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Home My WebLink About216-175From:Lau, Jack J (OGC) To:Oliver Sternicki Cc:PB Wells Integrity; Michael Hibbert Subject:RE: [EXTERNAL] Re: NK-15A (PTD# 216175) Request to flow under evaluation with TxIA comm for economic evaluation Date:Thursday, June 5, 2025 9:12:30 AM Good morning Oliver, You have approval to produce with gas lift for the under eval period. Please ensure the well is monitored for any additional signs of ann comm including IAxOA while online. Thanks, Jack From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, June 5, 2025 8:25 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com> Subject: RE: [EXTERNAL] Re: NK-15A (PTD# 216175) Request to flow under evaluation with TxIA comm for economic evaluation Jack, Ops has been trying to flow NK-15 since 5/30/25, but have not been able to get the well unloaded. We had previously assumed that we wouldn’t need gas lift on this well, but it looks like we will. We would like to request approval to use gas lift for this POP UE period on NK-15. Thanks, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, May 20, 2025 4:16 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] Re: NK-15A (PTD# 216175) Request to flow under evaluation with TxIA comm for economic evaluation Oliver, You are approved to produce NK-15A for up to 45 days under eval for economic evaluation of a RWO. Jack From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, May 15, 2025 10:12 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: NK-15A (PTD# 216175) Request to flow under evaluation with TxIA comm for economic evaluation Jack, NK-15A (PTD# 216175) is currently not operable since 6/21/23 due to failing a MIT-T. The well was secured and a subsequent LDL on 6/23/23 found holes in the tubing at 7930’ and 11120’ MD with a LLR of 0.5 bpm at 2500 psi. On 5/14/25 the well passed a CMIT- TxIA to 2834 psi verifying a competent secondary well barrier. Hilcorp would like to request permission to place NK-15A on production for up to 45 days to evaluate economics in support of a rig workover to replace the tubing. Gas lift will not be needed for this operation. IAP will be maintained below MOASP of 2500 psi and the well will be secured at the end of the evaluation period. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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. 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. 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:Lau, Jack J (OGC) To:Oliver Sternicki Subject:Re: NK-15A (PTD# 216175) Request to flow under evaluation with TxIA comm for economic evaluation Date:Tuesday, May 20, 2025 4:15:35 PM Oliver, You are approved to produce NK-15A for up to 45 days under eval for economic evaluation of a RWO. Jack From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, May 15, 2025 10:12 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: NK-15A (PTD# 216175) Request to flow under evaluation with TxIA comm for economic evaluation Jack, NK-15A (PTD# 216175) is currently not operable since 6/21/23 due to failing a MIT-T. The well was secured and a subsequent LDL on 6/23/23 found holes in the tubing at 7930’ and 11120’ MD with a LLR of 0.5 bpm at 2500 psi. On 5/14/25 the well passed a CMIT- TxIA to 2834 psi verifying a competent secondary well barrier. Hilcorp would like to request permission to place NK-15A on production for up to 45 days to evaluate economics in support of a rig workover to replace the tubing. Gas lift will not be needed for this operation. IAP will be maintained below MOASP of 2500 psi and the well will be secured at the end of the evaluation period. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU NK-15A Tbg swap Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 216-175 50-029-22745-01-00 0034635 , 0034630 16752 Conductor Surface Intermediate Liner Liner 9800 80 7324 7442 6853 2785 13944 20" 13-3/8" 9-5/8" 7" 4-1/2" 9460 49 - 129 48 - 7372 45 - 7487 7285 - 14138 13965 - 16750 3267 49 - 129 48 - 5075 45 - 5107 5051 - 9617 9477 - 9801 none 520 2260 4760 5410 7500 13944 , 14670 1530 5020 6870 7240 8430 14164 - 16700 4/12" 12.6# L-80 44 - 139659638 - 9814 Structural 4-1/2" HES TNT Perm No SSSV 13834 9372 Date: Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com 907.564.4061 PRUDHOE BAY 8-1-2023 Current Pools: RAVEN OIL Proposed Pools: RAVEN OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:17 am, Jul 14, 2023 323-397 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.07.14 07:16:52 -08'00' DSR-7/19/23 3267 MDG 7/21/2023 10-404 BOPE pressure test to 3500 psi. Annular to 2500 psi. MGR14JUL23GCW 07/24/2023JLC 7/24/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.24 19:06:17 -06'00'07/24/23 RBDMS JSB 072523 NK-15A : Tbg Swap PTD: 216-175 Page 1 of 7 Well Name:NK-15A API Number:50-029-22745-01-00 Current Status:Not Operable, Shut in Permit to Drill Number:216175 Estimated Start Date:August 2023 Rig:Thunderbird Regulatory Contact:Carrie Janowski Estimated Duration:6 days First Call Engineer:Eric Dickerman Cell Number:307-250-4013 Second Call Engineer:Dave Bjork Cell Number:907-440-0331 Brief Well Summary: NK-15A was drilled as an injector in the Raven block at Niakuk. The well was converted from an injector to a producer in 1Q 2021 and has been a full time producer since that time. In June 2023, the well was made Not Operable after a leak detection log found holes in the tubing at 7,930’ and 11,120’. A caliper was logged on June 24, 2023 and found the tubing in poor condition due to corrosion. x The well is currently secured with a plug in the tubing tail, and the well passed a CMIT-TxIA on 6/22/2023 indicating the tubing tail plug and production casing have integrity. Objective: Replace tubing. Return well to production. Current Bottom Hole Pressure:4,252psi at 9,850’TVDss | from NK-38B SBHP in same fault block 8.31 ppg EMW Max. Anticipated Surface Pressure:3,267psi (0.1psi/ft gas gradient to surface) Last Shut-in WHP:1,850psi (WSR 6/19/2023) Min. ID:3.725” XN Nipple at 13,944’md Max. Deviation:65.5 degrees at 12,125’md H2S Concentration:0 PPM (4/13/2023) Well Integrity Information: Tbg: MIT-T failed, 0.5bpm at 2,500psi. IA: CMIT-TxIA passed 2,250psi, 6/22/2023. OA: MIT-OA passed 1,115psi, 1/29/2018. PPPOT-T: PPPOT-T passed 5,000psi, 6/16/2023. PPPOT-IC: PPPOT-IC passed 3,500psi, 1/17/2018. 3,267psi ( NK-15A : Tbg Swap PTD: 216-175 Page 2 of 7 Wellwork Procedure: Wellhead: 1. PPPOT-IC. Function all LDS. Eline/Fullbore: 2. Cut tubing at ~13,754’. 3. Circulate the well to 9.8ppg KWF + freeze protect. DHD: 4. Bleed WHPs to 0 psi. Valve Shop: 5. Set and test TWC. 6. ND production tree and THA. Inspect landing threads. 7. NU BOPs for over 3K MASP, top down: Annular, 2-7/8”x 5” VBRs, blinds and integral flow cross, 2-7/8”x 5” VBRs. RWO: 8. MIRU Thunderbird #1 Rig. 9. Test BOPE to 250psi Low/3,500psi High, annular to 250psi Low/3,000psi High (hold each ram/valve and test for 5-min). A. Record accumulator pre-charge pressures and chart tests. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5” VBRs and annular with a 4-1/2” test joint. E. If a workstring run is required during the operation, stop and test VBR’s and annular with a 2-7/8” test joint. F. Submit to AOGCC a completed 10-424 form within 5 days of BOPE test. 10. Pull TWC. RU a lubricator if pressure is suspected below the TWC. 11. MU landing joint or spear, BOLDS and pull hanger to the floor. Circulate bottoms up. PU weights are expected to be ~148k# in 9.8ppg brine. 12. Lay down 4-1/2”, L-80, VamTop tubing. 13. Run 4-1/2”, 13Cr, VamTop gas lifted completion. a. Due to Niakuk’s proximity to a navigable waterway, the completion will include a tubing retrievable surface controlled subsurface safety valve with hydraulic control line set at ~2,000’md. i. Permafrost depth estimated at 1,900’md from offset well log picks. ii. A set depth of 2,000’md is within the engineered fail safe setting depth of the TRSV. iii. TRSV is planned to be the same manufacturer and model installed in the most recent drill wells at Niakuk: NK-08B (set at 2,053’md), NK-14B (set at 2,013’md), and NK-26A (set at 2,007’ md). 14. Land hanger. 15. Set TWC. 16. RDMO Thunderbird #1. NK-15A : Tbg Swap PTD: 216-175 Page 3 of 7 Valve Shop/Fullbore: 17. ND BOPE. 18. NU THA and production tree. Test tree and tubing hanger void to 500psi low/5,000psi high. 19. Pull TWC. 20. Circulate the well to inhibited 8.5ppg seawater. 21. Drop ball and rod and set packer. 22. Perform MIT-T to 3,000psi and MIT-IA to 3,000psi for 30 charted minutes. 23. Shear valve in top GLM. 24. Freeze protect well with diesel to 2,500’tvd. Slickline: 25. Pull ball and rod. 26. Set kick off gas lift design. 27. Pull plug from 13,944’md. 28. Hand well over to DSO to POP. 29. Obtain AOGCC witnessed SVS test within 5 days of putting well online. NK-15A : Tbg Swap PTD: 216-175 Page 4 of 7 Current Wellbore Schematic: NK-15A : Tbg Swap PTD: 216-175 Page 5 of 7 Proposed Schematic: NK-15A : Tbg Swap PTD: 216-175 Page 6 of 7 BOP Schematic: NK-15A : Tbg Swap PTD: 216-175 Page 7 of 7 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:216-175 6.50-029-22745-01-00 PRUDHOE BAY, RAVEN 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 16752 14670 9991 13834 none none 9372 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 49 - 129 49 - 129 1530 520 Surface 7324 13-3/8" 48 - 7372 48 - 5075 5020 / 5380 2260 / 2670 Intermediate 7442 9-5/8" 45 - 7487 45 - 5107 6870 4760 Liner 6853 7" 7285 - 14138 5051 - 9617 7240 5410 Perforation Depth: Measured depth: 14164 - 16700 feet True vertical depth:9638 - 9814 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 44 - 13965 44 - 9478 13834 9372Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Perm Packer Liner 2785 4-1/2" 13965 - 16750 9477 - 9801 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0000 4219912 1327 0 1309 967 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: Kirsty Schultz Kirsten.Schultz@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-5258 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9800 Sundry Number or N/A if C.O. Exempt: 320-543 K-valve 1994 1993 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 034635 & 034630 RAVN NK-15A 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 convert to producer, install new K-valve design By Samantha Carlisle at 9:43 am, Jan 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: 2021.01.28 15:39:25 -09'00' Bo York RBDMS HEW 1/29/2021 SFD 2/1/2021DSR-2/1/21MGR19FEB2021 ACTIVITYDATE SUMMARY 1/15/2021 ***WELL S/I ON ARRIVAL*** (SSSV MAINTENANCE) MISU POLLARD #57 TO SET HES K-VALVE AT 1,994' MD. ***LDFN, WELL S/I & SECURED, CONTINUE ON 1/16/21 WSR*** 1/16/2021 ***CONTINUED FROM 1/15/21 WSR*** (SSSV MAINTENANCE) SET 4-1/2" HES K-VALVE (722 Dome psi @ 60* - s/n = K5OA) AT 1,952' SLM / 1,994' MD. RAN 4-1/2" CHECK SET TO X-LOCK AT 1,952' SLM (Tool sheared indicating good set). ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** Daily Report of Well Operations PBU NK-15A Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:216-175 6.50-029-22745-01-00 PRUDHOE BAY, RAVEN 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 16752 14670 9991 13834 none none 9372 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 49 - 129 49 - 129 1530 520 Surface 7324 13-3/8" 48 - 7372 48 - 5075 5020 / 5380 2260 / 2670 Intermediate 7442 9-5/8" 45 - 7487 45 - 5107 6870 4760 Liner 6853 7" 7285 - 14138 5051 - 9617 7240 5410 Perforation Depth: Measured depth: 14164 - 16700 feet True vertical depth:9638 - 9814 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 44 - 13965 44 - 9478 13834 9372Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Perm Packer Liner 2785 4-1/2" 13965 - 16750 9477 - 9801 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 73916812737118 223100 0 1727 1560 1000 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: Kirsty Schultz Kirsten.Schultz@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-5258 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9800 Sundry Number or N/A if C.O. Exempt: 320-381 no SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Set CIBP Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 034635 & 034630 RAVN NK-15A 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 Samantha Carlisle at 3:44 pm, Jan 05, 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: 2021.01.05 12:51:54 -09'00' Bo York Convert to producer HEW MGR17FEB2021 DSR-1/6/21 RBDMS HEW 1/13/2021 SFD 1/13/2021 ACTIVITYDATE SUMMARY 11/8/2020 T/I/O=1750/690/0 Assist Slickline (Load tbg) Pump 2 bbls 60/40, 250 bbls 1% slick kcl, 33 bbls crude. Slickline unable to POOH into lubricator. Pump 10 bbls 60/40 & 18 bbls 180* crude down tbg to thaw lubricator. Load lubricator with 1.25 bbls neat meth FWHPs=1500/700/0 11/8/2020 ***WELL S/I ON ARRIVAL***(perforating). DRIFT W/ 3.625" CENT, 3' 1-7/8", 3.70" CENT TO DEVIATION @ 14,680' SLM. DRIFT W/ 30' X 2-7/8" DMY GUNS TO 9,025' SLM (unable to pass). LRS PUMPED 240 BBLS SAFE LUBE, 40 BBLS CRUDE DOWN TBG. ***JOB CONTINUED ON 11/9/20 WSR*** 11/8/2020 ***WELL S/I ON ARRIVAL***(perforating). DRIFT W/ 3.625" CENT, 3' 1-7/8", 3.70" CENT TO DEVIATION @ 14,680' SLM. DRIFT W/ 30' X 2-7/8" DMY GUNS TO 9,025' SLM (unable to pass). LRS PUMPED 240 BBLS SAFE LUBE, 40 BBLS CRUDE DOWN TBG. ***JOB CONTINUED ON 11/9/20 WSR*** 11/9/2020 ***JOB CONTINUED FROM 11/8/20 WSR***(perforating). RAN 20' x 2-7/8" DMY GUNS TO 14,500' SLM (no issues, used roller stem). ***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE*** 11/9/2020 ***JOB CONTINUED FROM 11/8/20 WSR***(perforating). RAN 20' x 2-7/8" DMY GUNS TO 14,500' SLM (no issues, used roller stem). ***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE*** 11/11/2020 ***WELL S/I ON ARRIVAL*** (HES E-Line PLUG & PERFORATE) SET 4-1/2" NORTHERN SOLUTIONS CIBP AT 14,670' MD MID-ELEMENT. ***JOB CONTINUED ON 12-NOV-20202*** 11/12/2020 ***JOB CONTINUED FROM 11-NOV-2020*** (HES E-Line Plug & Perforate) PERFORATE 14,221' - 14,241' W/ 2 7/8" MAXFORCE, 6 SPF, 60 DEG PHASE GUN. PERFORATE 14,201' - 14,221' W/ 2-7/8" MAXFORCE, 6 SPF, 60 DEG PHASE GUN. ***JOB CONTINUED ON 13-NOV-2020*** 11/13/2020 ***JOB CONTINUED FROM 12-NOV-2020*** (HES E-Line Plug & Perforate) PERFORATE 14181' - 14201' W/ 2 7/8" MAXFORCE, 6 SPF, 60 DEG PHASE GUN. PERFORATE 14164' - 14181' W/ 2 7/8" MAXFORCE, 6 SPF, 60 DEG PHASE GUN. ***JOB COMPLETE, WELL S/I AND SECURED ON DEPARTURE, DSO NOTIFIED*** 11/18/2020 LRS Test Unit #6 ,High H2S Injector Flowback, IL Well NK-15 , OL Well NK-38 ***Begin WSR 11/18/20*** MIRU , PT , POP/Flow/Stabilize ***Job in Progress***Continue on WSR 11/19/20*** 11/19/2020 LRS Test Unit #6 ,High H2S Injector Flowback, IL Well NK-15 , OL Well NK-38 ***Continue from WSR 11/18/20*** Continue Flow / Open Choke, 8 Hour Test ***Job in Progress***Continue on WSR 11/20/20*** 11/20/2020 LRS Test Unit #6 ,High H2S Injector Flowback, IL Well NK-15 , OL Well NK-38 ***Continue from WSR 11/19/20*** Continue Flow, completed 8 hr test, started 8 Hour Piggy Back Test, ***Job in Progress***Continue on WSR 11/21/20*** 11/21/2020 LRS Test Unit #6 ,High H2S Injector Flowback, IL Well NK-15 , OL Well NK-38 ***Continue from WSR 11/20/20*** Continue Flow, 8 hr Well Test ***Job in Progress***Continue on WSR 11/22/20*** 11/21/2020 LRS Test Unit #6 ,High H2S Injector Flowback, IL Well NK-15 , OL Well NK-38 ***Continue from WSR 11/20/20*** Continue Flow, 8 hr Well Test ***Job in Progress***Continue on WSR 11/22/20*** Daily Report of Well Operations PBU NK-15A Daily Report of Well Operations PBU NK-15A 11/22/2020 LRS Test Unit #6 ,High H2S Injector Flowback, IL Well NK-15 , OL Well NK-38 ***Continue from WSR 11/21/20*** Continue Flow, 8 hr Well Test ***Job in Progress***Continue on WSR 11/23/20*** 11/23/2020 LRS Test Unit #6 ,High H2S Injector Flowback, IL Well NK-15 , OL Well NK-38 ***Continue from WSR 11/22/20*** Continue Flow, 8 hr Well Test,RDMO ***Job Complete***End WSR 11/23/20*** 12/13/2020 LRS Well Test Unit 6. Well Test/ Rate Verification. Begin WSR 12/13/20, Perform Unit Move, Begin Rig Up. Inlet Well NK-15, Outlet Well NK-38. Job in Progress, Continued on WSR 12/14/20 12/14/2020 LRS Well Test Unit 6. Well Test/ Rate Verification. Continue from WSR 12/13/20. Complete Rig Up, PT, Standby, Inlet Well NK-15, Outlet Well NK-38. Job in Progress, Continued on WSR 12/15/20 12/15/2020 LRS Well Test Unit 6. Well Test/ Rate Verification. Continue from WSR 12/14/20. POP / Stabilize Well, Bypass IL Choke. Inlet Well NK-15, Outlet Well NK-38. Job in Progress, Continued on WSR 12/16/20 12/16/2020 LRS Well Test Unit 6. Well Test/ Rate Verification. Continue from WSR 12/15/20. Continue flowback. Inlet Well NK-15, Outlet Well NK-38. Job in Progress, Continued on WSR 12/17/20 12/17/2020 LRS Well Test Unit 6. Well Test/ Rate Verification. Continue from WSR 12/16/20. Continue flowback. DSO diverted NK-15 into WPS and began purge. Inlet Well NK- 15, Outlet Well NK-38. Job in Progress, Continued on WSR 12/18/20 12/18/2020 LRS Well Test Unit 6. Well Test/ Rate Verification. Continue from WSR 12/16/20. Continue flowback. Begin 8 hr Piggyback well test. Inlet Well NK-15, Outlet Well NK- 38. Job in Progress, Continued on WSR 12/18/20 12/19/2020 LRS Well Test Unit 6. Well Test/ Rate Verification. Continue from WSR 12/18/20. Continue flowback. Begin 8 hr well test. Inlet Well NK-15, Outlet Well NK-38. Job in Progress, Continued on WSR 12/20/20 12/20/2020 LRS Well Test Unit 6. Well Test/ Rate Verification. Continue from WSR 12/19/20. Continue flowback. perform 8 hr well test. Inlet Well NK-15, Outlet Well NK-38. Job in Progress, Continued on WSR 12/21/20 12/21/2020 LRS Well Test Unit 6. Well Test/ Rate Verification. Continue from WSR 12/20/20. Continue flowback. perform 8 hr well test. Inlet Well NK-15, Outlet Well NK-38. Job in Progress, Continued on WSR 12/22/20 12/22/2020 LRS Well Test Unit 6. Well Test/ Rate Verification. Continue from WSR 12/21/20. Continue flowback. perform 8 hr well test. Inlet Well NK-15, Outlet Well NK-38. Job in Progress, Continued on WSR 12/23/20 12/23/2020 LRS Well Test Unit 6. Well Test/ Rate Verification. Continue from WSR 12/22/20. BD, RDMO, SB for Scheduling. 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Received by the AOGCC 12/04/2020 PTD: 2161750 E-Set: 34318 Abby Bell 12/04/2020 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:216-175 6.API Number:50-029-22745-01-00 PRUDHOE BAY, RAVEN OIL / PRUDHOE BAY, NIAKUK OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 034635 & 034630 Property Designation (Lease Number):10. CO 329 B/C 8. RAVN NK-15A 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 convert to producer Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 16752 Effective Depth MD: L-80 11. 10/1/2020 Commission Representative: 15. Suspended Contact Name: Kirsty Schultz Contact Email: Kirsten.Schultz.hilcorp.com Authorized Name: Authorized Title: Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9800 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool 13834, 9372 No SSSV Installed Date: Liner 2785 4-1/2" 13965 - 16750 9477 - 9801 8430 7500 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 48 - 7372 48 - 5075 14. Estimated Date for Commencing Operations: BOP Sketch 49 - 129 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" HES TNT Perm Packer 16060 - 16700 9968 - 9814 4-1/2" 12.6# L-80 44 - 13965 Liner 16702 9813 None None 49 - 129 520 13-3/8" 9-5/8" Contact Phone:(907)564 - 5258 Date: 9-16-20 4760 80 153020"Conductor 2260 / 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. APPLICATION FOR SUNDRY APPROVALS20 AAC 25.280 Surface 7324 5020 / 5380 Intermediate 7442 45 - 7487 45 - 5107 6853 7" 7285 - 14138 5051 - 9617 7240 5410 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 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Torin Roschinger Sr. Operations Engineer 320-381 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2020.09.17 14:39:44 -08'00'Torin Roschinger (4662) X X 24 hour observer during temporary piping flow back test without SSSV. Increase well monitoring (minimum of 4 times per day) during flow back after permanent piping is in place. X flow test DLB 09/18/2020 DSR-9/18/2020 DLB 3700 10-404 MGR02OCT20 Performance test of safety valves. 24 hour notice. Yption Required? Comm 10/5/2020 dts 10/05/2020 JLC 10/5/2020 RBDMS HEW 10/28/2020 NK-15 Convert to Producer Integrity Engineer:Aras Worthington (907) 440-7692 Ops Engineer:Kirsty Schultz (907) 564-5258 Ops Manager: Bo York (907) 777-8345 Expected Start Date:August 31, 2020 History Drilled and completed in 1997 and then rotary sidetracked in 2018 as an injector in the Raven field. The well was back-flowed in December of 2019 but never put on injection. Objective Isolate existing perforations, shoot Sag perforations, and flow the well back to determine if it will make a competitive producer. Procedural steps Slickline or Eline 1. Set a CIBP or CBP @ ~14,450’ MD (or deeper if achievable) to isolate existing perforations. 2. Shoot perforations in the Sag from 14,167’ – 14,197’ MD and 14,205’ – 14,244’ MD. Wells Support 1. RU Temporary Flowback iron to an adjacent well. 2. Flowback the well for no more than 14 days without a SSSV (K-valve) to obtain representative well tests. 3. If the well tests prove the well is competitive then tie-in the well permanently as a Producer. 4. Flowback the well again for no more than 14 days without a K-valve to get representative well tests and flowing pressures down the well’s flowline in order to properly design K-valve. 5. Install K-valve and flow the well as a Producer. * If second flow back without a K valve is required: Submit a new 10-403 with a complete description of tagging, monitoring, witnessed performance testing, accurate schematics, and MPSP described. *Pressure test piping to MPSP. Performance test of safety valves. 24 hour notice to AOGCC for performance test witnessing. Pressure test flow back piping to minimum of MPSP. Performance test safey valves. AOGCC to witness. 3. MIT-IA (or set plug, CMIT TxIA, pull plug). Prior to flowing, well to be tagged per 20 AAC 25.265(m). 2 Bridge Plug with 25’ of cement between 8050’ and 8500’ MDSuperceded I CIBP @ ~14450’ MD or deeperSuperceded NK-15ANK-12CNK-15ANK-12CSuperceded CIBP @ ~14450’ MD or deeperPerforations 14,167-14197, 14205-14244 NK-15ANK-12CNK-15ANK-12C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED ncr, 1 e nn.n 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑Ope ❑ Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing ❑ Ch tl m gi Ap' r 0Qd TFO d ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Explo2tory ❑ 5. Permit to Drill Number 216-175 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service Q 6' API Number: 50-029-22745-01-00 7 Property Designation (Lease Number): ADL 034630 8 034635 B. Well Name and Number: PBU NK -15A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, RAVEN OIL 11. Present Well Condition Summary: Total Depth: measured 16752 feet Plugs measured None feet true vertical 9800 feet Junk measured None feet Effective Depth: measured 16702 feet Packer measured 13834 feet true vertical 9813 feet Packer true vertical 9372 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 49-129 49-129 1530 520 Surface 7324 13-3/8" 48-7372 48-5075 5020 / 5380 2260/2670 Intermediate 7442 9-5/8' 45-7487 45-5107 6870 4760 Liner 6853 7" 7285-14138 5051 -9617 7240 5410 Liner 2785 4-1/2" 13965 - 16750 9477 - 9801 8430 7500 Perforation Depth: Measured depth: 16060 - 16700 feet True vertical depth: 9968-9814 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 44-13965 44-9477 Packers and SSSV (type, measured and 4-1/2" HES TNT Perm Packer 13834 9372 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut In 649 0 Subsequent to operation: Shut In 2298 0 14. Attachments: (.gUireaper2ownc2s.m02ao7t a25.263) 15. Well Class after work: Daily Report of Wei( Operations Q Exploratory ❑ Development ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ Q WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Sauve, Mark A Contact Name: Sauve, Mark A Authorized Title: GPMA/Lisburne Lead PE Contact Email: Mark.Sauve@bp.com Authorized Signature: Date: (Z—(7_/7 Contact Phone: +1 907 564 4660 Form 10-404 Revised 04/2017 Submit Original Only �-.onMC�''J OEC 17 2019 Daily Report of Well Operations PBU NK -15A ACTIVITYnATF e I Innnn n ov ***WELL S/I ON ARRIVAL*** (Perforating) DRIFT TO DEVIATION AT 14,816' SLM W/ 3.70" CENT, S-BLR (No sample or issues). SET 4-1/2" WHIDDON C -SUB ON 4-1/2" XN-NIPPLE AT 13,916' SLM 113,944' MD. PULL BK-DGLV'S FROM ST #3 (4,692' MD) & FROM ST #2 (9,602' MD). SET BK-LGLV AT ST #3 (4,692' MD) & BK-OGLV AT ST #2 (9,602' MD). PULL EMPTY 4-1/2" WHIDDON CATCHER SUB FROM 13,944' MD. 2/17/2019 ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** CTU#9 1.75" CT. Job Scope: Mill Obstruction / Mill Shoe Track / Adperf MIRU CTU. Perform Weekly BOP Test. MU & RIH with Baker 2-7/8" Milling BHA w/ 3.70" 5 -Bladed Junk Mill &3.70" Carbide String Reamer. Take pipe displacement returns while rih. DryTag obstruction at 16350'. 11/24/2019 ***Continue Job on 11/25/19 WSR*** CTU#9 1.75" CT. Job Scope: Mill Obstruction / Mill Shoe Track / Adperf Mill Obstruction at 16350'. Mill thru w/ no issues. Tag again at 16373'. Mill thru w/ no issues. Likely cement stringers. Continue milling to PBTD. Tag PBTD at 16639'. Pump 10 bbl gel pill & chase ooh. Make up HES 2-7/8" Logging Carrier w/ 3.63" JSN. Tag PBTD at 16651'. Log from compression up to 11275'. Flagged pipe at 16550'. Pooh. Receive good data ( + 8 ' Correction ). Correlated to Baker Hughes MWD GR/Res Mar -2-2018. Corrected EOP at Flag= 16545.53'. Corrected PBTD = 16656.14'. MU & RIH w/ Baker 2-7/8" Milling BHA w/ 3.70" Diamond Speed Mill w/ Tempress. 11/25/2019 ***In Progress*** CTU#9 1.75" CT. Job Scope: Mill Obstruction / Mill Shoe Track / Adperf Continue Rih w/ Milling BHA. Tag PBTD 16648' down / 16639' up. Correct Bottom of Mill to Corrected PBTD Depth of 16656.14'. Begin Milling Liner Wiper Plug. First motor work seen at 16661.5'. Mill through LWP and down to float collar. Tag new PBTD at 16701.6'. PUH and paint flag at 16625' corrected to Mill face. POOH. Change packoffs. MU & RIH w/ Sib 2-7/8" x 31' PJ Omega Perf Gun #1. Tag PBTD & Correct Depth. Puh & Perforate Interval 16669'- 16700'. Pooh. *** New PBTD = 16701.6' *** 11/26/2019 ***In Pro ress*** CTU#9 1.75" CT. Job Scope: Mill Obstruction / Mill Shoe Track / Adperf Continue Pooh w/ Pef Gun #1. All shots fired, ball recovered. MU & RIH w/ Sib 2-7/8" x 31' PJ Omega Perf Gun #2. Tie into PBTD and shoot 16640-16671'. POOH and FP well. All shots fired, ball recovered. RDMO CTU. 11/27/2019 ***Job Com lete*** TREE= 6" CNV WELLHEAD = FMC GEN. 5 ACTUATOR= BAKER OKB. ELEV = 59.9 BF. ELEV = 22.35' KOP = 2500' Max Angle = 105° @ 16249' Datum MD= 13705' Datum TVD = 9200' SS Minimum ID = 3.725" @ 13944' 4-1/2" XN NIPPLE TOP OF 7" LNR 72 WHIPSTOCK (02/10/18) 7487- t, L-80 BTC, ID = 8.681" -7487' 7" TOC I-1 -11437' JT, .0152 bpf, D = 3.958" --L_13965- 7- -13965'7" LNR, 26#, L-80 VT HC, 14138' 0383 bpf, D = 6.276" SHOE TRACK 52 bpf, D = 3.958" K -15A PERFORATION SUMMARY SAFETYNOTES: WELL REQUIRES A SSSV. j HORIZONTAL WELL. WELL ANGLE> 70" @ 75801. DATE REF LOG: BKR MWD ON 03/02/18 0424197 ANGLE AT TOP PERF: 99" @ 16060' 07/17/18 Note: Refer to Production OB for Instorical erfdata SIZE SPF INTERVAL O NS z I DATE 2.88" 6 16060 -16090 O 10/13/18 2-3/4" 6 16090 -16110 O 03/15/18 2.3/4" 6 16110 -16170 O 10/13/18 23/4" 6 16200 -16220 O 03/15/18 2-7/8" 6 16640 -16671 O 11/27/19 2-7/8" 6 16669 -16700 O 11/26/19 SHOE TRACK 52 bpf, D = 3.958" K -15A REV BY SAFETYNOTES: WELL REQUIRES A SSSV. j HORIZONTAL WELL. WELL ANGLE> 70" @ 75801. DATE MAXDLS:19.1°@7502'. 0424197 ORIG COMPLETION, (POOL 7) 07/17/18 1789' 13-3/8" HES CEMENTER 03107118 P-272 ST NK -15A) 08/14/18 1994' 4-1 /2" HES X NIP, ID = 3.813" 03/08/18 JMD DRLG HO CORRECTIONS 11/06/18 GAS LFT MANDRELS - 03/12/18 BG/JMD ODE APPROVAL 02/18/19 ---E - TYPE-- — -. . ST MD ND SDEV VLV LATCH R7RT_. DATE 0321/18 OG/JMD GLV C/003/12/18 12/11/19 __ 3 4692 4259 60 KBG-2 DOME --BK -- - 16 02/17/19 0321/18 JCF/JMD PERFS & OBSTRUCTION 2 9602 6064 49 KBG-2 SO BK 22 02/17/19 1 11466 7490 38 KBG-2 DMY BK 0 03/06/18' & WFT WPHR HGR, D = 6.19" MILLOUT WINDOW (NK -16A) 7487'- 7501' 14-112" HES X NP, ID = 3.813" 1 17" X 4-1/2" HES TNT PKR, ID = 3.856" ------------- 4-1/2" HES X NIP. ID = 3.813" 13944' —14-1/2" HES XN NP. ID = 3.725" 13965-)4-1/2"WLEG,m=3.958"� 13965' 7"X 5" WFT LTPw/TEBK SLV & WFT HGR D=4.29" 13985'5" X 4-1/2" XO, D = 3.92" DATE REV BY COMMENTS DATE REV BY COMMENTS 0424197 ORIG COMPLETION, (POOL 7) 07/17/18 GJB/JMD GLV C/O (07114118) 03107118 P-272 ST NK -15A) 08/14/18 GJB/JMD GLV C/O (08/12/18) 03/08/18 JMD DRLG HO CORRECTIONS 11/06/18 JTC/JMD OBSTRUCTION TAG &ADPERFS 03/12/18 BG/JMD ODE APPROVAL 02/18/19 GJB/JMD GLV C/O (02117/19) 0321/18 OG/JMD GLV C/003/12/18 12/11/19 JCF/JMD MILLED SHOETRACK & ADPERFS 0321/18 JCF/JMD PERFS & OBSTRUCTION NIAKUK UNIT WELL: NK -15A PERMIT No: 216-175 API No: 50-029-22745-01 , T12N, R15E, 1373' FSL & 91 E BP Exploration (Alaska)