IRI • 13262'-13545' 8963'-8977' _____:21(1/11,2 I Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 2500' Freeze Protect w/96 Bbls Diesel 27. PRODUCTION TEST Date First Production: February 25,2016 Method of Operation(Flowing,gas lift,etc.):N/A Flowing Date of Test: 2/26/2016 Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 6 Test Period �► 114 108 608 S5 947 Flow Tubing 0 Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press 60 24 Hour Rate 455 431 2432 N/A Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only V rL- 3, 3/1. /3�z` �RBDMS Lt-- MAR 0 3 2016 3-2�w 28. CORE DATA Conventional Core(s) Yes ❑ No 0 Sidewall Cores Yes 0 No WI ' If Yes to either question,list formations and inteored(MD+TVD of top and bottom of each),and summar41ology and presence of oil,gas or water (submit separate sheets with this form,if needed. ubmit detailed descriptions,core chips,photographs and la tory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No l Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 10813' 8909' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Base of CGL-Zone 2C 10734' 8852' 23SB-ZONE 2B 10813' 8909' Formation at total depth: Zone 2B 10813' 8909' 31. List of Attachments: Summary of Daily Drilling Reports,Well Schematic Diagram,Survey,Cement Report Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Minge, David Email: David.Minge@bp.com Printed Name: Joe Lastu a Title: Drilling Technologist Signature: Okl,- Phone: +1 907 564 4091 Date:3/2//l0 INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only TREE= •WELLHEAD= FMC GEN1 SOYNOTES:WELLANGLE>-70°@10900'. ACTUATOR= 0 9_0 2 `.r# ***CHROME LNR& TBG***MAX DLS:39.3°@ OKB.ELEV= 54, JMD DRAFT 10930'. REF..B BI= 54 BF.B_EV= 20.72' /Ji co 2231' -17"CAM BAL-O SSSV NP,D=5.937"1 KOP= 3079' Max Angle= 94°@ 12820 __._......_. 2$85'_I-17"X 5-112"XQ D=4.892" Datum MD= 10736' \ GAS LFT MANDRELS Datum TVD-= 8800'SS — ST MD TVD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,MN-80,D=12.347' - 2726' 1 2998 2997 8 FMHO DOME RK 16 02/21/16 2 4619 4434 42 FMHO DMY RK 0 08/26/91 7"TBG,26#,13CR-80,.0383 bpf,D=6.276' H 2985' 3 5724 5221 45 FM-JO DMY RK 0 05/20/97 4 6401 5713 43 FMHO SO RK 20 02121/16 5 7035 6159 47 FM-I0 DMY RK 0 08/26/91 Minimum ID = 2.377" @ 10679' 6 7707 6626 45 FMHO DMY RK 0 08/26/91 3-1/2" X 2-7�8" XO **7 8295 7055 42 FMt JO DMY RK 0 08126/91 8 8840 7454 44 FMHO DMY RK 0 06/07/15 9 9424 7870 45 FM-JO DMY FE 0 08126/91 10 9797 8136 44 RHO DMY RK 0 06/07/15 11 10126 8379 41 FM-40 WED RKP 0 05/20/92 5-1/2"TBG,17#,13CR-80,.0232 bpf,ID=4.892" 10151' "*CANNOT PULL ST#7 AS OF 6/19/97 _1----1 10151' --I5-1/2'X 4-1/2"XO,D=3.958' 10153' -I BKR GBH-22 LOCATOR SEAL ASSY,D=? 10154' H9-5/8"X 4-1/2'BKR MODEL D PKR,tO 1 9-5/8"X 7'TIEBACK SLV,D=? 10222' 10168' -5'MILLOUT EXTENSION,10=? 9-5/8"X7. BKR&LNR HGR,ID=? -1 10230' - 10174' MLLOUT EXTSION XO TO 4-1/2",0=3.958" (- . 10241' -3.70"DEPLOYMENT SLV,D=3.00' I 10262' H 3-1/2"HRS X MP,D=2.812- 4-1/2"TBG, 12.6#,13CR-80,.0152 bpf,D=3.958" 1 10278' PERFORATION SUMMARY ! 10265' H4-1/2"OTIS XN NP MLLED 3.80"(12/4/15)... 10277'J-4-1/2"BKR SI-EA ROUT SUB,N3=? REF LOG: ON / / � \ NOTE:GR does not correlate w/BHCS due to'HOT'deposits 10278' H4-1/2"TUBNG IAL,D=3.958" ANGLE AT TOP PERF: 90°@ 12551' 10282' --i ELMD TT LOGGED 09/06/91 Note:Refer to Production OB for historical pert data .411: SEE SPF INTERVAL Opn/Sgz DATE 10453' --17'MARKERJOINT SEE PAGE 2 FOR PERFORATION INFORMATION 10474' -17"MARKER JONT I I 3-1/2"LNR,9.3#,13CR 85 STL, - 10679' 10679' H 3 1/2"X 2-7/8"XO,D=2.377" .0087 bpf,ID=2.992" MLLOUT WINDOW(09-02A)10732'-10743' 7'BKR DELTA WHIPSTOCK(12/08/15) H 10728' CBVEYT®WS N PLACE(12/14/15) H -10730' --._, 12400' -i PUP JT w/RA TAG CMT DUMP(12/08/15) -I -1075W =. 7"POSISET PLUG(12/04/15) -{ 10770' A••-•y0.9•., INTER WELL 350-700 HDC PLUG, H 10846' ---....- lift _ ME@ 10850'(11/11/12) �• _ . ._......_ __ FISH:IBP RUBBER ELEMENT(03/26/96) ? aft FISH:2 SMALL PIECES OF SPINNER HOUSING 11003' ■ PBTD -I 11055' r11111111 PBTD - 13581' 7"LNR 29#,13CR-80,.0371 bpf,D=6.184' H 11099' .*11/111/1/1/1/14. 11111111111 - ' 1111 4 444 2-7/8'LNR,6.5#,13CR 85 STL, - 13622' 9-5/8"CSG,474/,500-95/M4-80,ID=8.681" H 11153' 11111111111111111111 11111111111 .0058 bpf,ID=2.441" TD H 11199' , 8.1.1.88.4.8...•. DATE REV BY COMMENTS DATE REV BY COINIENTS PRLOHOE BAY UNIT 03/22/76 IMTIAL COMPLETION 02/12/16 JTG/JMD GLV C/O(02/21/16) WELL: 09-02A 08/25/76 ROW 34 RWO 02/25/16 TR/JMD UPDATED WS DBTTH,FIFE TY PES PERMIT No:"2151990 10/20/87 PAA 102 RWO 03/01/16 TR/JMD ADDED REF.ELEV AR Na: 50-029-20198-01 08/27/91 RWO SEC 2,T1ON,R15E,170'FSL&69T FEL 02/06/16 NORDICI CTD(09-02A) 02/08/16 JMD DRLG HO CORRECTIONS BP Exploration(Alaska) TREE= SA.NOTES:WELL ANGLE>—70°© 10900'. VtEll FEAR_ FMC GEN 1 • 09-02A "* OME LNR& TBG"`MAX DLS:39.3° ACTUATOR= 10930'. OKB.ELEV= 54' BF.8EV= I I KOP= 3079' Max Angle= 94" a 12820' Datum MD= 10736' Datum TVD= 8800'SS 101 J ;11( • • PERFORATION SUM1n ARY REF LOG: ON_/_I_ NOTE.GR does not correlate w/BHCS due to-1-IOr deposits ANGLE AT TOP FEW: 90°©1255V Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12551 -12656 0 02/05/16 2" 6 12770-12801 0 02/05/16 .. 2" 6 12918-13141 0 02/05/16 2" 6 13262-13545 0 02/05/16 ' •:r....**r. ■ 41111immir ,� • ••11111111111111/•1 111111111111111111111 111111111111111111111 !!!•!!!!!!� DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MT 03/22/76 INTIAL COMPLETION 02/22/16 JTG/JMD GLV C/O(02/21/16) WELL: 09-02A 08/25/76 ROW 34 RWO 02/25/16 TR/JMD UFDA IED WS DEPTH,PPE TYPES FERMI No: 2151990 10/20/87 PAA 102 RWO AR No: 50-029-20198-01 08/27/91 RVVO SEC 2,T1 ON,R15E,170'FSL&697'FEL 02/06/16 NORDIC1 CTD(09-02A) 02/08/16 JMD DRLG HO CORRECTIONS BP Exploration(Alaska) • • North America-ALASKA-BP Page 1 of 24 Operation Summary Report ' Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 I Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 I 54.00usft(above Mean Sea Level) Date From-To Hrs Task Code III NPT NPT Depth I Phase Description of Operations (hr) (usft) 1/20/2016 14:00 - 16:00 2.00 MOB P PRE PJSM.TEST ESD.JACK UP RIG AND PULL OFF OF 09-01.MOVE OVER TO 09-02. -WSL VERIFIED CHOCK BLOCK IN FRONT OF DRIVE WHEEL -ESD SWITCH FUNCTIONED PRIOR TO MOVE AND MANNED BY TOOL PUSHER 1-ALL SPOTTERS VERIFIED RADIO COMMUNICATIONS DURING SAFETY MEETING -THE AGREED COMMAND OF"STOP" DISCUSSED DURING SAFETY MEETING -TEST ESD,BACK OVER WELLAND SPOT UP. RIG ACCEPTED 16:00 HRS,01/20/2016. 16:00 - 17:00 1.00 BOPSUR P PRE PJSM.SPOT CUTTINGS BOX AND FUEL TRAILER. -RIG UP GUAGE GUARDS AND SENSORS. -RIG UP TIGER TANK. 17:00 - 21:30 4.50 BOPSUR P PRE PJSM.CYCLE TREE VALVES. -PERFORM LEAK TIGHT TEST ON MASTER VALVE AND SWAB VALVE TO 3500 PSI,OK. -N/D TREE CAP.N/U BOPE.INSTALL 2'SLB SPACER SPOOL. -FUNCTION AND GREASE HCR VALVE. WELL WORK TRANSFER PERMIT CLOSED OUT ON 09-01 WELL,NO ISSUES. 21:30 - 22:00 0.50 BOPSUR P PRE HOLD H2S/RIG EVACUATION DRILL. -ALL HANDS MUSTERED TO PRIMARY MUSTER AREA. -DRILL SITE OPERATOR NOTIFIED AND HEAD COUNT DONE. -AAR AND REVIEWED PROCEDURE FOR RIG EVACUATION. 22:00 23 30 1.50 BOPSUR P PRE PJSM.INSTALL TEST PLUG. -INSTALL NIGHT CAP AND FLUID PACK SURFACE LINES. -RIG UP TEST EQUIPMENT AND SHELL TEST 250/4500 PSI,5 MIN EACH,OK. 23:30 - 00:00 0.50 BOPSUR P PRE PERFORM INITIAL TEST ON BOPE AS PER IAOGCCAND BP REQUIREMENTS. AOGCC REP JOHNNIE HILL WAIVED WITNESSING THE TEST©23:30 HRS. Printed 2/22/2016 1:03.10PM •a North America-ALASKA-BP Page 2 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 , Spud Date/Time:2/16/1976 12:00:00AM ;Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 r©54.00usft(above Mean Sea Level) Date From-To ] Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1/21/2016 00:00 - 07:00 7.00 BOPSUR P PRE -PRESSURE TEST ALL BOP EQUIPMENT AS PER AOGCC REGS,PTD#215-200,AND CRT-AK-10-45 -TEST BOPE TO 250/3500 PSI FOR 5 CHARTED MIN EACH. -TEST CHOKE VALVES,CHOKE AND KILL HCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES,BOP RAMS AND ANNULAR PREVENTER(3500 PSI) -ALL VARIABLE PIPE RAMS TESTED WITH 2 3/8"-3 1/2"TEST JOINT -2 3/8"PIPE RAMS TESTED WITH 2 3/8"TEST JOINT -BLIND RAMS.TESTED ON OPEN HOLE AGAINST TEST PLUG.. ANNULAR TESTED WITH BOTH 2 3/8"AND 3 1/2"TEST JOINT -TEST FULL OPENING SAFETY VALVE -ALL TESTS ON ALL RAMS AND VALVES,250/ 3500 PSI/5 MIN EACH/CHARTED. -PERFORM ACCUMULATOR DRAW DOWN TEST. -FUNCTION BOP FROM BOTH REMOTE -PANELS ALL TEST WITNESSED BY DRILLER,RIG MANAGER OR BP WSL -AOGCC INSPECTOR JOHNNIE HILL WAIVED THE STATES RIGHT TO WITNESS THE TEST. -24 HOUR NOTIFICATION GIVEN TO THE AOGCC ON 1/19/2015 @ 07:45 HRS. 07:00 - 09:30 2.50 BOPSURP PRE CONTINUE TESTING ON CRITICAL PATH -TEST BULKHEAD,COIL AND INNER REEL VALVE©250/4700 PSI. -PERFORM H2S/RIG EVACUATION DRILLS (OFF CRITICAL PATH) 09:30 - 10:30 1.00 BOPSUR P PRE CIRCULATE DIESEL OUT OF REEL -FILL REEL WITH FRESH WATER FOR SLACK MANAGEMENT 10:30 - 15:00 4.50 BOPSUR P PRE PERFORM SLACK MANAGEMENT -CUT OFF BTT COIL CONNECTOR -INSTALL BOOT ON E-LINE -STAB ONTO WELL -PUMP SLACK INTO REEL -CUT 300'COIL -INSTALL SLB COIL CONNECTOR&TEST SAME -CIRCULATE 1 REEL VOLUME FORWARD -HEAD-UP WITH BHI UQC/LQC&TEST SAME 15:00 - 15:15 0.25 BOPSUR P PRE HELD PJSM FOR PU VALVE SHOP LUBRICATOR 15:15 - 17:45 2.50 BOPSUR P PRE PULL TWC -LOAD LUBRICATOR TOOLS ONTO RIG -RU LUBRICATOR AND STAB ONTO WELL -PRESSURE TEST 250 LOW/3500 HIGH -LATCH INTO TWC AND PULL FROM WELL -WELL ON A VACUUM -CLOSE MASTER/SWAB VALVES -RD VALVE SHOP LUBRICATOR 17:45 - 18:00 0.25 BOPSUR P PRE INSTALL NIGHT CAP -CIRCULATE ACROSS TOP TO FILL WELL -CLEAN RIG FLOOR Printed 2/22/2016 1:03:10PM North America-ALASKA-BP Page 3 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 1 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM ,Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 18:00 - 18:30 0.50 BOPSUR P PRE PJSM AND GREASE TREE VALVES. -HOLD PJSM WITH VALVE SHOP GREASE CREW. -GREASE MASTER AND SWAB VALVES. 18:30 - 19:00 0.50 BOPSUR P PRE FLOW CHECK WELL. -OPEN TREE VALVES AND VERIFY 0 PSI. -POP OFF NIGHT CAP AND FLOW CHECK 30 MIN-NO FLOW. 19:00 - 20:00 1.00 STWHIP P WEXIT PJSM AND MU MILLING BHA. -PU 2-7/8"XTREME MOTOR WITH 0.6°AKO. MU WINDOW MILL AND STRING MILL. WSL GAGE AND VERIFY MILLS 3.80"OD. -MU 2 JTS 2-3/8"PH6 AND CARRY SCRIBE. MU 3"COILTRAK AND TEST MWD TOOLS. 20:00 - 22:30 2.50 STWHIP P WEXIT RIH WITH MILLING ASSEMLBY SURFACE TO 10,700'MD. -TEST OTS TO 250/3500 PSI FOR 5/5 MIN. -RIH 100'/MIN WITH 1.49/2.02 BPM IN/OUT. -MW IN/OUT:8.33/7.74 PPG. -LOG TIE-IN WITH-14.5'CORRECTION. -WELL FLUIDS:METHANOL FREEZE PROTECT TO 2500'MD,1%KCL TO WHIPSTOCK AT 10,725'MD. -RIH CIRC 1%KCL DOWN COIL.TAKE ALL RETURNS TO TIGER TANK 22:30 - 00:00 1.50 STWHIP P WEXIT DISPLACE WELL TO 8.6 PPG MILLING FLUID. -2.90/2.90 BPM IN/OUT WITH 1275 PSI. -MW IN/OUT:8.34/8.58 PPG. -TAKE KCL RETURNS TO TIGER TANK 1/22/2016 00:00 - 01:30 1.50 STWHIP P WEXIT CONTINUE DISPLACE WELL TO 8.6 PPG MILLING FLUID. -3.17/3.17 BPM IN/OUT WITH 2210 PSI. -MW IN/OUT:8.65/8.35 PPG. -TAKE KCL RETURNS TO TIGER TANK -RIH AND DRY TAG WHIPSTOCK AT 10,732' MD. -PU AND TAG PUMPS ON 10,732'MD. 01:30 - 06:00 4.50 STWHIP P WEXIT MILL WINDOW 10,732'-10,734'MD -FS:2190 PSI MTR WRK:50-100 PSI WOB: 0.5-1.0K# -BPM IN/OUT:2.76/2.76 PVT:202 BBLS -MW IN/OUT:8.63/8.58 PPG -ECD/IA/OA:9.26 PPG/455 PSI/90 PSI -TIME MILL AT 1'/HR. 06:00 - 12:00 6.00 STWHIP P WEXIT MILL WINDOW 10,734.6'-10,736.2'MD -FS:2190 PSI MTR WRK:50-100 PSI WOB: 2.0-3.5K# -BPM IN/OUT:2.77/2.77 -MW IN/OUT:8.60/8.56 PPG -IA/OA/PVT:625 PSI/143 PSI/169 BBLS 12:00 - 16:00 4.00 STWHIP P WEXIT MILL WINDOW 10,736.2'-10,736.8'MD -FS:2190 PSI MTR WRK:50-100 PSI WOB: 2.0-3.5K# -BPM IN/OUT:2.77/2.77 -MW IN/OUT:8.60/8.56 PPG -IA/OA/PVT:638 PSI/176 PSI/165 BBLS ***PERFORM MUD SWAP FROM USED POWERPRO TO FLOWPRO SYSTEM*** Printed 2/22/2016 1:03:10PM North America-ALASKA-BP Page 4 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 18:30 2.50 STWHIP P WEXIT MILL WINDOW 10,736.8'-10,737.1'MD -FS:2190 PSI MTR WRK:50-100 PSI WOB: 2.0-3.5K# -BPM IN/OUT:2.77/2.77 -MW IN/OUT:8.60/8.56 PPG - -- -IA/OA/PVT:638 PSI/176 PSI/165 BBLS 18:30 - 22:00 3.50 STWHIP P WEXIT MILL WINDOW 10,737.1'-10,737.1'MD FS:2190 PSI MTR WRK:50-100 PSI WOB: 2.0-3.5K# -EIPM IN/OUT:2.77/2.77 -MW IN/OUT:8.56/8.48 PPG -IA/OA/PVT:707 PSI/220 PSI/290 BBLS 22:00 - 00:00 2.00 STWHIP P WEXIT MILL WINDOW 10,737.1'-10,737.9'MD FS:2190 PSI MTR WRK:50-100 PSI WOB: 2.0-3.5K# -BPM IN/OUT:2.77/2.77 -MW IN/OUT:8.56/8.48 PPG -IA/OA/PVT:707 PSI/220 PSI/290 BBLS 1/23/2016 00:00 - 04:00 4.00 STWHIP I P WEXIT MILL VVINDOW'10,737.9'-10,741.1'MD -FS:2190 PSI MTR WRK:50-100 PSI WOB: 2.0-3.5K# BPM IN/OUT:2.77/2.77 MW IN/OUT:8.56/8.48 PPG IA/OA/PVT:717 PSI/242 PSI/288 BBLS 1-WT ON BIT FELL OFF 10,739.3'TO.6-1K. 04:00 - 07:30 3.50 STWHIP P WEXIT MILL WINDOW 10,741.1'-10,745'MD -FS:2190 PSI MTR WRK:50-100 PSI WOB: .7-1.2K# -BPM IN/OUT:2.77/2.77 -MW IN/OUT:8.56/8.48 PPG -IA/OA/PVT:717 PSI/249 PSI/289 BBLS 07:30 - 09:30 2.00 STWHIP P WEXIT MILL 10'NEW FORMATION F/10,744'-10,754' MD MM IN/OUT:2.74/2.74 CIRC PSI:2153 -MW IN/OUT:8.52 PPG/8.48 PPG -IA/OA/PVT:708/259/284 -WOB/ECD:0.5-2K/9.03 PPG 09:30 - 12:00 , 2.50 STWHIP P WEXIT REAM AND DRESS VNNDOW PER PLAN -MM IN/OUT:2.74/2.74 CIRC PSI:2153 -MW IN/OUT:8.52 PPG/8.48 PPG ***DRY DRIFT WINDOW(NO ISSUES NOTED) 12:00 - 12:15 0.25 STWHIP P WEXIT FLOW CHECK 12:15 - 14:00 1.75 STWHIP P WEXIT POOH WITH MILLING ASSEMBLY F/10,755'- 200'MD -MM IN/OUT:3.82/3.25 CIRC PSI:2585 -MW IN/OUT:8.53 PPG/8.49 PPG -FLOW CHECK(GOOD) 14:00 - 14:30 0.50 STWHIP P WEXIT LD MILLING ASSEMBLY HOLD PJSM FOR LD MILLING ASSEMBLY -GET OFF WELL WITH INJECTOR(1410) -LD MILLING ASSEMBLY -GUAGE MILL:3.79 GO 3.78 NO GO -STRING:3.80 GO 3.79 NOGG 14:30 - 15:45 1.25 DRILL P PROD1 MU BUILD ASSEMBLY -HOLD PJSM ON RIG FLOOR -MU DIRECTIONAL/MWD TOOLS -GET ON WELL WITH INJECTOR(15:20) INITIALIZE MWD TOOLS -PRESSURE TEST QTS Printed 2/22/2016 1:03:10PM i S North America-ALASKA-BP Page 5 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:45 - 18:00 2.25 DRILL P PROD1 RIH VVITH BUILD ASSEMBLY -MM IN/OUT:3.82/3.25 CIRC PSI:550 -MW IN/OUT:8.47 PPG/8.49 PPG 18:00 - 18:30 0.50 DRILL P PROD1 CIRCULATE AT 10,500'MD -LOG TIE IN @ 10,520', MINUS 12.5' CORRECTION. 18:30 - 21:30 3.00 DRILL P PROD1 NORDIC PERFORMING REPAIRS ON GENERATOR#1. RISK ASSESSMENT FILLED OUT AND SIGNED OFF ON BY NORDIC SUPERINTENDANT AND TOOL PUSHER. REPLACED DSM AND TCB, REPROGRAMMED AND FUNCTION TESTED, OK. 21:30 - 00:00 2.50 DRILL P PROD1 RIH,SMOOTH THRU WINDOW. -TAG @ 10,757'AND BEGIN DRILLING BUILD SECTION. -DRILL 4.25"BUILD SECTION F/ 10,757'- 10,865 MD -FS:2465 PSI MTR WRK:100-250 PSI WOB:1.5-3.5K# ECD 9.1 -BPM IN/OUT:2.9/2.9 -MW IN/OUT:8.54/8.51 PPG { IA/OA/PVT:652 PSI/228 PSI/275 BBLS 1/24/2016 00:00 - 02:00 2.00 DRILL P PROD1 -DRILL 4.25"BUILD SECTION F/ 10,865' 10,925 MD -FS:2465 PSI MTR WRK:100-250 PSI WOB:1.5-3.5K# -BPM IN/OUT:2.9/2.9 -MW IN/OUT:8.54/8.51 PPG -IA/OA/PVT:652 PSI/228 PSI/275 BBLS 02:00 - 03:30 1.50 DRILL P PROD1 POOH TO 10,760',OPEN EDC AND CONTINUE TO 10,530'. -LOG F/10,530'- 10,780' @ 5 FPM.PLUS 1' CORRECTION. 03:30 - 06:00 2.50 DRILL P T PROD1 RBIH AND CONTINUE DRILLING BUILD SECTION. -DRILL 4.25"BUILD SECTION F/10,925'- 11,005'MD(LAND BUILD) -MM IN/OUT:3.00/3.00 CIRC PSI:2550 FS:2450 -MW IN/OUT:8.56 PPG/8.52 PPG -IA/OA/PVT:715/256/276 -WOB/ECD:2-4K/9.15 06:00 - 08:15 2.25 DRILL P PROD1 PJSM.10 MIN FLOW CHECK.WELL STATIC -POOH W/BUILD ASSEMBLY. -MM IN/OUT:3.82/3.22 CIRC PSI:2605 -MW IN/OUT:8.57 PPG 18.55 PPG 08:15 - 08:30 0.25 DRILL P PROD1 FLOW CHECK -HOLD PJSM FOR CHANGING BHA 08:30 - 09:30 1.00 DRILL P PROD1 CHANGE BUILD BHA -GET OFF WELL WITH INJECTOR(0830) -STAND BACK MWD TOOLS -GUAGE BIT(2-2) -CHANGE AKO MOTOR SETTING -MU DIRECTIONAL LATERAL ASSEMBLY -GET ON WELL WITH INJECTOR(0910) 1-INITIALIZE MWD TOOLS -PRESSURE TEST QTS Printed 2/22/2016 1:03:10PM • i North America-ALASKA-BP Page 6 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 09:30 - 11:30 2.00 DRILL P PROD1 RIH WITH 4.25"LATERAL ASSEMBLY -MM IN/OUT:3.40/3.95 CIRC PSI:2285 MW IN/OUT:8.57 PPG/8.55 PPG 11:30 - 12:45 1.25 DRILL P PROD1 LOG TIE-IN -DEPTH CORRECTION(-15) -LOG CCL F/10,150'-10,400'MD -RIH TO WINDOW 10,730'MD FINGERPRINT WELLBORE:1 BBL RIH TO BOTTOM 12:45 - 18:00 5.25 DRILL P PROD1 DRILL 4.25"LATERAL SECTION F/ 11,005'- 11,180'MD -MM IN/OUT:3.04/3.04 CIRC PSI:2776 FS:2550 -MW IN/OUT:8.56/8.53 PPG IA/OA/PVT:803 PSI/328 PSI/276 BBLS -WOB/ECD:1-4.5K/9.16 PPG "•PERFORMED COMPLEX D2 KICK WHILE DRILLING DRILL.SIMULATED 2 BBLS PIT GAIN,LOW METHANE GAS ALARM ON RIG FLOOR,LOSS OF ANNULAR PRESSURE AT THE ACCUMULATOR.DRILLER RESPONDED PROPERLY TO EACH FAILED COMPONENT. AAR HELD AT THE END OF THE DRILL.TIME TO SECURE WELL:3 MINS 15 SECONDS. TOTAL DRILL TIME:15 MINS 18:00 - 22:00 4.00 DRILL P PROD1 -DRILL4.25"LATERAL SECTION F/ 11,180'- 11,425'MD -MM IN/OUT:3.04/3.04 CIRC PSI:2776 FS:2550 -MW IN/OUT:8.56/8.53 PPG -IA/OA/PVT:1094 PSI/470 PSI/276 BBLS -WOB/ECD:1-4.5K/9.22 22:00 - 00:00 2.00 DRILL P PROD1 -DRILL 4.25"LATERAL SECTION F/ 11.180'- 11,425'MD -MM IN/OUT:3.04/3.04 CIRC PSI:3186 FS:2800 -MW IN/OUT:8.56/8.53 PPG -IA/OA/PVT:1094 PSI/470 PSI/276 BBLS -WOB/ECD:3-4.5K/9.29 1/25/2016 00:00 - 01:45 1.75 DRILL P PROD1 PERFORM LONG WIPER TRIP.POOH 30- 40 FPM. -PUMP SWEEP,20 BBLS LO VIS FOLLOWED BY 20 BBLS HI VIS. -OPEN EDC JUST ABOVE THE WINDOW AND PUMP @ 3.8 BPM/2750 PSI. -POOH TO 10,450',PUMPING SWEEP TO SURFACE.SLIGHT INCREASE IN CUTTINGS W/SWEEP BACK. 01:45 - 02:30 0.75 DRILL P PROD1 LOG TIE IN,10,530'-10,560'.ADD 1' CORRECTION. -CLOSE EDC,RBIH DOWN TO 10,425'. 02:30 - 06:00 3.50 DRILL P PROD1 -DRILL 4.25"LATERAL SECTION F/ 11,425'- 11,495 MD -MM IN/OUT:3.04/3.04 CIRC PSI:2776 FS:2550 -MW IN/OUT:8.56/8.53 PPG -IA/OA/PVT:555 PSI/502 PSI/292 BBLS -WOB/ECD:1-4.5K/9.22 -VERY TOUGH,SHALY DRILLING. Printed 2/22/2016 1:03:10PM • North America-ALASKA-BP Page 7 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:OOAM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 06:00 - 10:30 4.50 DRILL P PROD1 DRILL 4.25"LATERAL SECTION F/ 11,495'- 11,595 'MD MM IN/OUT:3.04/3.04 CIRC PSI:2776 FS:2550 -MW IN/OUT:8.64/8.59 PPG -IA/OA/PVT:591 PSI/502 PSI/292 BBLS -WOB/ECD:1-4.5K/9.22 10:30 - 11:00 0.50 DRILL P PROD1 POOH F/11,595'-10,700'MD. MM IN/OUT:3.04/2.80 CIRC PSI:2695 -MW IN/OUT:8.65/8.63 PPG 11:00 - 12:00 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP -MM IN/OUT:4.35/4.4.35 CIRC:3445 -MW IN/OUT:8.67 PPG/8.62 PPG 12:00 - 14:00 2.00 DRILL P PROD1 POOH F/10,700'-200'MD. -MM IN/OUT:3.04/2.80 CIRC PSI:2695 -MW IN/OUT:8.65/8.63 PPG 14:00 - 15:15 1.25 DRILL P PROD1 ,CHANGE DIRECTIONAL ASSEMBLY HELD PJSM FOR LD DIRECTIONAL TOOLS -STAND BACK INJECTOR(1410) -LD DIRECTIONAL TOOLS -GRADE BIT(1-1) ;-INCREASE AKO MOTOR SETTINGS(1.35) MU DIRECTIONAL TOOLS GET ON WELL WITH INJECTOR(1505) -INITIALIZE MWD TOOLS) -PRESSURE TEST QTS 15:15 - 18:45 3.50 DRILL P PROD1 !RIH WITH LATERAL ASSEMBLY F/200'-11,595' IMD -MM IN/OUT:0.93/1.43 CIRC PSI:775 -MW IN/OUT:8.59 PPG/8.61 PPG -LOG TIE-IN(-16')CORRECTION -RIH TO BOTTOM 18:45 - 23:00 4.25 DRILL P PROD1 WT TRANSFER ISSUES ON BOTTOM. ATTEMPT TO DRILL,PICK UP,SEE TIGHT SPOTS,PULL HEAVY @ 11,480',(65K UP WT). -WORK BACK TO BOTTOM. DRILL AHEAD F/11,595'. -DRILL 4.25"LATERAL SECTION F/ 11,595'- 11,682'MD MM IN/OUT:2.95/2.95 CIRC PSI:3275 FS:2800 -MW IN/OUT:8.56/8.53 PPG -IA/OA/PVT:510 PSI/491 PSI/286 BBLS -WOB/ECD:1-4.5K/9.22 -ROP INCREASING... NOT GETTING ENOUGH BUILD,NEED TO GO UP AND TO THE RIGHT. -NOTIFY ODE AND POOH TO DIAL UP AKO ON THE MOTOR. 23:00 - 00:00 1.00 DRILL P PROD1 PJSM.PUMP(20)BBLS LO VIS SWEEP FOLLOWED BY(20)BBLS HI VIS SWEEP. -PUMPING @ 2.8 BPM/2850 PSI,POOH @ 30 FPM.OPEN EDC @ WINDOW,FLOW CHECK. -WELL STATIC,8.6 PPG MUD IN AND OUT. Printed 2/22/2016 1:03:10PM • • North America-ALASKA-BP Page 8 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:OOAM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UVVI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1/26/2016 00:00 - 01:00 1.00 DRILL N DPRB 10,430.00 PROD1 EDC OPEN, BRING PUMP UP TO 3.85 BPM/ 2700 PSI. CONTINUE TO POOH,30 FPM,CHASING SWEEPS OUT. —@ 10,350',LOST RETURNS AND PULLED TIGHT,(PACKED OFF). -WORK PIPE DOWN HOLE,STACKED OUT, WORKED FREE. -PUMPING 2 BPM/NO RETURNS,FREE UP AND POOH SLOWLY. -NOTIFY FIELD SUPERINTENDANT @ 01:00 AND ADVISE AND GET ADVICE. 01:00 - 06:00 5.00 DRILL N DPRB 10,430.00 PROD1 RIH @ 5-10 FPM,PUMPING 1.5 BPM,NO RETURNS. ORDER MORE MUD AND PULL TIGHT COMING UP. -TEMPORARILY DETAINED,BLED OFF ALL PRESSURE AND FREED UP GOING DOWN. -WORK DOWN TO WINDOW AND POOH SLOWLY.PRESSURE UP ANNULUS TO 1000 PSI. NO RETURNS,PRESSURE ON ANNULUS HOLDING.NOTIFY TOWN WTLAND ODE. -CONTINUE WORKING PIPE UP AND DOWN F/ 10,430'-10,700'. -PUMP DOWN COIL AND OCCASIONALLY PRESSURE UP ANNULUS TO ATTEMPT TO GET FLUID MOVING. -UP WT 49K,DOWN WT 17K.MIX 30 BBLS LO VIS W/10 BBLS WATER AND PUMP DOWN COIL. -1.9 BPM/2000 PSI,NO RETURNS.PUMP COIL VOLUME AND GET PILL COMING OUT AT BIT. 06:00 - 06:45 0.75 DRILL N DPRB 10,430.00 PROD1 CONTINUE WORKING TO CLEAN-UP PACK-OFF ZONE -BLEED DOWN PRESSURE FROM BACKSIDE (OPEN EDC) -WORK COIL UP/DOWN F/10,640'-10,610' MD -MM IN/OUT:0.50/0.05 CIRC PSI:650 -SLOWLY WORK UP AND DOWN GRADUALLY INCREASING FLOW RATE -INCREASE MM IN:1.5 BPM(PACK-OFF BROKE FREE) -SLOWLY WORK COIL UP HOLE WHILE INCREASING PUMP RATES -JET LOW VIS PILL OUT OF EDC AT 4 BPM -MM IN/OUT:4.15/4.15 CIRC PSI:3014 (FULL RETURNS) 06:45 - 08:00 1.25 DRILL N DPRB 10,430.00 PROD1 CIRCULATE HOLE CLEAN -CIRCULATE BOTTOMS UP F/10,600'-MD -WORK UP TO 4-1/2"TUBING TAIL -MM IN/OUT:4.15/4.15 CIRC PSI:3036 -MW IN/OUT:8.69 PPG/8.7 PPG ***INITIAL BOTTOMS UP SHOWS VERY STICKY CLAY/SAND MIXTURE OF CUTTINGS. ***NO CLAY BALLS OR LARGE CUTTING SEEN AT SURFACE. Printed 2/22/2016 1:03:10PM • • North America-ALASKA-BP Page 9 of 24 Operation Summary Report Common Wet Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 09:00 1.00 DRILL N DPRB 10,430.00 PROD1 CIRCULATE 2ND BOTTOMS UP -CIRCULATE BOTTOMS UP WORKING COIL UP F/10,600'-10,200'MD -WORK UP TO 5-1/2"TUBING TAIL -MM IN/OUT:4.15/4.15 CIRC PSI:3036 -MW IN/OUT:8.69 PPG/8.7 PPG ***CIRCULATE HIGH VIS SWEEP F/10,700'TO CLEAN HOLE 09:00 - 09:35 0.58 DRILL P PROD1 RIH F/10,200'-11,100'MD -CLOSE EDC AT WINDOW MM IN/OUT:3.00/3.15 CIRC PSI:2523 MW IN/OUT:8.68 PPG/8.60 PPG ***WORK THRU INTERVAL F/10,725'-10,850' MD.REAM DOWN TO 11,100'MD. ***PUMP 10 BBLS HIGH VIS SWEEP.CHASE OUT OF HOLE. 09:35 - 10:40 1.08 DRILL P PROD1 !POOH F/11,100'-10,700'MD -MM IN/OUT:2.95/2.86 CIRC:2450 -MW IN/OUT:8.67 PPG/8.60 PPG -OPEN EDC;CIRCULATE BOTTOMS UP INSIDE WINDOW. 10:40 - 13:00 2.33 DRILL P PROD1 POOH FROM 10,700'TO 3000'MD. -POOH 20'/MIN FROM WINDOW TO TUBING TAIL. -MM IN/OUT:3.87/3.76 BPM. -MW IN/OUT:8.69/8.61 PPG. -PULL HEAVY AND SEE PRESSURE INCREASE(PACKOFF)AT 10,340'MD WITH BHA GOING THRU TUBING TAIL. -RIH AND REGAIN FULL CIRCULATION.POOH SLOW(15'/MIN)AND JET TUING TAIL TO 10,200'MD. CONITNUE POOH 90'/MIN TO 3000'MD. -MM IN/OUT:3.87/3.42 BPM. MW IN/OUT:8.69/8.62 PPG. 13:00 - 13:30 0.50 DRILL P PROD1 CIRC BU INSIDE 7"TUBING FROM 3000'MD. -4.22/4.22 BPM IN/OUT WITH 3354 PSI. -MW IN/OUT:8.72/8.65 PPG. '13:30 - 14:30 1.00 DRILL P PROD1 POOH FROM 3000'MD TO SURFACE. -55'/MIN WITH 3.72/3.42 BPM IN/OUT. -MW IN/OUT:8.70/8.63 PPG. 14:30 - 15:30 1.00 DRILL P PROD1 PJSM AND LD DRILLLING BHA. FLOW CHECK AT SURFACE,NO FLOW. -POP OFF,STAND BACK INJECTOR. -BLOW DOWN BHA. 1- LD MOTOR AND BIT. -BIT GRADE:1-1-BU-A-X-I-NO-BHA. -LD 3"COILTRAK. -CHANGE MOTOR FROM 1.35°TO 1.64°AKO. 15:30 - 16:00 0.50 DRILL P PROD1 PJSM AND MU DRILLING BHA. -PU 3"COILTRAK AND MU MOTOR AND BIT. -PU INJECTOR AND GET ON WELL. -PRESS TEST QTS 300/3500 PSI FOR 5/5/MIN. 16:00 - 18:30 2.50 DRILL P PROD1 RIH WITH DRILLING BHA. 95'/MIN WITH 3.33/3.85 BPM IN/OUT. -MW IN/OUT:8.69/8.62 PPG. -PUMP 10 BBL HI-VIS SWEEP INSIDE 7" TUBING. -LOG TIE-IN WITH-15'CORRECTION. Printed 2/22/2016 1:03:10PM • North America-ALASKA-BP IP Page 10 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 20:00 1.50 DRILL P PROD1 RIH AND WORK TO BOTTOM. -TAKE WT AT VARIOUS DEPTHS,11,270', 11,531'&11,625'. START 9.5 PPG FLO PRO AROUND. 20:00 - 22:30 2.50 DRILL P PROD1 -DRILL 4.25"LATERAL SECTION F/ 11,682'- 11,755'MD -MM IN/OUT:3.04/3.04 CIRC PSI:3365 FS:2990 -MW IN/OUT:9.48/9.45 PPG IA/OA/PVT:535 PSI/472 PSI/241 BBLS -VNOB/ECD:3-4.5K/10.2 22:30 - 00:00 1.50 DRILL P PROD1 DRILL 4.25"LATERAL SECTION F/ 11,755'- 11,840'MD -MM IN/OUT:3.04/3.04 CIRC PSI:3124 FS:2990 -MW IN/OUT:9.49/9.44 PPG -IA/OA/PVT:535 PSI/472 PSI/238 BBLS -WOB/ECD:1-4.5K/10.2 1/27/2016 00:00 - 01:45 1.75 DRILL P PROD1 -DRILL4.25"LATERAL SECTION F/ 11,840'- 11,900'MD -MM IN/OUT:3.01/3.01 CIRC PSI:3365 FS:2990 MW IN/OUT:9.49/9.46 PPG -IA/OA/PVT:535 PSI/472 PSI/241 BBLS -WOB/ECD:1-4.5K/10.2 01:45 - 03:30 1.75 DRILL C 11,900.00 PROD1 PJSM.PUMP(20)BBLS LO VIS SWEEP FOLLOWED BY(20)BBLS HI VIS SWEEP.3 BPM/2975 PSI. -W/SWEEPS OUT AT BIT,SLOWLY POOH. STARTED TO PULL HEAVY W/SIGNS OF PACKING OFF @ 11,065'. -RBIH SLOWLY AND BEGIN TO STACK POOH ©3-5 FPM AND THINGS CLEANED UP. -CONTINUE PUMPING SWEEPS OUT AND MAKE(3)PASSES F/10,850'TO WINDOW, (CLEAN). 03:30 - 04:45 1.25 DRILL C 11,900.00 PROD1 OPEN EDC,PULLABOVE WINDOWAND CBU, 4.5 BPM/4050 PSI. -SOME INCREASE IN CUTTINGS ACROSS SHAKER WHEN SWEEPS BACK. -FAIR AMOUNT OF CLAY/ROUNDED OFF SHALE IN THE DIFFUSER BOX. -MICRO MOTION SHOWS(12)BBLS LOST TO FORMATION W/CIRC BOTTOMS UP. 04:45 - 06:45 2.00 DRILL C 11,900.00 PROD1 FLOW CHECK,10 MIN/9.5 PPG MUD IN AND OUT,WELL STATIC. POOH W/LATERAL DRILLING BHA. -POOH @ 40 FPM,SEE IT START TO PULL HEAVY AND PACKING OFF @ 10,355'BIT DEPTH. '-RBIH,GET FULL RETURNS,POOH @ 5 FPM PUMPING 3.75 BPM/3245 PSI. !-SLOW DOWN TO 2 FPM WHEN @ 10,355' AND STILL SEE INTERMITTENT DECREASE IN RETURN RATE. -CONTINUE ON 00H WITH THINGS SMOOTHING OUT. 06:45 - 06:50 0.08 DRILL C 11,900.00 PROD1 AT SURFACE,JOG IN HOLE TO FLUSH ANY POTENTIAL CUTTINGS OUT BEFORE SHUTTING DOWN TO FLOW CHECK Printed 2/22/2016 1:03:10PM North America-ALASKA-BP • Page 11 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To j Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (usft) 06:50 - 07:10 0.33 DRILL C 11,900.00 PROD1 SHUT DOWN AND FLOW CHECK WELL WHILE RIG CREW FINISHES WALK AROUND AFTER CREW CHANGE -HOLD A PJSM TO PU THE INJECTOR, INSPECT PIPE AND LD THE DRILLING BHA -GOOD NO FLOW 07:10 - 07:45 0.58 DRILL C 11,900.00 PROD1 PU THE INJECTOR TO INSPECT PIPE -PIPE LOOKS GOOD -07:15 AT THE BHA -07:40 BHA OOH,BIT GRADE=1-1 07:45 - 08:00 0.25 DRILL C 11,900.00 PROD1 HOLD PJSM TO MU THE BILLET BHA 08:00 - 08:40 0.67 DRILL C 11,900.00 PROD1 MU BHA -VERIFY HIGH SIDE IS BETWEEN THE 2 UPPER SLIPS -08:15 BHA MU TO COIL -08:25 SHALLOW TEST BHA AND TEST QTS -08:35 OPEN EDC 08:40 - 10:50 2.17 DRILL C 11,900.00 PROD1 RIH,PUMP TRIP PRESSURE SET AT 850 PSI AND SET DOWN WT ADJUSTED WHILE RIH AT 2K LESS THAN RIH WT -10:35 LIGHT SET DOWN AT 10292' (UNCORRECTED),PU CLEAN,RIH CLEAN 10:50 - 11:05 0.25 DRILL C 11,900.00 PROD1 IF AT 0°,LOG TIE IN 11:05 - 11:25 0.33 DRILL C 11,900.00 PROD1 CORRECT DEPTH-16.5',RIH TO WINDOW -UP WT=43.2 K -SHUT DOWN PUMP AND CLOSE THE EDC -SETTING DOWN WT WHILE PASSING THROUGH THE WINDOW,PU LOOKS CLEAN -RIH AND SET DOWN AT 10736.8'WITH 4.6K DOWN -PU AT 44K JUST OVER PU WT 11:25 - 11:45 0.33 DRILL X DPRB 11,900.00 PROD1 SET DOWN 4 TIMES AT THIS DEPTH.BTT HAND WANTS TO CALL HIS MANAGER TO DISCUSS HOW MUCH WT THEIR COMFORTABLE SETTING DOWN CALL ODE AND INFORM 11:45 - 12:25 0.67 DRILL X DPRB 11,900.00 PROD1 10K MAX WT DOWN BUT DO NOT USE THE WOB SUB AS IT HAS A 3 SECOND DELAY SET CTDS INJECTOR TRIP TO 6K<THAN RIH WT BTT IS CONCERNED WITH WEAKENING THE SHEAR PINS ON THE TOOL,EACH SET DOWN IS WORKING THE PINS AGREE ON 3 MORE TIMES TO PASS THEN CALL SET DOWN 7K AT 10737.6',PU IS CLEAN SET DOWN AT 10737.4'WITH 7.22K DOWN SET DOWN AGAIN AT SAME DEPTH 10737.3' WITH 7.3 K DOWN OPEN EDC TO CIRCULATE AND CALL ODE TO DISCUSS OPS 12:25 - 14:10 1.75 DRILL X DPRB 11,900.00 PROD1 POOH FOR CLEAN OUT BHA HOLD A PJSM TO LD THE BHA 14:10 - 14:20 0.17 DRILL X DPRB 11,900.00 PROD1 FLOW CHECK WELL Printed 2/22/2016 1:03:10PM SNorth America-ALASKA-BP • Page 12 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:20 - 14:50 0.50 DRILL X DPRB 11,900.00 PROD1 GOOD NO FLOW,TAG UP AND LD THE BHA -14:30 INJECTOR OFF 14:50 - 15:00 0.17 DRILL P PROD1 BHA OOH,PREP TO CUT COIL FOR CHROME MANAGEMENT 15:00 - 15:10 0.17 DRILL P PROD1 HOLD PJSM TO CUT COILAND REHEAD 15:10 - 15:40 0.50 DRILL P PROD1 PU INJECTOR AND REMOVE UQC AND CUT OFF CTC RU CUTTER AND CUT 100'OF PIPE 15:40 - 16:20 0.67 DRILL P PROM' MU CTC AND PULL TEST 16:20 - 17:00 0.67 DRILL P PROD1 MU BHI UQC PT CTC AND UQC 17:00 - 17:30 0.50 DRILL P PROD1 RIG DOWNIEST EQUIPMENT AND REMOVE NIGHT CAP 17:30 - 18:00 0.50 DRILL X DPRB 11,900.00 PROD1 GET 3.5"NOZZLE FROM N2 18:00 - 18:30 0.50 DRILL X DPRB 11,900.00 PROD1 CREW CHANGE 18:30 - 19:30 1.00 DRILL X DPRB 11,900.00 PROD1 PJSM.M/U NOZZLE BHA TO CLEAN UP WHIP STOCK AREA. 19:30 - 21:45 2.25 DRILL X DPRB 11,900.00 PROD1 RIH W/CLEAN OUT BHA, -PUMPING 3.87 BPM/3575 PSI. -FLOW CHECK @ 7500',9.5 PPG MUD IN AND .OUT,WELL BORE STATIC. CONTINUE IN HOLE,94 FPM/PUMPING 3.85 BPM/3560 PSI. 21:45 - 22:00 0.25 DRILL X DPRB 11,900.00 PROD1 LOG TIE IN F/10,690'-10,717',MINUS 18' CORRECTION. -NOTED 200 PSI INCREASE IN PUMP PRESSURE. 22:00 - 23:00 1.00 DRILL X DPRB 11,900.00 PROD1 CONTINUE IN HOLE.20K DOWN WT. -PUMP LO VIS/HIO VIS SWEEP.4 BPM/3765 PSI. -RIH TO 10,751',SWEEP OUT NOZZLE,PICK UP TO TOW. -38K UP WT.4.1 BPM/3775 PSI.MAKE(3) PASSES THRU WINDOWAREA. 23:00 - 23:45 0.75 DRILL X DPRB 11,900.00 PROD1 CIRCULATE BOTTOMS UP,4.17/4200 PSI. 23:45 - 00:00 0.25 DRILL X DPRB 11,900.00 PROD1 RIH TO 10,759'.PUMPING 3.5 BPM/3163'. -TAG UP,STACK 5K,SEE PRESSURE INCREASE AND RETURNS DROPPING OFF. -PICK UP TO WINDOW,RBIH,SLOW PUMP RATE TO 1.4 BPM/950 PSI,TAG UP CO 10,761'.- 1/28/2016 00:00 - 01:15 1.25 DRILL X DPRB 11,900.00 PROD1 I ATTEMPT TO WORK 3.5"NOZZLE PAST 10,761'. -TRY SLOWER PUMP RATES,NO GOOD. -TRY WITH NO PUMP,UNABLE TO GET PAST 10,761'. 01:15 - 02:45 1.50 DRILL X DPRB 11,900.00 PROD1 PJSM.FLOW CHECK,9.5 PPG MUD IN AND OUT,WELL BORE STATIC. -POOH W/NOZZLE/DRIFT CLEANOUT BHA. -FLOW CHECK WELL AT SURFACE,9.5 PPG MUD IN AND OUT,WELL BORE STATIC. 02:45 - 03:30 0.75 DRILL X DPRB 11,900.00 PROD1 PJSM.BREAK OFF OF WELL,STAND BACK INJECTOR. -L/D CLEANOUT ASSEMBLY. 03:30 - 03:45 0.25 DRILL P PROD1 PJSM.CHANGE OUT PACKOFFS ON COIL INJECTOR. -FUNCTION TEST BOPE,OK. Printed 2/22/2016 1:03:10PM SNorth America-ALASKA-BP • Page 13 of 24 Af .,..-,, ,r. urArie ,i,'ekwo r4'es r VW! J%Wa -/i�,PAFWrXT,�griiy -',yf � ��Operation Summary Report 4 '�* rev �rde �: , Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:1/20/2016 I End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 I Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor NORDIC CALISTA I UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:45 - 05:15 1.50 DRILL P PROD1 PJSM.ATTEMPT TO TEST PACK OFFS AGAINST SWAB VALVE. -TEST PACK OFFS t 250/3500 PSI/5 MIN EACH. 05:15 - 05:30 0.25 DRILL P PROD1 GOOD TEST ON PACK OFFS 05:30 - 06:00 0.50 DRILL X DPRB 11,900.00 PROD1 PJSM TO MU THE BHA 06:00 - 06:20 0.33 DRILL X DPRB 11,900.00 PROD1 "BHA MU,MU INJECTOR AND STAB ON WELL SHALLOW TEST BHA AND TEST QTS 06:20 - 08:15 1.92 DRILL X DPRB 11,900.00 PROD1 ,GOOD SHALLOW TEST,OPEN EDC AND RIH FINE CUTTINGS COMING ACROSS SHAKER AND SEEING SOME PEA SIZE PEBBLES AS WELL 08:15 - 08:35 0.33 DRILL X DPRB 11,900.00 PROD1 LOG TIE IN 08:35 - 08:40 0.08 DRILL X DPRB 11,900.00 PROD1 CORRECT DEPTH-16'AND RIH 08:40 - 09:20 0.67 DRILL X DPRB 11,900.00 PROD1 STOP ABOVE THE WINDOW,CLOSE THE EDC,ORIENT TO 14°ROHS AND RIH SET DOWN AT 10740'AT MIN RATE PU AND BRING PUMP TO FULL RATE AND WORK DOWN MADE IT PAST 10740 CLEAN,NO MOTOR WORK CONTINUE RIH AT 5 FPM TO 10761' 10758'GETTING A LITTLE MOTOR WORK,TAG AT 10761'WITH-1.3K WOB PU AND RIH AT FASTER SPEED-10-15 FPM MADE IT PAST AT 14 FPM WITH-0.5K TO 1.1K WOB 200-300 PSI MOTOR WORK START 20 BBL EACH LOW&HIGH VIS PILLS DOWN HOLE TAG AT 10794.9' PU TO 10700 THE RIH 09:20 - 10:00 0.67 DRILL X DPRB 11,900.00 PROD1 MADE IT PAST 10795,CONTINUE DOWN TO 10850 'MADE IT TO 10850 FAIRLY CLEAN PU TO 10700' PU WAS CLEAN,RIH AND START 20 BBL LOW &HIGH VIS PILLS 10:00 - 10:50 0.83 DRILL X DPRB 11,900.00 PROD1 CLEANED OUT TO 10900'AS PER OCN,PUH TO 10700' CLEAN TO 10700,RIH RECIPROCATE PIPE TO LET PILLS COME OUT THEN PUH TO START DRESSING WINDOWAS PER OCN#5 10:50 - 12:10 1.33 DRILL X DPRB 11,900.00 PROD1 10750,START FIRST BACKREAM PASS UP AT 1 FPM AT 29°ROHS HAVING TROUBLE GETTING INJECTOR TO MAINTAIN 1 FPM 11:15 REAM DOWN AT 1 FPM FROM 10729 TO 10750 11:40 REAM UP FROM 10750 TO 10720 12:10 - 12:45 0.58 DRILL X DPRB 11,900.00 PROD1 FINISHED WITH REAM PASSES,DRY DRIFT AS PER OCN DRY DRIFT IS CLEAN,OPEN EDC TO JET ACROSS WS TRAY FOR 3 PASSES PUMPING 20 BBLS EACH LOW&HIGH VIS PILLS Printed 2/22/2016 1:03:10PM • North America-ALASKA-BP • Page 14 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:45 - 14:35 1.83 DRILL X DPRB 11,900.00 PROD1 PILLS OUT,POOH CHASING TO SURFACE PULLING THROUGH 7"SECTIONS AT 80-90% FIRST LOW HIGH VIS PILLS FROM WINDOW DID NOT HAVE ANY INCREASE IN CUTTINGS SECOND LOW&HIGH VIS PILLS FROM 10761 DID NOT PRODUCE ANY INCREASE IN CUTTINGS THIRD LOW&HIGH VIS PILLS SMALL 'INCREASE IN CUTTING 14:35 - 14:40 0.08 DRILL X DPRB 11,900.00 PROD1 50'JOG IN HOLE LOOKING FOR INCREASE IN CUTTINGS,-20%THEN CLEANED UP 14:40 - 14:55 0.25 DRILL X DPRB 11,900.00 PROD1 HOLD A PJSM TO LD THE MILLING BHA AND FLOW CHECK THE WELL 14:55 - 15:10 0.25 DRILL X DPRB 11,900.00 PROD1 GOOD NO FLOW,TAG UP AND REMOVE THE INJECTOR 04:55 INJECTOR.OFF 15:10 - 15:25 0.25 DRILL X DPRB 11,900.00 PROD1 BHA OOH PARABOLIC MILL GAUGED 2.77 GO 2.76 NO GO STRING MILL GAUGED 2.79 GO 2.78 NO GO HOLD A PJSM TO MU THE BILLET BHA 15:25 - 15:55 0.50 DRILL X DPRB 11,900.00 PROD1- MU BHA 15:55 - 16:10 0.25 DRILL X DPRB 11,900.00 PROD1 STAB ON AND SHALLOW TEST TOOLS AND PT THE QTS 16:10 - 19:00 2.83 DRILL X DPRB 11,900.00 PROD1 OPEN EDC AND RIH CIRC MAX RATE. -TIE IN WITH-15'CORRECTION. 19:00 - 19:30 0.50 DRILL X DPRB 11,900.00 PROD1 RIH AND SET BILLET ON DEPTH. -PUW=43K,SOW=20K ABOVE WINDOW. -CLOSE EDC AND RIH 20'/MIN. -SEE MAX 1.38K WOB WITH BILLET IN WINDOW.SLIDE PAST. -SEE MAX 0.32K WOB IN OPEN HOLE. -RIH TO 10,883.46'MD.TOP OF BILLET AT 10,840'MD. -PU TO 40K UP WT AND SET BILLET. -ONLINE WITH PUMPS AT 0.4 BPM.SEE SHEAR AT 4100 PSI. -SET DOWN 5.2K WOB AND CONFIRM SET. -PU AND SEE BREAKOVER AT 43K- RELEASED FROM BILLET. 19:30 - 23:00 3.50 DRILL C 11,900.00 PROD1 POOH WITH BILLET RUNNING TOOLS. -POOH INSIDE WINDOW CIRC 2.5 BPM ACROSS WHIPSTOCK -OPEN EDC,CIRC 20 BBL HI-VIS SWEEP. -POOH 6'/MIN WITH 3.75/3.66 BPM IN/OUT TO TUBING TAIL. -POOH 95'/MIN WITH 3.84/3.36 BPM IN/OUT TO SURFACE. -MW IN/OUT:9.47/9.47 PPG. -FLOW CHECK AT SURFACE-NO FLOW. 23:00 - 23:30 0.50 DRILL C 11,900.00 PROD1 PJSM AND LD BILLET RUNNING TOOLS. -POP OFF,STAND BACK INJECTOR. -BLOW DOWN BHA. -LD 3"COILTRAK. -LD BILLET SETTING TOOL-FUNCTIONED AS i DESIGNED. Printed 2/22/2016 1:03:10PM North America-ALASKA-BP • Page 15 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) ' Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611.482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(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 DRILL C 11,900.00 PROD1 PJSM AND MU KICK OFF/BUILD BHA. -MU 2-7/8"X-TREME MOTOR AND RERUN 4.25'.HYCALOG(1-1-BU). -MU 3"COILTRAK WITH RESISTIVITY. I-PU INJECTOR.GET ON WELL. -PRESS TEST QTS 300/3500 PSI FOR 5/5 MIN. 1/29/2016 00:00 - 02:45 2.75 DRILL C 11,900.00 PROD1 RIH WITH KICK OFF/BUILD BHA. 100'/MIN WITH 2.61/3.15 BPM IN/OUT. MW IN/OUT:9.47/9.45 PPG. '-LOG TIE-IN WITH-15.5'CORRECTION. -CLOSE EDC AND RUN INTO OPEN HOLE. -6'/MIN WITH 0.45/0.48 BPM IN/OUT. -HOLE SMOOTH TO TOP OF BILLET. TAG BILLET 10,841'MD PUMPS OFF. PU AND BRING ON PUMPS TO 2.6 BPM. -TAG BILLET AT 10,840'MD PUMPS ON. 02:45 - 06:00 3.25 DRILL C 11,900.00 PROD1 TIME DRILL AND KICK OFF BILLET. FS:2700 PSI MTR WRK:50-100 PSI WOB: 0.2-1.0K# -BPM IN/OUT:2.65/2.65 PVT:282 BBLS -MW IN/OUT:9.48/9.44 PPG -ECD/IA/OA:10.12 PPG/388 PSI/465 PSI 1-TIME DRILL OFF BILLET. :-1./HR FROM 10,840.1'TO 10,841.1'MD. -2'/HR FROM 10,841.1'TO 10,842.8'MD. -STALL AT 10,842.8'MD. PU AND RBIH.SEE MOTOR WORK AT 10,841.8'MD. -RESUME TIME DRILLING FROM 10,841.8'MD. _ 06:00 - 06:30 0.50 DRILL C 11,900.00 PROD1 10842.9 INCREASE ROP TO GET DEPATURE FROM BILLET 06:30 - 09:15 2.75 DRILL C 11,900.00 PROD1 CONTINUE DRILLING AHEAD DD SAYS WE HAVE DEPARTURE FREE SPIN=2710 PSI AT 2.65 BPM RATE IN=2.70 BPM RATE OUT=2.71 BPM MW IN=9.50 PPG MW OUT=9.44 PPG ECD =10.13 PPG ROP=79 FPH WOB=1.61 K CIRC PSI= 3098 PSI IAP=413 PSI OAP=476 PSI PVT=277 BBLS GETTING ALUMINUM BACK AT THE SHAKER 09:15 - 09:30 0.25 DRILL C 11,900.00 PROD1 FIRST SURVEY SHOWED-35°DLS, SHOOTING FOR 26'S '09:30 - 09:35 0.08 DRILL C 11,900.00 PROD1 PU OFF BOTTOM,DD TRIGGERED A SURVEY AND IT SHOWS ARE HAVE A 39"DLS START LOW&HIGH VIS PILLS DOWN HOLE 09:35 - 09:40 0.08 DRILL C 11,900.00 PROD1 DD SAYS WE CAN STOP HERE AND POOH, DYNAMIC FLOW CHECK WELL 09:40 - 10:00 0.33 DRILL C 11,900.00 PROD1 GOOD FLOW CHECK LOOKS LIKE WE ARE STILL IN GOOD SHAPE AND WILL CONTINUE FROM HERE WITH A 1.2°AKO PU TO THE BILLET AND JOG IN HOLE BEFORE • PULLING THROUGH AT MIN RATE SAME AT THE WINDOW Printed 2/22/2016 1:03:10PM North America-ALASKA-BP • Page 16 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 12:30 2.50 DRILL C 11,900.00 PROD1 AT THE WINDOW,JOG IN HOLE AND OPEN THE EDC EDC OPEN,WASH ACROSS THE WS TRAY AS LOW&HIGH VIS PILLS ARE STARTING TO COME OUT ABOVE THE WINDOW CIRCULATE A BOTTOMS UP AT MAX RAT NOT GETTING MUCH MORE RATE THAN WE GET WITH 1 PUMP,SHUT DOWN AND GO TO 1 PUMP AND POOH AT 50%IN THE 7" 12:30 - 12:40 0.17 DRILL C 11,900.00 PROD1 !FLOW CHECK AND HOLD PJSM TO SWAP MOTOR&BIT 12:40 - 13:35 0.92 DRILL C 11,900.00 PROD1 GOOD NO FLOW,TAG UP,REMOVE THE INJECTOR,BLOW DOWN THE BHA,PU THE BHA TO THE MOTOR&BIT AND SWAP OUT -12:50 INJECTOR OFF -13:20 INJECTOR ON SHALLOW TEST TOOL 13:35 - 15:30 1.92 DRILL C S 11,900.00 PROD1 GOOD TEST,OPEN EDC AND RIH 15:30 - 15:45 0.25 DRILL C 11,900.00 PROD1- LOG TIE IN 15:45 - 16:05 0.33 DRILL C 11,900.00 PROD1 CORRECT DEPTH 17.5'AND RIH 16:05 - 00:00 7.92 DRILL C 11,900.00 PROD1 DRILL AHEAD 10,964'-11,355'MD. -FS:3250 PSI MTR WRK:200-400 PSI WOB: 2.5-4.5K# -BPM IN/OUT:2.90/2.90 PVT:221 BBLS MW IN/OUT:9.58/9.56 PPG -ECD/IA/OA:10.33 PPG/762 PSI/691 PSI -PERFORM 100'WIPERS EVERY 150' DRILLED OR AS NEEDED. HOLD 89.5°INC AND FOLLOW FORMATION DIP. 1/30/2016 00:00 - 01:00 1.00 DRILL C 11,900.00 I PROD1 �DRILL AHEAD 11,355'-11,400'MD. -FS:3300 PSI MTR WRK:200-400 PSI WOB: 2.5-4.5K# BPM IN/OUT:2.92/2.92 PVT:221 BBLS MW IN/OUT:9.61/9.56 PPG -ECD/IA/OA:10.33 PPG/775 PSI/698 PSI PERFORM 100'WIPERS EVERY 150' DRILLED OR AS NEEDED. 01:00 - 02:30 1.50 DRILL C 11,900.00 PROD1 WIPER BACK TO 4-1/2"TUBING TAIL. -PUMP 15/15 BBL LO/HI-VIS SWEEP ON BOTTOM. -WIPER BACK TO WINDOW 20'/MIN WITH 2.90 ,BPM. '-REDUCE PUMPS 0.5 BPM ACROSS BILLET. -PULL INTO WINDOW AND OPEN EDC. -JET 7"SCAB LINER UP TO 10,270'MD INSIDE TUBING TAIL. -8'/MIN WITH 3.83/3.78 BPM IN/OUT. 02:30 - 03:00 0.50 DRILL C 11,900.00 PROD1 RIH BACK TO BOTTOM. 44'/MIN WITH 3.87/4.08 BPM IN/OUT. -TIE-IN WITH+4'CORRECTION. -CLOSE EDC AND RUN INTO OPEN HOLE. -43'/MIN WITH 2.73/2.96 BPM IN/OUT. • -REDUCE PUMPS 0.5 BPM ACROSS BILLET. Printed 2/22/2016 1:03:10PM SNorth America-ALASKA-BP • Page 17 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud DaterTime:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 06:00 3.00 DRILL C 11,900.00 PROD1 DRILLAHEAD 11,400'-11,650'MD. -FS:3100 PSI MTR WRK:200-600 PSI WOB: 2.0-4.5K# -BPM IN/OUT:2.91/2.91 PVT:235 BBLS -MW IN/OUT:9.60/9.58 PPG -ECD/IA/OA:10.33 PPG/415 PSI/182 PSI -PERFORM 100'WIPERS EVERY 150' DRILLED OR AS NEEDED. -BLEED IA FROM 770 TO 340 PSI-20 GAL DIESEL. -BLEED OA FROM 730 TO 170 PSI-GAS RETURNS. 06:00 - 08:15 2.25 DRILL C 11,900.00 PROD1 CONTINUE DRILLING AHEAD 1 FREE SPIN=3320 PSI AT 3.02 BPM RATE IN=3.02 BPM RATE OUT=2.99 BPM MW IN=9.63 PPG MW OUT=9.59 PPG ECD =10.33 PPG ROP=115 FPH WOB=1.90 K CIRC PSI= 3538 PSI IAP=450 PSI- OAP=195 PSI PVT=261 BBLS 08:15 - 08:25 0.17 DRILL C 11,900.00 PROD1 START LO-HI VIS PILLS 08:25 - 09:10 0.75 DRILL C 11,900.00 PROD1 DRILLED 450',WIPER TO WINDOW -PULL AND RUN THROUGH BILLET AT AS DRILLED TF 09:10 - 09:30 0.33 DRILL C 11,900.00 PROD1 j OPEN EDC AND CHASE CUTTINGS UP INTO THE TT 09:30 - 10:00 0.50 DRILL C 11,900.00 PROD1 LOG TIE IN CORRECT+2',CONTINUE CIRCULATING BOTTOMS UP 10:00 - 10:35 0.58 DRILL C 11,900.00 PROD1 CLOSE THE EDC TO RIH BACK TO BOTTOM LO-HI VIS PILLS DID NOT HAVE MUCH MORE CUTTINGS THAN NORMAL _ 10:35 - 11:00 0.42 DRILL C 11,900.00 PROD1 CONTINUE DRILLING AHEAD FREE SPIN=3320 PSI AT 3.02 BPM RATE IN=3.03 BPM RATE OUT=3.01 BPM MW IN=9.65 PPG MW OUT=9.59 PPG ECD =10.46 PPG ROP=120 FPH WOB=2.81 K CIRC PSI= 3602 PSI IAP=461 PSI OAP=222 PSI PVT=264 BBLS 11:00 - 12:20 1.33 DRILL P PROD1 BACK ON PRODUCTIVE TIME CONTINUE DRILLING AHEAD FREE SPIN=3320 PSI AT 3.02 BPM RATE IN=3.02 BPM RATE OUT=3.03 BPM MW IN=9.65 PPG MW OUT=9.59 PPG ECD =10.46 PPG ROP=121 FPH WOB=2.31 K CIRC PSI= 3596 PSI IAP=483 PSI OAP=232 PSI PVT=262 BBLS 12:20 - 13:40 1.33 DRILL P PROD1 CONTINUE DRILLING AHEAD FREE SPIN=3320 PSI AT 3.02 BPM RATE IN=3.02 BPM RATE OUT=3.05 BPM MW IN=9.66 PPG MW OUT=9.64 PPG ECD =10.49 PPG ROP=125 FPH WOB=2.45 K CIRC PSI= ,3713 PSI IAP=541 PSI OAP=248 PSI PVT=257 BBLS Printed 2/22/2016 1:03:10PM SNorth America-ALASKA-BP • Page 18 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:40 - 14:30 0.83 DRILL P PROD1 CONTINUE DRILLING AHEAD 'FREE SPIN=3320 PSI AT 3.02 BPM RATE IN=3.03 BPM RATE OUT=3.02 BPM MW IN=9.66 PPG MW OUT=9.63 PPG ECD =10.49 PPG ROP=118 FPH WOB=2.65 K CIRC PSI= 3713 PSI IAP=559 PSI OAP=256 PSI PVT=252 BBLS 14:30 - 16:00 1.50 DRILL P PROD1 CONTINUE DRILLING AHEAD FREE SPIN=3320 PSI AT 3.02 BPM RATE IN=3.01 BPM RATE OUT=3.03 BPM MW IN=9.67 PPG MW OUT=9.66 PPG ECD =10.53 PPG ROP=119 FPH WOB=2.27 K CIRC PSI= j 3615 PSI IAP=575 PSI OAP=264 PSI PVT=250 BBLS 16:00 - 16:30 0.50 DRILL P ' PROD1 PUMP 20 BBLS EACH LOW&HIGH VIS PILLS 16:30 - 17:20 0.83 DRILL P PROD1 DRILLED 450',WIPE TO THE WINDOW CHASING PILLS 17:20 - 19:20 2.00 DRILL P PROD1 AT THE WINDOW,OPEN THE EDC AND JET -ACROSS THE WS TRAY THEN POOH CHASING PILLE TO THE UPPER 7" -HAVE 10 BBLS LO VIS/10 BBLS HI VIS SWEEP COMING OUT @ 2800'. 19:20 - 20:30 1.17 DRILL P PROD1 RUN BACK IN HOLE.OBSERVE CUTTINGS/ SMALL PEBBLES BACK W/SWEEP. _ -RBIH TO 10,520' 20:30 - 20:45 0.25 DRILL P PROD1 LOG F/10,520'-10,550',ADD 9'CORRECTION. 20:45 - 21:45 1.00 DRILL ' P PROD1 CONTINUE IN HOLE,CLOSE EDC,SHUT DOWN PUMP AND GO THROUGH WINDOW. BRING PUMPS BACK UP AND SHUT DOWN AGAIN 10'ABOVE THE BILLET TO 10'BELOW THE BILLET. -@ 10,850',BRING PUMP BACK ON.AND RIH. TAG UP @ 12,300'. 21:45 - 00:00 2.25 DRILL P PROD1 DRILL AHEAD F/12,300'. I-FS:3215 PSI MTR WRK:200-400 PSI WOB: 2.5-4.5K# -BPM IN/OUT:2.92/2.92 PVT:221 BBLS -MW IN/OUT:9.61/9.56 PPG -ECD/IA/OA:10.52 PPG/562 PSI/287 PSI -DRILL TO 12395'.WT TRANSFER BECOMING PROBLEMATIC. -DECISION MADE TO CHANGE TO NEW MUD. PJSM. CONTINUE DRILLING.DRILL AHEAD TO 12,440'. 1/31/2016 00:00 - 00:30 0.50 DRILL P PROD1 DRILL AHEAD F/12,440-12,461'. -PICKED UP,PULLED HEAVY, DIFFERENTIALLY STUCK. -SLACK OFF,PICK UP AGAIN HEAVY, CIRCULATE BOTTOMS UP. 00:30 - 02:00 1.50 DRILL N STUC 12,462.00 PROD1 CIRCULATE BOTTOMS UP.2.98 BPM IN/2.98 BPM OUT. -3225 PSI,HOLDING 47K UP WT.CIRCULATE A FULL BOTTOMS OP. -RELAX COIL F/5 MINUTES AND PULL FREE. Printed 2/22/2016 1:03:10PM SNorth America-ALASKA-BP S Page 19 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 04:30 2.50 DRILL P PROD1 MAKE A WIPER TRIP TO THE 4 1/2"TUBING TAIL. -PUMPING 2.9 BPM/3175 PSI.SLOW TO MIN RATE @ BILLET AND WINDOW. -RBIH,LOG TIE IN F/10,520'-10,545',PLUS 5' CORRECTION. -RBIH,SHUTTING DOWN PUMP F/WINDOW AND BILLET. 04:30 - 06:15 1.75 DRILL P PROD1 DRILLING AHEAD F/12,459-12,565'. FREE SPIN=2950 PSI AT 2.95 BPM RATE IN=2.95 BPM RATE OUT=2.93 BPM MW IN=9.48 PPG MW OUT=9.42 PPG ECD =10.21 PPG ROP=80 FPH WOB=2.6 K CIRC PSI= 3150 PSI IAP=211 PSI OAP=107 PSI PVT=257 BBLS 06:15 - 06:45 0.50 DRILL P PROD1 CREW CHANGE WIPE TO 12000' 06:45 - 06:55 0.17 DRILL P PROD1 RIH TO CONTINUE DRILLING 06:55 - 08:45 1.83 DRILL P PROD1 BACK ON BOTTOM DRILLING FREE SPIN=3000 PSI AT 3.02 BPM -RATE IN=3.02 BPM RATE OUT=3.00 BPM MW IN=9.49 PPG MW OUT=9.45 PPG ECD =10.25 PPG ROP=92FPH WOB=2.14K CIRC PSI= 3252 PSI IAP=314 PSI OAP=126 PSI PVT=253 BBLS 08:45 - 09:00 0.25 DRILL P PROD1 ROP DOWN TO<20 FPH,DRILLED TO WHERE WE STARTED SEEING A REDUCTION IN ROP AND IT IS NOT REFLECTING A SHALE.EITHER THE BIT IS WORN OUT OR WE ARE AT THE END OF OUR PUSH AND NEED AN AGITATOR. FLOW CHECK WELLAND PREP TO POOH TO CHECK THE BIT 09:00 - 10:00 1.00 DRILL P PROD1 GOOD FLOW CHECK,POOH PUMPING LOW& HIGH VIS PILLS JOG IN HOLE AT THE BILLET AND WINDOW 10:00 - 11:55 1.92 DRILL P PROD1 OPEN THE EDC AND JET ACROSS THE WS TRAY POOH AT 50%IN THE 7"THEN POOH AT NORMAL SPEED TO THE UPPER 7" LOW&HIGH VIS PILLS DID NOT BERING UP ANY INCREASE IN CUTTINGS 11:55 - 12:05 0.17 DRILL P PROD1 AT SURFACE,JOG IN HOLE THE SHUT DOWN TO FLOW CHECK WELLAND HOLD A PJSM TO LD THE BHA 12:05 - 12:30 0.42 DRILL P PROD1 GOOD NO FLOW,TAG UP,REMOVE TEH INJECTOR AND LD THE BHA 12:10 INJECTOR OFF BIT GRADE=1-2 12:30 - 12:40 0.17 DRILL P PROD1 PJSM TO CUT PIPE&REHEAD 12:40 - 14:00 1.33 DRILL P PROD1 RD UQC RU CUTTER !CUT 100'OF COIL I RD CUTTER MU CTC PULL TEST TO 35K Printed 2/22/2016 1,03:10PM • North America-ALASKA-BP • Page 20 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor.NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 14:40 0.67 DRILL P PROD1 GOOD PULL TEST HEAD UP BHI UQC PT UQC AND CTC 14:40 - 15:00 0.33 DRILL P PROD1 GOOD PT,RD TEST EQUIPMENT AND PREP TO PU THE DRILLING BHA W/AGITATOR 15:00 - 15:10 0.17 DRILL P PROD1 PJSM TO MU THE BHA WELL IS TAKING-1 BBL EVERY 90 MIN 15:10 - 15:30 0.33 DRILL P PROD1 MU THE DRILLING BHA 15:30 - 17:35 2.08 DRILL P PROD1 STAB ON INJECTOR,SHALLOW TEST MWD AND AGITATOR AGITATOR IS WORKING AT 2.85 BPM OPEN EDC AND RIH 17:35 - 17:55 0.33 DRILL P PROD1 LOG TIE IN 17:55 - 19:00 1.08 DRILL P PROD1 CORRECT DEPTH-18'AND RIH -301MIN WITH 2.53/3.05 BPM IN/OUT. -MW IN/OU:9.52/9.45 PPG. -PUMPS OFF ACROSS BILLET. 19:00 - 00:00 5.00 DRILL P PROD1 DRILL AHEAD 12,627'-12,757'MD. -FS:3100-3300 PSI. -VARY PUMP RATES 2.4-2.9 BPM IN/OUT. -MTR WRK:200-400 PSI WOB:2.5-4.5K# -MW IN/OUT:9.55/9.50 PPG ECD/IA/OA:10.35 PPG/548 PSI/209 PSI -SLOW HARD DRILLING THRU SHALE STARTING-12,660'MD. -FIGHT DIFFERENTIAL STICKING. -DIFFICULT TO KEEP MOTOR WORK ON BOTTOM. 1-PICK UP HEAVY OFF BOTTOM 55-70K#. REQUIRE FREQUENT WIPER TRIPS TO KEEP FROM STICKING COIL. -INCREASE LUBE CONTENT OF MUD FROM 2%TO 3%. 2/1/2016 00:00 - 03:30 3.50 DRILL P PROD1 DRILL AHEAD 12,757'-12,872'MD. -FS:3100-3300 PSI. -VARY PUMP RATES 2.5-2.9 BPM IN/OUT. MTR WRK:200-400 PSI WOB:1.5-3.0K# -MW IN/OUT:9.50/9.51 PPG -ECD/IA/OA:10.39 PPG/552 PSI/210 PSI -CONTINUE SLOW HARD DRILLING THRU SHALE. -DIRECTIONAL STEERING DIFFICULT THRU FORMATION. REQUIRE FREQUENT WIPER TRIPS TO KEEP FROM STICKING COIL. 103:30 - 04:15 I 0.75 DRILL P PROD1 PERFORM MUD SWAP TO 9.5 PPG POWERPRO. -WIPER TO 12,800'MD WHILE SWAP MUD. -POOH 30'/MIN WITH 2.52/2.34 BPM IN/OUT. -RIH 39'/MIN WITH 2.55/2.76 BPM IN/OUT. -MW IN/OUT:9.48/9.52 PPG. Printed 2/22/2016 1:03:10PM • North America-ALASKA-BP • Page 21 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code 1 NPT NPT Depth Phase Description of Operations (hr) (usft) 04:15 - 06:35 2.33 DRILL P PROD1 DRILL AHEAD 12,872'-12,950'MD. -FS:2580 PSI MTR WRK:200-400 PSI WOB: 2.5-4.5K# -BPM IN/OUT:2.60/2.60 PVT:221 BBLS -MW IN/OUT:9.50/9.52 PPG -ECD/IA/OA:10.39 PPG/488 PSI/162 PSI -CONTINUE MUD SWAP WHILE DRILL AHEAD. SEE SIGNIFICANT IMPROVEMENT IN DRILLING PARAMETERS WITH NEW 9.5 PPG POWERPRO IN OPEN HOLE. -WIPER TO 12,100' 06:35 - 09:00 2.42 DRILL P PROD1 BACK ON BOTTOM DRILLING 'FREE SPIN=3080 PSI AT 2.85 BPM RATE IN=2.85 BPM RATE OUT=2.86 BPM MW IN=9.54 PPG MW OUT=9.45 PPG ECD =10.36 PPG ROP=73 FPH WOB=4.84 K CIRC PSI= 3292 PSI IAP=194 PSI ,OAP=59 PSI PVT=248 BELS 09:00 - 09:30 0.50 DRILL P PROD1 CONTINUE DRILLING FREE SPIN=3080 PSI AT 2.85 BPM RATE IN=2.85 BPM RATE OUT=2.86 BPM MW IN=9.53 PPG MW OUT=9.48 PPG ECD =10.42 PPG ROP=88 FPH WOB=2.83 K CIRC PSI= 3435 PSI IAP=310 PSI OAP=103 PSI PVT=247 BBLS 09:30 - 09:55 0.42 DRILL P PROD1 STACKING WT,PU TO UP WT AND-5 MORE i FEET.RIH AND STACKED OUT,PU AND PULLED HEAVY,WORK PIPE DOWN AND STACKED OUT. WORK PIPE FREE WITH 25K OVER UP WT AND KEEP PUH TO 12500' NOTHING ON THE WOB SUB SHOWED WE WERE PULLING ON THE BHA,ACTED LIKE DIFFERENTIAL STICKING ABOVE ON THE COIL OR UPPER BHA 09:55 - 11:45 1.83 DRILL P PROD1 BACK ON BOTTOM,WT TRANSFER&PU'S LOOK BETTER,CONTINUE DRILLING 11:45 - 13:30 1.75 DRILL P PROD1 DRILLED 450',WIPE TO THE WINDOW PUMPING LOW&HIGH VIS PILLS 11087 PULLING HEAVY,LOOKS LIKE WE ARE PACKING OFF A LITTLE NO WOB CHANGE,IT LOOKS LIKE THE CTC IS AT THE SHALE FROM 11,020 TO 10970 STRING WT IS RATTY AS THE BHA IS PULLING THROUGH THE SHALE 11002'GETTING MOTOR WORK AND PULLING HEAVY AT THE BIT TRY WORKING UP AND DOWN THROUGH SHALE AT REDUCED A REDUCED RATE 0.5 BPM STILL PULLING HEAVY TO 10996',RIH FAST AND POPPED FREE TRY COMING UP AGAIN,STILL PULLING HEAVY AT SAME DEPTH RIH AND POP FREE,RIH TO 11050'AND BRING PUMP UP TO MAX RATE AND PUH SLOW Printed 2/22/2016 1:03:10PM • North America-ALASKA-BP • Page 22 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 13:40 0.17 DRILL P PROD1 PRETTY RATTY COMING UP THROUGH SHALE TO 10970'THEN CLEANED UP, CONTINUE POOH TO WINDOW JOG IN HOLE AT THE BILLET THEN PULL THROUGH AT MIN RATE JOG IN HOLE AT THE WINDOW I OPEN EDC AND JET ACROSS THE WS THEN 'PULL INTO THE 7"PULLING AT 50 FPM UP INTO THE TT 13:40 - 14:20 0.67 DRILL P PROD1 POOH AT 50 FPM UP TO THE TT 11350'PACKING OFF AT THE TT AGAIN WHILE PUH CIRCULATE A BOTTOMS UP BEFORE SHUTTING DOWN 14:20 - 14:35 0.25 DRILL P PROD1 LOG TIE IN 14:35 - 15:00 0.42 DRILL P PROD1 CORRECT DEPTH+9',CONTINUE CIRCULATING BOTTOMS UP 15:00 - 16:05 1.08 DRILL P PROD1 I BOTTOMS UP DID NOT BRING UP ANY EXTRA CUTTINGS CLOSE THE EDC AND RIH TO CONTINUE DRILLING REDUCE RATE AT 10950 TO RIH THROUGH SHALE AT 10970 TO 11020' SET DOWN AT 10992 THEN POPPED THROUGH SET DOWN AT 11011,GAVE BACK A LITTLE WT PU TO UP WT AND RIH WITH A FEW BOBBLES THEN CLEAN AFTER 11020' 16:05 - 1700 0.92 DRILL P PROD1 BACK ON BOTTOM DRILLING FREE SPIN=3090 PSI AT 2.85 BPM RATE IN=2.87 BPM RATE OUT=2.87 BPM MW IN=9.53 PPG MW OUT=9.46 PPG ECD =10.45 PPG ROP=78 FPH WOB=3.03 K CIRC PSI= 3446 PSI IAP=444 PSI OAP=208 PSI PVT=248 BBLS 17:00 - 18:45 1.75 DRILL P PROD1 DRILLING AHEAD FREE SPIN=3090 PSI AT 2.85 BPM RATE IN=2.87 BPM RATE OUT=2.87 BPM MW IN=9.53 PPG MW OUT=9.46 PPG ECD =10.45 PPG ROP=48 FPH WOB=2.85 K CIRC PSI= 3368 PSI IAP=498 PSI OAP=228 PSI PVT=245 BBLS DRILL AHEAD TO 13,177'.PULLING HEAVY W/ WT TRANSFER ISSUES. -OPT TO DO A WIPER TRIP. I AGITATOR DOES NOT APPEAR TO BE WORKING VERY HARD 18:45 - 19:45 1.00 DRILL P PROD1 WIPER TRIP TO 12,175',30 FPM. -PUMPING 2.8 BPM/3050 PSI. -TAGGED UP©12,900'GOING BACK IN, ADJUSTED TOOL FACE AND THRU. Printed 2/22/2016 1:03:10PM • North America-ALASKA-BP • Page 23 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:45 - 21:45 2.00 DRILL P PROD1 DRILLAHEAD 13,177'-13,204.'MD. -FS:3000-3100 PSI @ 2.8 BPM IN AND OUT. -MTR WRK:100-200 PSI WOB:3-4.5K -MW IN/OUT:9.50/9.51 PPG -ECD/IA/OA:10.41 PPG/562 PSI/255 PSI -CONTINUE SLOW HARD DRILLING THRU SHALE. 21:45 - 22:15 0.50 DRILL P PROD1 "SHORT WIPER TRIP. 22:15 - 00:00 1.75 DRILL P PROD1 DRILLAHEAD 13,204'-13,240:MD. -FS:2850-2925 PSI @ 2.6 BPM IN AND OUT. -MTR WRK:100-200 PSI WOB:3-4K -MW IN/OUT:9.53/9.46 PPG -ECD/IA/OA:10.41 PPG/562 PSI/255 PSI -CONTINUE SLOW HARD DRILLING THRU SHALE. 2/2/2016 00:00 - 03:30 3.50 DRILL P PROD1 CONTINUE TO DRILL4.25"HOLE IN LATERAL SECTION AS PER PLAN. -DRILLAHEAD 13,240'-13,313.'MD. -FS:2875-2950 PSI. MTR WRK:100-200 PSI WOB:2-4K# MW IN/OUT:9.53/9.46 PPG ECD/IA/OA:10.41 PPG/562 PSI/255 PSI -CONTINUE SLOW HARD DRILLING THRU SHALE. -@ 13,285 ROP PICKING UP A BIT AND SEEING MORE MOTOR WORK. 03:30 - 04:00 0.50 DRILL P PROD1 PERFORM 500'WIPER TRIP, -HOLE WAS OK RUNNING BACK IN. 04:00 - 06:00 2.00 DRILL P PROD1 CONTINUE TO DRILL 4.25"HOLE IN LATERAL SECTION AS PER PLAN. -DRILL AHEAD 13,313'-13,350.'MD. -FS:2875-2950 PSI. -MTR WRK:100-200 PSI WOB:2-4K# -MW IN/OUT:9.53/9.46 PPG -ECD/IA/OA:10.41 PPG/562 PSI/255 PSI -GETTING BACK TO TOUGH DRILLING. 06:00 - 09:00 3.00 DRILL P PROD1 CONTINUE DRILLING AHEAD IN SHALE 'ADD 50 BBLS OF MUD TO PITS,C-PUMP STRUGLING TO KEEP PRIME WITH 216 BBLS AGITATOR FEELS LIKE ITS WORKING A LITTLE,BUT THE BIT MIGHT BE BALLED UP 09:00 - 11:00 2.00 DRILL P PROD1 DRILLING AHEAD FREE SPIN=3090 PSI AT 2.85 BPM RATE IN=2.78 BPM RATE OUT=2.76 BPM MW IN=9.58 PPG MW OUT=9.51 PPG ECD =10.60 PPG ROP=16 FPH WOB=3.5 K CIRC PSI= 3523 PSI IAP=601 PSI OAP=261 PSI PVT=261 BBLS CALL ODE AND DISCUSS SLOW ROP NOT IMPROVING 11:00 11:45 0.75 DRILL P PROD1 ROP PICKING UP Printed 2/22/2016 1:03:10PM • North America-ALASKA-BP S Page 24 of 24 Operation Summary Report Common Well Name:09-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/20/2016 End Date:2/3/2016 ,X3-017F6-C:(4,611,482.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:45 - 12:20 0.58 DRILL P PROD1 DRILLING AHEAD FREE SPIN=3090 PSI AT 2.85 BPM RATE IN=2.82 BPM RATE OUT=2.80 BPM MW IN=9.58 PPG MW OUT=9.51 PPG ECD =10.60 PPG ROP=45 FPH WOB=2.20 K CIRC PSI= 3571 PSI IAP=621 PSI OAP=275 PSI PVT=252 BBLS 12:20 - 13:05 0.75 DRILL P PROD1 DRILLING AHEAD FREE SPIN=3090 PSI AT 2.85 BPM RATE IN=2.82 BPM RATE OUT=2.80 BPM MW IN=9.58 PPG MW OUT=9.52 PPG ECD =10.69 PPG ROP=77 FPH WOB=2.01 K CIRC PSI= 3743 PSI IAP=648 PSI OAP=289 PSI PVT=251 BBLS 12.50 PUMP 20 BBL LOW&HIGH VIS PILLS 13:05 - 14:35 1.50 DRILL P -PROD1 DRILLED TO TD AND 445',WIPER TO THE WINDOW -11,110'CIRC PRESSURE INCREASING,CTC AT THE SHALE ABOVE 10,077'PULL HEAVY,RIH AND POPPED FREE REDUCE RATE TO 0.75 BPM 14:35 - 15:00 0.42 DRILL P PROD1 JOG IN HOLE AND OPEN THE EDC JET ACROSS WS TRAY AND POOH AT 50 FPM TO THE 4-1/2 TT THEN RIH TO LOG TIE IN 15:00 - 15:15 0.25 DRILL P PROD1 LOG TIE IN 15:15 - 16:45 1.50 DRILL P PROD1 CORRECT DEPTH 10'AND RIH MADE IT THROUGH SHALE 10970-11020 AT MIN RATE AND SOME BOBBLES 116:45 - 18:00 1.25 DRILL P PROD1 DRILL TO EXTENDED TD OF 13,620'PER OCN ✓ #6 18:00 - 23:00 5.00 DRILL P PROD1 WIPER TRIP TO WINDOW -PUMP 20 BBLS LOW VIS/20 BBLS HIGH VIS SWEEP AND CHASE TO WINDOW PULL INTO WINDOW,OPEN EDC AND CIRCULATE BOTTOMS UP -TIE-IN,+6'CORRECTION RIH TO BOTTOM;TAG AT 13,622' 23:00 - 00:00 1.00 DRILL P PROD1 tPOH WITH DRILLING ASSEMBLY -POH,LAYING IN 50 BBLS LINER RUNNING PILL 2/3/2016 00:00 - 02:15 2.25 DRILL P PROD1 CONTINUE POH WITH DRILLING ASSEMBLY PULL INTO WINDOW AND OPEN EDC; CIRCULATE MAX RATE AND POH AT 80% !POWER -STOP AND PAINT TD FLAG AT 9943'EOP AND WINDOW FLAG AT 7055'EOP POH TO SURFACE;IN/OUT RATE=4.1/3.6 BPM -IN/OUT DENSITY=9.59/9.53 PPG 02:15 - 03:00 0.75 DRILL P PROD1 LAY DOWN DRILLING BHA -FLOW CHECK,HOLD PJSM AND TAG UP WITH DRILLING BHA -UNSTAB INJECTOR(0230 HOURS)AND LAY DOWN BHA Printed 2/22/2016 1:03:10PM • • North America-ALASKA-BP Page 1 of 7 Operation Summary Report ✓e Common Well Name:09-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/3/2016 End Date:2/6/2016 X3-017F6-C:(1,318,323.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs f Task Code NPT NPT Depth Phase Description of Operations —_ (hr) (usft) 2/3/2016 03:00 - 04:30 1.50 BOPSUR P RUNPRD SLACK MANAGEMENT -HOLD PJSM WITH NORDIC AND SCHLUMBERGER -PICK UP INJECTOR,BREAK OUT LQC/UQC AND MAKE UP STINGER -STAB INJECTOR AND PUMP SLACK OUT 04:30 - 05:15 0.75 BOPSUR PRUNPRD PUMPED OUT 200'OF ELINE TRIM PIPE AND MU BTT CTC ',PULL TEST TO 40K PRESSURE TEST CTC TO 42.00 PSI 05:15 - 05:35 0.33 BOPSUR P RUNPRD PUMP 3/4"DRIFT BALL 05:35 - 05:45 0.17 BOPSUR P RUNPRD PU THE INJECTOR AND CHECK FOR THE BALL 05:45 - 06:10 0.42 BOPSUR P RUNPRD BALL RECOVERED,SET THE INJECTOR ON IT'S LEGS 06:10 - 06:20 0.17 BOPSUR P RUNPRD CREW CHANGE 06:20 - 07:10 0.83 BOPSUR P RUNPRD HOLD A PJSM TO PREP RIG FLOOR TO RUN LINER WALK THROUGH LINER SUMMARY WITH BTT ,TP,DRILLER AND WSL 07:10 - 07:30 0.33 BOPSUR P RUNPRD HOLDA PJSM TO MU LINER 07:30 - 08:45 1.25 BOPSUR P RUNPRD MU 2-7/8"LINER AS PER SUMMARY 08:45 - 09:20 0.58 BOPSUR, P RUNPRD 31 JTS RAN,FILL PIPE 09:20 - 10:20 1.00 BOPSUR P RUNPRD CONTINUE RUNNING LINER 10:10 VALVE DRILL,2:30 TO PU&MU SAFETY JOINT AND SHUT IN THE WELL 10:20 - 10:50 0.50 BOPSUR P RUNPRD 62 JTS RAN FILL PIPE 10:50 - 12:45 1.92 BOPSUR P RUNPRD CONTINUE RUNNING LINER. 12:45 - 14:00 1.25 BOPSUR P RUNPRD MU 3-1/2 JTS 14:00 - 14:40 0.67 BOPSUR P RUNPRD ALL PIPE RAN,FILL PIPE SWAP PUMPS,PUMP 1 SEEMS TO BE HAVING PROBLEMS VERIFY LINE UP FOLLOWING THE PRESSURE CROSS CHECK CARD COME ONLINE WITH PUMP 2 14:40 - 14:50 0.17 BOPSUR P RUNPRD TEST PUMP 1 ACROSS THE TOP STILL NOT 100% RD HOSE AND MU THE UPPER LINER RUNNING BHA Printed 2/22/2016 1:04:14PM • North America-ALASKA-BP • Page 2 of 7 Operation Summary Report Common Well Name:09-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/3/2016 End Date:2/6/2016 X3-017F6-C:(1,318,323.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.O0usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 14:50 - 15:45 0.92 BOPSUR P RUNPRD IAFTER FILLING THE PIPE WHILE RUNNING LINER,THE HOSE WAS RIGGED DOWN AND DRILLING MUD GOT ON THE FLOOR.THE FLOOR HAND STARTED MOPPING IT UP AND WHILE HE WAS MOPPING,HE BUMPED THE CASE DRAIN VALVE CLOSED WHICH DEAD HEADED THE PRESSURE AND POPPED THE SEALS ON THE VALVE BANK ON THE FARR TONGS.THE FLOOR HAND HEARD A NOISE AND LOOKED ACROSS THE FLOOR AND SAW HYDRAULIC FLUID LEAKING FROM THE VALVE BANKAND THE DRILLER SHUT OFF THE HYDRAULICS.THE FARR TONGS HAD TO BE RIGGED DOWN AND REPLACED WITH THE LITTLE JERKS TO MU THE REST OF THE UPPER BHA 15:45 - 16:15 0.50 BOPSUR P RUNPRD CONTINUE MAKING UP THE UPPER BHA 16:15 - 16:45 0.50 BOPSUR P RUNPRD PU THE INJECTOR,MU COIL TO THE LINER AND STAB ON 16:45 - 18:00 1.25 BOPSUR P RUNPRD RN WITH LINER 18:00 - 18:05 0.08 BOPSUR , 'P RUNPRD STOP AT WINDOW FLAG AND CORRECT ,DEPTH ELECTRONIC=10657.6 FLAG AT 7053 EOP+3584.9=10637.9' CORRECT DEPTH-19.7'WHICH IS CONSISTENT WITH OUR CORRECTIONS WHILE DRILLING-18' 18:05 - 22:15 4.17 BOPSUR P RUNPRD WORK LINER DOWN STARTING AT-13,150' -HANGING UP EVERY 30'AND WORKING DOWN -DIFFICULTY WORKING THROUGH SPOT AT 13,250' CONTINUE WORKING DOWN LINER, I HANGING UP EVERY-30' -REACH 13,435'AND CANNOT PASS, PRESSURE UP BACKSIDE TO 250 PSI -CONTINUE TO WORK LINER DOWN, HANGING UP EVERY-30' -TAG TD AT 13,615'. CONFIRM TD. 22:15 - 23:15 1.00 BOPSUR P RUNPRD RELEASE FROM LINER ESTABLISH 1:1 RETURNS WHILE CIRCULATING ON BOTTOM -ESTABLISH AND CONFIRM PUW OFF BOTTOM AT 25 FPM,PUW=58K -GET BREAKOVER PU WT 17'OFF BOTTOM WITH 5K COIL WEIGHT DOWN -LAUNCH 5/8"STEEL BALL -BALL LANDS AT 45.5 BBLS AWAY, PRESSURE UP TO 4230 PSI,SHEAR -OBTAIN PUW,WEIGHT BREAKS OVER AT 13,601'AT 40K.,CONFIRM PU WEIGHTS, CONFIRM RELEASE FROM LINER. STACK WEIGHT BACK DOWN ON LINER. 2315 - 00:00 0.75 BOPSUR P RUNPRD SWAP WELL OVER TO KCL Printed 2/22/2016 1 04:14PM North America-ALASKA-BP • Page 3 of 7 Operation Summary Report Common Well Name:09-02 AFE No Event Type:COM-ONSHORE(CON) Start Date.2/3/2016 End Date:2/6/2016 X3-017F6-C:(1,318,323.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/4/2016 00:00 - 00:30 0.50 CEMT P RUNPRD PRESSURE TEST CEMENT LINES -HOLD PJSM AND PERFORM PRESSURE CROSSCHECK,ESTABLISH LOWEST RATED COMPONENT IS SYSTEM,TRIP SETTING AND TESTING,EXCULSION ZONES,JOB ASSIGMENTS AND MAXIMUM TREATING PRESSURE FOR THE JOB. PRESSURE TEST CEMENT LINE 250 PSI LOW/4700 PSI HIGH FOR 5 CHARTED MINUTES EACH,GOOD TEST CONTINUE SWAPPING WELL TO KCL DURING PRESSURE TEST-TAKING MUD RETURNS OUTSIDE TO VAC TRUCKS 00:30 - 02:45 2.25 CEMT P RUNPRD CONTINUE SWAPPING WELL TO 1%KCL -KCL ALL THE WAY AROUND. SWAP BACK TO 1 PITS. -CIRC PRESSURE=480 PSI AT 1.5 BPM -HOLD PJSM FOR CEMENT JOB,PERFORM PRESSURE CROSSCHECK,ESTABLISH !LOWEST RATED COMPONENT IS SYSTEM, TRIP SETTING AND TESTING,EXCULSION ZONES,JOB ASSIGMENTS AND MAXIMUM TREATING PRESSURE FOR THE JOB. 02:45 - 04:45 2.00 CEMT P RUNPRD -MIX CEMENT. CEMENT WET AT 0250 1 HOURS,UP TO WEIGHT AT 0315 HOURS -ZERO IN MM ONCE DENSITY HITS 13.5 PPG. LOAD 50 BBLS OF 15.8 PPG CEMENT IN REEL. -PUSH EXHAUST TO CEMENTERS,SWAP TO RIG PUMP AND INCREASE RATE TO 3 BPM. CEMENT TO SHOE AT 78 BBLS. ZERO OUT MM,TAKE RETURNS TO PIT 1 FOR MANUAL STRAP,MANUAL STRAP=67 BBLS -SHUT DOWN PUMPS AT 105 BBLS AWAY(27 BBLS BEHIND PIPE). 1-PICK UP TO BREAKOVER+13'(13,589'),PER BTT REP AND EXPOSE DOGS,STACK BACK DOWN AT 13,604'(+10'),PUW=37K -SHIFT LINER WIPER PLUG DOWN,PICK BACK UP TO 13,589'AND SIDE EXHAUST 2 BBLS CEMENT/3 BBLS EXHAUST. -SET DOWN AT 13,604'AND LAUNCH PEE WEE DART. -ZERO IN MM AND PRESSURE UP ON WIPER PLUG. LINER WIPER PLUG SHEARED AT 3500 PSI(0.6 BBLS) -DISPLACE LINER WIPER PLUG AT 1.75 BPM/ 2040 PSI. PLUG BUMPED AT 20.9 BBLS/2400 'PSI(20.6 BBLS CALCULATED). -OPEN BAKER CHOKE AND CHECK FLOATS. -CLOSE BAKER CHOKE,PRESSURE UP ON COIL,PICK UP AND CONFIRM PRESSURE DROP. j-PLUG BUMPED AND FLOATS HELD AT 0430 HOURS -PIT 1 MANUAL STRAP FROM CEMENT EXIT SHOE SHOWS-47 BBLS BEHIND PIPE[50 PUMPED-(119 END STRAP-67 START STRAP -5 EXHAUST)]NO LOSSES OBSERVED. ESTIMATED TOP OF CEMENT=TOP OF LINER. Printed 2/22/2016 1.04:14PM • North America-ALASKA-BP • Page 4 of 7 Operation Summary Report Common Well Name:09-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/3/2016 End Date:2/6/2016 1X3-017F6-C:(1,318,323.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:45 - 07:10 2.42 CEMT P RUNPRD CIRCULATE OUT EXCESS CEMENT -UNSTING FROM LINER AND JET TOP OF !DEPLOYMENT SLEEVE PUH SLOWLY WHILE CIRCULATING OUT CEMENT AT 3.80 BPM AT 2150 PSI I-FIRST SLUG OF CMT AT SURFACE,TAKE RETURNS TO THE C-BOX RETUNS HAVE CLEANED UP GO TO TT SO WE CAN SUCK OUT THE C-BOX FOR THE 2ND SLUG OF CMT -C-BOX IS SUCKED OUT -DENSITY INCREASING,TAKE RETURNS TO THE C-BOX -DENSITY STARTING TO CLEAN UP -FILL PITS WITH FLUID FOR TRIP OOH 07:10 - 08:20 1.17 CEMT P RUNPRD PITS HAVE ENOUGH FLUID,POOH 08:20 - 08:35 0.25 CEMT P RUNPRD 3200'SHOWING A 1 BBLS GAIN OVER THE LAST 2000',STOP POOH AND FLOW CHECK THE WELL OUT MM ISA LITTLE IRRATIC LIKE IT MIGHT HAVE SOME DEBRIS BUT WE WILL FLOW CHECK FOR 10 MIN 08:35 - 09:00 0.42 CEMT P RUNPRD ;GOOD NO FLOW -BLOW OUT OUT MM RETURN RATE ON CTDS SCREEN IS CLEANER,POOH HOLD PJSM TO LD THE SELRT 09:00 - 09:10 0.17 CEMT P RUNPRD FLOW CHECK WELL 09:10 - 10:30 1.33 CEMT P RUNPRD GOOD NO FLOW,TAG UP,REMOVE THE INJECTOR LD THE UPPER BHA&SELRT AND LOAD OUT 10:30 - 10:40 0.17 CEMT P RUNPRD HOLD A PJSM TO CUT OFF THE CTS CTC AND MU THE BTT INTERNAL DIMPLE CONNECTOR 10:40 - 11:40 1.00 CEMT P RUNPRD CUT OFF THE CTC MU THE BTT INTERNAL DIMPLE CONNECTOR FOR THE PERF RUN PULL TEST TO 42K PT TO 4200 PSI 11:40 - 11:50 0.17 CEMT P RUNPRD HOLD A PJSM TO MU A NOZZLE BHAAND JET THE STACK 11:50 - 12:15 0.42 CEMT P RUNPRD PU THE INJECTOR,STAB ON AND JET THE STACK 12:15 - 12:25 0.17 CEMT P RUNPRD PU THE INJECTOR AND SET ON LEGS PJSM TO TEST BOPE 12:25 - 13:30 1.08 CEMT P RUNPRD MU THE TEST PLUG AND INSTALL FLUID PACK STACK 13:30 - 22:00 8.50 CEMT P RUNPRD TEST BOP -SHELL TEST BOP -TEST BOP PER NORDIC,BP AND AOGCC TO 250 PSI LOW P 3500 PSI HIGH FOR 5 MINUTES -AOGCC REP CHUCK SCHEVE WITNESSING THE TEST -VBR TEST FAILAT 2115 HOURS;COMPLETE REMAINING TEST Printed 2/22/2016 1:04:14PM • North America-ALASKA-BP • Page 5 of 7 Operation Summary Report Common Well Name:09-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/3/2016 End Date:2/6/2016 X3-017F6-C:(1,318,323.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) ' - (usft) 22:00 - 00:00 2.00 C MTE N RREP I 13,622.00 RUNPRD !CHANGE-OUT VBR -PJSM,LOTO ACCUMULATOR,SUCK OUT !STAC I -PULL AND INSPECT VBR;FIND DAMAGED PISTON ROD HEAD -REMOVE PISTON ROD HEAD 2/5/2016 00:00 - 05:00 5.00 CEMT N RREP 13,622.00 RUNPRD CHANGE-OUT VBR -WAIT ON REPLACEMENT PISTON ROD HEAD I FROM PERMAFROST PAD -PJSM AND INSTALL TOT PARTS AND VBR l -SHELL TEST BOP TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES -INSTALL 2-3/8"TEST JOINT 05:00 - 07:00 2.00 CEMT P i I RUNPRD !PRESSURE TEST VBR PER NORDIC,BP AND I AOGCC TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES 07:00 - 07:15 ' 0.25 CEMT P RUNPRD I HOLD A PJSM TO PU THE INJECTOR AND TEST THE IRV&PACK OFF 07:15 - 07:25 0.17 CEMT I P RUNPRD PU-THE INJECTOR AND STAB ON,LINE UP THE CHOKE MANIFOLD TO TO THE THROUGH THE CHOKE LINE VERIFYING VALVE&PUMP LINE UP USING THE PRESSURE CROSS CHECK LIST 07:25 - 08:20 0.92 CEMT P RUNPRD �'PERFORM LOW PRESSURE TEST ON IRV AND ,PACK OFF 08:20 - 08:45 0.42 CEMT P RUNPRD j GOOD PT ON IRV AND PACK OFF CLOSE THE CHOKE AND OPEN THE WELL TO CHECK FOR PRESSURE NO PRESSURE FILL TO HOLE TO ENSURE ITS FULL WELL TOOK 1.5 BBLS FLOW CHECK WELL 08:45 - 09:05 0.33 CEMT P RUNPRD .I GOOD NO FLOW,PU THE INJECTOR AND SET ON LEG 'INSTALL NIGHT CAP TO TEST LAP 09:05 - 09:15 0.17 CEMT P RUNPRD HOLD A PJSM TO SEAT THE NEW VALVE SEATS ON PUMP#1 AND TEST THE LINER I LAP 09.15 - 09:30 0.25 CEMT P RUNPRD LINE UP PUMP#1 ACROSS THE TOP,VERIFY LINE UP WITH THE PRESSURE CROSS I CHECK LIST ONLINE WITH THE CHARGE PUMP TO VERIFY I I FLOW I PRESSURE UP TO 4500 PSI VALVES ARE SEATED,BLEED OFF THROUGH i �� THE BAKER CHOKE OPEN KILL LINE,ONLINE WITH CHARGE I PUMP TO VERIFY FLOW PATH WE HAVE RETURNS I I I CLOSE THE CHOKE TO TEST LAP CMT UCA SHOWS 500 PSI COMPRESSIVE STRENGTH AT 13:12(HH:MM).CMT WAS IN PLACE AT 04:30 YESTERDAY MORNING AND SHOULD HAVE REACHED 500 PSI AY 17:42 LAST NIGHT 09:30 - 10:20 0.83 CEMT 1 P ' RUNPRD !ONLINE WITH PUMP#1 j 09:33 SHUT DOWN PUMP WITH 260 PSI 09:38 GOOD LOW PT ONLINE WITH PUMP FOR HIGH PT IA=0 PSI OA=135 PSI Printed 2/22/2016 1:04:14PM • North America-ALASKA-BP • Page 6 of 7 Operation Summary Report Common Well Name:09-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/3/2016 End Date:2/6/2016 X3-017F6-C:(1,318,323.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task ! Code NPT NPT Depth Phase J Description of Operations (hr) (usft) 10:20 - 10:45 0.42 CEMT P RUNPRD LAP TEST PASSED STARTING PRESSURE=2457 PSI LOST 44 PSI IN THE FIRST 15 MIN TO 2413 PSI LOST 22 PSI IN THE SECOND 15 MIN TO 2391 PSI BLEED OFF PRESSURE,FLOW CHECK AND REMOVE NIGHT CAP 10:45 - 10:55 0.17 PERF P OTHCMP HOLD A PJSM TO BRING TCP HANDLING EQUIPMENT TO THE RIG FLOOR 10:55 - 11:10 0.25 PERF P OTHCMP LOAD TCP HANDLING TOOLS ON THE RIG WALK GUN LAYOUT WITH THE TCP ENGINEER ALL GUNS ACCOUNTED FOR,NUMBERED AND BLANKS SPACED OUT AS PER LAYOUT 11:10 - 11:30 0.33 PERF P OTHCMP HOLD A PJSM TO MU GUNS AND CSH WORKSTRING 11:30 - 13:30 2.00 PERF P OTHCMP MU PERF BHA 13:30 - 15:00 1.50 PERF P OTHCMP GUNS MADE UP,RD TCP EQUIPMENT AND SWAP ELEVATORS 15:00 - 15:20 0.33 PERF P OTHCMP CSH FROM THE DERRICK RAN,CIRCULATE TO ENSURE THE SCALE HASN'T PLUGGED OFF THE FLOW PORT 15:20 - 17:45 2.42_ PERF P OTHCMP _MU SINGLE JTS OF CSH FROM THE PIPE SHED AND RATTLE VALVE DRILL,2 MIN TO GET THE SAFETY JOINT PU,MU,LOWERED AND SHUT IN 17:45 - 22:15 4.50 PERE P OTHCMP RIH WITH PERFORATING GUNS -STAB INJECTOR AND PRESSURE TEST QTS TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES -RIH AT 100 FPM IN/OUT RATE=0.48/1.02 BPM -IN/OUT DENSITY=8.32/8.36 PPG PROVIDE AOGCC WITH 24-HOUR BOP TEST NOTIFICATION VIA EMAIL FOR 02/06/2016 AT 1800 HOURS 22:15 - 22:30 0.25 PERF P OTHCMP FIRE PERFORATING GUNS -TAG PBTD WITH 1K DOWN WEIGHT, CORRECT DEPTH TO PBTD OF 13,580.86' -PUH AND PARK AT 13,549'AND PERFORM FIRING SEQUENCE -MOVE GUNS SLOWLY UPHOLE ON FINAL j FIRING SEQUENCE STEP j-GUNS FIRE ON DEPTH(13,545') -LOSE RETURNS AND SLB SHOT INDICATOR SHOWS POSITIVE INDICATION -BEGIN PINCHING IN CHOKE TO OBTAIN RETURNS AND POSITIVE WELLHEAD PRESSURE 22:30 - 00:00 1.50 PERF P OTHCMP POH WITH PERF GUNS •-HOLD-250 PSI WHP WHILE POH IN/OUT RATE=1.02/0.67 BPM -IN/OUT DENSITY=8.36/8.37 PPG 2/6/2016 00:00 - 01:15 1.25 PERF P OTHCMP CONTINUE POH WITH PERF GUNS -FLOW CHECK,TAG UP AND HOLD PJSM FOR LAYING DOWN BHA Printed 2/22/2016 1:04:14PM • North America-ALASKA-BP • Page 7 of 7 Operation Summary Report Common Well Name:09-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/3/2016 End Date:2/6/2016 ,X3-017F6-C:(1,318,323.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:2/16/1976 12:00:00AM Rig Release:2/6/2016 Rig Contractor:NORDIC CALISTA UWI:500292019800 Active datum:2:02 2/16/1976 00:00©54.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:15 - 09:00 7.75 PERF P OTHCMP LAY DOWN PERF ASSEMBLY -UNSTAB AND STAND BACK INJECTOR -FLUSH AND LAY DOWN 66 JOINTS 1-1/4" CSH -PULL TO MARKER JOINT AND HOLD PJSM WITH NORDIC AND SCHLUMBERGER TCP FOR LAYING DOWN PERF GUNS -LAY DOWN PERF GUNS 09:00 - 09:55 0.92 PERF P OTHCMP GUNS OOH,LOAD OUT GUNS AND HANDLING EQUIPMENT AND CALL OUT GREASE CREW 09:55 - 10:10 0.25 PERF P OTHCMP HOLD A PJSM TO MU A NOZZLE BHA W/DFCV'S AND RIH TO FREEZE PROTECT THE WELL 10:10 - 10:30 0.33 BOPSUR P OTHCMP MU NOZZLE BHA 10:30 - 11:15 0.75 BOPSUR P POST RIH TO FREEZE PROTECT THE WELL FROM 2500'WITH DIESEL 11:15 - 11:45 0.50 BOPSUR P POST POOH LAYING IN DIESEL FROM 2500' 11:45 - 12:00 0.25 BOPSUR P POST STOP AT 500'AND FINISH DISPLACEMENT TO DIESEL 12:00 - 12:10 0.17 BOPSUR P POST. FLOW CHECK WELL 12:10 - 12:30 0.33 BOPSUR P POST GOOD NO FLOW,TAG UP AND ALLOW -GREASE CREW TO SERVICE TREE 12:30 - 12:45 0.25 BOPSUR P POST HOLD A PJSM TO PU THE INJECTOR,RD THE j NOZZLE BHAAND PREP TO PUMP NEAT METHANOL DOWN THE TREE,SHUT IN AND LTT THE MASTER&SWAB 12:45 - 13:35 0.83 BOPSUR P POST IPU THE INJECTOR,REMOVE THE NOZZLE IBHA 1 PUMP NEAT METH DOWN THE TREE I SHUT IN MASTER AND FLUID PACK WITH NEAT METH CLOSE SWAB AND LTT THE MASTER&SWAB 13:35 - 13:45 0.17 BOPSUR P POST GOOD LTT,BLEED OFF AND MONITOR FOR INSPECTION AND ND ****PRESSURE UP ON SSV WITH CTS PANEL****TO REMOVE THE FUSIBLE CAP AND CLOSE THE SSV 13:45 - 16:00 2.25 BOPSUR P POST INSTALL NIGHT CAP,BLOW DOWN SURFACE LINES,SUCK OUT STACK AND PITS CLEAN OUT&RD HOT TUB 16:00 - 18:00 2.00 BOPSUR P POST ND BOPE GREASE CHOKE MANIFOLD NODIC HAS REQUESTED TIME TO PERFORM MAINTENANCE BETWEEN WELLS THAT THEY WOULD NORMALLY DO ON THE MOVE 18:00 - 19:00 1.00 BOPSUR P POST INSTALL TREE CAP PT TREE CAP LOW 250 PSI/3500 PSI-LEAK TIGHT TEST RESULTS-NO VISIBLE LEAKS NORDIC COMPLETES ROUTINE MAINTENANCE ***RIG RELEASED AT 19:00*** Printed 2/22/2016 1:04:14PM 0 • ..." 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'.13 ro o : j : r= 717400 _ -n Q ---- ------ S - -_-_.717401rn c Q 717200a _ t 00:7,4d, 71720m • 4 P4 -_ __-__. _ __ � __-- �_ - .__--__71700' I 717000 - mai 0 S 8 a al 8 8 8 8 8 S 8 v 8 `8 8 8 8 8 8 8 S § '4 $ 8, 8 S 8 (u�n3sn ooz)a !ytaou E • • 4* bp Post Drilling North America - ALASKA - BP Prudhoe Bay PB DS 09 09-02 09-02A 09-02A Anticollision Summary Report 04 February, 2016 AOGCC OFFSET REPORT 411 BP i bp Anticollisiion Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-02 Project: Prudhoe Bay TVD Reference: 2:02 2/16/1976 00:00 @ 54.00usft(generic drilling rig) Reference Site: PB DS 09 MD Reference: 2:02 2/16/1976 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-02 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-02A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-02A Offset TVD Reference: Offset Datum Reference 09-02A Filter type: NO GLOBAL FILTER:Using user defined selection&filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 500.00usft Error Surface: Elliptical Conic Survey Program Date 2/4/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 10,725.00 GyroData Gyro(09-02) GYD-GC-MS Gyrodata gyrocompassing m/s 10,728.00 10,818.88 CTK MWD 4-1/4"(09-02APB1) MWD MWD-Standard 10,839.89 13,583.23 CTK MWD 4-1/4"(09-02A) MWD MWD-Standard Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB DS 09 09-01-09-01-09-01 2,150.00 2,150.00 112.22 29.55 82.68 Pass-Major Risk 09-01-09-01A-09-01A 2,150.00 2,150.00 112.22 29.55 82.68 Pass-Major Risk 09-01-09-01APB1-09-01APB1 2,150.00 2,150.00 112.22 29.55 82.68 Pass-Major Risk 09-02-09-02-09-02 10,866.14 10,875.00 29.25 47.04 -14.71 FAIL-Major Risk 09-02-09-02APB1-09-02APB1 10,825.00 10,825.00 0.03 1.38 -1.34 FAIL-Major Risk 09-03-09-03-09-03 2,921.43 2,925.00 122.00 42.73 79.44 Pass-Major Risk 09-03-09-03A-09-03A 2,921.73 2,925.00 122.01 42.73 79.43 Pass-Major Risk 09-03-09-03A-Plan#7 09-03A Approved 2,920.65 2,925.00 121.99 42.71 79.44 Pass-Major Risk 09-04-09-04-09-04 2,821.84 2,825.00 234.96 63.37 171.62 Pass-Major Risk 09-04-09-04A-09-04A 2,821.84 2,825.00 234.96 63.37 171.62 Pass-Major Risk 09-05-09-05-09-05 2,747.35 2,750.00 376.02 45.21 330.82 Pass-Major Risk 09-05-09-05A-09-05A 2,747.35 2,750.00 376.02 45.10 330.93 Pass-Major Risk 09-06-09-06-09-06 2,819.12 2,825.00 487.92 47.19 440.73 Pass-Major Risk 09-13-09-13-09-13 Out of range 09-19-09-19-09-19 5,420.97 5,075.00 305.13 80.62 241.24 Pass-Major Risk 09-20-09-20-09-20 5,618.11 5,250.00 154.90 1,171.70 -1,015.83 FAIL-Major Risk 09-21-09-21-09-21 Out of range 09-22-09-22-09-22 Out of range 09-23-09-23-09-23 Out of range 09-23-09-23A-09-23A Out of range 09-23-09-23APB1-09-23APB1 Out of range 09-23-09-23APB2-09-23APB2 Out of range 09-25-09-25-09-25 Out of range 09-26-09-26-09-26 4,372.94 4,300.00 411.20 106.23 305.31 Pass-Major Risk 09-27-09-27-09-27 3,357.64 3,350.00 233.69 51.33 182.36 Pass-Major Risk 09-27-Plan 09-27A-09-27A wp07 3,368.84 3,375.00 233.77 51.26 182.51 Pass-Major Risk 09-28-09-28-09-28 1,266.94 1,275.00 316.97 26.99 290.03 Pass-Major Risk 09-28-09-28A-09-28A 1,266.94 1,275.00 316.97 26.99 290.03 Pass-Major Risk 09-37-09-37-09-37 4,997.64 4,575.00 455.39 66.19 393.71 Pass-Major Risk 09-51-09-51-09-51 Out of range AOo GCC OFFSET RE POo w= 2/4/2016 4:36:20PM Page 2 of 3 COMPASS 5000.1 Build 61 • i „400,,, BP 2®i1ek 1'bP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-02 Project: Prudhoe Bay TVD Reference: 2:02 2/16/1976 00:00 @ 54.00usft(generic drilling rig) Reference Site: PB DS 09 MD Reference: 2:02 2/16/1976 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-02 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-02A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-02A Offset TVD Reference: Offset Datum Reference Depths are relative to 2:02 2/16/1976 00:00 @ 54.00usft Coordinates are relative to:09-02 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:1.66° Ladder Plot I , 600— I I I I I I I I JJ J J J 1 = I E'► f 0 'P ,at 0 450— _ 1 9, I �. 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' •� i�� - k�imv v"v .._.. -.�rq :F J J J J _ I �� O I L 150— si • Ut I I I I I I I 0 I I I I 0 2000 4000 6000 8000 10000 12000 Measured Depth(2000 usn) LEGEND 09-01,09-01,09-01 V1 09-05,09-05A,09-05A V1 -0- 09-25,09-25,09-25 V1 09-01,09-01A,09-01AV0 09-06,09-06,09-06 V1 —6— 09-26,09-26,09-26 V1 09-01,09-01APB1,09-01APB1 VO 09-13,09-13,09-13 V1 09-27,09-27,09-27 V1 09-02,09-02,09-02 V1 09-19,09-19,09-19 V1 — — 09-27,Plan 09-27A,09-27A wp07 VO $ 09-02,09-02APB1,09-02APB1V0 09-20,09-20,09-20 V1 —A— 09-28,09-28,09-28 V1 - 09-03,09-03,09-03 V1 $ 09-21,09-21,09-21 V1 —I— 09-28,09-28A,09-28AV1 =^- 09-03,09-03A,09-03A VO 09-22,09-22,09-22 V1 —b— 09-37,09-37,09-37 V1 09-03,09-03A,Plan#7 09-03A Approved V0 09-23,09-23,09-23 V1 09-51,09-51,09-51 V1 •4)— 09-04,09-04,09-04 V1 09-23,09-23A,09-23A V4 -9- 09-02A I• v,,I• '-•,1• 1' •///(/V/�(��\\ c�II t(\1//`-��_• U9-2,i,U9-13Al-' i,,,UU9--ZSAYti1 VS AOGCV OFFSET RE?OR J 2/4/2016 4::36:20PM Page 3 of 3 COMPASS 5000.1 Build 61 • 0 N O llE co N C iL S Q C 92 o r O U U)co co) a) 2 La o) m F- Z F- c < W ) .)'O N CCO o v Ill U Uv a) C • _N a= `O E < m Q 2.3 m 65 N u! o u) '. 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Petrotechnical Data Center,LR2-1 DATA LOGGED /2014 WELL NAME 09-02A 900 E.Benson Blvd. M.K.BENDR Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE February 3,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(a�bakerhughes.com TODAYS DATE February 23,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF PRIN I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope 1 0 1 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I 0 1 1 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I 1 I 1 1 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4,State of Alaska -AOGCC I 1 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 I 1 1 I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 r'Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Nancy Landi TOTALS FOR THIS PAGE: 0 3 4 5 0 0 TOTALS FOR ALL PAGES: 0 3 4 5 0 0 CTI 0 0 col -- fr tw) 4, 4.....) ii. En I 0 . < o I w ca co Ce >11> -.-. ' 0 •..... CD ILI c4 •t. < CO C's8 M TC; 'We La eit. ' CD CNI la LI- , < ZIS CO 9 (i) co a) 0 . , 0 0 ii . CO +a 0 < N E CO ) E a cn u_ Sr! = z i 1.- 122 cc r3 2 on 0 Um It 0 0 0 0 0 ,-- eo ' . . , . . , . 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Da •rc Y CO U CO N a) OO n 0 CO M CO U) CO CO V V 0 CO 6) CO 0 CO 0 IN 10 N co U) V U) CD n CD V N r CO CO V 0 CO CO 0 U) CO CO N U) 0 N 0) 'V 0 O 0 0 0 0 Q O 0 0 r 4 W CD r 8N N N M M M M V V 6 U) N co • > m Qa 0 (4) < V 0 0 0 0 o 2 mo) w a Z a a 0 0 0 O O 0 0 o 0 o o 0 0 O O o 0 O o 0 0 o O O 0 0 o 0 O O CO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 • 0 0 0 0 0 0 0 0 0 0 o ) o 60 vi 0 6 0 U) 0 6 0 U) o U) 1 n 0 O co 0 0 co 0 o O o o U) n 0 N U) N- 0 N U) n 0 N N n 0 N (V ra 0 r N CO V U) CO n co O) co co 0 r r r r N N N N CO CO co co d' V O - N N N N N N N N N N C) M CM co' C)) M M co- (o tom) M M M t7 M co M ; N 33# .. R a * ea O C ,, co— co. O P C0 U JO O) tl9 'Nese O 0 w 4, y w. N O a Cryrv°i" 'S 0 C') i (� 1111 i . • • N C) C) 0 U) CO 0) V' 0 N V' CO O U) N V' N (0 V' C) N CO CO 0) U) CO U) O) U) V' U) O) (0 0 CO 0 r r V' 0 CO CO N 00 .- 00 O U) CO O V' N N 1 a 0) (3) . 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N) CV CO 0) CO 3Q 0) N (OO CN N O O NO _ t0 N N N VVt0 iN N V0)) (U0 VN OU) 0O 0) 0) N (O CO U t '- N O V' (V O) O 00 f` N N N N <0 0) O (N C) V' (O (O O N V' ti O 0 r r Y CO 0 (0 N 00 0) 0) 0 N 0 V' t0 CO N N O r N C) V (0 N O 0) 0 _N co co co 00 co o0 co O O) O CO O) 0) O 0) O) 0 0 0 0 0 0 0 0 0 r O N N S N N N N N N N N N N N N N N N N O co- 00 O O 00 O O O O O O O a C '2 N O N N N N N N N N n n N N N N N N N N N N N N N N N N N.. 13 C] 5 N N 1- 591 w (0 0 N CO O co co t0 (0 N 0 0 0) UO O N N 0 r) N CO O t- co O N U) U) 0 N CO 0) V' V' 00 0 (0 C) 0 CO Of ( U) C) 03 0 0 (O O M V' 0) O N 0 C) CA U) CO 0 V: CO CO O) CO N CO V- N O N V' N C) O V' CO N t r O N N O 4 M r O) N (0 M ,— O) tri N6 O (O M O co C) O ii co 0 0 0 0 6) 0) 0) CO 0) 0) O O CO CO N N N N N N CC) t0 (O co U) U) U) O 0 G t0 (0 (0 (0 U) t0 U) (0 t0 N (0 t0 (0 t0 U) (0 (0 U) (0 U) 0, (0 t0 t0 U) (0 t0 N : ._ $ .. _ . _ .. _ .. .. _ .. _ L = 0 V' 't V' v V' V' V' V' V' V' 4 7 4 7 4 4 V' V' V' V' V' V' V V V' 7 V' N C 6 4) co 0) co 0 co co CA CP 0) 0) 0) O 0) 0) O O co O co co O O 0) 0) 0) O a+ '0 Z to (0 t0 U) 0 U) U) V) U) U) U) t0 U) U) U) U) U) t0 U) U) t0 U) (0 t0 U) U) V) co 0 i0 0) i+ U )U -p• U 0y z a N C) O N N r U) N N V' 0) 0 V' N 0 N N V' C) N 00 0 N 0) O 0; V V' N N r N U) N r N CO C) N M CO V' C) V' O O) 70 N O N O t0 C) O( t� <v y w Q) N <) i, tf) C) O 6) CA N r N N- n N 0) O N4 CO N O) V' <0 O) O a) U N ha (-. 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N N 0 0 N 0 a r•-• a a 0, CI 0 CO 0 CV (N ,-- ..n NI- Lc) 0 N CO C, 0) 0) ,5 < 1 v- 0 N-., 00 0 ,- ,- CO C0 CO <- 0 0 LO 6 cs) 0 1 6 0 c‘i 4 6 6 0 6 )-,. <6 6 6 .-- (N (N 6 6 r- (N (I) N 0) N.. <7 <- CO ti, CV <- N- , E 0 , 0) a) 0 co co co co N. r,-. N- N- 0 0 0 0 0 • N 04 E , If, to e),4 N NI N N N N NI N N N N N N CV -...7 0 0 0 - I ,p 0 h N. N. N. N- N N.- N... N- N 1---- N N- N N a i 1.1.I , I , •or N MC00000 NLONN- 00 6 0) O (N a) 4 a) 6 co a) (N 0) '7 0 0 <7 ,- N NI N CO CO N- NI 0 N. N., 0 <- 0 CV 00 O; 6 6 6 N t•- N.: N: 6 4 c\i 0) 06 4 6 6 00 sm NICOet LOCONC001 ,-- ,- 0.100 Clett , C 11 o „,..,C AO 0) 0 0 0 0 0 LO 0 CO CO CO 0 0 0 ''''' Iiik, 0 0 ai 0) 0 6 0 0 6 6 6 (N 6 ai o .42,.. 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DATA LOGGED Petrotechnical Data Center,LR2-1 3/24,/201Ga WELL NAME 09-02APB1 900 E.Benson Blvd. M.K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE February 3,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(a�bakerhu ihes.com TODAYS DATE February 23,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF NFtIN I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope 1 0 1 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I 1 1 1 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 1 . 1 l Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** I 0 I 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential”on all material deliver to DNR 6 BP Exploration(Alaska)Inc. I I 1 I Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Nancy Landi TOTALS FOR THIS PAGE: 0 3 4 5 0 0 TOTALS FOR ALL PAGES: 0 3 4 5 0 0 01 r • tib tO 'r N N o_ CO 0 .1I 0 � y a IOW UT 8 ui c•A Q a .� >I LLIu m fac Ea `"V* 03 O ♦l N E. " 0 G d. o C NMI (13 VJ '^ C. L g co Z Ll. Q. Q o ul 0 LI.. d Q 0 • • r ! „• , .... co E 33-csi . • -0 CO = N. 2 ': ! N ,.60, . . : c5 0 -. -<:- . .-, I ai 06 01 0 0, CO -..4- r ! r r a c , ,r .4.. r ,,-.0 • _: Cf) 0) 0) , ; a, !!--,-. a. , , N.. , . : 0 1 : ! . ! ! 0 , 00 00 Z , . 4 ci < ! : 'no @ e) 0 0 00 1.. o , . 00 , . . , 00 „(2.2 . , . 00 . : (0 (9 to' (:e/ - :-, . . h, h , a 0) 0) , ,,t > C, N Zo iii 0 !!!!' — al -d-; 0 . ! . cc o t•- : : ; > -4 4; ! „ . . ii O :ii LI I 47.r 0 ... 1 ] , 0 0 RI 0 6-, , , : : 1,.... C 0-, 3 , . , . ... 0) a) ;I ; ; , , ; . , at 2 1 : ; , : ; c , C 2 ; II ; CO = 'otE '' !II ;. , .... , . . , .. „ , ' , , 0 Li., . 0 : g ,L13: L: 4'0 (3 iji • : , . : . 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"in _c ...... ui s„. .,- ai (.,.. ..- 06 6) 0 ,..., = ‘00 °iit" 0- 01 -- , 0) < , S. y CO 07 a) a> a, 0) C) .....1 .2., 6 co a.. a6 a5 06 a) < > : CO 0 >), SO CD ,,,, co gn , 0C) C) )0 a) a) c) E cu 0 a. a. 1 ..o 0 0 < < a) CC) 0 < a u) < < 112. .0 ,..,, L0 00 0) c) a"; )) C) 0.1 0) 74 , , 4.) = , (N LO 0) )--- 0 0 ...t C 0 0 0 ' .., a 0, r.,„ 1:::.,„ C„-: r,, a) co a, = , , . 0 01 0 CO 0 h) 0 c) 0 Z El 0_ o o o 1 c a, o 2 0. )0 a .0 ,I 0 0 c ; , 1: ..0 , N c , , 4 :. ) <,; 1 < , 3 c r , , , to CC 0 • 0 Pti OF T y, S • THE STATE Alaska Oil and Gas ofA a SK Conservation Commission i t 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 r)4A1,A51‘i' Fax: 907.276.7542 www.aogcc.alaska.gov John McMullen Engineering Team Lead BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool,PBU 09-02A BP Exploration(Alaska), Inc. Permit No: 215-199 Surface Location: 170' FSL, 697' FEL, Sec. 02, T1ON, R15E,UM Bottomhole Location: 2045' FNL, 3116' FEL, Sec. 12, T1ON,R15E,UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy '. Foerster Chair DATED this /it day of December,2015. F".,CI V CU STATE OF ALASKA 0 ASKA OIL AND GAS CONSERVATION COMMIS NOV 0 6 2015 PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: lb. Proposed Well Class: Development-Oil Q- Service-Winj 0 Single Zone •IA lc.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test 0 Development-Gas ❑ Service-Supply ❑ Multiple Zone 0 Colabed Gas 0 Gas Hydrates❑ Redrill 2• Reentry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond Blanket 10 -Single Well 0 11 Well Name and Number: BP Exploration(Alaska),Inc Bond No. 6194193 • PBU 09-02A • 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O.Box 196612 Anchorage,AK 99519-6612 MD: 13792' . TVD: 8909'ss ' PRUDHOE BAY,PRUDHOE OIL 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): ADL 028327 Surface: 170'FSL,697'FEL,Sec.02,T1ON,R15E,UM 8. Land Use Permit: 13. Approximate spud date: Top of Productive Horizon: 1316'FNL,3968'FEL,Sec.12,T1ON,R15E,UM January 15,2016 Total Depth: 2045'FNL,3116'FEL,Sec.12,T1ON,R15E,UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 10875 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: 54 -feet 15. Distance to Nearest Well Open toSurface:x- 717719 - 5941618 - Zone - ASP 4 GL Elevation above MSL: 20.5 -feet Same Pool: y- 715 16. Deviated wells: Kickoff Depth: 10726 • feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 3385 - Surface: 2510 ' 18. Casing Program: Specifications Top-Setting Depth-Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD • MD TVD (includinq stage data) 4-1/4" 3-1/2"x3-1/4" 9.3#/6.6# L-80 STL 3557' 10235' 8406'ss 13792' 8909'ss 198 sx Class'G' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): I Plugs(measured): I Effect.Depth MD(ft): I Effect.Depth TVD(ft): I Junk(measured): 11199 9214 10846 10846 8940 Unknown,11003' Casing Length Size Cement Volume MD TVD Conductor/Structural 80 20" 250 sx AS cmt 36-116 36-116 Surface 2691 13-3/8" 4350 sx AS cmt 35-2726 35-2726 Intermediate 175 sx Class'G' Production 11120 9-5/8" 1500 sx Class'G', 115 sx AS cmt 33-11153 33-9178 Liner 877 7" 10238-11115 8462-9149 Perforation Depth MD(ft): 10674-10972 Perforation Depth TVD(ft): 8805-9039 20.Attachments Property Plat ❑ BOP Sketch El Drilling Program Il Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and correct. Contact Minge,David ay Email David.Minge@bp.com Printed Name John McMUlley(r 'f / Title Engineering Team Lead J Signature �� l / Phone +1 907 564 4711 Date i (- Commission Use Only Permit to Drm �7 7,-- Permit Approval Number: / ./�— /V API Number: 50- 029-20198-01-00 Date: I 1 1s" See cover letter for other i-- a I J requirements: Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: rig Other: cop 7,-/-- ,'to �j 5-0_7 psi p�l sr��Yes 0 No f3 Mud log req'd: Yes 0 /" No Lii //r7n —Ia r re�e-,? fes,— 7 S mea ores Yes 3 No 0 Directional svy req'd: Yes © No 0 , Spacing exception req'd: Yes ❑ No 0 Inclination-only svy req'd: Yes 0 No IV APPROVED BY Approved by: 99,(444,_ COMMISSIONER THE COMMISSION Date:�2 _// ...../5"-- ORIGi AL //71 ''s Form 10-401 Revised 10/2012 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit Form and / Attachments in Duplicate �1 .. //-.c-t.A - i • To: Alaska Oil &Gas Conservation Commission From: David Minge Rig: Nordic 1 0 by CTD Engineer Target Reservoir: Ivishak Zone 2 Date: November 3, 2015 Re: 09-02A Permit to Drill Request History and current status: 09-02 (parent bore)was last online in December 2013, and its production rates were uncompetitive at the Flow Station 2 facility. Average production rate of 09-02 before it was shut-in were: 2 BOPD; 12,553 bwpd (100% WC), 1.5 mmscfd formation gas. The 09-02A sidetrack will access two stagnation polygons around corner producer 09-02. There is also a partially swept target area between the injector(09-19) and the corner producer(09-02)which the sidetrack will test. Proposed plan: Drill a through tubing sidetrack with the Nordic 1 Coiled Tubing Drilling rig on or around January 20st, 2016. E-line service unit will mill XN Nipple, Set Posiset Plug to isolate perforations below, set - whipstock and a Coil Tubing unit will cement squeeze perfs to isolate between 7' and 9-%" casing and the perforations above the side track depth. Nordic 1 will a mill a 3.80"window in the 7"x9-5/8" liner and drill a Zone 2 well to —13,792 MD. The lateral will be completed with a 3-1/2" x 3-1/4" L-80 liner which will be cemented and perforated. Pre-Rig Work: Schedules November 15th, 2015 Mill XN nipple. Set 4-1/2"x 7" Posi-Set plug at 10,740' MD. Set 4-1/2" x 7" 1. E Delta Whipstock at 10,726' MD 2. C Squeeze Cement into perforations - 3. V Pre CTD Tree Work. Set TWC Rig Work: 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. Maximum expected surface pressure with gas (0.10 psi/ft)to surface is 2,510 psi. 2. Mill 3.80"window plus 10' of rathole. Swap the well to 8.5 ppg drilling mud. 3. PU drilling BHA with GR/Resistivity • 4. Drill 4.25" hole to TD at—13,792' MD - 5. Run 3-1/2"x 3-1/4" L-80 liner leaving TOL at—10,235 MD. 6. Pump primary cement bringing TOC to TOL, 41 bbls of 15.8 ppg liner cmt planned* 7. Test liner lap to 2,400 psi. 8. Perforate liner per asset instructions 9. Freeze protect well, RDMO Post Rig: 1. V: Tree work as necessary. 2. S: Drift. LTP if necessary.*Set Live GLV's 3. F: Pressure test Liner top packer 4. T: ASRC flow back *Approved alternate plug placement per 20 AAC 25.112(i) Mud Program: - • Well kill: 8.4-8.6 ppg brine. • Milling/drilling: 8.4-9.5 ppg Power Pro for milling window and drilling (>460 psi over-balance ). -- Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. • S Hole size: 4.25" Liner Program: • 3-1/2", 9.3# L-80 STL Liner 10,235' MD— 10,640' MD • 3-1/4", 6.6# L-80, STL Liner 10,640' MD - 13,792' MD • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. • Magnetic and inclination surveys will be taken every 30 ft. • Distance to nearest property— 10,875' • Distance to nearest well within pool 715 Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. - Perforating: • SWS 2", 6 spf, perf guns • The primary barrier for this operation: a minimum EMW of 8.4 ppg. An EMW of 8.4 ppg for this well will provide over-balance to the reservoir. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti-Collision Failures • There are no wells that fail "Major Risk"with the 09-02A wellpath. - Hazards • DS 09 is an H2S pad • Low Risk of lost circulation • No anticipated fault crossings Reservoir Pressure • The reservoir pressure on 09-02A is expected to be 3,385 psi at 8,751' TVDss. (7.4 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft)to surface is 2,510 psi. 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S ! \ • Øbp North America - ALASKA - BP Prudhoe Bay PB DS 09 09-02 09-02A 09-02A WP15 Plus 500ft Anticollision Report 20 August, 2015 BAKER HUGHES III BP • Mill (44)by Anticollision Report RAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-02 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 09 MD Reference: 2:02 2/16/1976 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.0ousft North Reference: True Reference Well: 09-02 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-02A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-02A WP15 Plus 500ft Offset ND Reference: Offset Datum Reference 09-02A WP15 Plus 500ft Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,600.00 to 14,292.17usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 200.00usft Error Surface: Elliptical Conic Survey Tool Program Date 8/20/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 10,600.00 GyroData Gyro(09-02) GYD-GC-MS Gyrodata gyrocompassing m/s 10,600.00 14,292.17 09-02A WP15 Plus 500ft(09-02A) MWD MWD-Standard Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB DS 03 03-36-03-36-03-36 Out of range PB DS 09 09-02-09-02-09-02 10,650.00 10,650.00 0.00 0.69 -0.69 FAIL-NOERRORS 09-02-09-02A-09-02A WP15 13,792.17 13,792.17 0.00 90.90 -59.09 FAIL-Major Risk 09-12-09-12-09-12 Out of range 09-13-09-13-09-13 Out of range 09-19-09-19-09-19 Out of range 09-21-09-21-09-21 Out of range 09-22-09-22-09-22 Out of range 09-23-09-23-09-23 Out of range 09-23-09-23A-09-23A Out of range 09-23-09-23APB1-09-23APB1 Out of range 09-23-09-23APB2-09-23APB2 Out of range 09-25-09-25-09-25 Out of range 09-46-09-46-09-46 Out of range 09-51-09-51-09-51 Out of range 8/20/2015 3:42:36PM Page 2 of 7 COMPASS 5000.1 Build 61 • BP • FA Fill Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-02 Project: Prudhoe Bay ND Reference: Mean Sea Level Reference Site: PB DS 09 MD Reference: 2:02 2/16/1976 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-02 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-02A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-02A WP15 Plus 500ft Offset ND Reference: Offset Datum Offset Design PB DS 09- 09-02-09-02-09-02 Offset Site Error: 0.00 usft Survey Program: 100-GYD-GC-MS,10900-CB-GYRO-MS Rule Assigned:NOERRORS Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Tootface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +6//-6 +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (") (usft) (usft) lusft) (usft) (usft) (usft) 10,600.00 8,692.23 10,600.00 8,692.23 0.00 0.00 117.95 -1,463.24 4,626.09 7.750 0.00 0.65 -0.65 FAIL-NOERRORS 10,625.00 8,711.99 10,625.00 8,711.99 0.12 0.11 118.48 -1,470.48 4,639.59 7.750 0.00 0.66 -0.65 FAIL-NOERRORS 10,650.00 8,731.78 10,650.00 8,731.78 0.12 0.21 118.94 -1,477.82 4,652.99 7.750 0.00 0.69 -0.69 FAIL-NOERRORS,ES,SF 10,675.00 8,751.57 10,675.00 8,751.57 0.13 0.32 119.37 -1,485.26 4,666.33 7.750 0.00 0.67 -0.66 FAIL-NOERRORS 10,700.00 8,771.34 10,700.00 8,771.34 0.13 0.42 119.40 -1,492.76 4,679.66 7.750 0.00 0.67 -0.65 FAIL-NOERRORS 10,725.00 8,791.12 10,725.00 8,791.12 0.14 0.53 119.37 -1,500.27 4,692.99 7.750 0.00 0.73 -0.67 FAIL-NOERRORS,CC 10,749.99 8,810.61 10,750.00 8,810.88 0.15 0.63 -66.96 -1,507.82 4,706.31 3.875 0.43 0.88 -0.45 FAIL-NOERRORS 10,774.80 8,828.87 10,775.00 8,830.56 0.16 0.74 -62.83 -1,515.42 4,719.71 3.875 2.40 1.92 0.48 Pass-NOERRORS 10,799.14 8,845.39 10,800.00 8,850.21 0.17 0.84 -6160 -1,523.02 4,733.17 3.875 6.34 2.93 3.41 Pass-NOERRORS 10,822.72 8,859.96 10,825.00 8,869.86 0.19 1.50 -61.29 -1,530.63 4,746.63 3.875 12.23 3.91 8.33 Pass-NOERRORS 10,845.31 8,872.53 10,850.00 8,889.48 0.21 2.51 -61.13 -1,53826 4,760.11 3.875 19.91 4.82 15.10 Pass-NOERRORS 10,866.75 8,883.13 10,875.00 8,909.07 0.24 3.54 -61.03 -1,545.91 4,773.63 3.875 29.27 5.68 23.60 Pass-NOERRORS 10,886.94 8,891.87 10,900.00 8,928.63 0.26 4.56 -60.97 -1,553.58 4,787.18 3.875 40.16 6.46 33.72 Pass-NOERRORS 10,905.83 8898.93 10,925.00 8,948.14 0.29 4.59 -60.94 -1,56129 4,800.77 3.875 52.42 7.17 45.27 Pass-NOERRORS 10,925.00 8,904.96 10,950.00 8,96760 0.33 462 -60.95 -1,569.07 4,814.41 3.875 65.93 7.87 58.09 Pass-NOERRORS 10,939.79 8,908.82 10,975.00 8,987.00 0.35 4.64 -60.97 -1,576.91 4,828.09 3.875 80.47 8.38 72.12 Pass-NOERRORS 10,954.95 8,912.04 11,000.00 9,006.34 0.39 4.67 -61.01 -1,584.81 4,841.82 3.875 96.01 8.90 87.15 Pass-NOERRORS 10,968.96 8,914.35 11,025.00 9,025.64 0.42 4.64 -60.93 -1,592.56 4,855.69 3.875 112.43 9.35 103.12 Pass-NOERRORS 10,981.89 8,915.91 11,050.00 9,044.93 0.44 4.01 -60.78 -1,600.15 4,869.66 3.875 12966 9.76 119.95 Pass-NOERRORS 10,993.80 8,916.86 11,075.00 9,064.22 0.47 3.38 -60.66 -1,607.74 4,883.64 3.875 147.63 10.12 137.57 Pass-NOERRORS 11,004.78 8,917.33 11,100.00 9,083.51 0.50 2.75 -60.57 -1,615.32 4,897.61 3.875 166.24 10.44 155.86 Pass-NOERRORS 11,016.74 8,917.41 11,125.00 9,102.81 0.53 2.13 -61.09 -1,622.91 4,911.59 3.875 185.40 1066 174.83 Pass-NOERRORS 8/20/2015 3:42:36PM Page 3 of 7 COMPASS 5000 1 Build 61 ' by • BP • //L! Zy 4'Anticolllslon Report BAKER "�i HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-02 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 09 MD Reference: 2 02 2/16/1976 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-02 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-02A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-02A WP15 Plus 500ft Offset ND Reference: Offset Datum Offset Design PB DS 09- 09-02-09-02A-09-02A WP15 Offset Site Error: 0.00 usft Survey Program: 100-GVD-GC-MS.10600-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth .NIS +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) P) (usft) (usft) (usft) (usft) (usft) (usft) 10,600.00 8,692.23 10,600.00 8,692.23 0.00 0.00 117.95 -1,46324 4,626.09 7.750 0.00 0.65 -0.65 FAIL-Major Risk 10,625.00 8,711.99 10,625.00 8,711.99 0.12 0.12 118.48 -1,47048 4,639.59 7.750 0.00 5.79 -5.74 FAIL-Major Risk 10,650.00 8,731.78 10650,00 8,731.78 0.12 0.12 118.94 -1,477.82 4,652.99 7.750 0.00 6.03 -5.97 FAIL-Major Risk 10,675.00 8,751.57 10,675.00 8,751.57 0.13 0.13 119.37 -1,48526 4,666.33 7.750 0.00 6.28 -6.22 FAIL-Major Risk 10,700.00 8,771.34 10,700.00 8,771.34 0.13 0.13 119.40 -1,492.76 4,679.66 7.750 0.00 6.53 -6.47 FAIL-Major Risk 10,725.00 8,791.12 10,725.00 8,791.12 0.14 0.14 119.37 -1,500.27 4,69299 7.750 0.00 6.78 -6.71 FAIL-Major Risk 10,750.00 8,810.62 10,750.00 8,810.62 0.15 0.15 119.38 -1,507.94 4,706.62 3.875 0.00 6.75 -6,68 FAIL-Major Risk 10,775.00 8,829.01 10,775.00 8,829.01 0.16 0.16 119.38 -1,516.24 4,721.36 3.875 0.00 7.05 -6.97 FAIL-Major Risk 10,800.00 8,845.94 10,800.00 8,845.94 0.17 0.17 119.38 -1,525.26 4,737.38 3.875 0.00 7.29 -7.19 FAIL-Major Risk 10,825.00 8,861.29 10,825.00 8,861.29 0.19 0.19 119.38 -1,534.94 4,754.56 3.875 0.00 7.47 -7.35 FAIL-Major Risk 10850.00 8,874.96 10,850.00 8,87496 0.22 0.22 119,38 -1,545.20 4,772.80 3.875 0.00 7.60 -7.46 FAIL-Major Risk 10,875.00 8,886.84 10,875.00 8,886.84 0.25 0.25 119.38 -1,555.99 4,791.96 3.875 0.00 7.67 -7.49 FAIL-Major Risk 10,900.00 8,896.87 10,900.00 8,896.87 0.28 0.28 119.38 -1,56722 4,811.91 3.875 0.00 7.70 -7.45 FAIL-Major Risk 10,925,00 8,904.96 10,925.00 8,904.96 0.33 0.33 119.38 -1,578.82 4,832.51 3.875 0.00 7.67 -7.31 FAIL-Major Risk 10,950.00 8,911.07 10,950.00 8,911.07 0.37 0.37 119.38 -1,590,71 4,853.63 3.875 0,00 7.63 -7.05 FAIL-Major Risk 10,975.00 8,915.15 10,975.00 8,915.15 0.43 0.43 119.38 -1,602.81 4,875.12 3.875 0.00 7.65 -6.62 FAIL-Major Risk 11,000.00 8,917.17 11,000.00 8,917.17 0.49 0.49 119.38 -1,615.03 4,896.82 3.875 0.00 7.83 -5,80 FAIL-Major Risk 11,025.00 8,917.41 11,025.00 8,917.41 0.55 0.55 117.81 -1,627.14 4,918.69 3.875 0.00 8.18 -457 FAIL-Major Risk 11,050.00 8,917.41 11,050.00 8,917.41 0.62 0.62 114.81 -1,638.22 4,941.10 3.875 0.00 8.60 -4.82 FAIL-Major Risk 11,075.00 8,917.41 11,075.00 8,91741 0.69 0.69 111.81 -1,648.11 4,964.05 3.875 0,00 9.12 -5.07 FAIL-Major Risk 11,100.00 8,917.41 11,100.00 8,917.41 0.77 0,77 108.81 -1,656.79 4,987.50 3.875 0.00 9.69 -5.32 FAIL-Major Risk 11,125.00 8,917.41 11,125.00 8,917.41 0.85 0.85 105.81 -1,664.23 5,011.36 3.875 0.00 10.31 -5.57 FAIL-Major Risk 11,150.00 8,917,41 11,150.00 8,917.41 0.93 0.93 102.81 -1,670.41 5,035.58 3.875 0.00 10.94 -5.82 FAIL-Major Risk 11,175,00 8,917.41 11,175.00 8,917,41 1.02 1.02 102.95 -1,675.66 5,060.02 3.875 0.00 11.72 -6.24 FAIL-Major Risk 11,200.00 8,917.44 11,200.00 8,917.44 1.11 1.11 105.95 -1,681.90 5,084.23 3.875 0.00 12.66 -6.61 FAIL-Major Risk 11,225.00 8,917.48 11,225.00 8,91748 1.21 1.21 108.95 -1,689.39 5,108,08 3.875 0.00 13.62 -6.94 FAIL-Major Risk 11,250.00 8,917.55 11,250.00 8,917.55 1.32 1.32 111.94 -1,698.12 5,131.50 3.875 0.00 14.61 -7,26 FAIL-Major Risk 11,275.00 8,917.64 11,275.00 8,917.64 1.43 1,43 114.94 -1,708.07 5,154.43 3.875 0.00 15.60 -7.57 FAIL-Major Risk 11,300.00 8,917.76 11,300.00 8,917.76 1.54 1.54 117.94 -1,719.20 5,176.82 3.875 0.00 16.61 -7,87 FAIL-Major Risk 11,325.00 8,917.89 11,325.00 8,917.89 1.67 1.67 120.94 -1,731.49 5,198.58 3.875 0,00 17.61 -8.16 FAIL-Major Risk 11,350.00 8,918.05 11,350.00 8,918.05 1,80 1.80 123.94 -1,744.90 5,219.68 3.875 0.00 18.62 -8.45 FAIL-Major Risk 11,375.00 8,918.23 11,375.00 8,918.23 1.93 1,93 126.94 -1,759.39 5,240.04 3.875 0.00 19.62 -8.73 FAIL-Major Risk 11,400.00 8,918.42 11,400.00 8,918.42 2.07 2.07 129.94 -1,774.94 5,259.62 3.875 0.00 20.61 -9.01 FAIL-Major Risk 11,425.00 8,918.64 11,425.00 8,918.64 2.21 2.21 132.94 -1,79148 5,278.36 3.875 0.00 21.59 -9.28 FAIL-Major Risk 11,450,00 8,918.88 11,450.00 8,918.88 2.35 2.35 135.94 -1,808.98 5,296.20 3.875 0.00 22.56 -9.55 FAIL-Major Risk 11,475.00 8,919.14 11,475.00 8,919.14 2.50 2.50 138.94 -1,827.39 5,313.11 3.875 0.00 23.50 -9.81 FAIL-Major Risk 11,500.00 8,919.41 11,500.00 8,919.41 2.65 2.65 141.94 -1,846.66 5,329.03 3.875 0.00 24,42 -10.08 FAIL-Major Risk 11,525.00 8,919.71 11,525.00 8,919.71 280 2.80 144.94 -1,866.74 5,343.92 3.875 0.00 25.30 -10.33 FAIL-Major Risk 11,550.00 8,920.01 11,550.00 8,920.01 2.96 2.96 147.94 -1,887.57 5,357.73 3.875 0.00 26.16 -10.59 FAIL-Major Risk 11,575.00 8,920.33 11,575.00 8,920.33 3,12 3.12 150.94 -1,909.10 5,370.44 3.875 0.00 26.97 -10.81 FAIL-Major Risk 11,600.00 8,920.64 11,600.00 8,920.64 328 328 153.94 -1,93125 5,382.01 3.875 0.00 27.73 -11.02 FAIL-Major Risk 11,625.00 8,920.92 11,625.00 8,920.92 3.43 3.43 156.94 -1,953.99 5,392.39 3.875 0.00 28.45 -11.23 FAIL-Major Risk 11,650.00 8,921.19 11,650.00 8,921.19 3.60 3.60 159.94 -1,977.24 5,401.58 3.875 0.00 29.11 -11.43 FAIL-Major Risk 11,675.00 8,921.43 11,675.00 8,921.43 3.76 3.76 162.94 -2,000.93 5,409.53 3.875 0.00 29.71 -11.63 FAIL-Major Risk 11,700,00 8,921.66 11,700.00 8,921.66 3.92 3.92 165.94 -2,025.01 5,416.24 3.875 0.00 30.25 -11.83 FAIL-Major Risk 11,725.00 8,921.86 11,725.00 8,921.86 408 4.08 168.94 -2,049.41 5,421.67 3.875 0.00 30.73 -12.03 FAIL-Major Risk 11,750.00 8,92203 11,750.00 8,922.03 424 4.24 171.94 -2,074.06 5,425.83 3.875 0.00 31.14 -12.23 FAIL-Major Risk 11,775.00 8,922.19 11,775.00 8,922.19 4.39 4.39 17494 -2,098.89 5,428.68 3.875 0.00 31.48 -12.42 FAIL-Major Risk 8/20/2015 3:42:36PM Page 4 of 7 COMPASS 5000.1 Build 61 �.� • BP • P Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-02 Project: Prudhoe Bay ND Reference: Mean Sea Level Reference Site: PB DS 09 MD Reference: 2:02 2/16/1976 00:00 @ 54.O0usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-02 Survey Calculation Method: Minimum Curvature Well Error: 0.O0usft Output errors are at 1.00 sigma Reference Wellbore 09-02A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-02A WP15 Plus 500ft Offset ND Reference: Offset Datum Offset Design PB DS 09- 09-02-09-02A-09-02A WP15 Offset Site Error: 0.00 usft Survey Program: 100-GVD-GC-MS.10600-MVVD Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface* Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth *N/S 4.E/-IN Hole Size Centre Distance Deviation (usft) (usft) (tisk) (usft) (usft) link) I) lusft) (usft) (usft) (usft) (usft) (usft) 11,800.00 8,922.32 11,800.00 8,922.32 4.55 4.55 177.94 -2,123.84 5,430.23 3.875 0.00 31.75 -12.62 FAIL-Major Risk 11,825.00 8,922.42 11,825.00 8,922.42 4.70 4.70 -179.06 -2,148.84 5,430.48 3.875 0.00 31.95 -12.81 FAIL-Major Risk 11,850.00 8,922.50 11,850.00 8,922.50 4.85 4.85 -176.06 -2,173.81 5,429.42 3.875 0.00 32.08 -13.00 FAIL-Major Risk 11,875.00 8,922.56 11,875.00 8,922.56 5.00 5.00 -173.06 -2,198.70 5,427.05 3.875 0.00 32.14 -13.18 FAIL-Major Risk 11,900.00 8,922.59 11,900.00 8,922.59 514 5.14 -170.06 -2,223.42 5,423.38 3.875 0.00 32.13 -13.37 FAIL-Major Risk 11,925.00 8,922.60 11,925.00 8,922.60 5.29 5.29 -167.06 -2,247.92 5,418.42 3.875 0.00 32.06 -13.70 FAIL-Major Risk 11,950.00 8,922.58 11,950.00 8,922.58 5.42 5.42 -164.06 -2,27213 5,412.19 3.875 0.00 31.93 -14.21 FAIL-Major Risk 11,975.00 8,922.54 11,975.00 8,922.54 5.55 5.55 -161.06 -2,295.98 5,404.70 3.875 0.00 31.75 -14.74 FAIL-Major Risk 12,000.00 8,922.47 12,000.00 8,922.47 5.68 5.68 -158.06 -2,319.40 5,395.97 3.875 0.00 31.51 -15.26 FAIL-Major Risk 12,025.00 8,922.38 12,025.00 8,922.38 5.81 5.81 -155.07 -2,342.34 5,386.03 3.875 0.00 31.22 -15.79 FAIL-Major Risk 12,050.00 8,922.26 12,050.00 8,922.26 5.92 592 -152.07 -2,364.72 5,374.90 3.875 0.00 30.90 -16.33 FAIL-Major Risk 12,075.00 8,922.12 12,075.00 8,922.12 6.04 6.04 -149.07 -2,386.49 5,362.62 3.875 0.00 30.54 -16.87 FAIL-Major Risk 12,100.00 8,921.96 12,100.00 8,921.96 6.15 6.15 -146.07 -2,40759 5,349.21 3.875 0.00 30.15 -17.41 FAIL-Major Risk 12,125.00 8,921.77 12,125.00 8,921,77 6.25 6.25 -143.07 -2,427.96 5,334.72 3.875 0.00 29.73 -17.96 FAIL-Major Risk 12,150.00 8,921.56 12,150.00 8,921.56 6.35 6.35 -140.07 -2,447.54 5,319.18 3.875 0.00 29.31 -18.51 FAIL-Major Risk 12,175.00 8,921.33 12,175.00 8,921.33 6.44 6.44 -137.07 -2,466.28 5,302.64 3.875 0.00 28.87 -19.06 FAIL-Major Risk 12,200.00 8,921.07 12,200.00 8,921.07 6.53 6.53 -134.07 -2,484.13 5,285.14 3.875 0.00 28.45 -19.62 FAIL-Major Risk 12,225.00 8,920.80 12,225.00 8,920.80 6.61 6.61 -131.07 -2,501.04 5,266.74 3.875 0.00 28.03 -20.18 FAIL-Major Risk 12,250.00 8,920.50 12,250.00 8,920,50 6.69 6.69 -128.07 -2,516.96 5,247.47 3.875 0.00 27.65 -20.75 FAIL-Major Risk 12,275.00 8,920.19 12,275.00 8,920.19 6.76 6.76 -125.07 -2,531,85 5,227.39 3.875 0.00 27.32 -21.31 FAIL-Major Risk 12,300.00 8,919.86 12,300.00 8,919.86 6.82 6.82 -122.07 -2,545.67 5,206.57 3.875 0.00 27.06 -21.89 FAIL-Major Risk 12,325.00 8,919.51 12,325.00 8,919.51 6.88 6.88 -119.07 -2,55838 5,185.05 3.875 0.00 26.88 -22.46 FAIL-Major Risk 12,350.00 8,919.14 12,350.00 8,919.14 6.93 6.93 -116.07 -2,569.95 5,162.89 3.875 0.00 26.82 -23.03 FAIL-Major Risk 12,375.00 8,918.76 12,375.00 8,918.76 6.97 6.97 -113.07 -2,580.34 5,140.16 3.875 0_00 26.90 -23.61 FAIL-Major Risk 12,400.00 8,918.37 12,400.00 8,918.37 7.01 7.01 -110.07 -2,589.53 5,116.91 3.875 0.00 27.13 -24.19 FAIL-Major Risk 12,425.00 8,917.96 12,425.00 8,917.96 7.04 7.04 -107.07 -2,597.49 5,093.22 3.875 0.00 27.56 -24.78 FAIL-Major Risk 12,450.00 8,917.54 12,450.00 8,917.54 7.07 7.07 -104.07 -2,604.20 5,069.14 3.875 0.00 28.21 -25.36 FAIL-Major Risk 12,475.00 8,917.10 12,475.00 8,917.10 7.08 7.08 -101.07 -2,609.63 5,044.75 3.875 0.00 29.12 -25.95 FAIL-Major Risk 12,500.00 8,916.66 12,500.00 8,916.66 7.10 7.10 -98.07 -2,613.79 5,020.10 3.875 0.00 30.29 -26.54 FAIL-Major Risk 12,525.00 8,916.21 12,525.00 8,916.21 7.10 7.10 -95.07 -2516.65 4,995.27 3.875 0.00 31.66 -27.13 FAIL-Major Risk 12,550.00 8,915.75 12,550.00 8,915.75 7.10 7.10 -92.07 -2,618.20 4,970.33 3.875 0.00 33.19 -27.73 FAIL-Major Risk 12,575.00 8,91529 12,575.00 8,915.29 7.09 7.09 -89.07 -2,618.45 4,945.34 3.875 0.00 34.83 -28.33 FAIL-Major Risk 12,600.00 8,914.82 12,600.00 8,914.82 7.07 7.07 -86.06 -2,617.38 4,920.37 3.875 0.00 36.55 -28.93 FAIL-Major Risk 12,625.00 8,914.35 12,625.00 8,914.35 7.05 7.05 -83.06 -2,615.02 4,895.49 3.875 0.00 38.32 -2953 FAIL-Major Risk 12,650.00 8,913.87 12,650.00 8,913.87 7.02 7.02 -80.06 -2,611.35 4,870.77 3.875 0.00 40.12 -30.13 FAIL-Major Risk 12,675.00 8,913.39 12,675.00 8,913.39 6.99 6.99 -77.06 -2,60640 4,846.27 3.875 0.00 41.93 -30.74 FAIL-Major Risk 12,700.00 8,912.92 12,700.00 8,912.92 6.95 6.95 -74.06 -2,600.16 4,822.07 3.875 0.00 43.73 -31.35 FAIL-Major Risk 12,725.00 8,912.44 12,725.00 8,91244 6.90 6.90 -71.06 -2,592.67 4,79822 3.875 0.00 45.50 -31.96 FAIL-Major Risk 12,750.00 8,911.97 12,750.00 8,911.97 6.86 6.86 -68.06 -2,583.95 4,774.80 3.875 0.00 47.24 -32.57 FAIL-Major Risk 12,775.00 8,911.51 12,775.00 8,91151 6.81 6.81 -65.06 -2,574.01 4,751.87 3.875 0.00 48.92 -33.19 FAIL-Major Risk 12,800.00 8,911.04 12,800.00 8,911.04 6.76 6.76 -62.06 -2,562.88 4,729.49 3.875 0.00 50.55 -33.81 FAIL-Major Risk 12,825.00 8,910.59 12,825.00 8,910.59 6.70 6.70 -62.19 -2,550.90 4,707.55 3.875 0.00 50.93 -34.41 FAIL-Major Risk 12,850.00 8,910.19 12,850.00 8,910.19 6.65 6.65 -65.19 -2,539.83 4,685.15 3.875 0.00 50,33 -34.98 FAIL-Major Risk 12,875.00 8,909.85 12,875.00 8,909.85 6.61 6.61 -68.19 -2,529.94 4,662.19 3.875 0.00 49.87 -35.56 FAIL-Major Risk 12,900.00 8,909.56 12,900.00 8,909.56 6.58 6.58 -71.18 -2,521.26 4,638.75 3.875 0.00 49.56 -36.14 FAIL-Major Risk 12,925.00 8,909.33 12,925.00 8,909.33 655 6.55 -74.18 -2,513.82 4,614.89 3.875 0.00 4942 -36.72 FAIL-Major Risk 12,950.00 8,909.16 12,950.00 8,909.16 6.53 6.53 -77.18 -2,507.64 4,590.67 3.875 0.00 49.44 -37.30 FAIL-Major Risk 12,975.00 8,909.04 12,975.00 8,909.04 6.51 6.51 -80.18 -2,502.73 4,566.16 3.875 0.00 49.63 -37.89 FAIL-Major Risk 8/20/2015 3:42:36PM Page 5 of 7 COMPASS 5000.1 Build 61 • BP i IZte 0 bp Anticollision Report BAKER HUMES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-02 Project: Prudhoe Bay ND Reference: Mean Sea Level Reference Site: PB DS 09 MD Reference: 2:02 2/16/1976 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-02 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-02A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-02A WP15 Plus 500ft Offset TVD Reference: Offset Datum Offset Design PB DS 09- 09-02-09-02A-09-02A WP15 offset Site Error: 000 usft Survey Program: 100-GYD-GC-MS,10600-MWO Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +EI-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (osis) (usft) (usft) Cl (usft) (use) (usft) (usft) (usft) (usft) 13,000.00 8,908.99 13,000.00 8,908.99 6.50 6.50 -83.17 -2,499.11 4,541.43 3.875 0.00 49.99 -38.48 FAIL-Major Risk 13,025.00 8,908.98 13,025.00 8,908.98 6.49 6.49 -83.04 -2,496,43 4,516.57 3,875 0.00 51.03 -39.09 FAIL-Major Risk 13,050.00 8,908.98 13,050.00 8,908.98 6.47 6.47 -80.04 -2,492.75 4,491.84 3.875 0.00 52,61 -39.73 FAIL-Major Risk 13,075.00 8,908.98 13,075.00 8,908.98 6.45 6.45 -7704 -2,487.79 4,467.35 3.875 0.00 54.20 -40.38 FAIL-Major Risk 13,100.00 8,908.98 13,100.00 8,908.98 6.43 6.43 -74.04 -2,481.54 4,443.14 3.875 0.00 55.76 -41.03 FAIL-Major Risk 13,125.00 8,908.98 13,125.00 8,908.98 6.41 6.41 -71.04 -2,474,04 4,419.30 3.875 0.00 57.30 -41.68 FAIL-Major Risk 13,150.00 8,908.99 13,150.00 8,908.99 6.39 6.39 -68.04 -2,465.31 4,395.88 3.875 0.00 58.78 -42.33 FAIL-Major Risk 13,175.00 8,908.99 13,175.00 8,908.99 6.38 6.38 -65.04 -2,455.35 4,372.94 3.875 0.00 60.20 -42.99 FAIL-Major Risk 13,200.00 8,908.99 13,200.00 8,908.99 6.37 6.37 -62.04 -2,44421 4,350.57 3.875 0.00 61.54 -43.65 FAIL-Major Risk 13,225.00 8,908.99 13,225.00 8,908.99 6.37 6.37 -59.04 -2,431.92 4,328.80 3.875 0.00 6280 -44.30 FAIL-Major Risk 13,250.00 8,908.99 13,250.00 8,908.99 6.38 6.38 -56.04 -2,418.50 4,30771 3.875 0.00 63.97 -44.96 FAIL-Major Risk 13,275.00 8,908.99 13,275.00 8,908.99 6.42 6.42 -53,04 -2,404.00 4,287.35 3,875 0.00 65.04 -45,63 FAIL-Major Risk 13,300.00 8,908.99 13,300.00 8,908.99 6.48 6.48 -50.04 -2,388.45 4,267.78 3.875 0.00 66.01 -4629 FAIL-Major Risk 13,325.00 8,908.99 13,325.00 8,908.99 6.55 6.55 -50.17 -2,372.17 4,248.81 3.875 0.00 66.82 -46.95 FAIL-Major Risk 13,350.00 8,908.99 13,350.00 8,908.99 6.64 6.64 -53.17 -2,356.67 4,229.20 3.875 0.00 67.62 -47.57 FAIL-Major Risk 13,375.00 8,908.99 13,375.00 8,908.99 6.75 6.75 -56.17 -2,342.21 4,208,80 3.875 0.00 68.54 -48.20 FAIL-Major Risk 13,400.00 8,908.99 13,400.00 8,908.99 6.87 6.87 -59.17 -2,328.84 4,187.68 3.875 0.00 69.57 -48.82 FAIL-Major Risk 13,425.00 8,908.99 13,425.00 8,908.99 7.02 7.02 -62.17 -2,316.60 4,165.89 3.875 0.00 70.68 -49.45 FAIL-Major Risk 13,450.00 8,908.99 13450.00 8,908.99 7.18 7.18 -65.17 -2,305.51 4,143.48 3.875 0.00 71.87 -50.08 FAIL-Major Risk 13,475.00 8,909.00 13,475.00 8,909.00 7.34 7.34 -68.17 -2,295.62 4,120.53 3.875 0.00 73.12 -50.72 FAIL-Major Risk 13,500.00 8,909.00 13,500.00 8,909.00 7.52 7.52 -71.17 -2,286.93 4,097.09 3.875 0.00 74.40 -51.36 FAIL-Major Risk 13,525.00 8,909.00 13,525.00 8,909.00 7.71 7.71 -74.17 -2,279.49 4,073.23 3.875 0.00 75.71 -51.99 FAIL-Major Risk 13,550,00 8,909.00 13,550.00 8,909.00 7.90 7.90 -77.17 -2,273.30 4,049.01 3.875 0.00 77.03 -52.63 FAIL-Major Risk 13,575,00 8,909.00 13,575.00 8,909.00 8.09 8.09 -80.17 -2,268.39 4,024.50 3.875 0.00 78.35 -53.28 FAIL-Major Risk 13,600.00 8,909.00 13,600.00 8,909.00 829 8.29 -83.17 -2,264.77 3,999.76 3.875 0.00 79.65 -53.92 FAIL-Major Risk 13,625.00 8,909.00 13,625.00 8,909.00 8.49 8.49 -83.04 -2,262.09 3,974,91 3.875 0.00 81.21 -54.58 FAIL-Major Risk 13,650.00 8,909.00 13,650.00 8,909.00 8.71 8,71 -80.04 -2,258.41 3,950.18 3.875 0.00 82.97 -55.26 FAIL-Major Risk 13,675.00 8,909.00 13,675.00 8,909.00 8.93 8.93 -77.04 -2,253.45 3,925.69 3.875 0.00 84.62 -55.94 FAIL-Major Risk 13,700.00 8,90900 13,700.00 8,909.00 9.15 9.15 -74.04 -2,247.20 3,901.48 3.875 0.00 86.16 -56.63 FAIL-Major Risk 13,725.00 8,909.00 13,725.00 8,909.00 9.38 9.38 -71.04 -2,239.70 3,877.63 3.875 0,00 87.58 -57.31 FAIL-Major Risk 13,750.00 8,909.00 13,750.00 8,909.00 9.60 9.60 -68.04 -2,230.97 3,85421 3.875 0.00 88.86 -58.00 FAIL-Major Risk 13,77500 8,909.00 13,775.00 8,909.00 9.83 9.83 -65.04 -2,221.01 3,831.28 3.875 0,00 90.00 -58,69 FAIL-Major Risk 13,792.17 8,909.00 13,792.17 8,909.00 9.99 9.94 -62.98 -2,213.49 3,815.85 3.875 0.00 90.90 -59.09 FAIL-Major Risk,CC,ES,SF 8/20/2015 3:42:36PM Page 6 of 7 COMPASS 5000.1 Build 61 • BP • Falai Anticollision Report BAKER .' HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-02 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 09 MD Reference: 2:02 2/16/1976 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-02 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-02A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-02A WP15 Plus 500ft Offset TVD Reference: Offset Datum Reference Depths are relative to 2:02 2/16/1976 00:00 @ 54.00usft Coordinates are relative to:09-02 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:1.66° Ladder Plot • 180— -- — W I W I I ' l W I I W 8 q 1 B I tl 1 a s tl . a I I W Y tl Y I 17)135 1 Y W I I = 9 I I 1 Lr) N I I Y tl I I v 1 tl W W I fl 1 tl Y N1 I I SS 9 a 1 1 a N 1 1 rn 90— / tl I H 1 9 I 2 ! P I 1 = I W 1 1 N I tl Y 1 U J J J O W W 9 I I 1 1 W I I I W 1 I I ! 7 I 1 I I 1 I I 1 0 I ( I I I I 0 2500 5000 7500 10000 12500 15000 Measured Depth(2500 usft/in) LEGEND 03-36,03-36,03-36 V1 $ 09-06,09-06,09-06 V1 09-25,09-25,09-25 V1 -6- 09-01,09-01,09-01 V1 09-12,09-12,09-12 V1 09-26,09-26,09-26 V1 -X- 09-01,09-01A,09-01AV\PO1 VD -X- 09-13,09-13,09-13V1 $a 09-27,09-27,09-27 V1 $ 09-02,09-02,09-02 V1 09-18,09-18,09-18 V1 09-27,Plan 09-27A,09-27Awp04 VO -I- 09-02,09-02A,09-02AWP15 VO 09-19,09-19,09-19 V1 • -- 09-28,09-28,09-28 V1 -9- 09-03,09-03,09-03 V1 09-20,09-20,09-20 V1 09-28,09-28A,09-28A V1 09-03,09-03A,09-03A VO 09-21,09-21,09-21 V1 -9- 09-37,09-37,09-37 vi - - 09-03,09-03A,Plan#709-03AApproved VO 09-22,09-22,09-22 V1 09-46,09-46,09-46 V1 09-04,09-04,09-04 V1 09-23,09-23,09-23 V1 09-49,09-49A,09-49A VVP14 VO 09-04.09-04A,09-04A V2 09-23,09-23A,09-23A V4 09-51,09-51,09-51 V1 8/20/2015 3:42:36PM Page 7 of 7 COMPASS 5000.1 Build 61 • • '^ WELLBORE DETAILS:CG-02A F6s84CENMPIAMEN >.- Pref:Prudhoe Bay /�� a4ee...11%, aarrelli� See'PB OS 09 �� CO-NA Covdnxg(Dl Roe xe VYOS Le,S b19 II Well.09-02 1 iy,sle31.4n1' lMid(NO)Rdae4a AlsenSrlM BAKERHUGHES 0 Welmare:08-07A ( 4eo..n.Ni a Pier[Wellbore 0 02 dd um Meowed 0m 2 022/150915 6)5400um(9eleesa 9n9) HU1ir7i47 bp PW:0{BOAaders.01.00R 109-02/09-02A) tJ re�mvm�s Tie an MD-1000000 gym Mem smq a l7 Easting(95 ueMin) �7 w w 3 3 Y 4 Y 4 4 4 4 g . S 'Y, 4 0 0 4 Y 4 q Y._. w � w w � w w � m w > wm w w o u 999 w w w 5940]30 w -_� : .� _ _ _.___ _. __ __.__ -I -._ _-I I - _ _:-"'5940'/30 w a `w L— 4 -- I_ _ I �_ .___.__ i 5940635 L 5940540 - -- -�---.. } 1— 5940540 5940445 ... L :___ - _ �_ _ _ - --5940445 1I 1 5940350 - _ _ _-+ ( �(��\ � _._.t I -l-- _- } ' 40 I , X5940350 5940255 _.. ___-- —_ --I I -'r F..__ -� i __ - _.. _._,_,.(ytr -_+_F _I- ___---. i.-5940255 i . 5940160 _. -..L. .*. __ --. 4 -___"' 5940160 5940095 --. - - __._ Y___1. L_ I , .[_ 7j +-__ __ _____._ �. -_.,-_--.-_- .._ ..--5940065 _5939910 ._-_ __. ....-.... �. ` 4-- -_ _y—..L _ __ _. —__— — 58399102 59]9615_- -_ ___ -— _. —_L _ /� , 1 '.' �� , ,pl - 3939815 5 X5939180 -._ .!1 VM tTTi I _Ii 3 ... - --{-- I 5939180 1 1 a .5939885___.._ ____ _ - �. -,. I —_.. I I _I _ -- _ —5939685a...- _. I 1 5939590 I .. •i •F :_.._.. ._-._._.{_- _ .r.. - 3939590 1fl! ill 5939495 - - --._ _ ____ _ j I L �_ _ r :9495 5939400 -._ _� _ :. T I ! _ ri- '� 59394W III5939305 __ -- __-r ,. ..._.. 1- i _ ,�. I -- -5939305 5939210 --... _ ___ I __ .___ _---- .__ Ill I _ \ 1 - ;39210 OP I 5939115 -- - __- ..` i1.____ (_;__.. -_ , �� I _ _�. _F— F -. .. I-i 5939115 filli flf 5939020 _._ __. _-.-_— I -r_.- __.__._. 1 1 5938925-.. I ! _ - I -;-s}1 Ser 4e., : h- 0 - - H - :--- U el g7i. v 5d° ,u ,'i 5, 8 s o N i 1, § w s w a , 1 w w i i s o w ] S a 3 1 ,t a g g u 1 w o 1 1 1 Easting(95 usNn) Mean Sea Level TREE= aw ____ _ I r NO WELLHEAD= FMC GEN 1 • 09-02A I SA TES: ***CHROME LNR&TBG""• ACTUATOR= BAKER C OKB.ELEV= 54' CTD Sidetrack I 2231' H7"CAM BAL-OSSSV NP,D=5.937" BF.ELEV= KOP= 3079' / 2985' —17"X 5-1/2'XO,D=4.892" Max Angle= 47'(al, 7000' Datum MD= 10733' (7) Datum TVD= 8800'SS A GAS LFT MANDRELS _ / r ST MD ND DEV TYPE VLV LATCH PORT' DATE 13-3/8"CSG,72#,MN-80,D=12.347" -1 2726' ` / 1 2998 2997 8 FMHO DMY RK 16 1 05/06/15 2 4619 4434 42 FMHO DMY RK 0 !08/26/91 7"TBG,26#,13CR-80,.0383 bpf,D=6.276" H 2985 3 5724 5221 45 FMHO DMY RK 0 105120/97 4 6401 5713 43 FMHO DMY RK 16 +06/06/15 I 5 7035 6159 47 FMHO DMY RK 0 108/26/91 6 7707 6626 45 FMHO DMY RK 0 108/26/91 "7 8295 7055 42 FMHO DMY RK 0 1 08/26/91 Minimum ID = 3.725" @ 10265' 8 8840 7454 44 FMHO DMY RK 16 06/06/15 4-1/2" OTIS XN NO-GO NIPPLE 9 9424 7870 45 FMHO DMY RK 0 08/26/91 10 9797 8136 44 FMHO DMY RK 24 07/06/15 11 10126 8379 41 FMHO RKED RKP 0 05/20/92__ "'CANNOT PULL STI7 AS OF 8115197 10151' —15-1/2"X 4-1/2"XO,D=3.958" 5-112'TBG, 17#. 13CR-80. 0232 bpi, ID=4.892" l 10161 i - // 10153' -1 BKR GBH-22 LOCATOR SEAL ASSY,D=? I _ _ 10154' H9-5/8"X 4-12"BKR MEL.ODD PKR,D= 10168' —5"MILLOUT EXTENSION,ID=? 10173' —MLLOUT EXTSION XO TO 4-12",D=3.958' 19-5/8"X 7"TACK SLV,D=? H 10222' _ 3.70"BKR DEPLOY SLV,ID =3.00"@ 10,235'MD 9-5/8"X7"BKR&LNR HGR,ID=? 10230' 31/2"X-NppeID=2.813"@ 10,245'MD I 10265• —4-1/2'OTIS XN N8',D=3.725' M iXN 4-12"TBG, 12.6#,13CR-80,.0152 bpf,D=3.958" —1 10278' / 10277' H4-12"BKR SI-EAROUT SUB,D=? PERFORATION SUMMARY REF LOG: BHCS ON 03/10/76 10278' —14-12"TUBING IAL,D=3.958" NOTE GR does not correlate wIBHCS due l01107'deposits ANGLE AT TOP PERF: 38'@ 10674' _\ 10287 H FWD TT LOGGED 09/06/91 Note:Refer to Production DB for historical pert data 10453' —17"MARKER JOINT SIZE 1 SPF ( INTERVAL I Opn/Sqz 1 DATE SEE PAGE 2 FOR PERFORATION INFORMATION I 10474' —7"MARKER JOINT I I I 3-1/2"93`f STL 13CR-80---� 3 1/2"x3 1/4"XO @ -10,640'MD 197100' BUR 4-1/2"x 7"B akerTT whipstock@ 10,726 'MD i 38°nc@ wndow n 7"Tnflatabh Bri3ge Plig @ 10,74' ' RA TAG @ TBD TD @ 13,792 M 1 • 3-1/4"13CR Lsiertn"' 11003' H FISH-2 Small Pieces of Spinner Housing 1- IhY PBTD — 11055' 1 7"LNR,29#,13CR-80..0371 bpf,D=6.184" 11097' .'.'.'.'.'1�.A11 ��eA��g�e�g�gIege ?? _1—FISH-BP RUBBER ELEMENT(03/26/96) 9-5/8'CSG,47#,MN-80,D=8.681" 11153' 1.1.1.�.�.�/�1�1�.�•4 TD —i 11199' .'.'• DATE REV BY COMMENTS DATE REV BY CONVENTS FRUDHOE BAY UNIT 03/22/76 INITIAL COMPLETION 03/04/14 JMG/JMD SET PXN PLUG(02/22/14) WELL: 09-02 08/25/76 ROW 34 RWO 03/14/14 JLS/JMD PULLED PXN PLUG(03/11/14) PB:21IT No: 1760160 10/20/87 PAA 102 RWO API No: 50-029-20198-00 08/27/91 RWO SEC 2,T1 ON,R15E,170'FSL&697'FEL 09/07/12 MSS/JMD GLV C/O(09/05/12) 11/14/12 JCM'JMD SET HEX PLUG(11/11/12) BP Exploration(Alaska) 0 0 9 f O ' LL EX II: 0 V a E IX o 6 9 'i� Y -IONE u V V w i. G6 m ►�, a E w �' nilO A - F.V 111 O; gg1 ii • 2'252 5 m • ,A, m o G m gO " O a _ K a e m CI r 1 r J 1 ii• i I � 1I €1, o >X11 .- x 1 ., 111 111 LL iiiI = n 41 H /1 _ o Z 1 1 LL Zi- --- 1111 u III a iI .7, 11 w 1 « 1111 J > 1 E e I I Z C Q j or ' w y 1111 111 J likI g G ?O III U 3 0 y K" LL' • 111 ' �r I AMII I O .I� I • 1I1 nn a W u c m V 01 ,-, ,=,,,,p, r! W • y 71' U 1 I ¢ a m 'r � i I � im V I Q F y d I I . I 1> 1 ~; i Q 1 "° o c I ..1 vW E Q m 1 Y � Z I J,lIl\�ll'N N I= I I Il 0 i N .I s ill °mw 1 I a �� '� 11111 0 11 m t.t. ¢ * rc I M III II 11 � iv � e vii 1 III I� G o i P,' o 1 00 [� a ` Li* II Z2 I 111 j n I (-,--.) - rt0I---.Ii1111 a 111ii r 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: � 1S—, l9 VDevelopment Service Exploratory Stratigraphic Test _Non-Conventional FIELD: d7k 7POOL: % éhc (--1// Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 0 0 ❑❑ „ I N m 0 , N N , a) E , , � ; ; a , ;, , , , , , ; ,, 0 , 3, fo; c; N: O: E O a �i; 0 4 a Q o , w, cii v_) co, cc) o co v, 0 , p CO: •�: O: V,Na) �: d O O a L E D 0 a) �°,, a N ° a ar- a � N. JOCa.). I(c), N �, ,r, m: co o, w m, i° N rn o E 0 o' m' M m' I a E: ° o. w o O L c N: a > o: a M: N c @ o, O p 2, a�j _c ° Qo,; _ a), `°' o; E' ui °3 ca CP m 0; ap , L C 0 a, f-, O C m, C0: 3: '°. •uy N7: CO: �: �: m: a, C, m ° 2' a @ 3. �, iii: c, u) uui: 2' , ° m, , n a 2: E m: N (n' C a)' 0) Q 2, <; 5; 3; OO, , as c' c° c y' co, m, a O; CO; `m; c m m; a) Ce co a O O a) ' g. 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