The URL can be used to link to this page

Home My WebLink About218-1577. 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 E-100A Reservoir Abandonment, Permanently Pull LTP Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 218-157 50-029-22819-01-00 ADL 0028299, 0028304 15540 Conductor Surface Intermediate Liner Liner 9170 80 4398 12867 1136 3960 11620 20" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 8015 43 - 123 43 - 4441 40 - 12906 11852 - 12988 11580 - 15540 2450 43 - 123 43 - 3690 40 - 9072 8176 - 9148 7989 - 9170 None 470 4760 7020 7500 10530 11620, 15317 1490 6870 8160 8430 10160 14986 - 15486 4-1/2" 12.6# L-80 38 - 116469297 - 9183 Structural 4-1/2" Baker SB-3 Packer No SSSV Installed 11620, 8015 Date: Torin Roschinger Operations Manager Ben Walters benjamin.walters@hilcorp.com 907-564-4899 PRUDHOE BAY 2/6/2026 Current Pools: PRUDHOE OIL / SAMBUCA Undefined Oil Proposed Pools: PRUDHOE OIL / SAMBUCA Undefined 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 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2026.01.20 10:36:20 - 09'00' Torin Roschinger (4662) 326-040 By Grace Christianson at 7:41 am, Jan 21, 2026 10-407 AOGCC witnessed tag and MITT of 1st cement plug. AOGCC witnessed tag and CMIT-TxIA of 2nd cement plug. XX January 31, 2031 DSR-1/22/26A.Dewhurst 22JAN26 2:29 pm, Feb 02, 2026 IA CBL if CMIT Fails. J.Lau 2/4/26 If the CMIT-TxIA fails post cement abandonment plug the suspension is not approved. In that case a sundry to address the failed CMIT-TxIA shall be submitted before 6/1/26 and wok performed by 12/31/26. JLC 2/9/2026 02/09/26 Page 1 of 5 Well: E-100A Reservoir Abandon PTD: 218-157 Well Name: E-100A API Number: 50-029-22819-01 Current Status: Offline, Not Operable Pad: E Pad Reg. Approval Reqd? 10-403, 10-404 AFE Number: Regulatory Contact: Abbie Barker Job Type: Reservoir Abandon First Call Engineer: Ben Walters Phone: (907) 564-4899 Second Call Engineer: Leif Knatterud Phone: (907) 564-4667 Current Bottom Hole Pressure: 3250 psi (Estimated based on average Ivishak BHP) MPSP: 2450 psi (Estimated from BHP- 0.1 psi/ft gas gradient+ safety factor) Max Dev:108 deg @ 15,232 MD Min ID: 2.31 @ 11,582 MD X nipple in LTP Tie In Log: PDCL Log Aug 07, 2019 Revision 1 in red Background: Well E-100A is a U-shaped coil sidetrack drilled in the Prudhoe Oil Pool in May 2019, initially perforated across 32 feet in Zone 4 of the Ivishak formation with an additional 62 feet of Sag River formation perforated in 2020. Despite extensive troubleshooting, no definitive leak point has been identified in the tubing, production casing, or packer assembly, and given the well's limited production value (6,500 BFPD at 97% water cut), absence of permanent gas lift infrastructure, and ongoing integrity issues, the decision has been made to abandon the current bottom-hole location and suspend the well while retaining it as a future rig sidetrack candidate. The formations penetrated are neither abnormally geopressured nor depleted and following completion of reservoir abandonment operations and pressure testing to confirm mechanical integrity, the well will not permit fluid migration, damage productive formations, impair hydrocarbon recovery, or pose any threat to public health or the environment. Ongoing integrity issues started in 2022, slickline changed out GLVs and the well failed a TIFL. We ran a caliper and had tubing penetrations of 40 to 74%. We set a WRP right above the LTP and failed a CMIT. In 2023 SL changed out GLV dummy and ran an LDL on e-line pumping down IA w/ LLR of 0.9 BPM @ 1080psi. Later in 2023, E-line set IBP @13,217 and ran another LDL with spinner responses around the LTP with stop counts showing IBP was holding. In 2024, e-line set IBP at 11,620 and CMIT failed. Confining zones: HRZ 11,494-11,662 MD Kingak 12,067-12,943 MD Objective: Reservoir abandon and suspend well in accordance with 20 AAC 25.110 & 20 AAC 25.112. Procedure: SL 1. Drift & Tag IBP @ 11,620 2. Pull LTP @ 11,570 3. Pull IBP @ 11,620 Page 2 of 5 Well: E-100A Reservoir Abandon PTD: 218-157 Coil 4. MIRU 5. Drift to gauge carrier @ 15,317 & pull gauges. - FISH @ 13,348 3 rubber elements from WRP left 09/15/23, WSL leader discretion to attempt to retrieve FISH prior to pulling gauges. - Take note & record CTM when entering liner & XO, this will assist in depth control confirmation for the retainer 6. RIH w/ 1 Trip NS cement retainer down to 12,840 CTM, load wellbore CTxTbg with diesel. Once retainer sets, pump with either diesel or 60/40 to confirm injectivity. Currently we do not have historical injectivity from Sag & Ivishak perfs. - Injectivity of interval 14,986 15,018 during SIT 6/24/19 ~ 1BPM @ 1650 psi. (prior to Sag being perforated) - If injectivity is lower than 0.7 BPM contact OE to discuss. 7. Batch mix 30 bbls of cement Contact OE to discuss cement selection prior to the job. 8. After cement passes QC, Swap to hot KCl/SW down the coiled tubing until over the gooseneck and pump 21 bbls cement down the CT - If coil pressure indicates cement is squeezing off early, unsting and lay in cement 1:1 while POOH. 9. Un-sting and lay in 8 bbls of cement 1:1 while POOH. Target TOC = 11,800, contaminate down to 11,800 if needed with powervis & 1% KCl for coil displacement. 10. PUH to safety & let cement cure to 500 psi compressive strength a. Ensure backside has sufficient FP and diesel has not been displaced completely OOH if cleanout operations were necessary in Step #9. 11. RIH & tag TOC, record depth in WSR. 12. FP tubing to 2500 ft while POOH (38 bbls). Eline 13. Rig up & punch 11,612 - 11,617 w/ tubing punches through 3-1/2 & 4-1/2 3 ft above 7 x 4-1/2 Baker SB-3 pkr @ 11,620. a. Shoot AK e-line 2 RTG-2106-430 Coil 14. MIRU CTU & circulate tbg-IA with diesel through tubing punches at 11,612 - 11,617 15. RIH & tag TOC from previous work at approximately 11,800 a. AOGCC witnessed TOC tag. 16. Batch mix 50 bbls of 15.8 ppg cement. 17. After cement passes QC, PU 5 and lay in cement below packer at 11,620 MD till wellbore is no longer taking. - 3-1/4 liner volume, 0.0079 bpf * 180 ft = 1.5 bbls 18. lay in cement 1:1 (tubing & IA volume) while POOH up to target TOC of 11,300 in tubing and target IA TOC of 10,800. Contaminate down to 11,300 if needed with powervis & 1% KCl for coil displacement. - 7 x 4-1/2 liner annulus, 0.0175 bpf * 820 ft = 15 bbls - 4-1/2 liner volume, 0.0152 bpf * 320 ft = 8bbls SL 19. MIRU SL to drift and tag TOC a. AOGCC witnessed TOC tag. 20. Run CBL across cement to confirm IA top send results to AOGCC. FB 21. AOGCC witnessed CMIT-TxI to target pressure of 2500 psi (max pressure 2750 psi) Page 3 of 5 Well: E-100A Reservoir Abandon PTD: 218-157 Current Wellbore Schematic: Page 4 of 5 Well: E-100A Reservoir Abandon PTD: 218-157 Proposed Wellbore Schematic: Page 5 of 5 Well: E-100A Reservoir Abandon PTD: 218-157 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 Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Page 1 of 5 Well:E-100A Reservoir Abandon,Well Suspension PTD:218-157 Well Name:E-100A API Number:50-029-22819-01 Current Status:Offline, Not Operable Pad:E Pad Reg.Approval Reqd?10-403, 10-404 Regulatory Contact:Abbie Barker Job Type:Reservoir Abandon First Call Engineer:Ben Walters Phone:(907) 564-4899 Second Call Engineer:Leif Knatterud Phone:(907) 564-4667 Current Bottom Hole Pressure:3250 psi (Estimated based on average Ivishak BHP) MPSP:2450 psi (Estimated from BHP- 0.1 psi/ft gas gradient+ safety factor) Max Dev:108 deg @ 15,232 MD Min ID:2.31 @ 11,582 MD X nipple in LTP Tie In Log:PDCL Log Aug 07, 2019 Background: Well E-100A is a U-shaped coil sidetrack drilled in the Prudhoe Oil Pool in May 2019, initially perforated across 32 feet in Zone 4 of the Ivishak formation with an additional 62 feet of Sag River formation perforated in 2020. Despite extensive troubleshooting, no definitive leak point has been identified in the tubing, production casing, or packer assembly, and given the well's limited production value (6,500 BFPD at 97% water cut), absence of permanent gas lift infrastructure, and ongoing integrity issues, the decision has been made to abandon the current bottom-hole location and suspend the well while retaining it as a future rig sidetrack candidate. The formations penetrated are neither abnormally geopressured nor depleted and following completion of reservoir abandonment operations and pressure testing to confirm mechanical integrity, the well will not permit fluid migration, damage productive formations, impair hydrocarbon recovery, or pose any threat to public health or the environment. Confining zones: HRZ 11,494-11,662 MD Kingak 12,067-12,943 MD Objective: Reservoir abandon and suspend well in accordance with 20 AAC 25.110 & 20 AAC 25.112. Procedure: SL 1. Drift & Tag IBP @ 11,620 2. Pull LTP @ 11,570 3. Pull IBP @ 11,620 Coil 4. MIRU 5. Drift to gauge carrier @ 15,317 & pull gauges. - FISH @ 13,348 3 rubber elements from WRP left 09/15/23, WSL leader discretion to attempt to retrieve FISH prior to pulling gauges. - Take note & record CTM when entering liner & XO, this will assist in depth control confirmation for the retainer 6. RIH w/ 1 Trip NS cement retainer down to 12,840 CTM, load wellbore CTxTbg with diesel. ongoing integrity issues Page 2 of 5 Well: E-100A Reservoir Abandon, Well Suspension PTD: 218-157 Once retainer sets, pump with either diesel or 60/40 to confirm injectivity. Currently we do not have historical injectivity from Sag & Ivishak perfs. - Injectivity of interval 14,986 15,018 during SIT 6/24/19 ~ 1BPM @ 1650 psi. (prior to Sag being perforated) - If injectivity is lower than 0.7 BPM contact OE to discuss. 7. Batch mix 30 bbls of cement Contact OE to discuss cement selection prior to the job. 8. After cement passes QC, Swap to hot KCl/SW down the coiled tubing until over the gooseneck and pump 21 bbls cement down the CT - If coil pressure indicates cement is squeezing off early, unsting and lay in cement 1:1 while POOH. 9. Un-sting and lay in 8 bbls of cement 1:1 while POOH. Target TOC = 11,800, contaminate down to 11,800 if needed with powervis & 1% KCl for coil displacement. 10. PUH to safety & let cement cure to 500 psi compressive strength a. Ensure backside has sufficient FP and diesel has not been displaced completely OOH if cleanout operations were necessary in Step #9. 11. RIH & tag TOC, record depth in WSR. 12. FP tubing to 2500 psi while POOH (38 bbls) Eline 13. Rig up & punch 11,612 - 11,617 w/ tubing punches through 3-1/2 & 4-1/2 3 ft above 7 x 4-1/2 Baker SB-3 pkr @ 11,620. a. Shoot AK e-line 2 RTG-2106-430 Coil 14. MIRU CTU & circulate tbg-IA with diesel through tubing punches at 11,612 - 11,617 15. RIH & tag TOC from previous work at approximately 11,800 a. AOGCC witnessed TOC tag. 16. Batch mix 50 bbls of 15.8 ppg cement. 17. After cement passes QC, PU 5 and lay in cement below packer at 11,620 MD till wellbore is no longer taking. - 3-1/4 liner volume, 0.0079 bpf * 180 ft = 1.5 bbls 18. lay in cement 1:1 (tubing & IA volume) while POOH up to target TOC of 11,120 in tubing. Contaminate down to 11,120 if needed with powervis & 1% KCl for coil displacement. - 7 x 4-1/2 liner annulus, 0.0175 bpf * 500 ft = 9 bbls - 4-1/2 liner volume, 0.0152 bpf * 500 ft = 8bbls SL 19. MIRU SL to drift and tag TOC a. AOGCC witnessed TOC tag. FB 20. AOGCC witnessed CMIT-TxI to target pressure of 2500 psi (max pressure 2750 psi) Page 3 of 5 Well: E-100A Reservoir Abandon, Well Suspension PTD: 218-157 Current Wellbore Schematic: Hilcorp Alaska, LLC Page 4 of 5 Well: E-100A Reservoir Abandon, Well Suspension PTD: 218-157 Proposed Wellbore Schematic: Hilcorp Alaska, LLC Page 5 of 5 Well: E-100A Reservoir Abandon, Well Suspension PTD: 218-157 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 Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 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 E-100A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 218-157 50-029-22819-01-00 15540 Conductor Surface Intermediate Liner Liner 9170 80 4398 12867 1136 3960 11568 20" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 7981 43 - 123 43 - 4441 40 - 12906 11852 - 12988 11580 - 15540 43 - 123 43 - 3690 40 - 9072 8176 - 9148 7989 - 9170 None 470 4760 7020 7500 10530 11568, 15317 1490 6870 8160 8430 10160 14986 - 15486 4-1/2" 12.6# L-80 38 - 11646 9297 - 9183 Structural 4-1/2" Baker SB-3 Packer 11620, 8015 11620 8015 Torin Roschinger Area Operations Manager Kirsty Glasheen Kirsty.Glasheen@hilcorp.com 907.564.5258 PRUDHOE BAY, PRUDHOE OIL / SAMBUCA UNDEFINED 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 0028299, 0028304 38 - 8033 N/A N/A 223 Well Not Online 9276 6280 1700 900 347 736 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:38 am, May 12, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.05.11 19:22:50 -08'00' Torin Roschinger (4662) RBDMS JSB 051623 DSR-5/12/23WCB 1-8-2024 ACTIVITY DATE SUMMARY 7/29/2022 CTU #9 1.75"CT Job Objective: Set WRP with gages to monitor sag river pressure build up MIRU. Make up and RIH with 2.2" memory GR/CCL BHA and 2.29" JSN. Run into lock up at 15029. PUH out of liner and bullhead well with 200 BBL's of KCL w/ safelube. RBIH and drift cleanly to TD at 15487'. Log up and paint a "yellow/blue" flag at 15100.1' E / 15494' M / 15100.13' HES. Log up to 14,200' and then POOH. ***Job in Progress*** 7/30/2022 CTU #9 1.75" CT Job Objective: Set WRP with gauges to monitor sag river pressure build up Confirm good data (+28' correction). MU 2.25" NSAK WRP w/ SBHP gauges and RIH. Set the plug/gauges at 15,317'. POOH. FP well with diesel and relay status to DSO. IA is likely fluid packed. OOH with setting tool, ball recovered. RDMO. ***Job Complete*** 8/21/2022 T/I/O = 330/1360/40. Temp = 125°. TIFL FAILED (eval TxIA). PBGL RU from E-10 @ 920 psi, SI @ CV. IA FL inconclusive (unable to see past sta # 5 dome). Stacked WHPs to 1940/2100/50. Bled IAP to 1300 psi in 2 hrs. TP increased 370 psi, IA FL inflowed to surface. No monitor. Ops POP well upon departure. Final WHPs = 2310/1300/20. SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:30 8/22/2022 T/I/O = 370/1560/40. Temp = 128°. IA FL (eval TxIA). PBGL RU from E-10, SI @ CV. IA FL @ 11543' (sta #1, SO). SV = C. WV, SSV, MV = O. IA, OA = OTG. 13:00. 8/27/2022 ***WELL FLOWING ON ARRIVAL***(gas-lift) SET WHIDDON CATCHER ON LTP @11,570' MD MAKE MULTIPL ATTEMPTS TO PULL STA #1 @11,543' MD BRUSHED TBG W/ 4-1/2" BRUSH & 3.75" G-RING, FOCUSING ON STA.# 1 @ 11,543' MD MAKE ONE MORE ATTEMPT TO PULL STA.# 1 @ 11,543' MD (unsuccessful) ***CONTINUE ON 8-28-22 WSR*** 8/28/2022 ***CONTINUE ON FROM 8-27-22 WSR***(gas-lift) PULLED 4-1/2" WHIDDON CATCHER SUB FROM LTP @ 11,570' SLM SET 4-1/2" BAIT SUB ON LTP @ 11,577' SLM MAKE 2 ATTEMPTS TO LIB STA #1 PULL 4-1/2" BAIT SUB FROM LTP @11,578' SLM BRUSH & FLUSH TBG W/ LRS PUMPING 170 bbls DOWN TBG RE-SET 4-1/2" BAIT SUB ON LTP @ 11,578' SLM ***CONTINUE ON 8-29-22 WSR**** 8/28/2022 T/I/O = 2500/2500/12 (GAS LIFT-INTEGRITY) Assist PSL, Pumped 175 bbls 180*F crude down TBG to knock pressure down and brush/flush, SL in control upon LRS Departure. Daily Report of Well Operations PBU E-100A Daily Report of Well Operations PBU E-100A 8/29/2022 ***CONTINUE ON FROM 8-28-22 WSR*** PULLED STA. # 1 INT-OGLV FROM 11,543' MD ( btm of valve flow cut, check is scaled in, light flow cutting on ports, scale on body of valve) SET STA. # 1 INT-OGLV @ 11,543' MD PULL CATCHER FROM LTP @11,578' SLM ( 4 pieces of pkg in catcher, 2.62" roller wheel missing from roller stem) RAN KJ, BLB, 3.50" (M7) MAGNET TO SWEEP MANDRELS DOWN TO LTP RAN KJ, 3.74" CENT, 3' x 2-1/8", 3.75" CENT, XO ,2' x 1-1/2", 2.5" MAGNET. DRIFT INTO LTP, SD @11,583' SLM ( recovered roller wheel ) RESET 4-1/2" BAITSUB ON LTP @11,581' SLM PULLED STA. # 1 INT-OGLV FROM 11,543' MD ***CONTINUE ON 8-30-22 WSR*** 8/30/2022 ***CONTINUE ON FROM 8-29-22 WSR*** SET INT-OGLV FROM STA.#1 @ 11,543' MD. ATTEMPT IA DRAWDOWN, TBG TRACKS PULL INT-OGLV FROM STA.#1 @ 11,543' MD SET INT-OGLV (freudenberg pkg) @11,543' MD PULL CATCHER FROM LTP @11,570' MD ***WELL S/I ON DEPARTURE*** 9/1/2022 T/I/O = 380/1620/0+. Temp = 123°. TIFL FAILED (eval TxIA). Temporary AL SI @ CV. IA FL @ 11250' (293' above sta # 1 SO). Stacked well out to 1790/2030/0+ in 30 min. IA FL unchanged. Bled IAP to production to 960 psi in 1 hr 30 min. TP increased 210 psi, IA FL inflowed to surface. Well released to Ops for POP. Final WHPs = 2000/960/VAC. SV = C. WV, SSV, MV = O. IA, OA = OTG. 02:00 9/2/2022 ***WELL FLOWING ON ARRIVAL*** SET 4-1/2" BAIT SUB ON LTP @ 11,577' SLM (oal-18") ***CONTINUE ON 9-3-22 WSR*** 9/2/2022 T/I/O= 1900/1950/0 Temp= SI TFS unit #4 Assist SL (Gas lift Integrity) Road to location, Spot Equipment. ***Job Continued on 09/03/2022*** 9/3/2022 ***CONTINUE ON FROM 9-2-22 WSR*** PULLED STA.# 1 INT-OGLV FROM 11,543' MD RAN KJ, 4-1/2" OK-1, GA-2 , INT-DGLV, ATTEMPT TO SET IN STA #1, BROUGHT VALVE BACK RAN KJ, 4-1/2" OK-1, GA-2 INT-DGLV, SET VALVE IN STA #1 @11,543' MD (not good set) RAN KJ, 4-1/2" OK-1, 7" EXT, 1.25" LIB TO STA #1, GOT PICTURE OF OPEN POCKET RAN KJ, 3' x 1-3/4", 2.5" SAMPLE BLR W/ FLPR BTM TO CATCHER ON LTP. SD @11,581' SLM. OOH W/ NO VALVE RAN KJ, 2.62" CENT, 2.60" BELLGUIDE, 1-1/4" JD (unsuccessful pulling vlv from catcher) MAKE ONE MORE ATTEMPT TO PULL INT-DGLV FROM CATCHER SUB @ 11,581' SLM (unsuccessful) ***CONTINUE ON 9-4-22 WSR*** 9/3/2022 ***Job Continued from 09/02/2022*** Assist SL (Gas lift Integrity) Loaded IA with 2 bbls 50/50 followed by 245 bbls crude. ***Job Continued on 09/04/2022*** Daily Report of Well Operations PBU E-100A 9/4/2022 ***CONTINUE ON FROM 9-3-22 WSR*** RAN 1-1/4" KJ, KJ, 1-3/8" GUTTED JD W/ 1.80" MULE SHOE SCOOP SKIRT IN HOPES TO GRAB INT-DGLV FROM CATCHER @ 11,581' SLM(unsuccessful) GET IMPRESSION OF OPEN POCKET @ 11,543' MD STA.# 1 RAN 4-1/2" GR, SD & LATCH CATCHER ON LTP @ 11,577' SLM, OOH W/ EMPTY CATCHER RAN 4-1/2" GS, & SET KEYLESS X-CATCHER (xc-41, =36" oal) ON LTP @11,570' MD RAN KJ, BLB, KJ, BLB, 3.75" GAUGE RING, SWEEP ALL MANDRELS SEVERAL TIMES DOWN TO CATCHER. LIGHTLY TAG CATCHER @11,574' SLM RAN 4-1/2" GR TO LATCH CATCHER FROM LTP. SD & LATCH UP @11,571' SLM (11,570' MD). CATCHER EMPTY SET 4-1/2" KEYLESS X-CATCHER ON LTP @ 11,577' SLM (xc-41) RAN 1.25" LIB TO STA. # 4 @ 6,751' MD, SMALL MARK ON EDGE OF LIB ***CONTINUE ON 9-5-22 WSR*** 9/4/2022 ***Job continued from 09/03/2022*** TFS unit # 4 Assist Slickline (Gas lift Integrity) Standby for Slickline to fish valve ***Job continued on 09/05/2022*** 9/5/2022 ***Job continued from 09/04/2022*** TFS unit #4 Assist Slickline (Gas litf Integrity) No fluids pumped. SL in control of well upon departure. 9/5/2022 ***CONTINUE ON FROM 9-4-22 WSR*** RAN SWIVEL DE-CENT, CLOCK(6:30), MODIFIED OK-1 ARM, 2.25" MODIFIED BLR TO STA.# 4 & 3 @ 6,751' & 8,441' MD PULLED EMPTY 4-1/2" KEYLESS X-CATCHER FROM LTP @ 11,577' SLM SET 4-1/2" KEYLESS X-CATCHER ON LTP @ 11,575' SLM RAN SWIVEL DE-CENT, CLOCK (7:30), MODIFIED OK-1 ARM, 2.25" MODIFIED BLR TO STA.# 4 & 3 @ 6,751' & 8,441' MD RAN KJ, BLB, KJ, BLB, KJ, KJ, 1.86" GAUGE RING, MAKE SEVERAL PASSES THRU EACH MANDREL, NEVER SD, LIGHTLY TAG CATCHER. RAN 3.70" CENT, 3' x 1-3/4", 3.75" CENT, 2' x 1-1/2", 2.25" LIB, SD LIGHTLY @10,818' SLM, 11,135' SLM, SD ON CATCHER @11,574' SLM, & 11,576' SLM RAN 1.25" LIB TO STA.# 4 & 3 @ 6,751, 8,441' MD (no significant mark on lib) RAN KJ, 4-1/2" OK-1 TO STA.# 4 @ 6,751' MD, LOC BUT UNABLE TO SD ***CONTINUE ON 9-6-22 WSR*** 9/6/2022 ***CONTINUE ON FROM 9-5-22 WSR*** RAN KJ, 4-1/2" OMK TO STA.# 3 @ 8,454' SLM, LOC BUT UNABLE TO SD NPT DUE TO MECHANICAL ISSUES ***CONTINUE ON 9-7-22 WSR*** 9/7/2022 ***WELL S/I ON ARRIVAL*** R/U POLLAD #58 ***WSR CONT ON 9-8-22** 9/7/2022 ***WSR CONT FROM 9-6-22*** R/D POLLARD #58 ***CONT WSR ON 9-8-22*** 9/8/2022 T/I/O= 1800/1750/0 Temp=S/I (TFS Unit 4 assist SL with Leak Detect Log) Spot equipment. Job postponed due to High Winds. SL in control of well @ departure. FWHP=1800/1750/0 Daily Report of Well Operations PBU E-100A 9/8/2022 ***WSR CONT FROM 9-7-22*** CONT R/U POLLARD #58 RAN 3.84" NO-GO, TAG SSSV-NIP 2,216' SLM / 2,242' MD ( test run for digital counterhead & veeder root) RAN 4-1/2" BLB, 1-1/4" DOUBLE KJ, 1.85" G-RING, RADDLE MANDRELS RAN 3.55" LIB S/D @ 11,535' SLM / 11,543' MD, (IMPRESSION OF X-CATCHER) ATTEMPT TO RUN 2.70" LIB INSIDE OF X-CATCHER S/D @ 11,535' SLM / 11,543' MD (IMPRESSION OF X-CATCHER) RAN 2.50" LIB INSIDE OF X-CATCHER S/D @ 11,536' SLM / 11,543' MD (NO INDICATIONS OF GLV IN X-CATCHER) RAN 4-1/2" OK-1, 7" EXT, 1.25" LIB TO ST#1 @ 11,518' SLM / 11,543' MD (LIB INCONCLUSIVE) RAN 4-1/2" OK-1, POCKET POKER w/ TATTELTALE PINS, LOC & S/D AROUND ST#1 @ 11,510' SLM, 11,515' SLM & 11,521' SLM, w/ OUT SUCCESS ***WSR CONT ON9-9-22*** 9/9/2022 ***WSR CONT FROM 9-8-22*** STBY FOR WINDS ***WSR CONT ON 9-10-22*** 9/10/2022 ***WSR CONT FROM 9-9-22*** RAN 4-1/2" OK-6, POCKET POKER w/ TATTLETAIL PINS. (TATTLETAIL PINS NOT SHEARED) ATTEMPT TO RUN 4-1/2" GR (WSL CHANGED PLANS) RAN 4-1/2" OK-6 w/ 1.25" LIB. (SMEAR MARKS ON OUTTER EDGE OF LIB) RAN 4-1/2" BLB, 1-1/4" DOUBLE KJ, 1.85" G-RING TO RADDLE GLM's. (UNABLE TO WORK PAST 11,529' SLM) RAN DE-CENT, CLOCK (01:00), 4-1/2" OM-K, 1.25" LIB WITHOUT SUCCESS RAN 3.48" DE-CENT, 3.72" SWAGE, 3.74" LIB, S/D @ 11,525' SLM, IMPRESSION OF 4-1/2" G-FISH NECK (catcher) ***WSR CONT ON 9-11-22*** 9/11/2022 ***WSR CONT FROM 9-10-22*** RAN 3.48" DE-CENT, CLOCK (10:30), 4-1/2" OM-1, 1.25" LIB (IMPRESSION OF CHINA CAP) STBY FOR WELL SUPPORT RE-BUILD SWAB & DHD TO SHOOT FLUID LVL RAN 4-1/2" GR, 4-1/2" D&D HOLE FINDER FROM 11,535' SLM TO 3,393' SLM @ VARIOUS DEPTHS (see log) ***WSR CONT ON 9-12-22*** 9/11/2022 Inline Swab Valve Rebuild (stripped in open position). Barriers = MV & SSV. Verified by performing independent LTT (passed). Removed/Installed new Gate, Seats, Seat Seals & Rebuilt Bonnet. Pressure Tested 300/low & 5000/high (passed). 9/11/2022 T/I/O=2028/1888/0. Assist Slickline Leak Detection Log,RU IA, Load IA 120 bbls crude, RU TBG, Load TBG 176 bbls crude Begin testing. Pumped 60 bbls crude down tbg to assist SL with D&D hole finder. *** job continued to 09-12-22*** 9/11/2022 T/I/O = 1900/1850/0. Temp = SI. IA FL ( Assist SL). IA FL @ 5365' (264' below sta#5 dome, 94 bbls fill). SL in control of well on departure. 10:30. Daily Report of Well Operations PBU E-100A 9/12/2022 ***WSR CONT FROM 9-11-22*** RAN 4-1/2" D&D HOLE FINDER BETWEEN ST#6 & ST#5, NARROWED DOWN THE LEAK IN THE TBG BETWEEN 3,750' & 4,000' (see log) PULLED KEYLESS X-CATCHER FROM 11,535'SLM / 11,570' MD ATTEMPTED TO SET 2-7/8" XX-PLUG @ 11,582' MD (poor action, tools covered in asphaltines) RAN 2-7/8" BLB, 2.24" G-RING TO BRUSH X-NIP @ 11,582' MD. (found leak on s- box, pooh to repack) WEATHER STBY ***WSR CONT ON 9-13-22*** 9/12/2022 *** job continued from 09-11-22*** Continue with D&D hole finder Pumped 11 bbls crude down tbg to assist with finding hole. SL down for weather, rig down leave unit on location 9/13/2022 ***WSR CONT FROM 9-12-22*** STBY FOR WINDS ***WSR CONT ON 9-14-22*** 9/14/2022 ***WSR CONT FROM 9-13-22*** STBY FOR WINDS CALLED OFF JOB FOR COPMLIANCE WORK R/D POLLARD #58 ***JOB INCOMPLETE, WELL LEFTS/I*** 9/16/2022 ***WELL S/I ON ARRIVAL*** R/U POLLARD #58 ***WSR CONT ON 9-17-22*** 9/17/2022 ***WSR CONT FROM 9-16-22*** BRUSH 2-7/8" X-NIP @ 11,582" MD T-BIRD PUMPED 176bbls DOWN TBG SET KEYLESS X-CATCHER (#41) @ 11'542' SLM DHD TO SHOOT IA FLUID LEVEL (FLUID LEVEL 2,909') ATTEMPTED TO PULL ST# 2 @ 10,094 MD PULLED ST# 3 INT-LGLV FROM 8,441' MD ATTEMPTED TO PULL ST# 2 @ 10,094 MD PULLED ST# 4 INT-LGLV FROM 6,751' MD ATTEMPTED TO PULL ST# 2 @ 10,094 MD ***WSR CONT ON 9-18-22*** 9/17/2022 T/I/O = 400/1600/0+. Temp = SI. IA FL (Assist SL). IA FL @ 2909' (492' above Sta#6 Dome. 50 bbls fill ). SL in control of well upon departure. 10:15 9/17/2022 T/I/O= 1370/2180/0 (Assist Slickline) TFS U-3, Pumped 176 bbls to load TBG, Bleed IA pressure before and after loading TBG. Pumped 176 bbls crude to load TBG. ***Job Continued on 9-18-22*** Daily Report of Well Operations PBU E-100A 9/18/2022 ***WSR CONT FROM 9-17-22*** PULLED ST#2 INT-LGLV FROM 10,094' MD MADE MULTIPLE ATTEMPTS TO ST# 5 @ 5,101' MD w/ OUT SUCCESS SET ST#4 INT-DGLV @ 6,751' MD SET ST#3 INT-DGLV @ 8,441' MD T-BIRD LOAD TGB w/ 60bbls CRUDE ATTEMTED COMBO (failed)(see log) T-BIRD PUMPED 45blls crude IA FREEZE PROTECT SET ST#2 INT-DGLV @ 10,094' MD T-BIRD ATTEMPTED MIT-T 15bbls crude DOWN TBG @ 2 BPM, TBG 450#psi TO 850#psi FELL BACK TO 450#psi OFF THE PUMP IA PRESSURE 700#psi TO 750#psi DURING THE SAME TIME ***WSR CONT ON 9-19-22*** 9/18/2022 ***Job Continued from 9-17-22*** (Assist Slickline) TFS U-3, Pumped 140 bbls crude assisting SL and 45 bbls crude to FP IA. ***Job Continued on 9-19-22*** 9/19/2022 ***WSR CONT FROM 9-18-22*** PULLED KEYLESS X-CATCHER FROM 11,542' SLM RAN 45KB LTP TEST TOOL (KB1) TO 11,545' SLM / 11,570' MD (poor results, see log) ***JOB COMPLETE, WELL LEFT S/I, PAD-OP NOTIFIED*** 9/19/2022 ***Job Continued from 9-18-22*** (Assist Slickline) TFS U-3, Pumped 28 bbls crude down the TBG to Assist Slickline, Pumped 91 bbls crude to FP E-102 FL. 9/20/2022 T/I/O=454/587/0 Assist E-Line (LEAK DETECTION LOG) Pumped a total of 404 bbls of crude down the IA and 89 bbls of crude down the TBG at a steady rate of 2 bbls min. 9/20/2022 ***WELL SHUT IN ON ARRIVAL*** (LDL) MIRU E-LINE PT PCE 300PSI LOW, 2500 PSI HIGH PLUG IN THE LTP WAS OBSERVED TO BE LEAKING. DECISION MADE TO DETERMING TUBING LEAK POINTS WHILE PUMPING DOWN IA. LEAKS IDENTIFIED AT 5108' AND 11546'. ATTEMPT TO DETERMINE IF PC LEAK EXISTS. PUMP DOWN TUBING AND PERFORM STATION STOPS AT 5090', 11537' AND 11557'. DETERMINED FLUID ENTERING IA THROUGH THE LEAK AT 11546'. ***JOB COMPLETE, WELL SECURE AND TURNED OVER TO DSO*** 10/5/2022 ***WELL S/I ON ARRIVAL*** (LDL) EQUALIZE & PULL 2-7/8" XX PLUG BODY FROM 11,582' MD. ATTEMPT TO SET 4-1/2" NS WRP AT 11,567' MD (Partial set / DPU did not release / Shear GR). ***JOB IN PROGRESS, CONTINUED ON 10/5/22 WSR*** 10/6/2022 T/IA/OA= Assist SL pump as directed. Pumped 101 bbls crude down TBG. Released from job, Sl on well upon departure 10/6/2022 ***CONTINUED FROM 10/5/22 WSR*** (LDL) JAR ON HES DPU ATTACHED TO WRP AT 11,519' SLM FOR ~4 HRS (see log) ***JOB IN PROGRESS, CONTINUED ON 10/7/22 WSR*** Daily Report of Well Operations PBU E-100A 10/7/2022 ***CONT FROM 10/6/22 WSR*** (LDL) PULL HES DPU & ADAPTER SLEEVE FROM 11,516' SLM (Shear stud sheared - WRP LIH). PULL 4-1/2" NS WRP (Missing one element & slip spring) FROM 11,525' SLM. RAN 3.50" 3 - PRONG WIRE GRAB TO 45KB LTP AT 11,570' MD (No recovery). JOB INCOMPLETE, WILL RETURN TO SET PLUG WHEN TOOLS AVAILABLE. ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** 10/14/2022 ***WELL S/I ON ARRIVAL*** BRUSHED 4-1/2" TBG W/ 3.75 G-RING AND BRUSH BRUSHED & DRIFTED 3-1/2" LINER & 3-3/16" LINER TO 11,614' SLM W/ 2-7/8" BRUSH & S-BLR. RIH W/ READ 24 ARM EXT REACH CALIPER FROM 11,614' SLM (11,663' MD) & BEGIN LOGGING UP. ***CONTINUE ON 10-15-22 WSR*** 10/14/2022 T/I/O= 1800/1800/0 Temp= S/I (TFS Unit 4 Assist SL with Brush and Flush) Pumped166 bbls crude down TBG to Assist SL with B&F. SL in control of well @ departure. FWHP= 1100/1800/0 10/15/2022 ***CONTINUE FROM 10-14-2022*** TAGGED LINER TOP WITH 4 1/2"" DPU/ WRP DRIFT @ 11,570' MD SET 4 1/2" WRP AT 11,568' MD ***WELL S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** 10/21/2022 T/I/O = 1190/1930/0+. Temp = SI. T & IA FL (FB request). No AL. IA FL @ 5101' (Sta#5, Dome, 90 bbls). T FL @ 1092'. SV, WV, SSV = C. MV = O. IA & OA = OTG. 16:30 10/26/2022 T/I/O=1200/2000/0 Attempt to CMIT TxIA Bled gas from IA to flowline until fluid. Pumped 100 bbls crude down IA. Bled gas off Tbg until fluid. Pumped 66 bbls crude down tbg establishing a 1 bpm LLR @ 1040 psi tbg & 950 psi IA. Freeze protect flowline with 94 bbls crude leaving 1500 psi. FWHPs=750/630/0 2/10/2023 T/I/O = 790/1595/0. Temp = SI. TBG & IA FL (WIC request). No AL. IA FL @ 2530' (44.3 bbls. 870' above sta#6 DMY ), TBG FL @ surface. SV, WV, SSV = C. MV = O. IA & OA = OTG. 12:00. 2/13/2023 T/I/O= 980/1680/0 Temp= SI Pumped 50 bbls crude down IA. getting Fluid at surface on IA & Tbg (Tbg is slightly energized) Tags Hung Pad Op. notified of well status. SV,SSV,WV= C MV= O CV's= OTG FWHP's=900/1350/0 2/15/2023 T/I/O = SSV/1320/0. Temp = SI. Bleed IAP to 900 psi or till fluid @ surface (Not OP). No AL. IA FL @ 1290'. Bled IAP to BT from 1320 psi to 860 psi in 30 min. Monitored for 30 mins. IAP increased 80 psi. IA FL @ 192'. Final WHPs = SSV/940/0. SV, SSV, WV = C. MV = O. IA, OA = OTG. 11:45. 3/15/2023 T/I/O = SSV/1640/0. Temp = SI. Bleed IAP (secure). No AL. IA FL @ 2600' (2501' above sta # 5 dome). Bled IAP to BT to 860 psi in 6 hrs (FTS). Monitored for 30 min. IAP increased 60 psi. Final WHPs = SSV/960/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 TAGGED LINER TOP WITH 4 1/2"" DPU/ WRP DRIFT @ 11,570' MD SET 4 1/2" WRP AT 11,568' MD Daily Report of Well Operations PBU E-100A 4/19/2023 T/I/O = 530/1620/0. Temp = SI. PPPOT-IC (PASS), T&IA FL's (OE request). No AL. TBG FL @ surface, IA FL @ 2400' (1679' above sta#5 dome). PPPOT-IC: Stung into test port (400 psi), bled void to 0 psi. Monitored for 10 min, no increase in pressure. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. SV, WV, SSV = C. MV = O. IA & OA = OTG. 17:10 . 4/28/2023 ***WELL S/I ON ARRIVAL*** SET 4-1/2" KEYLESS X-CATCHER ON WRP @ 11,568' MD PULLED INTG-LGLV FROM ST#5 @ 5,101' MD. MADE MULTIPLE ATEMPST TO SET INT-DGLV IN STA# 5; DROPPED VALVE ON 3RD ATTEMPT. RAN KJ, 4 1/2" BRUSH, KJ, KJ, 3.59" BELL GUIDE, 2.50" BELL GUIDE, AND 1 1/4" JD (GUTTED); RATTLED MANDRELS TO CATCHER. *no recovery ***WSR CONTINUED ON 4-29-23*** 4/29/2023 ***WSR CONTINUED FROM 4-28-23*** PULLED 4 1/2" KEYLESS X CATCHER FROM 11,568' MD (Recovered dropped DGLV). SET 4 1/2" KEYLESS X CATCHER @ 11,568' MD. SET INT-DGLV IN STA# 5 @ 5101' MD. PULLED CATCHER FROM 11,568' MD. ***WELL S/I ON DEPARTURE*** @ PULLED CATCHER FROM 11,568' MD. 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:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC) Subject:FW: CANCELLATION : PBU E-100A (PTD #218-157) 10-403 Sundry # 322-350 Date:Thursday, May 11, 2023 9:56:40 AM Attachments:Sundry_322-350_062822.pdf From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Thursday, May 11, 2023 9:22 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Kirsty Glasheen <Kirsty.Glasheen@hilcorp.com>; PB Wells Tech Aides <PBWellsTechAides@hilcorp.com> Subject: CANCELLATION : PBU E-100A (PTD #218-157) 10-403 Sundry # 322-350 Hello, Please cancel the approved 10-403 Sundry Request for PBU E-100A Formation Evaluation Test (attached for reference). We will not be pursuing this work at this time. If you have any questions or need additional information, please let me know. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Cell: (907)351-2459 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. RBDMS JSB 052423 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/3/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221003 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 501332053001 214070 8/10/2022 Halliburton CH PPROF BRU 222-34 502832018600 222039 9/15/2022 Halliburton CH RBT BRU 244-27 502832018500 222038 9/13/2022 Halliburton CH RBT END 1-45 500292199100 189124 8/11/2022 Halliburton CH PERF KBU 22-06Y 501332065000 215044 8/22/2022 Halliburton CH PPROF KBU 43-07Y 501332062500 214019 9/7/2022 Halliburton CH PPROF MPU C-24A 500292302001 209134 8/3/2022 Halliburton CH COILFLAG MPU L-46 500292355100 215118 9/10/2022 Halliburton CH MFC24 MPU S-34 500292317100 203130 9/3/2022 Halliburton CH MFC24 NS-10 500292298500 200182 8/18/2022 Halliburton CH WFL- TMD3D NS-32 500292317900 203158 8/17/2022 Halliburton CH WFL- TMD3D PBU 04-30 500292134500 185089 9/17/2022 Halliburton CH RMT3D PBU 05-24A 500292220401 204218 9/12/2022 Halliburton CH CAST PBU 11-16 500292158100 186078 9/10/2022 Halliburton CH PPROF PBU 11-27A 500292163801 222036 8/20/2022 Halliburton CH RBT PBU C-24B 500292081602 212063 8/16/2022 Halliburton CH PPROF PBU E-100A 500292281901 218157 9/20/2022 Halliburton CH LDL PBU S-106 500292299900 201012 9/12/2022 Halliburton CH RBT Please include current contact information if different from above. T37103 T37104 T37105 T37106 T37107 T37108 T37109 T37110 T37111 T37112 T37113 T37114 T37115 T37116 T37117 T37118 T37119 T37120 PBU E-100A 500292281901 218157 9/20/2022 Halliburton CH LDL Kayla Junke Digitally signed by Kayla Junke Date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y Samantha Carlisle at 9:01 am, Jun 10, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV 0*5-81 '/%'65 ; GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.06.28 13:09:10 -08'00' RBDMS JSB 063022 ϲͬϭͬϮϮ Ͳ sĞƌƐŝŽŶ ϯ &ŽƌŵĂƚŝŽŶǀĂůƵĂƚŝŽŶ ͲϭϬϬ Wd͗ϮϭϴͲϭϱϳ tĞůůEĂŵĞ͗ͲϭϬϬW/EƵŵďĞƌ͗ϱϬͲϬϬϮϵͲϮϮϴϭϵͲϬϭ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗KŶůŝŶĞ ZŝŐ͗ŽŝůͬůŝŶĞͬ^> ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗YϮͬϯ ϮϬϮϮ ƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ͗ϰŽƉĞƌĂƚŝŽŶ ĚĂǇƐ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ďďŝĞĂƌŬĞƌ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϭϴͲϭϱϳ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗EŽĞůEŽĐĂƐ ;ϵϬϳͿ ϮϮϵͲϵϱϯϮ ;ĐͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗tǇĂƚƚZŝǀĂƌĚ ϱϬϵͿ ϲϳϬͲϴϬϬϭ ;ĐͿ ƐƚZĞƐĞƌǀŽŝƌƉƌĞƐƐƵƌĞ͗ϯϱϬϬ ƉƐŝ Λ ϵ͕ϯϬϬ͛dsƐƐ;ϳ͘ϯƉƉŐĞͿ DŝŶ/͗Ϯ͘ϯϭ͟Λϭϭ͕ϱϴϮ͟ ʹ ϮͲϳͬϴ͟yEŝƉƉůĞŝŶ>dWǁͬWd^ DĂǆŶŐůĞ͗ хϳϬΣΛ ϭϯ͕ϯϭϳ͛ ϭϭϬΣΛϭϯ͕ϵϬϬ͛D dŝĞͲ/Ŷ>ŽŐ͗ZĂĚŝĂůĞŵĞŶƚŽŶĚ>ŽŐĨƌŽŵ,>ŽŶ:ƵŶĞϱƚŚ͕ϮϬϭϵ ZĞĨĞƌĞŶĐĞ>ŽŐ͗W> ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ ͲϭϬϬŝƐƚŚĞĨŝƌƐƚĂŶĚŽŶůǇƉƌŽĚƵĐĞƌŝŶƚŚĞ^ĂŵďƵĐĂďůŽĐŬŝŶƚŚĞ^ĂŐ ZŝǀĞƌ ĂŶĚ/ǀŝƐŚĂŬ͘/ƚǁĂƐĂ ϮϲϬϬ͛d ƐŝĚĞƚƌĂĐŬĚƌŝůůĞĚŝŶϮϬϭϵ͘hƉŽŶĐŽŵƉůĞƚŝŽŶ͕ ƚŚĞ/ǀŝƐŚĂŬǁĂƐƉĞƌĨŽƌĂƚĞĚ͘ǇĞĂƌůĂƚĞƌƚŚĞ ^ĂŐ ZŝǀĞƌ ǁĂƐ ƉĞƌĨŽƌĂƚĞĚ ŝŶƚŚĞdK ŝŶĂƚƚĞŵƉƚƚŽŚĞůƉůŝĨƚƉƌŽĚƵĐƚŝŽŶĨƌŽŵƚŚĞ /ǀŝƐŚĂŬ͘ZĞĐĞŶƚůǇ͕ ĂĚĞĞƉŐĂƐůŝĨƚĚĞƐŝŐŶǁĂƐ ŝŶƐƚĂůůĞĚƚŽŚĞůƉƉƌŽĚƵĐƚŝŽŶ͘dŚĞƌĞŝƐǀĂůƵĞƚŽ,ŝůĐŽƌƉƚŽƉĞƌĨ ŽƌŵĂďƵŝůĚͲƵƉƚĞƐƚŽŶƚŚĞ ^ĂŐ ZŝǀĞƌ ƌĞƐĞƌǀŽŝƌƚŽ ƵŶĚĞƌƐƚĂŶĚŝƚƐ͛ ĞǆƚĞŶƚ͘ KďũĞĐƚŝǀĞ͗ WĞƌĨŽƌŵ ^ĂŐ ZŝǀĞƌƌĞƐĞƌǀŽŝƌďƵŝůĚƵƉƚĞƐƚĨŽƌϯϬĚĂǇƐ͘/ƐŽůĂƚĞ/ǀŝƐŚĂŬǁŝƚŚƉůƵŐĂŶĚŐĂƵŐĞƐ͕ĂĚĚ ,> ƉĞƌĨŽƌĂƚŝŽŶƐƚŽ^ĂŐ ZŝǀĞƌ ĂŶĚŵĞĂƐƵƌĞĚƌĂǁĚŽǁŶǁŝƚŚŐĂƵŐĞƐ͘WƵůůĂůůĞƋƵŝƉŵĞŶƚ͘ EŽƚĞƐ͗ ŶĂƚƚĞŵƉƚǁĂƐŵĂĚĞƚŽƐĞƚƚŚĞƉůƵŐǁŝƚŚĐŽŝůǁŚŝůĞƚŚĞǁĞůůǁĂƐĨůŽǁŝŶŐ͘dŚŝƐĨĂŝůĞĚ͕ƐŽǁĞǁŝůůƐĞƚƚŚĞƉůƵŐ ǁŝƚŚƚŚĞǁĞůůƐŚƵƚŝŶ͘ ,ĞĞů;^ĂŐͿ WĞƌĨŽƌĂƚŝŽŶƐĂƌĞŽƵƚƐŝĚĞŽĨƚŚĞWďŽƵŶĚĂƌŝĞƐďƵƚǁŝƚŚŝŶƚŚĞ WƌƵĚŚŽĞĂǇhŶŝƚďŽƵŶĚĂƌŝĞƐ͘ ϭϬͲϰϬϯ ƐƵŶĚƌǇ ĨƌŽŵK' ĂŶĚ dƌĂĐƚKƉĂƉƉƌŽǀĂůĨƌŽŵK'ŝƐƌĞƋƵŝƌĞĚ ĨŽƌƉĞƌĨŽƌĂƚŝŽŶƐ͘K' ŚĂƐĂƉƉƌŽǀĞĚ ƚŚĞ ŚĞĞů ƉĞƌĨŽƌĂƚŝŽŶƐ͘ dŚĞƐĞƉĞƌĨŽƌĂƚŝŽŶƐĂůƐŽƌĞƋƵŝƌĞĂ'KZǁĂŝǀĞƌ ĨƌŽŵK'͘ ŽŶĨŝƌŵǁŝƚŚ :ĞĨĨEĞůƐŽŶ ;'KͿ ƚŚĂƚƚŚŝƐĂƉƉƌŽǀĂůŝƐ ƐƚŝůůĂĐƚŝǀĞ ƉƌŝŽƌƚŽĂĚĚŝŶŐƉĞƌĨŽƌĂƚŝŽŶƐ͘ tŚĞŶƉĞƌĨŽƌĂƚŝŽŶƐ ĂƌĞĐŽŵƉůĞƚĞ͕ĞŵĂŝůK͕'KĂŶĚůŝĐŝĂ^ŚŽǁĂůƚĞƌƐŽK'ƌĞƋƵŝƌĞŵĞŶƚƐĐĂŶďĞĐŽŵƉůĞƚĞĚ͘ dŝŵĞƐŽĨƐŚƵƚŝŶĂŶĚďƵŝůĚƵƉƉƌĞƐƐƵƌĞƐĞƋƵĞŶĐŝŶŐŵĂǇǀĂƌǇĂŶĚĐŽƵůĚĐŚĂŶŐĞƉĞƌƚŚĞZ͘ Žŝů ϭ͘ D/Zh͘DĂŬĞƵƉĚƌŝĨƚͬŶŽǌǌůĞͬůŽŐŐŝŶŐ,ĂŶĚZ/,ƚŽd͘ WŽŽŚůŽŐŐŝŶŐĂŶĚĨůĂŐƉŝƉĞĂƐŶĞĞĚĞĚ͘ ŽŶĨŝƌŵƚŝĞŝŶǁͬK Ϯ͘ Z/,ǁŝƚŚ E^<ƌĞƚƌŝĞǀĂďůĞ ƉůƵŐĂŶĚƐĞƚďĞƚǁĞĞŶϭϱ͕ϮϱϬ͛ ʹ ϭϱ͕ϯϱϬ͛D͘ ,ĂŶŐŐĂƵŐĞƐďĞůŽǁ ƉůƵŐ͘ ϯ͘ ZDK ΎWKW ǁĞůůĨŽƌϳͲϭϰĚĂǇƐŝŶŽƌĚĞƌƚŽŐĞƚĂǁĞůůƚĞƐƚǁŝƚŚ/ǀŝƐŚĂŬŽŶůǇƉƌŽĚƵĐƚŝŽŶΎΎ '/% ŚĞĞů ƉĞƌĨŽƌĂƚŝŽŶƐ͘ WĞƌĨŽƌŵ ^ĂŐ ZŝǀĞƌƌĞƐĞƌǀŽŝƌďƵŝůĚƵƉƚĞƐƚĨŽƌϯϬĚĂǇƐ͘ K' ŚĂƐĂƉƉƌŽǀĞĚ ƚŚĞ '/% ϲͬϭͬϮϮ Ͳ sĞƌƐŝŽŶ ϯ &ŽƌŵĂƚŝŽŶǀĂůƵĂƚŝŽŶ ͲϭϬϬ Wd͗ϮϭϴͲϭϱϳ ^ƚĂƌƚŽĨ^ƵŶĚƌǇ KƉĞƌĂƚŝŽŶƐ ůŝŶĞ ϭ͘ ^Ğƚ/W;ĂŬĞƌͿĂƚĂƉƉǆϭϯ͕ϮϱϬ͛D͘,ĂŶŐŐĂƵŐĞƐďĞůŽǁƉůƵŐ͘ ;ϵϬͲĚĂǇƐŽĨĚĂƚĂ ŶĞĞĚĞĚͿ Ϯ͘ Wd/WƚŽϭϬϬϬƉƐŝƚŽĞŶƐƵƌĞŝƚŝƐŚŽůĚŝŶŐ͘ ϯ͘ hŶĚĞƌďĂůĂŶĐĞǁĞůůďǇďůĞĞĚŝŶŐΕϯϬϬƉƐŝƚŽĨůŽǁůŝŶĞ͘ ϰ͘ ĚĚ ƉĞƌĨŽƌĂƚŝŽŶƐĨƌŽŵϭϮ͕ϵϳϮͲϭϮ͕ϵϵϮ D͘ ϱ͘ Z/,ĂŶĚƚĂŐ/WƚŽĐŽŶĨŝƌŵƉůƵŐŚĂƐŶŽƚŵŽǀĞĚ͘ ϲ͘ KEKd&>Ktt>>hEd/>^>/<>/E^dW/^&/E/^, ϳ͘ ZDK͘ ΎΎKEKd &>Ktt>>hEd/>^>/<>/EKDW>d^'h'ZKWΎΎ ^ůŝĐŬůŝŶĞ ϴ͘ D/Zh͘ ϵ͘ Z/,ĂŶĚƚĂŐ/WǁŝƚŚ>/ƚŽĐŽŶĨŝƌŵĐĞŶƚƌĂůŝǌĂƚŝŽŶ͘WKK,͘ ϭϬ͘ ZŝŐƵƉ͕Z/,ĂŶĚƌŽƉŐĂƵŐĞƐŽŶ/W ;ϵϬĚĂǇƐŽĨĚĂƚĂŶĞĞĚĞĚͿ͘DŽĚŝĨǇĐĂƌƌŝĞƌŽƌĐĂƚĐŚĞƌĂƐƚŽŶŽƚƐůŝƉ ŐĂƵŐĞƐƉĂƐƚĨŝƐŚŝŶŐŶĞĐŬŽĨ/W͘ĚĚĐĞŶƚƌĂůŝǌĂƚŝŽŶŝĨŶĞĐĞƐƐĂƌ ǇƚŽŚĞůƉĨŝƐŚŝŶŐŐĂƵŐĞƐŽƵƚŽĨŚŽůĞ͘ ϭϭ͘ ŝƐĐƵƐƐǁŝƚŚKŝĨ/W^ƚŽƉŝƐŶĞĞĚĞĚ͘ ϭϮ͘ ,ĂŶĚǁĞůůŽǀĞƌƚŽŽƉĞƌĂƚŽƌĨŽƌǁĞůůƉŽƉ ϭϯ͘ ZDK͘ WŽƌƚĂďůĞdĞƐƚ^ĞƉĂƌĂƚŽƌͬ&ƵůůďŽƌĞ ϭϰ͘ D/Zh͘^ƉŽƚƐŽůŝŶĞĐĂŶŐĞƚŽŶǁĞůůŝĨŵŽƌĞƉĞƌĨƐĂƌĞŶĞĞĚĞĚĂŶĚƐŽ&ĐĂŶƉĞƌĨŽƌŵ,WŝĨŶĞĞĚĞĚ͘ ϭϱ͘ KďƚĂŝŶ ^ĂŐƚĞƐƚĨŽƌϮϰͲϰϴ ŚŽƵƌƐ ŽŶĐĞĨůŽǁŝŶŐ ϭϲ͘ WĞŶĚŝŶŐ͗/ĨǁĞůůĚŽĞƐŶ͛ƚĨůŽǁ͕&ƉĞƌĨŽƌŵ,WƉĞƌKƉƵŵƉƐĐŚĞĚƵůĞ͘/ĨŝƚĚŽĞƐŶŽƚĨůŽǁĂŐĂŝŶ͕ůŝŶĞ ĂĚĚĐŽŶƚŝŶŐĞŶƚƉĞƌĨƐ;ďĞůŽǁͿ ϭϳ͘ ZDK ΎΎ&>Ktt>>&KZD/E/DhDK& ϯϬ z^͕ ƚŚĞŶ ƐŚƵƚͲŝŶǁĞůůĨŽƌϯϬĚĂǇƐŽĨďƵŝůĚƵƉ͘ ĐŽŶĨŝƌŵƚŝŵĞǁŝƚŚZΎΎ ŽŶƚŝŶŐĞŶƚ Ͳ /ĨŚĞĞůƉĞƌĨƐǁĞƌĞŶŽƚƐƵĨĨŝĐŝĞŶƚĨŽƌůŝĨƚ ůŝŶĞ;WĞŶĚŝŶŐͿ Ͳ ϭϴ͘ D/Zh͘ ϭϵ͘ /ĨĐƵƌƌĞŶƚƉĞƌĨƐǁŝůůŶŽƚĨůŽǁ͕hŶĚĞƌďĂůĂŶĐĞǁĞůůďǇΕϯϬϬƉƐŝ ϮϬ͘ ĚĚ ƉĞƌĨŽƌĂƚŝŽŶƐĨƌŽŵϭϮ͕ϵϵϮͲϭϯ͕ϬϭϮ͛D͘;Z/,ĂŶĚƚĂŐ/WƚŽĐŽŶĨŝƌŵƐĞƚͿ Ϯϭ͘ ZDK͘ ϮϮ͘ WŽƌƚĂďůĞƐĞƉĂƌĂƚŽƌƚŽŽďƚĂŝŶƚĞƐƚĂŶĚKW^ƚŽƉĞƌĨŽƌŵϯϬĚĂǇŽŶͬϯϬĚĂǇďƵŝůĚƵƉƚĞƐƚ EK&^hEZzKWZd/KE^ ^ůŝĐŬůŝŶĞ ʹ ĐŽŶĨŝƌŵǁŝƚŚKƉƌŝŽƌƚŽƚŚĞƐĞƐƚĞƉƐ͊tĞůůŵƵƐƚŚĂǀĞŚĂĚ ϯϬ ĚĂǇƐ ŽŶƚŝŵĞĨŽůůŽǁĞĚďǇϯϬ ĚĂǇƐ ^/ƚŝŵĞ Ϯϯ͘ D/Zh͘ Ϯϰ͘ WƵůů/W^ƚŽƉŝĨƐĞƚ͕ &ŝƐŚ'ĂƵŐĞƐĨƌŽŵƚŽƉŽĨƉůƵŐ͘ Ϯϱ͘ WƵůů/WͬWůƵŐ͘ Ϯϲ͘ ^ĞŶĚŐĂƵŐĞĚĂƚĂƚŽK;EŽĞůEŽĐĂƐͿ'ĞŽ;:ĞĨĨEĞůƐŽŶͿĂŶĚZ;dŝŵĂǀŝƐͿ Ϯϳ͘ ZDK ΎΎ&ůŽǁǁĞůůĂŶĚŐĞƚǁĞůůƚĞƐƚƐϮͲϱĚĂǇƐ͘/ĨŶĞǁ ƉĞƌĨŽƌĂƚŝŽŶƐĂƌĞŶŽƚĂĚĚŝŶŐĞŶŽƵŐŚĨŽƌŐĂƐůŝĨƚƚŚĞŶƚŚĞĐŽŝů ĐŽŶƚŝŶŐĞŶƚƐƚĞƉƐďĞůŽǁǁŝůůďĞƉĞƌĨŽƌŵĞĚΎΎ Žŝů ϲͬϭͬϮϮ Ͳ sĞƌƐŝŽŶ ϯ &ŽƌŵĂƚŝŽŶǀĂůƵĂƚŝŽŶ ͲϭϬϬ Wd͗ϮϭϴͲϭϱϳ Ϯϴ͘ D/Zh Ϯϵ͘ WƵůůZĞƚƌŝĞǀĂďůĞƉůƵŐ ŽŶƚŝŶŐĞŶƚ^ƚĞƉƐ ϯϬ͘ DĂŬĞƵƉĚƌŝĨƚͬ>ŽŐ,͘>ŽŐĚŽǁŶƚŽWdĂŶĚĨůĂŐƉŝƉĞĂƐŶĞĐ ĞƐƐĂƌǇ͘ĂŶƐŬŝƉƚŚŝƐƐƚĞƉŝĨWdŝƐ ĐŽŶĨŝƌŵĞĚŽŶůŽŐĨƌŽŵĨŝƌƐƚĐŽŝůƐƚĞƉƐĂŶĚĂƚĂŐͬƐƉĂĐĞŽƵƚŽĨƉĞƌĨŐƵŶƐŝƐƉŽƐƐŝďůĞǁͬŽůŽŐŐŝŶŐ͘t^^ ĚŝƐĐƌĞƚŝŽŶ ϯϭ͘ ĚĚϲϮ͛WĞƌĨŽƌĂƚŝŽŶƐĨƌŽŵϭϱ͕ϯϵϯ͛ ʹ ϭϱ͕ϰϮϰ͛ĂŶĚϭϱ͕ϰϴϲͲϭϱ͕ϱϭϳ͛D;ϮƌƵŶƐͿ ϯϮ͘ ZDK KƉƐ͗ WKWǁĞůů ĂŶĚƚĞƐƚŝŶ>W͘ ϲͬϭͬϮϮ Ͳ sĞƌƐŝŽŶ ϯ &ŽƌŵĂƚŝŽŶǀĂůƵĂƚŝŽŶ ͲϭϬϬ Wd͗ϮϭϴͲϭϱϳ tĞůůďŽƌĞ ^ĐŚĞŵĂƚŝĐ ϲͬϭͬϮϮ Ͳ sĞƌƐŝŽŶ ϯ &ŽƌŵĂƚŝŽŶǀĂůƵĂƚŝŽŶ ͲϭϬϬ Wd͗ϮϭϴͲϭϱϳ WƌŽƉŽƐĞĚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ +LOFRUS 1RUWK6ORSH//&+LOFRUS 1RUWK6ORSH//&Changes to Approved Work Over Sundry Procedure'DWH 6XEMHFW &KDQJHVWR$SSURYHG 6XQGU\3URFHGXUHIRU :HOO ($6XQGU\ $Q\PRGLILFDWLRQVWR DQ DSSURYHGVXQGU\ ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ &KDQJHVWRDQDSSURYHG VXQGU\ ZLOOEHFRPPXQLFDWHGWRWKH$2*&& E\WKH ZRUNRYHU:2³ILUVWFDOO´HQJLQHHU $2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6WHS3DJH'DWH 3URFHGXUH&KDQJH+163UHSDUHG%\,QLWLDOV+16$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH$SSURYDO$VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH3UHSDUHG)LUVW&DOO 2SHUDWLRQV (QJLQHHU 'DWH-XQH Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:218-157 6.50-029-22819-01-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 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 15540 15523 9174 11620 None None 8015 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 43 - 123 43 - 123 1490 470 Surface 4398 9-5/8" 43 - 4441 43 - 3690 6870 4760 Intermediate 12866 7" 40 - 12906 40 - 9072 8160 7020 Liner 1143 4-1/2" 11845 - 12988 8171 - 9148 8430 7500 Perforation Depth: Measured depth: 14986 - 15486 feet True vertical depth:9297 - 9183 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 38 - 11646 38 - 8033 11620 8015Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker SB-3 Packer Liner 3970 3-1/2"x3-1/4"x2-7/11570 - 15540 7982 - 9170 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 18627979 0 1400 290 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: Oshiro, Joleen JOLEEN.OSHIRO@bp.com Authorized Name:Oshiro, Joleen Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 4606 Treatment descriptions including volumes used and final pressure: 13. EGPY Pad Engineer/Subsurface Performance Ana 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 measured9170 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program 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: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028304 & 028299 PBU E-100A 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 Joleen Oshiro Digitally signed by Joleen Oshiro Date: 2020.05.18 12:28:08 -08'00' By Samantha Carlisle at 1:40 pm, May 18, 2020 MGR18MAY20 DSR-5/18/2020 RBDMS HEW 5/20/2020 ACTIVITYDATE SUMMARY 4/4/2020 ***WELL FLOWING ON ARRIVAL*** (perforating) DRIFTED W/ 2.35" CENTRALIZER TO FLOW THROUGH SUB @ 11,582' MD PULLED FLOW THROUGH SUB W/ GAUGES FROM X NIPPLE @ 11,582' MD DRIFTED W/ 2.20" CENTRALIZER, 1 1/2" SAMPLE BAILER TO DEVIATION @ 13,290' SLM ***CONTINUE JOB ON 04/05/2020*** 4/5/2020 ***CONTINUE JOB FROM 04/04/2020*** (perforating) SWCP 4517 RIG DOWN ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** 4/15/2020 CTU #9 1.75" CT .156 wt Job Scope: Add Perf to add competitive Sag gas for lifting of well. MU Baker dimple on connector MHA HES memory logging tools. Tag bottom @ 15,499' waiit 5 min in compression and log up at 50 fpm. Off bottom 15492' Stop for 5 min at 15400' paint white flag, Continue logging up at 50 fpm ...Continue WSR on 4/16/2020... 4/16/2020 CTU #9 1.75" CT .156 wt ***WSR continued from 4-15-2020*** Job Scope: Add Perf to add competitive Sag gas for lifting of well. Continue WSR from 4/15/2020 Stop at top of logging interval for 5 min. POOH. Recover data with +23' correction to tie-in log. Corrected PBTD tag of 15522.6' (vs. reference log). MU RIH w/HES TCP 2.0" Maxforce perf gun, 6 spf. Tie-in to flag and perforate 15455'-15486' (vs. Reference log, 8/7/19 PDCL). POOH. All shots fired and ball recovered.Turn well over to operations to and perform 8 hour well test. ...Continued on WSR 4-17-20... 4/17/2020 CTU #9 1.75" CT .156 wt ***WSR continued from 4-16-2020*** Job Scope: Add Perf to add competitive Sag gas for lifting of well. Standby while well test performed. Well POPed with DPBGL. Begin test at 03:30. At 14:00 discussed with APE and will perf next interval at 15,424 - 15,455. MU HES 31' x 2.0" MaxForce perf gun, 6 spf and RIH. Tie in at flag and perforate 15,424-15,455 (vs. Ref Log). POOH. ...Job continued on 04/18/20....... 4/18/2020 CTU #9 1.75" CT .156 wt ***WSR continued from 4-17-2020*** Job Scope: Add Perf to add competitive Sag gas for lifting of well. POOH and lay down perf guns. All shots fired, ball recovered. PT tree cap and Hand well over to production for Well Test. After 4 hour test; 930 BOPD, 5.8 Gas, 2400 Water, Discuss w/Ape says, to rig down. ...Job Complete... Daily Report of Well Operations PBU E-100A DATA SUBMITTAL COMPLIANCE REPORT 9/5/2019 Permit to Drill 2181570 Well Name/No. PRUDHOE BAY UNIT E -100A Operator BP Exploration (Alaska) Inc. MD 15540 TVD 9170 Completion Date 6/6/2019 Completion Status 1 -OIL REQUIRED INFORMATION / Mud Log NV Samples No I/ DATA INFORMATION List of Logs Obtained: MWD/GR/RES, GR/CCL/RPM, CMT EVAL Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ED C 30901 Digital Data ED C 30901 Digital Data ED C 30901 Digital Data ED C 30901 Digital Data ED C 30901 Digital Data ED C 30901 Digital Data Log C 30901 Log Header Scans ED C 30921 Digital Data ED C 30921 Digital Data AOGCC Current Status 1 -OIL API No. 50-029-22819-01-00 UIC No Directional Survey Yes (from Master Well Data/Logs) Interval OHI Start Stop CH Received Comments 12900 15527 6/18/2019 Electronic Data Set, Filename: E- 100A_PNC3D_ MRPM_RAW_PASS0IUP_6JUN2 019_BHl.las 13100 13300 6/18/2019 Electronic Data Set, Filename: E- 100A_PNC3D MRPM_RAW_PASS02UP_6JUN2 019 6Hl.las 6/18/2019 Electronic File: E - 100A PNC3D_MRPM_RAW_PASS01UP_6JUN2 019 BHl.dlis 6/18/2019 Electronic File: E - 100A PNC3D_MRPM_RAW_PASS02UP_6JUN2 019 6Hl.dlis 6/18/2019 Electronic File: E- 100A_PNC3D_MRPM_RAW_6JUN2019_BHl.me to 6/18/2019 Electronic File: E- 100A_PNC3D_MRPM_RAW_6JUN2019_BHI.PD F 0 0 2181570 PRUDHOE BAY UNIT E -100A LOG HEADERS 12588 15540 6/27/2019 Electronic Data Set, Filename: E- 100A_LW D_ FINAL_ FIELD_COMPOSITE_26May 2019_BHI_CTK.las 6/27/2019 Electronic File: E- 100A_GR_m Res— 26May2019_ MD_ FINAL _ FIELD_ BHI_CTK.cg Pagel of 3 Thursday, September 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 9/5/2019 Permit to Drill 2181570 Well Name/No. PRUDHOE BAY UNIT E -100A Operator BP Exploration (Alaska) Inc. API No. 50-029-22819-01-00 MD 15540 TVD 9170 Completion Date 6/6/2019 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 30921 Digital Data 6/27/2019 Electronic File: E - 100A GR Res _26May2019_TVDSS_FINAL_FIE LD_BHI_CTK.cgm ED C 30921 Digital Data 6/27/2019 Electronic File: E- 100A_GR_Res _ 26May2019_MD_FINAL_FIELD_ BHI_CTK.pdf ED C 30921 Digital Data 6/27/2019 Electronic File: E- 100A_GR_Res _26May2019_ TVDSS_FINAL_FIE LD_BHI_CTK.pdf ED C 30921 Digital Data 6/27/2019 Electronic File: E-1 DOA Final Field Surveys.osv ED C 30921 Digital Data 6/27/2019 Electronic File: E -100A Final Field Surveys.xlsx ED C 30921 Digital Data 6/27/2019 Electronic File: E -100A Final Surveys.pdf ED C 30921 Digital Data 6/27/2019 Electronic File: E -100A Final Surveys.txt ED C 30921 Digital Data 6/27/2019 Electronic File: E- 1ODA _25_tapescan_B H I_CTK.txt ED C 30921 Digital Data 6/27/2019 Electronic File: E-100A_5_tapescan_BHI_CTK.txt ED C 30921 Digital Data 6/27/2019 Electronic File: E-100A_output.tap ED C 30921 Digital Data 6/27/2019 Electronic File: E- 100A_GR_Res— 26May2019_ MD_ FINAL_FIELD— FIELD_ BHI_CTK.tif BHI ED C 30921 Digital Data 6/27/2019 Electronic File: E- 100A_GR_Res 26May2019_TVDSS_FINAL—FIE LD_BHI_CTK.tif Log C 30921 Log Header Scans 0 0 2181570 PRUDHOE BAY UNIT E -100A LOG HEADERS ED C 31100 Digital Data 11297 15485 8/13/2019 Electronic Data Set, Filename: E- tOOA_C1_20190605_RBT_HAL_MAIN_MEM.las ED C 31100 Digital Data 11305 15493 8/13/2019 Electronic Data Set, Filename: E- t00A_C1_20190605_RBT_HAL_REPEAT_MEM.I as ED C 31100 Digital Data 8/13/2019 Electronic File: E- 10OA_C1_20190605_RBT_HAL_MAIN_MEM.dlis ED C 31100 Digital Data 8/13/2019 Electronic File: E- 10OA_C 1_20190605_RBT_HAL_MEM. pdf ED C 31100 Digital Data 8/13/2019 Electronic File: E- 10OA_C 1_20190605_RBT_HAL_MEM_i mg.tiff AOGCC Page 2 of 3 Thursday, September 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 9/5/2019 Permit to Drill 2181570 Well Name/No. PRUDHOE BAY UNIT E -100A Operator BP Exploration (Alaska) Inc. API No. 50-029-22819-01-00 MD 15540 TVD 9170 Completion Date 6/6/2019 Completion Status 1-0I1 Current Status 1-0I1 UIC No ED C 31100 Digital Data 8/13/2019 Electronic File: E - 100A_ C1_ 20190605_RBT_HAL_REPEAT_MEM. this Log C 31100 Log Header Scans 0 0 2181570 PRUDHOE BAY UNIT E -100A LOG HEADERS Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report YO Production Test Informations NA Geologic Markers/Tops 0 COMPLIANCE HISTORY Completion Date: 6/6/2019 Release Date: 12/6/2018 Description Comments: Sample Interval Set Start Stop Sent Received Number Comments Directional / Inclination Data D Mud Logs, Image Files, Digital Data Y & Core Chips Y!NA l Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files 0 Core Photographs Y Daily Operations Summary O Cuttings Samples Y / 6) Laboratory Analyses Y v! Date Comments Compliance Reviewed By: Y \ Date: A000C Page 3 of 3 Thursday, September 5-2019 WELL LOG TRANSMITTAL 4905740912 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: E -100A Run Date: 6/5/2019 2 18 157 31100 August 8, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 E -100A Data in LAS format, Digital Log Image files 50-029-22819-01 RECEIVED AUG 13 2019 AOGCC 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com and GANCPDC@USAANC.hou. Date: Vlno# Signed: Winston, Hugh E (CED) From: Davies, Stephen F (CED) Sent: Thursday, January 16, 2020 9:44 AM To: Roby, David S (CED) Cc: Winston, Hugh E (CED) Subject: RE: PBU E-10OA well Dave, I'm a fan of overkill to ensure a completely clear public record, so I would: • pull the paper 407 out of the well history file, • hand -correct the completed interval on it, then initial and date the correction, • rescan the corrected 407, then replace the current, incorrect 407 image within Laserfiche, • place the corrected paper 407 back into the well history file, and • scan your email and insert that image into Laserfiche well history file. Cheers, Steve D. From: Roby, David S (CED) <dave.roby@alaska.gov> Sent: Wednesday, January 15, 2020 10:49 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Subject: PBU E -100A well Steve, BP submitted a 407 last year after the subject well was drilled and completed showing that the well was completed in the Sambuca Undefined Oil Pool (see attached). BP has been reporting production for this well against the Prudhoe Oil Pool but I've been having Huey change it to Sambuca to match what RBDMS had for the completed interval otherwise it caused errors when running the RCC. However, BP informed me yesterday that all the perfs in the well are actually in the Prudhoe Oil Pool, by a matter of tens of feet, so the POP reporting was correct. I'm having Huey move the production back to the POP and to change the completed interval for the well from Sambuca to POP so we don't have errors in the future. I have a question for you though, should I pull the 407 out of the well file and correct the completed interval on it and then have the page rescanned and put back in the file, or is just something like this email enough to throw in the well file to indicate what the correct pool should be? Thanks, David Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, STATE OF ALASKA CLASKA OIL AND GAS CONSERVATION COMMISe--N WELL IMPLETION OR RECOMPLETION REPO AND LOG 1a. Well Status: Oil 0- Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 tb. Well Class: GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: One Development 0 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date C� omp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 6/6/2019 • 218457 3. Address: 7. Date Spudded. 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 5/17/2019 50-029-22819-01-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: 5/25/2019 PBU E -100A • Surface: 5001' FSL, 500' FEL, Sec. 06, T11 N, R14E, UM Ref Elevations 9. KB 71.00 17. Field/Pool1'1(s): �/`Vl(nrF( (71 Top of Productive Interval: 2737 FSL, 1611' FEL, Sec. 30, T12N, R14E, UM GL 28.96 BF 31.16 PRUGHOE BAY, Total Depth: 2808' FSL, 556' FWL, Sec. 29, T12N, R14E, UM 10. Plug Back Depth(MDrIVD): 18. Property Designation: 15523'19174' ADL 028304 8 028299 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 664447 - y- 5976785 ' Zone - ASP 4 , 15540'19170- - 89-111 TPI: x- 663125 y- 5985053 Zone - ASP 4 Total Depth: x- 665290 y- 5985172 Zone - ASP 4 12. SSSV Depth (MD/TVD): None 40 Thickness of Permafrost MD"D: 1900' (Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top NAndow Submit electronic and printed information per 20 AAC 25.050MD7rVD NIA (h MSL) : 12988' / 9148' 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 RECEIVED MWD / GR / RES, OR / CCL / RPM, Cement Evaluation UN J 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECOR A0GC AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H40 43' 123' 43' 123' 30" 260 sx Arctic Set (Approx.) 9-5/8" 47# L-80 43' 4441' 43' 3690' 12-1/4" 2189 sx PF'E', 335 sx Class'G 7" 29# L-80 40' 12906' 40' 9072' 6-1/2" 300 sx Sillicalite 4-1/2" 12.6# L-80 11845' 12988' 8171' 9148' 6" 180 ax Class 'G' 3-1/2"x3-1/4" 9.3#/6.6# tecras 11570' 15540' 7982' 9170' 4-1/4" 187 sx Class'G' ✓ x2-7/8" /6.5# 24. Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Tap and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD1TV 4-1/2" 12.6# L-80 11646' 11620'18015' 2" Gun Diameter, 6 apt 6/6/2019 14986'-15018' 9297'-9291' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes 11 No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information (30MPLETIO N DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Q TE l VE r 'D 2278' Freeze Protect w/ 35 Bbls Diesel 27. PRODUCTION TEST Date First Production: June 14, 2019 Method of Operation (Flowing, gas lift, etc.): Flowing Date of Test: 6/18/19 Hours Tested: 12 Production for Test Period �► Oil -Bbl: 442 Gas -MCF: 1700 Water -Bbl: 46 Choke Size: 96 Gas -Oil Ratio: 3845 Flow Tubing 180 Press Casino Press: 800 Calculated 24 Hour Rate �► Oil -Bbl: 884 Gas -MCF: 3400 Water -Bbl: g2 Oil Gravity -API loom: 24.1 Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only AVNI µ6k12Ak&19 RBDMSA'F�JUL 0 2 2019 b'`�' V I/f4/to 28. CORE DATA I Conventional Comm) Yes ❑ No 0 Sidewall Cores Yes ❑ No El I If Yes to either question, list formations and intervals coretl (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No Permafrost - Base If yes, list intervals and formations tested briefly summarizing test results. Attach Top of Productive Interval 13072' 9221' separate sheets to this forth, if needed, and submit detailed test information per 20 AAC 25.071, Shublik 13010' 9168' Sadlerochit-Zone 4 13072' 9221' CGL - Zone 3 13157' 9282' Base of CGL - Zone 2 13220' 9321' Zone 3 (Invert) 14613' 9372' Zone 4 14904' 9315' Shublik 15152' 9266' Sag River 15371' 9209' Formation at total depth. Sag River From Base) 15371' 9209' 31. List of Attachments: Summary of Daily Drilling Reports, Summary of Post -Rig Work, Surrey, Cement Report, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Hyatt, Trevor Authorized Title: St6 S ecialist ftContact Email: Tmwr.Hyatt@bp.cem Authorized Signature: Date: Contact Phone: +1907 564 4627 INSTRUCTIONS General: This forth 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 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-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 forth 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 coretl 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: care analysis, paleontological report, production or well test results. Form 10407 Revised 5/2017 Submit ORIGINAL Only WELLHEAD= FMC,11 ACTUATOR= 2-7/8' X Ip, D = 2.31' 1 3-12"x14P,11)=2.813• 4-1/2' FES X NIP, ID = 3,81- .81"3-1/2'x3-3/16°XO, OKB. EJ3! = 71' BF. ELEV = 31.16' KOP= 1100' Max Angle = 108^ @ 1523Y Datum MD= 11774' DatumTVD= 80501SS 1 9-518- CSG, 47#, L-80, ID = 8.681' 1-1 4441' Minimum ID = 2.377" @ 13634' 33/16" X 2-718" XO TOPOF 3-12' X 3-1/4' X 2-7/8" LNR 11580' ID = 3.958' PERFORATION SUWVIARY REF LOG: ON ANGLEAT TOP PERF: 101^ @ 14986' Note: Refer to Production DB for historical mrf data 7" CSG, 29#, L-80, ID = 6.184- G %w?:i:Y 1 4-12' LNR, 12.6#, L-80, .0152 bpf, D = 3.958" 1-i --12966' I LNR, 6.6#, 13CR-65 STL, .0058 tpf, D = 2.441' - 15540' E -1 00A �TES@W91'.-CHRANGLE 70ELNRO317'. 111 h_.d D1S:25° 13360'. "CHROME LNR" l_J GAS LFT MANDRILS ST MD ITVDIDEVI 2-7/8' X Ip, D = 2.31' 1 3-12"x14P,11)=2.813• 4-1/2' FES X NIP, ID = 3,81- .81"3-1/2'x3-3/16°XO, TYPE VLV LATCH PORT DATE 6 3401 3072 47 KBG2-LS DOMINTO 06/11/19 JMCVJMD GLV C/O (06/08/19) 06/08/19 5 5101 4079 54 KBG-2-LS OMY0826/18 4 6751 5070 52 KBG-2-LS SO06!08/19 3 8441 6069 54 KBG-2-LS OMY0826/18 2 10094 7067 52 KBG-2-LS 01,11'0826/18 1 11543 7964 50 KBG-2-LS DMY0826/18 11�--13.70' HES X DEPLOY SLV, D=3.00 - =3.00'11587 1158Z 2-7/8' X Ip, D = 2.31' 1 3-12"x14P,11)=2.813• 4-1/2' FES X NIP, ID = 3,81- .81"3-1/2'x3-3/16°XO, 1160T 11609' 06104/19 JMD ORLG HO CORRECTIONS 3-1/2' X 3-3/16' XO,ID=2.786^ 06/10/19 KPT.NJMD PE3RFS (06/06/19) .875' 11620' 7'X4-1/2"BAKER SS -3 PKR ID=3.875- HESX NIP, D=3.81' 11848' ELMD TT LOGGED 12/12/97 IBAKERZXPPKR/HGRI 14-12" HES X MP. ID = 3.813' 1 MILLOUT WINDOW (E -100A) 12988' - 12996' DATE REV BY COMVENTS DATE REV BY COMMENTS 12/15197 ORIGINAL COMPLETION 06/12/19 TWJMD FMLODEAPPROVAL 0528/19 N-CDR2 CTOST(E-100A) D827/19 JNL/JMD CORREICTED TOPOF PISA 06104/19 JMD ORLG HO CORRECTIONS 06/10/19 KPT.NJMD PE3RFS (06/06/19) 06/11/19 JMG/JMD SEI LTP w/PISA B CCLL&X NP 06/11/19 JMCVJMD GLV C/O (06/08/19) MIDNIGHT SUN UNIT WELL: E100A PERMIT No: 218-157 AR No: 50-029-22819-01 SEC6, T11 N, R14F 5000' NSL & 500' WT3 BIP Exploration (Alaska) Printed 6/26/2019 9:42:07AM ''All dephts reported in Drillers Depths" North America - ALASKA - BP Page 1 of 15 Operation Summary Report Common Well Name: E-100 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/14/2019 End Date: 5/26/2019 X3 -019C7 -C: (1,935,703.00 ) Project: PBU Site: E Rig Name/No.: CDR -2 Spud DateRme: 10/25/1997 12:00:OOAM Rig Release: 5/28/2019 Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00000716 Active datum: KB @71.00usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ (usft) 5/14/2019 0000 - 0300 3.00 MOB P PRE FINISH RIG DOWN HOLD PJSM FOR RIG MOVE PULL RIG OFF WELLAND MOVE TO SIDE OF PAD FOR SWAPPING CT REELS. 03:00 - 06:00 3.00 MOB P PRE SWAPCOILTUBING REELTO23/8"COIL 06:00 - 10:00 4.00 MOB P PRE INSTALL REEL HARDLINE. 10:00 - 13:00 3.00 MOB P PRE PJSM WITH NABORS AND PEAK CREW FOR MOVING OVER WELL. MOVE SUB OVER WELLAND SET DOWN. MOVE PIT MODULE NEXT TO SUB AND SET DOWN. ACCEPT RIG AT I3'. 00. 13:00 - 17:00 4.00 MOB P PRE CYCLE TREE VALVES, LEAVE MASTER OPEN FOR THERMAL EXPANSION. START R/U CHECKLISTS. PREP TO STAB PIPE. INSTALLGRAPPLE. REMOVE SHIPPING COVER FROM REEL. STAB PIPE 17:00 - 00:00 7.00 MOB P PRE PJSM AND REVIEW PROCEDURE FOR .INSTALLING CONNECTOR. INSTALL COIL CONNECTOR AND PULL TEST TO 50K LEAK TIGHT TEST MASTER AND SWAB VALVE TO 3500 PSI -GOOD TEST REMOVE TREE CAP NIPPLE UP BOPS RECONFIGURE TEST JOINT FOR 2 31S COIL COMPLETE RIG UP CHECKLIST BRING DRILLING FLUIDS ONTO RIG. INSTALL UQC WITHOUT FLOATS 5/15/2019 00:00 - 01:00 1.00 RIGU P PRE HELD PRE SPUD AND H2S DRILL WITH MICAH BUSHES CREW 01:00 - 02:00 1.00 RIGU P PRE MAKE UP NOZZLE TO COIL, INSTALL LUBRICATOR ON BOTTOM OF INJECTOR, MAKE UP INJECTOR 0200 - 0500 3.00 RIGU P PRE PURGE SURFACE LINES AND COIL WITH WATER, GREASE TREE VALVES, T1 AND T2 VALVES AND TORQUE TREE BOLTS, SHELL TEST BOPAND MUD PUMP 2 TO 250/4000 PSI. Printed 6/26/2019 9:42:07AM ''All dephts reported in Drillers Depths" North America -ALASKA - BP Page 2 of 15 Operation Summary Report Common Well Name: E-100 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/14/2019 End Date: 5/26/2019 X3 -019C7-0 (1,935,703.00 ) Project PBU Site: E Rig Name/No.: CDR -2 Spud Date/Time: 10/25/1997 12:00:OOAM Rig Release: 5/28/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000716 Active datum: KB @71.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Desonpbon of Operations __. _.. (hr) (usft) - 05:00 - 15:00 10.00 BOPSUR P PRE 15:00 - 19:30 4.50 RIGU P PRE 19-.30 - 21:45 2.25 RIGU P PRE Primed 6/26@019 9:42:07AM "All dephts reported in Drillers Depths" TEST BOPS AS PER AOGCC AND BP STANDARDS. TEST IS WITNESSED BY WSLAND TOOLPUSHER, AOGCC HAS WAIVED WITNESS. ALL TESTS TO 250 / 3500 PSI. TEST 1: IRV, RACKOFF, C9, CIO BACKWARDS -PASS TEST2: BLIND /SHEARS,RI,BLIA,BI,B4- PASS TEST 3: ANNULAR (2-3/8"), TIW1, 03, B2, BL1 - PASS TEST 4: UPPER 2-3/8" PIPE / SLIPS, TIW2, SL2, R2, T2, C75 - FAIL ON PIPE / SLIPS, CARRY ON WITH TESTING THE OTHERS. WILL CHANGE OUT UPPER 2-3/8" PIPE / SLIPS AND RE -TEST. - TESTS: C16, T7, C11 -PASS TEST 6: VBR (2-3/8"), C7, C9, C10, TV2 - FAIL ON C7. GREASE AND RE -TEST, PASS. TEST 7: LOWER 2-3/8" PIPE / SLIP, C5, C6, C8, TV1-PASS ',TEST B: CHOKE A, C -PASS TEST 9: ANNULAR (3-1/2"), Cl, C4 - PASS TEST 10: VBR (3-1/2") C2, C3 - PASS PJSM TO SWAP OUT UPPER 2-3/8" PIPE / SLIP RETEST UPPER 2-3/8" PIPE / SLIP - PASS RD TEST EQUIPMENT -SWAP OUT LUBRICATORS - INSTALL BHI CVS - PT THE CTC & UQC - STAB ON WELL, PT THE LUBRICATOR AND CHECK VALVES -GOOD TEST ON THE LUBRICATOR -PUMP SLACK FORWARD FOR ONE COIL VOLUME AT 2 BPM AT 1400 PSI -BREAK OFF INJECTOR AND RIG UP TEST PLATE AND TEST CHECK VALVES PULL TWC -HOLD PJSM WITH CREW AND REVIEW PROCEDURE -MOBILIZE LUBRICATOR AND EQUIPMENT TO RIG FLOOR. -MAKE UP PULLING TOOLAND MAKE LUBRICATOR UP TO WELL. -FLUID PACK STACK WITH METHANOL TO PT VC LUBRICATOR - WORK THROUGH COMMAND AND CONTROL VALVE CHECKLIST -PRESSURE UP TO 250 FOR VISUAL LTT - GOOD LOW GO TO 3700 HIGH PT -TIGHTEN MANIFOLD ON LUBRICATOR AND HOSE FITTING ON TEST PUMP. - GOOD PT, BLEED OFFAND OPEN UP TO TWC -TWC PULLED, WELL ON VAC - CLOSE M & S VALVES, LTT 3500 PSI CONFIRMED - REMOVE LUBRICATOR - LD TWC, BODY SEAL IS NOT ON PLUG, North America - ALASKA - BP Operation Summary Report Page 3 of 15 Common Well Name. E-100 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/14/2019 End Date: 5/26/2019 X3 -019C7 -C. (1,935,703.00 ) Protect: PBU Site:E Rig Name/No.. CDR -2 Spud DateTme: 10/25/1997 12:00:00AM Rig Release: 5/28/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000716 Active datum'. KB 071.00usR (above Mean Sea Level) Date From - To Firs Task Code NPT Total Depth Phase Description of Operations (hr) _. _ (usft) _ 21:45 - 00:00 2.25 RIGU P PRE WELL KILL -HOLD PJSM WITH CREW -MAKEUP NOZZLE BHA WITH CHECKS -MAKE UP INJECTOR AND TEST LUBRICATOR TO 3500 PSI -GOOD TEST -DISPLACE FRESH WATER FROM COIL WITH 15 BBL MEOH SPEAR FOLLOWED BY 8.4 PPG SLICK KCL -LINE UP TO TAKE RETURNS TO TIGER TANK -OPEN MASTER AND SWAB VALVE -0 PSI ON .WELL 5/16/2019 00:00 - 00:30 0.50 RIGU P PRE WELL KILL -PUMP 0.25 BPM 10.33 OUT AT 22 PSI WELL TOOK 5 BBLS TO FILL RIH TO 200' 00:30 - 01:00 0.50 RIGU P PRE -RIG MAINTENENCE -ADJUST ROLLERS ON HORSE HEAD -SECURE INNER REEL IRON -ADJUST COUNTER WHEELS -GREASE HORSE HEAD -TIGHTEN SADDLE CLAMPS ON REEL HUB 01:00 - 06:30 5.50 KILLW P 12,992.00 PRE WELL KILL -PUMP 0.25 BPM / 0.33 OUT AT 22 PSI at 20 FPM -PUMP 0.25 BPM / 0.56 OUT AT 22 PSI at 60 FPM -RIH FROM 200' TO 10300' -MAINTAINING 1 FOR 1 RETURNS NOTE: INITIAL WELL ENTRY WITH NEW COIL RUN AT 60 FPM. NOTE AT 6000' STOP FOR 10 MINUTES AND CHECK TORQUE ON SADDLE CLAMPS - 05:50 TAG PINCH POINT AT 12992', PU WT= 62K - CLOSE CHOKE, CHECK SADDLE CLAMPS ON REELAND SUCK OUT TIGER TANK, NOT ENOUGH ROOM FOR BTM'S UP KILL Printed 6/26/2019 9:42:07AM **All dephts reported in Drillers Depths" Common Well Name. E-100 Event Type: RE-ENTER- ONSHORE(RON) Project: PBU Rig Contractor: NABORS ALASKA DRILLING IN Active datum: KB @71.00usft (above Mean Sea Date From - To Him _ (hr) 06:30 - 12:00 5.50 12:00 - 17:30 5.50 17.30 - 00'.00 6.50 North America -ALASKA - BP Page 4 of 15 Operation Summary Report Stan Date: 5/14/2019 End Date: 5/26/2019 Site: E Spud Date/Time: 10/25/1997 12:00:OOAM Task Code NPT Total Depth Phase (usft) KILLW P 12,992.00 PRE STWHIP - P -- STWHIP P 12,886.00 WEXIT AFE No Q -01 9C7 -C' (1,935,703.00 ) Rig Release: 5/28/2015 BPUOI: USA00000716 Description of Operations BOTTOMS UP KILL - PUMP 210 BBLS OF HOT KCL TO CONDITION WELL - SWAP TO 8.6 PPG MUD -CHOKE PACKED OFF AFTER 82 BBLS PUMPED, WHIP BLEEDING OFF, BLEED OFF RESIDUAL PRESSURE - LINE UP TO BLOW DOWN CHOKE - BACK ON LINE - BOTTOMS UP IS CLEAN, NO GAS ON FIRST CIRCULATION - SWAP TO 8.6 PPG MUD - TAG WS, MUD AT NOZZLE, PUH SLOW - BLEED OFF OA FROM 678 PSI TO 350 PSI -0.25 BBLS - 1.5 VOLUMES CIRCUALTED CLEAN RETURNS -MUD TO SURFACE, BRING RETURNS INSIDE, REDUCE RATE TO DRILLING RATE - SHUT DOWN PUMPAND FINGERPRINT BLEED OFF TO NO FLOW i- BLED OFF 1.0 BBLS IN 2:22 '- FLOW CHECK WELL - GOOD NO FLOW, POOH -- JOG IN HOLE AT SURFACE 100' - FLOW CHECK - GOOD NO FLOW, CREW CHANGEAND PJSM TO LD THE NOZZLE BHAAND MU THE MILLING BHA WINDOW MILLING OPS - LD NOZZLE BHA MU MILLING BHA - MU THE INJECTOR, PT THE OTS AND RIH - LOG TIE IN AT 12,680' - CORRECT DEPTH - 4', PU WT 50K RIH WT= 21K - CLOSE EDC AND RIH TO TAG - TAG AT 12981' WITH 4K WOB, PU 10' AND START MOTOR AND VERIFY PINCH POINT OR CMT TAG AT 12989.0' AND START MILLING WINDOW - FREE SPIN: 2620 PSI, 2.79 BPM - RATE: 2.79 BPM IN, 2.80 BPM OUT. CIRC PRESSURE: 3842 PSI - MUD WEIGHT: 8.61 PPG IN, 8.53 PPG OUT, ECD: 9.87 PPG - WEIGHT ON BIT 1- 3 K 12996.00 WEXIT TAG AT 12989.0'AND START MILLING WINDOW TO 12996 - FREE SPIN: 2620 PSI, 2.79 BPM - RATE: 2.79 BPM IN, 2.80 BPM OUT. CIRC PRESSURE: 3842 PSI - MUD WEIGHT: 8.61 PPG IN, 8.53 PPG OUT, ECD: 9.87 PPG - WEIGHT ON BIT 1- 3 K Printed 6/262019 9:42:07AM **All dephts reported in Drillers Depths** North America - ALASKA - BP Operation Summary Report Common Well Name: E-100 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 5!14/2019 End Dale. 5/262019 X3 -019C7 -C: (1,935,703.00 ) Proiect: PBU Site: E Page 5 or 15 Rig Contractor: NABORS ALASKA DRILLING INC. - 1230 5.00 DRILL P 1230 BPUOI: USA00000716 Active datum: KB C?71.00usft (above Mean Sea Level) DRILL P - CORRECT DEPTH -3', RIH TO TD AND DRILL BUILD_ Date From - To Hrs Task Code NPT Total Depth Phase Description or Operations . (hr) PRESSURE: 3463 PSI (usft) - ECD: 10.14 PPG, 185 PSI CHOKE PRESSURE 5/17/2019 00:00 - 01:45 1.75 WHIP P 13,006.00 WEXIT MILL WINDOWAND 10' RATHOLE TO 13006' - RATE: 2.93 BPM IN, 2.96 BPM OUT. CIRC PRESSURE: 3605 PSI - FREE SPIN: 2620 PSI, 2.79 BPM - ECD: 10.18 PPG, 95 PSI CHOKE PRESSURE - WEIGHT ON BIT 2- 3 K PROD1 - RATE: 2.79 BPM IN, 2.80 BPM OUT. CIRC -CHASE 10X10 PILLS TO THE WINDOW - PUMP 5X5 PILL FOR THE CASED HOLE PRESSURE: 3842 PSI IN CUTTING - CLEAN TRIP TO THE WINDOW �- MUD WEIGHT: 8.61 PPG IN, 8.53 PPG OUT, -PULL TO 11501 PERFORM CCL LOG NOTE: DURING CCL LOG SAT DOWN ON GLM ECD: 9.87 PPG WEIGHT ON BIT 1-3K _ 0145 - 0230 0.75 WHIP P 13,006.00 WEXIT CONDUCT CLEAN REAMING PASS UPAT1 FT/MIN CONDUCT CLEAN REAMING DOWN PASS AT TFT/MIN DRY DRIFT IS CLEAN, TAG AT 13008', PULL ABOVE WINDOW AND MINITOR WELL FOR 10 MINUTES STATIC. 02:30 - 07'.30 5.00 WHIP P 13,008.00 WEXIT POOH -OPEN EDC - MUD WEIGHT: 8.58 PPG IN, 8.53 PPG OUT - RATE: 2.51 BPM IN, 2.07 BPM OUT PRESSURE 2086 PSI NOTE KICK WHILE TRIPPING DRILL HELD WITH MICAH BUSH'S CREW. DRILL EXECUTED IN A TIMELY FASION WITH SHUT IN SIMULATED IN 1 MINUTE 38 SECONDS LOST 0.7 BBLS ON TOOH - FLOW CHECK WELL GOOD NO FLOW 0730 - 1230 5.00 DRILL P 1230 - 0000 11.50 DRILL P - LO BHA, MILLS GAUGED 3.80" GO 2.79" NO GO 13,006.00 PROD1 DRILL BUILD SECTION 13,335.00 5/18/2019 0000 - 0315 3.25 DRILL P 13,450.00 03.15 - 0815 5.00 DRILL P 13450.00 Printed 6/26/1019 9:42:07AM "All dephts reported in Drillers Depths" - BHA MU, STAB ON, PT THE OTS AND RIH - 11:00 - 11:20 STOP TO ADD SHIM TO ODS REELCLAMP - LOG TIE IN AT 12625' - CORRECT DEPTH -3', RIH TO TD AND DRILL BUILD_ PROD? DRILL BUILD FROM 13006' TO 13335' - FREE SPIN: 3377 PSI, 2.75 BPM - RATE: 2.75 BPM IN, 2.79 BPM OUT. CIRC PRESSURE: 3463 PSI - MUD WEIGHT: 8.63 PPG IN, 8.54 PPG OUT - ECD: 10.14 PPG, 185 PSI CHOKE PRESSURE _- WEIGHT ON BIT 1- 3 K PROD1 DRILL BUILD FROM 13335' TO 13450' - FREE SPIN: 3400 PSI, 2.93 BPM - RATE: 2.93 BPM IN, 2.96 BPM OUT. CIRC PRESSURE: 3605 PSI - MUD WEIGHT: 8.70 PPG IN, 8.62 PPG OUT - ECD: 10.18 PPG, 95 PSI CHOKE PRESSURE - WEIGHT ON BIT 2- 3 K PROD1 WIPER TRIP TO 11500 -CHASE 10X10 PILLS TO THE WINDOW - PUMP 5X5 PILL FOR THE CASED HOLE - FIRST 10X10 BROUGHT UP 20% INCREASE IN CUTTING - CLEAN TRIP TO THE WINDOW - LOG TIE IN, CORRECT DEPTH +4 -PULL TO 11501 PERFORM CCL LOG NOTE: DURING CCL LOG SAT DOWN ON GLM AT 11543' MD WITH 8K, ORIENT HIGH SIDE Printed 6/26/1019 9:42:07AM "All dephts reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 6 of 15 Common Well Name: E-100 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/14/2019 End Date. 5/26/2019 X3 -019C7 -C: (1,935,703.00 ) Project: PBU Site: E Rig Name/No.: CDR -2 Spud Datef-rime: 10/25/1997 12:00:OOAM Rig Release: 5/28/2019 Rig Contractor. NABORS ALASKA DRILLING INC. BPUOI: USA00000716 Active datum: KB @71.00usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usR) . 0815 - 1345 5.50 DRILL P 13,550.00 PROD? BUILD LANDED 1345 - 1700 3.25 DRILL P 17:00 - 21:30 4.50 DRILL 21:30 - 00:00 2.50 DRILL -DYNAMIC FLOW CHECK WELL - IN & OUT RATES ARE 1:1 - POOH CHASING 5X5 LHVP'S - JOG IN HOLE AT THE WINDOW REDUCE RATE TO 0.5 BPM AND PULL THROUGH WINDOW - OPEN EDCAND PUMP 5X5 LHVP'S OUT AND CHASE OOH - PUMP LHVP'S FOR THE 7' CASING AND SLOW DOWN WHILE PULLING THROUGH THE 7", JOG BACK DOWN 50' THEN POOH - OOH FLOW CHECK WELL - GOOD NO FLOW, PU INJECTOR AND INSPECT THE LAST 50'OF COIL 13,550.00 PROD1 FOUND GOUGES ON THE PIPE JUST ABOVE .THE CTC, LD BHAAND INSPECT PIPE INJECTOR OFF AT 12:35 - LD BUILD BHAAND BUILD LATERAL BHAAND HANG -13:45 CUT OFF CTC, CUT 11' OF COILAND 'RE -HEAD - PULL TEST CTC TO 50K - RE -HEAD BHI UQC PT CTC AND UQC 70 4200 PSI - GOOD PT, BLEED OFF AND PT THE DFCVS - GOOD TEST, RD TEST EQUIPMENT P 13,550.00 PROD1 DEPLOY LATER AL BHA P 5/19/2019 00'.00 - 0700 7.00 DRILL P -MU INJECTOR -SURFACE TEST MWD AND AGITATOR AT 2.3/2.8 BPM @ 2550/3270 PSI -RIH AND TIE IN AT 12360', CORRECTION d' -TURN OFF PUMPS, CLOSE EDC AND PASS THROUGH WINDOW WITH NO ISSUES -RIH 13,661.00 PROD1 DRILL LATERAL FROM 13550' TO 13661' - FREE SPIN: 3330 PSI, 2.7 BPM - RATE: 2.7 BPM IN, 2.73 BPM OUT. CIRC PRESSURE: 3520 PSI - MUD WEIGHT: 8 70 PPG IN, 8.62 PPG OUT - ECD: 10.01 PPG, 95 PSI CHOKE PRESSURE - WEIGHT ON BIT 1- 3 K _ 13,892.00 PROD1 DRILL LATERAL FROM 1366VTO 13892" - FREE SPIN: 3340 PSI, 2.68 BPM - RATE: 2.68 BPM IN, 2.68 BPM OUT. CIRC PRESSURE. 3400 PSI MUD WEIGHT: 8.70 PPG IN, 8.66 PPG OUT - ECD: 10.1 PPG, 40 PSI CHOKE PRESSURE - WEIGHT ON BIT 1- 3 K Printed 6/2612019 9:42:07AM **All dephts reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 7 of 15 Common Well Name: E-100 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/14/2019 End Date. 5/26/2019 X3 -019C7 -C: (1,935,703.00 ) Project: PBU Site: E Rig Name/No.: CDR -2 Spud Date/Time: 10/25/1997 12:00:OOAM Rig Release: 5/28/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000716 Active datum: KB @71.00usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) _ 0700 - 1000 3.00 DRILL P 14,000.00 PROD1 WIPER TRIP TO WINDOW - JOG 100' IN HOLE AT THE WINDOW -PULL THROUGH WINDOW, OPEN EDC - JET AT 4.0 BPM UP TO 7" TIMING PILLS TO CLEAN UP 7" - GETTING A LOT OF CUTTINGS WHILE RIH FROM ABOVE THE 7" - LHVP'S UNLOADING MORE CUTTINGS -50% INCREASE -LOG TIE IN - CORRECT DEPTH +5', CONTINUE TO CIRC • WITH EDC OPEN UNTIL SHAKER CLEANS UP - SHAKERS CLEANED UP, CLOSE EDC AND RIH TO CONTINUE DRILLING 10.00 - 2300 13.00 DRILL P 14,394.00 PROD? DRILL LATERAL FROM 14000' TO - FREE SPIN: 3378 PSI, 2.72 BPM - RATE: 2.72 BPM IN, 2.71 BPM OUT. CIRC PRESSURE: 3526 PSI - MUD WEIGHT: 8.73 PPG IN, 8.63 PPG OUT - ECP. 10.0 PPG, 40 PSI CHOKE PRESSURE -WEIGHT ON BIT 2-3.4K - DD NOT GETTING ENOUGH BUILD, REDUCE PUMP RATE TO 2.5 BPM -SWAP TO NEW MUD SYSTEM DUE TO SLOW ROP DECREASED WEIGHT TRANSFER WITH NOIMPROVEMENT. -PUMP 5X 5 HI/LO VIS SWEEP NOTE: LOST 300 PSI DIFFERENTIAL, SUSPECTAGITATOR FAILURE "'HOLD A KWD DRILL" CREW RESPNDED WELLTO THE DRILL, MORE INFO IN SAFETY COMMENTS 23.00 - 0000 1.00 DRILL P 14,394.00 PROD1 POOH -PERFORM DYNAMIC FLOW CHECK -NO GAINS OR LOSSES _ -POOH CHASING 5_X5 LHVP'S 5/20/2019 00.00 - 0430 4.50 DRILL P 14,394.00 PROD1 POOH - POOH CHASING 5X5 LHVP'S -JOG IN HOLE AT THE WINDOW - REDUCE RATE TO 0.5 BPM AND PULL THROUGH WINDOW - OPEN EDC AND PUMP 1 OX10 LHVP'S OUT AND CHASE OOH AT 4 BPM - PUMP LHVP'S FOR THE 7' CASING AND SLOW DOWN WHILE PULLING THROUGH THE 7", JOG BACK DOWN 50' THEN POOH - JOG 500' AT SURFACE - TEST AGITATOR AT SURFACE, 300 PSI PRESSURE DROP COMPARED TO INTIIAL TESTAND NO AGITATION FELT. -OOH FLOW CHECK WELL -STATIC - HOLD PJSM FOR BHA HANDLING - GOOD NO FLOW, PU INJECTOR AND INSPECT THE LAST 50' OF COIL Printed 6/262019 9:42:07AM **All dephts reported in Drillers Depths" Printed 6/262019 9:42:07AM '"All dephts reported in Drillers DepthY' North America - ALASKA - BP Pape 8 of 15 Operation Summary Report Common Well Name'. E-100 AFE No Event Type. RE-ENTER- ONSHORE (RON) Start Date: 5/14/2019 End Date. 5/26/2019 X3 -019C7 -C: (1,935,703.00 ) Project PBU Site. E Rig Name/No.: CDR -2 Spud Date/Tme: 10/25/1997 12:00:OOAM Rig Release: 5/28/2019 Rig Contractor NABORS ALASKA DRILLING INC. BPUOI: USA00000716 Active datum: KB @71.O1 (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) _ 04:30 - 09:00 4.50 DRILL P 14,394.00 PROD1 - INJECTOR OFF AT 04: 45 - LD MOTOR, AGITATOR AND BIT, HANG REST OF BHA - BIT GRADE 4-3 RUNG OUT - 05:00 CHANGE OUT PACK OFFS AND TEST - FLUID PACK WELLAND STACK THEN CLOSE SWAB VALVE, MONITOR WELL THROUGH MPL I- NO WHP, OPEN SWAB AND FLOW CHECK WELL - GOOD NO FLOW, PU TEST JOINTAND FUNCTION TEST BOPE -BOPE FUNCTION TESTED, DEPLOY DRILLING BHA _ 0900 - 1315 4.25 DRILL P 14,394.00 PROD1 RIH WITH DRILLING BHA - SHALLOW TEST AGITATOR .- GOOD TEST RIH - LOG TIE IN, CORRECT DEPTH :--3' CORRECTION CLOSE EDC AND RIH TO TO 1315 - 0000 10.75 DRILL P 14,643.00 PROD1 DRILL LATERAL FROM 14399 TO 14643' - FREE SPIN: 3575 PSI, 2.79 BPM RATE: 2.76 BPM IN, 2.76 BPM OUT. CIRC PRESSURE: 3926 PSI '- MUD WEIGHT: 8.65 PPG IN, 8.53 PPG OUT - ECD: 10.01 PPG, 39 PSI CHOKE PRESSURE - WEIGHT ON BIT 2.0 - 4.25K NOTE: HELD D2 KICK WHILE DRILLING DRILL WITH RYAN BEARD'S CREW. TIME TO SECURE WELL (SIMULATED) 1 MINUTE 34 SECONDS. FOR MORE DETAILS SEE RIGSITE _ SV&O REPORT. 5/21/2019 0000 - 0245 2.75 DRILL P 14,65200 PROD1 DRILL LATERAL FROM 14643 TO 14652" - FREE SPIN: 3575 PSI, 2.79 BPM - RATE: 2.76 BPM IN, 2.76 BPM OUT. CIRC PRESSURE: 3926 PSI - MUD WEIGHT: 8.65 PPG IN, 8.53 PPG OUT - ECD: 10.01 PPG, 39 PSI CHOKE PRESSURE - WEIGHT ON BIT 2.0 - 4.25K. Printed 6/262019 9:42:07AM '"All dephts reported in Drillers DepthY' North America - ALASKA- BP Operation Summary Report Page 9 of 15 Common Well Name: E-100 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 5/14/2019 End Date 5126/2019 X3 -019C7 -C3 (1,935,703.00 ) Project: PBU Site: E Active tlatum: KB @71.00usft (above Mean Sea Level) Date From - To Hrs Task (hr) 02:45 - 10:00 7.25 DRILL BPU01: USA00000716 Code NPT Total Depth Phase Description of Operations (usft) P 14,652.00 PROD1 POOH FOR SLOW ROP AND LOW 1330 DIFFERENTIAL 1.50 - PERFORM DYNAMIC FLOW CHECK -GOOD N - POOH CHASING 5X5 LHVP'S 1500 - JOG IN HOLE AT THE WINDOW 1.25 - REDUCE RATE TO 0.5 BPM AND PULL P THROUGH WINDOW 16:15 - OPEN EDC AND PUMP 10X10 LHVP'S OUT 0.25 AND CHASE OOH AT 4 BPM P - PUMP LHVP'S FOR THE T CASING AND SLOW DOWN WHILE PULLING THROUGH THE T', JOG BACK DOWN 50' THEN POOH - JOG AT SURFACE - CLOSE EDC AND TEST AGITATOR - FAILED - LASTAGITATOR FROM BHA #4 ONLY HAD 26 CIRCULATING HRS AND THIS AGITATOR ONLY HAD 15 CIRCULATING HRS - FLOW CHECK WELL - GOOD NO FLOW, TAG UPAND REMOVE THE INJECTOR -BIT GRADE =3-2 RO, BT - MU A NEW HYCALOG IMPACT 13MM CUTTER BITAND NEWAGITATOR - CIRC PORTS ON THE HOTARE STARTING TO WASH OUT, SWAP HOT'S - TEST OTS AND SHALLOW TEST AGITATOR 1000 - 1330 3.50 DRILL P 14,652.00 PROD? GOOD TEST ON AGITATOR - RIH - LOG TIE IN -CORRECT DEPTH -11', CLOSE THE EDC AND RIH TO BOTTOM _ PROD1 STOP RIH, PUMP #2 HAS A VALVE OR SEAT THAT IS WASHED OUT AND NEEDS TO BE REPLACED, POOH TO THE CASED HOLE - PUMP REPAIRED, PT PT PUMP TO 250 LOW AND 470OPSI HIGH PROD1 PUMP REPAIRED AND PRESSURE TESTED _- RIH TO CONTINUE DRILLING PROD1 DRILL LATERAL SECTION - FREE SPIN: 4178 PSI, 2.06 BPM - RATE: 2.60 BPM IN, 2.61 BPM OUT. CIRC PRESSURE: 4235 PSI - MUD WEIGHT: 8.69 PPG IN, 8.56 PPG OUT - ECD: 10.40 PPG, 30 PSI CHOKE PRESSURE - WEIGHT ON BIT 2.0 - 3.0 K Printed 6/26/2019 9.42o7AM **All dephts reported in Drillers Depths" 1330 - 1500 1.50 DRILL N 14,652.00 1500 - 16:15 1.25 DRILL P 14,652.00 16:15 - 16:30 0.25 DRILL P 14,646.00 - RIH - LOG TIE IN -CORRECT DEPTH -11', CLOSE THE EDC AND RIH TO BOTTOM _ PROD1 STOP RIH, PUMP #2 HAS A VALVE OR SEAT THAT IS WASHED OUT AND NEEDS TO BE REPLACED, POOH TO THE CASED HOLE - PUMP REPAIRED, PT PT PUMP TO 250 LOW AND 470OPSI HIGH PROD1 PUMP REPAIRED AND PRESSURE TESTED _- RIH TO CONTINUE DRILLING PROD1 DRILL LATERAL SECTION - FREE SPIN: 4178 PSI, 2.06 BPM - RATE: 2.60 BPM IN, 2.61 BPM OUT. CIRC PRESSURE: 4235 PSI - MUD WEIGHT: 8.69 PPG IN, 8.56 PPG OUT - ECD: 10.40 PPG, 30 PSI CHOKE PRESSURE - WEIGHT ON BIT 2.0 - 3.0 K Printed 6/26/2019 9.42o7AM **All dephts reported in Drillers Depths" Common Well Name: E-100 Event Type: RE-ENTER- ONSHORE(RON) Project: PBU Rig Contractor: NABORS ALASKA DRILLING INC. Active datum: KB @71.00usft (above Mean Sea Lr Date From - To Ars (hr) 16:30 - 23:30 7.00 North America - ALASKA - BP Page 10 of 15 Operation Summary Report Start Date. 5/14/2019 End Date. 5/26/2019 Site: E Spud Date/Time: 10/25/1997 12:00:OOAM Task Code NPT Total Depth (usft) DRILL N 14,648.00 2330 - 0000 0.5 R L P 5/22/2019 00:00 - 08:45 8.75 DRILL P 0845 - 1530 6.75 DRILL 15:30 - 1900 3.50 DRILL P P APE No K3 -019C7 -C (1,935,703.00 ) Rig Release: 5/28/2019 Phase Description of Operations PROD1 LOST PUMP 2 AGAIN, FOUND CRACK IN POD #2 AND WILL NEED TO BE REPLACED - DISCUSS OPTIONS WITH WSUPT AND ODE - MOBILIZE LRS AS A BACKUP PUMP TO CONTINUE OPS - CALL FOR ANOTHER VAC TRUCK TO SUPPORT THE LRS TRUCK IF THEY NEED TO PUMP - POOH TO ABOVE WINDOW AT 12950' - REPLACE FLUID END ON PUMP 2. SIMOPS: UPON ARRIVALAT 2230 HRS RIG UP LITTLE RED TO TIGER TANK TO FLUSH MEOH OUT OF LINES. RIG UP TO CUSTOMER VALVE ON RIG AND PRESSURE TEST TO 4700 PSI WITH WATER. HOOK UP VAC TRUCK WITH 270 BBLS OF 8.6 PPG QUICK DRILL N. SET MECHANICAL PRV TO 5000 PSI AND ELECTRONIC PRV TO 4700 PSI. - WITH LITTLE RED WITH LITTLE RED SERVICES RIGGED UP AND TESTED START 14,648.00 PRODt DRILL LATERAL - FREE SPIN: 4200 PSI, 2.06 BPM RATE: 2.60 BPM IN, 2.61 BPM OUT. CIRC PRESSURE: 4300 PSI - MUD WEIGHT: 8.69 PPG IN, 8.56 PPG OUT ' - ECD: 10.40 PPG,O PSI CHOKE PRESSURE -WEIGHT ON BIT 2.0-3.0K SIMOPS-CONTINUE WORKING ON MP FLUID END, PRESSURE TEST SAME TO 4500 PSI AT 2330 HOURS 14,732.00 PROD? DRILL LATERALFROM 14648'-14732' - FREE SPIN: 4250 PSI, 2..6 BPM - RATE: 2.62 BPM IN, 2.62 BPM OUT. CIRC PRESSURE: 4350 PSI - MUD WEIGHT: 8.69 PPG IN, 8.56 PPG OUT - ECD: 10..1 PPG, 0 PSI CHOKE PRESSURE - WEIGHT ON BIT 2.0 - 3.0 K 14,770.00 PROD1 NO PROGRESS IN 2 -HRS, POOH TO CHECK THE BIT - DYNAMIC FLOW CHECK WELL - GOOD FLOW CHECK, POOH PUMPING PILLS FOR THE 7" - JOG IN HOLE AT SURFACE - CLOSE THE EDC AND SHALLOW TEST THE AGITATOR - GOOD AGITATOR TEST - FLOW CHECK WELL 14,770.00 PRODi GOOD NO FLOW, PU THE INJECTOR AND PULLTHEBHA - BHA PULLED AND THE BIT IS RUNG OUT ON THE NOSE AND THE SHOULDER OF THE BI -CENTER WING. - MU HYC E2 IMPACT CUTTER BITAND RIH - LOG TIE IN WITH -7' CORRECTION Printed 6/26/2019 9:42:07AM **All dephts reported in Drillers Depths" North America - ALASKA - BP Page 11 of 15 Operation Summary Report Common Well Name: E-100 OPEN EDC AT WINDOW 0230 - 0830 6.00 DRILL P 14,840.00 APE No Event Type: RE-ENTER- ONSHORE(RON) Start Date. 5/14/2019 End Date: 5/26/2019 X3 -019C7-0 (1,935,703.00) Project: PBU Site: E VERIFY HYCALOG DOES NOT HAVE Rig Name/No.: CDR -2 Spud DateTme: 10/25/1997 12:00:OOAM Rig Release: 5/28/2019 Rig Contractor: NABORS ALASKA DRILLING INC. -GOOD NO FLOW, LD BHA, MU USED BPUOI: USA00000716 Active datum: KB @71.00usft (above Mean Sea Level) BHA Date From - To HIM Task Code NPT Total Depth Phase Description of Operations (hr) _ _ _ (usft) _ 1900 - 2300 4.00 DRILL P 14,827.00 PROD1 DRILL 4-1/4" LATERAL FROM 14770'MD 23:00 - 0000 1.00 5/23/2019 0000 - 01:30 1.50 DRILL DRILL 01:30 - 0230 1.00 DRILL P 14,83100 PROD1 P 14,840.00 PROD1 P 14,840.00 PROD1 - FREE SPIN: 4100 PSI, 2.49 BPM - RATE: 2.50 BPM IN, 2.50 BPM OUT. CIRC PRESSURE: 4100-4300 PSI MUD WEIGHT: 8.69 PPG IN, 8.56 PPG OUT, ECD: 10.4 PPG - ROP: 20 FT/HR, WOB: 2-3 KLBS START BRINGING LOVIS TO HELP WITH PRESSURES. DRILL 4-1/4" LATERAL FROM 14827' MD - FREE SPIN: 3930 PSI, 2.78 BPM RATE: 2.78 BPM IN, 2.78 BPM OUT. CIRC PRESSURE: 3825- PSI - MUD WEIGHT: 8.69 PPG IN, 8.56 PPG OUT, ECD: 10.07 PPG - ROP: 20 FT/HR, WOB: 2-4 KLBS -ROP FALLING OFF, CONTINUE TO INCREASE PUMP RATE AS WE GET MUD THINNED BACK. DRILLING AHEAD ROP DOWN TO UNDER 9 FPH. CHERT IN SAMPLE BETWEEN 40 AND 60%. STACKING UPWARDS OF 4K ON BIT WITH - LITTLE TO NO MOTOR WORK. PERFORM 10 MIN DYNAMIC FLOW CHECK. GOOD FLOW CHECK. POOH TO INSPECT CONDITION OF BIT Printed 6/26/2019 94'.07AM "All dephts reported in Drillers Depths- OPEN EDC AT WINDOW 0230 - 0830 6.00 DRILL P 14,840.00 PROD1 POOH - MUD WEIGHT: 8.70 PPG IN, 8.56 PPG OUT - RATE: 3.91 BPM IN, 3.73 BPM OUT - SHALLOW TEST AGITATOR - NOT WORKING, VERIFY HYCALOG DOES NOT HAVE ANOTHER ON - FLOW CHECK WELL -GOOD NO FLOW, LD BHA, MU USED AGITATOR AND TEST BEFORE MU TO THE BHA - TESTED OK, MU THE BHA 08'.30 - 1230 4.00 DRILL P 14,840.00 PROD? -RIH WITH DRILLING BHA l)8 - SHALLOW TEST AGITATOR AT 2.5 & 2.8 BPM (2705 PSI & 3159 PSI) - LOG TIE IN -CORRECT DEPTH-14'AND RI_H 12:30 - 1800 5.50 DRILL P 14,899.00 PROD? DRILL LATERAL PU Wr=53K DRILL 4-1/4" LATERAL FROM 14770' MD - FREE SPIN: 3470 PSI, 2.76 BPM - RATE: 2.77 BPM IN, 2.78 BPM OUT. CIRC PRESSURE: 3468-3600 PSI - MUD WEIGHT: 8.68 PPG IN, 8.58 PPG OUT, ECD: 10.18 PPG - ROP: 18 FT/HR, WOB: 1-2.5 KLBS - ESTABLISH CUTTING PATTERN FOR THIS BIT THEN START APPLYING MORE WOB - DRILLED -35-40' OF Z3 AND LOOKS LIKE WE ARE IN Z4 NOW AT 14780' Printed 6/26/2019 94'.07AM "All dephts reported in Drillers Depths- Rig Contractor: NABORSALASKA DRILLING INC. North America - ALASKA - BP Page 12 of 15 Operation Summary Report Common Well Name: E-100 AFE No Event Type. RE -ENTER -ONSHORE (RON) Start Date 5/14/2019 End Date: 5/26/2019 X3 -019C7 -C: (1,935,703.00) Project: PBU Site: E Rig Name/No.: CDR -2 Spud Date/Time: 10/25/1997 12:00:OOAM Rig Release: 5/28/2019 Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00000716 Active datum: KB ID71.00usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 18:00 - 2030 2.50 DRILL P 14,899.00 PROD1 DRILL 4-1/4" LATERAL INCREASE RATES, AGITATOR DOES NOTAPPEAR TO BE WORKING - FREE SPIN: 3793 PSI, 3.00 BPM - RATE: 3.00 BPM IN, 2.99 BPM OUT. CIRC PRESSURE: 3793-3853 PSI - MUD WEIGHT: 8.69 PPG IN, 8.57 PPG OUT, ECD: 10.29 PPG -ROP: 8-26 FT/HR, WOB: 1.5-2.5 KLBS - DRILLING BREAKAT 14901' ROP WENT FROM 6 TO 26 FPH 2030'. - 2230 2.00 DRILL P 14,975.00 PROD1 DRILLING AHEAD. CHERT PERCENTAGE INDICATIVE OF ZONE 4, LESSTHAN2%. - AT 14932' STARTED LOSING FLUID. AT 14937' WELL HAD TAKEN A 5 BBL DRINK. _____ CONTINUED DRILLING AHEAD. 2230 - 0000 1.50 DRILL P 14,995.00 PROD1 ROP CONTINUING TO DECLINE MAINTAINING 3 5 TO 4K AND GETTING 5/24/2019 0000 - 0030 0.50 MINIMAL MOTOR WORK DRILL P 14,995.00 PROD1 ROP HAS FALLING OFF TO UNDER 3 FPH. PERFORM 10 MIN DYNAMIC FLOW CHECK .OFF BOTTOM. WELL STATIC 00:30 - 04:30 4.00 DRILL P 14,995.00 PROD1 POOH - MUD WEIGHT: 8.73 PPG IN, 8.59 PPG OUT _ - RATE: 4.02 BPM IN, 3.69 BPM OUT 04:30 - 05:00 0.50 DRILL P 14,995.00 PROD? - SHALLOW TEST AGITATOR AT MULTIPLE 05:00 - 11:00 6.00 DRILL P 11:00 - 18:00 7.00 DRILL P RATES. DIFFERENTIAL NEVER WENTABOVE 537#. 2.5 BPM TO 3.1 BPM. (NO GOOD) MONITOR WELL FOR 10 MINUTES AT BHA: STATIC -INJECTOR OFF: 0515 14,995.00 PROD? - BREAK OFF MOTOR. SCRIBE MOTOR MU BIT AND DEPLOY BHA - MU INJECTOR TO BHA - PT THE QTS, SHALLOW TEST THE AGITATOR AND RIH LOG TIE IN - CORRECT DEPTH AV AND RIH TO TO 15,197.00 PROD1 DRILL 4-114" LATERAL - FREE SPIN: 3866 PSI, 2.72 BPM - RATE: 2.72 BPM IN, 2.70 BPM OUT. CIRC PRESSURE: 3793-3853 PSI - MUD WEIGHT: 8.71 PPG IN, 8.59 PPG OUT, ECD: 10.32 PPG - ROP: 49 FT/HR, WOB: 1.5 - 2.5 KLBS - STACKING WT AT 15,036' PU A LITTLE RATTY, RIH AND STACKED OUT, PU AND PULLED 12K OVER, - DRILLED TO 15,150', PU TO 14900' ABOVE THE POSSIBLE FRACTURE TO MAKE SURE ITS CLEAN BEHIND US AFTER PULLING HEAVYAND STACKING WT BELOW IT - SHORT WIPER WAS CLEAN, RIH AND CONTINUE DRILLING - 15165 LOOKS LIKE WE MIGHT BE IN THE SHUBLIK - NOTABLE TO KEEP WOB, INCREASED RATE AND SAME, REDUCE RATE TO 2.4 WHERE WE SAW A LITTLE MORE ACTION FROM THE AGITATOR ON THE SURFACE TEST - 2.4 BPM IS WORKING TO KEEP WOB Printed 8/26/2019 9:42:07AM **All dephts reported in Drillers Depths" NorthAnterica- ALASKA - BP Operation Summary Report Common Well Name. E-100 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 5/14/2019 End Date. 5/26/2019 X3 -019C7 -C: (1,935,703.00 ) Project: P Site: E Rig Name/No.: CDR -2 Spud Date/Time: 10/25/1997 12:00:OOAM Ria Release: 5/28/2019 Page 13 of 15 Rig Contractor: NABORS ALASKA DRILLING INC. Active datum: KB @71.00usft (above Mean Sea Level) BPUOI: USA00000716 Date From - To Him Task Code NPT Total Depth Phase Description of Operations - (hr) _. _ _ (usft) 18:00 - 19:00 1.00 DRILL P 15,197.00 PROD1 DRILL 4-1/4' LATERAL WEIGHT TRANSFER GETTING WORSE. PREP FOR MUD SWP - FREE SPIN: 3286 PSI, 2.80 BPM - RATE: 2.80 BPM IN, 2.80 BPM OUT. CIRC PRESSURE: 3980-4064 PSI - MUD WEIGHT: 8.75 PPG IN, 8.64 PPG OUT, ECD: 10.36 PPG ROP: 15-20 FT/HR, WOB_ 2.3 - 3.30 KLBS _ 1900 - 0000 5.00 DRILL P 15,265.00 PROD1 WEIGHT TRANSFER BECOMING ISSUE. STICK SLIP PERFORM MUD SWAP DRILL 4-1/4' LATERAL - FREE SPIN: 3286 PSI, 2.80 BPM - RATE: 2.80 BPM IN, 2.80 BPM OUT. CIRC PRESSURE: 3980 - 4064 PSI - MUD WEIGHT: 8.63 PPG IN, 8.54 PPG OUT, ECD: 10.40 PPG - ROP: 15-20 FT/HR. WOB: 2.3 - 4K KLBS - HAVING TO ADJUST RATES TO KEEP _ AGITATOR WORKING. 5/25/2019 00:00 - 07:45 7.75 DRILL P 15,364.00 PRODt DRILL 4-114" LATERAL - FREE SPIN: 3286 PSI, 2.80 BPM -RATE: 2.80 BPM IN, 2.80 BPM OUT. CIRC PRESSURE: 3980-4064 PSI - MUD WEIGHT: 8.66 PPG IN, 8.55 PPG OUT, ECD: 10.43 PPG - ROP: 15 FT/HR, WOB: 2.3 - 4K KLBS ERRATIC DRILLING. - DRILLED OUT OF THE SHUBLIK- 15371' AND _ WE ARE SEEING BETTER ROP AND GAMMA 0745 - 1200 4.25 DRILL P 1 15,465.00 PROD? WIPER TRIP TO WINDOW - DRILLED 465' SINCE LAST WIPER, LAST PU WE STACKED OUT GOING BACK TO BOTTOM, VERIFY WELL IS CLEAN BEHIND US BEFORE DRILLING TO TO -JOG IN HOLE AT WINDOW, PULL THROUGH AND OPEN EDC, PUH TO JET 7" AND PUMP 5X5 PILLS FOR 7" - SAW MAYBE A 20% INCREASE IN CUTTINGS WHEN WE BROUGHT OUR RATE UP TO 4.0 BPM, PILLS DID NOT HAVE ANY INCREASE IN CUTTINGS - LOG TIE IN, CORRECT +8', CLOSE EDC AND RIH 12:00 - 13:00 1.00 DRILL P 15,465.00 PROD? DRILL 4-1/4" LATERAL j - FREE SPIN: 3778 PSI, 2.80 BPM - RATE: 2.80 BPM IN, 2.80 BPM OUT. CIRC PRESSURE: 3778 - 4110 PSI - MUD WEIGHT: 8.70 PPG IN, 8.62 PPG OUT, ECD: 10.59 PPG ROP: 50 FT/HR, WOB: 2.5 - 3.5K KLBS Printed 6/26/2019 9:42:07AM **All dephts reported in Drillers Depths" North America -ALASKA -BP Operation Summary Report Common Well Name: E-100 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/14/2019 End Date. 5/26/2019 Project: PBU Site: E K3 -019C7 -C: (1,935,703.00 ) Page 14 of 15 Rig Contractor. NABORS ALASKA DRILLING INC. Active datum: KB Q71.00usft (above Mean Sea Level) BPUOI: USA00000716 Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 13:00 - 21:30 8.50 DRILL P 15,540.00 PROD1 GEO'S CALLED TD AT 15,540' DRILL- ALLOW WOB TO OFF THEM POOH FOR FIRST OF 2 WIPER TRIPS - OPEN EDC AND PUMP AT MAX RATE ACROSS WS TRAY AND UP INTO THE 7" - PULLED TO 11465' BIT DEPTH AND RIH - LOG TIE IN WITH A+4' CORRECTION, RIH TO WINDOW - CLOSE EDC AND RIH TO CONFIRM TO - SET DOWN AT 15360', PU AND RIH AND SET DOWN AGAIN, NO MOTOR WORK, PU AND DRAGGING SOMETHING UPALONG THE BHA THEN PULLED FREE. PU 30' THEN BRING PUMP BACK ONLINE AT 2.5 BPM RIH AT 20 FPM ,- RAN PAST WITH 1 BOBBLE IN WTAT SHALLOWER DEPTH - TAG ON DEPTH AT 15540', POOH AT MAX RATE - PULLED 1.4K AT BIT AT 15381', 15363' - PULLED 6.5KAT 15335' THROUGH SHUBLIK. - CONTINUE TO PULLAT 15 FPM TILL INTO HORIZONTAL. INCREASE PULL SPEED TO 30 .FPM - PULL THROUGH WINDOW - JET WHIPSTOCK TRAY AT MAX RATE. JET UP THROUGH 7". CIRCULATED BOTTOMS UP. NO SIGNIFICANT CUTIINGS ON BOTTOMS UP 21:30 - 00:00 2.50 DRILL P r 15,540.00 PRODI DISCUSS STRATEGY WITH ODE. LOG TIE IN WITH +41 CORRECTION CLOSE EDC. RIH AT MINIMUM RATE BOBBLE AT 15144, AND 15343' TAG AT 15540' PUH THROUGH SHUBLIKAT MIN RATE. BOBBLES AT SAME DEPTHS. RUNBACKTO BOTTOM. BOBBLES COMING THROUGH AT MIN RATE. BOBBLES GOING BY THE 15335 TO 15339 AREA. LAY IN LINER RUNNING PILL 5/26/2019 0000 - 01:30 1.50 DRILL P 15,540.00 PROD1 LAY IN BEADS - 0.75 BPM IN RATE 0.53 BPM OUT -PULL 72KAT 15414'. POPPEDTHROUGH. COIL CONNECTOR AT 15330' NOTHINGSEEN ON WOB INDICATOR - PULL 68KAT 15336'. POPPED THROUGH. 6K SEEN ON WOB INDICATOR. SAME PLACE AS BEFORE. - DISCUSS WITH ODE. HAD NO SIGNIFICANT OVERPULLS WHEN RATE WAS DROPPED TO MINIMUM. - NO MORE ISSUES IN THE OPEN HOLE. PULL THROUGH WINDOW. OPEN EDC Printed 61262019 9:42:07AM ••A8 dephts reported in Drillers Depths" North America - ALASKA - EP Operation Summary Report Common Well Name: E-100 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/142019 End Date: 5/26/2019 X3 -019C7 -C: (1,935,703 00 ) Project: PBU Site: E Page 15 of 15 Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00000716 Active datum: KB @71.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations _ (hr) (usft) 01:30 - 0530 4.00 DRILL P 15,540.00 PRODi POOH - MUD WEIGHT: 8.72 PPG IN, 8.59 PPG OUT - RATE: 4.01 BPM IN, 3.83 BPM OUT - CIRC PRESSURE: 4016 PSI - PULLAT 40 FPM UP THROUGH THE 7" CASING - PAINT YELLOW TD FLAG AT 11362.56' BIT DEPTH (11278.63 EOP) - PAINT WHITE WINDOW FLAG AT 8810.25' BIT DEPTH (8726.32' EOP) -PULL TO 500', PERFORM BHA JOG - STOP AT 200'. CLOSE EDC. SHALLOW TEST AGITATOR. WORKING, BUT VERY WEAK _ SURFACERESPONSE. 05.30 - 07.30 2.00 DRILL P 15,540.00 PRODt MONITOR WELL FOR 10 MINUTES AT BHA: STATIC - CLOSE EDC, POWER DOWN - INJECTOR OFF: 06:15 BHA OOH - FUNCTION TEST ROPE END RON EVENT AND CONTINUE REPORT ON 'CON EVENT Printed 6/26/2019 9:42:07AM **All dephts reported in Drillers Depths" Printed 6/26/2019 9:42:45AM —All depths reported in Drillers Depths" North America - ALASKA - BP Page 1 of 5 Operation Summary Report Common Well Name. E-100 AFE No Event Type. COM -ONSHORE (CON) Start Date. 5/26/2019 End Date. 5/28/2019 X3 -019C7 -C'. (2,616,338.00 ) Project: PBU Site: E Rig Name/No.: CDR -2 Spud Date/Time: 10/25/1997 12:00:OOAM Rig Release: 5/28/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000716 Active datum: KB @71.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) _ 5/26/2019 0730 - 1630 9.00 CASING P 15.540.00 RUNPRD REEL OPS SIMOPS "RE -RIG HP REEL HOSE, BEND RADIUS IS TIGHTER THAN MANUFACTURE'S RECOMMENDATION (MIN IS RADIUS IS 36") "RD BHI UQC AND CUT FLAT SPOTABOVE CTC THEN REREAD, FLAT SPOT ABOVE THE CTC IS BELOW MINIMUMS (>20% WALL LOSS - 0.190 WALL WORN DOWN TO 0.128) AND WILL NEED TO BE CUT OUT - CUT 20' OF CT AND MU THE CTC - PULL TEST THE CTC TO 50K - PT CTC AND INNER REEL HOSE TO 250 LOW AND 4700PSI HIGH - RD TEST PLATE, PU 1 JT OF 2-3/8" PH6, STAB ON AND PUMP SLACK OUT - PUMPED 250' OF 331', WE HAVE 180+' OF PH6 TO ABSORB THE REMAINING ELINE - BOOT ELINE AND CHANGE PACKOFFS - STAB ON AND PT THE PACKOFFS - GOOD PT, LOAD 7/8" DRIFT BALL AND PUMP -BALLRECOVERED -PU INJECTOR, INSTALL TEST PLATE AND PT THE SWIVEL CONNECTION - GOOD TEST, RD TEST PLATE, MOVE INJECTOR BACK, RU RIG FLOOR TO RUN LINER 1630 - 0000 7.50 CASING P 15,540.00 ' RUNPRD RUN PRODUCTION LINER - MU SHOE TRACK WITH INDEXING GUIDE SHOE - MU 2-7/8" 13CR-85 LINER PER APPROVED SUMMARY. - SWAP HANDLING EQUIPMENT TO 3-1/4" -MU 3-1/4"13CR-85 PERAPPROVED SUMMARY LOSS 19.1 BBLS ON TRIP SO FAR 5/27/2019 00:00 - 02:30 2.50 CASING P 15,540.00 RUNPRD MAKEUP PRODUCTION LINER AS PER TALLY -MAKEUP LINER RUNNING TOOL AND 6 JOINTS OF 2-3/8" BTS -6 02:30 - 04:00 1.50 CASING P 15,540.00 RUNPRD PJSM FOR HANGING OFF LINER. DISCUSS STRIPPING OVER BHA - CLOSE BOTH PIPE RAMS. MAKE UP SWIVEL. - STRIP DOWN OVER BTS -6. - TEST QTS -PULL TEST TO 29K. BACK OUT LOCK DOWNS. OPEN RAMS Printed 6/26/2019 9:42:45AM —All depths reported in Drillers Depths" Common Well Name: E-100 Event Type: COM- ONSHORE (CON) Proiect: PBU North America - ALASKA - BP Page 2 of 5 Operation Summary Report AFE No Start Date: 5/26/2019 End Date: 528/2019 X3 -019C7 -C'. (2,616,338.00) Site: E Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000716 Active datum: KB @71.00usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations _ _ _ _ -(hr) _(usft) 04:00 - 09:00 5.00 CASING P 15,540.00 RUNPRD BREAK CIRCULATION RIH WITH LINER - RATE: 0.24 BPM IN, 0.50 BPM OUT. CIRC PRESSURE: 1812 PSI - MUD WEIGHT: 8.68 PPG IN, 8.62 PPG OUT - VERIFY LINER LEFT IN PIPE SHED, CORRECT JOINTS AND PUMPS '- STOPAT FLAG ELEC DEPTH = 12886.1' (EOP = 8710') CORRECT DEPTH -18.4' TO 12867.7 -PU WT=58K, RIH WT= 20K,RIH WITH LINER - SET DOWN AT 15244', PU (60-70K) RAN PAST CLEAN -SET DOWN AT 15337', PU (72K) RIH AND SET DOWN AT SAME DEPTH 2X, ONLINE WITH PUMP - SHUT DOWN PUMP, PU 72K MOVE Y THEN RIH, RAN PAST - SET DOWN AT 15399, ONLINE WITH PUMP, ZERO OUT MM TO MONITOR FOR BOTTOMS UP - SHUT DOWN PUMP, PU 70K MOVE 3' THEN RIH AND RAN PAST - YELLOW TO FLAG ON DEPTH AT 15420' - SET DOWN AT 15451', ONLINE WITH PUMP - SHUT DOWN PUMP, PU AND RIH CLEAN TO 15530' - PU AND TRY RIH LAST I0', SET DOWN AT 15525, LOST 5', ONLINE WITH PUMP - SHUT DOWN PUMP, RIH AND TAG AT SAME DEPTH, ONLINE WITH PUMP THEN TRY FEW MORE TIME TO GET THE LAST 13' - PU AND PULLED HEAVIER FROM 73 TO 78K A LITTLE RATTY - RIH AND START SETTING DOWN AT 15523 4' HIGHER THEN TAGGED AT 15530 AGAIN - ONLINE WITH PUMP AGAIN TO SEE IF WE CAN GET DEEPER - SHUT DOWN PUMP, PU IS CLEAN, RIH AND STARTED TAKING WT AGAIN AT 15527'. IT LOOKS LIKE BOTTOM OR THE SHALE AT TOE HAS SWELLED STOPPING US AT 15530' WITH tOK DOWN. CALL ODE AND DISCUSS. CALLED BOTTOM UNTIL LOGGED - ESTABLISH CIRCULATION 1:1, 0,351N 0.35 OUT AT 2157 PSI Printed 626/2019 9:42.45AM **All depths reported in Drillers Depths" - HOLD A PJSM WITH ALL CREW MEMBERS TO PERFORM VOLUME TEST 14.30 - 16'.00 1.50 CASING P 15,540.00 RUNPRD SHUT DOWN RIG PUMP, LINE UP SLB CMT VAN TO REEL -ONLINE WITH SLB, PUMP 610 BBL STAGES TO VERIFY RATE AND VOLUME FOR EACH STAGE - THE NABORS IN MICRO -MOTION WAS ONLY 0.09 BBLS OFF IN 60 BBLS - CALL SWSL NEWLON AND ODE HYATT AND DISCUSS RESULTS - BOTH AGREE TO USE THE RIG MICRO -MOTION FOR VOLUMES ALSO SUGGEST GOING BACK TO NORMAL CMT VOLUMES AFTER SEEING LOSSES WITH MUD ON THE BACKSIDE Printed 6262019 9:42:45AM "All depths reported in Drillers Depths" North America - ALASKA - BP Page 3 of 5 Operation Summary Report Common Well Name'. E-100 APE No Event Type: COM- ONSHORE (CON) Start Date: 526/2019 End Date 5/28/2019 X3 -019C7 -C'. (2,616,338.00) Project: PBU Site: E Rig Name/No.: CDR -2 Spud Date/Time: 1025/1997 12:00:OOAM Rig Release'. 5/28/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000716 Active datum: KB @71.00usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 09:00 - 14:30 5.50 CASING P 15,540.00 RUNPRD TOWN IS GOOD WITH WHERE WEAREABLE TO GET THE LINER DOWN TO AT THIS DEPTH - 15527' To PBTD = 15510', TOL = 11568' —17' BELOW GLM #1 ENOUGH FOR A LTP - GET UP AND DOWN WT'S AND VERIFY BALL DROP POSITION - PU WT = 70K AT 15513', SET DOWN 10KAT 15530' - PU TO BALL DROP DEPTH AT 15522' '- VERIFY BALL SIZE (5/8" STEEL) AND LOAD INTO REEL '- ZERO VOLUME TOTALS ON BOTH MICRO -MOTION METERS AND ORION - BALL CONFIRMED ROLLING, RATE IN = 1.78 BPM, RATE OUT 1.56 - BALL ON SEAT AT 53 BBLS, SHUT DOWN PUMP AT 4600 PSI, SHEARED AT 4520 PSI '- SHUT DOWN PUMP AND PU TO VERIFY WE ARE RELEASED - PU TO VERIFY WE ARE FREE, UP WT=6K PULLED T CLEAN AND STOPPED - SWAP WELL OVER TO KCL, RATE IN=2.4 BPM, OUT RATE = 2.03 BPM - KCLAT THE SHOE, LOSSES IMPROVING - KCL TO SURFACE IN 8 OUT RATES ARE 1:1 - PT CMT LINE TO 5000 PSI - HOLD A PJSM WITH ALL CREW MEMBERS TO PERFORM VOLUME TEST 14.30 - 16'.00 1.50 CASING P 15,540.00 RUNPRD SHUT DOWN RIG PUMP, LINE UP SLB CMT VAN TO REEL -ONLINE WITH SLB, PUMP 610 BBL STAGES TO VERIFY RATE AND VOLUME FOR EACH STAGE - THE NABORS IN MICRO -MOTION WAS ONLY 0.09 BBLS OFF IN 60 BBLS - CALL SWSL NEWLON AND ODE HYATT AND DISCUSS RESULTS - BOTH AGREE TO USE THE RIG MICRO -MOTION FOR VOLUMES ALSO SUGGEST GOING BACK TO NORMAL CMT VOLUMES AFTER SEEING LOSSES WITH MUD ON THE BACKSIDE Printed 6262019 9:42:45AM "All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: E-100 Event Type: COM- ONSHORE (CON) Start Date. 5/26/2019 End Date: 5/28/2019 Project: PBU Site: E Rig Name/No.: CDR -2 Spud Datei 10/25/1997 12:00:OOAM Rig Contractor: NABORS ALASKA DRILLING INC. Active datum: KB @71.O1 (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase (hr) (usft) 16:00 - 19:10 3.17 CASING P 15,540.00 RUNPRD 19:10 - 20:30 1.33 CASING P 15,540.00 RUNPRD Printed 6/26/2019 9 42 45A **All depths reported in Drillers Depths" Page 4 of 5 AFE No K3 -019C7 -C: (2,616,338,00) Rig Release: 5/28/2019 Description of Operations PJSM TO PUMP CMT WITH NAD, SLB AND JACOBS MIX AND PUMP 43.65 BBLS OF CEMENT: - RATE AT 1.5 BPM PRESSURE = 685 PSI CEMENT WETAT 16:13 HRS - 16:39 SWAP TO EXHAUST PILL, PUMP 5 BBLS THEN SHUT DOWN PUMP -16:42 SWAP TO SLB AND PUMP PUMPING 5 BBLS OF KCLAHEAD OF CMT - 16:46 ZERO IN MM ONCE DENSITY = 13.5 PPG, LOAD 43.65 BBLS 15.3 PPG CEMENT IN REEL - 17:09 43.65 BBLS AWAY SHUT DOWN PUMP, SWAP TO RIG PUMP. CLEANUP LINES TO SLB UNIT. - 1715 DISPLACE CEMENT WITH 1.5 PPG GEOVIS EXHAUST PILL, RATE: 2.65 BPM IN, 2.58 BPM OUT 2481 PSI - 17:31 87.4 BELS AWAY ZERO OUT MM WITH CEMENT AT SHOE, TAKE RETURNS TO PIT #2 (0.2 BBLS START VOL)FOR MANUAL STRAP - 17:36 100.8 BBLS AWAY SHUT DOWN PUMPS (OUT MM = 13.80 BELS) - 17:40 PICK UP TO BREAKOVER +16 FT PER BTT REP, EXPOSE DOGS, SET DOWN 10K AND LAUNCH PEE WEE DART. - 17:43 PRESSURE UP TO 1500 PSI TO LAND THE PEE WEE DART (PUMPED 0.50 BELS) - 17:44 PICK BACK UPAND SIDE EXHAUST 3 BBLS OF CEMENT AND 2 BBLS OF 1.5 PPG GEOVIS (PUMPED 6 BBLS) -17:49 OPEN PUMP BLEED, SET DOWN IOK. PRESSURE UP TO 2000 PSI ON WIPER PLUG AND ZERO IN MM - 17:59 LINER WIPER PLUG SHEARED AT 3900 PSI DISPLACE LINER WIPER PLUG - 18:00 DISPLACE AT 2.8 BPM: 3130 PSI - 18:20 PLUG BUMPED AT 27.32BBLS, 3586 PSI (27.10 BBLS CALCULATED) PRESSURE UP TO 4423 PSI - 18:11 OPEN PUMP BLEED AND CHECK FLOATS. GOOD TEST. CEMENT IN PLACE - OUT MM VOL = 43.16 BBLS - 5 BBLS = 38.16 BBLS BEHIND PIPE 4.1 BBLS OVER THE TOL - 115:21) CLUbt HUMP P L, PICK UP AND CONFIRM PRESSURE DROP - ONLINE AT 0.5 BPM TO CONTAM CMT AT TOL - RECIPROCATE AT LINER TOP WHILE CIRCULATING EXHAUST. - EXHAUSTED CEMENT WAS SEEN ON OUT MM WITH A LULL THEN CEMENT THAT CAME OVER LINER TOP WAS INDICATED WITHA DENSITY INCREASE 10.6. CIRCULATE REMAINING EXHAUST FLUID OUT. _ _ _ CIRCULATE WELLBORE OVER TO CLEAN 8.4 PPG 1% KCL - 2.93 BPM RATE IN 12.94 BPM OUT. 1:1 -CLEAN FLUID SURFACE TO SURFACE North America - ALASKA - BP Page 5 of 5 Operation Summary Report Common Well Name: E-100 AFE No Event Type: COM- ONSHORE (CON) Start Date. 5/26;2619 End Date: 5/28/2019 X3 -019C7 -G (2,616,338.00 ) Project: PBU Site' E rtig Namenvo.: UUK-Z bpuo Uate/lime 1U/2b/199/ 12:00:00AM Rig Release: 5/28/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000716 Active datum: KB @71.00usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations - __ _ III _. (usft) 20:30 - 21:00 0.50 CASING P 15,540.00 RUNPRD PERFORM 30 MIN FLOWCHECK - SIMOPS: RU LRS AND PT LINES -WELL REMAINED STATIC. NOTIFYODEAND _ ACTING WELL SUPERINTENDENT. 21:00 - 00:00 3.00 CASING P 15,540.00 RUNPRD PUMP REMAINING 30 BBLS OF 1.5 PPG GEOVIS PILL. TAIL WITH 8.4 PPG 1%KCL JETAREAABOVE LINER TOP WITH PILL THHEN CHASE OOH - MUD WEIGHT: 8.41 PPG IN, 8.41 PPG OUT - RATE: 2.81 BPM IN, 2.36 BPM OUT - CONTINUE OUT OF HOLE 5/28/2019 00'.00 - 01:30 1.50 01:30 - 0300 1.50 CASING P 15,540.00 ' RUNPRD POOH WHILE INSPECTING INJECTOR. CASING 0300 - 0430 1.50 CASING 04:30 - 14:00 9.50 RIGID DISCUSS WITH NABORS MECHANIC AND SUPERINTENDENT. _ PUH TO FREEZE PROTECT DEPTH. P 15,540.00 RUNPRD LOAD REEL WITH DIESEL WITH LRS. 2.89 BPM IN 12.89 OUT 6.81 PPG IN / 8.39 PPG OUT CLEAN DIESELTO SURFACE. j PERFORM 10 MIN FLOW CHECK WELL STATIC P 15,540.00 RUNPRD LAY DOWN LINER RUNNING EQUIPMENT 5/8" STEEL BALL RECOVERED - GREASE CREW SERVICED TREE P 15,540.00 POST START END OF WELL OPS - STAB ON AND PUMP SLACK BACK - PU INJECTOR, INSTALL PIPE CUTTER AN CUT 276' MAX - MU CTC, PULL TEST TO 50K - MU STINGER & NOZZLEAND PUMP SLAC FORWARD - HEAD UP BHI UQC - BLOW DOWN REELAND SURFACE LINES -CIRCULATE PITS & PIPING WITH FRESH WATER - CLOSE AND LTT THE MASTER & SWAB VALVES -GOOD PT, NO MPLAND BOPE - NU TREE CAP AND TEST -GOODTEST AT 14:00 HRS Printed 6/26/2019 9:42.45AM ••AJI depths reported in Drillers Depths" Daily Report of Well Operations E -100A ACTiviTYnATF SUMMARY TWO = 0/0/0. (Post CTD). Set 4" H TWC #440 @100" w/ Lubricator 840, Performed LTT on TWC (Pass). RD Target 90, RD CDR2 Tree, RU Upper Tree. PT'd against TWC 350/5000 PSI (Pass) Charted and Retained. Pulled 4" H TWC #440 @125". RDMO. ***Job 5/30/2019 Complete`**. FWPs = 0/0/0. CTU#8 1.5" CT. Job Scope: PT Liner Lap / Cont CBL / RPM Log /Adperf MIRU CTU 6/4/2019 ***Continue Job on 6/5/19 WSR*** CTU#8 1.5" CT. Job Scope: PT Liner Lap/ Cont CBL / RPM Log /Adperf Rig up CTU. Liner Lap Pressure Test Failed. Pressure climbed up to - 1650psi then broke over. LLR= 0.7bpm @ - 1580psi. No change in IA or OA during Pressure Test. RIH wl 2.25" Drift Nozzle. Tag TD at 15471' CTMD, PUH 50' and paint white TD flag. POOH. Make up HES RBT Cement Bond Log BHA and RIH. RIH to white flag and log two passes from TD to 11,300'. POOH. Confirm good data. Change pack offs and trim 100' of coil. 6/5/2019 ed on WSR 6-6-19_ 1.50" Coil, 0.109 wt ***Cont. from WSR 6-5-19*`* ctive: PT Liner lap, CBL, RPM log, Perforate RPM logging BHA and RIH. Tag TD and log up from compression from 15494' rrecovReoreMFORDMO. 12800', painting a tie-in flag at 14900'. POOH and send RPM data to town for tion. MU & RIH with HES 2" x 32' Maxforce gun. Perforate 14986'- 15018' with 2" e guns. POOH. Freeze protect well with 38 bbls 50/50 methanol. Shots fired and ered. RDMO. 6/6/2019 ***Continued on 6/7/19 WSR*** ***WELL SHUT IN ON ARRIVAL***(post ctd) RAN 2.25" CENT & 1.75" S-BLR. STOPPED DUE TO DEV @ 13,360' SLM. RAN KOT FOR CORRECTION RUN TO STA #1. 6/7/2019 **CONT ON 6-8-19 WSR"` CTU #8 - 1.50" Coil, 0.109 wt ***Cont. from WSR 6-6-19*** Complete rig down. 6/7/2019 ***Job Complete*** ***CONT FROM 6-7-19 WSR***(post ctd) RAN SBHPS PER PROGRAM. PULLED DMY INT-GLVS FROM STA#4 &6. SET LIVE VLV-INT IN STA#6 & S/O-INT IN STA#4. PULLED EMPTY CSUB FROM 11,562' SLM. 6/8/2019 ***CONT ON 6-9-19 WSR"* ***CONT FROM 6-8-19 WSR***(post ctd) RAN 45KB & PTSA DRIFT TO LINER TOP AT 11,580' MD. UNABLE TO GET ALL THE WAY IN. BRUSHED LINER WITH 3 1/2" BRUSH & TBG WITH 4 1/2" BL -BRUSH WHILE LRS PUMPED 50 BBLS OF CRUDE. RAN 45KB & PTSA DRIFT TO LINER TOP AT 11 580' MD. UNABLE TO GET ALL T WAY IN. SUCCESSFULLY DRIFTED INTO LINER TOP WITH XO & PTSAAT 11,580' MD. SET QCLL & PTSA IN LINER TOPAT 11,580' MD. SET 45KB IN PTSA QCLL (TOP @ 11570' MD) 6/9/2019 *`*CONT ON 6-9-19 WSR*** TWO= 69/0/8 Temp= S/I (LRS Unit 42 Assist Slickline: Load well to secure) Pumped 50 bbls of 70* crude down TBG for slickline to do brush -N -flush. Further pumped 22 bbls of 65* F crude down TBG to assist SL with getting down hole to set LTP. Continued on WSR 06-10- 6/9/2019 2019 Daily Report of Well Operations E -100A ** Continued From 6-9-19 WSR** (LRS Unit 42 Assist Slickline: MIT -T) MIT -T Passed @ 2357 psi. Target psi 2250 Max applied =2500 Pressured up TBG to 2479 psi with 3.8 bbls crude. 1 st 15 Min TBG lost 87 psi, 2nd 15 Min TBG lost 35 psi for a total loss of 122 psi in a 30 min test. Bled TBG to 300 psi and recovered - 4 bbls. Tags hung. Slickline in control of 6/10/2019 well upon departure. IA OA= OTG. Final WHP's= 300/0/0 ***CONT FROM 6-9-19 WSR***(post ctd) LRS OBTAINED PASSING MIT -T TO 2250#. PULLED 2 7/8" RSG PLUG FROM PTSA. 6/10/2019 ***WELL LEFT S/I ON DEPARTURE, PAD -OP NOTIFIED OF STATUS*** by North America - ALASKA - BP PBU E E-100 E -100A 500292281901 Design: E -100A Final Survey Report 31 May, 2019 � ea Company: North America - ALASKA - BP Project: PBU Site: E Well: E-100 Wellbore: E -100A Design: E -100A BP Final Survey Report Local Co-ordinate Reference: Well E-100 TVD Reference: KB @ 71.00usft MD Reference: KB @ 71.00usft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Project PBU, PBU, PRUDHOE Map System: Alaska NAD27 State Plane Zones System Datum: Mean Sea Level Geo Datum: NAD27' OGP-Usa AK [4267`15864] Using Well Reference Point Map Zone: NAD27.OGP-Usa AK/ Alaska zone 4[26734'1586• Using geodetic scale factor Site E, TR -11-14 Site Position: From: Map Position Uncertainty: 0.00 usft Well E-100, E-100 Well Position -NIS 0.00 usft +El -W 0.00 usft Position Uncertainty 0.00 usft Wellbore E -100A Northing: Easting: Slot Radius: Northing: Easting: Wellhead Elevation: 5,973,160.880 usft Latitude: 662,538.970 usft Longitude: 0.000 in Grid Convergence: 5,976,784.650 usft Latitude: 664,447.430 usft Longitude: 31.16 usft Ground Level: 70° 19' 59.134 N 148" 40'53.054 W 1.24 ° 70" 20'34.358 N 148° 39'55.015 W 28.96 usft Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2018 5/1/2019 16.90 80.95 57,430 Design E -100A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,950.00 Vertical Section: Depth From (TVD) +N/S +El -W Direction (usft) (usft) (usft) (°) 39.84 0.00 0.00 0.00 5/312019 2:28:59PM Page 2 COMPASS 5000.1 Build 81D BP Final Survey Report Company: North America - ALASKA - BP Inc Local Coordinate Reference: Well E-100 Project: PBU TVDSS TVD Reference: KB @ 71.00usft 390: E Easting MD Reference: KB @ 71.00usft Well: E-100 V) North Reference: True Wellbore: E -100A (usft) Survey Calculation Method: Minimum Curvature Design: E -100A (*1101 ft) Database: EDM R5K-Alaska PROD -ANCP1 Survey Program Date 5/31/2019 39.84 -31.16 From To 0.00 5,976,784.650 664,447.430 (usft) (usft) Survey (Wellbore) Tool Name Description 24.45 100.00 12,950.00 3: Gyrodata cont casing m/s (E-100) GVD-CT-CMS Gyrodala cont casing m/s 0.02 12,988.00 15,540.00 Survey #1(E -100A) MWD MWD -Standard 0.08 Survey MD Inc Azi TVD TVDSS WS EIW Northing Easting DLeg (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) (*1101 ft) 39.84 0.00 0.00 39.84 -31.16 0.00 0.00 5,976,784.650 664,447.430 0.00 100.00 0.05 24.45 100.00 29.00 0.02 0.01 5,976,784.674 664,447.440 0.08 200.00 0.49 278.58 200.00 129.00 0.13 -0.39 5,978,784.769 664,447.033 0.51 300.00 0.79 274.06 299.99 228.99 0.24 -1.50 5,976,784.857 664,445.921 0.30 402.00 1.36 271.28 401.97 330.97 0.32 -3.42 5,976,784.892 664,444.008 0.56 501.00 2.16 270.20 500.93 429.93 0.35 -6.46 5,976,784.858 664,440.968 0.81 601.00 3.20 269.90 600.82 529.82 0.35 -11.13 5,976,784.757 664,436.294 1.04 701.00 4.14 269.86 700.61 629.61 0.34 -17.53 5,976,784.803 664,429.895 0.94 800.00 4.81 272.24 799.31 728.31 0.49 -25.25 5,976,784.587 664,422.173 0.70 901.00 6.00 285.13 899.86 828.86 2.03 -34.58 5,976,785-925 664,412.815 1.68 1,000.00 7.89 297.66 998.13 927.13 6.54 -45.60 5,976,790.188 664,401.704 2.44 1,101.00 9.44 305.02 1,097.98 1,026.98 14.51 -58.52 5,976,797.874 664,388.609 1.88 1,201.00 11.24 307.39 1,196.35 1,125.35 25.14 -72.98 5,976,808.178 664,373.920 1.85 1,302.00 13.86 309.72 1,294.93 1,223.93 38.85 -90.11 5,976,821.509 664,356.496 2.64 1,350.00 15.00 311.52 1,341.42 1,270.42 46.64 -99.18 5,976,829.099 664,347.254 2.55 1,400.00 15.96 313.32 1,389.60 1,318.60 55.64 -109.03 5,976,837.886 664,337.214 2.15 1,450.00 16.47 315.29 1,437.62 1,366.62 65.40 -119.02 5,976,847.417 664,327.015 1.50 1,500.00 16.73 316.57 1,485.53 1,414.53 7566 -128.95 5,976,857.460 664,316.859 0.90 1,550.00 17.01 317.65 1,533.38 1,462.38 86.29 -138.83 5,976,867.871 664,306.755 0.84 1,600.00 17.31 318.43 1,581.15 1,510.15 97.26 -148.69 5,976,878.621 664,296.655 0.76 1,650.00 17.73 319.57 1,628.84 1,557.84 108.62 -158.56 5,976,889.762 664,286.535 1.08 V. Sec (usft) 0.00 0 02 0.13 0.24 0 32 0.35 0 35 0 34 0.49 2.03 6.54 14.51 25.14 38.85 46.64 55.64 65.40 75.66 86.29 97.26 106.62 513112019 2:28'59PM Page 3 COMPASS 5000.1 Build 81D BP by Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well E-100 Project: PBU TVD Reference: KB @ 71.00usft Site: E MD Reference: KB Q 71.00usft Well: E-100 North Reference: True Wellbore: E -100A Survey Calculation Method: Minimum Curvature Design: E -100A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi TVD TVDSS NIS EMI Northing Easting DLeg V. Sec (ush) (°) (°) (usR) (usR) (usR) (usft) (usft) (usR) (°1100usft) (usft) 1,700.00 18.18 320.62 1,676.40 1,60540 120,45 -168.45 5,976,901.366 664,276.393 1.11 120.45 1,750.00 18.98 321.62 1,723.79 1,652.79 132.85 -178.44 5,976,913.546 664,266.126 1.72 132.85 1,800.00 19.79 322.07 1,770.96 1,699.96 145.90 -168.70 5,976,926.367 564,255.592 1.65 145.90 1,850.00 20.33 321.73 1,817.93 1,746.93 159.40 -199.28 5,976,939.627 664,244.716 1.10 159.40 1,900.00 21.21 320.80 1,864.68 1,793.68 173.23 -210.38 5,976,953.208 664,233.320 1.88 173.23 1,950.00 23.31 320.17 1,910.95 1,839.95 187.83 -222.43 5,976,967.546 664,220.949 4.23 187.83 2,000.00 25.69 320.10 1,956.44 1,885.44 203.75 -235.72 5,976,983-164 664,207.314 4.76 203.75 2,050.00 27.69 320.88 2,001.11 1,930.11 221.08 -250.00 5,977,000.174 664,192.655 4.06 221.08 2,100.00 29.08 322.79 2,045.10 1,974.10 239.77 -264.68 5,977,018.537 664,177.571 3.32 23977 2,150.00 29.70 325.19 2,088.67 2,017.67 259.62 -279.10 5,977,038.063 664,162.721 2.66 259.62 2,200.00 29.75 326.60 2,132.09 2,061.09 280.14 -293.00 5,977,058.278 664,148.375 1.40 280.14 2,250.00 29.99 326.36 2,175.45 2,104.45 301.14 -306.39 5,977,078.974 664,134.534 1.82 301.14 2,300.00 30.44 329.93 2,218.65 2,147.65 322.74 -319.29 5,977,100.285 664,121.162 1.82 322.74 2,350.00 31.29 331.36 2,261-57 2,190.57 345.10 -331.86 5,977,122.360 664,108.105 2.25 345.10 2,400.00 32.15 332.45 2,304.11 2,233.11 368.29 -344.23 5,977,145.272 664,095.224 2.07 368.29 2,450.00 33.20 334.15 2,346.19 2,275.19 392.40 -356.36 5,977,169.114 664,082.576 2.79 392.40 2,500.00 33.92 335.33 2,387.86 2,316.86 417,40 -368.15 5,977,193.846 664,070.239 1.94 417.40 2,550.00 34.46 336.60 2,429.22 2,358.22 443.06 -379.59 5,977,219.247 664,058.239 1.79 443.06 2,600.00 34.75 338.34 2,470.37 2,399.37 469.29 -390.47 5,977,245.227 664,046.789 2.05 469.29 2,650.00 35.13 340.59 2,511.36 2,440.36 496.10 -400.51 5,977,271.812 664,036.163 2.69 496.10 2,700.00 35.65 342.11 2,552.12 2,481.12 523.54 -409.77 5,977,299.035 664,026.307 2.04 523,54 2,750.00 36.79 343.01 2,592.46 2,521.46 551.72 -418.62 5,977,327.018 664,016.840 2.52 551.72 2,800.00 37.70 343.50 2,632.26 2,561.26 580.70 -427.33 5,977,355.796 664,007.490 1.91 580.70 2,850.00 38.94 343.98 2,671.49 2,600.49 610.46 -436.01 5,977,385.359 663,998.161 2.55 61046 2,900.00 39.77 345.07 2,710.15 2,639.15 641.02 -444.47 5,977,415.720 663,989.037 2.16 641.02 2,950.00 40.97 347.45 2,748.25 2,677.25 672.47 452.15 5,977,446.998 663,980.667 3.91 672.47 3,000.00 42.02 348.92 2,785.70 2,714.70 704.90 458.93 5,977,479.263 663,973.179 2.86 704.90 5/312019 2:28:59PM Page 4 COMPASS 5000.1 Build 81D BP Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well E-100 Project POU ND Reference: KB @ 71.00usft Site: E MD Reference: KB @ 71.00usft Well: E-100 North Reference: True Wellborn: E -100A Survey Calculation Method; Minimum Curvature Design: E -100A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi TVD TVDSS NIS EIW Northing Easting DLeg V. Sec (usft) (°) 0 (usft) (usft) (usft) (usft) (usft) (usft) (°NOOusft) (usft) 3,050.00 42.63 349.97 2,822.67 2,751.67 737.99 -465.10 5,977,512.214 663,966.290 1.87 737.99 3,100.00 43.08 350.54 2,859.32 2,788.32 771.51 470.85 5,977,545.594 663,959.801 1.19 771.51 3,150.00 43.57 350.60 2,895.69 2,024.69 805.35 476.47 5,977,579.303 663,953.440 0.98 805.35 3,200.00 44.17 350.66 2,931.74 2,860.74 839.54 482.11 5,977,613.358 663,947.050 1.20 839.54 3,250.00 44.76 350.65 2,967.42 2,896.42 874.10 -487.80 5,977,647.781 663,940.607 1.18 874.10 3,300.00 45.47 350.74 3,002.71 2,931.71 909.06 -493.53 5,977,682.604 663,934.114 1.43 909.06 3,350,00 46.24 350.94 3,037.53 2,966.53 944.48 -499.24 5,977,717.889 663,927,627 1.57 944.46 3,400.00 47.06 351.45 3,071.85 3,000.85 980.41 -504.80 5,977,753.686 663,921.277 1.80 980.41 3,450.00 47.78 351.90 3,105.88 3,034.68 1,016.84 -510.13 5,977,789.986 663,915.150 1.59 1,016.84 3,500.00 48.80 352.55 3,138.95 3,067.95 1,053.82 -515.18 5,977,826.846 663,909.292 2.26 1,053.82 3,550.00 49.87 353.01 3,171.53 3,100.53 1,091.45 -519.95 5,977,864.355 663,903.703 2.25 1,091.45 3,600.00 50.46 353.53 3,203.56 3,132.56 1,129.58 -524.45 5,977,902.375 663,898.369 1.42 1,129.58 3,650.00 51.06 354.63 3,235.19 3,164.19 1,168.10 -528.44 5,977,940.793 663,893.533 2.08 1,168.10 3,700.00 52.17 355.54 3,266.24 3,195.24 1,207.14 -531.79 5,977,979.754 663,889.322 2.64 1,207.14 3,750.00 54.03 356.37 3,296.26 3,225.26 1,247.03 -534.61 5,978,019.563 663,885.631 3.95 1,247.03 3,800.00 55.43 356.72 3,325.13 3,254.13 1,287.77 -537.07 5,978,060.243 663,882.279 2.86 1,287.77 3,850.00 56.03 356.86 3,353.28 3,282.28 1,329.03 -539.38 5,978,101.434 663,879.062 1.22 1,329.03 3,900.00 56.31 357.47 3,381.12 3,310.12 1,370.51 -541.44 5,978,142.860 663,876.098 1.16 1,370.51 3,950.00 56.72 357.99 3,408.71 3,337.71 1,412.18 -543.09 5,978,184.479 663,873.534 1.19 1,412.18 4,000.00 56.57 358.43 3,436.20 3,365.20 1,453.92 -544.39 5,978,226.181 663,871.314 0.79 1,453.92 4,050.00 55.84 358.70 3,464,01 3,393.01 1,495.46 -545.43 5,978,267.683 663,869.362 1.53 1,495.46 4,100.00 55.75 358.43 3,492.12 3,421.12 1,536.80 -546.47 5,978,308.986 663,867.420 0.48 1,536.80 4,150.00 55.26 357.85 3,520.43 3,449.43 1,577.99 -547.81 5,978,350.131 663,865.180 1.37 1,577.99 4,200.00 55.13 357.00 3,548.97 3,477.97 1,619.00 -549.65 5,978,391.091 663,862.437 1.42 1,619.00 4,250.00 54.86 356.07 3,577.66 3,506.66 1,659.88 -552.13 5,978,431.903 663,859.066 1.62 1,659.88 4,300.00 54.40 355.15 3,606.60 3,535.60 1,700.53 -555.25 5,978,472.473 663,855.056 1.76 1,700.53 4,350.00 53.87 354.42 3,635.89 3,564.89 1,740.88 -558.93 5,978,512.732 663,850.490 1.59 1,740.86 5/312019 2.28:59PM Page 5 COMPASS 5000.1 Build BID BP by Final Survey Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well E-100 Project: PBU TVD Reference: KB @ 71.00usft Site: E MD Reference: KB @ 71.00usR Well: E-100 North Reference: True Wellbore: E -100A Survey Calculation Method: Minimum Curvature Design: E-1 ODA Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi TVD TVDSS NIS EMI Northing Euting Di-eg V. Sac (usft) (°) (°) (usft) (asfl) (usft) (usft) (usft) (Unfit) (•MOOusft) (usft) 4,400.00 53.72 354.32 3,66543 3,594.43 1,781.03 -562.89 5,978,552.783 663,845.652 0.34 1,781.03 4,450.00 53.29 354.32 3,695.16 3,624.16 1,821.03 -566.86 5,978,592.662 663,640.798 0.86 1,821.03 4,500.00 53.41 354.19 3,725.01 3,654.01 1,860.94 -570.88 5,978,632.495 663,835.908 0.32 1,860.94 4,550.00 53.77 354.00 3,754.69 3,683.69 1,900.97 -575.02 5,978,672.417 663,830.891 0.78 1,900.97 4,600.00 53.82 353.84 3,784.22 3,713.22 1,941.09 -579.29 5,978,712.430 663,825.739 0.28 1,941.09 4,650.00 53.78 353.62 3,813.75 3,742.75 1,981.19 -583.70 5,978,752.427 663,820A54 0.36 1,981.19 4,700.00 53.67 353.40 3,843.34 3,772.34 2,021.25 -588.25 5,978,792.366 663,815.021 0.42 2,021.25 4,750.00 54.06 353.29 3,872.82 3,801.82 2,061.36 -592.93 5,978,832.360 663,809.463 0.80 2,061.36 4,800.00 54.30 353.09 3,902.08 3,831.08 2,101.61 -597.74 5,978,672.499 663,803.774 0.58 2,10161 4,850.00 54.42 352.78 3,931.22 3,860.22 2,141.94 -602.74 5,978,912.703 663,797.893 0.56 2,141.94 4,900.00 54.35 352.38 3,960.33 3,889.33 2,182.24 -607.99 5,978,952.882 663,791.761 0.67 2,182.24 4,950.00 53.43 35246 3,989.80 3,918.80 2,222.29 -613.32 5,978,992.794 663,785.556 1.84 2,222.29 5,000.00 53.53 352.30 4,019.56 3,948.56 2,262.11 -618.65 6,979,032.492 663,779.355 0.33 2,262.11 5,050.00 53.76 352.12 4,049.19 3,978.19 2,302.01 -624.10 5,979,072.256 663,773.024 0.54 2,302.01 5,100.00 53.80 352.07 4078.74 4,007.74 2,341.96 -629.65 5,979,112.077 663,766.601 0.11 2,341.96 5,150.00 53.46 352.18 4,108.39 4,037.39 2,381.84 -635.17 5,979,151.824 663,760.212 0.70 2,381.84 5,200.00 53.46 352.66 4,138.16 4,067.16 2,421.67 -640.47 5,979,191.516 663,754.041 0.77 2,421.67 5,250.00 53.07 353.35 4,168.06 4,097.06 2,461.44 -645.35 5,979,231.168 663,748.290 1.35 2,461.44 5,300.00 52.76 353.31 4,198.21 4,127.21 2,501.05 -649.98 5,979,270.671 663,742.789 0.62 2,501.05 5,350.00 53.16 353.30 4,228.33 4,157.33 2,540.69 -654.63 5,979,310.196 663,737.268 0.80 2,540.89 5,400.00 53.01 353.14 4,258.36 4,187.36 2,580.39 -659.35 5,979,349.777 663,731.680 0.39 2,580.39 5,450.00 53.02 352.88 4,288.44 4,217.44 2,620.03 -664.21 5,979,389.300 663,725.951 042 2,620.03 5,500.00 53.27 352.43 4,318.43 4,247.43 2,659.71 -669.33 5,979,428.855 663,719.967 0.88 2,659.71 5,550DO 53.62 352.06 4,348.21 4,277.21 2,699.51 -674.75 5,979,468.521 663,713.676 0.92 2,699.51 5,600.00 53.71 351.89 4,377.84 4,306.84 2,739.39 -680.37 5,979,508.269 663,707.180 0.33 2,739.39 5,650.00 53.56 352.20 4,407.49 4,336.49 2,779.27 -685.94 5,979,548.010 663,700.735 0.58 2,779.27 5,700.00 53.15 353.25 4,437.33 4,366.33 2,819.06 -691.03 5,979,587.679 663,694.782 1.87 2,819.06 5/312019 2:28:59PM Page 6 COMPASS 5000.1 Build BID BP Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well E-100 Project: PBU TVD Reference: KB @ 71.00usft Site: E MD Reference: KB Q 71.00usft Well: E-100 North Reference: True Wellbore: E -100A Survey Calculation Method: Minimum Curvature Design: E -100A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azl TVD TVDSS NIS EM Northing Easting DLeg V. Sec (usft) V) (q (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 5,750.00 52.82 353.94 4,467.43 4,396.43 2,858.73 -695.48 5,979,627.243 663,689.459 1.28 2,858.73 5,800.00 52.97 353.95 4,497.59 4,426.59 2,898.39 -699.69 5,979,666.793 663,684.385 0.30 2,898.39 5,850.00 53.30 353.85 4,527.59 4,456.59 2,938.16 -703.94 5,979,706.463 663,679.262 0.68 2,938.16 5,900.00 53.53 353.78 4,557.39 4,486.39 2,978.08 -708.26 5,979,746.271 663,674.063 0.47 2,978.08 5,950.00 53.49 353.96 4,587.13 4,516.13 3,018.05 -712.55 5,979,786.132 663,668.895 0.30 3,018.05 6,000.00 52.53 354.74 4,617.21 4,546.21 3,057.79 -716.49 5,979,825.776 663,664.091 2.29 3,057.79 6,050.00 52.51 355.07 4,647.63 4,576.63 3,097.31 -720.01 5,979,865.208 663,659.701 0.53 3,097.31 6,100.00 52.67 355.17 4,678.01 4,607.01 3,136.88 -723.39 5,979,904.693 663,655.455 0.36 3,136.88 6,150.00 52.59 354.84 4,708.36 4,637.35 3,176.47 -726.85 5,979,944.190 663,651.129 0.55 3,176.47 6,200.00 52.57 354.61 4,738.74 4,667.74 3,216.01 -730.50 5,979,983.640 663,646.612 0.37 3,216.01 6,250.00 52.72 354.46 4,769.08 4,698.08 3,255.57 -734.29 5,980,023.108 663,641.960 0.38 3,255.57 6,300.00 52.95 354.20 4,799.28 4,728.28 3,295.22 -738.22 5,980,062.860 663,637.154 0.62 3,295.22 6,350.00 53.25 354.13 4,829.30 4,758.30 3,335.00 -742.28 5,980,102.335 663,632.218 0.61 3,335.00 6,400.00 53.42 354.12 4859.16 4,788.16 3,374.90 -748.39 5,980,142.129 663,627.239 0.34 3,374.90 6,450.00 52.37 354.82 4,889.32 4,818.32 3,414.59 -750.24 5,980,181.722 663,622.525 2.38 3,414.59 6,500.00 52.41 354.98 4,919.84 4,648.84 3,454.04 -753.76 5,980,221.085 663,618.140 0,27 3,454.04 6,550.00 52.97 354.76 4,950.15 4,879.15 3,493.65 -757.31 5,980,260.604 663,613.723 1.16 3,493.65 6,600.00 53.30 354.77 4,980.14 4,909.14 3,533.49 -760.95 5,980,300.348 663,609.207 0.66 3,533.49 6,650.00 53.46 354.92 5,009.97 4,938.97 3,573.45 -764.56 5,980,340.225 663,604.726 0.40 3,573.45 6,700.00 53.67 354.98 5,039.66 4,968.66 3,613.52 -768.10 5,980,380.205 663,600.307 0.43 3,613.52 6,750.00 52.40 355.16 5,069.73 4,998.73 3,653.33 -771.53 5,980,419.919 663,596.002 2.56 3,653.33 6,800.00 52.32 354.83 5,100.26 5,029.26 3,692.77 -774.99 5,980,459.273 663,591.683 0.55 3,692.77 6,850.00 52.72 354.30 5,130.69 5,059.69 3,732.27 -778.74 5,980,498.678 663,587.059 1.16 3,732.27 6,900.00 53.01 353.90 5,160.87 5,089.87 3,771.92 -782.84 5,980,538.225 663,582.093 0.86 3,771.92 6,950.00 53.23 353.49 5,190.88 5,119.88 3,811.67 -787.23 5,980,577.869 663,576.830 0.79 3,811.67 7,000.00 53.59 353.25 5,220.68 5,149.68 3,851.55 -791.87 5,980,617.633 663,571.322 0.82 3,851.55 7,050.00 54.11 353.07 5,250.18 5,179.18 3,891.63 -796.68 5,980,657.601 663,565.635 1.08 3,891.63 5/312019 2:28.59PM Page 7 COMPASS 5000.1 Build 81D ee BP Final Survey Report Company: North Amenca-ALASKA-BP Local Coordinate Reference: Well E-100 Project: PBU TVD Reference: KB @ 71.00usft Site: E MD Reference: KB @ 71.00usft Well: E-100 North Reference: True Wellbore: E -100A Survey Calculation Method: Minimum Curvature Design: E-1 00A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi ND TVDSS NIS EIW Northing Easting DLeg V. Sec (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) (*1100usft) (usft) 7,100.00 53.74 353.51 5,27962 5,208.62 3,931.77 -801.40 5,980,697.620 663,560.034 1.03 3,931.77 7,150.00 53.22 354.43 5,309.38 5,238.38 3,971.73 -805.62 5,980,737.474 663,554.937 1.81 3,971.73 7,200.00 52.94 354.70 5,339.41 5,268.41 4,011.52 -809.41 5,980,777.173 663,550.279 0.71 4,011.52 7,250.00 53.20 354.83 5,369.45 5,298.45 4,051.32 -813.06 5,980,816.882 663,545.760 0.56 4,051.32 7,300.00 53.46 354.97 5,399.31 5,328.31 4,091.27 -816.62 5,980,856.737 663,541.320 0.57 4,091.27 7,350.00 53.49 354.97 5,429.07 5,358.07 4,131.29 -820.14 5,980,896.673 663,536.920 0.06 4,131.29 7,400.00 53.46 355.00 5,458.83 5,387.83 4,171.32 -823.86 5,980,936.610 663,532.531 0.08 4,171.32 7,450.00 53.71 354.95 5,488.51 5,417.51 4,211.40 -827.18 5,980,976.602 663,528.126 0.51 4,211.40 7,500.00 53.78 354.51 5,518.08 5,447.08 4,251.55 -830.88 5,981,016.657 663,523.545 0.72 4,251.55 7,550.00 54.22 354.05 5,547.47 5,476.47 4,291.80 -834.92 5,981,056.806 663,518.632 1.15 4,291.80 7,600.00 54.42 353.66 5,576.83 5,505.63 4,332.18 -839.26 5,981,097.079 663,513.400 0.75 4,332.18 7,650.00 54.24 353.93 5,605.79 5,534.79 4,372.56 -843.65 5,981,137.351 663,508.125 0.57 4,372.56 7,700.00 52.64 355.72 5,635.57 5,564.57 4,412.56 -047.28 5,981,177.252 663,503.620 4.30 4,412.56 7,750.00 52.94 355.88 5,665.81 5,594.81 4,452.27 -850.20 5,981,216.890 663,499.833 0.65 4,452.27 7,800.00 53.18 355.75 5,695.86 5,624.86 4,492.13 -853.12 5,981,256.671 663,496.044 0.52 4,492.13 7,850.00 53.40 355.43 5,725.75 5,654.75 4,532.09 -856.20 5,981,296.555 663,492.086 0.68 4,532.09 7,900.00 53.55 355.05 5,755.51 5,684.51 4,572.13 -859.53 5,981,336.511 663,487.874 0.68 4,572.13 7,950.00 54.00 354.69 5,785.05 5,714.05 4,612.31 -863.14 5,981,378.593 663,483.387 1.07 4,612.31 8,000.00 54.30 354.26 5,814.34 5,743.34 4,652.64 -867.04 5,981,416.834 663,478.601 0.92 4,652.64 8,050.00 54.62 353.85 5,843.40 5,772.40 4,693.11 -871.26 5,981,457.195 663,473.500 0.92 4,693.11 8,100.00 55.11 353.61 5,872.18 5,801.18 4,733.76 -875.72 5,981,497.730 663,468.144 1.06 4,733.76 8,150.00 53.47 354.49 5,901.36 5,830.36 4,774.13 -879.93 5,981,538.003 663,463.048 3.58 4,774.13 8,200.00 53.40 354.78 5,931.15 5,860.15 4,814.12 -883.69 5,981,577.891 663,458.418 049 4,814.12 8,250.00 53.93 354.68 5,960.77 5,889.77 4,854.23 -887.39 5,981,617.906 663,453.839 1.07 4,854.23 8,300.00 54.74 354.54 5,969.92 5,918.92 4,894.67 -891.20 5,981,658.251 663,449.137 1.64 4,894.67 8,350.00 55.24 354.22 6,018.61 5,947.61 4,935,42 -895.21 5,981,698.906 663,444.234 1.13 4,935.42 8,400.00 55.64 354.15 6,046.97 5,975.97 4,976.39 -899.39 5,981,739.767 663,439.165 0.81 4,976.39 5/31/2019 2.'26.'59PM Page 8 COMPASS 5000.1 Build 81D BP bp Final Survey Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well E-100 Project: Pau TVD Reference: KB @ 71.00usft Site: E MD Reference: KB @ 71,00usft Well: E-100 North Reference: True Wellbore: E -100A Survey Calculation Method: Minimum Curvature Design: E -100A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azt TVD TVDSS NIS EIWI Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°1100usft) (usft) 8,450.00 53.79 355.07 6,075.85 6,004.85 5,017.02 -903.22 5,981,780.301 663,434.437 3.99 5,017.02 8,500.00 53.93 355.09 6,105.34 6,034.34 5,057.25 -906.69 5,981,820.443 663,430.093 0.28 5,057.25 8,550.00 54.38 354.80 6,134.62 6,063.62 5,097.62 -910.26 5,981,860.724 663,425.637 1.02 5,097.62 8,600.00 54.71 35444 6,163.63 6,092.83 5,138.17 -914.08 5,981,901.177 663,420.929 0.88 5,138.17 8,650.00 55.33 354.15 6,192.29 6,121.29 5,178.93 -918.15 5,981,941.839 663,415.964 1.33 5,178.93 8,700.00 55.24 354.20 6,220.76 6,149.76 5,219.82 -922.32 5,981,982.623 663,410.897 0.20 5,219.82 8,750.00 54.00 354.50 6,249.71 6,178.71 5,260.39 -926.34 5,982,023.089 663,405.994 2.53 5,260.39 8,800.00 53.44 355.76 6,279.30 6,208.30 5,300.55 -929.76 5,982,063.162 663,401.691 2.32 5,300.55 8,850.00 52.30 356.99 6,309.48 6,238.48 5,340.33 -932.28 5,982,102.875 663,398.296 3.01 5,340.33 8,900.00 52.81 356.93 6,339.88 6,268.88 5,379.97 -934.39 5,982,142.458 663,395.321 1.02 5,379.97 8,950.00 53.54 356.69 6,369.85 6,298.85 5,419.93 -936.62 5,982,182.358 663,392.218 1.51 5,419.93 9,000.00 53.98 356.43 6,399.41 6,32841 5,460.19 -939.04 5,982,222.547 663,388.916 0.97 5,460.19 9,050.00 54.21 356.31 6,428.73 6,357.73 5,500.60 •941.60 5,982,262.896 663,385.466 0.50 5,500.60 9,100.00 52.94 356.55 6,458.42 6,387.42 5,540.76 -044.11 5,982,302.981 663,382.080 2.57 5,540.76 9,150.00 52.29 356.50 6,488.78 6,417.78 5,580.41 -946.51 5,982,342.572 663,378.803 1.30 5,580.41 9,200.00 52.68 356.13 6,519.23 6,448.23 5,619.99 -949.06 5,982,382.081 663,375.386 0.98 5,619.99 9,250.00 52.93 355.88 6,549.45 8,478.45 5,659.72 -951.84 5,982,421.740 663,371.740 0.64 5,659.72 9,300.00 53.22 355.66 6,579.49 6,508.49 5,699.59 -954.79 5,982,461.525 663,367.919 0.68 5,699.59 9,350.00 53.34 355.40 6,609.39 6,538.39 5,739.54 -957.91 5,982,501.401 663,363.919 0.48 5,739.54 9,400.00 52.02 356.02 6,639.70 6,568.70 5,779.19 -960.89 5,982,540.973 663,360.074 2.82 5,779.19 9,450.00 51.78 356.00 6,670.55 6,599.55 5,818.44 -963.62 5,982,580.153 663,356.476 0.48 5,818.44 9,500.00 51.78 355.71 6,701.48 6,630.48 5,857.62 -966.46 5,982,619.257 663,352.778 0.46 5,857.62 9,550.00 51.94 355.35 6,732.36 6,661.36 5,896.83 -969.53 5,982,658.383 663,348.854 0.65 5,89683 9,600.00 51.98 355.03 6,763.17 6,692.17 5,936.07 -972.83 5,982,697.539 663,344.693 0.51 5,936.07 9,650.00 52.10 354.68 6,793.93 6,722.93 5,975.33 -976.37 5,982,736.712 663,340.297 0.60 5,975.33 9,700.00 51.86 354.23 6,824.73 6,753.73 6,014.54 -960.17 5,982,775.822 663,335.633 0.86 6,014.54 9,750.00 52.15 353.94 6,855.51 6,784.51 6,053.73 -984.23 5,982,814.914 663,330.713 0.74 6,053.73 5/312019 2r28:59PM Page 9 COMPASS 5000 1 Build 810 HE BP Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well E-100 Project: PBU TVD Reference: KB @ 71.00usft Site: E MD Reference: KB @ 71.00usft Well: E-100 North Reference: True Wellbore: E -100A Survey Calculation Method: Minimum Curvature Design: E -1100A Database: EDM R5K-Alaska PROD -ANCPI Survey MD Inc Azi TVD TVDSS NIS E/W Northing Easting DLeg V. Sec (usft) (°) (") (usft) (usft) (usft) (usft) (usft) (usft) (°1100usft) (usft) 9,800.00 52.29 354.03 6,886.14 6,815.14 6.093.03 -988.37 5,982,854.112 663,325.711 0.31 6,093.03 9,850.00 51A3 355.13 6,916.88 6,845.88 6,132.29 -992.10 5,982,893.273 663,321.126 188 6,132.29 9,900.00 51.35 355.35 6,947.94 6,876.94 6,171.33 -995.35 5,982,932.234 663,317.019 1.02 6,171.33 9,950.00 51.58 355.26 6,979.09 6,908.09 6,210.31 -998.55 5,982,971.132 663,312.963 0.48 6,210.31 10,000.00 51.69 355.17 7,010.13 6,939.13 6,249.38 -1,001.82 5,983,010.115 663,308.837 0.26 6,249.38 10,050.00 51.87 354.96 7,041.06 6,970.06 6,288.51 -1,005.20 5,983,049.165 663,304.600 049 6,288.51 10,100.00 52.02 354.73 7,071.88 7,000.88 6,327.72 -1,008.74 5,983,088.287 663,300.204 0.47 6,327.72 10,150.00 52.05 354.84 7,102.64 7,031.64 6,366.97 -1,012.39 5,983,127.444 663,295.893 0.15 6,366.97 10,200.00 52.17 354.47 7,133.35 7,062.35 6,406.26 -1,016.13 5,983,166.632 663,291.088 0.36 6,406.26 10,250.00 52.17 354.17 7,164.02 7,093.02 6,445.55 -1,020.04 5,983,205.831 663,286.318 0.47 6,445.55 10,300.00 52.21 354.07 7,194.67 7,123.67 6,484.85 -1,024.09 5,983,245.025 663,281.411 0.18 6,484.85 10,350.00 52.60 353.91 7,225.17 7,154.17 6,524.25 -1,028.24 5,983,284.321 663,276.400 0.82 6,524.25 10,400.00 52.75 353.81 7,25549 7,184.49 6,563.78 -1,032.49 5,983,323.748 663,271.281 0.34 6,583.78 10,450.00 52.89 353.55 7,285.70 7,214.70 6,603.37 -1,036.88 5,983,363.234 663,266.029 0.50 6,603.37 10,500.00 52.72 353.54 7,315.93 7,244.93 6,642.95 -1,041.35 5,983,402.700 663,260.684 0.34 6,642.95 10,550.00 53.03 353.40 7,346.11 7,275.11 6,682.56 -1,045.89 5,983,442.196 663,255.283 0.66 6,882.56 10,600.00 53.04 353.44 7,376.17 7,305.17 6,722.25 -1,050.47 5,983,481.770 663,249.836 0.07 6,722.25 10,650.00 53.00 353.11 7,406.25 7,335.25 6,761.91 -1,055.14 5,983,521.323 663,244.290 0.53 6,761.91 10,700.00 52.65 352.93 7,436.46 7,365.46 6,801.46 -1,059.98 5,983,560.749 663,238.583 0.76 6,80146 10,750.00 52.55 352.97 7,466.83 7,395.83 6,840.88 -1,064.86 5,983,600.050 663,232.844 0.21 6,840.88 10,800.00 53.30 352.96 7,496.98 7,425.98 6,880.47 -1,069.75 5,983,639.522 663,227.092 1.50 6,880.47 10,850.00 53.46 352.79 7,526.80 7,455.80 6,920.29 -1,074.72 5,983,679.221 663,221.242 0.42 6,920.29 10,900.00 53.47 352.66 7,556.57 7,485.57 6,960.14 -1,079.80 5,983,718.949 663,215.289 0.18 6,960.14 10,950.00 53.55 352.70 7,586.30 7,515.30 7,000.01 -1,084.92 5,983,758.696 663,209.301 0.16 7,000.01 11,000.00 52.02 353.55 7,616.54 7,545.54 7,039.54 -1,089.69 5,983,798.109 663,203.667 3.35 7,039.54 11,050.00 51.56 353.97 7,647.47 7,576.47 7,078.60 -1,093.96 5,983,837.058 663,198.540 1.13 7,078.60 11,100.00 49.72 355.12 7,679.18 7,608.18 7,117.08 -1,097.64 5,983,875.446 663,194.018 4.09 7,117.08 5/31/2019 2:28,59PM Page 10 COMPASS 50001 Build 81D BP Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well E-100 Project: PBU TVD Reference: KB @ 71.00usft Site: E MD Reference: KB @ 71.00usft Well: E-100 North Reference: True Wellbore. E-1 GOA Survey Calculation Method: Minimum Curvature Design: E -100A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc An TVD TVOSS NIS E/W Northing Easting Di -eq V. Seo (uaft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°MOOusft) (usft) 11,150.00 49.10 355.36 7,711.71 7,640.71 7,154.92 -1,100.79 5,983,913.203 663,190.037 1.29 7,154.92 11,200.00 49.24 355.16 7,744.40 7,673.40 7,192.62 -1,103.92 5,983,950.826 663,186.085 0.41 7,192.62 11,250.00 49.38 354.93 7,777.00 7,706.00 7,230.39 -1,107.19 5,983,988.513 663,181.983 0.45 7,230.39 11,300.00 49.65 354.82 7,809.46 7,738.46 7,268.27 -1,110.59 5,984,026.304 663,177.756 0.57 7,268.27 11,350.00 49.83 354.77 7,641.77 7,770.77 7,306.27 -1,114.05 5,984,064.214 663,173.462 0.37 7,305.27 11,400.00 50.10 354.88 7,873.94 7,802.94 7,344.39 -1,117.50 5,984,102.253 663,169.174 0.57 7,344.39 11,450.00 50.42 354.93 7,905.90 7,834.90 7,382.69 -1,120.92 5,984,140.462 663,164.920 0.64 7,382.69 11,500.00 51.00 355.14 7,937.56 7,866.56 7,421.24 -1,124.27 5,984,178.929 663,160.727 1.20 7,421.24 11,550.00 50.18 356.40 7,969.31 7,898.31 7,459.76 -1,127.12 5,984,217.379 663,157.031 2.55 7,45976 11,600.00 48.60 357.62 8,001.85 7,930.85 7,497.67 -1,129.10 5,984,255.227 663,154.216 3.66 7,497.67 11,650.00 47.09 358.28 8,035.41 7,964.41 7,534.71 -1,130.43 5,984,292.227 663,152.075 3.17 7,534.71 11,700.00 46.57 359.24 8,069.62 7,998.62 7,571.17 -1,131.22 5,984,328.656 663,150.485 1.74 7,571.17 11,750.00 45.40 359.49 8,104.38 8,033.36 7,607.12 -1.131.62 5,984,364,591 663,149.297 2.37 7,607.12 11,800.00 45.53 358.43 8,139.43 8,068.43 7,642.75 -1,132.27 5,984,400.200 663,147.869 1.53 7,642.75 11,850.00 43.83 358.40 8,174.98 8,103.98 7,677.90 -1,133.24 5,984,435.310 663,146.126 3.40 7,677.90 11,900.00 42.85 358.77 8,211.34 8,140.34 7,712.20 -1,134.09 5,984,469.586 663,144.525 2.02 7,712.20 11,950.00 40.80 359.20 8,248.60 8,177.60 7,745,54 -1,134,68 5,984,502.898 663,143.201 4.14 7,745.54 12,000.00 38.12 359.91 8,287.20 8,216.20 7,777.31 -1,134.93 5,984,534.656 663,142.252 544 7,777.31 12,050.00 35.89 359.53 8,327.13 8,256.13 7,807.40 -1,135.08 5,984,564.735 663,141.447 4.48 7,807.40 12,100.00 35.20 359.00 8,367.81 8,296.81 7,836.47 -1,135.45 5,984,593.782 663,140.438 1.51 7,836.47 12,150.00 34.55 358.59 8,408.83 8,337.83 7,865.05 -1,136.05 5,984,622.343 663,139.211 1.38 7,865.05 12,200.00 34.20 358.64 8,450.10 8,379.10 7,893.27 -1,136.73 5,984,650.541 663,137.910 0.70 7,893.27 12,250.00 33.27 358.74 8,491.68 8,420.68 7,921.03 -1,137.37 5,984,678.279 663,136.666 1.86 7,921.03 12,300.00 32.74 358.42 8,533.61 8,462.61 7,948.26 -1,138.04 5,984,705.483 663,135.395 1.12 7,948.26 12,350.00 31.58 358.50 8,575.94 8,504.94 7,974.86 -1,138.76 5,984,732.063 663,134.096 2.32 7,974.86 12,400.00 31.26 358.34 8,618.60 8,547.60 8,000.92 -1,139.48 5,984,758.095 663,132.806 0.66 8,000.92 12,450.00 31.27 357.96 8,661.34 8,590.34 8,026.85 -1,140.31 5,984,784.004 663,131.399 0.39 8,026.85 5/31/2019 2:28:59PM Page 11 COMPASS 5000.1 Build 81D RE. Company: North America - ALASKA - BP Project PBU Site: E Well: E-100 Wellbore: E -100A Design: E -100A MD Inc Well E-100 (usft) O KB @ 71.00usft 12,500.00 30.31 12,550.00 28.43 12,600.00 27.27 12,650.00 26.25 12,700.00 24.78 12,750.00 23.77 12,800.00 22.26 12,850.00 21.99 12,900.00 22.26 12,950.00 22.23 mein point E-100 8,704.29 12,988.00 21.65 KOP - Top of Whipstock 13,006.68 24.10 Interpolated Azimuth 13,035.32 28.98 Interpolated Azimuth 8,747.87 13,066.41 34.61 First Clean Survey 13,095.36 40.78 13,125.48 47.80 13,155.16 50.16 13,185.28 51.55 13,216.29 54.88 13,245.43 56.88 13,275.85 59.96 13,302.59 65.28 13.330.34 71.86 5/31/2019 2:28:59PM BP Final Survey Report Local Coordinate Reference: Well E-100 TVD Reference: KB @ 71.00usft MD Reference: KB @ 71.00usft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 An TVD TVDSS NIS ENV Northing Easting DLeg V. Bee (') (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 358.11 8,704.29 8,633.29 8,052.43 -1,141.19 5,984,809.556 663,129.960 1.93 8,052.43 358.64 8,747.87 8,676.87 8,076.95 -1,141.89 5,984,834.045 663,128.724 3.80 8,076.95 358.86 8,792.07 8,721.07 8,100.30 -1,142.40 5,984,857.378 663,127.702 2.33 8,100.30 358.90 8,836.72 8,765.72 8,122.81 -1,142.84 5,964,879.870 663,126.768 2.04 8,122.81 359.77 8,881.84 8,810.84 8,144.34 -1,143.10 5,984,901.392 663,126.042 3.03 8,144.34 0.63 8,927.42 8,856.42 8,164.90 -1,143.03 5,984,921.942 663,125.659 2.14 8,164.90 0.36 8,973.44 8,902.44 8,184.44 -1,142.86 5,984,941.487 663,125.401 3.03 8,184.44 0.32 9,019.76 8,948.76 8,203.27 -1,142.74 5,984,960.315 663,125.100 0.54 8,203.27 0.63 9,066.08 8,995.08 8,222.10 -1,142.59 5,984,979.143 663,124.843 0.59 8,222.10 2.11 9,112.35 9,041.35 8,241.03 -1,142.14 5,984,998.069 663,124.880 1.12 8,24103 0.16 9,147.60 9,076.60 8,255.22 -1141.85 5,985,012.264 663,124.853 2.45 8,255.22 0.43 9,164.81 9,093.81 8,262.48 -1,141.81 5,985,019.523 663,124.732 13.13 8,262.48 0.73 9,190.43 9,119.43 8,275.27 -1,141.68 5,985,032.314 663,124.583 17.05 8,275.27 0.99 9,216.84 9,145.84 8,291.64 -1,141.43 5,985,048.687 663,124.473 18.11 8,291.64 2.25 9,239.74 9,168.74 8,309.33 -1,140.92 5,985,066.378 663,124.599 21.48 8,309.33 3.76 9,261.28 9,190.28 8,330.32 -1,139.80 5,985,087.384 663,125.257 23.57 8,330.32 11.01 9,280.78 9,209.78 8,352.49 -1,136.90 5,985,109.616 663,127.670 20.06 8,352.49 18.15 9,299.81 9,228.81 8,375.07 -1,131.01 5,985,132.315 663,133.060 18.95 8,375.07 23.22 9,318.38 9,247.38 8,398.28 -1,122.22 5,985,155.710 663,141.337 16.93 8,398.28 29.49 9,334.74 9,263.74 8,419.87 -1,111.51 5,985,177.529 663,151.574 19.08 8,419.87 33.20 9,350.67 9,279.67 8,441.99 -1,098.02 5,985,199.935 663,164.572 14.51 8,441.99 35.06 9,362.96 9,291.96 8,461.63 -1,084.70 5,985,219.863 663,177.461 20.83 8,461.63 36.55 9,373.10 9,302.10 8,482.56 -1,069.59 5,985,241.121 863,192.107 24.23 8,482.56 Page 12 COMPASS 5000.1 Build 81D BP Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well E-100 Project: Pau TVD Reference: KB Q 71.00usft Site: E MD Reference: KB r@ 71.00usft Well: E-100 North Reference: True Wellbore: E -100A Survey Calculation Method: Minimum Curvature Design: E -100A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi TVD iVDSS NIS E/W Northing Eacting. D1.e9 V. Sec (usft) (•) (•) (usft) (usft) (usft) (usft) (usft) (usft) (•1100usft) (usft) 13,360.29 79.10 38.47 9,380.80 9,309.60 8,505.54 -1,051.94 5,985,264.478 663,209.245 24.96 8,505.54 13,391.75 85.72 41.40 9,384.76 9,313.76 8,529.43 -1,031.93 5,985,288.801 663,228.724 22.98 8,529.43 13,417.90 87.91 46.66 9,386.21 9,315.21 8,548.19 -1,013.79 5,985,307.957 663,246.447 21.76 8,548.19 13,450.14 88.74 53.20 9,387.15 9,316.15 8,568.93 -989.14 5,985,329.224 663,270.633 20.44 8,568.93 13,480.32 90.58 58.54 9,387.33 9,316.33 8,585.85 -964.17 5,985,346.692 663,295.226 18.71 8,585.85 13,510.47 90.28 64.60 9,387.11 9,316.11 8,600.20 -937.67 5,985,361.616 663,321.403 20.12 8,600.20 13,540.54 90.00 70.92 9,387.03 9,316.03 8,611.57 -909.85 5,985,373.598 663,348.964 21.04 8,611.57 13,570.48 90.00 74.87 9,387.03 9,316.03 8,620.38 -881.24 5,985,383.027 663,377.372 13.19 8,620.38 13,600.48 90.40 77.93 9,386.93 9,315.93 8,627.43 -852.09 5,985,390.718 663,406.363 10.29 8,627.43 13,630.37 90.52 81.63 9,366.69 9,315.69 8,632.73 -822.88 5,985,395.664 663,435.648 12.38 8,632.73 13,660.42 90.46 84.05 9,386.43 9,315.43 8,636.48 -792.86 5,985,401.061 663,465.369 8.06 8,636.48 13,690.56 90.74 86.75 9,386.11 9,315.11 8,638.90 -762.83 5,985,404.137 663,495.345 9.01 8,638.90 13,720.48 90.09 90.53 9,385.90 9,314.90 8,639.61 -732.92 5,985,405.502 663,525.225 12.82 8,639.61 13,750.59 89.54 93.44 9,385.99 9,314.99 8,638.56 •702.83 5,985,405.120 663,555.327 9.84 8,638.56 13,780.66 88.99 96.38 9,386.38 9,315.38 8,635.99 -672.88 5,985,403.204 663,585.328 9.95 8,635,99 13,810.60 88.99 99.71 9,386.91 9,315.91 8,631.80 -643.24 5,985,399.667 663,615.047 11.12 8,631.80 13,840.53 89.14 103.06 9,387.40 9,316.40 8,625.90 -613.91 5,985,394.406 663,644.501 11.20 8,625.90 13,872.45 89.11 107.23 9,387.88 9,316.88 8,617,56 -583.11 5,985,386.747 663,675.475 13.06 8,617.56 13,900.42 88.74 110.73 9,388.41 9,317.41 8,608.46 -556.67 5,985,378.236 663,702.107 12.58 8,608.46 13,930.66 87.45 110.54 9,389.41 9,318.41 8,597.81 -528.38 5,985,368.209 663,730.615 4.31 8,597.81 13,963.64 87.42 109.98 9,390.89 9,319.89 8,586.40 -497.48 5,985,357.482 663,761.765 1.70 8,586.40 13,992.58 88.00 108.51 9,392.05 9,321.05 8,576.87 -470.18 5,985,348.552 663,789.265 5.46 8,576.87 14,020.54 90.86 108.94 9,392.33 9,321.33 8,567.90 -443.70 5,985,340.161 663,815.930 10.34 8,567.90 14,050.40 88.90 108.41 9,392.39 9,321.39 8,558.34 -415.41 5,985,331.224 663,844.417 6.80 8,558.34 14,080.42 91.01 108.70 9,392.41 9,321.41 8,548.79 -386.95 5,985,322.299 663,873.076 7.09 8,548.79 14,110.44 92.64 108.47 9,391.46 9,320.46 8,539.22 -358.52 5,985,313.363 663,901.716 5.48 8,539.22 14,140.30 93.04 106.73 9,389.98 9,318.98 8,530.21 -330.09 5,985,304.972 663,930.331 5.97 8,530.21 &3112019 2:28:59PM Page 13 COMPASS 5000.1 Build BID BP bp Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well E-100 Project: PBU ND Reference: KB @ 71.00usft Site: E MD Reference: KB @ 71.00usft Well: E-100 North Reference: True Wellbore: E -100A Survey Calculation Method: Minimum Curvature Design: E -100A Database: EDM R5K-Alaska PROD -ANCP1 Survey MD Inc Azi ND NDSS N/S E/W Northing Essting DLeg V. Sac (weft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (11100usft) (usft) 14,170.32 92.18 105.24 9,388.61 9,317.61 8,521.95 -301.26 5,985,297.349 663,959.331 5.73 8,521.95 14,200.48 91.50 103.98 9,387.64 9,316.64 8,514.35 -272.09 5,985,290.388 663,988.658 4.75 8,514.35 14,229.62 90.37 103.52 9,387.16 9,316.16 8,507.42 -243.79 5,985,284.086 664,017.102 4.19 8,50742 14,260.62 89.69 102.71 9,387.15 9,316.15 8,500.39 -213.60 5,985,277.716 664,047.438 3.41 8,500.39 14,289.84 89.17 101.32 9,387.44 9,316.44 8,494.30 -185.02 5,985,272.263 664,076.140 5.08 8,494.30 14,315.21 88.83 99.60 9,387.88 9,316.88 8,489.70 -160.08 5,985,268.206 664,101.177 6.91 8,489.70 14,347.89 89.88 98.13 9,388.25 9,317.25 8,484.66 -127.79 5,985,263.881 664,133.564 5.53 8,484.66 14,380.11 89.48 96.27 9,388.43 9,317.43 8,480.63 -95.83 5,985,260.545 664,165.606 5.90 8,480.63 14,410.25 92.05 96.20 9,388.03 9,317.03 8,477.35 -65.87 5,985,257.930 664,195.625 8.53 8,477.35 14,440.29 96.43 96.94 9,385.81 9,314.81 8,473.93 -36.12 5,985,255.158 664,225.445 14.79 8,473.93 14,470.26 101.28 96.00 9,381.19 9,310.19 8,470.59 -6.70 5,985,252.466 664,254.924 16.48 8,470.59 14,501.10 102.41 93.46 9,374.86 9,303.86 8,468.10 23.37 5,985,250.637 664,285.046 8.85 8,468.10 14,531.40 100.64 91.09 9,368.81 9,297.81 8,466.92 53.04 5,985,250.111 664,314.725 9.64 8,466.92 14,565.17 100.15 89.06 9,362.72 9,291.72 8,466.88 86.25 5,985,250.797 664,347.930 6.09 8,466.88 14,588.05 101.06 87.05 9,358.50 9,287.50 8,467.64 108.72 5,985,252.052 664,370.381 9.51 8,467.64 14,621.94 99.04 85.04 9,352.59 9,281.59 8,469.95 142.01 5,985,255.085 664,403.607 8.34 8,469.95 14,655.32 96.60 81.16 9,348.05 9,277.05 8,473.92 174.83 5,985,259.779 664,436.330 13.64 8,473.92 14,684.86 94.73 80.08 9,345.13 9,274.13 8,478.71 203.83 5,985,265.205 664,465.217 7.30 8,478.71 14,717.39 94.55 83.78 9,342.50 9,271.50 8,483.26 235.93 5,985,270.458 664,497.204 11.35 8,483.26 14,749.30 94.49 89.65 9,339.98 9,268.98 8,485.08 267.67 5,985,272.976 664,528.898 18.34 8,485.08 14,779.99 95.94 93.29 9,337.19 9,266.19 8,484.30 298.22 5,985,272.863 664,559.453 12.72 8,484.30 14,810.36 98.84 95.47 9,333.28 9,262.28 8,482.00 328.25 5,985,271.225 664,589.519 11.91 8,482.00 14,839.63 100.62 100.01 9,328.34 9,257.34 8,478.12 356.82 5,985,267.972 664,618.173 16.45 8,478.12 14,870.21 102.99 104.17 9,322.08 9,251.08 8,471.86 386.08 5,985,262.353 664,647.562 15.41 8,471.86 14,900.27 102.87 101.38 9,315.35 9,244.35 8,465.38 414.65 5,985,256.504 664,678.265 9.05 8,465.38 14,930.29 103.11 98.70 9,308.60 9,237.60 8,460.28 443.45 5,985,252.038 664,705.169 8.74 8,460.28 14,958.97 102.01 96.31 9,302.36 9,231.36 8,456.63 471.21 5,985,248.993 664,732.992 8.99 8,456.63 5/31/2019 2:28.59PM Page 14 COMPASS 5000.1 Build 81D BP Final Survey Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well E-100 Project: PBU ND Reference: KB @ 71.00usft Site: E MD Reference: KB @ 71.00usft Well: E-100 North Reference: True Wellbore: E -100A Survey Calculation Method: Minimum Curvature Design: E -100A Database: EDM RSK- Alaska PROD -ANCPI Survey MD Inc Azi TVD TVDSS NIS ENV Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°I100usft) (usft) 14,989.76 100.94 92.05 9,296.24 9,225.24 8,454.43 501.29 5,985,247.457 664,763.117 14.00 8,454.43 15,020.02 102.37 91.14 9,290.12 9,219.12 8,453.61 530.92 5,985,247.281 664,792.750 5.57 8,453.61 15,052.08 101.27 94.94 9,283.55 9,212.55 8,451.94 562.24 5,985,246.303 664,824.106 12.10 8,451.94 15,081.22 99.73 99.24 9,278.24 9,207.24 8,448.40 590.67 5,985,243.389 664,852.599 15.44 8,448.40 15,110.40 99.91 102.91 9,273.26 9,202.26 8,442.88 618.88 5,985,238.488 664,880.923 12.41 8,442.88 15,140.23 100.89 107.39 9,267.87 9,196.87 8,435.22 647.19 5,985,231.447 664,909.395 15.13 8,435.22 15,170.12 103.47 111.29 9,261.57 9,190.57 8,425.55 674.76 5,985,222.387 664,937.161 15.40 8,425.55 15,201.69 106.40 107.75 9,253.43 9,182.43 8,415.35 703.50 5,985,212,825 664,966.115 14.26 8,415.35 15,232.35 108.25 104.85 9,244.30 9,173.30 8,407.13 731.58 5,985,205.226 664,994.374 10.86 8,407.13 15,260.17 107.33 104.27 9,235.80 9,164.80 8,400,48 757.22 5,985,199.132 665,020.150 3.86 8,400.48 15,292.14 104.68 102.96 9,226.98 9,155.98 8,393.24 787.09 5,985,192.558 665,050.164 9.18 8,393.24 15,320.62 103.86 101.99 9,219.96 9,148.96 8,387.28 814.03 5,985,187.190 665,077.236 4.38 8,387.28 15,349.34 101.95 101.28 9,213.55 9,142.55 8,381.64 841.45 5,985,182.148 665,104.769 7.07 8,381.64 15,379.48 102.63 98.83 9,207.13 9,136.13 8,378.50 870.45 5,985,177.643 665,133.867 8.26 8,376.50 15,408.89 102.59 96.23 9,200.71 9,129.71 8,372.74 898.90 5,985,174.508 665,162.391 8.63 8,372.74 15,440.47 103.49 94.82 9,193.58 9,122.58 8,369.77 929.52 5,985,172.218 665,193.068 5.20 8,369.77 15,465.43 103.90 92.72 9,187.67 9,116.67 8,368.18 953.72 5,985,171.154 665,217.292 8.34 8,368.18 15,495.23 103.86 91.08 9,180.53 9,109.53 8,367.22 982.63 5,985,170.830 665,246.217 5.34 8,367.22 15,503.68 104.20 90.11 9,178.48 9,107.48 8,367.13 990.83 5,985,170.924 665,254.414 11.84 8,367.13 15,540.00 104.20 90.11 9,169.57 9,098.57 8,367,07 1,026.04 5,985,171.629 665,289.614 0.00 8,367.07 Projection to TD 5/312019 2:28'59PM Page 15 COMPASS 5000.1 Build BID In A LLBORE DETAILS: 6100A I ENMNfpUlpProfeCl: PBU egE1WAWNI: 6100 aWN@me 6100A EiWAaWal: 610b1 McMMD: 12950.00 Aloeu a�amn wfma: s5 �um�c5unaue AOGCC Offsets within 500ft Embng (400 usNin) North America - ALASKA - BP PBU E E-100 E -100A E -1 00A 500292281901 AOGCC Offset Well Report 31 May, 2019 Company: North America - ALASKA - BP Project: PBU Reference Site: E Site Error: 0 oousft Reference Well: E-100 Well Error: O.00usft Reference Wellbore E -100A Reference Design: E -100A BP Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well E-100 KB @ 71.00usft KB @ 71.00usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference E -100A Filter type: NO GLOBAL FILTER. Using user defined selection 8 filtering criteria Reference 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 5/31/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 12,950.00 3 Gyrodata cont.casing m/s (E-100) GYD-CT-CMS Gyrodata cont.casing Ms 12,988.00 15,540.00 Survey#1(E-100A) MWD MWD -Standard Summary Reference Offset Centre to Measured Measured Centre Site Name Depth Depth Distance Offset Well - Wellbore - Design (usft) (usft) (usft) E E -07 -E -07-E-07 1,675.90 1,650.00 210.55 E-07 - E -07A - E -07A 1,675.90 1,650.00 210.55 E-07 - E-07APB1 - E-07APB1 1,675.90 1,650.00 210.55 E-07 - E-07APB2 - E-07APB2 1,675.90 1,650.00 210.55 E-07 - E -07B - E -07B 1,675.90 1,650.00 210.55 E-08 - E-08 - E-08 1,340.54 1,325.00 131.94 E-08 - E -08A- E -08A 1,340.54 1,325.00 131.94 E-09 - E-09 - E-09 635.06 625.00 32.48 E-09 - E -09A - E -09A 630.33 625.00 32.42 E-09 - E-09APB1 - E-09APB1 630.33 625.00 32.42 E-09 - E -09B - E -09B 630.33 625.00 32.42 E-09 - E -09C - E -09C 630.33 625.00 32.42 E-09 - E-09CPB1 - E-09CPBI 630.33 625.00 32.42 E-10 - E-10 - E-10 610.11 600.00 79.89 E-10 - E-1 OA- E -10A 810.11 600.00 79.89 E-10 - E-1 OB - E-1 OB 610.87 600.00 79.90 E-100 - E-1 ODA- E -100A WP03 11 Odeg build 14,676.25 14,675.00 43.52 E -102 -E -102-E-102 1,028.03 1,025.00 36.35 E-104 - E-104 - E-104 926.14 925.00 116.23 E-11 - E-11 - E-11 510.03 500.00 187.50 E-11 - E -11A- E -11A 52721 525.00 187.79 E-11 - E-11APB1 - E-11APB1 527.21 525.00 187.79 E-11 - E-11 B- E-11 B 512.98 500.00 187.55 E-11 - E-111311 - E-11BI-1 512.98 500.00 187.55 E-11 - E-11BI-1-01 - E-11BL1-01 512.98 500.00 187.55 E-11 - E-11BL1PB1 - E-11BLlPBI 512.98 500.00 187.55 E-11 - E-11 BLlPB1 - Plan #7 512.98 500.00 187.55 E-11 - E-11BL1PB2 - E-11BL1PB2 512.98 500.00 187.55 E-34 - E-34 - E-34 627.93 625.00 108.30 E-34 - E -34A - E -34A 627.93 625.00 108.30 E-34 - E-341.1 - E-341-1 627.93 625.00 108.30 E-38 - E-38 - E-38 2,234.71 2,175.00 172.05 E-38 - E-38PB1 - E-38PB1 2,234.71 2,175.00 172.05 E-38 - E-38PB2 - E-38PB2 2,234.71 2,175.00 172.05 5!312019 2:43:08PM Page 2 of 2 COMPASS 5000.1 Build 81D - North America - ALASKA - BP Page 1 of 2 Cementing Report Common Well Name: E-100 / 01 - - - - Report no.: 1 Report date: 512712019 ' rolect: PBU Site: E Spud Dame: 10/25/1997 Event Type: COM- ONSHORE (CON) Start Date: 5/26/2019 Eno Date: 528/2019 AFE No.: Contractor: NABORS ALASKA DRILLING INC. Rig Name/No.: CDR-2 LRig Release: 5282019 X3-019C7-C: (2,616,338.00 ) BPUOI: USA00000718 Active datum: KB L871.00usft (above Mean See Level) General Information Job type: Primary Cement job start date/time: 5/27/2019 4:OOPM Job end date/dme: 5/27/2019 7:10PM Cement Company: SCHLUMSERGER Cementer: KEITH PIERCE Cemented String: PRODUCTION LINER 1 String Size: 2.875 (in) String Set TMD: 15,540.00 (usft) Hole Size: 4.250 (In) Pipe Movement Pipe Movement: NO MOVEMENT Rotating Time (Start-End): RPM: Rotating Torque (initlavg/max): (ft-Ibf) Reciprocating Time (Start-End): Recip Drag Up/Down: - (kip) SPM: Stroke Length. Fluld Name: CEMENT Fluids (1 of 1) Slurry Type: CEMENT Purpose: PRIMARY Class: G-CLASS Description: TAIL SLURRY Density: 15.30(ppg) Yield: 1.3100 (ft'/sk) Mix Water Ratio: 4.200 (gaVsk94) Excess: Mix Method: BATCH Sacks Used: 187.00 (941b sacks) Water Volume: 18.7 (bbl) Excess Slurry Volume: Density Measured by: DENSOMETER Other Volume: Total Vol in Well: Slurry Volume: 43.6 (bbl) Excess Measured From: EST. GAUGE HOLE Mud Type: Density: PV: YP: Viscosity: Gels 10 Sec: Gels 10 Min: Addithin Name Type Amount Units Concentration Unit D163 CEMENT 5.000 %BWOC D047 ANTIFOAMAGENT 0.100 GALISX D206 ANTIFOAM AGENT 0.100 GAUSX 0065 DISPERSANT 1.000 %BWOC D600 G GAS-BLOCK 1.500 GAUSX D167 FLUID LOSS 0.100 %BWOC D177 RETARDER 0.120 GAUSX Fluid Testa Thick time Thick Free water Free water Fluid loss Fluid loss Fluid loss Comp Comp Comp Comp Comp Strength Comp Strength (hr) temp. (%) temp. (CC130min) temp. press. Strength Strength Strength Strength Time Pressure 2 Temperature 2 (°F) (°F) (•F) (psi) Time 1 Pressure 1 Temperature 1 2 (Ps0 ("F) min °F min) 5.57 202.00 0.00 80.00 50.0 180.00 Printed 6/28/2019 9:32.35AM Printed 6/26/2019 9:32:35AM North America - ALASKA - SP Page 2 of 2 Cementing Report ---- - Comnron Well Name: E-100/61 - - -- -- - -- — - - ,Report no.: t Report date. 5/27/2019 Pmlect PBU -TSite. E Spud Date/Time: 10/25/1997 Event Type: COM- ONSHORE (CON) Start Date: 5/26/2019 I End Data 5/28/2079 AFE No Contractor: NABORS ALASKA DRILLING INC. Rig Name/No.: CDR -2 Rig Release: 5/20/2019 X3 -019C7 -C: (2,616,338.00 ) BPUOI: USA00000716 Active datum: KB (dU71.00usfl (above Mean Sea Level) Steges Stage Stage Type Est. Top Est, Bottom Mud Circ. Mud Circ. Top Bottom plug Pressure Floal Pressure Returns Circulate Cmt Vol to Total Annular no. (usft) (usft) Rate Press. Plug Plug Bumped Bumped Hew Hew Prior Surface Mud Lost Flaw (gpm) (psi) (hr) (bbl) (bbl) After r -i) (m,e) 1 PRIMARY CEMENT 11,581.00 15,540.00 Y V y y Pumping Schedule Fluid pumped Volume Avg. Max Disp. Slurry Top Slurry Base Start Mix Cmt Start Slurry Pumping end Start Disp Foam Gas Type Gas Vol BH cim. Bh static Pumped Disp. Rate TMD TMD PM p date/time job Used temp. temp. (bbl) Rate (bbymin) (usft) (usft) (scf) bbymin Teats Casing Test Shoe Test Liner Top Test Test Pressure: (psi) FIT/LOT: (ppg) Liner Overlap: (usft) Time: (min) Tool: N Positive Test: (ppg) Positive Test Tool: N Cement Found between Shoe and Collar: N Open Hole Length: (usft) Negative Test: (PPg) Negative Test Tool: N Hours Before Start: (hr) Time before test: (hr) Curt Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: (usft) Under Pressure: (psi) How Determined Bond Quality: TOC Sufficient N CET Run: N Job Rating: Bond Quality: If Unsuccessful, Detection Indicator: Temp Survey: N Remedial Cement Required: N Him Prior to Log. (hr) How Determined: Printed 6/26/2019 9:32:35AM BAPRINT DISTRIBUTION LIST I1UGER HES % � a GE company COMPANY BP Exploration Alaska Inc. WELL NAME E -100A FIELD Prudhoe Bay Unit COUNTY PRUDHOE BAY BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Riqer@bh_qe.com STATUS Final Replacement: DIRSTITIMJTT"y ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION a ) OP North Slope. EOA, PROC, PRB-20 (Of rc 109) D&C Wells Project Aides Attn: Benda Glassmaker & Peggy O'Neil 900 E. Benson Bbd. Anchorage, Alaska 99508 2 Conocol hillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99501 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 218157 30 92 1 ise sign and return one copy of this transmittal form to: Exploration (Alaska) Inc. rotechnical Data Center, LR2-1 ) E. Benson Blvd. :h, AK 99508 or GANCPDC@bp365.onmicrosoft.com LOG TYPE GR - RES LOG DATE May 26, 2019 TODAYS DATE June 26, 2019 Revision No Details: Rev. Requested by: --- FIELD/ FINAL CD/DVD- FINAL PRELIM LOGS (las, tills, PDF, META, SURVEY I REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES +r v v v 0 1 0 1 0 0 1 0 1 1 1 1 10 RECEIVED JUN 2 7 2019 1 0 1 0 I A 1 0 I 0 1 0 1 1 1 1 1 0 1 0 5 DNR - Division of Oil & Gas *** 0 0 1 0 0 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on a6 material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Attn: Nancy Land! TOTALS FOR THIS PAGE: 0 2 4 2 0 BA �R FUGHES SO PRINT DISTRIBUTION LIST a GE company COMPANY BP Exploration Alaska Inc. WELL NAME E -100A FIELD Prudhoe Bay Unit COUNTY PRUDHOEBAY BHI DISTRICT Alaska 21 8 15 7 30901 Ise sign and return one copy of this transmittal form to: Exploration (Alaska)Inc. rotechnical Data Center, LR2-1 I E. Benson Blvd. :horage, Alaska 99508 or AKGDMINTERNAL@bp.com LOG TYPE RPM:PNC3D LOG DATE June 6, 2019 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bhge.com TODAYS DATE June 17, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: -- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V t BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aides Attn: Benda Glassmaker & Peggy O'Neil 900 E. Benson Blvd. Anchorage, Alaska 99508 FIELD/ FINAL CD/DVD FINAL ATO 3-344 PRELIM LOGS las, dlis, PDF, META, (las, SURVEY REPORT LOGS i Final Surveys) (Compass) 3201 C Street, Suite 505 # OF PRINTS Anchorage, AK 99503 # OF COPIES I#OFCOPIES l#OFCOPlES lu 4 2 ConocoPhillips Alaska Inc. i Attn: Ricky Elgarico ATO 3-344 700 G Street Anchorage, AK 99501 3 ExxunMobil, Alaska i Attn: Lynda M. Yaskell and/or Lisa Boggs 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC RECEIVED Attn: Makana Bender p JUN 18 2019 9 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 AOGCC 5 DNR - Division of Oil & Gas Attn: Garret Brown 550 West 7th Avenue, Suite 1100 .Anchorage, Alaska 99501 6 SP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Attn: Gerardo Cedillo TOTALS FOR THIS PAGE: 0 1 4 0 0 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY March 21, 2019 Ms. Katrina Gamer West Area manager/Reservoir Management, Prudhoe Bay Unit BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 RE: Docket Number: CO -19-010 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.olaska.gov Request to transfer a waiver of the gas oil ratio limitations of 20 AAC 25.240(a) from well Prudhoe Bay Unit E-100 (PTD 197-188) to the Prudhoe Bay Unit E - 100A (PTD 218-157) 111murwt MfSill=_ By letter dated March 4, 2019, BP Exploration (Alaska), Inc. (BPXA) requested that a waiver of the gas -oil ratio limitations in 20 AAC 25.240(a) granted on February 22, 2018, for the testing of the Prudhoe Bay Unit E-100 well (PBU E-100) (PTD 197-188) be transferred to the well Prudhoe Bay Unit E -100A (PBU E -100A) (PTD 218-157). 'BPXA stated that the PBU E-100 well proved not useable for the planned test of the Sag River and Ivishak formations and that the PBU E -100A well will be drilled to replace the PBU E-100 wellbore and conduct the proposed flow test. BPXA's request is granted under the conditions below. The PBU E-100, was completed as a water injector in the Midnight Sun Oil Pool, but is no longer needed since it was replaced by the PBU P1-122 well. The PBU P1-122 has the capability to inject miscible injectant, which the PBU E-100 lacked since there was no MI supplied to E -Pad. Since this well was no longer needed as a Midnight Sun injection well BPXA planned to recomplete the well to conduct an extended flow test in the Sag River and Ivishak Formations. The Prudhoe Oil Pool (POP) contains the Sag River and Ivishak formations and has an existing GOR waiver due to the ongoing enhanced recovery project in the POP, but the location of the PBU E-100 was outside the affected area of the POP. The PBU E-100 well proved unusable for the planned test and BPXA has proposed drilling the PBU E -100A sidetrack to conduct the planned test of the Sag River and Ivishak formations in this portion of the field. Since the PBU E -100A well would be outside the POP boundary it is subject to statewide regulations and the GOR limitations of 20 AAC 25.240 apply to the proposed test of this well. BPXA plans to collect detailed well testing data and fluid samples, after completion of this testing period BPXA plans to connect the well to temporary production facilities and put it on regular production to collect longer term performance data. BPXA will make future SCANNED 012019 Docket Number: CO -19-010 March 21, 2019 Page 2 of 2 development decisions, which may include expanding the POP to encompass this area, based on the results of the collected performance data. Because the GOR of the well might increase above the GOR limits during testing, BPXA has requested a GOR waiver while it collects reservoir performance data in order to determine future development plans for this area. In accordance with 20 AAC 25.240(b)(3) BPXA's request is granted on the following conditions: 1) The GOR waiver for the PBU E-100 well dated February 22, 2018, is hereby rescinded. 2) The PBU E -100A well must be tested in accordance with the PBU's well testing and allocation procedures and must be tested at least twice per month while flowing. 3) The GOR waiver expires one year after the extended flow testing period commences. BPXA must notify the AOGCC when the extended flow testing period commences. 4) On a quarterly basis, the operator must submit copies of all well tests for the PBU E -100A well showing the GOR at the time of the test. 5) Prior to expiration of this GOR waiver the operator must meet with the AOGCC to discuss results during this test period and future development plans for this area. DONE at Anchorage, Alaska and dated March 21, 2019. Daniel T. Seunount, Jr. Commissioner ' � J JeIe L. Chmielowski missioner As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state hnliday. March 4, 2019 Commissioners Alaska Oil and Gas Conservation Commission 333 West 7"' Ave, Suite 100 Anchorage, AK 99501 RE: Docket Number OTH-18-017 E -100A: Transfer of Temporary GOR Waiver from E-100 Dear Commissioners: BP Exploration (Alaska) Inc 900 East Benson Boulevard P O Box 196612 Anchorage. Alaska 99519-6612 (907)561-5111 C E2iVEb, MAR 0 6 2019 ACCCC BP Exploration (Alaska), Inc (BPXA), as operator of the Prudhoe Bay Unit, requests that the temporary GOR waiver granted February 22, 2018 for the E-100 recompletion attempt be transferred to the sidetrack E -100A (PTD 218-157). E -100A is a new wellbore which will be drilled because E-100 was not useable for its planned test. In E - 100A, BPXA plans to collect the same data as were proposed for the E-100, and requests the same time frame (one year from commencement of extended flow testing) for the temporary waiver. If you have any questions regarding the reports please contact Bill Bredar at 564-5348 or through email at William.bredargbp.com. Respectfully, 9 L, -�-w� Katrina Gamer West Area Manager/Reservoir Management, Prudhoe Bay Unit Alaska Reservoir Development, BPXA Cc: Eric Reinhold, ConocoPhillips Alaska, Inc Jeff Farr, ExxonMobil Alaska, Production Inc Dave White, Chevron USA Dave Roby, AOGCC Kevin Pike, SOA DNR -Division of Oil and Gas THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean M. McLaughlin CTD & RWO SDE BP Exploration (Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 wwW.aog CC.alaska.gov Re: Prudhoe Bay Field, Sambuca Undefined Oil Pool, PBU E -1 00A BP Exploration (Alaska), Inc. Permit to Drill Number: 218-157 Surface Location: 5001' FSL, 500' FEL, SEC. 06, TI IN, R14E, UM Bottomhole Location: 2853' FSL, 589' FEL, SEC. 29, T12N, R14E, UM Dear Mr. McLaughlin: Enclosed is the approved application for the permit to redrill the above referenced development well. 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. 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, of an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair k�-, DATED this (0 day of December, 2018. STATE OF ALASKA ASKA OIL AND GAS CONSERVATION CO11i PERMIT TO DRILL 20 AAC 25.005 RECEIVED NOV 2 6 2018 la. Type of Work:1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG 13Service -Dip❑ 1c. Specify proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil 0 • Service - Winj ❑ Single Zone 0. (if �well�'is Coalb§�� s I lr tes ❑ Rednll 0 Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name. 5. Bond Blanket 0 • Single Well ❑ 11. Well Name and Number: BP Exploration (Alaska), Inc Bond No. 29SIO5380 PBU E -1 00A 3 Address: B. Proposed Depth: 12. Field/Pool(s): P.O. Box 196512 Anchoratie, AK 9951 M612 MD: 15580' " TVD: 9129'ss PRUDHOE BAY, SAMBUCAA OIL 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): �lA //. 22 ADL 028304 8 028299 8. DNR Approval Number: 13. Approximate spUd date: Surface: 5001' FSL, 500' FEL, Sec. 06, T11N ,R14E, UM 2878' FSL, 1631' FEL, Sec. 30, T12N, R14E, UM 89-111 January 1, 2019 Top of Productive Horizon: 9. Acres in Property: 2469 8 2459 14. Distance to Nearest Property: Total Depth. 2853' FSL, 589' FWL, Sec. 29, T12N, R14E, UM 880 4b, Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 71.0 feet 15. Distance to Nearest Well Open to Same Pool: Surface. x- 664447 ' y- 5976785 Zone - ASP 4 GL Elevation aMSL: 30.2 feet bove 16. Deviated wells: Kickoff Depth: 12986 - feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 100 degrees Downhole: 3725 / 3848 Surface. 2794 / 3040 18. Casing Program: Specifications Top- Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casina Weight Grace Couolino Len th MD TVD MID TVD includinq stage datal 4-1/4" 3-1/4"x2-7/8" 6.6#/6.5# L-80 STL/TCII 4000' 11580' 791 Yes 15580' 9129'ss 201 sx Class'G' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measuretl): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 13282 9423 13018,13024 13018 9176 13000 Casing Length Size Cement Volume MD TVD CondudodStructural 80 20" 260 sx Arctic Set (Approx.) 43 - 123 43-123 Surface 4398 9-5/8" 2189 sx PF'E% 335 sx Class'G' 43-4441 43-3689 Intermediate 12867 7" 300 sx Silicalite 40-12906 40-9072 Production Liner 1382 4-12" 180 sx Class'G' 11845 - 13227 8171-9371 Perforation Depth MD (ft): 11665 - 13165 Perforation Depth TVD (ft): 8045-9313 Hydraulic Fracture planned? Yes ❑ No 0 20. Attachments Property Plat ❑ BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Name Browning. Zachary H from without prior written approval. Contact Email Zachary.Browning0bp.com Authorized Name McLaughlin, Sean M Authorized Title CTD RWO SDE Contact Phone +1 907 564 5220 Authorized Signature Data 11 26 Commission lJsb Only Permit to Drill -1 / ��1 7 API: 50- 029-22819-01-00 Permit Approval See cover letter for other Number: / Date: 1 requirements: Conditions of approval If box is checked well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Be, PcTE_Sr lc 3Slo '51 ❑ No log Yes ❑ No Other: Samples req' Yes / Mud req'd : Hz�+�AH-►�`�`Pl P1n�.� r -t vh. b ce+a 20L9 At25, H2S measures Yes No ❑1 Directional svy req'd: Yes 51 No ❑ kp/ Spacing exception req'd: Yes ❑ No ® Inclination -only svy req'd: Yes ❑ No Id Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY I Approved by: COMMISSIONER THE COMMISSION Date: 'IZ l l Foran 10401 Revised 5/2017 This permit is valid for 24 mo Q fpr\ IelQyleJO,ap A LAAC 25.005(g)) Submit Form and (vLG.R o6DECC6 Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Zach Browning CTD Engineer Date: November 26, 2018 Re: E -100A Permit to Drill Request p Approval is requested for a permit to drill a CTD sidetrack lateral from well E-100 with the Nabors CDR2 Coiled Tubing Drilling rig on or January 1", 2019. Proposed plan forE-100A: The sidetrack E -100A will be the first producer in the Sambuca block in the Sag or Ivishak. It will be a 2600' coil sidetrack drilled with the Nabors CDR2 rig on or around January 1" 2019. The objective will be Ivishak and Sag production via a U-shaped well. During pre -rig work it is proposed to squeeze off the Kuparuk perfs if possible, and pressure test. Then a whipstock will be se in the 4-1/2" liner. The rig will move in, test BOPE and kill the well. A 3.80" window + 10' of rathole will be milled. The well will kick off in the sag, build and land in Zone 2 before inverting back up into the sag in a U-shaped profile. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" L-80 solid liner, cemented in place and selectively perforated (post rig). This completion will completely isolate and abandon the parent Kuparuk and Ivishak perfs and allow for production solely from the Ivishak. Rig Work (scheduled to begin January V, 2019) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP: 2794 psi if Kuparuk is successfully isolated, 3040 psi if Kuparuk is open). 2. Mill 3.80" Window+ 10' of rathole 3. Drill build section: 4.25" OH, `600' (20 deg DLS planned). 4. Drill lateral section: 4.25" OH, 2000' (12 deg DLS planned). 5. Run 2-7/8" x 3-1/4" L-80 liner to TD. 6. Pump primary cement job: 41.5 bbls, 15.3 ppg Class G, TOC at TOL ("11,580 MD)*. 7. Freeze protect well to a min 2,200' TVDss. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. V: Valve & tree work 2. F: Test Liner Lap 3. C: Drift. RPM log. Perforate "100'. Contingent CBL. 4. S: SBHPS, set LTP* (if necessary). Set live GLVs. 5. T: Portable test separator flowback. Operation Details: Mud Program: • If KUP is isolated: Drilling/Completion: a min EMW of 8.4 ppg KCL with Geovis for drilling (343 psi over -balance). • If KUP is open: Drilling/Completion: a min EMW of 9.4 ppg KCL with Geovis for drilling (100 psi over -balance). Disposal: • All Class 1& II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3 at DS 6. • Fluids >3% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. • Fluids with solids that will not pass through 1/4" screen must go to GNI. • Fluids with PH >11 must go to GNI. Hole Size: • 4.25" for entirety of the production hole section. Liner Program: • 2-7/8", 6.511, L-80 solid liner: 15,580' MD -14,400' MD • 3-1/4", 6.611, L-80 solid liner: ✓ 14,400' MD —11,580' MD • A planned 41.5 bbls of 15.3 ppg ceem nt will be used for liner cementing (TOC = TOL at —11,580' MD). • The primary barrier for this operation: a minimum EMW of 8.4 ppg (343 psi over -balance) if KUP isolated, and 9.4 ppg (100 psi over -balance) if KUP open. • A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi.'/ Directional: • See attached directional plan. Maximum planned hole angle is 100`, inclination at kickoff point is 22°. • Magnetic and inclination surveys will betaken every 30 ft. No gyro will be run. • Distance to nearest property — 880' • Distance to nearest well within pool — N/A Well is out of the pool Logging: • MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. • A cased hole GR/CCL/RPM log is planned post rig. Perforating: • Perforating: —100' of perforations (post -rig), 2", 60 deg random phasing, 6 spf, perf guns. • A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti -Collision Failures: • None. All offset wells pass BP anti -collision scan criteria. Hazards: • E -pad is considered an H2S pad. No H2S data on E-100 (injector). Max recorded on the pad: 130 ppm on E-102 (9/25/09). . • There is one predicted fault crossings along this well plan. It is expected to have `20' of throw DTN. Moderate risk of losses expected at the crossing. • Overall Lost circulation risk on E -100A is considered Low. Reservoir Pressure: • The Ivishak reservoir pressure on E -100A is expected to be 3725 psi at 9315' TVDSS (7.69 ppg equivalent). • The Kuparuk reservoir pressure on E-100 is expected to be 3848 psi at 8078' TVDSS (9.16 ppg equivalent). Kuparuk is planned to be isolated pre -rig with a cement squeeze. • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2794 psi if Kuparuk is successfully isolated, 3040 psi if Kuparuk is open. • Amin EMW of 8.4 ppg for this well will provide 343 psi over -balance to the Ivishak reservoir. • A min EMW of 9.4 ppg will be used if Kuparuk is open and will provide 100 psi overbalance to the Kuparuk reservoir. Zach Browning CC: Well File CTD Engineer Joseph Lastufka 564-5220 ( 9-5/e' CSG, 47#, L-80, D = 8.681' —i "41 Minimum ID = 3.813" (aD' 2242' 4-112" HES HX O SVLN ASSY OF 4-1/2' LNR PERFORATION SL1w. MIRY REF LOG: SNS-EllICSIGR ON 11/24/97 WflLF£AD= Fl -- ACTUATOR= BAKH2 KBR 6W __.. - - E1F. BEV = _-- -_ KOP= _--- -- 11W W An = 57' Q 3950' Datum AD= 11771' Datum ND= - 8050'SS ( 9-5/e' CSG, 47#, L-80, D = 8.681' —i "41 Minimum ID = 3.813" (aD' 2242' 4-112" HES HX O SVLN ASSY OF 4-1/2' LNR PERFORATION SL1w. MIRY REF LOG: SNS-EllICSIGR ON 11/24/97 ANGLE AT TOP PERF: 47` @ 11665' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpNSgz DATE 3-3/8" 6 11665-11775 O 11117100 3-3/8" 8 11775-11795 O 11/07/00 33/8' 6 12960-13010 O 08/12/00 2-7/8" 6 13150- 13155 C 12/26/97 2-112" 4 13155 - 13165 C 12/19/97 E-100 w SAFETY NOTES: CE EWE CAP @ 12370' 1 2242' H4-1/2' FfS. HXO SVLN ASSY. D = 3.813' I GAS LFT M1NORES ST AD TVD DEV TYPE VLV LATCH PORT DATE 6 3401 3072 47 KBG-2-1-S DW INT 0 08/26/18 5 5101 4079 54 KBG-2-LS OW7' NT 0 08/26118 4 6751 5070 52 KBG-2-LS DW NT 0 08/26118 3 8441 6069 54 KBG-2-LS DW NT 0 08/26/18 2 10094 7067 52 KBG-2-LS DW NT 0 08/26/18 1 11543 7964 50 KBG-2-LS MY NT 0 08/26/18 1 11609' 1 14-1/2- FES X NP. ID = 3.811- 1 i 11646' H4-1/2" V1lEG, 3.958• 11648' ELkD TT LOGGED 12/12/97 1 11862' 1 13000' 13018' CTM DATE REV BY COMA, NTS DATE REV BY COLOA34M 12/15/97 ORIGINAL COMPLETION 07/12118 RCS/AD GLV CIO (071W1 8) 1025/00 SIS-Isl CONVERTIDTOCANVAS 07130/18 JL/JAD MILLET) CMT &SAND(0729/18) 01/10/01 SIS -LG REVISION 08/29118 JW. -d AD GLV 55(o826118) 10/04/01 RWTP CORFECTIONS 09112/18 JMGdJAD LEFT FISH DH(0826118) 04/08103 DRS/TP WOMU COHECTIONS 11105/18 JAO MINOR CLEAN LIP PEER TALLY 07/18/17 LMAD CORRECTIONS TO SAND & I BAKER ZXP PKR/ HGR I HIS X NP. D=3.813' 4-112" HES X NP, D = 3.813 - FISH: SL TOOLSTRNG LOST ON TOP OF RUG 29.7' OAL, TIED INTO TBG TAIL (08/26/18) MLLED CWT 8 CLEANED OUT SAND ,ES XN NAP, D=3.7: RUG SET 01/11/98 MDNGFTT SL1N LINT WELL E-100 FEiMT No: 1971880 API No: 50-02322819-00 T11 N, RI4F SOWNSL 8 5WWEL BP Exploration (Alaska) TREE= ins•, 5000 FS V4fl1lH1D= FMC,11 ACTLbkTOR= BAKER KB.ELEV = 89' BF. 9.E/ = 6 KOP= 1100' Max Angle = _' @ ' DKurn MD= _ Dak1mTVD= 805(y SS PROPOSED E-1 OOA I SAFMNOTES: CEMEPIT CAP@ 12370' 2242' 4-1/2' FES, FlXO SVLN ASSY, D = 3.813' O227T 9-5/8' FIB CEMENTER GAS LFT MANDRELS 9.5/8- CSO. 479. L-00, D - 8.651- N 4447 Minimum ID = 3.813" @ 2242' 4-1/2" HES HXO SVLN ASSY ST MJ ITVDIDEVI TYPE VLV LATCH FORT DATE 6 3401 3072 47 KBG2-LS DMY M 0 08/26/18 5 5101 4079 54 KBG-2-LS OMY M 0 08/26/18 4 6751 5070 52 KBG-2-LS DMY M 0 08126/18 3 8441 6069 54 KBG-2-LS DMY M 0 oa/26118 2 10094 7067 52 KBG-2-LS DOW M 0 08/26/18 1 11543 7964 50 KBG-2-LS DOW M 0 08/26/18 11609' 4-12' FES X NP, D = 3.81' 11820' T X 4-12' BAKER SB -3 WM D - 3.875' 11636' 4.12' FES X NP, D= 3.81' 4-12' TBG, 12.69, L-80_0152 bpf, D = 3.958' 11646' 11646' 4-12' ALEC, 3 958' 11648' HELmD TT LOGO 12/12197 OF 4-12' LNR 11862' P07FORATM SLIM1M1ARY REF LOG: ON ANGLE AT TOP PEW: _"@ Note: Refer to Production DB for historical perf data 7- CSG, 299, L-80, D = 8.184' 3-1/4' LNR, 6.6#. L-80 TCI 1..0079 bpf, D = PBTD — LNR 6.59, L-80 STL, .0058 bpf. D = 2.441' 16680' 11862' NBAKt322XPFMFr-R 11870' .813' DATE RET/ BY 0OWNT6 DATE REV BY COMMENTS 1211597 ORIGINAL COMPLETION 11/05/18 CTD(E-1DOA) 11/05/18 JMD BUILT PROPOSAL IPOPJT W IRA TAG I KDNIGHT SUN LINT VA LL: E -100A PERMIT No: API No: 50 -020 -22819 - TI 1 0-029-22819-T11 R R14F 5000' NSL & 500' W EL BP Exploration (Ala ka) North America - ALASKA - BP PBU E E-100 PLAN E -100A Plan: E -1 00A WP03 BP Coil Tubing Report 20 November, 2018 DAM Company: North America -ALASKA - BP Project PBU Site: E Well: E-100 Wellbore: PLAN E -100A Design: E -100A WP03 BP BP Coil Tubing Report Local Co-ordinate Reference: Well E-100 TVD Reference: Mean Sea Level MD Reference: KB @ 71.00usft ' North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Project PBU, PBU, PRUDHOE Map System: Alaska NAD27 State Plane Zones System Datum: Mean Sea Level Geo Datum: NAD27' OGP-Usa AK [4267'15864] Using Well Reference Point Map Zone: NAD27'OGP-Usa AK/ Alaska zone 4[26734'1586 Using geodetic scale factor Site E, TR -11-14 Site Position: 662,538.970 usft From: Map Position Uncertainty: 0.00 usft Well E-100, E-100 Well Position +N/ -S 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.00 Usti Wellbore PLAN E -100A Magnetics Model Name Sample Date BGGM2018 4/1/2019 Design E -100A WP03 Audit Notes: Version: Vertical Section: Phase: Depth From (TVD) (usft) -31 16 Northing: 5,973,160.880 usft Easting: 662,538.970 usft Slot Radius: 0.000 in Northing: 5,976,784.650 usft Easting: 664,447.430 usft Wellhead Elevation: 31.16 usft Declination 1°I 1694 PROTOTYPE +NAS (usft) 0.00 Latitude: Longitude: Grid Convergence: Latitude: Longitude: Ground Level: Dip Angle Field Strength 1°I (nT) 80.96 57,433 Tie On Depth: 12.950 00 +E/ -W Direction (usft) 1°1 000 90 00 70° 19'59.134 N 148' 40'53.054 W 1.24 ° 70' 20'34.358 N 148° 39'55,015 W 30.20 usft . 11/2012018 9: 15 58A Page 2 COMPASS 5000.1 BUdd 81D by Company: North America - ALASKA - BP Local Co-ordinate Reference: Project: PBU Site: E TVD Reference: Mean Sea Level Well: E-100 Wellbore: PLAN E -100A KB @ 71.00usft Design: E-100AWP03 Survey Tool Program Date 11/20/2016 True From To Survey Calculation (usft) (usft) Survey (Wellbore) 100.00 12,950.00 3Gyrodata contcasing m/s (E-100) 12,950 00 15,580.00 E -100A WP03 (PLAN E -1 00A) Planned Survey Tool Name Description�I MD Inc Azi TVDSS (usft) (°) V) (usft) 12,950.00 22.23 2.11 9,041.35 E-100 Actual Survey - TIP 12,957.18 22.12 1.75 9,048.00 TSGR DLeg V. Sec TFace 12,986.00 21.68 0.27 9,074.74 KOP (usft) (°) 8,241.03 13,000.00 22.94 0.27 9,087.70 13,006.00 23.48 0.27 9,093.21 3 663,124.912 2.45 -1,142.04 13,013.45 24.97 0.27 9,100.00 TSHU 245 -1,141.85 -129.16 13,027.96 27.87 0.27 9,113.00 TCGL -1,141.83 0.00 8,262.16 13,074.26 37.13 0.27 9,15200 TSAD 0.00 8,265.21 -1,141.80 13,100.00 42.28 027 9,171.80 13,126.00 4748 0.27 9,190.22 4 20.00 -1,141.77 0.00 13,133.11 47.98 2.07 9,195.00 PGOC -1,141.66 0.00 8,312.96 13,200.00 53.91 17.55 9,237.28 13,224.04 56.49 22.49 9,251.00 BCBL 663,123.544 20.00 -1,141.49 BP BP Coil Tubing Report 111202018 9:15:58AM Page 3 COMPASS 5000 1 Build 81D Local Co-ordinate Reference: Well E-100 TVD Reference: Mean Sea Level MD Reference: KB @ 71.00usft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K- Alaska PROD - ANCP1 Tool Name Description�I GVD-CT-CMS Gyrodata contcasing m/s MWD MWD -Standard NIS ENV Northing Eating DLeg V. Sec TFace (usft) (usft) (usft) (usft) (°NOOusft) (usft) (°) 8,241.03 -1,142.14 5.984,998 069 663,124.880 0.00 -1,142.14 0.00 8,243.73 -1,142.04 5,985,000.777 663,124.912 2.45 -1,142.04 -129.49 8,254.48 -1,141.85 5,985,011.526 663,124.867 245 -1,141.85 -129.16 8,259.80 -1,141.83 5,985,016.839 663,124.775 9.00 -1,141.83 0.00 8,262.16 -1,141.82 5,985,019.203 663,124.735 9.00 -1,141.82 0.00 8,265.21 -1,141.80 5,985,022.258 563,124.682 20.00 -1,141.80 0.00 8,271.67 -1,141.77 5,985,028.715 663,124.571 20.00 -1,141.77 0.00 8,296.52 -1,141.66 5,985,053.558 663,124.143 20.00 -1,141.66 0.00 8,312.96 -1,141.58 5,985,069.994 663,123.860 20.00 -1,141.58 0.00 8,331.30 -1,141.49 5,985,088.330 663,123.544 20.00 -1,141.49 0.00 8,336.56 -1,141.38 5,985,093.593 663,123.536 20.00 -1,141.38 70.00 8,387.39 -1,132.30 5,985,144.605 663,131.506 2000. -1,132.30 68.79 8,405.92 -1,125.53 5,985,163.278 663,137.864 20.00 -1,125.53 58.99 111202018 9:15:58AM Page 3 COMPASS 5000 1 Build 81D am BP BP Coil Tubing Report Company: North America - ALASKA - BP Local Coordinate Reference: Well E-100 Project: PBU TVD Reference: Mean Sea Level Site: E MD Reference: KB @ 71.00usft Well: E-100 North Reference: True Wellbore: PLAN E -100A Survey Calculation Method: Minimum Curvature Design: E-t00AWP03 Database: EDM RSK- Alaska PROD -ANCP1 Planned Survey MD Inc Azi TVDSS NIS ENy Northing Easting DLeg V. Sec Waco (usft) r) (`) (usft) (usft) (usft) (usft) (usft( ("HOeusfq (usft) r) 13,254.43 60.01 28.32 9,257.00 8,42924 -1,114.43 5,985,186.831 663,148.451 20.00 -1,114.43 56,17 POWC 13,300.00 65.73 36.31 9,287.80 8,463.42 -1,092.72 5,985,221.479 663,169.401 20.00 -1,092.72 53.09 13,311.00 67.17 38.12 9,292.19 8,471 AS -1,086.62 5,985,229.639 663,175.321 20.00 -1,086.62 4944 5 13,400.00 83.99 44.16 9,314.30 8,535.99 -1,030.02 5,985,295.397 663,230.491 20.00 -1,030.02 2000. 13,431.00 89.87 46.12 9,315.96 8,557.61 -1,008.09 5,985,317.697 663,251.936 20.00 -1,008.09 18.48 6 13,500.00 89.88 59.92 9,316.11 8,599.22 -953.10 5,985,360.298 663,305.996 20.00 -953.10 90.00 13,591.00 89.89 78.12 9,316.30 8,631.67 -868.50 5,985,394.593 663,389.866 20.00 -868.50 89.97 End 20dis 13,600.00 89.89 79.20 9,316.32 8,633.44 -859.67 5,985,396.557 663,398.649 12.00 -859.67 90.00 13,700.00 89.89 91.20 9,316.51 8,641.80 -760.20 5,985,407.093 663,497.901 12.00 -760.20 90.00 13,800.00 89,90 103.20 9,316.69 8,629.29 -661.17 5,985,396.764 663,597.176 12.00 -661.17 89.98 13,891.00 89.91 114.12 9,316.83 8,600.22 -57509 5,985,369.594 663,683.874 12.00 -575.09 89.95 7 13,900.00 89.91 113.04 9,316.85 8,596.62 -566.84 5,985,366.176 663,692.199 12.00 -566.84 -90.00 14,000.00 89.91 101.04 9,317.00 8,567.38 471.40 5,985,339.033 663,788.248 12.00 -471.40 -90.00 14,100.00 89.92 89.04 9,317.15 8,558.61 -371.97 5,985,332453 663,887.841 12.00 -371.97 -89.98 14,191.00 89.93 76.12 9,317.27 8,568.78 -281.68 5,985,344.595 663,977.882 12.00 -281.68 -89.96 8 14,200.00 89.93 79.20 9,317.28 8,570.55 -272.85 5,985,346.558 663,986.664 12.00 -272.85 90.00 14,300.00 89.93 91.20 9,31740 8,578.91 -173.39 5,985,357.095 664,085.917 12.00 -173.39 90.00 14,400.00 89.94 103.20 9,317.52 8,566.40 -74.36 5,985,346.765 664,185.191 12.00 -74.36 89.98 14,411.00 89.94 104.52 9,317.53 8,563.77 -63.68 5,985,344.366 664,195.925 12.00 -63.68 89.97 9 14,496.00 99.39 108.37 9,310.63 8,539.83 17.47 5,985,322.220 664,277.576 12.00 17.47 22.00 10 1120/2018 9:15:58AM Page 4 COMPASS 5000.1 Build BID by BP BP Coil Tubing Report Company: North America - ALASKA- BP Local Co-ordinate Reference: Well E-100 Project: PBU TVD Reference: Mean Sea Level Site: E MD Reference: KB @ 71.00usft Well: E-100 North Reference: True Wellbore: PLAN E -100A Survey Calculation Method: Minimum Curvature Design: E-100AWP03 Database: EDM RSK- Alaska PROD -ANCPI Planned Survey MD Inc AN TVDSS _ NIS ENV Northing Easting DLeg V. Sec TFace (usft) (°) i°) (usft) (usfy (usft) (usft) (usft) (°/100usft) (usft) (°) 14,500.00 99.39 108.86 9,309.98 8,538.57 21.21 5,985,321.043 664,281.343 12.00 21.21 89.00 14,556.00 99.44 115,67 9,300.80 8,517.66 72.31 5,985,301.252 664,332.881 12.00 72.31 89.08 11 14,600.00 99.67 110.32 9,293.49 8,500.71 112.24 5,985,285.188 664,373.166 12.00 112.24 -87.00 14,700.00 99.90 98.15 9,276.44 8,476.52 207.56 5,985,263.101 664,468.996 12.00 207.56 -87.89 14,800.00 99.69 85.97 9,259.37 8,473.00 305.85 5,985,261.730 664,567.326 12.00 30585 -89.97 14,856.00 99.38 79.16 9,250.08 8,480.14 360.58 5,985,270.070 664,621.881 12.00 360.58 -92.04 12 14,900.00 99.62 84.51 9,242.81 8,486.30 403.52 5,985,277.171 664,664.673 12.00 403.52 87.00 15,000.00 99.84 96.68 9,225.85 8,485.28 501.88 5,985,278.306 654,763.024 12.00 501.88 87.88 15,100.00 99.64 108.86 9,208.87 8,463.53 597.80 5,985,258.670 664,859.400 1200. 597.80 89.95 15,156.00 99.34 115.67 9,199.63 8,442.62 648.89 5,985,238.883 664,910.927 12.00 648.89 92.02 13 15,200.00 99.57 110.32 9,192.39 8,42567 688.83 5,985,222.818 664,951.226 12.00 688.83 -87.00 15,300.00 99.80 98.15 9,175.51 8,401.48 784.19 5,985,200.728 665,047.085 12.00 784.19 -87.88 15,400.00 99.60 85.97 9,158.60 8,397.95 882.50 5,985,199.354 665,145.443 12.00 882.50 -89.93 15,456.00 99.30 79.17 9,149.39 8,405.09 937.24 5,985,207.693 665,200.011 12.00 937.24 -91.99 14 15,500.00 99.35 84.52 9,142.26 8,411.25 980.20 5,985,214.792 665,242.826 12.00 980.20 89.00 15,580.00 99.24 94.24 9,129.30 8,412.10 1,059.05 5,985,217.372 665,321.628 12.00 1,059.05 89.87 TD at 16580.00 1112012018 9'15:58AM Page 5 COMPASS 5000.1 Build 81D BP BP Coil Tubing Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well E-100 Project: PBU TVD Reference: Mean Sea Level Site: E MD Reference: KB @ 71.00usft Well: E-100 North Reference: True Wellbore: PLAN E -100A Survey Calculation Method: Minimum Curvature Design: E-100AWP03 Database: EDM RSK- Alaska PROD -ANCP1 Plan Annotations Measured Vertical Local Coordinates Depth Depth +W -S +E/ -W (usft) (usft) (usft) (usft) Comment 12,950.00 9,041.35 8,241.03 -1,142.14 E-100 Actual Survey - TIP 12,986.00 9,074.74 8,254.48 -1,141.85 KOP 13,006.00 9,093.21 8,262.16 -1,141.82 3 13,126.00 9,190.22 8,331.30 -1,141.49 4 13,311.00 9,292.19 8,471.45 -1,086.62 5 13,431.00 9,315.96 8,557.81 -1,008.09 6 13,591.00 9,316.30 8,631.67 -868.50 End 20d1s 13,891.00 9,318.83 8,600.22 -575.09 7 14,191.00 9,317.27 8,568.78 -281.68 8 14,411.00 9,317.53 8,563.77 -63.68 9 14,496.00 9,310.63 8,539.83 17.47 10 14,556.00 9,300.80 8,517.66 72.31 11 14,856.00 9,250.08 8,480.14 360.58 12 15,156.00 9,199.63 8,442.62 648.89 13 15,456.00 9,149.39 8,405.09 937.24 14 15,580.00 9,129.30 8,412.10 1,059.05 TO at 15580.00 1112012018 9'15:58AM Page 6 COMPASS 5000.1 Build 81D #-�Av� 4 kP `naaNl� North America - ALASKA - BP PBU E E-100 PLAN E -100A E -1 00A WP03 Anticollision Summary Report 20 November, 2018 hp Company: North America - ALASKA - BP Project: PBU Reference Site: E Site Error: 0.00usft Reference Well: E-100 Well Error: 0,00usft Reference Wellbore PLAN E -100A Reference Design: E -100A WP03 BP Anticollision Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well E-100 Mean Sea Level KB @ 71.O0usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference E -100A WP03 Filter type: NO GLOBAL FILTER: Using user defined selection 8 filtering criteria WARNING: There is hidden tight data in this project Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 12,950.00 to 15,580.00usft Scan Method: Trani. Cylinder North Results Limited by: Maximum center -center distance of 1,754.02usft Error Surface: Elliptical Conic Survey Tool Program Date 11/20/2018 From To (usft) (usff) Survey (Wellbore) Tool Name Description 100.00 12,950.00 3: Gyrodata contcasing mis (E-100) GVD-CT-CMS Gyrodata cont casing m/s 12,950.00 15,580.00 E -100A WP03 (PLAN E -100A) MWD MWD - Standard Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usR) from Plan Offset Well - Wellbore - Design (us@) (usR) lush) (usR) E E-07 - E -07A - E -07A Out of range E-07 - E -07B - E -07B Out of range E-08 - E-08 - E-08 Out of range E-08 - E -08A - E -08A Out of range E-09 - E-09 - E-09 Out of range E-09 - E -09A - E -09A Out of range E-09 - E-09APB1 - E-09APB1 Out of range E-09 - E -09B - E-098 Out of range E-09 - E -09C - E -09C Out of range E-09 - E-09CPB1 - E-09CPB1 Out of range E -100 -E -100-E-100 12,950.00 12,950.00 0.00 0.00 0.00 Pass-NOERRORS E-11 - E-11 1311-01 - E-11131-1 -01 Out of range E-34 - E-34 - E-34 Out of range E-34 - E -34A - E -34A Out of range E-34 - E-3411 - E-3411 Out of range E-38 - E-38 - E-38 Out of range E-38 - E-38PB1 - E-38PB1 Out of range E-38 - E-38PB2 - E-38PB2 Out of range 111202018 8:55,15AM Page 2 of 3 COMPASS 5000.1 Build 81D MI Company: North America - ALASKA - BP Project: PBU Reference Site: E Site Error: O.00usft Reference Well: E-100 Well Error: O.00usft Reference Wellbore PLAN E -100A Reference Design: E -100A WPO3 BP Anticollision Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well E-100 Mean Sea Level KB Q 71.00usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP7 Offset Datum Reference Depths are relative to KB (off 71.00usft Coordinates are relative to: E-100 Difset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27' OGP-Usa AK -en[ml Meridian is 150° 0'0.000 W ° Grid Convergence at Surface is: 1.28° Ladder Plot 7500 10000 12500 15000 Measure Depth 12500 usfUn) $ E-07,E-07B,E-07BVO I I I I -X- E-07, E-07, E-07 V5 ------------ --------- --- ------------ ----------- i I -I- E-07,E-07APB2, E-07APB2 V1 -} E-09,E-09APB1, E-09APB1 V1 -6- E-11, E-11 BLI P81, E-11 BLt P61 V2 -t- E-07,E-07A,E-07AV2 $ E-09,E-09C,E-09CVO $ E -11,E-11 BLt PB1, Plan#7 VI � I I $ E-34,E-34A,E34AVO $ E -102,E -102,E-102\114 $ E-t0,E-10,E-10V10 $ E -34,E -34,E -34V7 M I I I C E-11,E-11A,E-11AV1 E -38,E -38,E-38\11 -A- E-08,E-0SA,E-08AV3 -ate E-11,E-11811PB2,E-11BL1PS2V1 -IS- E-38,E-38PB2, E-38PB2 V1 ry I d I I I C I I v I p I L1 C ra 30U I I I I I i I I I I I 7500 10000 12500 15000 Measure Depth 12500 usfUn) $ E-07,E-07B,E-07BVO $ E-09,E-09A,E-09AV1 $ E-11, E-11 BL1, E-11 BL7 V3 -X- E-07, E-07, E-07 V5 -)F E-09, E-09, E-09 V3 -F E -11,E-11 BU -01,E-11611-01 V4 -I- E-07,E-07APB2, E-07APB2 V1 -} E-09,E-09APB1, E-09APB1 V1 -6- E-11, E-11 BLI P81, E-11 BLt P61 V2 -t- E-07,E-07A,E-07AV2 $ E-09,E-09C,E-09CVO $ E -11,E-11 BLt PB1, Plan#7 VI $ E-07,E-07APBl.E-07APB1 V1 $ E -10,E -t OA,E-t0AV8 $ E-34,E-34A,E34AVO $ E -102,E -102,E-102\114 $ E-t0,E-10,E-10V10 $ E -34,E -34,E -34V7 $ E -104,E -104,E -104V11 $ E-10,E-10B,E-10BV4 $ E-34, E341-1, E-3411 VO -F E -100,E -100,E -100V3 E-11,E-11A,E-11AV1 E -38,E -38,E-38\11 -A- E-08,E-0SA,E-08AV3 -ate E-11,E-11811PB2,E-11BL1PS2V1 -IS- E-38,E-38PB2, E-38PB2 V1 1112012018 8..55: 15AM Page 3 of 3 COMPASS 5000.1 Build 81D L.�p U Project; PBU Site: E Wall: E-100 Wellbore: PLAN E -CODA Plan: E100AWPO3 u uT_. o..awnn lsa• sewn srmlanr °ie""ALOE Ime<wllese ,. WELLBORE DETAILS: PLAN E-100,1 � E-100,1 Parent Wellbore: E-100 Tie on MD: 12950.00 fdBbaENIEINF01UM110N LVa4heh IWEl Pehrcma: vt1 Et00.ilueaam vwmlMOl Bmmrce: Mean sn lml secewrysl NXlmarm: sN1-NaN'.OnOEI haN OepMNelarelw XB@n80uG1 p4nhbpl MNmX Mmmm QlrvYure WELL DETAILS: E-100 GmuneLewl. 30.00 ,W -s +E4W NoMing Eastlng I-e.de LongiLOe 000 000 58]8784BSD 864447,190 70.20.343SON 14r39'55.015W SECTIONDETAILS Sec MD Inc An %TVD +*S +EFW Net TFace VSad TaWt 1 1295000 2223 2.11 904135 8241.03 .1142.14 0.00 0.00 .1142.14 2 1298600 21.68 0.27 9074.74 8254.48 -1141.85 2.45 -129.49-1141.85 3 7300600 23.48 0.27 909311 8262.16 -114132 9.00 0.00-1141.112 4 13126.00 47.48 0.27 9190.22 833130 -1141A9 20.00 0.00 -1141.49 5 13311.00 67.17 38.12 9292.19 8471.45 .108632 20.00 70.00.1086.62 6 13431.00 8937 46.12 9315.96 8557.81 .1008.09 20.00 20.00 -1008.09 7 13591.00 89,119 78.12 931630 8631.67 .868.50 20.00 90.00 .86B.50 8 13891.00 89.91 114.12 9316.83 8600.22 575.09 12.00 90.00 -575A9 9 14191,10 89.93 78.12 9317.27 8566.78 -2111.68 1200. -90.00 -281LB 10 14411.00 89.94 10452 9317.53 856317 -63.68 12.00 90.00 -63.68 11 14496.00 Will 10837 9310.63 8539.83 17.47 12.00 2200 17.47 12 14556.00 99.44 115.67 9300.80 8517.66 72.31 12.00 89.00 72.31 13 14856A 9938 79.16 9250.08 8480.14 360.58 12.00 .87.00 360.58 14 15156.00 99.34 115.67 919933 8442.62 648.89 12.00 87.00 649.89 15 15456.00 99.30 79.17 914979 6405.09 937.24 12.00 .87.00 937.24 16 15580.00 9924 94.24 9129.30 8412.10 1059.05 12.00 89.00 1059.05 A911V G_ YIIIXI 0 lube O YIVU- ItTI 1\"11 4Y2UU'IViI% YlW IL WC Y41XI u y 45VU F Ylnll ANNOTATIONS MIND MD Annotation 9041.35 12950.00 E-100 Actual Sunni, TIP 9074.74 12986.00 KOP 9093.21 13006.00 3 9190.22 13126.00 4 9292.19 13311.00 5 9315.96 73431.00 6 9316.30 13591.00 End 20,1E 9316.83 13891.00 7 931]2714191.00 8 9317.53 14411.00 9 9310.63 14496.00 10 9300.80 14556.00 11 9250.08 14856.00 12 9199.63 15156.00 13 9749.39 15456.00 14 9129.30 15580.00 TDa115580.00 Y.-IWklml9unn lip 1:or �3 Wloo1II 6 F:nd2UJlx 10000' 9800 WOO G 9400 nao 0 N Wno + 8800 t C 0 800 Z Z, 840-6 t 7 ti ezao Boas 7800 7600 7400 E -100A WP03 -JIM -1400 -1200 -1000 -NO 400 400 -200 0 200 400 one 000 IWO 1200 1400 1500 1800 2000 West( -)/East(') (200 ustt/in) E -100A WP03 ]ANA12 14 12 Maen_� lin �LL 21 Vryp1 L -:VW -IYW -INW -I]W -161N1 -1-644 -1944 -IIUI -IEW -1144 -IINNI !11111 -tlUU -]VV -LUV -inn dVV -$W 344 -IUU V IN ]IIV 344 4UU 51111 61N ]VV XVU 'WU IIIUII IIW I]W I111U 14VV ISUV 141111 I>IIII Vertical Section at 90.00° (100 usftlin) RE Possible Magnetic Interference: From KOP to 13,170' MD Project: PBU Site: E Well: E-100 Wellbore: PLAN E -100A Plan: E-100AWP03 E-100 ANTI -COLLISION SETTINGS COMPANY DETAILS: North America -ALASKA -BP Interpolation Method: interval: 2558 Calculation Method: Minimum Curvature 129MD, Ran 15580.00 Depth Range From: Error System: ISCWSA Results Centre Di to By: Centre Distance: 1754.02 Scan Method: Trev. Cylinder North Refers Reference: Plan: E-iIMIA WP03 E-100/PLAN E-100.4) Error Surface: Elliptical Conic Warning Method: Rules Based Depth Range: 12950.00 To 15580.00 From Colour To MD 12950 -- - 13170 13170 15580 20 LEGEND L-Im E-1 W. E1M V W.. UoW: 30.20 NYf .WN x.,NMy Sol" Uo.. LonalWa. eM "a 447678"M M4447.0) mWlu.lux 1u•3r M.ouw my 1 12950.00 22.23 2.11 9041.35 8241.03 -1142.14 0.00 0.00 -1142.14 2 129H 00 21.all 0.27 W74.74 6254.48 -1141.85 2.45 -129.49 -1141.85 3 130M 00 23.48 0.27 9093.21 8282.16 .1141.82 9.00 0.00 -1141.82 413126.00 47.40 0.27 919022 8331.30 -1141.49 20.00 too -1141.49 5 13311.00 67.17 30.12 9292.19 8471.45 .1086.62 20.09 70.00 .1086.52 6 13431.00 89.87 46.12 9315.96 8557.81 -1008.09 20.00 20.00 -1008.09 7 13591.00 89.89 78.12 9316.30 8631.67 -00.50 20.00 90.00 -888.50 B 13891.00 89.91 114.12 9316.03 8600.22 -575.09 12.00 90.00 -575.09 9 14191.00 89.93 78.12 9317.27 8568.78 -281.68 12.00 -90.00 -261.68 10 14411.00 89.94 104.52 9317.53 8563.77 -63.68 12.00 90.00 -63.68 11 14496.00 99.39 108.37 9310.63 8539.83 17.47 12.00 22.00 17.47 12 14556.00 99.44 115.67 9300.80 8517.66 72.31 12AD 09.00 72.31 13 14856.00 99.38 79.16 9250.08 8480.14 360.50 12.00 -07.00 360.5B 14 15156.00 98.34 115.67 9199.63 8442.62 Was 12.00 07.00 648.89 15 15456.00 99.30 79.17 9149.39 8405.09 937.24 12.D0 -07.00 937.24 16 15580.00 99.24 94.24 912930 0412.10 1059.05 12.00 89.00 1059.05 51JN Y%30GuoM OpIB Fun ooA b SuZ,O Tool 100.00129M.00 3-. Gyro9lamnlcxlpmk (E-100) oylt T- . 12950.00 155BOM E-1 MR K}V])PIAN E -I M4) MM 180 Azimuth from Nodh I -I vs Centre to Centre Separation [40 usfUn] Azimuth from North [°]vs Centre to Centre Separation [10 usfl/in] 20 P Project: PBD Silo: E Well: E-100sw WNIBen: PLANE-IDQA Plan: E100A WPoO PIus6Wtt MD ama.tl T,.xom u.sremuw.�ssa u m r.tl nmiHr o sA'0 Wim- xm�iewiwia WELLBORE DETAILS: PLAN E -100A E-t00A E-100 Tie an MD: 12950.00uie00e°°i PESFAENCEMFpVAMinN mnoklw lR hrtu nb1E100T xm veror RD)W,. Nmn s® l sc'ooe Nslaeiereru su iomw.aOLE Peh11C xEMnoauen lUb. Warta W—.C. E.el ng (550 tlsNln) Mean Sea Level I North America - ALASKA - BP PBU E E-100 PLAN E -100A E -100A WP03 Plus 500ft MD AOGCC Offset Well Report 20 November, 2018 Company: North America - ALASKA - BP Project: PBU Reference Site: E Site Error: 0.00usft Reference Well: E-100 Well Error: 0.00usft Reference Wellbore PLAN E -100A Reference Design: E -1 00A WP03 Plus 500ft MD BP Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well E-100 Mean Sea Level KB @ 71.00usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference E -1 00A WP03 Plus 500ft MD Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria WARNING: There is hidden tight data in this project Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 200.00usft Error Surface: Elliptical Conic Survey Tool Program Date 11/20/2018 -- --- -�-- From To (usR) (usft) Survey (Wellbore) Tool Name Description 100.00 12,950.00 3: Gyrodata cont.casing nVs (E-100) GYD-CT-CMS Gyrodata cont.casing m/s 12,950.00 16,080.00 E -100A WP03 Plus 500ft MD (PLAN E-100 MWD MWD - Standard Summary Reference Offset Centre to Measured Measured Centre Site Name Depth Depth Distance Offset Well - Wellbore - Design (usft) lush) (usft( E E-08 - E-08 - E-08 1,340.54 1,325.00 131.94 E-08 - E -08A - E -08A 1,340.54 1,325.00 131.94 E-09 - E-09 - E-09 635.06 625.00 32.48 E-09 - E -09A - E -09A 630.33 625.00 32.42 E-09 - E-09AP01 - E-09APB1 630.33 625.00 32.42 E-09 - E -09B - E -09B 630.33 625.00 32.42 E-09 - E -09C - E -09C 630.33 625.00 32.42 E-09 - E-09CPB1 - E-09CPBI 630.33 625.00 32.42 E-10 - E-10 - E-10 610.11 600.00 79.89 E-10 - E -10A - E -10A 610.11 600.00 79.89 E-10 - E-1 OB - E-108 610.87 600.00 79.90 E-100- PLAN E -100A -E -100A WP03 15,580.00 15,580.00 0.00 E -102 -E -102-E-102 1,028.03 1,025.00 36.35 E-104 - E-104 - E-104 926.14 925.00 116.23 E-11 - E-11 - E-11 510.03 500.00 187.50 E-11 - E -11A - E -11A 52721 525.00 187.79 E-11 - E-11APBi - E-11APB1 527.21 525.00 187.79 E-11 - E-11 B - E-116 512.98 500.00 187.55 E-11 - E-11 311 - E-11 BL1 51298 500.00 187.55 E-11 - E-11 311-01 - E-11 311-01 512.98 500.00 187.55 E -11-E-1181.1 PB1-E-11BL1 PB1 512.98 500.00 187.55 E-11 - E-11 BL1 PB1 - Plan #7 512.98 500.00 187.55 E-11 - E-11 311 PB2 - E-11 BL1 PB2 512.98 500.00 187.55 E-34 - E-34 - E-34 627.93 625.00 108.30 E-34 - E -34A - E -34A 627.93 625.00 108.30 E-34 - E-3411 - E-3411 627.93 625.00 108.30 E-38 - E-38 - E-38 2,234.71 2,175.00 172.05 E-38 - E-38PB1 - E-38PBI 2,234.71 2,175.00 172.05 E-38 - E-38PB2 - E-38PB2 2,234.71 2,175.00 172.05 P1 1120/2018 9:34:45AM Page 2 of 2 COMPASS 5000 1 Build 810 Well Blghole CDR2-AC 4 Ram BOP Schematic Date Quick Test Sub to Otis Top of 7" Otis O.Oft —---------- — ——.—.... —CDR2 Rig's Drip Pan Distances from top of riser Excluding quick -test sub r— 7-1116" 61, Flange x 7' Otis Box Top of Annular fi.0 ft Hydril 71116" ,y Top of Annular Element 6J ft Annular y Bottom Annular CL Blind/Shears BIinNShear y CL 2-3/8" Pipe/Slips 2-318" PlpelSlips 0 assaiiiiiii Kill Line�A � �� sM.a �B6 tb�, crass III Y1B"v]-1Vs 2-3/8" Pipe/Slips 2JIB"Pipe/SlipsCIL A16— CL CL of Top Swab 16.0 ft f— Swab T1 1 T2 CL of Flow Cross 17.4 ft 71A CL of MasterLDS OA LDS Ground Level 0 Choke Line Test Pump Hose Davies, Stephen F (DOA) From: Roby, David S (DOA) Sent: Wednesday, November 7, 2018 12:01 PM To: Bredar, William L; Davies, Stephen F (DOA) Subject: RE: E-100 Sidetrack Planning Hi Bill; Since the GOR waiver is a temporary one for reservoir performance gathering it does not require notice and hearing, so you can submit it whenever. Probably easiest thing to do is just say that the E-100 wasn't usable for its planned test and you'd like to transfer the existing GOR waiver from it to the proposed E -100A wellbore which will be drilled and completed for the same purpose as what was intended for E-100. I don't see any problems with your plan to extend a liner across to Kuparuk to ensure zonal isolation between it and the Ivishak. Dave Roby 907-793-1232 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use oft he intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Dave Roby at 907- 793-1232 or dave.roby@alaska.gov. From: Bredar, William L <William.Bredar@bp.com> Sent: Wednesday, November 7, 2018 11:49 AM To: Roby, David 5 (DOA) <dave.roby@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: E-100 Sidetrack Planning Hi Dave and Steve, Thanks for your reply Dave. Going down Dave's list... 1) For the GOR waiver we will need a minimum of one year of extended flow testing with intention, prior to expiration, to meet with AOGCC staff to discuss results and future development plans for the area which may include expanding the POP. We expect all the perfs for extended flow testing to be located outside of the POP. Eventually perfs may be added in the toe which is within the POP. How much in advance of the PTD application should I begin this process? Should we submit this application soon? (anticipated spud is March, 2019) 2) Steve, I presume you concur with Dave's determination of no need for a spacing exception and will not pursue unless you advise. FYI the wellplan has changed slightly but is over 500' from the Unit boundary for its entirety. A revised wellplan will accompany the PTD. 3) We are advising our Drilling department to review for any differences in well drilling or construction practices between pool rule and statewide regs. Thanks for the tip. Davies, Stephen F (DOA) From: Bredar, William L <William.Bredar@bp.com> Sent: Wednesday, November 7, 2018 11:49 AM To: Roby, David S (DOA); Davies, Stephen F (DOA) Subject: RE: E-100 Sidetrack Planning Hi Dave and Steve, Thanks for your reply Dave. Going down Dave's list... 1) For the GOR waiver we will need a minimum of one year of extended flow testing with intention, prior to expiration, to meet with AOGCC staff to discuss results and future development plans for the area which may include expanding the POP. We expect all the perfs for extended flow testing to be located outside of the POP. Eventually perfs may be added in the toe which is within the POP. How much in advance of the PTD application should I begin this process? Should we submit this application soon? (anticipated spud is March, 2019) 2) Steve, I presume you concur with Dave's determination of no need for a spacing exception and will not pursue unless you advise. FYI the wellplan has changed slightly but is over 500' from the Unit boundary for its entirety. A revised wellplan will accompany the PTD. 3) We are advising our Drilling department to review for any differences in well drilling or construction practices between pool rule and statewide reqs. Thanks for the tip. 4) Yes there were issues squeezing the Kuparuk in the well. The sidetrack is kicking off below the Kuparuk. We have a plan to deal with the currently open Kuparuk. Drilling will try another squeeze as part of the pre -rig activity. If the pre -rig squeeze fails we would be exposed to Kuparuk pressure while drilling. For the completion, we are planning on running liner up over Kuparuk perf interval too. The purpose of running (and cementing) the liner above the Kuparuk perfs is to assure that the Kuparuk is isolated from the Ivishak below (post -rig). Please advise if you foresee any problems with this plan. Regards, Bill Bill Bredar State of Alaska Interactions -Reservoirs; Surveillance Champion Alaska Region Performance Management Team BP Exploration (Alaska) Inc (907) 564-5348 - office (907) 227-7252 - mobile From: Roby, David S (DOA) <dave.roby@alaska.gov> Sent: Thursday, November 1, 20184:35 PM To: Bredar, William L <William.Bredar@bp.com>; Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: E-100 Sidetrack Planning Davies, Stephen F (DOA) From: Roby, David S (DOA) Sent: Thursday, November 1, 2018 4:35 PM To: Bredar, William L; Davies, Stephen F (DOA) Subject: RE: E-100 Sidetrack Planning Hi Bill, Yes, you'll need to have the GOR waiver amended to cover the sidetrack. And I'll take a crack at Steve's question as well. Since the portion of section 30 where the well is located and all of section 29 are in the PBU the ownership of the two tracts should be the same, so there's no spacing related issue with drilling across the section line/pool boundary. And, since there's no other Sag/lvishak penetrations in section 30 there's no issue with interwell spacing. So no spacing exception under 25.055 is needed for this proposed well. One area where there might be a concern would be if there's a conflict between the pool rules and the statewide reqs in regards to well drilling or construction practices. So, your drillers should check into that to make sure a waiver of the regs or rules is necessary for the well. Looking at the sundry submitted for attempting to test the Sag/Ivishak in this well it looks like there were issues with attempting to squeeze the Kuparuk in the well. Is the sidetrack going to kick off above the Kuparuk or are you planning to do something else to ensure the Kuparuk is isolated? Regards, Dave Roby 907-793-1232 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Dave Roby at 907- 793-1232 or dave.robyPalaska.eov. From: Bredar, William L <William.Breda r@bp.com> Sent: Thursday, November 1, 2018 4:02 PM To: Roby, David S (DOA) <dave.roby@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: E-100 Sidetrack Planning Hello Steve and Dave, Further to the phone discussion I had with Steve yesterday, am sending this to both of you as Dave was involved with the GOR waiver (attached) that BP received in February, 2018 for the E-100 recompletion which unfortunately was unsuccessful. We will now be applying for a PTD for a sidetrack in the Sag/Ivishak interval heading east from the E-100 original hole, drilling from lands outside of the POP to a planned TD within the POP, as shown on the attached plat (reference E- 100A_cp3). We anticipate perforations in both the non -pool and in -pool portions. The plat shows the following legal boundaries: Prudhoe Oil Pool, Prudhoe Bay Unit, Section -Township -Range, Lease numbers, Gas Cap PA, Oil Rim PA. The intended sidetrack trajectory is more than 500' from the PBU boundary for its entire length. Davies, Stephen F (DOA) From: Bredar, William L <William.Bredar@bp.com> Sent: Thursday, November 1, 2018 4:02 PM To: Roby, David S (DOA); Davies, Stephen F (DOA) Subject: E-100 Sidetrack Planning Attachments: E-100 Waiver of GOR limitations_AOGCC Approval 02.22.18.pdf; E-100A_prospect.pdf Hello Steve and Dave, Further to the phone discussion I had with Steve yesterday, am sending this to both of you as Dave was involved with the GOR waiver (attached) that BP received in February, 2018 for the E-100 recompletion which unfortunately was unsuccessful. We will now be applying for a PTD for a sidetrack in the Sag/Ivishak interval heading east from the E-100 original hole, drilling from lands outside of the POP to a planned TD within the POP, as shown on the attached plat (reference E- 100A_cp3). We anticipate perforations in both the non -pool and in -pool portions. The plat shows the following legal boundaries: Prudhoe Oil Pool, Prudhoe Bay Unit, Section -Township -Range, Lease numbers, Gas Cap PA, Oil Rim PA. The intended sidetrack trajectory is more than 500' from the PBU boundary for its entire length. Would like your advice about what BP needs to do to proceed to PTD. Planned spud date is March, 2019. The wellbore is seemingly under statewide regulations for a portion and under pool rules of the POP for the remainder. The portion of E-100 below the sidetrack depth should be considered abandoned although that operation has not yet occurred. It will be isolated when the sidetrack liner is cemented in place. Question for Steve: Do you see any hurdles for us to cross re: 20 AAC 25.055? If there is need for spacing exception would want to get 30 day notice going. There are no other Ivishak penetrations in section 30. Any other hurdles on the PTD? Question for Dave: Does the attached order for the GOR waiver need to be amended for the new operation which involves a new wellbore? FYI, with regard to Division of Oil and Gas, we have an agreed way forward. As the E-100 original hole is inside the PBU and outside the Gas Cap and Oil Rim PA we were issued a Tract Operation for the recompletion. Now that the plan is to sidetrack from a Tract into a PA, we have been assured they will grant a modification based on perfs. After the sidetrack is drilled, DOG will amend the existing Tract Operation authorization or issue a new one. Production from the well we be split between the PA and the lease on the basis of productive lateral footage. If necessary, BP can meet with you sometime next week. Thanks, Bill Bill Bredar State of Alaska Interactions -Reservoirs; Surveillance Champion Alaska Region Performance Management Team BP Exploration (Alaska) Inc (907) 564-5348 - office Q � � c m d d Q m LL G t Cw aU' O a n L'n d aaoo�� WOSB65 OOOOB6S WDri[65 I Q ry Q i Q WW W Z 2 g a � � a a 304 VNLLL 304tlWZLL 3LLHINLLI I Z n 7 O t $ a i.lt;lf a - ('filfli fillRI F" 11 !s €g Ag 3p.41Ii i s 5[�i(ailf1 m vifi'ff�t g sO .� 3ISO F WOSB65 OOOOB6S WDri[65 I Q ry Q i Q WW W Z 2 g a � � a a 304 VNLLL 304tlWZLL 3LLHINLLI I Z n 7 O t $ a THE STATE °fALASKA GOVERNOR BILL WALKER February 22, 2018 Ms. Laurie Derrick E -Pad Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 1-96612 Anchorage, Alaska 99519-6612 Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.acgcc.alaska.gov RE: Docket Number: OTH-18-017 Request for a waiver of the gas oil ratio limitations of 20 AAC 25.240(a) for well Prudhoe Bay Unit E-100 (PTD 197-188) Dear Ms. Derrick: By letter received February 9, 2018, BP Exploration (Alaska), Inc. (BPXA) requested a waiver of the gas -oil ratio limitations in 20 AAC 25.240(a). By email received February 14, 2018, BPXA stated that it was requesting a waiver for a period of one year. The basis for the request is to allow long term testing of the Prudhoe Bay Unit E-100 well (PBU E- 100) (PTD 197-188) in the Sag River and Ivishak Formations to acquire reservoir performance data to help determine the potential for additional reservoir development. BPXA's request is granted under the conditions below. The PBU E-100, is completed as a water injector in the Midnight Sun Oil Pool, but is no longer needed since it was replaced by the PBU P1-122 well. The PBU P1-122 has the capability to inject miscible injectant, which the PBU E-100 lacked since there was no Ml supplied to E -Pad. Since this well is no longer needed as a Midnight Sun injection well BPXA plans to recomplete the well to conduct an extended flow test in the Sag River and Ivishak Formations. The Prudhoe Oil Pool (POP) contains the Sag River and Ivishak formations and has an existing GOR waiver due to the ongoing enhanced recovery project in the POP, but the location of the PBU E-100 is outside the affected area of the POP. Since the PBU E-100 well is outside the POP boundary it is subject to statewide regulations and the GOR limitations of 20 AAC 25.240 apply to the proposed test of this well. BPXA plans to collect detailed well testing data and fluid samples over a period of 30 days. After completion of the 30 -day testing period BPXA plans to connect the well to temporary production facilities and put it on regular production to collect longer term performance data. BPXA will make future development decisions, which may include expanding the POP to encompass this area, based on the results of the collected performance data. Because the GOR of the well might increase above the GOR limits during testing, BPXA has requested a GOR waiver while it collects reservoir performance data in order to determine future development plans for this area. Docket Number: OTH-18-017 February 22, 2018 Page 2 of 2 In accordance with 20 AAC 25.240(b)(3) BPXA's request is granted on the following conditions: 1) The PBU E-100 well must be tested in accordance with the PBU's well testing and allocation procedures and must tested at least twice per month while flowing. 2) The GOR waiver expires one year after the extended flow testing period commences. BPXA must notify the AOGCC when the extended flow testing period commences. 3) On a quarterly basis, the operator must submit copies of all well tests for the PBU E-100 well showing the GOR at the time of the test. 4) Prior to expiration of this GOR waiver the operator must meet with the AOGCC to discuss results during this test period and future development plans for this area. DONE at Anchorage, Alaska and dated February 22, 2018. p� I Hollis S. French Daniel T. Seamount, Jr. Cathy P. Foerster Chair, Commissioner Commissioner Commissioner As provided in AS 31.05.080(x), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is fried. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision docs not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. (this language was removed from the statute a few years ago) In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs „nrtt s -on n m. nn the next day that does not fall on a weekend or state holiday. AOGCC PTD No. 218-167 Coordinate Check 27 November 2018 INPUT Geographic, NAD27 PBU E -100A Latitude: 70 20 34.35800 Longitude: 148 39 55.01500 OUTPUT Stale Plane, NAD27 5004 -Alaska 4, U.S. Feet 111 NorthinglY: 5976764.644 EastinglX: 664447.432 Convergence: 1 15 25.05554 Scale Factor: 0.999930720 Remark: Corpscon v6.0.7, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: _Aa C-1,; PTD: �Development _Service _Exploratory _ Stratigraphic Test _ Non -Conventional FIELD:AJ4-0—r— Check POOL:r/ / LUS'e W'4 Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter =nurnberare TEXT FOR APPRuvAL Uhl ir.n The permit is for a new wellbore segment of existing well Permit No. API No. 50 gits Production should continue to be reported as a function of the original are API number stated above. 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 i imliu Vii wahe permit is approved subject to full compliance with 20 AAC 25.055. pproval to produce/inject is contingent upon issuance of a conservation rder approving a spacing exception. (Comnanv Name) Operator ssumes the liability of any protest to the spacing exception that may ccur.ll dry ditch sample sets submitted to the AOGCC must be in no greater han 30' sample intervals from below the permafrost or from where sam les are first can ht and10'sam le intervals throu tar et zones.Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Comnanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comnanv Name) must contact the AOGCC to obtain advance a roval of such water well testingprogram. 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 (Comnanv 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 WELL PERMIT CHECKLIST Field &Pool PRUDHOE BAY, SAMBUCA UNDEF OIL - 64016 Name: PRUDHOE BAY UNIT E -100A Program DEV - _ Well bore seg ❑ -- - - --64 PTD#:2181570 Company BP EXPLORAT�N_(ALASKA) INO,_ _ _— Initial Class/Type --- DEV / PENL)__GeoArea 890 Unit 11650 On/Off Shore On_Annular Disposal ❑ Administration i17 Nonconven gas conforms to AS31 05,030c, 1 A) r,2 A -D) NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Date ,SZ _k_Ps, M 12/6/t � i z� 1"e-, '.1 Permit fee attached ................ _.. NA_ __._....... ..........__ ___... _... _ 2 Lease number appropriate. .... . . . ... . . . _ _ _ _ _ Yes _ Surface Location lies within ADL0028304; Top Prod Int & TD lie within ADL0028299... 3 Unique well. name and number . . ... . ..... . . . . _ _ _ _ _ Yes 4 Well located in a. defined pool_ _ _ _ _ _ _ _ _ _ _ _ _ _ No. _ Portion. of well will lie within Prudhoe Oil Pool, and a portion will lie outside of the 5 Well located proper distance from drilling unit boundary. _ _ _ Yes current boundary of the pool. CO 341 F governs portion within the. pool; statewide ... - 6 Well located proper distance from other wells _ _ Yes _ _ _ _ _ regulations govern portion. lying outside of pool. Well will lie within PBU......... . . . . 7 Sufficient acreage. available in.drilling unit. _ _ _ _ _ Yes _ _ _ Well will conform to spacing requirements.... 8 If.deviated, is wellbore plat included ... Yes 9 Operator only affected part'... _ _ _ ........ _ Yes 10 Operator has appropriate. bond in force _ _ _ _ _ _ _ _ Yes Appr Date 11 Permit can be issued without conservation order.... _ _ _ _ _ ...... _ _ _ Yes SFD 11/27/2018 12 Permit can be issued without administrative. approval _ _ .. _ _ _ _ _ ..... Yes ... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ________ 13 Can permit .be approved before 15 day wait......... Yes _ ______ 14 Well located within area and.strata authorized by. Injection Order # (put 10# in.comments)_(For NA 15 All wells within 114.mile area of review identified (For service well only) _ _ _ _ _ _ ... NA.... 16 Pre -produced injector; duration of pre production less than 3 months. (For service well only) NA_ _ _ _ ........... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ............. . 18 Conductor string. provided _ _ _ _ _ _ . NA, . _ _ . _ _ _ CTD sidetrack in production zone ___________ Engineering 19 Surface casing. protects all known USDWs _ _ _ _ _ _ ...... NA ...... CTD sidetrack in production zone 20 CMT vol adequate to circulate.on conductor. & surl.csg _ _ _ .. _ ..... _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ CTD sidetrack in production zone 21 CMT vol adequate to tie-in long string to.surf csg. . . . . ........... . . . . . . . . . NA...... _ . CTD sidetrack in production zone 22 CMT_will coverall known_ productive horizons . ... . . . . . . . . . . .......... Yes _ Fully cemented production liner 23 Casing designs adequate for C, T, B & permafrost _ _ _ _ _ _ _ Yes _ .. Production. liner.only change and is adequate 24 Adequate tankage or reserve pit _ _ Yes _ _ _ Ongoing CDR2 operations 25 If a. re -drill, has a 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _________ Yes .. _ _ _ _ Sundry 318-524 will be approved _ _ ....... 26 Adequate wellbore separation_ proposed... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ No BP :major collision risk' failurs 27 If diverter required., does it meet regulations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ ... _ Drilling thru tubing production_ hole_ only.... Appr Date 28 Drilling fluid_program schematic & equip list adequate_ _ _ ... _ _ Yes _ _ _ Overbalance drill in fluid If Kuparuk remains open can weight up to 9.4 ppg MGR 12/6/2018 29 BOPEs, do they meet regulation _ _ _ _ Yes 30 BOPE_press rating appropriate; test lo.(put psig in comments).. _ _ _ _ ......... Yes ... _ . CDR 2 ongoing operations . . . . ........ . . . .. . . . . .. 31 Choke.manifold complies w/API_RP-53 (May 84).. _ _ _ _ _ . Yes _ _ _ _ _ CDR 2 ongoing operations ____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 32 Work will occur, without operation shutdown _ _ _ . _ _ _ _ _ _ _ . Yes ____ _ _ _ _ _ _ 33 Is presence of H2S gas probable _ _ Yes Standard_ HZS. monitoring in. place 34 Mechanical condition of wells within AOR verified (For service well only) _ _ _ _ _ _ _ NA _ _ _ This well.will bean lvishok producer 135 Permit can be issued w/o hydrogen sulfide measures _ ...... _ _ _ _ _ .. _ .No _ ... E Pad wells are H2S_bearing: measures required.. .... .. _ Geology 36 Data presented on. potential overpressure zones _ . _ ... Yes .... _ Operator's_ planned_ mud weights appear adequate to control forecast pressures. Appr Date 37 Seismic.analysis of shallow gas_ zones_ _ ______ _ _ _ _ _ _ _ _ _ NA SFD 11/27/2018 38 Seabed condition survey (if off -shore) _ . _ _ _ . _ . _ _ . _ _ .. _ _ _ _ . _ NA _ _ _ _ _ _ _ _ _ _ _ _ _____ 139 Contact name/phone for weekly progress reports_ [exploratory only] ______ _ _ _ _ _ _ _ _ _ _ _ NA_ Geologic Engineering Public Commissioner: Date: Commissioner: Date Date ,SZ _k_Ps, M 12/6/t � i z� 1"e-,