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215-055
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 S-42A Pull IBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-055 50-029-22662-01-00 11250 Conductor Surface Intermediate Production Liner 6714 80 2966 8435 2929 11121 20" 9-5/8" 7" 4-1/2" 6714 47 - 127 47 - 3013 45 - 8480 8319 - 11248 47 - 127 47 - 3012 45 - 6770 6678 - 6714 8680 470 3090 5410 7500 None 1490 5750 7240 8430 8506 - 10896 4-1/2" 12.6# 13cr85 43 - 8328 6783 - 6721 Structural 4-1/2" HES TNT Packer 8202, 6604 8202 6604 Aras Worthington for Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028257, 0028258 43 - 6683 N/A N/A 348 261 428 380 522 474 850 941 186 210 N/A 13b. Pools active after work:PRUDHOE BAY, AURORA 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 Samantha Carlisle at 9:49 am, Nov 14, 2023 Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2023.11.08 16:49:00 -09'00' Aras Worthington (4643) RBDMS JSB 111623 DSR-11/15/23WCB 3-14-2024 The IBP was not retrieved from the hole. -WCB ACTIVITY DATE SUMMARY 10/3/2023 ****WELL S/I ON ARRIVAL*** (Profile modification) RAN 2.5" LIB TO IBP @ 8,538'SLM(Impression of clean fn) RAN IBP EQ SLEEVE IN MULTIPLE CONFIGURATIONS BEFORE EQUALIZING IBP JARRED ON IBP FOR 45MIN w/ JU(No movement) ***CONTINUED ON 10/4/23 WSR*** 10/4/2023 ***CONTINUED FROM 10/4/23 WSR*** (Profile modification) JARRED ON IBP @ 8,540' SLM FOR 8 HOURS TOTAL ***CONTINUED ON 10/5/23 WSR*** 10/5/2023 ***CONTINUED FROM 10/4/23 WSR*** (Profile modification) RIG DOWN POLLARD SLU #60. ***JOB SUSPENDED, WELL S/I ON DEPARTURE*** 10/13/2023 ***WELL S/I ON ARRIVAL*** RIGGED UP .160 WIRE. RAN 3" IBP SLEEVE W/ 2" SB. S/D @ 8534' SLM, WORK PAST AND DEVIATE OUT @ 8680' SLM. ***CONTINUED ON 10-14-23*** 10/14/2023 ***WSR CONTINUED FROM 10-13-23*** RAN KJ, 3" IBP SLEEVE, AND 2" SB TO 8680' SLM AND STALL TO DEVIATION. SET 4 1/2" IBP STOP IN X NIPPLE @ 8,171' MD (checkset good) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** Daily Report of Well Operations PBU S-42A ( JARRED ON IBP @ 8,540' SLM FOR 8 HOURS TOTAL @( ) RAN IBP EQ SLEEVE IN MULTIPLE CONFIGURATIONS BEFORE EQUALIZING IBP JARRED ON IBP FOR 45MIN w/ JU(No movement) 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 S-42A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-055 50-029-22662-01-00 11250 Conductor Surface Intermediate Production Liner 6714 80 2966 8435 2929 8580 20" 9-5/8" 7" 4-1/2" 6815 47 - 127 47 - 3013 45 - 8480 8319 - 11248 47 - 127 47 - 3012 45 - 6770 6678 - 6714 None 470 3090 5410 7500 8580 1490 5750 7240 8430 8533 - 10896 4-1/2" 12.6# 13cr85 43 - 8328 6796 - 6721 Structural 4-1/2" HES TNT Packer 8202, 6604 8202 6604 Torin Roschinger Operations Manager Marshall Brown henry.brown@hilcorp.com 601-613-0173 PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028257, 0028258 43 - 6683 N/A N/A 348 No Well Test Available 428 522 850 1200 186 1650 N/A 13b. Pools active after work:PRUDHOE BAY, AURORA 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 2:35 pm, Oct 13, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.10.13 12:06:52 -08'00' Torin Roschinger (4662) WCB 3-14-2024 DSR-10/13/23 RBDMS JSB 101723 ACTIVITY DATE SUMMARY 9/15/2023 ***WELL FLOWLING ON ARRIVAL*** R/U SLICKLINE. ***WSR CONTINUED ON 9-16-23*** 9/16/2023 T/I/O = 620/640/50. Temp = SI. T FL (Ops request). ALP = 2290 psi, SI @ CV. T FL @ 40' (0.6 bbls). SV, WV = C. SSV, MV = O. IA & OA = OTG. 11:00 9/16/2023 *** WELL SI ON ARRIVAL *** INITIAL T/I/O = 625/700/0 PT PCE 30PSI LOW 3000PSI HIGH YJOS ELINE SETTING BAKER IBP AT 8580 FT MID JOINT, CCL OFFSET = 24.4 FT, CCL STOP = 8555.6 FT.SLACKED OFF AFTER SETTING, BAKER REPORTS GOOD INDICATION. ELINE IBP COMPLETE. FINAL T/I/O = 625/700/0 *** WELL SI ON DEPARTURE, DSO NOTIFIED *** 9/16/2023 ***WSR CONTINUED FROM 9-15-23*** RAN 10' x 3.66 DUMMY GUNS UNABLE TO WORK PAST 8510' SLM RAN 3.75 CENTRALIZER TO TAG PORT #7 @ 8533' MD RAN 4-1/2" BRUSH & 3.55" G-RING, BRUSHED PORT #7 RAN 10' x 2.5" BAILER TO 8600' SLM WITHOUT ISSUE ***WELL LEFT S/I ON DEPARTURE*** 9/21/2023 T/I/O= 600/550/0 (Assist Slickline) TFS U-3, Pumped 133 BBLS of diesel for TBG load. Further pumped 45 BBLS of diesel for injectivity test. ***Job continued on 9/22/23*** 9/21/2023 ***WELL FLOWING ON ARRIVAL*** RIH W/ 2.80" LIB TAG IMPRESSION OF F/N OF IBP @ 8,563' SLM RIH W/ 4-1/2" X-LINE, 4-1/2" X-CATCHER (xc-44) CORRECTION FROM X-NIP @ 8,311' MD (+8') BRUSH PERFS @ 8,506' MD TO 8526' MD W/ 4-1/2" BLB & 3.5" G.RING T-BIRD PUMPS 130 BBLS DIESEL TO LOAD AND 45 BBLS FOR INJECTIVITY TEST T-BIRD WAS ABLE TO GET 5 BPM @ 2450# ***CONT WSR ON 09/22/2023*** 9/22/2023 ***CONT WSR FROM 09/21/2023*** TAG IBP @ 8,580' MD W/ 3.5" BARBELL & 2.8" LIB ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** Daily Report of Well Operations PBU S-42A TAG IBP @ 8,580' MD ELINE SETTING BAKER IBP AT 8580 FT MID JOINT ELINE IBP COMPLETE 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 S-42A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-055 50-029-22662-01-00 11250 Conductor Surface Intermediate Production Liner 6714 80 2966 8435 2929 11121 20" 9-5/8" 7" 4-1/2" 6714 47 - 127 47 - 3013 45 - 8480 8319 - 11248 47 - 127 47 - 3012 45 - 6770 6678 - 6714 None 470 3090 5410 7500 None 1490 5750 7240 8430 8506 - 10896 4-1/2" 12.6# 13cr85 43 - 8328 6783 - 6721 Structural 4-1/2" HES TNT Packer 8202, 6604 8202 6604 Torin Roschinger Operations Manager Marshall Brown henry.brown@hilcorp.com 601-613-0173 PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028257, 0028258 43 - 6683 N/A N/A 294 203 402 336 737 303 850 950 216 262 N/A 13b. Pools active after work:PRUDHOE BAY, AURORA 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 8:44 am, Sep 14, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.09.13 20:16:16 -08'00' Torin Roschinger (4662) RBDMS JSB 091423 WCB 3-13-2024 DSR-9/15/23 ACTIVITY DATE SUMMARY 9/6/2023 T/I/O 256/675/45 Assist E-line (PROFILE MODIFICATION) Pumped 57 bbls of crude down TBG to free up E-line. Well left in E-line's control. IA and OA = OTG. FWHP's = 0 /675/45 9/6/2023 ****WELL S/I ON ARRIVAL*** FISHING E-LINE TOOLSTRING & SHOT PERF GUNS @ 8,500' ELMD ***CONTINUE 9/7/23*** 9/6/2023 ***WELL SHUT IN ON ARRIVAL*** Pressure test PCE from 200LP - 3000HP RIH WITH 1 7/16" CABLE HEAD, 3.60" ROLLERBOGY, 3.125" GR/CCL, 2.75" SHOCK SUB, 3.60" ROLLERBOGY, 2.75" PERF GUN (MAX OD = 3.60" , MAX LENTH = 37'') CORRELATE TO READ PPROF DATED 11-AUG-23 Gun #1 - Shooting Depth = 8,506' - 8,526' WITH 2.75" 6SPF 60PHASE HSC W/ RAZOR CHARGES, CCL Offset = 10.9' , CCL Stop Depth = 8,495.1' GOOD INDICATION OF FIRING TOOL STRING STUCK IN HOLE. (EMD = 8,495.1') WORK WIRE WHILE PUMPING FOR 2 HOURS, PULL FREE FROM ROPE SOCKET RIG DOWN AND MOVE OFF ***WELL SHUT IN ON DEPARTURE*** (READY FOR FISHING OPERATIONS) 9/7/2023 Assist Slickline (PROFILE MODIFICATION) Pumped 70 bbls DSL down Tbg to try and free up SL. Pumped 255 bbls crude down Tbg. Pumped 130 bbls sea water w/safelube and 51 bbls crude. ***Job Continued to 09-08-2023*** 9/7/2023 ***CONTINUE FROM 9/6/23*** FISHING E-LINE TOOL STRING @ 8,500' ELMD HANGING UP @ 8,285' SLM, PUMP 70 BBLS DIESEL & 255 BBLS CRUDE PUMP ADDITIONAL 50 BBLS CRUDE & 280 BBLS SAFE LUBE SLICKLINE TOOLS FREE UP OOH W/ SLICKLINE RUN 3.50" LIB S/D @ 8,421' SLM (IMPRESSION OF CABLE) RIH W/ KJ, 2.80" CENT. 3-1/2" GR, 3-1/2" BAIT SUB, WIRE FINDER & WIRE GRAB ASSEMBLY ***CONTINUE 9/8/23*** 9/8/2023 ***Continue Job from 09-07-2023*** Assist Slickline as Directed. Pumped 118 bbs of seawater down TBG. Pumped 38 bbls of crude down TBG to FP. RDMO. Well left in SL control. IA and OA = OTG. FWHP's = 0/675/50 9/8/2023 LRS Welltesting Unit #1. Begin WSR on 09/08/23. SLBU/Monitoring for solids. IL S- 42, OL S-213. Unit move, Begin RU. Continue WSR on 09/09/23. 9/8/2023 ***CONTINUE FROM 9/7/23*** RECOVERED ~130' ELINE, AND ELINE FISH @ 8421' SLM CONFIRMED ALL SHOTS FIRED ON GUN LRS PUMPED 38 BBLS F/P ***WELL LEFT S/I ON DEPARTURE*** 9/9/2023 LRS Welltesting Unit #1. Continue WSR from 09/09/23. SLBU/Monitoring for solids. IL S-42, OL S-213. Continue RU, Pt, Pop well. Continue WSR on 09/10/23. 9/10/2023 LRS Welltesting Unit #1. Continue WSR from 09/09/23. SLBU/Monitoring for solids. IL S-42, OL S-213. Continue to flow and stabilize well. Continue WSR on 09/11/23. 9/11/2023 LRS Welltesting Unit #1. Continue WSR from 09/10/23. SLBU/Monitoring for solids. IL S-42, OL S-213. Continue to flow and stabilize well.Begin 4 Hour Purge @ 23:00, Continue WSR on 09/12/23. Daily Report of Well Operations PBU S-42A FISHING E-LINE TOOL STRING @ 8,500' ELMD@ HANGING UP @ 8,285' SLM, PUMP 70 BBLS DIESEL & 255 BBLS CRUDE@ PUMP ADDITIONAL 50 BBLS CRUDE & 280 BBLS SAFE LUBE SLICKLINE TOOLS FREE UP OOH W / SLICKLINE RUN 3.50" LIB S/D @ 8,421' SLM (IMPRESSION OF CABLE)@( ) RIH W/ KJ, 2.80" CENT. 3-1/2" GR, 3-1/2" BAIT SUB, WIRE FINDER & WIRE GRAB ASSEMBLY Gun #1 - Shooting Depth = 8,506' - 8,526' WITH 2.75" 6SPF 60PHASE HSC W/g RAZOR CHARGES, RECOVERED ~130' ELINE, AND ELINE FISH @ 8421' SLM CONFIRMED ALL SHOTS FIRED ON GUN TOOL STRING STUCK IN HOLE. (EMD = 8,495.1')() WORK WIRE WHILE PUMPING FOR 2 HOURS, PULL FREE FROM ROPE SOCKET Daily Report of Well Operations PBU S-42A 9/12/2023 LRS Welltesting Unit #1. Continue WSR from 09/11/23. SLBU/Monitoring for solids. IL S-42, OL S-213. Continue to flow and stabilize well. Perform 8 Hour PB Test, BD, RDMO. End WSR on 09/12/23. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/14/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230914 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU S-210 (Revision)50029236300000 219057 4/17/2023 READ Injection Profile PBU S-42A 50029226620100 215055 8/8/2023 AK E-LINE Gamma Ray/CCL Revision explanation: PBU S-210: Updated LAS files and Final Report added. Please include current contact information if different from above. T37996 T37727 Revised 9/15/2023 PBU S-42A 50029226620100 215055 8/8/2023 AK E-LINE Gamma Ray/CCL Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.15 13:32:45 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/24/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230824 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 14-6Y 50133205720000 207149 8/10/2023 YELLOW JACKET GPT/Plug/Perf KBU 14-6Y 50133205720000 207149 8/12/2023 YELLOW JACKET GPT/Plug/Perf KBU 14-6Y 50133205720000 207149 8/17/2023 YELLOW JACKET GPT/Plug/Perf KBU 22-06 50133205500000 205054 8/3/2023 YELLOW JACKET Gamma Ray KBU 22-06 50133205500000 205054 8/6/2023 YELLOW JACKET Gamma Ray KBU 22-06 50133205500000 205054 8/11/2023 YELLOW JACKET GPT/Plug/Perf MPU J-29A 50029236880100 221023 8/19/2023 READ Caliper Survey PBU S-42A 50029226620100 215055 8/11/2023 READ MAPP PBU PSI-09 50029230950000 202124 7/28/2023 HALLIBURTON WFL-TMD3D Please include current contact information if different from above. T37955 T37955 T37955 T37956 T37956 T37956 T37957 T37958 T37959 8/28/2023 PBU S-42A 50029226620100 215055 8/11/2023 READ MAPP Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.28 15:49:42 -08'00' 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 S-42A Acid Job Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-055 50-029-22662-01-00 11250 Conductor Surface Intermediate Production Liner 6714 80 2966 8435 2929 11121 20" 9-5/8" 7" 4-1/2" 6714 47 - 127 47 - 3013 45 - 8480 8319 - 11248 47 - 127 47 - 3012 45 - 6770 6678 - 6714 None 470 3090 5410 7500 None 1490 5750 7240 8430 8533 - 10896 4-1/2" 12.6# 13cr85 43 - 8328 6796 - 6721 Structural 4-1/2" HES TNT Packer 8202, 6604 8202 6604 Torin Roschinger Operations Manager Claire Mayfield claire.mayfield@hilcorp.com 907-564-4375 PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028257, 0028258 43 - 6683 Frac Ports 8533 - 10896 Pump 30-bbls 12% HCl Acid. Final pressure = 0-psi 218 225 395 534 300 302 849 864 219 211 N/A 13b. Pools active after work:PRUDHOE BAY, AURORA 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 11:08 am, Aug 10, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.08.09 06:36:47 -08'00' Torin Roschinger (4662) RBDMS JSB 081523 DSR-8/14/23WCB 3-12-2024 ACTIVITY DATE SUMMARY 8/2/2023 T/I/O=570/676/235 (PPROF) 12% HCL Acid Job. Pumped 5 bbls Neet down tbg. Pumped 30 bbls 12 % HCL Acid down tbg. Pumped 5 bbls water down tbg. Pumped 2 bbls Neet. Pumped 100 bbls crude @ 5 bpm. Pumped 30 bbls crude @ 1/2 bpm. SD Turn well over to dso. Time to start flowing well is 4:30 PM. FWHP=0/669/286 Secure well Upon departure. SV,WV= Closed. SSV,MV,IA,OA=Open. Daily Report of Well Operations PBU S-42A 12% HCL Acid Job. Pumped 5 bbls Neet down tbg.()g Pumped 30 bbls 12 % HCL Acid down tbg. Pumped 5 bbls water down tbg. Pumped gg 2 bbls Neet. Pumped 100 bbls crude @ 5 bpm. Pumped 30 bbls crude @ 1/2 bpm. SD Turn well over to dso. STATE OF ALASKA 0 •ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS u 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate I1 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 215-055 3. Address: P.O.Box 196612 Anchorage, Development El Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22662-01-00 7. Property Designation(Lease Number): ADL 0028258 8. Well Name and Number: PBU S-42A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11250 feet Plugs measured feet true vertical 6714 feet Junk measured feet 0 C T 14 2015 Effective Depth: measured 11200 feet Packer measured 8202 feet true vertical 6714 feet Packer true vertical 6603.52 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 47-127 47-127 1490 470 Surface 3043 9-5/8"40#L-80 47-3089 47-3088 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 8340-8603 feet 8643-8739 feet 8779-9041 feet 9081-9592 feet 9632-9993 feet 10264-10663 10701-11140 feet True vertical depth: 6690-6823 feet 6835-6851 feet 6852-6802 feet 6789-6732 feet 6730-6737 feet 6752-6737 6735-6714 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: pp�� 8g�� (�9944 Intervals treated(measured): SCANNED K V 2U IU Stage 1:10701-11140 Stage 4:9081-9592 Stage 7:8340-8603 Stage 2:10264-10663 Stage 5:8779-9041 Treatment descriptions including volumes used and final pressure: See Schlumberger FracCat Treatment Reports 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: New Well Subsequent to operation: 5486 3897 1486 1474 617 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil l J Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-462 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature e..� ,� - Phone +1 907 56`4'4424 Date 10/13/15 Form 10-404 Revised 5/2015 VTI ////WA•cb / 3/i4 2oid RBDMS+bC l 2015 Submit Original Only 3l� ( EJ rcc e,iv clOG,/ • 0• 0 co co co co co 0 0 O CO LO ccr CO N- CO U y 0 0 0 0 0 0 0 0 L O) Cf) N CO N CO CV • V N- N O V O O m A- 10 O) CO O CO 0) CO O ct N CO C O N- N- N- N- 10 (0 CO CO CO CO CO CO O CO CO I I I I I I I I F-- N- N 10 N CO CO CO �t CD N- N 0 CO (0 CO CO CO CO G) 0) C ' (N cc C O O r 10 N CV O V N CO CO CO _ _ _ CO CO CO CO11111111 V 0 Q Q Nrn r N v r-- M OD CO COC 12 • cO O o COO10 d 00 ccCO CD C2 © C2 = J COCO CO J CO CO CO N O $ in co co N to N c • N N Udao - - rr O N N N N M r r r co in CV t O "Cr CO CO 10 CO N C cc O V CO 't N- A- CO r- 0 CO CO N CO W 0)O C W o • U W U C Ct CC Z_ _Z Z_ Z � W W WCOEm O D H Z_ Z Z D D J i i Packers and SSV's Attachment PBU S-42A SW Name Type MD TVD Depscription S-42A TBG PACKER 8201.62 6603.52 4-1/2" HES TNT Perm Packer S-42A PACKER 8318.69 6677.36 5" Baker ZXP Top Packer S-42A PACKER 8602.73 6823.1 4-1/2" Swell Packer S-42A PACKER 8738.84 6851.02 4-1/2" Swell Packer S-42A PACKER 9040.66 6801.9 4-1/2" Swell Packer S-42A PACKER 9592.01 6732 4-1/2" Swell Packer S-42A PACKER 9993.46 6737.23 4-1/2" Swell Packer S-42A PACKER 10226.97 6751.35 4-1/2" Swell Packer S-42A PACKER 10663.33 6737.35 4-1/2" Swell Packer co • • a) L o_ • cL a>i 0) N Yoga) E Csa- co N N !Z - N o C O 0 Q >i V O La i 3 - Y w n N o_ Q N ° a)• 0) ° > C CO O V O O C U O O_ . 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O 0 0 0 0 0 0 O O O O O O O O O 0 O O O O O Q) O 0 0 0 0 0 0 0 0 0 O O O O 0 O O 0 0 0 0 0 N O 0 0 0 0 0 0 O O O O O O O O O O O 0 0 0 0 L U) (a fa aT N N co a) N Ct a2 T T r f� V >L., M O) N i i i i (0 O L) CO(0 E as c.1 as60 mcr) as inN co aMO aD CO 46 aD n ^ V m O VN. t co N co a) a) O 0-) a) Cn a o_ •r_ _ CO O co O o. ,_ M co co N M CU d L) O_ C 00 •- Q N n O 0) O CU a0 N M 0 1 0) CO O CO CO CO 0 O 0 OO 0 _O = N 'O CU CO V 00 CO (.0 c0 CO CO O O C) o N 0_ CO a. .- "-- r COL) r N (L 0 COcO 0_ CO(O COc0 N- ) a 0_ Uf 0) O O m E a) O L `O O T L7 U _ Cµ' �_ T O a) O O O X Iic•] ? dO-o r O as mi U L T O _ U MI C L 05 > CO L 11 o c CO Oa) u`)i .11 .- � ° NY_ O EC o o. a) E o E a) E � � O a = U co co E o �T o . 3a � ° N E o n) T cCU 0as N E N C - ,-O c ._ -O _O a CU N a)N co N (a ,, a) 0 .L. -0 O C O O N❑X 2 N U w L a) 0 C n Q)U) O T .. o O L CO a) E a) O L a) N N a) > Ti 6 Y U o -o a�ro E o T(a c o a) c -a c c .N E Cn a) U C o Y — a) ,a'a C -O N N a) E X a) U N O` X a) n a X' E L.� X a) L 5-1>,-61) C (a E co y ❑ al N L a) a) "N O i4 E O Y U O L O `O Q_ 175 75'O La O (6 7 N (0 O L E" O -O Y .-co... 2_12"O co U I 0 0 0 r LL'O d Q < (n C'') d GO N a) c Cl) H L..0 r Z Cn c CO o 0 LL U) Q 1:1)"O _0 C CU 0_ c ❑•— -O O LL O v N L N_ D 30 P c o m c o.`E' m a N U _0 CY (a Oa)LL .cU L.ca u)m N N 2 N j O a) 0 00 d-0 2j ) N E U X -O v, ETE o O y 0- E O U C C L 0) U O7 00 O_`0 a) a)a) o C E L,;5' > O On a).c 'El O ❑ E >•- p O 0 To`c is o O LL',- O C O i6 O LL 7 o C O H— p o) Z= • Date:July 20, 2015 Subject:S-42A Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: Chris Wallace Attached is BP's proposal and supporting documents to fracture stimulate the Kuparuk interval of well S-42A. Well S-42A is a Kuparuk producer with an undulating wellbore in the Cl, C2 and C4 sands. The well will be stimulated with 6 hydraulic fracture stages. There is a fault between the 2'd and 3rd stages that has been isolated with swell packers. The#6 sleeve will not be stimulated at this time. We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which require identification of fresh water aquifers and a plan for basewater sampling. Please direct questions or comments to David Wages • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF NOTICE OF OPERATIONS Before me, the undersigned authority, on this day personally appeared Y (/i no , who being duly sworn states: 1. My name is David Wages. I am 18 years of age or older and I have personal knowledge of the facts stated in this affidavit. 2. I am employed as an Engineer by BP Exploration(Alaska) Inc. ("BPXA")and I am familiar with the Application for Sundry Approvals to stimulate the S-42a Well (the "Well") by hydraulic fracturing as defined in 20 AAC 25.283(m). 3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well,a true copy of which is attached to this Affidavit as Attachment 1 ("Notice of Operations"). 4. On July 23, 2015, the Notice of Operations was sent to all owners, landowners, surface owners and operators within a one-half mile radius of the current or proposed wellbore trajectory of the Well. The Notice of Operations included: a. A statement that upon request a complete copy of the Application for Sundry Approvals is available from BPXA; b. BPXA's contact information. Signed this 22nd day of July,2015. ,. (Signature) 1' STATE OF ALASKA THIRD JUDICIAL DISTRICT Subscribed nd sworn to or affirmed before me at \V, f S"( �Q on the day of ,20\�j Signature of Officer\ !OWN 3.1 Title of Officer 'at..,1VeisOC ;‘, • 40V VV WxGr• \\\\Q I\O(W5 Agor • • 118},_ (3W4 1/16"5 004151 )141114All 1M: ,S„I4ZA 9AFFTYNOTFR Will ANOt1'.70'11 -1Op1'" ACTUATOR BAKER C V MAX Ot Y./2'pi 1748• —CIIIROMF 0111 A 1 MR— 4(a ELEV= /1 79• r _ ' aI 145V= 37 76' KIIP 3013 Ar[KIND --{ 80' NW A Igle= 111'18 9031Y � _ 8605U 1988' I 14 117'11.S X 44-.0 32117 11//n140Datum TVD- 6700'S3 I31N l IKi4441116r 1(34:K(fXVJQ1161 1 3013' (9\811 S.I I I t 1131 9110,Si-8 03114• 3 +013' I -•� � 41.1_00T WN00'N{5�12A{ 3013 3030' r -3KH OW(M020/1.ii-l-{ 3035' 1 Minimum ID=3.813"Q 1828'! [IAS LIFT l Mi LS 4-1/2"MES X NIPPLE ST`, 143 TVO GEE TYR- VI _AT1I1 PORT DA 11- - • '' 1/18 3688 2! KC#14 T IXKC 7 *1( 0 •O/N/tl4 1 t3✓or CEMEN 1 106/18/151 I 1 -4804' 1 Elli 3 6280 5097 47 KOB4 S OM? BK 0 07/07715 4 2 7862 0121 '10 K($14.S, DMI BK 0 07/07)15 1 8057 8507 48 *MI 9 MN OK 0 t 07107115 •• ♦ 6 8138' 4 1711'IX:M MI 1 (A SNC)1 111171' • l3A1**-M'tFi iAUCs F) 3 804' is5171' 1 141/2'(ESXNP.0 3.013• 06114 0• 9202' 1!•X4117'11111411/7114,11 3_856' I • Ma , 8238' 1 613" • rt fair }---.p trr les x KAP 0-3 8131 1 • 8315' Fir X 5'AKR 1i63F 7%01 IP I 104101-4-1J7"OM 1- 8319• - ► �wt 11 I4t r7 4:18(1' 4-117'ISO.17 Fit 13CR-88 V AM TCIP. I- { 832$' R�*, i` _y 4 1/7 Wit G,D•3 958' 0157 bpf,0=3958' -I 8341 --{7'X 5 SKR CG F1,190.0CX 14744,13=4 349 1 r_.,,G,7111 L 821 VA 10P HC:, 1 8490' 1 1 8363' .5'X 4t1-77-40 13 7/9"I -..... OW Cpt t)-6776" moow SCHLLIM FRAC PORTS FIS 61413.L PACKERS 1_•'' -. _....w.__...„._....�....,,r..._....__..__.. ND 1:0484 SEAT S2 ACTUAL SPF C9C+ !]ATE 110 STOP CEPI)IIAN 0, 7' RC 412' 8603 3.02. 7 8533 3 375' 5.630' C }Or4)77T5 6 8549 3 75” 5 630' C O/4)r/t!7 S 41/2' 8739 392" :•_•• 5 8981 3125' 5630' C 0/4)11775 5 41/2• 9041 392" 4 d 112' 9592 3 4Y •_ 4 9389 3�" 5.630' C 07,07/1'3 •-' 3 9837 2875' 5631' C 074)7715 3 41/2' 9()93 392' 2 10475 2.375' 5,630' C 07107115 2 412' 10227 702' 1 fOfl46 •1301 5630' C •0/4)!/15 1 4112' 10663 3.95 .•■•• . 31(2"AMCF40RP1GR�a1140', ��� OBiFRACFCRT,D=375" lD-200.7• ':• _.... __.. ..� ,� ---1 10995 i 14 117•ISOACIt1A II1)144 :VAI vl.1) 3/5•j 13110 11121' 11(19' 1 14 1/7"SKR SI WI TC%31 vFHFEA rn(.1 SUFI i)-.3 9T 4-1/YUMR,1351,13CR-10F.YOG21. -{ 11131' ---_` --i 11121' I (4-1/'9KRISOL*1)3NVA:.VI 01524.91,D=3958' '-i •=.1 1 11131' H4112'X1-117K()•ti 11418-I 4 111 1144 tars 13C111SO 14,1 l 1 t. I 11248' 564 "--1 11172' I t1 to-k 4 14'x0,1)•71CFJ•i .0192 991.U=3.19.01* GATE 18?'0 .•' . iwwS"II_. I.PM I L d MIBA '• /BY COS Fi21.330E 8+17 UMT 1429191 kORG HORIZ COMPLETION MCA. S 42A 07(09(15 P-273 SICE!RACK(3.42A) 1184ATI1M.2150550 0//1011:7 J40 (18 G 147 coaraEcrions ' API Pb:50 029 27667.01 Of/114117 .1511 ) MAL OCE APFROVAL SEC 35,T1211.R12E,41611'FSI 6 4'4)3 1+1 . _ 07122!15 .1217 A1111131-11-F11-1-1 l 1 0/0701)JWJSV EDITS TO FIRACJS1A43L SYM3OL ORDER 1_ 8P 6lploratlon(Alaska) Page I 6 of 7 • TubeMove Analysis: Force(IGO(+Tensile) d et) N W W o pO re 0 O0 V0 0i cal0 O 0 0 IV 0 0 O ? N O 000 0 0 0 0 0 0 0 0 0 0 0 ry 3 d Co 0 0 m o 5 _ 0 o 0 m o, a o • 0 y 0 S V N Loo a m1 0 a i o 0a 0 Oo t .... ..... ,...., e a P, o o m c P..."or a Frisr c. r It N O 0 a v 1 O C T ^ O lT 3 0_ . .. o W CO o 00 a O W c o a 40 a n n m va o0_ _... 0 b d 0 >r N N_ m A 1 o T a ; 5 R 1 0 N to D 11 ro 0— O c O a n a _ O U' N 0 0 0 Effective Differential Pressure(psi) MD(t4 M 40 CO V O 0 a W N k o 0 0 0 0 o § § Q i•S w 0 $ 0 0 0 • 0 0 0 0 0 0 0 0 0 0 0 0 $ $ 0 o 0 0 0 0 0 0 0 0 0 0 0 3 00 c Z ! 7 O 0 o ro a m o N r qcn , cn3 ......_ a o (+ n 07 p • 0 e a 3 Z j e v i. $ 3 ` a to . \ItZ a e"...."--'�,w•-dxA.ae..&'. a :«y,i -.44.-^-^*----1 a 14 b 1 O o . Co a v I . • j _ 1 a . 0N O— O/ n N y w. T ♦ � .• 0 J N O (N/1 r \\I\\\ _ f 0 • :: CO N O o• .. • r o m' , , v r i. • • o W cn 0 • R CO O PJ N W : i ,yy{q{( O ap S� N if e W O a 0 k'"j T ; i", m CO , r p T 3: 1 eZ1 isop o N D 1 0 a m ? ~ y 0 r a ✓ . i 0 o n atop 0 0 CO0 a • , Y t. .. . n O n a a 0 0 v ; p NPA , O N O O • O O O O Page l of 7 • Affidavit of Notification(20 AAC 25.283,a, 1) Partners notified 6/11/2015: ConocoPhillips ExxonMobil Chevron Department of Natural Resources Plat Identifying Wells(20 AAC 25.283,a,2,A-C)and Faults(20 AAC 25.283,a, 11) 7 ,...ag,„ , , , „..., ,„ . ti 10- ,�'•'I..Mwv,ti w W' ., 11111®. „' so' NE v. ), I �,,,—ii A u . I • . 30' W. .raa.i 1 ,'.-2,-1,14#106,„„ • 11 2 .„0.00.yor Jis-1 1 4\ 50' W f' `. t!$ 1 ' .. +. • Red lines indicate approximate length and location of fracs '1, Producers within ��mile of S-42a: S-108 S-31A S-112 S-105 S-1108 S-104 S-109 S-115 Per the plat above, there are no water wells within 1/2 mile of the subject well. The above map shows 3 faults of concern: 1, 2 and 3. The remaining faults are well away from stimulation chemicals and/or on the other side of three main faults. Faults#2 and 3 are parallel to the primary stress plane (the direction our frac is going to grow) and should remain isolated from frac fluids. Fault#1 is the primary fault of concern. In order to ensure the induced frac stays well away from this fault, a data frac is planned which will give information on the rock including closure pressure, leak-off coefficient and will help determine more accurately the anticipated length and height of fracturing fluids. Given the above information, all fracturing fluids should remain within the matrix areas of C1-4. • Exemption for Freshwater Aquifers(20 AAC 25.283,a,3-4) Well S-42a is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated July 11, 1986 where Standard Alaska Production Company requested the Alaska Oil and Gas Conservation Commission to issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II Injection activities. Findings 1-4 state: 1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are situated at a depth and location the makes recovery of water for drinking water purposes economically impracticable. 3. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are reported to have a total dissolved solids content of 7000 mg/I or more. 4. By letter of July 1, 1986, EPA-Region 10 advises that the aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a non-substantial program revision not requiring notice in the Federal Registrar. Per the above findings, "Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC 25.440." thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283,a,5-6) Well S-42a was sidetracked on 6/14/15. After de-completing the weil, a whipstock was set at 3035' and 9.3 ppg drilling fluid was circulated in the well. A window was milled in the 9-5/8" casing from 3013'-3049' with cement observed behind the casing. An 8-1/2" intermediate hole was drill where 7" 26#, L-80 Vam Top HC casing was run to 8480' and cemented in place with 50 bbls of 11 ppg Mudpush II spacer, 100.4 bbls of 11.5 ppg litecrete (40% excess) and19.1 bbls of 15.8 ppg Class G cement (40% excess). The casing was pressure tested to 3500 psi for 30 minutes for a passing test. The 6-1/8" production hole was drilled where a 4-1/2" 13.5#, 13Cr80 HYD 521 liner with sliding sleeves and swell packers was run and landed at 11,248' no significant issues were encountered while drilling the production hole. The 7" production casing has been tested to 3500 psi with 10.3 ppg brine in the well. Accurate Pressure Ratings of Tubulars and Schematic(20 AAC 25.283,a,8) 1414 - <�,.1/115-6500 PSI VIC S-�4 2 A I �V1F7 414-At1 iM; SAFETY NnTF$ Wil 1 AN(11 f�70•Efj -0000'•'• ACIUA TOR BAKQ3 C MAX DI S 12'44 8740'"'CNR1N r 11111 A I NR'-' Uc8 73 EV- rt/IT r ' LW FFV- 3770' 'KCA 3013 70'CO JO --i 8Q' 1 Mur Angle I11' 40M& 2163 1595' 114_il:'•115%VI'1, 09C anMc- 7,A ) 8605 2'7 -.. WMn1VD 0700 GS 19 5.0r IIKN441iii!l(x.K(05771N1157 I . 3013' 193,8"Cr,S TR 104.1-90 9S,0-9 835 -- -3013' 1 141_LOUT314840 .04(54241 3013 3030 /x-147 .,,,caw(L5,70/151 1-1 .3036' Minimum ID=3.813"a 1099' LAS LW!NWALa,E15 4-1n"HES X NIPPLE SE 143 IVU OW TYPE 1 VI V '.A1(71'PORT FAIT 4 1/771 3688 7/ mass}1XX2 11X II 010/115 Its!1(7F c:.tiAEN1109r2&'I51 I-J -'1804' - _ 3 6240 5007 47 KC.RM S ),0 BK 0 0707115 I 1-- 2; /517 1/121 30 4(934.5 OAKBK 0 07/0/1115 + I 8057 0507 46 10304 S 1/MV OK 0 0707115 h 'r .+ .� Q I'n1R 9148' 41r2' d:lANA Y4i( 144491 lN/f X' e SAF(440/4` 0 3.034' .4` A i 8171' 1 14 112'1CSXM'.0-3.9t3•1 144.:4 _4x 8202' 1/•8411r1110IN),1KI/I3 3.694'1 ' 8238- 4-1121-15 X 52,U 1 911- 8311' 4 1729 FEffi X AP D 1 61]', 8319` j-If-X S'SKR 144F7X21TP I1(3-'OF 4-172":W�-� 8319' ' _.., w111lX,It 4191' , 4.1R'THC:.470E 13CR.84 YAM TOP 1._.-{ 8328' 08• •4:A J -(4 t/7MACC,O-3958'I 0152 Apt,113-,3059" I ,.+. 1 � 1C 8343' '-17'X li RKR(r.FI FX1(X.K 14-44,D-4 340' k L0(ZG 1 LNOVAMIUPHL, I L11460' 9363' 5'X4117X0 D 759 I 383 bp( D-11778- .... SCHLIAN FRAC PORTS FES SWELL PACKERS - '... NO CFTSEAT SZ ACTL7AL SEE QC DATE No svCr(mn11114-MHa 7 4-112' 8003 ' 3.992' ` •-.111.1,-• 7 957333 3 375' 5.6311' C 107477719 6 9619 371^ 56:97 C '0/471115 6 4 772' 0719 3 92' •_ 5 8961 3 125' 5 6M• C 107/0//15 5 41!9 9041 3 92' : 4 931 00 3. ' 5630' C 107477/15 4 41/2'1 9592 397 —•:• 3 9937 2875' 5630- C 07477115 3 4-1/Y I 8993 392' 1 2 412' 10227 3 Oa 2 10475 2 775' S 0730' C 07417115 1 412'1 10063 3.95 .•,III., I 10896 '19N 5630' C 10747/115 3432'AMNONPPR di11140'. .—. Eel FRAC R)RT,13=375' JD-2402- ':'Ell' -1 10888' - 14.17'+Np A(111A RIM PAC VA!VI It 1P 3 x8111 11121' INN _... 110W 141/7"MR SI F T II83 Vf RFIf.,4 HON SUR D-197 4-1/2'LFR,135413CR-401110521 -1 11131' --__1s" --4 11121' 1 14-12'BKRSOLAIFJN VAIN=I 0157401,13=3958'. •-• •3 11131' 14172'x1-.12'X00=2 96-I 4 177'I M7.I:I SI 13CR-40 16111101 I 11248' " .I,2, 14112' 1 1 x 1(',"Y 4 1,"2"30 T7 "RP.'' 0152 407,IU-3.956' 1141E FE,or' wM.lNIJ 1 u+a IV-V BY' (XMINENT5 1091NOF.HAY(HI 04/25961 _ NO }ONG RIZ COMPLETION WELL:S(2A 07/09413 P-273 SIDETRACK(542 )_... 1EA41T No 21`0550 0/110'15 IMP OTFG HD CJIJRIECTAHS AA No:530)29 22462 01 0//211th 4(.11.0 FINAL ODE AFFt4OVAL SEC 35.01214,R121.4161'1-57&4503'Itl 07/22/15 911) Agt17 HIE IHrI 1 1 01177119 .9LJb0 1EC4T5 TO F'RACJS'AaL SYMBOL ORDER BP Exploration(*114 pa) Name/Size Weight Grade ID Burst,psi Collapse,psi 9-5/8" Production 40# L-80 8.835" 5750 3090 7" Liner Production#1 26# L-80 6.276" 7240 5410 4-1/2" Liner Production#2 13.5# 13Cr80 3.92" 9020 8540 4-1/2" Tubing 12.6# 13Cr85 2.958" 8430 7500 • Wellhead: FMC manufactured wellhead, rated to 5000 psi. Tree:4-1/16" 6,500psi Tubing head adaptor: 13-5/8" 5,000psi x 4-1/16" 6,500psi Tubing Spool: 13-5/8" 5,000psi w/2-1/16" side outlets Casing Spool: 13-5/8" 5,000psi w/2-1/16" side outlets • • Geological Frac Information (20 AAC 25.283,a,9) Formation MD MD TVDss TVDss TVD Frac Grad Lithological Desc. Top Bot top bot Thickness HRZ 8394 8455 6640 _ 6650 10 0.75 Shale Kalublk 8455 8482 6650 6688 38 0.75 Shale TKC2B 8482 8493 6688 6694 6 0585 Sandstone TKC2A 8493 8535 6694 6714 20 0,585 Sandstone TKC1C 8535 8571 6714 6729 15 0.65 Sandstone LCU 8571 8611 6729 6743 14 0.75 Shale TKA6 8611 8634 6743 6750 7 0.65 Silty Sandstone TKA5 8634 8712 6750 6766 16 0.6 Sandstone TKA4 8712 8781 6766 6770 4 0.65 Silty Sandstone Invert#1 8781 6770 TKA4(Invert) 8910 8781 6758 6770 12 0.65 Silty Sandstone TKA5(Invert) 8980 8910 6740 6758 18 0.6 Sandstone TKA6(Invert) 9008 8980 , 6731 6740 9 0.65 Silty Sandstone LCU(Invert) 9070 9008 6709 6731 22 0.75 Shale TKC1C(Invert) 9157 9070 6686 6709 23 0.65 Sandstone TKC2A(Invert) 9252 9157 6671 6686 15 0.585 Sandstone Revert#1(TKC2A) 9762 _ 6644 Fault(TKC2A) 10130 10306 6663 6644 Invert#2(TKC2A) 10306 11190 6669 6663 Sandstone TKC1C 11190 6632 Not Drilled 0.65 Sandstone HRZ 8394 8455 6640 6650 10 0.75 Shale Kalubik 8455 8482 6650 6688 38 0.75 Shale TKC2B 8482 8493 6688 6694 6 0.585 Sandstone ea S-42A_Horizontal Borehole Profile gat vt-sx �5 n —0,,, e/t.�6:`artr- 4.G:at M•! WAN* _ _.. 6500 6520 Ii1 i4ki'Ner q _..._ __ ...t f Weems._.. 0500 6 N CO " _... -_._..._. ._. . 0020 \Y .- _.,... I'CY41Htl t sin NOa 6610 Q .16.4.«wr: 4 +�°-s rix — tl6E0 '�,- ... ' Cl . 6 (.690 q 1 ~ IMO iww10 • 1410. <''k / a/n0 2 .' � OONYhot'Mer 41, .,.'WO „6 ^-".. ” �. ... 6,19 r r N90 . 6,.50 .a..,.®..., 6160 6400 MN 6820 WO _... 0010 i w'n2irneap68966990__..._--.� 9x69 xv Measured Depth • • Mechanical Information of nearby wells(20 AAC 25.283,a, 10) Per plat above, the following wells have been reviewed for casing and cement information Well S-108 Spud Dat. 6123/2001 Perforation Interval P&A'ed TO-MD(ft) Csg sizenw Comments I Cementing Information Surface Casing:I 2,857 7 5-108 is P&D'd to surface 29 7#,1-80 Intermediate Liner/Casing:, Drilled intermediate section with 6-3/4'bit Cemented with 87 Drllitng/Productlon Liner. 5,497 5-1/2", bbls of LiteCrete at 12 ppg and 15.5#,1-80 57 bits of GasBlok cement at 15 8 ppg.Plug was bumped and casing was tested to 2700 psi. Drilling/Production Liner. 7,835 3-1/2",9 3#, Ranas 3-1/2"x 5-1/2"tapered L-80 string Tubing: 1,884 31 Kill string L-80 Production Packer N/A Well S-31A Spud Dab 12/20/1990 Perforation Interval 2 intervals from 8169'-7999'MD TO-MD(ft) Csg size/wt Cementing Information Surface Casing: 2,708 133/8`, 68#,NT-80 Intermediate Liner/Casing: 10,783 9-5/8",47#, NT-80 Drilling/Production Liner. 11,428 �'28#'L- 80 3-1/2",9.2#, Tubing: 10,469 1 x 4- 112',12.6#, 1-80 Production Packer 7,634 Well S-112 Spud Date 8/72002 Perforation Interval 3 intervals from 8535'-6900'MD Till-MD(ft) Csg size/el Cementing Information Surface Casbtg: 2,915 9-98",40#, L-80 Drilled intermediate section with 8-3/4"bit.Cemented with 93 Intermediate Liner/Casing: 6,825 P,2fM,L- bbls of LiteCre[e at 12 ppg and 80 38 bbls of 15.8 ppg cement Plug was bumped and casing was tested to 3500 psi. Drilling/Production Liner. 8,535 12.6#,L-80 Tubing: 6,718 4-1l2, 12.6#,1-80 Production Packer 6,858 • • Well 5-106 Spud Date_ 11/10/2000 • Perforation Interval 2 producing intervals from 7685'-7650'MD TD-MD(ft) Csg size/w1 Cementing Information Surface Casing: 2,996 9-518,40#, L-80 Drilled intermediate section with 8-3/4"bit Cemented with 115 Intermediate Liner/Casing: 8,103 7",28#,L- bbls of 11.5 ppg cement and 55 BO bbls of 15.8 ppg cement Plug was bumped and casing was tested to 3500 psi. Tubing: 7,630 3-1/2",9.2#, 1-80 Production Packer 7,594 Well S-1106 Spud Date RSTd 2113/14 Perforation Interval 1 interval from 8770'-8728'MD TD-MD(ft) Csg size/wt Cementing Information Surface Casing: 2,716 9-5l8",40#• L-80 Drifted intermediate section with 8-1/2"bit.Cemented with 85 7"Intermediate LinerlCasing: 8,672 1- bbls LiteCrete at 11.5 ppg and 80 35 bbis of Class G at 15.8 ppg. Plug was bumped and casing was tested to 4000 psi DrlllinglProducdon Liner. 8,774 44/2", 12.6#,L-80 Tubing: 8,594 4-VT, 1246#,L-60 Production Packer 8,510 Well S-104 Spud Date 2/912001 Perforation Interval 11 intervals from 8836'-8920'Ml) TD-MD(ft) Csg sizelwl Cementing kiafmabon Surface Casing: 3,736 9-5/13", 1-80 Drilled intermediate section with B-3/4"bit_Cemented with 111 Intermediate Liner/Casing: 9.186 7",264,L- bbis of LiteCrete at 12 ppg and 80 52 bbls of GasOlok at 15 8 ppg. Plug was bumped and casing was festal)l0 3600 psi Tubing; 8,736 4-112", 12.6#,1-80 Production Packer 8,853 Well 5-109 Spud Date: 1/17/2003 Perforation Interval: 8 intervals from 11428'-7858'MD TO-MD(ft) Csg size/wt. Cementing Information Surface Casing: 3,030 9-5/8",404, L-80 Drilled intermediate section with 8-3/4"bit.Cemented with 131 intermediate Liner/Casing: 7,820 7",28#,L- bbls of LiteCrete at 12 ppg and 80 19 bbls of Premium cement at 15.8 ppg Plug was bumped and casing was tested to 4000 psi. Drilling/Production Liner 11,470 4-112", 12.6#,L-80 Tubing: 7,851 4-1/2", 12 6#,L-80 Production Packer: 7,552 • • Well S-115 Spud Date 12/30/2002 Perforation Interval 2 intervals from 7400'-7250'MD TD-MD(ft) Csg size/wt Cementing Information 7.5/8", Surface Casing: 3.248 29 7#,S- 951L-80 Drilled intermediate section with 6-3/4"bit Cemented with 81 5-1/2" bbls of LiteCrete at 12 ppg and Intermediate Liner/Casing: 5,382 155# L-80 40 bbls of Premium Class G cement at 15 8 ppg Plug was bumped and IA was tested to 4000 psi Drilling/Production Liner. 7.585 3-1/2" 9 2#, L-80 Tubing: 5,399 3-1/2".9 2#. L-80 Production Packer 5.383 Summary Hydraulic Fracture Program (20 AAC 25.283,a,12) (Detailed program included) 0 0.6.48 S-I2A_Horizontel Borehole Profile »nr. 6520 . INNANE ,x566 T,TWAT!...syn.* .._ ,06 T4Y�YYM'tVA, WO. VANN TEE "+w,eA..,:., -�".. - 4 raraerrn e.iw, eaa Alm> ps•. _ o ipow- .a+e .:.+w• r�',.=,,� F "^" ar2J ..�..... 4)N "lM 6)30 0.0 sae 5 0720 6 _mss s,xi^' 689 arra;.. +41... -_- _.. _.. ...,... - •',•�N__ .— _ �..,.._........ 9330 fMi'liIlf�Y•r 0E0 6000 t I Measured Depth Above is a cross-section of the wellbore. Sliding sleeves or fracports are labelled with Green diamonds and the swell packers(external casing swell packers)are labelled with the black rectangles, both of which are along the wellbore. Hydraulic fracture treatment schedule stage 1-5: FLAT® PUMP *MTV VOLGBTE DIRTY VOLUME PROPPA8T STAGE AVERAGE CONTENTS TYPE RATE STAGE CIM TOT EGO STAGE CUM TOT JON STAGE STAGE CUM CIM SEE • PPA .....P. F,..."..1 • PO , tZ ttlt to ....x44....,-.x403 at** ...I<t46° Ess 4 a r ?42,346.:. 3e 1 *MP.,! FletPrva aa* • 44.11/0 19 1k! 9 MO/ 4,140 14 3114 141.,z46 4/111 4,f111345353 3r, 3 F p,e 4S ru"Pyx AM Y!''M6 44 . aeo , z Too !7 esa aT acs s sss r sas 354 Ssi M 38 4 F.gPe,I IS FIS t* •.44 Yt ,9 le � Z Ts4 14,700 (214St UI 032 1T 831 364,070 b 20 33 a" F.ep«I.S FAA emP AO 4 37 48 111 454 8183 420. rn sno /33,88S 25,041 42.420 - 338,024 rr J11 o Frgw1.S. FhtPne ..._ ge._....... .',j . bs 4 a"_.xstab.,. 44 4a1t?4.... 48+tIt... 7',.••4.1 ;O,.• r er1: V8 Cif is'1 o% . '3318 . Iso 23.8371,Mn.3 d' 434.60/ Hydraulic fracture treatment schedule stage 7: • • tLUIO PUMP MATY VOLUME UMW VOLUME PPOPPANT STAGE AVERAGE COMMENTS TYPE NATE STAGE CUM TOE JOB STAGE CUM TOT JOB STAGE STAGE CUM CUM SIZE • PPA (BPM) (0(ILI MOO TORO (GALI (GALL (GAO 1 0.8191 UM) P.neowJ I7= *31'art 15'441 V41t,P44:+ ..,. 42 ,0 f1MMa1 AT 0.01 Y7 lJ0 aQ 300 300 $._FAO -I7009 +21740. PAM' o 434,191 ....__AS ,..,....! Gropes,AT Fitt P,a r 1? ._..v7 It?. :.._..a+7 +: 315 3723 4 3,15u ISMS/...:1513,415 7 a,71 ....3,021 471,402.. M 741 44 3 F.„00 47 rife 0,41, 4A .+.? ?. ...10 ..:. .?4 +?o......arse 3.1w T ?11 9t10...103,4 y V,37e II,3$3 : 44N573 111 ....,.,..45 0 FauM!!u+AT ll Pitip +( :...vrin?....; an Iu0 SW ASO d�11+4W ... +fiJ '....4, ...?!4§z. lgs.6t7 zV +? 46 a Troop..17 11.10.04. I 1 7 Lin au '1w 150 40314 96 .0 0,49114 31 501+ _177,03S-,S0,61.7„ 111 SS9 siva' V IO ....._. 4T ... �III F opo Ol I?...F +Atial._.,.....fl It 2 1CI 00 10S0 4390 17,0110 44,96)...10a„07S.911-,314 IF.9,01'7 ,054 q 9 ..... . ,... ae 0 Rea+Pmc t7 044, r7+TR in 5:555 MO � !S')7 ,'4.45Z2,63,552 tel,tai" S .OSA The maximum horizontal stress has been determined to be nearly perpendicular to the wellbore, this is based on image logs taken while drilling as well as historical information. The maximum horizontal stress means that the induced hydraulic fractures will be perpendicular to the wellbore. In order to insure the induced frac does not establish communication with Fault#1. Maximum Anticipated Treating Pressure: 5000 psi Stage 1-5: Anticipated half length: 300' Anticipated height growth: 75' Stage 7: Anticipated half length:400' Anticipated height growth: 100' Due to the horizontal nature of the well, we are unable to specify a MD for the frac height. The above values were calculated using modeling software. Surface pressure is calculated based on a closure pressure of -0.57 psi/ft or -3800 psi, this combined with the anticipated net pressure to be built and the friction gives a surface pressure of 5000 psi at the time of flush. The frac height is primarily based on closure pressure differences between the confining shale layers harder, more brittle carbonate reservoir. Average confining layer stress is anticipated to be -0.7 psi/ft. Half length is based on confining layer stress as well as leak-off and formation modulus. Given the values, the above half lengths are calculated. Pressure Test Information(20 AAC 25.283,a,7) Per the frac program, the both the tubing and the IA will be pressure tested. The IA will be tested to 4000 psi and the tubing will be tested to 4500 psi (118% of max differential of 3800 psi). PRV setting procedures and annulus monitoring: Maximum Allowable Treating Pressure: 6500 psi(WH pressure limit) Stagger Pump Kickouts between: 6175 psi and 5850 psi(90%to 95%of MATP) Global Kickout: 6175 psi(95%of MATP) IA pop-off set pressure: 3000 psi(75%of MIT-IA) Treating line test pressure: 7500 psi Sand Requirement 465,643#20/40 Carbolite, 138,441#16-20 RC Minimum Water Requirement 5,000 bbls(pump schedule:4035 bbls) IA Hold Pressure 2700-2900 psi(IA pop-off @ 3000 psi) OA Monitor and maintain open to atmosphere • • There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally,the treating pressure, IA pressure and OA pressure will be monitored in the frac van. r ....miia S-42a Rig Up .dMdr. Trups .Domed ea ..` loner Annulus Line Ceninte 41/1161 <armaibmwereas control I I ! 1,-------"111111111.111111 MEI............ . 11114111111.1.1 111111111 ! • Chemical Disclosure(20 AAC 25.283,a,12) ;hod Dos,eunuui-y YF128FIex0:WF328 165,126 Gal Contains:Water,Surfactant,Breaker,Gelling Agent,Crosslinker,Scale Inhibitor,Gay Control Agent,Additive, Bactericide,Propping Agent thermal volume Nered In the renter a,ove represennrbe Summation fvcu ono,Uorove,Wannampooee by tpe»r -- CAS Number Chemical r.iii, Water(Including Mix Water Supplied by Client' _68 55 eu4u2e8-4 Ceramic materials and wares,chemicals "30% 9000-30-0y Guar gum "2% 67-46-1 2-hydrory-N.h.N trimethydethanamiraum chloride <1% 1119-33-1 eoronatrocakite <0.1 107-21-1Ethylene Glycol -�- <0.1% 7727-54-0 .. __. ...-..... ._._... _.. Oxammonium peraxrdisulphate _ <0.1% ._......__. .__ _._......._.___- 129898.01-7 2-Propenmc and,polymer with sodium phosphinate <0.11% 67-63-0 Proof -ol — <0.1% 111-76-2 2-butoxyethanol § <0.1% 34398-01-1 Alcohol,C11 linear,etho)ylated 1 <0,1% 25038-72-6 Yinyiklsne chiortde/methylacrylare copolymer r <0.1% 68131.39-5 f. C12-15 alcohol athyoxylated <0.01% 1330-43-4 Sanborn tett aborate <0.01% 7631.86-9 Non-crystalline silica(impurity) <0.01% 1310-73-2 Sodium hydroxide(tmpur ty) <0.01% 7647-14-5 Sodium chloride <0.01.% 110-17-S Furraric acid <0.01% 7704-73-6 Morw:Odom fumarete. <0.01% 10043-35-3 Bond and <0.01% 10043-52-4 _., Calcium Chloride <0.01% 91053-39-3 Diatomaceous earth,calcined <0,01% 112-42-5 ._.. 1-undecarwi <OA_.. .. _ 0 l% 1480796-6 M ii.;:.tum silicate hydrate(talc( <0.001% 10377-60-3 --- ....._... i .. . .........,._.-.. . _ Magne_s+um ululate .......-_.___....._ __..'......_.. .._ 0.001% . 111-46-6 ?,77•oitydlethanoi(impurity) <0.001% _.. 26172-55-4 5-dllono-l-methyl-2h-isathiazoiol-3-one <0.001% 7786-30-3 Magraeuurn chloride a <0,001% 900234 0 Poly('reiraihiocoethyl#ne) <0.00.1% 125005-87-0 Diutan guns <t1.1x161% 7447-40-7 Potassium chloride{impurity) <00001% 2682-20-4 2 anatltyl 2h-1C$lri0zol-3.005 - <0.0001% • 127-08-2 Acetic acid,potassium salt - <0.0001% • • 14808-60-7 Quartz,Crystalline silica ,0.0001% 14464-46.1 Crlstobalte <0.0001% • 64-19-7 Acetic acid bneurity <0,0001% `Mat - itx0% S Schlumberger FracCAT Treatment Report: S-42a Stages 2-6 Well :S-42a Field :Aurora Formation :Kuparuk C Well Location : County :Prudhoe Bay State :Alaska Country :United States Prepared for Client :BP Exploration Alaska Client Rep :David Wages Date Prepared :September 10,2015 Prepared by Name :Alexander Martinez Division :Schlumberger Phone :5613895006 Pressure(All Zones) Initial Wellhead Pressure(psi) On Vacuum Initial BHP at Gauge(psi) 2,477 Surface Shut in Pressure(psi) 3,773 BH Shut in Pressure(psi) 6,245 Maximum Treating Pressure(psi) 5,882 Note:This job resulted in a screen out Treatment Totals(All Zones As Per FracCAT) Total Slurry Pumped 5,936 Total YF128FIexD Past Wellhead(bbls) 5,292 (Water+Adds+Proppant)(bbls) Total WF128 Past Wellhead(bbls) 618 Total Freeze Protect Past Wellhead 11 (bbls) Total Proppant Pumped(lbs.) 512,810 Total Proppant in Formation(lbs.) 507,830 Total 12%HCI Pumped(bbls) 0 Total 16/20 CarboLite Pumped 372,350 Total 16/20 GarboBond Pumped(lbs) 140,460 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103(gal) 222 222 M275(lbs.) 74 73 L065(gal) 216 215 J475(lbs.) 1815 1813 L064(gal) 48 47 J134(lbs.) 25 0 L071 (gal) 367 366 M002(lbs.) 102 101 J604(gal) 418 417 J511 (lbs.) 486 485 J580(lbs.) 5,866 5,736 D206(gal) 2 2 Disclaimer Notice This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • • Schlumberger Client:BP Exploration Alaska �t Well:S-24 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 1 : Stage 2, Propped Frac: As Measured Pump Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Step Step Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass Name (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (Ib) 1 PAD 197.1 36.7 6.3 YF128FIexD 8278 0 0 0 2 Scour 50.1 39.4 1.3 YF128FIexD 2076 CarboLite 16/20 0.5 0.2 912 3 PAD 150 39.7 3.8 YF128FIexD 6298 0.5 0 0 4 1.0 PPA 50.1 39.5 1.3 YF128FIexD 2032 CarboLite 16/20 1 0.7 1631 5 2.0 PPA 50 39.1 1.3 YF128FIexD 1943 CarboLite 16/20 2.1 1.7 3590 6 3.0 PPA 99.6 37.8 2.6 YF128FIexD 3708 CarboLite 16/20 3.1 2.7 10802 7 4.0 PPA 99.9 38.1 2.6 YF128FIexD 3580 CarboLite 16/20 4.1 1.2 14058 8 5.0 PPA 172.9 36.5 4.7 YF128FIexD 6064 CarboLite 16/20 5.1 0 27444 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step I Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 36.7 39.9 3327 3693 85 2 Scour 39.4 39.8 3293 3333 3248 3 PAD 39.7 39.9 3211 3250 3080 4 1.0 PPA 39.5 39.9 2964 3077 2895 5 2.0 PPA 39.1 39.4 2838 2892 2757 6 3.0 PPA 37.8 39.0 2522 2746 2359 7 4.0 PPA 38.1 38.6 2296 2357 2184 8 5.0 PPA 36.5 37.0 2139 2232 2008 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 869.7 23.9 33951 58439 Average Treating Pressure: 2806 psi Maximum Treating Pressure: 3693 psi Minimum Treating Pressure: 85 psi Average Injection Rate: 37.7 bbl/min Maximum Injection Rate: 39.9 bbl/min Average Horsepower: 2608.5 hhp Maximum Horsepower: 3582.7 hhp Maximum Prop Concentration: 5.1 PPA . • Schiumberger CeWell:5-24 Formation:Kuparuk C District:Prudhoe Bay Country.United States Section 2: Sta• e 2, Pro . sed Frac: Job Messa•es Message Log Treating Annulus # Time Message Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 1 07:45:11 Started Acquisition 2 08:09:09 Preparing to Prime pumps 3 08:26:43 Priming pumps 4 08:46:25 Started Recording 5 08:46:32 All Pumps Primed 187 0 0 0 0 6 08:48:37 Changing N2 bottle 188 0 0 0 0 7 08:57:45 Low PT 586 1 0 0 0 8 09:05:10 High PT 7487 1 0 0 0 9 09:10:24 High PT:good 7361 0 0 0 0 10 09:11:44 Check valve test:good 7302 0 0 0 0 11 09:24:06 gathering for safety meeting 89 0 0 0 0 12 09:24:31 SLB completions arrived on location 90 0 0 0 0 13 09:24:45 connecting BH gauge 90 0 0 0 0 14 09:47:07 LVT primed on ball dropper 6 0 0 0 0 15 09:51:58 Ball 2.988'loaded 5 0 0 0 0 16 09:52:08 Ball 3.122"loaded. 5 0 0 0 0 17 10:02:56 BH gauge hooked up and checked 5 0 0 0 0 18 10:06:35 Bringing up blender discharge pressure 6 0 0 0 0 19 10:07:26 Priming LAS unit lines 6 0 0 0 0 20 10:10:08 Troubleshooting POD RD Side 6 0 0 0 0 21 10:12:47 LAS primed 16 0 0 0 0 22 10:21:01 Linear gel good:28# 17 0 0 0 0 23 10:42:36 Toubleshooting POD Hydraulics 16 0 0 0 0 24 12:42:31 POD phase 4 rigged in -9 0 0 0 0 25 12:43:04 Discharge pressure in blender:good 19 0 0 0 0 26 12:48:58 500 psi on the line,preparing to open the well 565 0 0 0 0 27 12:49:04 Master valve is open 561 0 0 0 0 28 12:51:54 SSV is open,2100psi 512 0 0 0 0 29 12:53:06 Swab valve is open 8 0 0 0 0 30 12:54:08 LRS to bring up IA pressure 136 0 0 0 0 31 12:57:21 Start Propped Frac Automatically 100 2019 0 0 0 32 12:57:21 Start Stage 2 Automatically 100 2019 0 0 0 33 12:57:21 Started Pumping 100 2019 0 0 0 34 12:57:50 Rolling pumps 83 2010 0.2 2 0 35 12:57:58 Starting XL liquid ads 666 2073 0.5 3.6 0 36 13:00:39 Activated Extend Stage 3357 2858 65.9 37.9 0 37 13:01:43 POD densos are zeroed 3604 2993 107.1 39.7 0 38 13:01:49 FC densos zeroed 3600 2996 111.1 39.6 0 39 13:02:08 out. 3622 PAD by 50 bbl to account for LAS lining 3622 3014 123.6 39.7 0 40 13:02:19 XL pH=9.4,sample is good 3639 3025 130.9 39.6 0 41 13:03:18 Stage at Perfs:PAD 3367 3070 169.9 39.8 0 42 13:03:46 Started Pumping Prop 3331 3096 188.5 39.8 0 43 13:03:48 Deactivated Extend Stage 3340 3086 189.8 39.7 0 44 13:04:21 Sand is falling for scour 3313 3023 211.6 39.7 0.2 45 13:09:30 Sand is falling 2940 3057 415.7 39.8 1 46 13:09:32 Stage at Perfs:Scour 2943 3059 417 39.8 1 • • ScbluiNberger C'ient:BP Exploration Alaska Wet:S-24 Formation:Kuparuk C District:Prudhoe Bay Country.United States Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. i Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 47 13:10:06 XL sample pH =9.4 2901 3075 439.3 39.4 1 48 13:11:36 Packing smoking on pump 5,bringing rate down 2650 3052 497.9 38.9 2 49 13:11:52 Grabbing another gear with another pump 2629 3057 508.1 37.8 2.9 50 13:13:27 Stage at Perfs:PAD 2444 3035 567.7 37.9 3 51 13:14:46 Stage at Perfs:1.0 PPA 2334 3053 617.8 38.3 4 52 13:15:29 XL pH=9.2 2299 3067 645.3 38 3.9 53 , 13:15:50 Coming down on pump 5 2281 3057 658.6 37.8 4 54 13:15:57 Bringing rate up with another pump 2175 3070 663 37.8 4 55 13:16:04 Stage at Perfs:2.0 PPA 2402 3069 667.4 37.4 4.1 56 13:17:49 POD gate%check:good 2265 3044 732.1 35.2 5.2 57 13:18:47 Stage at Perfs:3.0 PPA 2119 3028 767.4 36.1 5.1 58 13:20:42 Activated Extend Stage 2151 3017 837.5 36.5 5 59 13:21:30 Stage at Perfs:4.0 PPA 2233 3027 866.6 36.6 0 • ! Schiumberger Client BP Exploration Alaska Well S-24 Formation:Kuparuk C District.Prudhoe Bay Country.United States Section 3: Stage 3, Propped Frac: As Measured Pump Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Step Step Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass Name (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (Ib) 1 Spacer 15 37.1 0.4 YF128FIexD 630 CarboLite 16/20 0 0 0 2 3"Ball 124.5 37.2 3.3 YF128FIexD 5229 CarboLite 16/20 0 0 0 Slow 4 3 19.2 31 0.7 YF128FIexD 813 CarboLite 16/20 0 0 0 seat 4 PAD 75.4 31.4 2.4 YF128FIexD 3157 CarboLite 16/20 0 0 0 5 Scour 50.1 37.5 1.3 YF128FIexD 2067 CarboLite 16/20 0.5 0.4 1039 6 PAD 150 37.3 4 YF128FIexD 6291 CarboLite 16/20 0.5 0 0 7 1.0 PPA 50.1 37.7 1.3 YF128FIexD 2031 CarboLite 16/20 1 0.1 1666 8 2.0 PPA 50 37.6 1.3 YF128FIexD 1943 CarboLite 16/20 2.1 0.4 3593 9 3.0 PPA 99.6 37.2 2.7 YF128FIexD 3706 CarboLite 16/20 3.1 1.8 10849 10 4.0 PPA 99.9 37.5 2.7 YF128FIexD 3580 CarboLite 16/20 4.1 3.2 14039 11 5.0 PPA 99.9 37.2 2.7 YF128FIexD 3454 CarboLite 16/20 5.1 2.4 16987 12 6.0 PPA 50.5 37.3 1.4 YF128FIexD 1738 16/20 CarboBond Lite 6.1 1.2 9703 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Spacer 37.1 37.2 2327 2482 2233 2 3"Ball 37.2 37.3 2656 2794 2449 3 Slow 4 seat 31.0 37.2 2632 2823 2181 4 PAD 31.4 37.4 2882 3069 2715 5 Scour 37.5 38.0 3049 3119 3009 6 PAD 37.3 38.1 2976 3056 2906 7 1.0 PPA 37.7 38.2 2995 3056 2949 8 2.0 PPA 37.6 37.7 2904 2969 2822 9 3.0 PPA 37.2 37.6 2714 ,2852 2604 10 4.0 PPA 37.5 37.8 2644 2684 2587 11 5.0 PPA 37.2 37.4 2606 2658 2531 12 6.0 PPA 37.3 37.4 2619 2659 2555 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 884.2 24.2 34639 57876 Average Treating Pressure: 2776 psi Maximum Treating Pressure: 3119 psi Minimum Treating Pressure: 2181 psi Average Injection Rate: 36.7 bbl/min Maximum Injection Rate: 38.2 bbl/min Average Horsepower: 2495.7 hhp Maximum Horsepower: 2881.6 hhp Maximum Prop Concentration: 6.1 PPA 0 • Schlumberger Client:BP Exploration Alaska Well S-24 Formation.Kuparuk C District:Prudhoe Bay Country.United States Section 4: Stage 4, Propped Frac: As Measured Pump Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Step Step Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass # Name Conc (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (Ib) 1 Spacer 21.1 37 0.6 YF128FIexD 886 6 0 0 2 3.125"ball 27 37.8 3.3 YF128FIexD 1134 0 0 0 3 Displace 96 37.8 3.3 WF128 4032 0 0 0 Slow 4 4 43 24.8 35.8 WF128 1831 0 0 0 seat 5 PAD 39.1 22.1 2.5 YF128FIexD 1622 0 0 C 6 PAD 150 37.2 4 YF128FIexD 6293 CarboLite 16/20 0.1 0 0 7 Scour 50.1 39.7 1.3 YF128FIexD 2066 CarboLite 16/20 0.5 0.2 1032 8 PAD 150 39.8 3.8 YF128FIexD 6292 CarboLite 16/20 0.5 0 0 9 1.0 PPA 50.1 39.8 1.3 YF128FIexD 2030 CarboLite 16/20 1 0.4 1663 10 2.0 PPA 50 39.8 1.3 YF128FIexD 1944 CarboLite 16/20 2.1 0.1 3562 11 3.0 PPA 49.8 39.8 1.3 YF128FIexD 1859 CarboLite 16/20 3.1 2.8 5272 12 4.0 PPA 50.5 39.8 1.3 YF128FIexD 1817 CarboLite 16/20 4.1 3 6957 13 5.0 PPA 99.9 39.8 2.5 YF128FIexD 3452 CarboLite 16/20 5.2 0.2 17010 14 6.0 PPA 99.7 39.8 2.5 YF128FIexD 3333 CarboLite 16/20 6.1 3.5 19519 15 7.0 PPA 73.3 39.8 1.8 YF128FIexD 2543 16/20 CarboBond Lite 8.2 4.9 10810 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Spacer 37.0 37.4 2635 2691 2600 2 3.125'ball 37.8 38.0 3079 3316 2674 3 Slow 4 seat 24.8 38.0 2511 3306 2 4 PAD 22.1 30.1 2652 2923 636 5 PAD 37.2 39.3 3073 3201 2892 6 Scour 39.7 39.8 3104 3145 3037 7 PAD 39.8 39.8 3152 3223 3021 8 1.0 PPA 39.8 39.8 3158 3215 3100 9 2.0 PPA 39.8 39.8 3046 3100 2984 10 3.0 PPA 39.8 39.8 2911 2980 2838 11 4.0 PPA 39.8 39.8 2808 2840 2750 12 5.0 PPA 39.8 39.8 2777 2838 2739 13 6.0 PPA 39.8 39.9 2914 2961 2838 14 7.0 PPA 39.8 39.8 2996 3139 2939 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (lb) 1049.7 63.3 41136 65825 0 • Schlumberger Client:BP Exploration Alaska E' Well:5-24 Formation:Kuparuk C District.Prudhoe Bay Country United States Average Treating Pressure: 2973 psi Maximum Treating Pressure: 3316 psi Minimum Treating Pressure: 2 psi Average Injection Rate: 37.8 bbl/min Maximum Injection Rate: 39.9 bbl/min Average Horsepower: 2775.7 hhp Maximum Horsepower: 3142.9 hhp Maximum Prop Concentration: 8.2 PPA Section 5: Stale 4, Pro . •ed Frac: Job Messases Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. I Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 13:45:49 Start Propped Frac Automatically 2526 2896 0.0 36.8 5.9 2 13:45:49 Start Stage 4 Automatically 2526 2896 0.0 36.8 5.9 3 13:45:54 Activated Extend Stage 2629 2866 3.1 36.7 6.0 4 13:46:04 Stage at Perfs:4.0 PPA 2605 2892 9.2 37.0 0.3 5 13:46:23 Deactivated Extend Stage 2719 2849 21.0 37.7 0.0 6 13:47:06 XL ads cut 2961 2888 48.1 37.7 -0.0 7 13:47:24 Ball away 1786 slurry 3032 2869 59.3 37.6 D.0 8 13:47.54 Stopped Pumping Prop 3153 2896 78.2 37.8 0.0 9 13:48:43 Stage at Perfs:5.0 PPA 3183 2939 109.1 37.9 0.0 10 13:50:01 ,Activated Extend Stage 2420 2946 158.2 30.8 0.0 11 13:50:04 Stage at Perfs:6.0 PPA 2458 2954 159.6 27.9 0.0 12 13:50:42 Stage at Perfs:Spacer 2440 2907 173.5 20.7 0.0 13 13:51:12 Shutting down to re-load balls 1971 2870 181.2 1.6 0.0 14 14:02:50 Swab Shut 23.5 turns 1384 2750 183.2 0.0 0.0 15 14:03:30 #5 Ball Loaded 3.249" -6 2743 183.2 0.0 0.0 16 14:03:41 #6 Ball Loaded 3.374" -7 2742 183.2 0.0 0.0 17 14:05:40 #7 Ball loaded 3.498" -5 2723 183.2 0.0 0.0 18 14:11:32 Swab is open,23.5 turns 1063 2670 183.9 0.1 0.0 19 14:11:48 WH open 1053 2668 183.9 0.1 0.0 20 14:26:54 Getting ready all around 663 2565 186.6 0.2 O.C. 21 14:28:28 Deactivated Extend Stage 636 2557 187.0 0.3 O.C. 22 14:31:10 XL ads lined out 2949 2774 231.7 32.0 0.0 23 14:32:58 Stage at Perfs:3.125"ball 3131 2854 297.4 37.9 0.0 24 14:33:41 XL pH=9.5 2984 2830 324.6 37.8 0.0 25 14:34:05 Stage at Perfs:Slow 4 seat 3095 2974 339.9 38.7 0.0 26 14:34:51 Started Pumping Prop 3144 2945 369.6 37.0 0.0 27 14:35:06 Stage at Perfs:Slow 4 seat 3165 3020 379.4 40.0 0.0 28 14:35:19 Sand falling for scour 3145 2974 388.0 39.7 0.4 29 14:36:48 Stopped Pumping Prop 3002 3004 447.0 39.8 0.0 30 14:38:52 Stage at Perfs:PAD 3212 3051 529.2 39.6 0.0 31 14:40:00 Started Pumping Prop 3213 3087 574.2 39.8 0.0 32 14:40:08 Stage at Perfs:PAD 3217 3090 579.5 39.7 0.0 33 14:41 12 XL pH=9.5 3104 3027 622.0 39.7 1.0 34 14:42:05 POD gate%check:good 3014 3051 657.1 39.7 2.0 35 14:43:54 Stage at Perfs:Scour 2827 3015 729.3 39.7 3.0 36 14:45:10 Stage at Ports:PAD 2746 3018 779.7 39.9 4.0 37 14:46:10 Tank 5:8'5" 2730 3007 819.5 39.8 5.0 38 14:46:25 Stage at Perfs:1.0 PPA 2749 3007 829.5 39.7 5.0 0 • Schiumbergef Client:BP Exploration Alaska u Well:S-24 Formation:Kuparuk C District:Prudhoe Bay Country:United States Message Log Treating Annulus Message Total Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 39 14:47:41 Stage at Perfs:2.0 PPA 2871 2993 879,9 39.9 5.0 40 14:48:09 POD gate%check:good 2919 2991 898.4 39.7 6.1 41 14:48:57 Stage at Perfs:3.0 PPA 2901 2968 930.3 39.9 6.0 42 14:49:26 IPPA is going to be CarboBond 2947 2965 949.5 39.6 6.0 43 1450:02 Pressurizing ball drop van to 3800psi 2961 2949 973.3 39.8 5.8 44 14:50:07 CarboBOND falling 2941 2945 976.7 39.7 6.0 45 14:51:11 Activated Extend Stage 3005 2925 1019.1 39.8 6.1 46 14:51:27 Stage at Perfs:4.0 PPA 3012 2919 1029.7 39.9 3.7 • • Schlumberger Client:BP Exploration Alaska Well.S-24 Formation:Kuparuk C District Prudhoe Bay Country:United States Section 6: Stage 5, Propped Frac: As Measured Pump Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Step Step Name Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass it (bbl) (bbl/min) (min) (gal) PPA) (PPA) (Ib) 1 Spacer 15 39.7 0.4 YF128FIexD 630 0.1 0 0 2 3.25"Ball 114.2 39.8 2.9 WF128 4796 0.1 0 0 3 Slow 4 Seat 20.4 27.3 0.8 WF128 857 0 0 0 4 Pump-down 117.7 8.9 15.1 WF128 4943 0 0 0 5 PAD 150 36.6 4.3 YF128FIexD 6281 0 0 0 6 Scour 50.1 39.4 1.3 YF128FIexD 2069 CarboLite 16/20 0.5 0.3 1064 7 PAD 150 39.8 3.8 YF128FIexD 6283 0.5 0 389 8 1.0 PPA 50.1 39.6 1.3 YF128FIexD 2031 CarboLite 16/20 1 0.1 1665 9 2.0 PPA 50 39.2 1.3 YF128FIexD 1944 CarboLite 16/20 2 0.8 3566 10 3.0 PPA 99.6 39.2 2.5 YF128FIexD 3706 CarboLite 16/20 3.1 0.3 10837 11 4.0 PPA 99.9 39.2 2.5 YF128FIexD 3580 CarboLite 16/20 4.1 1.2 14018 12 5.0 PPA 99.9 39.6 2.5 YF128FIexD 3454 CarboLite 16/20 5.1 3.1 16994 13 6.0 PPA 99.7 39.1 2.5 YF128FIexD 3331 CarboLite 16/20 6.1 4.5 19545 14 7.0 PPA 100.6 39.1 2.6 YF128FIexD 3240 16/20 CarboBond Lite 7.2 3.6 19351 15 8.0 PPA 63.2 39.3 1.6 YF128FIexD 2145 16/20 CarboBond Lite 8.4 0 11026 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step it Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Spacer 39.7 /39.8 3216 3356 3142 2 3.25"Ball 39.8 39.8 3434 3497 3318 3 Slow 4 Seat 27.3 39.8 3298 5486 2417 4 PAD 8.9 20.6 4542 5474 0 5 PAD 6.0 9.9 2892 3681 691 6 PAD 36.6 39.8 3117 3681 2921 7 Scour 39.4 39.8 3146 3177 3127 8 PAD 39.8 40.0 3203 3261 3136 9 1.0 PPA 39.6 40.1 3213 3261 3171 10 2.0 PPA 39.2 39.5 3116 3171 3053 11 3.0 PPA 39.2 39.6 2943 3050 2876 12 4.0 PPA 39.2 39.5 2890 /2914 2867 13 5.0 PPA 39.6 40.1 2912 "2949 2892 14 6.0 PPA 39.1 39.6 2984 3037 2946 15 7.0 PPA 39.1 39.6 3119 3211 3039 16 8.0 PPA 39.3 39.6 3244 3315 3209 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 1280.4 45.4 49290 98455 • • Schiumberger Client:BP Exploration Alaska Well 5-24 Formation:Kuparuk C District.Prudhoe Bay Country.United States Average Treating Pressure: 3244 psi Maximum Treating Pressure: 5486 psi Minimum Treating Pressure: 0 psi Average Injection Rate: 36.1 bbl/min Maximum Injection Rate: 40.1 bbl/min Average Horsepower: 2777.5 hhp Maximum Horsepower: 3410.6 hhp Maximum Prop Concentration: 8.4 PPA Section 7: Sta• e 5, Pro . •ed Frac: Job Messa•es Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. 1 Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 14:51:58 Deactivated Extend Stage 3172 2919 0.7 39.7 0.1 2 14:51:58 Start Propped Frac Manually 3172 2919 0.7 39.7 0.1 3 14:51:58 Start Stage 5 Automatically 3172 2919 0.7 39.7 0.1 4 14:53:55 Stopped Pumping Prop 3430 2913 78.2 39.8 0.0 5 14:53:58 Stage at Perfs:5.0 PPA 3436 2915 80.2 39.7 0.0 6 14:56:21 Stage at Perfs:6.0 PPA 5113 3110 153.3 12.5 0.0 7 14:56:53 Activated Extend Stage 4801 2988 160.0 12.5 0.0 8 14:57:02 Stage at Perfs:7.0 PPA 4636 2898 161.8 12.5 0.0 9 14:57:27 Shutting down 4791 3003 167.0 12.5 0.C. 10 14:57:47 Ball away at 2816 total slurry 2566 2720 167.6 0.0 D.0 11 14:59:07 XL pH=9.5 2076 2663 167.6 0.0 0.0 12 15:00:57 On linear gel,bring pumps backup 5 BPM 1833 2624 167.6 0.0 0.0 13 15:04:09 slowly walking rate up 4432 2992 183.2 6.1 0.0 14 15:07:05 Bringing rate up again 4665 3012 202.7 6.6 0.0 5 15:0832 Letting pressure line out,preparing to shutdown 4723 3021 214.6 8.4 0.C. for 30 min 16 15:08:53 Shutdown 4016 2978 217.6 8.3 0.0 17 15:27:41 Preparing to surge:bleeding pressure at surface 1733 2599 217.7 0.0 0.0 18 15:27:56 Once pressure is bled off,we'll put pump in gear. 1728 2598 217.7 0.0 0.0 19 15:29:09 Pressure is bled off 17 2440 217.7 0.0 0.0 20 15:29:16 Bringing up blender discharge pressure 199 2439 217.7 0.0 0.0 21 15:30:31 Down on pumps 3454 2782 221.6 0.0 O.C. 22 15:30:38 Bleeding pressure off 3164 2741 221.6 0.0 D.0 23 15:31:38 Pressure bled off 34 2461 221.6 0.0 0.0 24 15:35:13 Closing bleeds -1 2412 221.6 0.0 0.0 25 15:35:43 Bringing up blender pressure 146 2418 221.6 0.0 0.0 26 15:36:01 Pumps in gear 575 2446 221.6 0.0 0.0 27 15:36:46 Keeping 5300psi on the line 5215 2928 227.9 8.3 0.0 28 15:39:25 Shutting down 4755 2905 250.1 8.4 0.0 29 15:40:21 Cutting blender discharge 2305 2636 250.8 0.0 0.0 30 15:40:26 Preparing to surge. 2296 2634 250.8 0.0 0.0 31 15:45:20 Pump in gear 1378 2533 250.9 3.3 0.0 32 15:4738 Shutting down,Gathering ourselves,preparing to 1292 2575 264.5 0.0 0.0 go downhole. 33 16:20:22 Deactivated Extend Stage 690 2416 264.5 0.0 0.0 34 16:21:23 Stage at Perfs:Spacer 3034 2642 275.7 21.4 0.0 35 16:22:04 Stage at Perfs:3.25"Ball 3114 2723 296.2 35.7 0.0 36 16:24:41 XL pH=9.5 3153 3021 399.1 39.7 0.0 • Schiumberger Cent,BPxploration Well,S-24 Formation,Kuparuk C District Prudhoe Bay Country:United States Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. i Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 37 16:25:00 Stage at Perfs:3.25"Ball 3173 3034 411.7 39.7 0.0 38 16:25:03 Stage at Perfs:3.25"Ball 3173 3034 413.6 39.7 0.0 39 16:25:26 Started Pumping Prop 3165 3044 428.9 39.9 0.0 40 16:28:50 Stage at Perfs:Slow 4 Seat 3218 3087 563.8 39.9 0.1 41 16:30:06 Stage at Perfs:PAD 3251 2999 614.3 39.9 0.1 42 16:31:41 POD gate%check:good 3152 2997 676.9 39.0 1.8 43 16:33:54 Stage at Perfs:PAD 2923 2975 764.0 39.1 3.0 44 16:34:51 POD gate%check:good 2874 2965 801.1 39.0 3.1 45 16:35:00 XL pH=9.4 2881 2966 806.9 39.2 3.0 46 16:35:11 Stage at Perfs:PAD 2874 2965 814.1 38.9 3.0 47 16:36:28 Stage at Perfs:Scour 2868 2961 864.2 39.1 3.9 48 16:38:59 Stage at Perfs:PAD 2889 2964 963.5 39.8 5.1 49 16:41:32 Stage at Perfs:1.0 PPA 2942 2970 1063.4 39.9 6.0 50 16:42:32 Pressurizing van up to 3,800 3031 2966 1102.9 39.2 5.5 51 16:42:43 On CarboBOND:sand falling . 3033 2962 1110.1 39.3 6.0 52 16:44:05 Stage at Perfs:2.0 PPA 3101 2946 1163.7 38.8 7.0 53 16:45:44 Activated Extend Stage 3241 2922 1228.1 39.2 7.6 54 16:46:38 Stage at Perfs:3.0 PPA 3240 2904 1263.6 39.3 3.3 i Scbiemberger FracCAT Treatment Report: S-42a Stace 1 Well :S-42a Field :Aurora Formation :Kuparuk C Well Location : County :Prudhoe Bay State :Alaska Country :United States Prepared for Client :BP Exploration Alaska Client Rep :David Wages Date Prepared :September 07,2015 Prepared by Name :Alexander Martinez Division :Schlumberger Phone :5613895006 Pressure(All Zones) Initial Wellhead Pressure(psi) 905 Initial BHP at Gauge(psi) 4,428 Calibration Surface ISIP(psi) 1,301 Calibration ISIP at Gauge(psi) 4,118 Surface Shut in Pressure(psi) 557 BH Shut in Pressure(psi) 3,572 Maximum Treating Pressure(psi) 7,746 Note:This job resulted in a screen out Treatment Totals(All Zones As Per FracCAT) Total Slurry Pumped 1,283 Total YF128FIexD Past Wellhead(bbls) 867 (Water+Adds+Proppant)(bbls) Total WF128 Past Wellhead(bbls) 270 Total Freeze Protect Past Wellhead 0 (bbls) Total Proppant Pumped(lbs.) 59,703 Total Proppant in Formation(lbs.) 33,866 Total 12%HCI Pumped(bbls) 47.7 Total 16/20 Carbolite Pumped 59,703 0 Total 16/20 CarboBond Pumped(lbs) 0 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103(gal) 50 49 M275(lbs.) 21 20 [065(gal) 51 50 J475(lbs.) 330 327 [064(gal) 85 84 J134(lbs.) 10 0 J604(gal) 79 78 M002(lbs.) 21 20 J580(lbs.) 1,771 1,489 J511 (lbs.) 93 92 Disclaimer Notice This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • • Schiumberger Client BP Exploration Alaska Well:5-42 Formation.Kuparuk C District:Prudhoe Bay Country:United States Section 1 : Sta• e 1 , Dia. nostic: As Measured Pum • Schedule As Measured Pump Schedule Ste Ste Slurry Slurry Pump Fluid MaxrProp Prop p p Volume Rate Time Fluid Name Volume Proppant Name p Conc Mass # Name Conc (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (Ib) 1 Load Hole 5.3 3.2 1.9 WF128 222 0.0 0.0 0 Acid 2 47.2 4.5 10.6 HCI 12 1938 0.0 0.0 0 Spear 3 H2O flush 5.0 5.4 0.9 WF128 209 0.0 0.0 0 4 LVT 86.6 12.4 9.1 Freezeprotect 3630 0.0 0.0 0 Calibratio 5 19.4 14.0 1.4 YF128FIexD 813 0.0 0.0 0 n Calibratio 6 100.0 20.2 5.4 YF128FIexD 4187 0.0 0.0 0 n 7 Displace 164.9 38.2 4.4 WF128 6923 0.0 0.0 0 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Load Hole 3.2 4.6 2148 4834 1142 2 Acid Spear 4.5 5.0 1408 1604 1109 3 H2O flush 5.4 5.9 1642 1731 1522 4 LVT 12.4 14.0 1992 2302 942 5 Calibration 14.0 14.0 2078 2089 2065 6 Calibration 20.2 33.1 2514 3106 2061 7 Displace 38.2 39.4 3337 3488 5 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 428.3 33.7 17921 0 Average Treating Pressure: 2577 psi Maximum Treating Pressure: 4834 psi Minimum Treating Pressure: 5 psi Average Injection Rate: 23.2 bbl/min Maximum Injection Rate: 39.4 bbl/min Average Horsepower: 1703.5 hhp Maximum Horsepower: 3362.3 hhp Maximum Prop Concentration: 0.0 PPA • • Schiumberger Client BP Exploration Alaska Well 5-42 Formation:Kuparuk C District.Prudhoe Bay Country,United States Section 2: Stase 1 , Dia• nostic: Job Messa• es Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 7:30:00 Arrived on location 0 0 0.0 0.0 0.0 2 9:45:11 LRS Pring line 0 0 0.0 0.0 0.1 3 9:52:20 Stand pipe mic check:good 0 0 0.0 0.0 0.1 4 10:35:51 Double tapping iron 0 0 0.0 0.0 0.1 5 10:35:58 Gathering for safety meeting. 0 0 0.0 0.0 0.1 6 11:29:04 Priming pumps 1 8 0.0 0.0 0.1. 7 11:58:34 Disconnecting re-circ line 258 8 0.0 0.0 0.1 8 11:58:45 Pushing water to ball drop van 257 8 0.0 0,0 0.1 9 12:09:09 Getting clear all-around 76 8 0.0 0.0 0.1 10 12:09:17 Preparing low PT 76 8 0.0 0.0 0.1 11 12:14:22 Low PT start 292 8 0.0 0.0 0.1 12 12:18:11 Low PT good 1870 8 0.0 1.3 0.1 13 12:18:16 Coming up to high PT 1869 8 0.0 0.0 0.1 14 12:21:08 All clear,coming up to high PT 5292 8 0.0 0.0 0.1 15 12:22:20 Bleeding pressure,removing popoff in cmnt van 4545 8 0.0 0.0 0.0 16 12:22:48 Ball dropper van pressure bled off 4534 8 0.0 0.0 0.1 17 12:24:06 Pressure equalized,bringing up high PT 1592 8 0.0 0.0 0.1 18 12:25:39 High PT start 7608 8 0.0 0.0 0.1 19 12:31:36 High PT good 7462 8 0.0 0.0 0.1 20 12:31:48 Preparing for check valve test 7459 8 0.0 0.0 0.1 21 12:32:45 Check valve test good 335 8 0.0 0.0 0.1 22 12:32:48 Bleeding pressure 401 8 0.0 0.0 0.1 23 12:33:13 Priming LAS lines 541 8 0.0 0.0 0.1 24 12:34:01 28#gel in PCM 566 8 0.0 0.0 0.1 25 12:42:48 SSV is open,2,000psi 563 8 0.0 0.0 0.1 26 12:42:58 23.5 turns on master valve:Open 562 8 0.0 0.0 0.1 27 12:43:48 WH open 905 7 0.0 0.0 0.1 28 12:44:47 LRS bringing IA to 2,000psi 893 7 0.0 0.0 0.1 29 12:48:57 Confirm IA pressure with LRS:good 1325 2791 0.0 0.0 0.1 30 12:49:10 Adjusting Popoff to-6500 1324 2790 0.0 0.0 0.1 31 12:51:13 LAS hose clogged,troubleshooting 1331 2820 0.0 0.0 0.1 32 13:00:33 LAS hose fixed,primed,ready to go. 1329 2808 0.0 0.0 0.1 33 13:01:56 Start Diagnostic Automatically 1329 2806 0.0 0.0 0.0 34 13:01:56 Start Stage 1 Automatically 1329 2806 0.0 0.0 0.1 35 13:01:56 Started Pumping 1329 2806 0.0 0.0 0.1 36 13:02:56 Activated Extend Stage 4935 3146 1.4 2.6 0.1 37 13:03:20 frac port sheared 1539 2564 2.6 3.6 0.1 38 13:03:39 Bringing on acid 1649 2576 3.7 3.6 0.1 39 13:04:02 Deactivated Extend Stage 1275 2530 5.3 3.8 0.1 40 13:14:41 Swapped to water 1520 2840 52.0 4.7 0.1 41 13:15:10 rolling frac pump 1728 2856 54.5 5.9 0.1 42 13:15:29 Flushing acid line with water 1724 2853 56.4 5.8 0.1 43 13:15:31 Swapped to LVT 1725 2851 56.5 5.8 0.1 44 13:15:50 Activated Extend Stage 1095 2781 58.0 1.5 0.1 45 13:16:28 Lost rate in ball drop van on LVT 1183 2793 59.4 2.4 0.1 46 13:16:36 Back on LVT in ball drop van 1040 2785 59.7 2.1 0.1 47 13:18:28 Shutdown in ball drop van 1144 2783 64.9 3.9 0.1. • • SchluiNberger Client:BP Exploration Alaska Well 5-42 Formation:Kuparuk C District:Prudhoe Bay Country:United States Message Log Treating Annulus Time Message Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 48 13:18:45 Walking up rate on frac pumps:15bpm 1304 2791 65.6 4.5 0.1 49 13:20:18 Waiting on liquid ads to start rolling 2099 2862 82.7 14.0 0.1 50 13:24:08 Liquid ads starting to roll 2051 2985 136.3 14.0 0.1 51 13:24:37 Deactivated Extend Stage 2071 3014 143.0 14.0 0.1 52 13:26:17 Liquids ads lined out. Begin calibration stage 2126 3051 166.4 14.0 0.1 53 13:26:54 Stage at Perfs:Load Hole 2106 3006 175.0 14.0 0.1 54 13:27:05 XL pH=9.3 2076 3008 177.6 14.1 0.1 55 13:27:16 Stage at Perfs:Acid Spear 2086 3021 180.1 14.0 0.1 56 13:30:02 Walking rate up to 40 bpm 2742 3040 222.7 23.7 0.1 57 13:30:12 Stage at Perfs:H2O flush 2758 3040 226.7 24.9 0.1 58 13:30:24 Stage at Perfs:LVT 2779 3003 231.8 26.1 0.1 59 13:31:36 LAS ads cut for linear displacement 3132 3053 268.0 34.5 0.1 60 13:32:59 Stage at Perfs:Calibration 3339 3095 318.5 38.7 0.1 61 13:33:29 Stage at Perfs:Calibration 3413 3022 338.0 39.4 0.1 62 13:35:24 Activated Extend Stage 3481 3092 413.5 39.3 0.1 63 13:35:48 Hard shutdown 1436 2961 427.3 0.7 0.1 64 13:37:44 Surface ISIP:1,301 psi 959 2888 427.3 0.0 0.1 65 13:38:05 BH ISIP:4,120psi 927 2880 427.3 0.0 0.1 66 13:57:57 2.5"Ball Loaded 14 2686 427.3 0.0 0.1 67 13:59:50 2.998"Ball Loaded 10 2680 427.3 0.0 0.1 • • Schlumberger Client BP Exploration Alaska Well:S-42 Formation,Kuparuk C District Prudhoe Bay Country:United States Section 3: Stage 1 , Propped Frac: As Measured Pump Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Step Step Volume Rate Time Fluid Name Volume Proppant Name PfOp Conc Mass # Name Conc (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (Ib) 1 WF PAD 80 38 13.4 WF128 3360 CarboLite 16/20 0 0 0 2 YF PAD 401.4 38 13.4 YF128FIexD 16859 CarboLite 16/20 0 0 9 3 1.0 PPA i 50 39 1.3 YF128FIexD 1962 CarboLite 16/20 2.6 0 3140 4 3.0 PPA 50.3 38.7 1.3 YF128FIexD 1794 CarboLite 16/20 5.4 0.7 7190 5 6.0 PPA 50.9 38.3 1.3 YF128FIexD 1653 CarboLite 16/20 7.6 0.6 11122 6 8.0 PPA 75.3 39.1 1.9 YF128FIexD 2284 CarboLite 16/20 9.7 6.2 19962 7 10.0 PPA 55.1 39.6 1.4 YF128FIexD 1611 CarboLite 16/20 10.1 0 18280 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step it Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 38.0 39.6 3212 3592 74 2 1.0 PPA 39.0 39.6 3080 3141 3015 3 3.0 PPA 38.7 38.8 2910 3009 2805 4 6.0 PPA 38.3 38.8 2642 2804 2464 5 8.0 PPA 39.1 40.0 2698 2896 2474 6 10.0 PPA 39.6 39.9 3110 3302 2900 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 763.0 20.6 29493 59703 Average Treating Pressure: 3087 psi Maximum Treating Pressure: 3592 psi Minimum Treating Pressure: 74 psi Average Injection Rate: 38.4 bbl/min Maximum Injection Rate: 40.0 bbl/min Average Horsepower: 2911.0 hhp Maximum Horsepower: 3427.9 hhp Maximum Prop Concentration: 10.1 PPA • 111111 Schlumberger Client:BP Exploration Alaska Well:5-42 Formation:Kuparuk C District Prudhoe Bay Country:United States Section 4: Stage 1 , Pro . sed Frac: Job Messages Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. I Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 14:23:08 Deactivated Extend Stage 76 2620 427.3 0.0 0.0 2 14:23:08 Start Propped Frac Manually 76 2620 427.3 0.0 0.0 3 14:23:39 First two PAD stages extended to 400bbIs 2228 2869 1.3 7.8 0.0 4 14:23:44 Going downhole 2255 2860 2.0 8.9 0.0 5 14:24:20 Stage at Perfs:Calibration 2834 2914 10.9 18.9 0.0 6 14:28:30 XL pH=9.3 3288 3049 160.0 39.5 0.0 7 14:28:54 Stage at Perfs:PAD 3223 3078 175.8 39.5 0.0 8 14:28:59 Zero on POD 3204 3081 179.1 39.6 0.0 9 14:29:08 XL delay=2mins 3191 3090 185.0 39.5 0.0 10 14:30:25 Inline densos good zero 3181 3055 235.7 39.5 0.0 11 14:30:54 Activated Extend Stage 3191 3080 254.8 39.5 0.0 12 14:32:13 Extending PAD by 80 bbls to account for LAS 3189 3030 306.8 39.5 0.0 getting rolling 13 14:35:33 Setting popoff to 6500 3149 3041 438.5 39.6 0.0 14 14:36.21 Started Pumping Prop 3143 3031 470.2 39.6 0.0 15 14:36:38 Deactivated Extend Stage 3150 3013 481.4 39.6 0.3 16 14:37:43 Gate check on POD=good 3007 3028 523.7 38.8 2.4 17 14:38:16 XL pH=9.3 2940 3032 545.0 38.8 3.4 18 14:39:55 XL pH=9.2 2663 3006 608.9 38.6 6.8 19 14:40:33 Pump 3 rate unsteady 2402 2958 632.7 37.1 7.9 20 14:41:11 Stage at Perfs:1.0 PPA 2804 3054 656.6 38.7 8.4 21 14:42:03 ball dropper van pressured up 2826 2975 691.1 39.7 9.4 22 14:42:27 Stage at Perfs:3.0 PPA 2914 2977 707.0 40.0 9.7 23 14:42:38 tank 3:8'6" 2952 2984 714.3 39.6 10.0 24 14:43:16 Activated Extend Stage 3146 2999 739.4 39.4 10.0 25 14:43:43 Stage at Perfs:6.0 PPA 3298 2985 757.1 39.0 10.2 26 14:43:51 Deactivated Extend Stage 3266 3003 762.4 39.5 9.9 • • Schlumberger Client BP Exploration Alaska Well:S-42 Formation,Kuparuk C District Prudhoe Bay Country:United States Section 5: Stage 2, Propped Frac: As Measured Pump Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Step Step Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass # Name (bbl) (bbl/min) (min) (gal) PPA) (PPA) (Ib) 1 2.5in ball 15.0 40.2 1.3 YF128FIexD 630 CarboLite 16/20 10.1 0.0 0 PAD to 2 76.4 35.7 3.3 YF128FIexD 3209 CarboLite 16/20 0.0 0.0 0 Perf Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 2.5in ball 40.2 40.7 3751 4251 3313 2 PAD to Perf 35.7 40.6 4459 6744 56 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 91.4 4.7 3839 0 Average Treating Pressure: 4057 psi Maximum Treating Pressure: 7746 psi Minimum Treating Pressure: 56 psi Average Injection Rate: 38.4 bbl/min Maximum Injection Rate: 40.7 bbl/min Average Horsepower: 3758.7 hhp Maximum Horsepower: 5395.2 hhp Maximum Prop Concentration: 10.1 PPA • • Schlumberger Client.BP Exploration Alaska Well:5-42 Formation:Kuparuk C District,Prudhoe Bay Country.United States Section 6: Sta•e 2, Pro . •ed Frac: Job Messa•es Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 14:43:52 Start Propped Frac Automatically 3302 3014 0.0 39.5 9.9 2 14:43:52 Start Stage 2 Automatically 3302 3014 0.0 39.5 9.9 3 14:43:58 Activated Extend Stage 3369 3008 3.9 39.4 9.9 4 14:44:59 Stage at Perfs:8.0 PPA 4224 3064 44.8 40.5 0.0 5 14:45:12 Deactivated Extend Stage 3917 3047 53.6 39.9 -0.0 6 14:46:14 Stopped Pumping Prop 6733 3250 88.3 0.0 0.1 7 14:47:12 Pressured out,popoff blew on surface. 6703 2838 88.3 0.0 0.0 8 14:47:31 popoff isolated 6695 2789 88.3 0.0 0.0 9 14:48:37 bleeding surface pressure 137 2866 88.3 0.0 0.0 10 14:50:53 ball away 1227 total slurry 174 2753 88.3 0.0 0.0 11 14.54:33 Rebuilding popoff 165 2676 88.3 0.0 D.0 12 14:55:27 SSV shut 161 2662 88.3 0.0 D.0 13 14:59:51 SSV pressure bled off 144 2602 88.3 0.0 0.0 14 15:00:02 master valve closed:23.5 turns 144 2600 88.3 0.0 0.0 15 15:12:02 Shutting swab valve,opening SSV and master 106 2488 88.3 0.0 0.0 valve 16 15:12:50 pressurizing popoff to 6,175psi 104 2481 88.3 0.0 O.C. 17 15:39:20 SSV open,2,300psi 72 2294 88.3 0.0 0.0 18 15:39:28 Swab closed,master open 72 2294 88.3 0.0 0.0 19 1540:37 Bringing pressure up to 500psi before we open 73 2287 88.3 0.0 0.0 master 20 15:42:05 Opening swab valve 517 2278 88.4 0.0 0.0 21 15:42:54 Swab open,WH open 618 2273 88.4 0.0 0.0 22 15:43:48 setting popoff to 6,200psi 593 2267 88.4 0.0 0.0 23 15:44:54 kicking pump in gear 1218 2268 88.4 1.0 0.0 24 15:46:01 Activated Extend Stage 3829 2880 89.9 1.4 0.0 25 15:47:18 Down on pumps 5210 3025 91.4 0.0 0.0 26 15:48:17 Coming down on blender pressure 4168, 2901 91.4 0.0 0.0 27 15:48:23 bleeding WH pressure down 4083 2890 91.4 0.0 0.0 28 15:50:50 WH pressure bled off 744 2536 91.4 0.0 0.0 29 15:51:33 Master valve closed,23.5 turns 643 1729 91.4 0.0 0.0 30 15:51:55 SSV is closed 564 1262 91.4 0.0 0.0 31 15:53:13 Swab valve is closed. 562 223 91.4 0.0 0.0 32 15:53:40 Bleeding surface pressure 560 74 91.4 0.0 0.0 33 15:54:14 Surface pressure bled off, IA bled off 58 7 91.4 0.0 0.0 34 15:54:32 Deactivated Extend Stage 55 3 91.4 0.0 0.0 • 0 Schluoiberger Client,BP Exploration Alaska Well S-42 Formation,Kuparuk C District Prudhoe Bay Country:United States Section 7: Post-Job Plots Pressure Test — Treating Pressure BP Exploration Alaska Annulus Pressure S-42 Stage 1 i BH Pressure 09-07-2015 Slurry Rate Prop Concentration BH Prop Concentration8000 PLM Vtscosty100 O 7000- iri t7 O 80 n 6000- tD to CI a 5000- if 60 3 y O. -o tv 4000- D m 3000- 40 I a _ to S 2000- 1-- ------\' 20 ;' 1000 cr 3 0 •-- - - – 0 12:14:03 12:19:53 12:25:43 12:31:33 12:37:23 Time-hh:mm:ss ©Schlumberger 1994-2012 Scirver Acid Pum pdown,Calibration&Decline — Treating Pressure BP Exploration Alaska - Annulus Pressure 0942 -2 Stage -201 1 0e — BH Pressure — Slurry Rate 9000 A — PropConcentrati•n 40 - 1 — BH Prop Concentration -Oa 8000 — PCM Viscosity n O m 7000 t7 30 2 o- 6000 Begin alibration rtil Acid Di placement O O 5000 ii PA =.1111111111P116"4111111 D 20 In 4000 xian m d 3000MEI Aillim IIIIIMIIAIIIIIIIIIIWIIIIWM 13 2000_ ff 10 3 1000 fII1 0ili 0 3 12:51:26 13:12:16 13:33:06 13:53:56 14:14:46 Time-hh:mm:ss On acid Water and LVT flush ©Schlumberger 1994-2012 Scl*unkerger • • Schlumberger Cliont.BPExploration Alaska Well,S-42 Formation,Kuparuk C District:Prudhoe Bay Country:United States Stage 1 Main Treatment Treating Pressure BP Exploration Alaska °--- Annulus Pressure S-42 Stage 1 09-07-2015 — BH Pressure Slurry Rate 10000 " — Prop Concentration ' • 50 9000- — BH Prop Concentration PCM Viscosity 8000 I 7000 �' 6000 30 4 5000 11.---s—'" 1 400020 i 3000 1111111"1111-1W M 1 2000• alli 10 1000 I 0 14:20:35 14:45:35 15:10:35 15:35:35 0 16:00:35 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger Stage 1 — Treating Pressure BP Exploration Alaska — Annulus Pressure 542 Stage 1 09-07-2015 — BH Pressure — Slurry Rate 10000 — Prop Concentration50 9000- -- BH Prop Concentration — PCM Viscosity 8000 --.ti 40 kic 7000- ' 6000 ./1 30 g 5000- �--:_, 4000 J ! • 0 Schlumberger Client:BP Exploration Alaska Well:S-42 Formation:Kuparuk C District:Prudhoe Bay Country:United States POD Additives Acid Pumpdown&Calibration BP Exploration Alaska S-42 Stage 1 09-07-2015 40 - 4 r 20 — Shirty Rate '0— Clean Fluid — J511 Rate D O — Prop Con a 0 — J604 Rate m 30' — U028 Rate 3 m 15 o E — J475 1' m o a — Road Gate% CO .0 — Deck Gate% 4\r"''" 3 A a Q20 2 10 c I C) 3 o a " 10, r •1 v •5va D 3 "0m -110• 1 0 y 0 13:01:02 13:11:27 13:21:52 13:32:17 13:42:42 Time-hh:mm:ss ©Schlumberaer 1994-2012 Schlumberger POD Additives Stage 1 BP Exploration Alaska S-42 Stage 1 09-07-2015 50 20 r 90 a — SlurryRate 18 80 O -- Clean Fluid a O — J511 40 — Prop Con .16 a 70 v _ — J604 m — J475 14 0 60 a 30' — Road Gate% 12 -a 4. — Deck Gate% 3 •50 v up _ (t 10 v n < r 40 o �l 20' • � .8 Ts r) n i J o •30 N '6 m a 10. - '4 D 20 ii al 2 •10 v , i r M 1 fl -0 14:22:30 14:30:50 14:39:10 14:47:30 14:55:50 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger Note J475 was only run on one side of the blender at concentrations of 12ppt and 16ppt. Exactly double of what the schedule called for. • 0 Schlumberger Client:BP Exploration Alaska Well:S-42 Formation:Kuparuk C District:Prudhoe Bay Country:United States PCM Additives Stage 1 Main Treatment BP Exploration Alaska — SlurryRate Clen Fluid Rate 09-07-2015 e 1 — PCM Viscosity — J580 Conc60 14 ----j- F103 — L065 — L064 I •50 12 40• /----'syr - f • 11J�/ wl 40 N •10 ofr— N. 0 c E.n -c" `,0. a :_t, 8 >a Q •30 0 0 o' 0 •6 �i i0 v D n — 20 4 m 10• , v _......_v_i 10 •2 X14 • 0- ,- •. 0 0 14.17:43 14:26:03 14:34:23 14:42:43 14:51:03 Time-hh:mm:ss ©Scldumberger 1994-2012 Schlumberger PCM Additives Acid Pumpdown&Calibration BP Exploration Alaska — SlurryRate -• CleFluid Rate 09-0 2015 1 — PCM Viscosity r0 — J580 Conc 60 25 —' F103 — L065 — L064 L0• •50 •20 _< r c 40 N a n c n E :•0• •73 •15 D n w o H -30 u'w o 0 < 0 �i �0 o11111111 = •10 v D 0 -20 2 CU 10• •5 •10 0 r 0 0 12:57:12 13:07:37 13:18:02 13:28:27 13:38:52 Time-hh:mm:ss Schlumberger ©Schlumberger 1994-2012 • 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable _ bdirect inspection of the file. _1-5 - 0.55 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: olor Items: ❑ Maps: payscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Mari, Date: ii/ I1 !15-r /s/ ri1F Project Proofing BY: 44:155 Date: 1 i ' ///5-4' /s/ rii I° Scanning Preparation _5 x 30 = / 50 + V =TOTAL PAGES 1 5 (Count does not include cover sheet) 04 BY: Maria Date: ! 1 17 1/15' lsl Production Scanning (� Stage 1 Page Count from Scanned File: 15 "1 (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: tial Date: 11 f/? fis /s/ VVVp t Stage I If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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N d 3 In CO C o L G N 0 = I o Jr E 1 M Q N Eto O VI 0. r CZ Z _ Zco c� I7 G O N m m 'p o a > w v/ I f• 0 p Q ao a OI z o E o E U Z a> ► I . 1 co in > m 0 E > co N N w O co O h C.,1 .2 :. c U a d to U r V £ Q O E E a 2° C.) 1 3 PBU S-42A/PTD # 215-055 • Page 1 of 1 PBU S-42A / PTD # 215-055 Lastufka, Joseph N [Joseph.Lastufka©bp.com] Sent:Tuesday, September 29, 2015 3:50 PM To: AOGCC Reporting (DOA sponsored) Hello, Please reference the following well: Well Name: PBU S-42A RECEIVED Permit#: 215-055 SEP 2 9 2015 API #: 50-029-22662-01-00 AOGCC Date of Test: 9/21/15 Type of Test: IPT (Initial Production Test) Choke Size: 176 Choke Unit: 64ths Production Method: Gas Lift Duration (Hours Tested): 4 Top Reference (Top Perf MD): 8533' Bottom Reference (Bottom Perf MD): 10896' Tubing Flowing (Pressure): 0 Casing Pressure: 1900 Total Test (Rate f/0, W, G): 733 /91 /634 24-Hour Rate (0, W, G): 4398 /546/ 3804 Gravity (Oil, API): Not Available GOR (Gas-Oil Ratio): 865 This well began Production on Method of Operations on this date: 9/20/2015 https://webmaila.alaska.gov/owa/?ae=Item&t=IPM.Note&id=RgAAAABKLne2zgP4So... 10/12/2015 • 215055 • 2 6098 Schlumberger AUG 1 3 2O1f: Transmittal#: 12AUG15-SPO1 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery %it'yr2m$ ACV' K.BENDER Customer: BP Exploration Alaska Inc Dispatched To: Makana Bender Well No: S-42A Date Dispatched: 12-Aug-15 APIN: 50-029-22662-01-00 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Delivered To: AOGCC Makana Bender 10 Total Contents on CD N/A Color Log Prints: 8 VISION*Services 2"MD MAD Pass x x VISION*Services _ 2"MD VISION*Services 2'TVDSS x x VISION*Services 5'MD MAD Pass x x VISION*Services 5'MD Quadrant Density MAD Pass x x VISION*Services 5"MD Quadrant Density x x VISION*Services 5'MD VISION*Services 5'TVDSS x x Digital Data N/A Contents on CD x Survey 1 Contents on CD ASP Final Survey x x EOW CD 1 Contents on CD Graphics:PDF x Data:DLIS/ASCII x Survey:PDF,XLS x Please sign and email a copy to: Please sign and email a copy to: AlaskaPTSPrintCenterslb.com qancpdcbp.com Alaska PTS Print Center ATTN:Merion Kendall Received By: III S 1 O 0 tw Ge j p 0 0 0 0 C C V O p y T n p [ 3 a r 2g22 °, a33 as=R ;7'11 5 m m T p e c a D "a 'o - ao . m IDE n O O w m^o O v m- - 41 8 m g a m p m O m io2Zo,p 0 m �m 2 A 3 X m o --.1 m y yC N N N N N W N N N+ + ++++ +++ a O N U W V V V + e W J W U_N W W W A y V W U W A0 S y, W W V+ O0i 0 W Oo 0 .... 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A AAA W N N N O ONO N-.low. j+ m A co J A N J N 2 v ANN J A+2 T A T A N J A N 2 J A N 2 J U N O w T Ap W+0 2 tG J T U A +J A O T N J N T W-.MONO N m 0 W 2 W w Wp J N w A 0 N N T+T N V W w U iN W W W N 0 2++ c T+T w +O O J V U+2 V J(N)1 N A A w 2 2T N m rn N 2 2 2 0 N�w w N 0 2 0 0 0 22822 O T T rn J N W 22'W2 A T W N A U+W m A W 2 A A A A+O b a t � w W J W w T O R O w w N 0 + t0 O O V A 222'82 0 2 2 8'8222 w N 2 T 01 T O N W 0+W W rn W ,,..N O U 411 111 , .. o 22 a 3 9m mm N y 3 0 N r i2 n b_ j , O N . w EI+ 82998 0 0 0 0 0 0 O y j, NNO aI °Mg2 ON 8 2 1 tQ 1 O�,p Nm Om+N m W W rP7cs! 8 8 m w U W 00,A N N W O i titi`.vC1VCV STATE OF ALASKA SKA OIL AND GAS CONSERVATION COMMIS. JUL 2 3 2015 WELL AlltPLETION OR RECOMPLETION REPO ND LOG la. Well Status: Oil 0 ' Gas 0 SPLUG 0 Other ❑ Abandoned 0 Suspended CI1 b.Well C'la1Ay °n GCC 20AAC 25.105 20AAC 25.110 • Development 0Exploratory ❑ GINJ 0 WINJ 0 WAG ❑ WDSPL 0 No.of Completions: One • Service ❑ Stratigraphic Test 0 2. Operator Name: 6. D e Comp Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc •7/9/2015 215-055 ^ 3. Address: 7. Date Spudded: 15 API Number: P.O.Box 196612 Anchorage,AK 99519-6612 •6/21/2015 50-029-22662-01-00• 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: '7/3/2015 _ PBU S-42A • Surface: 4181'FSL,4503'FEL,Sec.35,T12N,R12E,UM • 17. Field/Pool(s): 9. KB(ft above MSL): 82.68' • Top of Productive Interval: 866'FSL,2927'FEL,Sec.26,T12N,R12E,UM GL(ft above MSL): 37.1' • PRUDHOE BAY,AURORA OIL• Total Depth: 1626'FSL,241'FEL,Sec.27,T12N,R12E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: • 11121'/6714' ' ADL 028257&028258 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 618930• y- 5980384 ' Zone - ASP 4 • 11250'/6714'. TPI: x- 620472 y- 5982374 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 617865 •y- 5983093 • Zone - ASP 4 None 1900'(Approx.) • 5. Directional Survey: Yes 0 (attached) No 0 13. Water Depth.if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) .3013'/3012' 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray.caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD/GR/RES,MWD/GR/RES/NEU/DEN 23. CASING,LINER AND CEMENTING RECORD CASING Wi.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H40 47' 127' 47' 127' 30" 260 sx Arctic Set(Approx.) 9-5/8" 40# L-80 47' 3013' 47' 3012' 12-1/4" 850 sx CS III,300 sx Class'G',300 sx CS II 7" 26# L-80 45' 8480' 45' 6770' 8-1/2" 320 sx LiteCrete,92 sx Class'G' 4-1/2" 13.5# 13crao 8319' 11248' 6678' 6714' 6-1/8" Uncemented Sliding Sleeves w/Swell Packers 24. Open to production or injection'? Yes 0 No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom:Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2", 12.6#, 13Cr85 8328' 8202'/6604' 4-1/2"Sliding Sleeves w/Swell Packers 8533' 6796' • 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 8649' 6837' 8981' 6823' _ Was hydraulic fracturing used during completion? Yes 0 No 0 9389' 6744' ido%rtf' Per 20 AAC 25.283(i)(2)attach electronic and printed 9837' 6728' nformation 10475' 6744' 1 iii �j DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10896' 6721' i� It "f b 250' Freeze Protect w/8.5 Bbls Diesel ' SIA. I 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ,..+ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate �.• - -----_.-..----- ----.-__.---------- Form 10-407 Revised 5/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only 1/7-1 x/81 i5' ,6, 94/7------ RBDM 01 2015 , ,d_..? `a,ism G 28. CORE DATA • Conventional Core(s) Yes 0 No ❑ • Sidewall Cores Yes 0 No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No IRI Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach separate sheets to this form,if needed,and submit detailed test information per 20 Ugnu • 3616' 3596' MC 25.071. Schrader Bluff NA • 6190' 5037' Schrader Bluff NB 6210' 5050' Schrader Bluff NC • 6237' 5068' Schrader Bluff OA• 6340' 5138' Schrader Bluff OBA. 6390' 5173' Schrader Bluff OBD 6567' 5304' Schrader Bluff OBF 6677' 5390' Schrader Bluff OBF Base 6724' 5429' Coleville Mudstone • 7843' 6347' HRZ ' 8394' 6722' Kalubik • 8455' 6757' Kuparuk C4 • 8468' 6764' Kuparuk C2B 8482' 6771' KUPARUK C2A 8493' 6777' Kuparuk C1C 8535' 6797' LCU • 8571' 6812' Kuparuk A6 • 8611' 6826' Kuparuk A5 • 8634' 6833' Kuparuk A4 • 8712' 6848' Kuparuk A5(Invert) 8980' 6823' Kuparuk A6 9008' 6814' LCU 9070' 6792' Kuparuk CIC 9157' 6769' Kuparuk C2A 9252' 6754' Formation at total depth: Kuparuk C2A(From Base) 9252' 6754' 31. List of Attachments: Summary of Daily Drilling Reports,LOT/FIT Summary,Wellbore Schematic,Survey,Cement Report Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Rose,John G Email: John.G.Rose@bp.com Printed Name: Joe Lastufka Title: Drilling Technologist Signature: ne: +1907-564-4091 Date: f1•/2�/�5 INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 MC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 MC 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 MC 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 induding,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only 1LF QW4,,,6"6500 PSI VVEi • S-42A LHEAD= FMCSATES: WELL ANGLE>70°(§ -8600'- ACTUATOR= BAKER C MAX SAFE. 12°@ 8746' -'CHROME TBG 8 LNR"' OKB ELEV= 71.79' I I BF.ELEV= 37.1' KOP= 3013 20"COND, - 80' Max Angle= 111' 9030' 215# [ 1989' -.4-1/2"I LS X Imo,D=3.813" Datum MD= 8505' p= • I I Cetum TVD= 6700'SS 9-5/8"BKR WHIPSTOCK(06/20/15) - 3013' 9-5/8"CGS,40#,L-80 BTRS,0=8.835' - -3013' MLLOUT WNDOW(5-42A) 3013'-3030' 9-5/8'BKR CEP(06/20/15) .1- 3035' Minimum ID = 3.813" @ 1989' GAS LFTI44M8S BO 4-112" HES X NIPPLE \ ST do TVD DEV TYPE VLV LATCH RT DATE 4 3718 3688 27 KG84-5 DCK-2 BE( 0 07/07/15 3 6280 5097 47 KG84-5 DMI BK 0 07/07/15 TOP OF CEMENT(06/28/15) -I --4804' 2 7562 6121 36 KG1345 DAY BK 0 07/07/15 1 8057 6507 46 KGB4-5 OMY BK 0 07/07/15 54 %, I ,' mt 8136' -4-1/2'SGM-PDPG-CA SNGLECROP 1I I4 SA PPHRE GAUGED=3.864" 71, ' , 8171' J-'4-1/2-HES X NP,D=3.813" - _, '-1to 8202' -7"X 4-1/2"HES TNT R(R,D=3.856' I e Pb { 8238' j-4-1/2-I$C3 X NP,D=3.813" %, ,; ' ' le 8311' i---4-1/2'I LC a X NP,D=3.813" , ce if, F--.. 8319' 7"X 5"BKR HRD-E ZXP LTP TOP OF 4-1/2'LNR -I 8319' .r w/TE6K,0=4.380" 4-12'TBG, 12.6#, 13CR-85 VAM TOP, - 8328' v'A, '� �A 8328' -4-1/2'WLEG,D=3.958" J .0152 bpf,0=3.958" rie 8343' -7"X 5"BKR DG FLEX LOCK HGR,D=4.340" J 7'CSG,26#,L-80 VA TOP HC, - 8480' 8353' I-5'X 4 1/2'XO,D=3.89' .0383 bpf, D=6.276' rI.4 0:14 SCHLUM FRAC PORTS I$SWELL PACKH7.S .1.,1111 k_. NO DEPTH SEAT SZ. ACTUAL SIZE 0/C DATE ND SIZE TOP DEPTH MND 7 8533 3.375" 5.630' C 07/07/15 7 4-1/2" 8603 3.9T .-_Ill.1. 6 8649 325" 5.630' C 07/07/15 6 4-1/2' 8739 3.97 5 8981 3.125" 5.630' C 07/07/15 5 41/2' 9041 3.92" ._.fill '= 4 9389 3.00' 5.630' C 07/07/15 4 4-1/2' 9592 3.97 1111 3 9837 2.875" 5.630" C 07/07/15 3 41/2' 9993 3.9T 2 10475 2.375" 5.630' C 07/07/15 2 4-1,7 10227 3.92' BMA 1 10896 • 5.630" C 07/07/15 1 4-1/2' 10663 3.97 DH-I C PORT,I)=3.75" .1.11111 ._, ._, 10896' -4-12'HY D-ACtUATED FRAC VALVE,D=3.75' ' PBTD - 11121' 11099' -I4-12"BKR SHFT TOOL V ERF1CATION SUB,0=3.92' 4-1/2'LNR, 13.5#,13CR-80 HYD521, - 11131' 11121' -I4-12"BKR ISOLATION VALVE .0152 bpf,D=3.958" ►l 0;'4'''S•••• 11131' H4-1n"X 3-1/2'XO,0=2.96" 4-1/2"LNR, 13,5#,13CR-80 HYD 521, H 11248' . _ ± 11140' H3-12'ANCHOR PKR D=2.992" .0152 bpf,D=3.958' 11172' -3-12"X 4-12"XO,D=2.992' DATE REV BY COM.UITS DATE REV BY COMMENTS PRU3FtDEBAY UNIT 04129/96 ORIG HORTZ COMPLETION VVELL: S-42A 07/09/15 P-273 SIDETRACK(S-42A) PNMT No:`2150550 07/10/15 JM3 DRLG HO CORRECTIONS AR No: 50-029-22662-01 07/15/15 JR/JM) MAL ODE AI4APPROVAL SEC 35,T12N,R12E 4181'FSL&4503'FE_ BP Exploration(Alaska) • . �. BP AMERICA ",,;,,,,-';''',4;';' „ i , T/ FIT ,, �„ , . LO Summary i.: f,,,i,. sf f ''.l , Well Name: S-42A ,,.. %/ Surface Leak Off r% Test ;,Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP) (psi) (ppg) 06/20/15 LOT 3,018.63 3,017.63 9.30 850.00 2,308.53 14.72 07/01/15 FIT 8,480.00 6,771.00 10.40 669.00 4,327.11 12.30 Page 1 of 1 • • - ; �: - Page1of34 North America ALASKA BP � Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) j Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 I Spud Date/Time:4/4/1996 12:00:00AM Rig Release 7/9/2015 Rig Contractor:PARKER DRILLING CO. I UWI:500292266200 Active datum:S-42A actual tt82.68usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/14/2015 00:00 - 02:30 1 2.50 RIGD P 1 PRE **RELEASE FROM RIG MAINTENANCE AT 06-14-2015 AT 00:00** PREP FLOOR FOR RIG MOVE -PJSM I-RIG DOWN FLOOR -PERFORM DERRICK INSPECTION -REMOVE ROOF TOP WALKWAYS -POWER WASH INSIDE DERRICK WALLS SKID CATTLE SHOOT 02:30 - 04:30 2.00 RIGD P PRE LOWER DERRICK -PJSM -SKID RIG FLOOR -LAY DERRICK DOWN ON HEADACHE RACK, 377K **SET DUMMY WELLHOUSE AT S-PAD** 04:30 - 08:00 3.50 1 RIGD P PRE SEPARATE MODULES AND STAGE AT CC2A PAD ENTRANCE ' REMOVE ROOF TOP TRANSITION PLATES -UNHOOK UM AND DM ELECTRICAL CABLES } I-START DM GENSET 08:00 - 12:00 4.00 MOB P PRE ,MOVE MODULES FROM CC2A TO N-PAD 'ACCESS ROAD -MOVE ALL THREE MODULES TOGETHER 12:00 - 19:00 7.00 MOB � P PRE MOVE MODULES FROM N-PAD ACCESS ROAD TO S-PAD -MOVE ALL THREE MODULES TOGETHER 19:00 - 22:00 3.00 MOB -- P PRE SPOT OVER S-42A MATE MODULES TOGETHER I-SPOT DRILL MOD OVER S-42A -MATE MUD MOD WITH DRILL MOD UTILITY MOD WITH DRILL MOD I 22:00 - 00:00 2.00 MOB P PRE RIG UP i -RIG UP ELECTRICALAND UTILITY INTERCONNECTS -CONNECT STEAM,ELECTRICAL PLUG i BOARD,ROOF AND FLOOR PANELS 6/15/2015 00:00 02:30 2.50 MOB P PRE RAISE DERRICK AND SKID RIG FLOOR -PJSM RAISE DERRICK,LIFT OFF HEADACHE AT 520K,MAX PULL 526K -SKID RIG FLOOR -RAISE PIPE CAT I -SKID CATTLE SHOOT I-INSTALL MANRIDER WINCHES -INSTALL TORQUE TUBE PIN T 02:30 - 03:30 1.00 MOB P PRE BRIDLE DOWN I I-BRIDLE DOWN AND SECURE BRIDLE LINES 1 **SIMOPS** -SPOT FLOWBACK TANK -RIG UP HARDLINES AND CHOKE SKID Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP • Page 2 of 34 ',,, ,* 2,- `rr' w '` r,., /:/,.„ ' moi' . vg Operation Summary Report Common Well Name:S-42 AFE No Event Type RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site.PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12'00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03 30 - 09:00 5.50 1 MOB P PRE CONTINUE RIG UP HANG RIG TONGS -INSTALL MUD,CEMENT,AND BLEEDER LINES TO RIG FLOOR -MAKE UP FLOW AND FILL LINES -SPOT CUTTINGS TANK **ACCEPT RIG AT 09:00 ON 06/15/2015 09:00 - 12:00 3.00 RIGU P PRE RIG UP DSM LUBRICATOR -PJSM WITH DSM AND RIG CREW -RIG UP PER LUBRICATOR PER DSM -PRESSURE TEST LUBRICATOR TO 250 PSI 1 LOW AND 3500 PSI HIGH FOR 5 MIN EACH 12:00 - 13:00 1.00 DHB P DECOMP PULL BACK PRESSURE VALVE I-PULL BACK PRESSURE VALVE PER DSM RIG DOWN LUBRICATOR 13:00 - 15:30 2.50 WHSUR P DECOMP ;CIRCULATE OUT FREEZE PROTECT -PJSM PRIOR TO CIRCULATION 1-CIRCULATE DOWN TUBING AND UP IA ' -PUMP INITIAL 10 BBLS TO TIGER TANK -PUMP 128 BBLS TO THE PITS 1-PUMP 15 BBLS TO TIGER TANK -MONITOR WELL FOR 10 MINUTES:WELL ;STATIC -BLOW DOWN AND RIG DOWN LINES 15:30 - 18.00 2.50 DHB P DECOMP INSTALL TWO WAY CHECK -PJSM WITH DSM AND RIG CREW -RIG UP LUBRICATOR PER DSM j -PRESSURE TEST LUBRICATOR TO 250 PSI LOW,3500 PSI HIGH FOR 5 MIN EACH -PRESSURE TEST TWO WAY CHECK TO 250 PSI LOW,3500 PSI HIGH FOR 5 MIN EACH FROM ABOVE AND BELOW -BLEED OFF PRESSURE AND RIG DOWN LUBRICATOR 18:00 - 19:00 1.00 DHB P j DECOMP I HOLD RIG EVAC DRILL WITH JAMES HUNDLEY CREW -AAR WITH RIG CREW 19:00 - 23.00 4.00 WHSUR P DECOMP NIPPLE DOWN DRY HOLE TREE AND ADAPTOR FLANGE -PJSM WITH FMC AND RIG CREW -ATTEMPT TO PULL TREE WITH 5K TREE i CRANE,NO SUCCESS -ATTEMPT TO PULL TREE WITH 10K FLOOR TUGGERS,NO SUCCESS 1 -RIG UP TO PULL TREE WITH TOP DRIVE, PULL 15K,NO SUCCESS -HEAT AND STEAM WELLHEAD ATTEMPT TO PULL TREE WITH 15K FROM 1 TOP DRIVE.NO SUCCESS ,-RIG UP PORTA-POWERS ON TREE PULL 15K WITH TOP DRIVE TO PULL TREE , -LAYDOWN TREE 1 -CLEAN RING GROOVE AND MAKE UP CROSS OVER TO HANGER -8 TURNS TO MAKE UP 23:00 - 00:00 1.00 BOPSUR P 1 DECOMP NIPPLE UP HIGH PRESSURE RISER -PJSM WITH RIG CREW -MAKE UP TO WELLHEAD AND TORQUE BOLTS Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP 0 Page 3 of 34 Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site.PB S Pad 1 Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual t82.68usft(above Mean Sea Level) Date From-To Hrs Task 1 Code 1 NPT NPT Depth Phase Description of Operations I (hr) 1 (usft) 6/16/2015 00:00 - 03:00 3.00 BOPSUR P DECOMP CONTINUE NIPPLE UP HIGH PRESSURE [RISER 1 -PJSM WITH RIG CREW I 1 -ADD SPACER SPOOL TO RISER -NIPPLE UP TO TUBING SPOOL 03:00 - 06:00 3.00 BOPSUR P DECOMP NIPPLE UP BOP -PJSM WITH RIG CREW 1 I INSTALL API RING ONTO HIGH PRESSURE I RISER -BREAK BOP FROM STUMP -POSITION AND LOWER BOP ONTO HIGH PRESSURE RISER I-TORQUE CONNECTIONS BETWEEN RAMS AND MUD CROSS 06:00 - 09:00 3.00 BOPSUR P DECOMP CHANGE OUT ANNULAR API RING -BREAK ANNULAR FROM BOP STACK -REPLACE 5 STUDS j 1 -INSTALL NEW API RING AND LOWER ANNULAR BACK ONTO STACK -INSTALL AND TORQUE CONNECTION BETWEEN ANNULAR AND DOUBLE GATE 09:00 - 10:00 1.00 BOPSUR P DECOMP ,NIPPLE UP LOW PRESSURE EQUIPMENT ' ,-N/U FLOW NIPPLE TO FLOW BOX INFLATE AIR BOOT -RIG UP FLOW AND FILL LINES 10.00 - 12:00 2.00 BOPSUR P i DECOMP 1 PRESSURE TEST BOP 11-TEST BOP ACCORDING TO AOGCC,BP AND I I PARKER REQUIREMENTS 1 1 -TEST BOP TO 250 PSI LOW AND 3500 PSI 1 HIGH FOR 5 MINUTES EACH 1 ! -TEST WITH 4",4-1/2",AND 7"TEST JOINTS 1-ALL TESTS CHARTED,SEE ATTACHED -TEST WITNESS WAIVED BYAOGCC REP JEFF JONES -BOP CONFIGURATION FROM TOP TO BOTTOM:ANNULAR PREVENTER,7"CASING RAMS,BLIND SHEAR RAMS,MUD CROSS, . 2-7/8"X 5-1/2"VBRS 12:00 - 13:30 1.50 BOPSUR N SFAL -1.37 I DECOMP CHANGE OUT DOOR SEAL ON LOWER RAMS -POOH WITH TEST JOINT I-DE-ENERGIZE ACCUMULATOR I 1 1-C/O SEAL , 1-RE-ENERGIZE ACCUMULATOR 13 30 - 14:30 1.00 1 BOPSUR N SFAL -1.37 DECOMP I RIG UP TEST EQUIPMENT 1 -FILL WITH TEST FLUID,PURGE SYSTEM OF AIR -RIH WITH TEST JOINT 14 30 20:00 5.50 BOPSUR P DECOMP PRESSURE TEST BOP -TEST BOP ACCORDING TO AOGCC,BP AND PARKER REQUIREMENTS -TEST BOP TO 250 PSI LOW AND 3500 PSI 1 HIGH FOR 5 MINUTES EACH 1 1-TEST WITH 4",4-1/2",AND 7"TEST JOINTS 1-ALL TESTS CHARTED,SEE ATTACHED -TEST WITNESS WAIVED BYAOGCC REP JEFF JONES I-BOP CONFIGURATION FROM TOP TO BOTTOM:ANNULAR PREVENTER,7"CASING RAMS,BLIND SHEAR RAMS,MUD CROSS, 2-7/8"X 5"VBRS Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP • Page 4 of 34 Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:'PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To ! Hrs i Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 20:30 I 0.50 BOPSUR P DECOMP RIG DOWN BOP TEST EQUIPMENT � ! -BLOW DOWN TEST EQUIPMENT ' i-PULL TEST JOINT AND TEST PLUG 20:30 - 23:30 3.00 BOPSUR P ! DECOMP RIG UP DUTCH RISER SYSTEM I-P/U AND R/U LUBRICATOR -PRESSURE TEST LUBRICATOR,250 PSI ' LOW/3500 PSI HIGH FOR 5 MIN EACH 1 i 1-PULL BPV AS PER DSM -R/D LUBRICATOR AND DUTCH RISER SYSTEM 23:30 - 00:00 0.50 BOPSUR N WSEQ -1.37 DECOMP COMMISSION AMPHION SYSTEM AS PER NOV REP 1.50 "MAINTENANCE AFE** !COMMISSION AMPHI'ON AS PER NOV REP 6/17/2015 010 04:00 PULL N WSEQ -1.37 DECOMP '**MAINTENANCE AFE" 30 2.50 PULL P DECOMP PULL FMC TUBING HANGER I -RIG UP 4-1/2"HANDLING EQUIPMENT STAGE CONTROL LINE SPOOLER ON RIG 1 FLOOR I-DRAIN STACK i-RUN IN HOLE AND ENGAGE LANDING JOINT 1 IN NSCT TUBING HANGER WITH 8 TURNS -FMC BACK OUT LOCK DOWN SCREWS,4.75" .OUT,3.75"IN ' PULL HANGER OFF SEAT AT 85K LBS I INCLUDING 35K TOP DRIVE) 04:00 - 05:30 1.50 PULL P T DECOMP CIRCULATE 2 X BOTTOMS UP -PULL LANDING JOINT AND HANGER TO RIG FLOOR -CIRCULATE 9.5 PPG BRINE -PUMP AT 338 GPM,430 PSI -MONITOR WELL FOR 10 MIN PRIOR TO PULLING HANGER TO FLOOR:WELL IS STATIC -LAY DOWN LANDING JOINT AND HANGER 05:30 - 12:00 6.50 PULL P DECOMP POOH WITH 4-1/2"12.6#CR-NSCT TUBING -LAY DOWN 1 X 1 IN PIPE SHED j I-POOH FROM 4,500'MD -SPOOL CONTROL LINE WITH SLB SPOOLER I-P/U=54K,S/O=54K AT 2,470'MD 1-AT 2170 FT DISCONNECT CONTROL LINE FROM SVLN LAY DOWN SVLN -REMOVE CONTROL LINE SPOOLER FROM RIG FLOOR -UTILIZE AIR TOOL TO TAKE OFF CONTROL LINE BANDS -RECOVER 46 STEEL BANDS&110 JOINTS OF TUBING -CUT JOINT 2.06 FT -MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT 12:00 - 14:00 2.00 PULL P DECOMP RIG DOWN TUBING HANDLING EQUIPMENT RIG DOWN CASING TONGS AND SEND OFF !FLOOR I-STAGE CASING CUTTING ASSEMBLY TO RIG FLOOR -CLEAN AND CLEAR RIG FLOOR -INSTALL 7-1/8"WEAR RING Printed 7/20/2015 10:46:22AM •• North America-ALASKA-BP = Page 5 of 34 • ,,. Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay I Site:PB S Pad Rig Name/No.:PARKER 273 I Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 14:00 - 14:30 0.50 PULL P DECOMP PICK UP 7"CASING CUTTER BHA#1 -MAKE UP 7"CASING CUTTER AS PER BAKER REP -BAKER MSC,STABILIZER,XO 14:30 - 19:30 5.00 PULL P DECOMP RIH ON ELEVATORS WITH 7"CASING CUTTER BHA#1 FROM SURFACE TO 3,085'MD -RIH PICKING UP 4"XT-39 DP SINGLES FROM SHED RIH AT 150 FT/MIN P/U=70K,S/O=70K -MONITOR WELL VIA TRIP TANK PROPER DISPLACEMENT 19.30 - 20:30 1.00 PULL P DECOMP CUT 7"CASING -P/U 1 STAND AND MAKE UP TOP DRIVE -OBTAIN CUTTING PARAMETERS -P/U=70K,S/O=70K,80-RPM 1K TORQUE -LOCATE COLLARS AT 3,008'MD,3,047'MD, AND 3,086'MD -P/U 5 FT&CUT 7"CASING AT 3,081'MD PER BAKER -PUMP AT 168 GPM AND 700 PSI -PRESSURE DROP TO 450 PSI OBSERVE 450 PSI ON OA I-CONTINUE ROTATING FOR 15 MINS GOOD INDICATION OF CUT 20:30 - 22:30 t 2.00 PULL P DECOMP CIRCULATE OUT DEAD CRUDE FROM 7"X 9-5/8"OUTER ANNULUS CLOSE ANNULAR AND OPEN OA TO FLOW BACK TANK ICP:168 GPM,880 PSI FCP:168 GPM,660 PSI PUMP 25 BBL HI VIS SWEEP PUMP 100 BBL 9.5 PPG BRINE 1-PUMP 40 BBL DEEP CLEAN PILL -PUMP 120 BBL 9.5 PPG BRINE I-CATCH SAMPLES AT WELLHEAD I-FIRST SAMPLE DEAD CRUDE -SECOND SAMPLE DEEP CLEAN PILL,NO OIL -THIRD SAMPLE 9.5 PPG BRINE,NO OIL -GOOD INDICATIONS OF CLEAN 9.5 PPG BRINE AROUND -MONITOR WELL FOR 10 MIN:WELL STATIC -SHUT IN OA&BLOW DOWN LINE TO TANK 22:30 - 23:30 1.00 PULL P DECOMP RIG UP TO PUMP DOWN DS TAKING I RETURNS OUT OA TO PITS THRU MUD GAS (SEPARATOR -DISCUSS WITH ODE,DECISION TO CIRCULATE AT HIGHER RATE MADE HIGH PRESSURES SEEN AT 168 GPM TO I FLOW BACK TANK,LINEUP THRU RIG SYSTEM TO INCREASE RATE TO 210 GPM 23:30 00:00 -STAGE PUMPS UP TO 210 GPM,1350 PSI 0.50 PULL P DECOMP POH ON ELEVATORS WITH 7"CASING I i CUTTING BHA#1 FROM 3,081'MD TO 2,279' MD -MONITOR WELL FOR 10 MIN:WELL STATIC -BRINE WEIGHT:9.5 PPG IN,9.5 PPG OUT 1-STAND BACK 4"XT-39 DP -P/U=60K,S/O=60K MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT Printed 7/20/2015 10.46.22AM 11111 North America-ALASKA-BP • Page 6 of 34 1IIIIII1IJIIII Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations I (hr) (usft) 6/18/2015 00:00 - 01.00 1.00 PULL P DECOMP POH ON ELEVATORS WITH 7"CASING 'CUTTING BHA#1 FROM 2,279'MD TO SURFACE -BRINE WEIGHT:9.5 PPG IN,9.5 PPG OUT STAND BACK 4"XT-39 DP I-P/U=60K,S/O=60KAT 2,279'MD MONITOR WELL VIA TRIP TANK:PROPER 'DISPLACEMENT 01:00 - 02:00 1.00 PULL P DECOMP ,L/D 7"CASING CUTTING BHA#1 -L/D STABILIZER,XO,&CUTTER AS PER BAKER -GOOD INDICATIONS OF CUT ON CUTTER -PULL WEAR RING 02 00 - 03.00 1.00 PULL P DECOMP M/U PACKOFF PULLING TOOL -RIH AND ENGAGE PACKOFF '-BACK OUT LOCK DOWN SCREWS AS PER ,FMC I-PULL PACKOFF OUT -L/D PACKOFF PULLING TOOL **SIMOPS:RIG UP DOYON CASING i EQUIPTMENT 03:00 - 03:30 0.50 PULL P DECOMP M/U 7'SPEAR ASSEMBLY BHA#2 -RIH AND ENGAGE 7"CASING -PICKUP TO UNSEAT HANGER,P/U=97K 03.30 - 04:00 0.50 PULL P DECOMP CIRCULATE BOTTOMS UP X 2 I-336 GPM,336 PSI CONTAMINATED,UNSET CEMENT RETURNS SEEN ACROSS SHAKERS 04:00 - 04:30 0.50 PULL P DECOMP PULL AND LAY DOWN 7"CASING HANGER -MONITOR WELL FOR 10 MIN:WELL STATIC I-DISENGAGE SPEAR&LAY DOWN HANGER 04.30 - 08:00 3.50 PULL P DECOMP PULL 7"26#,L-80 CASING FROM 3,081'MD TO SURFACE 1-LAY DOWN 1 X 1 IN PIPE SHED -CASING IN GOOD CONDITION,NO NOTICEABLE ISSUES 1-LAY DOWN 76 FULL JOINTS -CUT JOINT:35.18 FT WITH 7.75"FLARE NORM ALL CASING PULLED -MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT 08:00 - 09:30 1.50 PULL P DECOMP R/D 7"DOYON CASING EQUIPMENT I-CHANGE ELEVATORS FROM SIDE DOOR TO DP i -CLEAN AND CLEAR RIG FLOOR 1 INSTALL 9-1/8"WEAR RING 09:30 10:00 0.50 PULL P t DECOMP I RIG SERVICE i '-SERVICE TOP DRIVE,GREASE BLOCKS, I PERFORM DERRICK INSPECTION 10:00 - 15:00 5.00 PULL -rP DECOMP MAKE UP CLEAN OUT BHA#3 FROM SURFACE TO 793'MD -8.5"USED BIT,(2)7"BOOT BASKETS,BIT SUB,8.5"UPPER WATERMELON MILL, BUMPER SUB,OIL JAR,(9)6.25"DRILL ' ' COLLARS,(15)5"HWDP,XO �' �I -P/U=75K,S/O=75K Printed 7/20/2015 10.46:22AM • North America-ALASKA-BP • Page 7 of 34 fi *./0,±7;j / ,:,�%?J��F iJ � Y�� av`irfF"s�ri'ii'f f L' '''p/.&4"/ / J 14 , J °'6',A47,010/ 40 O Operation SummaryReport / Common Well Name.S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 18:30 3.50 PULL P DECOMP RIH WITH CLEAN OUT BHA#3 FROM 793'MD TO 7"CASING STUB AT 3,081'MD -PICK UP 4"XT-39 DP SINGLES FROM SHED -FILL PIPE EVERY 20 STANDS -P/U=105K,S/O=103K -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 18:30 - 19:30 1.00 PULL P DECOMP CIRCULATE WELL CLEAN -PUMP 20 BBL HI VIS SWEEP 600 GPM,1200 PSI RECIPROCATE PIPE 90' MONITOR WELL FOR 10 MIN:WELL STATIC 19:30 - 23:30 4.00 PULL P DECOMP CUT AND SLIP DRILLING LINE CUT 105 WRAPS FOR 892'OF LINE CALIBRATE AMPHION SYSTEM CHECK COM 23 30 - 00:00 0.50 PULL P DECOMP POOH WITH CLEAN OUT BHA#3 FROM 3,050' MD TO 1,940'MD -MONITOR WELL FOR 10 MIN:WELL STATIC -BRINE WEIGHT:9.5 PPG IN,9.5 PPG OUT P/U=90K,S/0=90KAT 1,940'MD i-MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 6/19/2015 100:00 - 02:30 2.50 PULL P DECOMP -POOH WITH CLEAN OUT BHA#3 FROM 1,940' MD TO SURFACE P/U=90K,S/0=90KAT 1,940'MD -BRINE WEIGHT:9.5 PPG IN,9.5 PPG OUT STAND BACK HWDP AND DC -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 02.30 - 04:00 1.50 PULL P DECOMP RIG UP HES E-LINE CLEAN AND CLEAR RIG FLOOR RIG UP SHEAVES AND BRING TOOLS TO RIG FLOOR -MAKE UP TOOLS AS PER HES -MAKE UP EZSV/CCL AS PER HES 04:00 - 09:30 5.50 PULL P DECOMP RIH AND SET HES 9-5/8"EZSV(7.75"OD) RIH WITH EZSV/CCL FROM SURFACE TO TUBING STUB AT 3080'MD ELMD LOG UP FROM 3,080'ELMD UNCERTAINTY ON COLLAR LOCATIONS, POOH AND ADD WEIGHT BARS RIH FOR SECOND LOGGING RUN RIH TO 3,080'ELMD,LOCATE COLLARS,ALL COLLARS SHOWING PUT EZSV AT 3,034'ELMD,5'ABOVE COLLAR -SET TOP OF EZSV AT 3034'ELMD,8'ABOVE CASING COLLAR 1-BOTTOM OF EZSV AT 3037'ELMD j-PULL OUT OF HOLE AND R/D E-LINE Printed 7/20/2015 10:46.22AM • North America-ALASKA-BP • Page 8 of 34 Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12.00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:30 - 13:00 3.50 PULL N SFAL -1.37 DECOMP ATTEMPT TO PRESSURE TEST EZSV TO 250 PSI LOW FOR 5 MIN,3000 PSI HIGH FOR 30 MIN EACH GOOD 250 PSI LOW PRESSURE TEST PRESSURE UP TO 3000 PSI,PRESSURE LEAKING OFF TROUBLESHOOT SURFACE SYSTEM,GLAND NUT ON CASING SPOOL LEAKING -TIGHTEN GLAND NUT GOOD 250 PSI LOW TEST PRESSURE UP TO 3000 PSI,FLANGE 1 LEAKING BETWEEN CASING SPOOL AND TUBING SPOOL 1-CALL FMC TO TROUBLESHOOT FMC TORQUED ALL BOLTS ON FLANGE CONNECTION BETWEEN CASING AND TUBING SPOOL -GOOD 250 PSI TEST PRESSURE UP TO 3000 PSI,GLAND NUT LEAKING ON SPOOL FMC TORQUED GLAND NUT 13:00 - 14:00 1.00 PULL P DECOMP PRESSURE TEST EZSV TO 250 PSI LOW FOR 5 MIN,3000 PSI HIGH FOR 30 MIN EACH GOOD 250 PSI LOW TEST GOOD 3000 PSI HIGH TEST -NOTIFIED WTLAND RECEIVED APPROVAL -TEST CHARTED AND ATTACHED 14:00 - 14:30 0.50 PULL P DECOMP I RIG SERVICE SERVICE RIG FLOOR EQUIPMENT I-GREASE TOP DRIVE 14:30 - 15:30 1.00 STWHIP P WEXIT RIG UP SPERRY E-LINE FOR GYRO TO I ORIENT WHIPSTOCK 15:30 - 18:00 2.50 STWHIP P WEXIT j CHANGE OUT UPPER PIPE RAM FROM 7"TO 2-7/8"X 5-1/2"VBRS PULL 9-1/8"WEAR RING -M/U 4"TEST JOINT -CLOSE BLIND RAMS -DE-ENERGIZE ACCUMULATOR C/O RAMS FROM 7"TO 2-7/8"X 5-1/2"VBRS RE-ENERGIZE ACCUMULATOR -INSTALL TEST PLUG,TEST WITH 4"TEST JOINT 250 PSI LOW,3500 PSI HIGH -PULL TEST PLUG,INSTALL 9-1/8"WEAR RING -R/D TEST EQUIPMENT -OPEN BLIND RAMS -CLEAN AND CLEAR RIG FLOOR -BOP CONFIGURATION FROM TOP TO BOTTOM:ANNULAR PREVENTER,2-7/8"X 5" VBRS,BLIND SHEAR RAMS,MUD CROSS, 2-7/8"X 5-1/2"VBRS Printed 7/20/2015 10:46•22AM • North America-ALASKA-BP • Page 9 of 34 Operation Summary Report 4 {r,� r���,'0,;0,4090,2,',7-;/ r . Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date 7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 1 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To 1 Hrs Task I Code NPT NPT Depth Phase Description of Operations 1 (hr) (usft) 118:00 - 21:00 3.00 STWHIP P WEXIT MAKE UP BAKER WHIPSTOCKASSEMBLY I FROM SURFACE TO 835'MD I-MAKEUP 9-5/8"GEN II 3-STRING MILL AND LEAD MILL ASSEMBLY ' -CONFIRM ANCHOR SET FOR 20 KLBS SHEAR AND REMOVAL OF SHIPPING PIN i '-BKR REP AND SLB DD ON RIG FLOOR ORIENT UBHO WITH WHIPSTOCK HIGHSIDE AND CONFIRM GYRO DATA TOOL PROPERLY ORIENTED !-RIH 9 X 6 1/2"DRILL COLLARS I-RIH WITH 15 JTS 5"HWDP -P/U=75K,S/0=75K 21 00 - 23:00 2.00 STWHIP P WEXIT RIH WITH WHIPSTOCK/MILLING BHA#4 FROM 1835'MD TO 3,000'MD -RIH WITH 4"DP FROM DERRICK -P/U=105K,S/O=105K -FILL PIPE EVERY 20 STANDS MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 00:00 W 23:00 - 1.00 STWHIP P WEXIT RIH GYRODATA ORIENT HIPSTOCK -R/U GYRODATA ,-RIH AND ORIENT WHIPSTOCK 64 DEG GTF 'AS PER SLB&GYRODATA -POOH AND R/D ELINE 6/20/2015 00:00 01:00 1.00 STWHIP P I 1 WEXIT 'SET WHIPSTOCK AS PER BAKER REP , I I-RIH AND TAG EZSVAT3,035'MD I-P/U=105K,S/0=105K !-STACK 20K TO SHEAR ANCHOR I-P/U 5K OVERPULL TO CONFIRM ANCHOR SET STACK 40K TO SHEAR MILLING ASSEMBLY P/U TO CONFIRM ASSEMBLY FREE.P/U 101K PROJECTED WINDOW:TOW 3,013'MD, BOW:3,030'MD 01 00 - 02:00 1.00 STWHIP P WEXIT 'DISPLACE WELL FROM 9.5 PPG BRINE TO 9.3 PPG MILLING FLUID -256 GPM,325 PSI • -PUMP 30 BBL HI VIS SWEEP SPACER I ! -PUMP 236 BBLS MILLING FLUID 10:30 8.50 STWHIP P WEXIT 02:00 KICKOFF S-42A SIDETRACK AND MILL WINDOW MILL WINDOW IN 9-5/8"CASING WITH 8-1/2" MILLING ASSEMBLY -MILL FROM 3,013'MD TO 3,049'MD• -450 GPM,725 PSI -80 RPM,3-6K TORQUE -WOB:3-4K I-P/U=103K,S/O=103K,ROT=103K -CEMENT OBSERVED BEHIND CASING -PUMP TWO 20 BBL HIGH VIS SWEEPS DURING MILLING AT 3,020'MD AND 3,029'MD -WORK MILLS THRU WINDOW MULTIPLE TIMES TO ENSURE SMOOTH WINDOW -NO DRAG i TOP OF WINDOW:3,013'MD,3,013'TVD MIDDLE OF WINDOW:3,021'MD,3,021'TVD BOTTOM OF WINDOW 3,030'MD,3,030'TVD Printed 7/20/2015 10.46.22AM SNorth America-ALASKA-BP • Page 10 of 34 "IIII'-; •,% • r i b ,. , ..„ r"4.4', `:' ? ,°.� Operation Summary Report r Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site.PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum.S-42A actual @82.68usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 11:30 1.00 STWHIP P ! WEXIT CIRCULATE BOTTOMS UP 2 TIMES -PUMP 35 BBL HIGH VIS SWEEP WITH SUPERSWEEP MATERIAL I -550 GPM,923 PSI MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT -MONITOR WELL FOR 10 MIN:WELL STATIC 111:30 - 13:00 1.50 STWHIP P WEXIT PERFORM LEAK-OFF TEST -MUD WEIGHT:9.3 PPG,3,020'TVD -PUMP 1.8 BBLS AT 0.75 BPM,PRESSURE BROKE OVER AT 850 PSI,BLEED BACK 1.5 , BBLS 1 I-ACHIEVE 14.7 PPG FIT,>50 BBL KICK I I TOLERANCE DISCUSS RESULTS WITH ODE I -BLOW DOWN TEST EQUIPMENT -SEE ATTACHED DOCUMENTATION 13:00 - 14:30 1.50 STWHIP P WEXIT CIRCULATE HOLE CLEAN TO ENSURE METAL I SHAVINGS OUT OF HOLE I-550 GPM,900 PSI -OBTAIN SPR'S 14:30 - 15:30 1.00 STWHIP P -WEXIT ,POOH WITH MILLING BHA#4 FROM 3,049'MD TO 800'MD i I-MONITOR WELL FOR 10 MINUTES:WELL STATIC -P/U=100K,S/0=100K -MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT I-MONITOR WELL VIA TRIP TANK:PROPER _ I DISPLACEMENT 15:30 - 18:00 ' 2.50 STWHIP t P j WEXIT I L/D MILLING BHA#3 FROM 800'MD TO i ISURFACE MONITOR WELL FOR 10 MINUTES BEFORE PULLING NON SHEARABLES ACROSS STACK WELL STATIC L/D 6-1/4"DRILL COLLARS -STAND BACK 5"HWDP WINDOW MILL 1/4"UNDERGAUGE I I-ALL WATERMELON MILLS IN GAUGE -P/U=70K,S/O=70K -CLEAN AND CLEAR RIG FLOOR 18.00 - 19:00 1.00 STWHIP P WEXIT FLUSH STACKAND FUNCTION BOP IELEMENTS -PULL 9-1/8"WEAR RING I FLUSH BOP WITH BOP WASHING TOOL I -FUNCTION RAMS I I -BLOW DOWN CHOKE AND KILL LINES I -DRAIN STACK INSTALL 9-1/8"WEAR RING 19:00 - 22:00 3.00 DRILL P WEXIT MAKE UP 8.5"MOTOR DRILLING BHA#4 FROM SURFACE TO 770'MD -M/U AS PER SLB DD/MWD,GYRODATA -P/U=70K,S/O=70K -8-1/2"MILLED TOOTH BIT,6-3/4"XP MOTOR 11.5 DEG,8-3/8 NM STAB,NM XO.GYROPULSE 1675,TELESCOPE 675 MWD,ARC 675 LWD,XO, I 8-3/8"NM STABILIZER,(3)FLEX COLLAR, FLOAT SUB,(12JTS)5"HWDP, HYDRAULIC JARS,(5 JTS)5"HWDP,XO Printed 7/20/2015 10:46.22AM • North America-ALASKA-BP • Page 11 of 34 Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site.PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 23:30 1.50 DRILL P WEXIT TRIH WITH 8.5"MOTOR DRILLING BHA#4 FROM 770'MD TO 1,711'MD -RIH WITH DP SINGLES FROM SHED -PERFORM SHALLOW HOLE MWD TEST AT 1,500'MD,GOOD TEST -FILL PIPE EVERY 10 STANDS f-P/U=80K,S/0=80K -MONITOR WELL VIA TRIP TANK:PROPER _ IP DISPLACEMENT 23:30 - 00:00 0.50 DRILL WEXIT I RIG SERVICE -LUBRICATE RIG -GREASE TRAVELING BLOCK ASSEMBLY& ROTARY 6/21/2015 00:00 - 02:30 2.50 DRILL P WEXIT RIH WITH 8.5"MOTOR DRILLING BHA#4 FROM 1,771'MD TO 3,049'MD RIH WITH DP SINGLES FROM SHED I-FILL PIPE EVERY 10 STANDS P/U=80K,S/O=80K CALCULATE BASELINE ECD ,-ORIENT HIGH SIDE AS PER GYRO/DD -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 02:30 - 03:00 0.50 DRILL P WEXIT 'BENCH MARK ECD's OBTAIN ECD BASELINE AS PER MWD. -ORIENTATE TOOL FACE AS PER GYRO/DD -OBTAIN SPR'S -#1 @ 30 SPM=238 PSI @40 SPM=288 PSI -#2 @ 30 SPM=232 PSI @40 SPM=284 PSI 03:00 - 12:30 9.50 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 3,049'MD TO 3,546'MD(3,520'TVD) -600 GPM,1,805 PSI ON,1729 PSI OFF -80 RPM, 3K TORQUE ON, 1K TORQUE OFF -P/U=110K,S/O=105K ROT 100K. -WOB:5-15K ECD:ACTUAL:9.88 PPG CALCULATED:9.88 ,PPG -SURVEY EVERY-30FT -MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT -ACTUAL ROT TIME=1.41 HRS,ACTUAL SLIDE TIME=2.94 HRS,TOTAL BIT TIME= 4.35 -TOTAL JAR TIME=4.35 HRS -PUMP 30 BBL HI VIS SWEEP AT 3,504'MD, 10%INCREASE IN CUTTINGS AND LARGE CLAY BALLS SEEN -CLEAN MWD SURVEYS NOT OBTAINED BY 3,550 AS PER SURVEY PROGRAM -DISCUSS WITH ODE,SLB -DECISION TO POOH FOR RSS ASSEMBLY MADE 12:30 - 13:30 1.00 DRILL I N DFAL 3,546.00 INTI CIRCULATE BOTTOMS UP 1X -600 GPM,1800 PSI -OBTAIN SPRS Printed 7/20/2015 10:46.22AM 40 0 North America-ALASKA-BP Page 12 of 34 'Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual©82.68usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT NPT Depth Phase 1 Description of Operations 1 (hr) (usft) 13:30 - 15:30 2.00 DRILL N DFAL 3,546.00 INTI ,POOH ON ELEVATORS WITH MOTOR DRILLING BHA#4 FROM 3,546'MD TO 800'MD -MONITOR WELL FOR 10 MINUTES BEFORE I 'COMING OFF BOTTOM:WELL STATIC -MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT I -P/U=110K,S/0=105K i 1 MONITOR WELL FOR 10 MINUTE AT WINDOW:WELL STATIC 1 �-PULLAT 90 FT/MIN IN OH AND 150 FT/MIN IN CH -MONITOR WELL VIA TRIP TANK:PROPER - 1 1 DISPLACEMENT 115:30 - 18:00 2.50 DRILL N DFAL 3,546.00 i INTI UD MOTOR DRILLING BHA#4 FROM 800'MD TO SURFACE 1 ( MONITOR WELL FOR 10 MINUTES BEFORE PULLING NON SHEARABLES ACROSS STACK WELL STATIC -STAND BACK 5"HWDP IN DERRICK -P/U=70K,5/0=70K -CLEAN AND CLEAR RIG FLOOR 18 00 - 18:30 0.50 DRILL P INTI RIG SERVICE 1 LUBRICATE RIG 1 -GREASE TD BLOCKS AND CROWN 1 -SERVICE RIG FLOOR EQUIPMENT 18:30 - 20:00 1.50 DRILL N DFAL 1 3,546.00 INTI I BRING E-LINE EQUIPMENT TO RIG FLOOR 1 I SIMOPS:SLB PROGRAM 8.5"RSS DRILLING BHA#6 20:00 - 22:00 2.00 , DRILL N ! DFAL 3,546.00 I INTI I MAKE UP 8.5"RSS DRILLING BHA#5 FROM L SURFACE TO 555'MD i j -M/U AS PER SLB DD/MWD 1 i , -P/U=58K,S/O=58K I 8-1/2"HYCALOG PDC,PD675 X6 RSS,E-MAG RECEIVER,FLEX COLLAR,ARC 675 LWD, TELESCOPE 675 MWD,NM XO,NM STABILIZER,(3)NM FLEX COLLARS,SAVER SUB,(3 JTS)5"HWDP,6-1/2"HYDRAULIC JARS,(8 JTS)5"HWDP,XO SUB,(42 JTS)4" DP,8-1/2"GHOST REAMER 22:00 - 00:00 2.00 DRILL N DFAL 3,546.00 INTI RIH WITH 8.5"RSS DRILLING BHA#5 FROM 555'MD TO 1,973'MD PICK UP DP SINGLES FROM SHED TO 1,220' MD -FILL PIPE EVERY 15 STANDS -SHALLOW HOLE TEST AT 1,973'MD,GOOD TEST -P/U=75K,S/O=75K 1 1-MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 6/22/2015 00:00 - 01:30 1.50 DRILL N DFAL 3,546.00 INTI RIH WITH 8.5"RSS DRILLING BHA#6 FROM 1,973'MD TO 3,480'MD i -FILL PIPE EVERY 10 STANDS i -P/U=95K,S/O=95K -MONITOR WELL VIA TRIP TANK:PROPER (DISPLACEMENT }01:30 02:00 0.50 DRILL j N DFAL 3,546.00 INTI PERFORM CHECK SHOT SURVEYS -OBTAIN CHECK SHOT SURVEYS AT 3,497' 1 1 MD,3,528'MD I -CLEAN MWD SURVEYS -OBTAIN SPRS Printed 7/20/2015 10:46:22AM 0 North America-ALASKA-BP S Page 13 of 34 9 Operation Summary Report` "Ziftegar4A*0araggir4i4S01;xtratiOfrUA:4 /-1"." :''','V'20X114;1f011ifi.411.00%;t:':Vae-, Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad 1 Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UW:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft)_-- 02:00 04:00 1 2.00 DRILL P 1 INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 3,546'MD TO 3,666'MD -600 GPM,1,790 PSI ON,1700 PSI OFF -80 RPM, 3K TORQUE ON, 1K TORQUE OFF -P/U=110K,S/O=105K ROT 100K. -WOB:5-15K ECD:ACTUAL:9.88 PPG CALCULATED:9.88 PPG SURVEY EVERY-30FT -MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT -SURVEY COMING BACK NOT IN SPEC -PHONE ODE TO DISCUSS 04:00 - 05:00 1.00 DRILL N DPRB 3,664.63 INTI TROUBLESHOOT MWD SURVEY -DISCUSS WITH SLB,SPERRY CORRECTIONS,AND ODE ' I-CIRCULATE AND CONDITION MUD -400 GPM,930 PSI 1-80 RPM,IK TORQUE RECIPROCATE PIPE 90' -SURVEYS CORRECTED BY SPERRY,WITHIN 'SPEC -PHONE ODE TO DISCUSS PLAN FORWARD 05 00 - 07:30 2.50 DRILL P I INTI 1 DRILL 8-1/2"INTERMEDIATE HOLE FROM {3,666'MD TO 3,828'MD(3,793'TVD) -600 GPM,1,790 PSI ON,1700 PSI OFF • 80 RPM, 3K TORQUE ON, 1K TORQUE OFF I -P/U=110K,S/O=105K ROT 100K. I-WOB:5-15K -ECD:ACTUAL:9.94 PPG CALCULATED:9.88 PPG 1-SURVEY EVERY-30FT -MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT -ACTUAL ROTATE TIME:2.02 HRS -TOTAL JAR TIME:6.4 HRS -SEND SURVEYS TO SPERRY FOR I CORRECTION I % -RSS NOT ACHIEVING DOG LEGS NEEDED FOR BUILD -TROUBLESHOOT RSS,PUMP 40 BBL LOW HIGH VIS SWEEP AT 3,760'MD -475 GPM,1260 PSI,40%INCREASE IN CUTTINGS SEEN -RSS NOT BUILDING,DISCUSS WITH ODE, DECISION TO TRIP FOR MOTOR 07:30 - 08:00 0.50 1 DRILL P ' INTI CIRCULATE BOTTOMS UP -600 GPM,1780 PSI -150 RPM,1K TORQUE 08:00 - 10:30 2.50 DRILL P INTI POOH ON ELEVATORS WITH 8.5"RSS DRILLING BHA#5 FROM 3,828'MD TO 551'MD -MONITOR WELL FOR 10 MINUTES:WELL I STATIC I-MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT P/U=92K,S/G=92KAT3000'MD 1-MONITOR WELL FOR 10 MINUTES AT 1 WINDOW:WELL STATIC I -P/U=58K,S/0=58K AT 551'MD MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT Printed 7/20/2015 10.46.22AM • North America ALASKA BP Page 14 of 34 �, .a, , Operation Summary Report ' Common Well Name.S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date 6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual©82.68usft(above Mean Sea Level) Date From-To Firs Task , Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 13:00 2.50 DRILL P INTI L/D 8.5"RSS DRILLING BHA#5 FROM 551'MD TO SURFACE -MONITOR WELL FOR 10 MINUTES BEFORE PULLING NON SHEARABLES ACROSS STACK WELL STATIC -STAND BACK HWDP AND FLEX COLLARS L/D AS PER DD/MWD STAGE SPERRY ELINE EQUIPMENT TO RIG FLOOR CLEAN AND CLEAR RIG FLOOR 13.00 - 13:30 0.50 DRILL P j INTI I RIG SERVICE i-LUBRICATE RIG SERVICE TOP DRIVE,BLOCKS,RIG FLOOR EQUIPMENT 13:30 - 15:00 1.50 DRILL P INTI INSPECT,CALIBRATE,AND PROGRAM MWD/LWD BY SLB 15:00 - 17:00 2.00 j DRILL P INTI MAKE UP 8.5"MOTOR DRILLING BHA#6 FROM SURFACE TO 569'MD -M/U AS PER SLB DD/MWD -P/U=55K,S/O=55K -8-1/2"MILLED TOOTH BIT,6-3/4"XP MOTOR 1.5 DEG,8-3/8 NM STAB,NM PONY COLLAR, NM XO.ARC LWD 675,TELESCOPE 675 MWD, XO,8-3/8"NM STABILIZER,(3)FLEX COLLAR, j FLOAT SUB,(3JTS)5"HWDP, HYDRAULIC JARS,(8 JTS)5"HWDP,XO 17 00 - 20:30 3.50 DRILL P INTI IRIH ON ELEVATORS WITH 8.5"MOTOR DRILLING BHA#6 FROM 569'MD TO 3,828'MD FILL PIPE EVERY 15 STANDS -P/U=90K,5/0=90KAT 3,000'MD I-SHALLOW HOLE TEST MWD TOOLS AT 1,500' MD,550 GPM,1100 PSI,GOOD TEST OBTAIN BASELINE ECD AT WINDOW -OBTAIN SPRS P/U=105K,S/0=100K AT 3,828'MD 20 30 - 00 00 3.50 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 3,828'MD TO 4,011'MD(3,942'TVD) -550 GPM,1,780 PSI ON,1690 PSI OFF -80 RPM, 4K TORQUE ON, 3K TORQUE OFF P/U=108K,S/0=95K ROT 98K. WOB:5-15K ECD:ACTUAL:9.95 PPG CALCULATED:9.94 PPG -SURVEY EVERY-30 FT -MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT -WIPE 10 FT ON CONNECTIONS -ACTUAL ROTATE TIME:0.66 HRS -ACTUAL SLIDE TIME:1.54 HRS -TOTAL JAR TIME:9.9 HRS Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP • Page 15 of 34 Operation Summary Report I1 Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 1X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay I Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM 1Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. I UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations i (hr) (usft) 6/23/2015 00:00 - 12:00 12.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM j 4,011'MD TO 4,564'MD(4,308'TVD) -600 GPM,2120 PSI ON,2065 PSI OFF 1-80 RPM, 4K TORQUE ON, 2.5K TORQUE OFF -P/U=110K,S/O=95K ROT 98K -WOB:5-15K -ECD:ACTUAL:9.95 PPG CALCULATED:9.90 PPG SURVEY EVERY-30FT -SURVEYS REQUIRE CORRECTIONS FROM SPERRY TO BE IN SPEC I-MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT i-WIPE 10 FT ON CONNECTIONS 1-ACTUAL ROTATE TIME:1.87 HRS I 1-ACTUAL SLIDE TIME:5.00 HRS -TOTAL JAR TIME:15.0 HRS I 1 -PUMP SWEEP AT 4,339'MD WITH 10% RETURN IN CUTTINGS 12:00 - 15:00 3.00 DRILL P ( INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 4,564'MD TO 4,720'MD(4,375'TVD) 600 GPM,2300 PSI ON,2200 PSI OFF 80 RPM, 4K TORQUE ON, 2K TORQUE OFF ' P/U=115K,S/O=95K ROT 100K I1-ECD:ACTUAL:10.00 PPG CALCULATED: 9.91 PPG I-SURVEY EVERY-30FT -MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT -WIPE 15 FT ON CONNECTIONS -ACTUAL ROTATE TIME:0.63 HRS -ACTUAL SLIDE TIME:1.72 HRS -TOTAL JAR TIME:17.3 HRS -LAND CURVE SECTION,TRIP FOR RSS 15:00 - 16:00 1.00 1 DRILL P INTI CIRCULATE BOTTOMS UP I-PUMP HIGH VIS SWEEP:10%INCREASE IN CUTTINGS 1 -600 GPM,2250 PSI -80 RPM,4K TORQUE 16:00 - 19:00 3.00 DRILL P INTI POOH ON ELEVATORS WITH 8.5"MOTOR BHA #6 FROM 4,720'MD TO 6,00'MD I-MONITOR WELL FOR 10 MINUTES:WELL STATIC -MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT -P/U=110K,S/O=95K I 1-MONITOR WELL FOR 10 MINUTES AT WINDOW:WELL STATIC -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 19:00 - 22:00 3.00 DRILL P INTI .LAY DOWN 8.5"MOTOR BHA#6 FROM 600'MD TO SURFACE -MONITOR WELL FOR 10 MINUTES BEFORE I PULLING NON SHEARABLES ACROSS STACK WELL STATIC 1-PJSM WITH SLB AND RIG CREW i -STAND BACK HWDP AND FLEX COLLARS -L/D BHA PER DD/MWD -CLEAN AND CLEAR RIG FLOOR -BIT GRADE:2-1-WT-A-E-I-NO-BHA 22:00 - 22:30 0.50 DRILL P INTI RIG SERVICE -LUBRICATE RIG -GREASE TOP DRIVE,BLOCKS,AND CROWN -SERVICE RIG FLOOR EQUIPMENT Printed 7/20/2015 10:46:22AM 0 North America-ALASKA-BP • Page 16 of 34 ff�,�r,%,��r.,,r?r,i"'e/ ,r";f�ffIWa4 � 'J r'',: %,fr'#-,1**4,04!4*% r3 .,/~.4', ;, '°r�, ;f' + �� r ;1 %! ' f�OperationSummary Report' r,� ` i/ r Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual©82.68usft(above Mean Sea Level) Date From-To Hrs l Task Code NPT NPT Depth Phase Description of Operations (hr) - (usft) 22:30 - 00:00 1.50 DRILL N WAIT INTI DOWNLOAD MWD TOOL DATA i -WAIT ON SLB TO DOWNLOAD MWD DATA -PROGRAM ARC LWD CONFIRM PROGRAMMING WITH SLB IN TOWN 6/24/2015 00:00 - 01:30 , 1.50 DRILL P INTI MAKE UP 8.5"RSS DRILLING BHA#7 FROM I SURFACE TO 555'MD I -PJSM WITH SLB AND RIG CREW -M/U BHA PER SLB DD/MWD 8-1/2"HYCALOG PDC,PD675 X6 RSS,E-MAG RECEIVER,FLEX COLLAR,ARC 675 LWD, `TELESCOPE 675 MWD,NM XO,NM STABILIZER,(3)NM FLEX COLLARS,SAVER SUB,(3 JTS)5"HWDP,6-1/2"HYDRAULIC JARS,(8 JTS)5"HWDP,XO SUB,(42 JTS)4" DP,8-1/2"GHOST REAMER 01:30 - 06:00 4.50 DRILL P INTI RIH WITH 8.5"RSS DRILLING BHA#7 FROM 555'MD TO 4,720'MD -RIH ON 4"DP FROM DERRICK ;-FILL PIPE EVERY 15 STANDS -SHALLOW HOLE TEST AT 1,878'MD,GOOD TEST j P/U=75K,S/0=75KAT 1,878'MD OBTAIN SPRS 1-MONITOR WELL VIA TRIP TANK:PROPER I DISPLACEMENT 06:00 - 12:00 6.00 DRILL P INTI I DRILL 8-1/2"INTERMEDIATE HOLE FROM 4,720'MD TO 5,466'MD(4,666'TVD) -600 GPM,2546 PSI ON,2530 PSI OFF 1-150 RPM, 6K TORQUE ON, 3K TORQUE OFF I -P/U=111K,S/O=93K ROT 96K. I I I -WOB:5-15K 1 -ECD:ACTUAL:10.28 PPG CALCULATED: 110.07 PPG ' I-SURVEY EVERY-90 FT -ACTUAL ROTATE TIME:3.39 HRS -TOTAL JAR TIME:20.7 HRS -WIPE 10 FT PRIOR TO CONNECTIONS -MUD WEIGHT:9.4 PPG IN,9.4 PPG OUT -PUMP 30 BBL HIGH VIS SWEEP AT 5,000'MD WITH 20%INCREASE IN RETURNS 12:00 - 23:30 11.50 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM I 5,720'MD TO 6,885'MD(5,508'ND) I-600 GPM,3100 PSI ON,3030 PSI OFF I-150 RPM, 7K TORQUE ON,5K TORQUE OFF i 1-P/U=145K,S/O=105K ROT 110K. -WOB:5-15K -ECD:ACTUAL:10.7 PPG CALCULATED: I 10.25 PPG I-SURVEY EVERY-90FT -ACTUAL ROTATE TIME:7.96 HRS -TOTAL JAR TIME:25.26 HRS I-MUD WEIGHT:9.5 PPG IN,9.5 PPG OUT '-WIPE 10 FT ON CONNECTIONS -OBTAINS SPRS EVERY 500 FT -PUMP 30 BBL HIGH VIS SWEEP AT 5,570'MD, 10%INCREASE IN CUTTINGS -PUMP 30 BBL HIGH VIS SWEEP AT 6,050'MD, 110%INCREASE IN CUTTINGS Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP S Page 17 of 34 Operation Summary Report ' , . ** y* , ' "417 f' Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 IX3-016TH-C:(8,089,714.00) Project:Prudhoe Bay I Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12.00:00AM I Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase I Description of Operations (hr) (usft) 23:30 - 00:00 0.50 DRILL P INTI RIG SERVICE -LUBRICATE RIG -SERVICE TOP DRIVE,BLOCKS,CROWN, AND RIG FLOOR EQUIPMENT -GREASE WASHPIPE 6/25/2015 00.00 - 12:00 12.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 6,885'MD TO 8,017'MD(6486'TVD) I 600 GPM,3423 PSI ON,3400 PSI OFF I-180 RPM, 8K TORQUE ON,7K TORQUE OFF P/U=163K,S/O=112K ROT 122K. -WOB:5-15K -ECD:ACTUAL:10.36 PPG CALCULATED: 10.18 PPG I-SURVEY EVERY-90FT -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT WIPE 90 FT ON CONNECTIONS OBTAIN SPRS'EVERY 500 FT -PUMP 30 BBL HIGH VIS SWEEP AT 6,885'MD, 10%INCREASE IN CUTTINGS WEIGHT UP BY 7,852'MD TO 10.4 PPG OVER 3 CIRCULATIONS USING 14.7 PPG SPIKE (FLUID 12:00 - 19:00 7.00 DRILL P INTI I DRILL 8-1/2"INTERMEDIATE HOLE FROM 8,017'MD TO TD AT 8,482'MD(6,775'TVD) I-550 GPM,3560 PSI ON,3530 PSI OFF I-180 RPM, 9K TORQUE ON,8K TORQUE OFF -P/U=280K,S/O=115K ROT 125K. ECD:ACTUAL:11.30 PPG CALCULATED: 11.10 PPG -SURVEY EVERY-90FT -MUD WEIGHT:10.5 PPG IN,10.5 PPG OUT -BACKREAM 90 FT ON CONNECTIONS -OBTAIN SPRS'EVERY 500 FT -CONTROL DRILLING PARAMETERS AT 8,350' MD IN PREPARATION FOR CASING PICK -WOB:6K,180 RPM,ROP 60-80 FT/HR I-CALL TD BASED ON GAMMA AT BIT READING 19:00 - 21 00 2.00 DRILL INTI I CIRCULATE 3X BOTTOMS UP P it - CIRCULATE BOTTOMS UP FOR SAMPLES -CONFIRM TOP KUPARUK SAND 550 GPM,3540 PSI -180 RPM,7K TORQUE -RECIPROCATE PIPE 90' 21 00 - 21:30 0.50 DRILL P INTI PUMP OUT OF HOLE FROM 8,482'MD TO THRZ AT 8,394'MD -MONITOR HOLE FOR 10 MINUTES PRIOR TO PULLING OFF BOTTOM:WELL STATIC PUMP OUT OF HOLE THROUGH THE TOP HRZ AT 50'PER MIN -MUD WEIGHT:10.5 PPG IN,10.5 PPG OUT 21:30 - 23:00 1.50 DRILL P INT1 PULL OUT OF HOLE ON ELEVATORS FROM 8,394'MD TO 7,074'MD -PULL OUT OF HOLE AT 60'PER MIN -MUD WEIGHT:10.5 PPG IN,10.5 PPG OUT P/U=180K,S/O=110K I 1 - ENCOUNTER CONSISTENT OVERPULL BUILDING UP TO-35K -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT Printed 7/20/2015 10 46 22AM • North America-ALASKA-BP S Page 18 of 34 Operation Summary Report ti Common Well Name S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. I UWI:500292266200 Active datum:S-42A actual t82.68usft(above Mean Sea Level) Date From-To Hrs ! Task Code NPT I NPT Depth 1 Phase I Description of Operations (hr) (usft) 23:00 - 00:00 1 1.00 DRILL P INTI CIRCULATE BOTTOMS UP TO CLEANUP HOLE DUE TO DRAG -STAGE PUMPS UP TO 550 GPM,IN 42 GPM 1 INCREMENTS I-82 GPM,400 PSI -166 GPM,540 PSI 249 GPM,998 PSI 320 GPM,1465 PSI -403 GPM,2075 PSI 1-550 GPM,ICP:3300 PSI FCP:3132 PSI -120 RPM,7K TORQUE -RECIPROCATE PIPE 50' 6/26/2015 00:00 - 02:30 2.50 DRILL 1 P INTI PULL OUT OF HOLE ON ELEVATORS FOR WIPER TRIP FROM 7,075'MD TO 4700'MD -PULL OUT OF HOLE AT 60-80'PER MIN -MUD WEIGHT:10.5 PPG IN,10.5 PPG OUT -P/U=152K,S/O=101K -MONITOR WELL VIA TRIP TANK PROPER DISPLACEMENT 02:30 - 03:30 1.00 DRILL P INTI CIRCULATE 8tOTTOMS UP 2 TIMES AT TOP OF WIPER TRIP -STAGE PUMPS UP TO 550 GPM,IN 42 GPM 'INCREMENTS 80 GPM,154 PSI 1 -166 GPM,273 PSI -245 GPM,580 PSI -328 GPM,1044 PSI -415 GPM,1550 PSI -550 GPM,ICP:2475 PSI FCP:2427 PSI -MUD WEIGHT:10.5 PPG IN,10.5 PPG OUT -80 RPM,3K TORQUE RECIPROCATE PIPE 90' 03 30 - 08 00 4.50 DRILL P INTI RIH ON ELEVATORS FOR WIPER TRIP WITH RSS BHA#7 FROM 4,700'MD TO 8,482'MD -RIH WITH 4"DP FROM DERRICK -FILL PIPE EVERY 15 STANDS I -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT -WASH LAST STAND TO BOTTOM,128 GPM, 92 PSI 08:00 - 10:00 2.00 DRILL P INT1 CIRCULATE BOTTOMS UP 3 TIMES -STAGE PUMPS UP TO 550 GPM,IN 42 GPM INCREMENTS -128 GPM,92 PSI -188 GPM,756 PSI -245 GPM,1177 PSI -354 GPM,1830 PSI -396 GPM,2158 PSI -460 GPM,2775 PSI -550 GPM,ICP:3650 PSI FCP:3392 PSI MUD WEIGHT 10.5 PPG IN,10.5 PPG OUT -150 RPM,8K TORQUE -RECIPROCATE PIPE 90' I-ECD:ACTUAL:11.19 PPG CALCULATED: 11.13 PPG Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP • Page 19 of 34 ' Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089;714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase • Description of Operations (hr) 1 1 (usft) 10:00 - 11:30 1.50 DRILL P 11 INTI PUMP OUT OF HOLE FROM 8,482'MD TO ITHRZ AT8,303'MD -MONITOR HOLE FOR 10 MINUTES PRIOR TO PULLING OFF BOTTOM:WELL STATIC i -PUMP OUT OF HOLE THROUGH THE TOP 1 HRZ AT 50'PER MIN I -P/U=180K,S/O=105K I -MUD WEIGHT:10.5 PPG IN,10.5 PPG OUT 1 -OBSERVE TIGHT SPOT AT THRZ AT 8,395'MD -WASH BACK TO BOTTOM AND PUMP BACK OUT AT 30 FT/MIN 11:30 - 15:30 4.00 DRILL P INTI PULL OUT OF HOLE ON ELEVATORS FROM I 8,303'MD TO 3,000'MD I-PULL OUT OF HOLE AT 60-90 FT/MIN 1-P/U=175K,5/0=110K 1-MUD WEIGHT:10.5 PPG IN,10.5 PPG OUT -MONITOR WELL FOR 10 MINUTES AT 8,303' I MD:WELL STATIC 1 -MONITOR WELL FOR 10 MINUTES AT WINDOW AT 3,020'MD:WELL STATIC - -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 15:30 - 17:00 1.50 DRILL P INTI PULL OUT OF HOLE ON ELEVATORS FROM "3,000'MD TO 600'MD PULL OUT OF HOLE AT 150 FT/MIN -P/U=90K,5/0=90K 1 -MUD WEIGHT:10.5 PPG IN,10.5 PPG OUT I-MONITOR WELL FOR 10 MINUTES AT WINDOW:WELL STATIC MONITOR WELL VIA TRIP TANK PROPER DISPLACEMENT 17:00 - 19:30 1 2.50 DRILL P INT1 I LAY DOWN 8.5"RSS DRILLING BHA#7 FROM 1600'MD TO SURFACE PJSM WITH SLB AND RIG CREW MONITOR WELL FOR 10 MINUTES BEFORE 1 PULLING BHA INTO STACK:WELL STATIC -LAYDOWN HWDPAND FLEX COLLARS -LAYDOWN BHA PER SLB DD/MWD I ,-BIT GRADE:1-2-BT-N-X-I-WT-TD I '-CLEAN AND CLEAR RIG FLOOR 19:30 - 21:00 1.50 BOPSUR P INTI CHANGE OUT UPPER PIPE RAM FROM 2-7/8" I X 5-1/2"VBRS TO 7" -CLOSE BLIND RAMS I-BARRIERS FOR RAM CHANGEOUT:KWF, BLIND RAMS I-PUMP OUT STACK -PULL 9-1/8"WEAR RING M/U 7"TEST JOINT -DE-ENERGIZE ACCUMULATOR -C/O RAMS FROM 2-7/8"X 5-1/2"VBRS TO 7" -RE-ENERGIZE ACCUMULATOR OPEN BLIND RAMS -BOP CONFIGURATION FROM TOP TO BOTTOM:ANNULAR PREVENTER,2-7/8"X 5" I VBRS,BLIND SHEAR RAMS,MUD CROSS,7" RAMS Printed 7/20/2015 10:46:22AM North America-ALASKA-BP Page 20 of 34 Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) I 21:00 - 22:00 1.00 BOPSUR , P INTI PRESSURE TEST7"CASING RAMS -INSTALL TEST PLUG AND 7"TEST JOINT -FILL STACK PRESSURE TEST UPPER 7"RAMS TO 250 PSI !LOW,3500 PSI HIGH FOR 5 MINUTES EACH -PERFORM WEEKLY BOP FUNCTION TEST i I-PULL TEST PLUG I-R/D TEST EQUIPMENT -CLEAN AND CLEAR RIG FLOOR 22:00 - 23:00 1.00 CASING P INTI RIG UP FOR 7"DUMMY RUN j I !-PICK UP 7"CASING HANGER AND LANDING JOINT !-RUN IN 44.92'TO LAND W I l PULL OUT OF HOLE AND LAYDON 7" HANGER AND LANDING JOINT 1 **SIMOPS** -STAGE DOYON CASING EQUIPMENT TO RIG FLOOR -RIG UP DOYON CASING EQUIPMENT 23:00 - 00:00 1.00 CASING PINTI RIG UP FOR 7"CASING RUN INSTALL LONG BAIL ONTO TOP DRIVE . -PJSM WITH DOYON CASING,FMC,AND RIG CREW -RIG UP VOLANT TOOL,BAIL EXTENSIONS, i I LAND ELEVATORS MAKE UP FOSV CROSSOVER -RIG UP HOLE FILL LINE 6/27/2015 00:00 - 01:00 1.00 CASING P INTI RIG UP TO RUN CASING -PJSM WITH DOYON,PARKER,WSL i REVIEWING PIPE COUNT,RUNNING ORDER, SAFETY,PRE-JOB ' -CONFIRM ELEVATOR&SLIP ID'S i 1 1 i I**SIMOPS:PRESSURE TEST CEMENT LINE TO 13500 PSI** Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP • Page 21 of 34 Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual c82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr)01:00 - 12:00 11.00 (usft) CASING p INTI RUN 7",26#,L-80,VAM TOP HC CASING FROM SURFACE TO 4,453'MD -BAKER LOC SHOE TRACK -CHECK FLOATS:HOLDING USE JET LUBE SEAL GUARD PIPE DOPE -TORQUE CONNECTIONS TO 11,950 FT-LBS -JOINT 1 CENTRALIZER LOCKED DOWN 5' FROM PIN JOINT 2 CENTRALIZER LOCKED DOWN MID JOINT I-RUN 1/JT FREE FLOATING STRAIGHT BLADE CENTRALIZERS ON JOINTS 3-36 PER ;PROGRAM RUN 2/JT FREE FLOATING WITH STOP RING i MID JOINT STRAIGHT BLADE CENTRLIZERS ON JOINTS 37-91 PER PROGRAM RUN IN CASED HOLE AT 60 FT/MIN FROM I SURFACE TO WINDOW I-CIRCULATE BOTTOMS UP AT WINDOW:283 GPM,550 PSI- -RUN IN OPEN HOLE AT 40-50 FT/MIN -BREAK CIRCULATION EVERY 10 JOINTS AT 126 GPM -FILL CASING ON THE FLY WITH FILL UP •HOSE -OBTAIN PU/SO WEIGHTS EVERY 10 JOINTS -MUD WEIGHT 10.4 PPG IN,10.4 PPG OUT 12:00 - 16:30 4.50 CASING P INTI RUN 7",26#,L-80,VAM TOP HC CASING FROM 4,453'MD TO 6,182'MD -USE JET LUBE SEAL GUARD PIPE DOPE -TORQUE CONNECTIONS TO 11,950 FT-LBS -RUN IN OPEN HOLE AT 40-50 FT/MIN -BREAK CIRCULATION EVERY 5 JOINTS AT 126 GPM FILL CASING ON THE FLY WITH FILL UP HOSE I-OBTAIN PU/SO WEIGHTS EVERY 10 JOINTS 17:30 1.00 CASING N RREP MUD WEIGHT 10.4 PPG IN,10.4 PPG OUT 16:30 6,200.00 INTI REPAIR PIPE SKATE FIX PIPE SKATE ROLLER WHEEL WORK PIPE 50'AND CIRCULATE AT 126 GPM,ICP:500 PSI FCP:384 PSI -P/U=150K,S/O=115K Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP • Page 22 of 34 Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To I Hrs Task I Code I NPT I NPT Depth I Phase I Description of Operations (hr) - (usft) _ 17:30 - 23:30 6.00 CASING P INTI I RUN 7",26#,L-80,VAM TOP HC CASING FROM 6,182'MD TO 8,405'MD i I-USE JET LUBE SEAL GUARD PIPE DOPE I -TORQUE CONNECTIONS TO 11,950 FT-LBS -RUN IN OPEN HOLE AT 40-50 FT/MIN I -BREAK CIRCULATION EVERY 10 JOINTS AT 1126 GPM FROM 6,200'MD TO 8,140'MD ' SI--WASH DOWN EVERY JOINT AT 126 GPM FOR I 10 MIN/JT FROM 8,140'MD TO 8,405'MD -PICK UP MANDREL HANGER AND LANDING I JOINT ' I-CIRCULATE LAST JOINT DOWN AT 84 GPM, I INDICATIONS OF FILL -LAND ON RING AT 8,480'MD -P/U=230K,S/O=130K -FILL CASING ON THE FLY WITH FILL UP i I I ' HOSE j I I-OBTAIN PU/SO-WEIGHTS EVERY 10 JOINTS MUD WEIGHT 10.4 PPG IN,10.4 PPG OUT TOTAL LOSSES WHILE RUN IN HOLE:25 BBLS 23:30 - 00:00 0.50 CASING P INTI I RIG SERVICE I LUBRICATE RIG l-SERVICE TOP DRIVE,BLOCKS,CROWN, i IAND RIG FLOOR EQUIPMENT I _ -GREASE WASHPIPE 6/28/2015 00:00 - 14:00 14.00 CASING P INTI CIRCULATE PRIOR TO CEMENT JOB -STAGE UP IN 21 GPM INCREMENTS TO 294 GPM -83 GPM,ICP:540 PSI,FCP:486 PSI -116 GPM,ICP:500 PSI,FCP:470 PSI 150 GPM,ICP:590 PSI,FCP:560 PSI -183 GPM,ICP:750 PSI,FCP:730 PSI 200 GPM,ICP:997 PSI,FCP:895 PSI 226 GPM,ICP:1003 PSI,FCP:986 PSI -250 GPM,PRESSURE IN EXCESS OF 1,100 I ' PSI,HOLE STARTING TO PACK OFF -AT INDICATIONS OF PACKOFF,STAGE I DOWN PUMPS AND STAGE PUMPS UP I SLOWLY CONDITION MUD PER MUD ENGINEER ' -RECIPROCATE PIPE 6'PLUS STRETCH 1 -MUD WEIGHT 10.4 PPG IN,10.4 PPG OUT -DISCUSS PACKOFF INDICATIONS, CIRCULATING RATES WITH ODE AND SLB -DECISION MADE TO RE-RUN CADE AND PERFORM CEMENT JOB AT 210 GPM Printed 7/20/2015 10:46:22AM 44,z 464,47,2 **14Z(/:, y�r 3r�fit Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12.00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum.S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 18:00 4.00 CEMT P INTI CEMENT 7"INTERMEDIATE CASING -PJSM WITH RIG CREWAND SLB CEMENTERS -REVIEW PRESSURE CROSSCHECK LIST -FILL LINES WITH WATER AND PRESSURE TEST TO 4000 PSI FOR 5 MINUTES -PUMP 50 BBLS OF 11.0 PPG MUDPUSH II SPACER AT 5.0 BPM -SHUT DOWN PUMPS,DISENGAGE VOLANT TOOL,AND EVACUATE 6 FT FLUID WITH RIG VAC -INSTALL BOTTOM PLUG WITH TEFLON PLUG TOOL AND VOLANT TOOL -PUMP 100.4 BBLS OF 11.5 PPG LITECRETE (40%EXCESS)AT 5 BPM:ICP 757 PSI,FCP 635 PSI -PUMP 19.1 BBLS OF 15.8 PPG CLASS G CEMENT(40%EXCESS)AT 5 BPM.ICP 760 PSI,FCP 625 PSI -CEMENT WET AT 14:13 -SHUT DOWN PUMPS,DISENGAGE VOLANT TOOL -INSTALL TOP PLUG WITH TEFLON PLUG TOOL AND VOLANT TOOL 4-SLB WASHUP WITH 10 BBLS WATER -PERFORM DISPLACEMENT WITH RIG PUMPS AND 10.4 PPG LSND MUD PER SLB CADE -DISPLACE 240 BBLS AT 5 BPM:ICP 640 PSI 10%RETURN FLOW,FCP 1075 PSI 100% RETURNS -DISPLACE 40 BBLS AT 4 BPM:ICP 985 PSI 9%RETURN FLOW,FCP 1025 PSI 100% RETURNS -DISPLACE 10 BBLS AT 3 BPM.ICP 770 PSI 7%RETURN FLOW,FCP 811 PSI 100% RETURNS -DISPLACE 21 BBLS AT 2 BPM:ICP 640 PSI 6%RETURN FLOW,FCP 780 PSI 100% RETURNS -BUMP PLUG AT 311 BBLS,800 PSI AND INCREASE PRESSURE TO 1400 PSI -STROKES TO PLUG BUMP 3350 -CHECK FLOATS:HOLDING -NO LOSSES AFTER CEMENT TURNED CORNER -TOTAL LOSSES DURING JOB:16 BBLS -BOTTOM WEATHERFORD PLUG BURST WITH 400 PSI OVER PUMP PRESSURE -CEMENT IN PLACE AT 17.05 18:00 - 19:00 1.00 CEMT P INTI PRESSURE TEST 7 CASING -PJSM WITH RIG CREW -PRESSURE TEST CASING TO 250 PSI LOW FOR 5 MIN AND 3500 PSI HIGH FOR 30 MINUTES -4.6 BBLS TO PRESSURE UP,4.6 BBLS BLEED BACK -LOST 20 PSI IN THE FIRST 15 MINUTES AND 10 PSI IN THE SECOND 15 MINUTES -TEST CHARTED AND ATTACHED -MADE NOTIFICATION TO WTLAND RECEIVED PERMISSION TO PROCEED Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP • Page 24 of 34 � I . ,,/,%;44,2,',4;,,. Operation Summary Report ""774/74,1110 '. „ ,. Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) ' Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12'00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual©82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) — (usft) 19:00 - 21:00 2.00 CEMT P INTI RIG DOWN FROM CEMENT JOB -BACKOUT AND LAY DOWN LANDING JOINT -RIG DOWN VOLANT TOOL !-SEND CASING RUNNING EQUIPMENT OFF I RIG FLOOR VIA TOOL CRANE ,-DRAIN STACK -CLEAN AND CLEAR RIG FLOOR 1 1 *SIMOPS** -LINE UP ON KILL LINE,CLOSE ANNULAR, PUMP DOWN OA THROUGH KILL LINE, BREAKOVER AT 760 PSI,INJECT 5 BBLS 21:00 - 23.00 ' 2.00 CEMT P INTI INSTALL AND PRESSURE TEST 7"PACKOFF i-INSTALL PACKOFF PER FMC REP RUN IN LOCKDOWN CREWS TO ENERGIZE SEAL(4.75"OUT,3.75"IN) GLAND NUTS TORQUED TO 420 FT-LBS, LOCKDOWN SCREWS TORQUED TO 450 FT-LBS -PRESSURE TEST PACKOFF TO 250 PSI LOW � I FOR 5 MINUTES AND 5000 PSI HIGH FOR 30 MINUTES 23:00 - 00:00 1.00 CEMT P INTI CHANGE OUT BOP RAMS CHANGE OUT UPPER RAMS FROM 7" I CASING RAMS TO 2-7/8"X 5-1/2"VBRS -BARRIERS FOR RAM CHANGE OUT:CLOSED BLINDS,KILL WEIGHT FLUID,TESTED 7" CASING 6/29/2015 00:00 - 02:00 2.00 CEMT P INTI RIG UP FOR BOP TEST -M/U TEST JOINT AND TEST PLUG -INSTALL TEST PLUG -RIG UP TEST EQUIPMENT -FILL STACK AND CHECK FOR LEAKS **SIMOPS** -LINE UP ON SECONDARY KILL LINE,PUMP DOWN OA,BREAKOVER AT 750 PSI,INJECT 2 BBLS 02:00 - 06:30 4.50 CEMT P INTI PRESSURE TEST BOP TEST BOP ACCORDING TO AOGCC,BP REGULATIONS AND PARKER PROCEDURES -PRESSURE TEST BOP RAMS TO 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH -PRESSURE TEST BOP ANNULAR i PREVENTOR TO 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH WITH 4"TEST JOINT -TEST UPPER AND LOWER VBRS WITH 4" AND 4.5"TEST JOINTS -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS -AOGCC REP JOHNNIE HILL WAIVED BOP TEST WITNESS -BOP CONFIGURATION FROM TOP TO BOTTOM:ANNULAR PREVENTOR, 2-7/8"X ! 5-1/2"VBRS,BLIND SHEAR RAMS,HCR/KILL LINE,2-7/8"X 5-1/2"VBRS I **SIMOPS** LINE UP ON SECONDARY KILL LINE,PUMP DOWN OA,BREAKOVER AT 750 PSI,INJECT 2.0 BBLS Printed 7/20/2015 10:46:22AM ,., s tion = Common Well Name:5-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time.4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual©82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 - 08:30 2.00 CEMT P INTI RIG DOWN FROM BOP TEST I-BLOW DOWN TEST EQUIPMENT PULL TEST PLUG 1-INSTALL 7-1/8"WEAR RING -R/D TEST EQUIPMENT L/D TEST JOINT CHANGE OUT LONG BAILS FOR 11'BAILS R/U 4"ELEVATORS **SIMOPS** -LINE OLIE, P DOWN UP OA,N BREAKOVERSECONDARY ATKILL 750 PSIN,INJECT 1.5 BBLS 08:30 11:00 2.50 CEMT P INTI 6-1 " _P PJSM PICK UP WITH/8RIG CREW DRILLING ANDBHA SLB DD/MWD -MAKE UP BHA PER SLB DD/MWD SURFACE TEST ARCHER PER SLB DD -P/U 38K,S/O 38K -6-1/8"SMITH PDC BIT,PD 475 ARCHER,PD FLEX COLLAR,PD RECEIVER,IMPULSE MWD 475,INLINE STAB,ADNVISION 475,(3)NM FLEX COLLAR,CROSSOVER 11.00 14:30 3.50 CEMT P INTI RUN IN HOLE WITH 6-1/8'DRILLING BHA#8 FROM 181'MD TO 1,580'MD -SINGLE INTO HOLE WITH 4"DP FROM PIPE SHED BREAK CIRCULATION EVERY 15 STANDS -MONITOR WELL VIA TRIP TANK.PROPER DISPLACEMENT SHALLOW HOLE TEST TOOL AT 1,580'MD -250 GPM,1470 PSI -220 GPM,1123 PSI -P/U 93K,S/O 82K -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT CALL ODE AND TOWN SLB TO DISCUSS HIGHER THAN EXPECTED SHALLOW HOLE TEST PRESSURES DECISION MADE TO PULL OUT OF HOLE AND CHANGE OUT BHA "SIMOPS" 500 PSI COMPRESSIVE STRENGTH REACHED AT 1140 AM FREEZE PROTECT 9-5/8"X 7"ANNULUS WITH LRS -PUMP 62 BBLS OF DEAD CRUDE AT 2 BPM, 780 PSI SHUT C -OA PRESSUREINANDSE710 PSI OA 14:30 - 16:00 1.50 CEMT N DFAL 1,580.00 INTI PULL OUT OF HOLE ON ELEVATORS FROM 1,580'MD TO 181'MD -PULL OUT OF HOLE TO INVESTIGATE BHA PRESSURE -MONITOR WELL FOR 10 MINUTES:WELL STATIC -RACK BACK 4"DP STANDS -P/U 40K,S/O 40K -HOLE TAKING PROPER DISPLACEMENT -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT Printed 7/20/2015 10.46:22AM . • North America-ALASKA-BP • Page 26 of 34 ,* Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 I End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. I UW:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 16:00 - 18:00 2.00 CEMT N DFAL 1,580.00 1 INTI LAY DOWN 6-1/8"DRILLING BHA#8 -FLOW CHECK WELL PRIOR TO PULLING INTO STACK:STATIC PJSM WITH RIG CREWAND SLB DD/MWD I-LAYDOWN BHA PER SLB DD/MWD '-RACK BACK FLEX COLLARS -LAYDOWN ADN,IMPULSE AND ARCHER 475 H NO OBSTRUCTION FOUND IN BHA OR BIT I -P/U STAND OF DP AND PUMP AT 500 GPM,60 PSI TO ENSURE PRESSURE NOT FROM I SURFACE SYSTEM 18:00 - 20:00 I 2.00 1 CEMT N DFAL 1,580.00 INTI PICK UP 6-1/8"DRILLING BHA#9 I-PJSM WITH RIG CREWAND SLB DD/MWD -MAKE UP BHA PER SLB DD/MWD SWAP TO BACK UP SLB,ADN,IMPULSE AND I !ARCHER 475 -SURFACE TEST ARCHER PER SLB DD -P/U 38K,S/O 38K -6-1/8"SMITH PDC BIT,PD 475 ARCHER,PD FLEX COLLAR,PD RECEIVER,IMPULSE MWD 475,INLINE STAB,ADNVISION 475,(3)NM FLEX COLLAR,CROSSOVER 20:00 - 22:00 2.00 CEMT 1 N DFAL 1,580.00 INTI I RUN IN HOLE WITH 6-1/8"DRILLING BHA#9 1 FROM 181'MD TO 1,580'MD -RIH WITH 4"DP STANDS -BREAK CIRCULATION EVERY 15 STANDS I- MONITOR WELL VIA TRIP TANK:PROPER I DISPLACEMENT SHALLOW HOLE TEST TOOL AT 1,580'MD -257 GPM,1450 PSI -220 GPM,1140 PSI -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT CALL ODE AND TOWN SLB TO DISCUSS I SHALLOW HOLE TEST PRESSURES 22:00 - 23:30 1.50 CEMT I P IINTI I RUN IN HOLE WITH 6-1/8"DRILLING BHA#9 FROM 1,580'MD TO 3,000'MD -RIH WITH 4"DP SINGLE FROM 1,580'MD TO I 3,000'MD -BREAK CIRCULATION EVERY 15 STANDS I I-MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 123:30 - 00:00 0.50 CEMT P INTI I RIG SERVICE GREASE WASHPIPE,BLOCKS,ROLLER ASSEMBLY,ST-80/CROWN CLUSTER 6/30/2015 00:00 - 04:00 4.00 CEMT 1 P INTI RUN IN HOLE WITH 6-1/8"DRILLING BHA#9 FROM 3,000'MD TO 6,100'MD I -RIH WITH 4"DP SINGLE FROM 3,000'MD TO 3,465'MD I1-RIH WITH 4"DP FROM DERRICK -BREAK CIRCULATION EVERY 15 STANDS II-MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 04 00 - 04 30 0.50 CEMT P INTI RIG SERVICE -CHANGE OUT WASHPIPE ON TOP DRIVE Printed 7/20/2015 10:46:22AM 410 North America-ALASKA BP;, Page 27 of 34 Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual©82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) + 04:30 - 08:00 3.50 CEMT N DFAL 8,482.00 INTI TROUBLESHOOT MWD SENSORS -VARY PUMP RATES FROM 100 GPM TO 276 GPM -WORK PIPE 90' -PUMP HIGH VIS PILL -CALL ODE TO DISCUSS 08:00 - 09:30 1.50 CEMT P INTI RUN IN HOLE WITH 6-1/8"DRILLING BHA#9 'FROM 6,100'MD TO 8,127'MD -RIH WITH 4"DP FROM DERRICK -BREAK CIRCULATION EVERY 15 STANDS -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 09.30 - 10:00 0.50 CEMT P INTI WASH DOWN FROM 8,127'MD TO 8,343'MD -250 GPM,1978 PSI -OBTAIN SLOW PUMP RATES AT 8,343'MD 10:00 11:00 1.00 CEMT P INTI REAM DOWN FROM 8,343'MD TO 8,393'MD -245 GPM,2550 PSI I � � -100 RPM,9K TORQUE -TAG CEMENT AT 8,343'MD -TAG PLUGS AT 8,392'MD -HARD CEMENT RETURNS COMING OVER SHAKERS HIGH MUD PH LEVEL RUBBER CHUNKS COMING OVER SHAKERS -MUD WEIGHT:10.4 PPG IN,10.2 PPG OUT 11:00 - 13:30 2.50 CEMT P ( INT1 DRILL OUT FLOAT COLLAR AND SHOE TRACK j FROM 8,393'MD TO 8,470'MD -250 GPM,1980 PSI -60 RPM,7K TORQUE -P/U 163K,S/O 101K,ROT 117K -HARD CEMENT RETURNS COMING OVER SHAKERS MUD WEIGHT:10.4 PPG IN,10.3 PPG OUT 13.30 - 14:30 1.00 CEMT P INTI CIRCULATE BOTTOMS UP AT 8,470'MD -250 GPM,1884 PSI -30 RPM,6k TORQUE -RECIPROCATE PIPE 90' -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 14:30 - 18:30 4.00 CEMT N DFAL 8,470.00 INTI PULL OUT OF HOLE WITH BHA#9 ON ELEVATORS FROM 8,470'MD TO 181'MD -PULL OUT OF HOLE TO INVESTIGATE MWD SENSOR FAILURE MONITOR WELL FOR 10 MINUTES:WELL STATIC -RACK BACK 4"DP STANDS -P/U 162K,S/O 102K -HOLE TAKING PROPER DISPLACEMENT -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 18:30 - 20:30 2.00 CEMT N DFAL j 8,470.00 INTI LAY DOWN 6-1/8"DRILLING BHA#9 -FLOW CHECK WELL PRIOR TO PULLING I INTO STACK:STATIC PJSM WITH RIG CREWAND SLB DD/MWD LAYDOWN BHA PER SLB DD/MWD -RACK BACK FLEX COLLARS -LAYDOWN ADN,IMPULSE AND ARCHER 475 -BIT GRADE 0-0 IN GAUGE Printed 7/20/2015 10:46 22AM • North America-ALASKA-BP • Page 28 of 34 Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date I From-To i Hrs Task Code I NPT j NPT Depth Phase I Description of Operations I (hr) (usft) 20:30 - 22:30 2.00 CEMT N DFAL 8,470.00 INTI PICK UP 6-1/8"DRILLING BHA#10 j I-PJSM WITH RIG CREWAND SLB DD/MWD i -MAKE UP BHA PER SLB DD/MWD -SWAP TO BACK UP SLB,ADN,IMPULSE AND ARCHER 475 -SURFACE TEST ARCHER PER SLB DD 1-P/U 38K,S/O 38K I-6-1/8"SMITH PDC BIT,PD 475 ARCHER,PD I FLEX COLLAR,PD RECEIVER,IMPULSE MWD 475,INLINE STAB,ADNVISION 475,(3)NM FLEX COLLAR,CROSSOVER 22:30 - 00:00 1.50 j CEMT N DFAL I 8,470.00 INTI I RUN IN HOLE WITH 6-1/8"DRILLING BHA#10 I FROM 181'MD TO 2,160'MD RIH WITH 4"DP STANDS I '-BREAK CIRCULATION EVERY 15 STANDS I I-MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT I-SHALLOW HOLE TEST TOOL AT 1,580'MD, GOOD TEST -249 GPM,1385 PSI }i-MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 7/1/2015 00:00 - 04:00 4.00 DRILL -N DFAL 8,470.0E I INTI I RUN IN HOLE WITH 6-1/8"DRILLING BHA#10 FROM 2,160'MD TO 8,470'MD -RIH WITH 4"DP FROM DERRICK -BREAK CIRCULATION EVERY 15 STANDS -MONITOR WELL VIA TRIP TANK:PROPER I DISPLACEMENT MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT I-WASH DOWN LAST STAND TAKE SPRS 04 00 - 06:00 2.00 , DRILL P 1 INTI DISPLACE WELLBORE FROM 10.4 PPG LSND I TO 10.4 PPG FLO-PRO NT MUD -250 GPM,2057 PSI ROTATE 80 RPM,RECIPROCATE PIPE 90 FT I I-PUMP 20 BBL STEEL LUBE PILL,PUMP 40 I BBL HI-VIS SPACER FOLLOWED BY 10.4 PPG FLO-PRO MUD I -TORQUE DECREASE FROM 8.5K TO 5.5K I-P/U 193K,S/O 149K -OBTAIN SPR WITH 10.4 PPG FLO-PRO I-MONITOR WELL FOR 10 MINUTES:WELL ISTATIC ,- 06 00 - 07:00 1.00 DRILL P INTI CUT AND SLIP DRILLING LINE PJSM WITH RIG CREW I 1 -CUT AND SLIP 68 FT OF DRILLING LINE,8 I WRAPS INSPECT DERRICK GREASE WASHPIPE 07.00 - 08:30 1.50 1 DRILL P INTI CHANGE OUT SAVER SUB -PJSM WITH RIG CREW -CHANGE OUT XT-39 SAVER SUB DRILL CALIBRATE BLOCKS 0.50 08:30 - 09:00 P INTI CIRCULATE AND CONDITION MUD ENSURE 10.4 PPG ALL THE WAY AROUND PRIOR TO DRILLING OUT -P/U 150K,S/O 106K Printed 7/20/2015 10.46:22AM • North America-ALASKA-BP • Page 29 of 34 Operation Summary Report Common Well Name.S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual t 82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 10:00 1.00 DRILL P INTI DRILL 6-1/8"PRODUCTION HOLE FROM 8,470' MD TO 8,486'MD 1-DRILL REMAINING SHOE TRACK AND 4'OF NEW FORMATION -270 GPM,2328 PSI 60 RPM,7K TORQUE ON,5K TORQUE OFF P/U 151K,S/O 106K,ROT 116K MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 10:00 - 12:00 2.00 DRILL N RREP 8,486.00 INTI REPAIR TOP DRIVE HYDRAULIC LINE FAILURE CHANGE OUT HYDRAULIC LINE 12:00 - 12:30 0.50 DRILL P INTI DRILL 6-1/8"PRODUCTION HOLE FROM 8,486' MD TO 8,503'MD -DRILL 17'OF NEW FORMATION(21'TOTAL) -270 GPM,2328 PSI -60 RPM,7K TORQUE ON,5K TORQUE OFF P/U 151K,S/O 106K,ROT 116K MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 12:30 - 13:30 1.00 DRILL P INTI CIRCULATE BOTTOMS UP 1-275 GPM,2400 PSI -30 RPM,6K TORQUE -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 13:30 - 14:00 0.50 EVAL P INTI RIG UP AND PERFORM FIT MUD WEIGHT:10.4 PPG,6,770'TVD,8,480' MD -PUMP 0.75 BBLS TO 669 PSI,BLEED BACK 0.6 BBLS -LOTEMW=12.30PPG **OBTAIN APPROVAL FROM ODE TO PROCEED** 14:00 - 23:30 9.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 8,503' MD TO 8,915'MD(6846'TVD) -275 GPM,2570 PSI -80 RPM,8K TORQUE ON,8K TORQUE OFF -P/U 174K,S/O 99K,ROT 116K -SURVEY EVERY 30 FT -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -PUMP LOW VIS/HI VIS SWEEP AT 8,675'MD, NO SIGNIFICANT INCREASE IN RETURNS -ACTUAL ROTATE TIME:7.25 HRS -TOTAL BIT TIME:7.25 HRS -TOTAL JAR TIME:7.25 HRS **TOTAL DAILY LOSSES TO FORMATION=10 BBLS** 23:30 - 00:00 0.50 DRILL P PROD1 RIG SERVICE I-GREASE WASHPIE,BLOCKS,ROLLER ASSEMBLY Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP • Page 30 of 34 Operation Summary Report f� „r Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016T1-1-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 1 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) T (usft) 7/2/2015 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 8,915' MD TO 9,596'MD(6731'TVD) -272 GPM,2624 PSI -80 RPM,9K TORQUE ON,BK TORQUE OFF P/U 171K,S/O 95K,ROT 114K -SURVEY EVERY 30 FT -WIPE WITH PUMPS 20 FT PRIOR TO CONNECTIONS -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT ACTUAL ROTATE TIME:8.89 HRS -TOTAL BIT TIME:16.1 HRS -TOTAL JAR TIME:16.1 HRS -FORAMTION LOSSES:6 BBLS 12:00 - 23:30 11.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 9,596' MD TO 10,220'MD(6751'TVD) -272 GPM,2480 PSI -80 RPM,10K TORQUE ON,8K TORQUE OFF P/U 189K,S/O 91K,ROT 113K -SURVEY EVERY 90 FT -WIPE WITH PUMPS 20 FT PRIOR TO I CONNECTIONS I-MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT CROSSED FAULT#1 AT 10,130'MD -ACTUAL ROTATE TIME:8.74 HRS -TOTAL BIT TIME:24.88 HRS -TOTAL JAR TIME:24.88 HRS -FORMATION LOSSES:10 BBLS 23:30 - 00:00 0.50 DRILL P PROD1 RIG SERVICE -GREASE WASHPIPE,BLOCKS,ROLLERS, AND CROWN -DERRICK INSPECTION 7/3/2015 00:00 - 06:00 6.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 10,220'MD TO 11,057'MD(6712'TVD) -272 GPM,2562 PSI 80 RPM,10K TORQUE ON,9K TORQUE OFF -P/U 192K,S/O 95K,ROT 114K -SURVEY EVERY 90 FT 1-WIPE WITH PUMPS 20 FT PRIOR TO CONNECTIONS -MUD WEIGHT:10.4 PPG IN,10.5 PPG OUT -ACTUAL ROTATE TIME:9.29 HRS TOTAL BIT TIME:34.17 HRS I-TOTAL JAR TIME:34.17 HRS -FORMATION LOSSES:7 BBLS 06:00 - 14:30 8.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 11,057'MD TO 11,250'MD(6714'TVD) -272 GPM,2562 PSI -80 RPM,10K TORQUE ON,9K TORQUE OFF -P/U 192K,S/O 95K,ROT 114K -SURVEY EVERY 90 FT -WIPE WITH PUMPS 20 FT PRIOR TO I CONNECTIONS !-MUD WEIGHT:10.4 PPG IN,10.5 PPG OUT -ACTUAL ROTATE TIME.2.0 HRS -TOTAL BIT TIME:36.2 HRS -TOTAL JAR TIME:36.2 HRS Printed 7/20/2015 10:46:22AM North America-ALASKA-BP I Page 31 of 34 Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 15:30 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP 11,250'MD CIRCULATE 1X BOTTOMS UP AT TD -270 GPM,2575 PSI -150 RPM,10K TORQUE -MUD WEIGHT:10.4 PPG IN,10.5 PPG OUT -RECIPROCATE PIPE 30 FT -MONITOR WELL FOR 10 MINUTES:FLUID FALLING 15:30 - 21:30 6.00 DRILL P PROD1 BACKREAM OUT OF HOLE FROM 11,250'MD TO 9,160'MD 272 GPM,2575 PSI 80 RPM,9K TORQUE BACKREAM AT 1000 FT/HR 4-6 BBUHR LOSS RATE 21:30 - 22:30 1.00 DRILL P , PROD1 TMAD PASS FROM 9,160'MD TO 9,020'MD -MAD PASS AT 600 FT/HR -260 GPM,2190 PSI -110 RPM,8K TORQUE 22:30 - 00:00 1.50 DRILL P PROD1 MAD PASS THROUGH TIGHT HOLE FROM 9,020'MD TO 9,000'MD -HOLE SHOWING INDICATIONS OF PACKOFF, PRESSURE SPIKES 200-300 PSI -TORQUE SPIKES FROM 8K TO 16K WHEN PACKOFF ENCOUNTERED,STALLS TOP DRIVE RIH AND REDUCE PUMP RATE WHEN PACKOFF ENCOUNTERED REDUCE BACKREAMING SPEED TO 30-90 FT/HR -260 GPM,2190 PSI -30-80 RPM,8K TORQUE -MAD PASS REQUIRES MINIMUM OF 40 RPM AND 190 GPM -WORK PIPE THROUGH TIGHT AREA WITH PUMPS OFF,20-30K DRAG -WIPED THROUGH TWICE -SHALE CUTTINGS COMING OVER SHAKERS I,**TOTAL LOSSES TO FORMATION:27 BBLS** 7/4/2015 00:00 - 01:00 1.00 DRILLP PROD1 MAD PASS THROUGH TIGHT HOLE FROM i 9,000'MD TO 8,960'MD HOLE SHOWING INDICATIONS OF PACKOFF, PRESSURE SPIKES 200-300 PSI -TORQUE SPIKES FROM 8K TO 16K WHEN •PACKOFF ENCOUNTERED,STALLING TOP DRIVE -RIH AND REDUCE PUMP RATE WHEN PACKOFF ENCOUNTERED REDUCE BACKREAMING SPEED TO 30-90 FT/HR -260 GPM,2190 PSI I-30-80 RPM,8K TORQUE -MAD PASS REQUIRES MINIMUM OF 40 RPM AND 190 GPM -WORK PIPE THROUGH TIGHT AREA WITH PUMPS OFF,20-30K DRAG WIPED THROUGH TWICE -AT 8,955'MD TORQUE AND PRESSURE RETURNED TO NORMAL SHALE CUTTINGS COMING OVER SHAKERS Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP S Page 32 of 34 Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Task Code NPT NPT Depth Phase Description of Operations s Date From-To (hr) (usft) 01:00 - 02:00 1.00 DRILL P PROD1 MAD PASS FROM 8,960'MD TO 8,870'MD -260 GPM,2125 PSI !-80 RPM,8K TORQUE MAD PASS AT 600 FT/MIN 02:00 - 05:30 3.50 DRILL P PROD1 MAD PASS THROUGH TIGHT HOLE FROM 8,870'MD TO 8,780'MD •-HOLE SHOWING INDICATIONS OF PACKOFF, `PRESSURE SPIKES 200-300 PSI '-TORQUE SPIKES FROM 8K TO 16K WHEN 'PACKOFF ENCOUNTERED -WORK PIPE THROUGH TIGHT AREA WITH PUMPS OFF,20-30K DRAG -PACKOFF LESS SEVERE WITH LOWER FLOW RATE -210 GPM,1650 PSI i -210 RPM,8K TORQUE I-SHALE CUTTINGS COMING OVER SHAKERS 05:30 - 07:30 2.00 DRILL P PROD1 PULL OUT HOLE ON ELEVATORS WITH 6-1/8" DRILLING BHA FROM 8,780'MD TO 8,480'MD -WORK THROUGH TIGHT SPOT AT 8,695'MD, I40 OVERPULL - ATTEMPT TO WORK THROUGH TIGHT SPOT AT 8,640'MD SCREW INTO STAND AND ATTEMPT TO PUMP OUT,HOLE PACKING OFF WORK THROUGH STAND ON ELEVATORS WITH 40K OVERPULL ATTEMPT TO WORK THROUGH TIGHT SPOT AT 8,550'MD WITH NO SUCCESS ATTEMPT TO WORK THROUGH WITH PUMPS ON AT 200 GPM,1380 PSI WITH NO SUCCESS -OVERPULL 40K WITH NO PACKOFF -WORK THROUGH TIGHT SPOT AT 200 GPM, 1400 PSI,20 RPM,7-11K TORQUE 07:30 - 08:30 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP 8,480'MD -CIRCULATE 1.5X BOTTOMS UP AT 7"CASING 1 ,SHOE -260 GPM,2190 PSI -80 RPM,8K TORQUE -RECIPROCATE PIPE 90 FT -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -MONITOR WELL FOR 10 MINUTES:WELL STATIC 08:30 - 09:000.50 DRILL PROD1 I RIG SERVICE P � -SERVICE TOP DRIVE,INSPECT DERRICK 09:00 - 09:30 0.50 DRILL P PROD1 RUN IN HOLE ON ELEVATORS WITH 6-1/8" DRILLING BHA FROM 8,480'MD TO 9,039'MD -RUN IN HOLE 6 STANDS TO GAUGE HOLE CONDITION -P/U 175K,S/O 98K -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP • Page 33 of 34 Operation Summary Report Common Well Name:S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM I Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. 1 UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) P (usft)__-1 09:30 - 10:00 0.50 DRILL PROD1 I PULL OUT OF HOLE ON ELEVATORS WITH 6-1/8"DRILLING BHA FROM 9,039'MD TO 8,480'MD PULL BACK INTO THE 7"CASING SHOE TO !GAUGE HOLE CONDITION 1 -MONITOR WELL FOR 10 MINUTES:WELL I STATIC P/U 175K,S/O 98K f ' MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 10:00 - 12:00 2.00 DRILL P PROD1 RUN IN HOLE ON ELEVATORS WITH 6-1/8" DRILLING BHA FROM 8,470'MD TO 11,250'MD -RUN BACK TO TD FOR WIPER TRIP#1 I P/U 185K,S/O 94K I i -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT' 12:00 - 15:00 3.00 DRILL P PROD1 CIRCULATE BOTTOMS UP 11,250'MD INO FILL ON BOTTOM I I ; CIRCULATE 3X BOTTOMS UP AT TD 1 ' -272 GPM,2600 PSI 1 -150 RPM,9K TORQUE ' -RECIPROCATE PIPE 40 FT -PUMP LOW VIS/HIGH VIS SWEEP -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT - MONITOR WELL FOR 10 MINUTES:WELL STATIC 15:00 - 18:00 3.00 DRILL P PROD1 I PULL OUT OF HOLE ON ELEVATORS WITH 6-1/8"DRILLING BHA FROM 11,250'MD TO 8,480'MD -TRIP BACK INTO THE 7"CASING SHOE FOR WIPER TRIP#2 MONITOR WELL FOR 10 MINUTES:WELL STATIC I P/U 195K,SIO 92K -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT MONITOR WELL VIA TRIP TANK PROPER : DISPLACEMENT -BROOMSTICK SHOWING HIGH FRICTION FACTOR,DISCUSS WITH ODE 18:00 - 19:00 1.00 DRILL II P PROD1 CIRCULATE BOTTOMS UP 8,480'MD 1 I-CIRCULATE IX BOTTOMS UP AT7"SHOE I-MONITOR WELL FOR 10 MINUTES:WELL STATIC -272 GPM,2130 PSI -80 RPM,7K TORQUE RECIPROCATE PIPE 90 FT MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 19:00 - 21:00 2.00 DRILL P PROD1 RUN IN HOLE ON ELEVATORS WITH 6-1/8" DRILLING BHA FROM 8,480'MD TO 11,250'MD RUN BACK TO TD FOR WIPER TRIP#2 -BREAK CIRCULATION EVERY 15 STANDS, 190 GPM,1470 PSI -P/U 195K,S/O 92K -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -MONITOR WELL VIA TRIP TANK PROPER DISPLACEMENT Printed 7/20/2015 10:46:22AM • North America-ALASKA-BP . Page 34 of 34 ''0:03,VAr.;/14ree:SiWPOWfica% Operation Summary Report Common Well Name S-42 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/14/2015 End Date:7/5/2015 X3-016TH-C:(8,089,714.00) Project:Prudhoe Bay 1 Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time 4/4/1996 12'00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 1 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase I Description of Operations 21:00 - 22:30 1.50 DRILL P (usft) 1 PROD1 1CIRCULATE BOTTOMS UP 11,250'MD -CIRCULATE 2X BOTTOMS UP AT TD -272 GPM,2600 PSI 1 150 RPM,9K TORQUE 1 -RECIPROCATE PIPE 40 FT -PUMP 30 BBL HI VIS SWEEP,NO INCREASE 1 1IN CUTTINGS _ �-MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT ---1- 122:30 - 00:00 1.50 DRILL P PROD1 PULL OUT OF HOLE ON ELEVATORS WITH j 6-1/8"DRILLING BHA FROM 11,250'MD TO 1 [ 10,655'MD -FINAL TRIP OUT OF THE HOLE -MONITOR WELL FOR 10 MINUTES:WELL STATIC P/U 195K,S/O 92K -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -SIGNS OF DIFFERENTIAL STICKING IF DRILL !STRING SITS FOR MORE THAN 3-5 MINUTES **TOTAL LOSSES TO FORMATION:18 BBLS** 7/5/2015 00:00 - 01:30 1.50 DRILL P ' PROD1 I PULL OUT OF HOLE ON ELEVATORS WITH I, 6-1/8"DRILLING BHA FROM 10,655'MD TO 1 1 8,480'MD -P/U 178K,S/O 100K -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 1 01:30 02:30 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP 8,480'MD MONITOR WELL FOR 10 MINUTES:WELL STATIC -CIRCULATE 1X BOTTOMS UP AT 7"CASING SHOE -272 GPM,2311 PSI -80 RPM,8K TORQUE -RECIPROCATE PIPE 90 FT -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 02:30 - 08:00 5.50 j DRILL P PROD1 PULL OUT OF HOLE ON ELEVATORS WITH 1 6-1/8"DRILLING BHA FROM 8,480'MD TO 183' 1 MD I-MONITOR WELL FOR 10 MINUTES:WELL 'STATIC -DRIFTED DRILL STRING TO 2-3/8" 1 i -P/U 74K,S/O 74K j -LAYDOWN HWDPAND JARS -FUNCTION TEST BOP 1-MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT 1-MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 08:00 - 10:00 2.00 DRILL P 1 PROD1 I LAY DOWN 6-1/8"DRILLING BHA#10 1-FLOW CHECK WELL PRIOR TO PULLING INTO STACK:STATIC -PJSM WITH RIG CREWAND SLB DD/MWD LAYDOWN BHA PER SLB DD/MWD LAYDOWN FLEX COLLARS BIT GRADE 0-0-WT-A-X-I-NO-TD CLEAN AND CLEAR RIG FLOOR I -INSPECT SAVER SUB -FUNCTION TEST BLINDS **SWITCH TO CON EVENT ON 07/05/2015 AT 10:00 AM** Printed 7/20/2015 10:46:22AM • • North America-ALASKA-BP Page 1 of 7 Operation Summary Report Common Well Name:S-42 AFE No Event Type:COM-ONSHORE(CON) 1 Start Date:7/5/2015 End Date:7/9/2015 X3-016TH-C:(2,911,773.00) I Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual(g82.68usft(above Mean Sea Level) Date From-To 11 Hrs Task Code NPT : NPT Depth Phase Description of Operations (hr) (usft) L- 7/5/2015 10:00 - 11:30 1.50 CASING P I RUNPRD 1 RIG UP FOR 4-1/2"LINER RUN 1-PJSM WITH DOYON CASING AND RIG CREW RIG UP DOYON CASING EQUIPMENT -CONFIRM ELEVATOR AND SLIP ID _ _ INSPECT 4-1/2"SAVER SUB '11:30 - 20:30 9.00 CASING P RUNPRD RUN 4-1/2",13.5#,13CR HYDRIL LINER FROM I SURFACE TO 2,936'MD -PJSM WITH RIG CREW,DOYON CASING, BAKER,HALLIBURTON,AND SLB REPS BAKER ALL CONNECTIONS BELOW THE WIV CHECK FLOATS:HOLDING USE LET LUBE SEAL GUARD PIPE DOPE ' 1-TORQUE HYDRIL CONNECTIONS TO 4,700 FT-LBS -RUN 1 CENTRALIZER LOCKED DOWN 5' !FROM SHOE ! -RUN 1 CENTRALIZER FREE FLOATING ON 120'FLOAT COLLAR PUP RUN FLOATING CENTRALIZERS ON JOINTS 11-55 -FILL CASING ON THE FLY AND TOP OFF I EVERY 10 JOINTS I -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 1-RUN 1 HES ANCHOR PACKER -RUN 1 BKR WIV -RUN 1 BKR SNS 1-RUN 7 TOTAL SLB FRAC PORTS -RUN 7 HES SWELL PACKERS -RUN IN HOLE AT 90 FT/MIN I-MAKEUP LINER HANGER/PACKER PER I BAKER REP I 1-ADD PAL MIX ' I-CIRCULATE 1.5X LINER VOLUME AT 3 BPM, 412 PSI 20:30 - 00:00 3.50 CASING P RUNPRD RUN 4-1/2",13.5#,13CR HYDRIL LINER FROM I 12936'MD TO 7,550'MD -RUN IN WITH 4"DRILL PIPE FROM DERRICK -RUN IN CASED HOLE AT 90 FT/MIN I I-FILL STANDS ON THE FLY AND TOP OFF EVERY 10 1-MONITOR WELL VIA TRIP TANK:PROPER I DISPLACEMENT 7/6/2015 00:00 - 01:30 1.50 ; CASING P 1 RUNPRD RUN 4-1/2",13.5#,13CR HYDRIL LINER FROM 7,550'MD TO 8,480'MD I RUN IN WITH 4"DRILL PIPE FROM DERRICK RUN IN CASED HOLE AT 90 FT/MIN FILL STANDS ON THE FLY AND TOP OFF EVERY 10 -MONITOR WELL VIA TRIP TANK PROPER I DISPLACEMENT I -CIRCULATE 1.5X LINER AND DRILL PIPE I VOLUME AT THE 7"CASING SHOE,3 BPM,740 ' I 1 PSI -P/U 132K,S/O 98K 10 RPM,5.2K TORQUE -20 RPM,5.6 TORQUE Printed 7/20/2015 10:47 16AM Pae2of7 North America-ALASKA BP 110 � g Operation Summary Report ry Common Well Name:S-42 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/5/2015 End Date:7/9/2015 X3-016TH-C:(2,911,773.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 04:30 3.00 CASING P RUNPRD RUN 4-1/2",13.5#,13CR HYDRIL LINER FROM 8,480'MD TO 11,248'MD RUN IN WITH 4"DRILL PIPE FROM DERRICK i I -RUN IN OPEN HOLE AT 60 FT/MIN I-FILL STANDS ON THE FLY AND TOP OFF EVERY 10 STANDS,3 BPM FOR 5 MINUTES -OBTAIN DOWN WEIGHTS EVERY 10 STANDS MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT OBSERVE GRADUAL REDUCTION IN STRING WEIGHT I-CALL ODE TO DISCUSS PUTTING TORQUE INTO THE STRING 11,000'MD 10 RPM,8.5K TORQUE 2 BPM,1078 PSI -STRING WEIGHT RETURNED WHILE ROTATING -ATTEMPT TO WORK DOWN ON ELEVATORS, LOST STRING WEIGHT ROTATED LINER DOWN TO 11,210'MD AT 10 RPM I-REGAINED STRING WEIGHT AND WASHED LINER TO BOTTOM I-TAG BOTTOM AT 11,250'MD I-PICK UP 2'MD P/U 160K,S/O 69K -LINER SET AT 11,248'MD -LINER TOP PACKER SET AT 8,319'MD 04:30 - 06:30 2.00 CASING P RUNPRD DISPLACE 4-1/2"LINER FROM 10.4 PPG FLO-PRO TO 10.4 PPG LOW SALINITY WBM STAGE UP PUMPS TO 3.5 BPM,1050 PSI I-PUMP 30 BBL,10.4 PPG LOW SALINITY I HI-VIS SPACER -PUMP 75 BBL LOW SALINITY 10.4 WBM -PUMP 20 BBL,10.4 PPG LOW SALINITY HI-VIS PILL DROP 1-7/16"BAKER BALL I-PUMP 15 BBL,10.4 PPG LOW SALINITY HI-VIS PILL -PUMP 135 BBL LOW SALINITY DISPLACEMENT FLUID -1-7/16"BALL LANDS IN WIVAT 1250 STROKES 06:30 - 07:30 1.00 CASING P RUNPRD SET BAKER HRD-E ZXP PACKER PER BAKER REP -PRESSURE UP TO 2800 PSI TO SET LINER HANGER. SLACK-OFF 50K TO CONFIRM HANGER SET. INCREASE PRESSURE TO 4,450 PSI TO RELEASE HRD-E LINER RUNNING TOOL. -PICK UP 5'TO EXPOSE DOG SUB. SLACK-OFF 25K TO SET ZXP PACKER& GOOD SURFACE INDICATION THAT PACKER SET -P/U AND REPEAT WITH 15 RPM,5K TORQUE Printed 7/20/2015 10:47:16AM • North America-ALASKA-BP S Page 3 of 7 Operation Summary Report Common Well Name:S-42 AFE No Event Type:COM-ONSHORE(CON) ; Start Date:7/5/2015 End Date:7/9/2015 X3-016TH-C:(2,911,773.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual(q)82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations 1 I (hr) , (usft) i i 07:30 - 10:30 3.00 CASING N SFAL 11,250.00 ! RUNPRD ATTEMPT TO MIT 7"L-80 26#CASING AND BAKER 7"X 4-1/2"LINER TOP I-REVIEW PRESSURE CROSSCHECK LIST WITH BP,PARKER,BAKER -RIG UP TO PRESSURE TEST , -LINE UP TO KILL LINE AND FLUID PACK LINES j -CLOSE ANNULAR -250 PSI LOW FOR 5 MINS 3500 PSI HIGH FOR 30 MINS, PRESSURE LOSS IN SECOND 15 GREATER i THAN HALF PRESSURE LOSS IN FIRST 15 1 1 f MIN. -ATTEMPT SECOND TEST WITH SIMILAR RESULTS.CALL ODE TO DISCUSS AND DECISION MADE TO UNSTING. UNSTING AND ATTEMPT TO PRESSURE TEST LINER TOP PACKER.TEST TO 250 LOW, PRESSURE BLEEDING OFF !-CALL ODE TO DISCUSS,DECISION TO DISPLACE WELL TO 10.3 PPG BRINE 10:30 - 12:00 1.50 CASING P RUNPRD 1 DISPLACE WELL TO BRINE -PICKUP ABOVE LINER TOP TO 8,300'MD --TOP OF LINER AT 8,319'MD MARK NO GO DISPLACE FROM 10.4 PPG FLO-PRO TO 10.3 PPG BRINE ' -PUMP 30 BBL HI VIS PILL -10.3 PPG BRINE SURFACE TO SURFACE PUMP 300 GPM,1160 PSI 12:00 - 13:30 1.50 CASING P RUNPRD MIT 7"L-80 26#CASING,4.5"SWELL PACKER LINER AND BAKER 7"X 4-1/2"LINER TOP REVIEW PRESSURE CROSSCHECK LIST WITH BP,PARKER,BAKER I-RIG UP TO PRESSURE TEST i-LINE UP TO KILL LINE AND FLUID PACK LINES 1-CLOSE UPPER RAMS -250 PSI LOW FOR 5 MINS -3500 PSI HIGH FOR 30 MINS,4.9 BBLS I !PUMPED ! ! -TEST MEETS BP STP CRT-AK-10-45 CRITERIA '-TEST CHARTED AND ATTACHED -BLEED OFF PRESSURE,4.9 BBL'S BLED BACK R/D TEST EQUIPMENT 13:30 - 19:30 6.00 CASING P RUNPRD PULL OUT OF HOLE WITH LINER RUNNING TOOL FROM 8319'MD TO 2420'MD -MONITOR WELL FOR 10 MINUTES:WELL IS STATIC -MUD WEIGHT:10.3 PPG IN,10.3 PPG OUT -PULL OUT OF HOLE ON ELEVATORS L/D DP SINGLES TO PIPE SHED -MONITOR TRIP VIA TRIP TANK PROPER DISPLACEMENT 19:30 - 20:00 0.50 CASING P RUNPRD RIG SERVICE ' -CHANGE OUT 0-RING ON PIPE SKATE GREASE PIPE SKATE Printed 7/20/2015 10:47:16AM • North America ALASKA BP Page Operation Summary Report 7 Common Well Name S-42 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/5/2015 End Date 7/9/2015 X3-016TH-C:(2,911,773.00) Project:Prudhoe Bay T Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. l UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth ' Phase I Description of Operations I (hr) (usft) 20:00 - 21:00 1.00 CASING P RUNPRD H2S DRILL H2S ALARM IN BOP DECK SECURE WELL AND EVACUATE RIG I [-MAKE NOTIFICATIONS TO PAD OPERATOR, SUPERINTENDENT,WTL -RIG MANAGER AND DRILLER WEAR SCBA AND SWEEP RIG I-VERIFY ZERO PPM H2S AND FAULTY ' I SENSOR -APPROVAL FROM WTLAND SUPERINTENDENT TO RE-ENTER RIG I -CHANGE OUT H2S SENSOR AND TEST SAME.GOOD TEST ,-REFER TO TRACTION ITEM IR-5041177 21:00 - 23:00 2.00 CASING P RUNPRD !PULL OUT OF HOLE WITH LINER RUNNING ' ', I TOOL FROM 2420'MD TO SURFACE , -MUD WEIGHT:10.3 PPG IN,10.3 PPG OUT -PULL OUT OF HOLE ON ELEVATORS I ` -L/D DP SINGLES TO PIPE SHED -MONITOR TRIP VIA TRIP TANK PROPER 'DISPLACEMENT 23:00 - 00:00 , 1.00 1 CASING P RUNPRD LAY DOWN LINER RUNNING TOOL -L/D BUMPER SUB AND RUNNING TOOL AS I `PER BAKER REP '-VERIFY DOG SUB SHEARED -VERIFY SEALS INTACT '-CLEAN AND CLEAR RIG FLOOR 7/7/2015 00:00 - 03:00 3.00 RUNCOM ' P RUNCMP RIG UP TO RUN 4-1/2"VAM TOP COMPLETION j -MAKE UP WEAR RING RUNNING TOOL -PULL WEAR RING I i -CHANGE OUT PS-21 SLIPS TO AIR SLIPS -CHANGE OUT 4"DRILL PIPE ELEVATORS TO 4-1/2"MANUAL ELEVATORS RIG UP 4-1/2"DOYON CASING TONGS ' 1 -CONFIRM FOSV X/O IS ON THE RIG FLOOR 03 00 - 04.00 1.00 RUNCOM P RUNCMP RUN IN HOLE WITH 4-1/2"12.6#13CR-85 VAM TOP TUBING FROM SURFACE TO 250'MD I -MAKE UP WLEG WITH X NIPPLE AND RHC I PLUG -MAKE UP 7"X 4-1/2"HES TNT PACKER TO X-NIPPLE I BAKER LOCK CONNECTIONS BELOW PACKER -MAKE UP WITH TORQUE TURN TO 4,440 FT/LBS ,-USE JET LUBE SEAL GUARD ON VAM TOP THREADS I-MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT 04.00 - 05:00 1.00 RUNCOM P ' RUNCMP PRESSURE TEST SAPPHIRE GAUGE SUB -RIG UP I-WIRE AND PRESSURE GAUGE I I -INSTALL PRESSURE GAUGE INTO SUB -PRESSURE TEST GAUGE SUB TO 5000 PSI FOR 10 MINUTES -INSTALL I-WIRE CLAMPS Printed 7/20/2015 10.47:16AM • North America-ALASKA-BP 0 Page 6 oY 7 Operation Summary Report Common Well Name:S-42 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/5/2015 End Date:7/9/2015 X3-016TH-C:(2,911,773.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 12:00 7.00 RUNCOM P RUNCMP RUN IN HOLE WITH 4-1/2"12.6#13CR-85 VAM TOP TUBING FROM 250'MD TO 4300'MD -RIH PICKING UP TUBING AS PER RUNNING ORDER. -RUN I-WIRE FROM GAUGE SUB TO SURFACE -MAKE UP WITH TORQUE TURN TO 4,440 FT/LBS -USE JET LUBE SEAL GUARD ON VAM TOP THREADS MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT 12:00 - 19:30 7.50 RUNCOM P RUNCMP RUN IN HOLE WITH 4-1/2"12.6#13CR-85 VAM TOP TUBING FROM 4300'MD TO 8328'MD -RUN I-WIRE FROM GAUGE SUB TO SURFACE -RIH @ 90 FT/MIN -MAKE UP WITH TORQUE TURN TO 4,440 FT/LBS -USE JET LUBE SEAL GUARD ON VAM TOP THREADS -MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT 19:30 - 20:30 1.00 RUNCOM P RUNCMP .TAG UP ON NO/GO SPACE OUT TUBING. -TAG UP ON NO/GO AT 8334' - LAY DOWN 3 JOINTS OF TUBING. -PICK UP 2 PUPS FOR SPACE OUT OF WLEG -PICK UP JOINT RIH. 20:30 - 23:30 3.00 RUNCOM P RUNCMP PICK UP LANDING JOINT AND MAKE UP HANGER. -MAKE UP HANGER TO LANDING JOINT. -CUT I WIRE AND INSTALL IN HANGER.WITH FMC FITTINGS -TOTAL CLAMPS INSTALLED 197 CROSS COLLAR CLAMPS#4500-A-07 -TEST I WIRE FITTINGS TO 5 K PSI AS PER FMC/SLB PROCEDURES. -SIMOPS -CLEAN AND CLEAR RIG FLOOR OF DOYON TUBING EQUIPMENT -VOID BOP STACK OF FLUID TO LAND HANGER -LAND HANGER,RUN IN LOCK DOWN SCREWS. 23:30 - 00:00 0.50 RUNCOM P RUNCMP RIG SERVICE,ST-80,BLOCKS,TOP DRIVE 7/8/2015 00:00 - 02:00 2.00 RUNCOM P RUNCMP CIRCULATE WELL WITH CLEAN BRINE -REVERSE CIRCULATE 127 BBLS OF CLEAN 10.3 BRINE @4 BPM @500 PSI -CHASE W/83 BBLS 10.3 BRINE WITH CORROSION INHIBITED BRINE @ 3 BPM @ 350 PSI -CHASE WITH 74 BBLS CLEAN 10.3 BRINE @ 4 BPM©500 PSI -CIRCULATE AN ADDITIONAL 5 BBLS DOWN TUBING TO CLEAN OFF RHC FACE @ 2 BPM @ 300 PSI Printed 7/20/2015 10:47:16AM • North America-ALASKA-BP • Page 6 of 7 Operation Summary Report Common Well Name S-42 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/5/2015 End Date:7/9/2015 X3-016TH-C(2,911,773.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual @82.68usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 05:30 3.50 RUNCOM P RUNCMP MU LANDING JOINT DROP 1.875 BALL AND ROD -WAIT 10 MINUTES FOR BALL TO LAND ON SEAT. I-PRESSURE TEST TUBING 250 PSI LOW 3500 PSI HIGH FOR 30 MINUTES. -BLED TUBING DOWN TO 2000 PSI 1-PRESSURE TEST ANNULUS 250 LOW FOR 5 MINUTE.3500 PSI HIGH FOR 30 MINUTES. PACKER STARTED SETTING AT 1900 PSI SETTING COMPLETED AT 3500 PSI. -CONSULT WITH WTL RECEIVED APPROVAL TO PROCEED 05 30 - 06:00 0.50 RUNCOM P RUNCMP SHEAR DCK VALVE 1-BLED OFF TUBING TO SHEAR DCK VALVE PUMP 2.5 BBLS BOTH WAYS THROUGH GLM TO CONFIRM CIRCULATION DOWN TUBING=1,000 PSI -DOWN ANNULUS=800 PSI 06:00 - 08:30 2.50 RUNCOM P RUNCMP PJSM FREEZE PROTECT WELL BORE PUMP 8.5 BBLS OF HEATED DIESEL(a)1 BPM DOWN IA WITH 250 PSI. '-SHUT IN FREEZE PROTECT PUMP. OPEN VALVE TO LET DIESEL U-TUBE INTO I THE TUBING FOR 1 HR. 08:30 - 10:30 2.00 RUNCOM P RUNCMP PJSM SETTING 2 WAY CHECK VALVE -VOID STACK OF FLUIDS PICK-UP T BAR SET 2 WAY CHECK VALVE AS PER FMC PROCEDURE 110:30 12:00 1.50 RUNCOM P RUNCMP PRESSURE TEST 2 WAY CHECK VALVE I-PRESSURE TEST TWC FROM ABOVE LOW 250 PSI FOR 5 MINUTES -HIGH 3500 PSI FOR 5 MINUTES. -PRESSURE TEST BELOW TWC LOW 250 PSI FOR 5 MINUTES HIGHT TEST BELOW 3500 PSI FOR 5 MINUTES -VOID STACK OF FLUIDS TO BEGAN NIPPLE DOWN. 12:00 - 18-30 6.50 WHSUR P RUNCMP NIPPLE DOWN BOPE -BLOW DOWN CHOKE,KILL,AND SURFACE LINES - VOID STACK OF BLOWN DOWN FLUIDS REMOVE MOUSE HOLE REMOVE BELL NIPPLE -NIPPLE DOWN BOP STACK AND SET ON STUMP SECURE BOP TO STUMP NIPPLE DOWN SPACER RISERS RAISE RISER THROUGH ROTARY TABLE WITH BLOCKS 1-LAY RISER DOWN IN PIPE SHED SIMOPS BREAKING OUT AND LAYING DOWN STANDS FROM DERRICK WITH OFF LINE STAND BUILDING SYSTEM Printed 7/20/2015 10:47.16AM • North America-ALASKA-BP S Page 7 of 7 Operation Summary Report Common Well Name:S-42 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/5/2015 End Date:7/9/2015 X3-016TH-C:(2,911,773.00) Project:Prudhoe Bay 1 Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:4/4/1996 12:00:00AM Rig Release:7/9/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292266200 Active datum:S-42A actual I82.68usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 00:00 j 5.50 WHSUR P RUNCMP NIPPLE UP ADAPTER FLANGE AND TREE PICK UP ADAPTER FLANGE INSTALL I-WIRE THROUGH PORT INSTALL NUTS ON ADAPTER FLANGE TORQUE ADAPTER FLANGE TEST ADAPTER FLANGE AS PER FMC PROCEDURE(GOOD TEST) '- NIPPLE UP DRY HOLE TREE AND TORQUE SIMOPS RIG DOWN TONGS,RIG FLOOR CEMENT LINES,RIG FLOOR MUD LINES,GAS BUSTER LINE,FLOW LINE,VOID RIG FLOOR SUMPS OF LIQUIDS. 7/9/2015 00:00 - 01:00 1.00 WHSUR P RUNCMP PJSM TEST TREE WITH DIESEL -TEST TREE 250 PSI LOW -TEST TREE 5000 PSI HIGH i-GOOD TEST 1-POUR 3 BOTTLES OF HEAT IN THE TREE TO PREVENT ICE PLUG -CLEAN CELLAR AREA 01:00 - 03:30 2.50 RIGD I P RUNCMP PJSM RIG DOWN -STUMP TOP DRIVE I-INSTALL BRIDLE LINES ONTO BLOCKS Y-REMOVE TORQUE TUBE PIN 1-SECURE SERVICE LOOPS IN DERRICK -LOWER PIPE CAT TO RIG MOVE POSITION -PULL OFF LINE MOUSE HOLES -SECURE DERRICK BOARD -PIN FORUM CRANE 03:30 - 04:30 1.00 RIGD 131 RUNCMP PJSM SKID FLOOR -REMOVE HANDRAILS ON ROOF TOP WALKWAYS -SKID CATTLE CHUTE TO STORAGE POSITION -INSTALL FLANGES ON IA AND OA VALVES -INSTALL NEEDLE VALVES AND GAUGES ON IAAND OA 04:30 - 05:00 0.50 RIGD P RUNCMP PJSM SKID RIG FLOOR INTO POSITION TO LAY DERRICK OVER 05:00 - 06:00 1.00 RIGD P RUNCMP 1PJSM SEPARATE MUD MODULE FROM DRILL 1 MODULE STAGE MUD MODULE ON THE SIDE I OF THE PAD FOR SHAKER PALLET ELEVATOR 1WORK RIG RELEASED FROM S-42AAT 0600 HRS ON 107-09-2015 Printed 7/20/2015 10:47:16AM i 1 in yo O°.^..00000 2228' AtWONa M N 00 48821 r A(r0°0 (N.'pr m Y r yN n aWa OO,' Oy2yg'a yOyNO 0 F, OdOd3�OMi OyyD r 2q34,94� 00000M1 W W a p t`AA AA A M MM MM tOMAAM AAAAA m MCa9 A mM MAMMA AM 2 J 00000 OOOOO 00000 00000 00000 00000 O. a 66666 tri trim of6 66666 66666 mtri trimtri 66666 66 a add a d a a a d 'a-4-4-am- a a a a a m-4-4-rm. a d a a d d d co 7777 77 •- ' 7777 77777 77777 77777 77777 0.4.M.-0 ^ Nm^ '-Ido OWNOW NWnOn MnN N0 a NWW OM tNM^ aWWOr MWWN 0N0Wn ODMWW 0-N-0-WW W.- N.- W W 3c0 c0 W W W 1202 8222 22222 �rO WArn n rn NmOtPO 2,1882 t2�2 o 22NANtOON 22222 2222' 22222 22222 0222 22222 22222 mm222 22 N J OOy')M O'iM MMMMM 00000 00000 00000 00000 00000 00000 00 0 0 0 0 0 P P P n n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 P P n P r n n m^� ,-W W d W n^ W'-Mtpd MNNNa M W.ON M.-N W P N. 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O p H V)NA m2:6 MC( h LL 00000000 C CO wN 'O b O D 06 JV :1,1i t4 ,,8‘ttor0mm(0mmm000 0 ¢< W ¢¢ . _ m w ry m T37. d C 0 .1.• 3 rn r mCC �?o u N lL ' r '' ONHSI gO )- a aWE 8ncOr mM<ONOA22Wr N 00000000 0ATm00 Y 0 WWvOm CNNWN O<; m' AOC (' R mmmi NmmMM MMMmM FO WmWMO wf. tmmmmmmmmmm WMMmyyNN W c ❑❑0 Q '! 13 N Q OW0tW N 0 o M Z N J: .00,1,0,4.rA . 7N�'-mUEOO8N88 0_Nh0'- C' < —88VNm;MNi' NW ~ 00000 0<p02 2202W LL 00000000 NNNNN NNNNN NNNNN O0 0 ,00 '�N Z Q 2 2 v-M0Wm' -Ju)N NAF w0 0 N N r%) WMN J > f0 (0YWN C thIiWU e MNMWC ON< m Am;<0 O N ;;;;;<; N 72LL Wm O)0MN< WAWRN Wm0p0 > C y JaN a co_;, N N o W 0 C LL ll o .. O O m m d W A N 0 c a v e U Q E 00000 000(00 M m p 0 2 y C J vio 2u")OOM NmMpO 6 S M M W N A N m O M W N W W O '[ N m N 0N,-,-C, ,00100 0 A N N N O 'C F 0 0 0 0 0 00 0 0 0 0 O;N N N 0 0 00000 0000 O y N N- C C q In O W O) Op 6 J (1 o E S`e a U N O?t 0 c w a o E EE 2 U 4 wm 6 • 0 North America - ALASKA - BP Prudhoe Bay PB S Pad S-42 S-42A S-42A Anticollision Summary Report 09 July, 2015 • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well S-42 Project: Prudhoe Bay TVD Reference: S-42A actual @ 82.68usft(P273 actual) Reference Site: PB S Pad MD Reference: S-42A actual @ 82.68usft(P273 actual) Site Error: 0.00usft North Reference: True Reference Well: S-42 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore S-42A Database: EDM RSK-Alaska PROD-ANCP1 Reference Design: S-42A Offset TVD Reference: Offset Datum Reference S-42A Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of 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 7/9/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 222.29 2,946.70 S-42 Sry 1 MWD(S-42PB1) MWD MWD-Standard 3,013.00 3,496.67 S-42A Srvy 1 GYD-WD-SS(S-42A) GYRO-WD-SS Gyro while drilling single shots 3,509.41 3,761.99 S-42A Srvy 2 MWD+IFR+MS-WOCA(S-42 MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 3,788.51 4,639.47 S-42A Srvy 3 MWD+IFR+MS-WOCA(S-42 MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 4,675.68 8,418.36 S-42A Srvy 4 MWD+IFR+MS-WOCA(S-42 MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,435.15 8,463.30 S-42A Srvy 5 INC+TREND(S-42A) INC+TREND Inclinometer+known azi trend 8,494.39 11,209.38 S-42A Srvy 6 MWD+IFR+MS-WOCA(S-42 MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 7/9/2015 4:22:49PM Page 2 of 6 COMPASS 5000.1 Build 61 • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well S-42 Project: Prudhoe Bay TVD Reference: S-42A actual©82.68usft(P273 actual) Reference Site: PB S Pad MD Reference: S-42A actual @ 82.68usft(P273 actual) Site Error: 0.00usft North Reference: True Reference Well: S-42 Survey Calculation Method: Minimum.Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore S-42A Database: EDM RSK-Alaska PROD-ANCP1 Reference Design: S-42A Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB S Pad Plan Kup S-xxx Manchester United Slot SS-18 v3. Out of range Plan S-136(Arsenal)-Plan S-136-Plan#6b S-13 699.15 700.00 44.57 12.18 32.40 Pass-Major Risk S-03-S-03-S-03 3,173.48 3,275.00 216.17 44.27 172.01 Pass-Major Risk S-04-Plan S-04A-Plan#5c S-04A 4,459.17 4,475.00 140.95 55.66 95.68 Pass-Major Risk S-09-S-09A-S-09A 5,590.30 5,125.00 473.76 72.44 401.33 Pass-Major Risk S-09-S-09APB1-Plan#7 S-09A 5,590.30 5,125.00 473.76 72.50 401.26 Pass-Major Risk S-09-S-09APB1-S-09APB1 5,590.30 5,125.00 473.76 72.44 401.33 Pass-Major Risk S-09-S-09APB2-S-09APB2 5,590.30 5,125.00 473.76 72.44 401.33 Pass-Major Risk S-09-S-09APB3-S-09APB3 5,590.30 5,125.00 473.76 72.44 401.33 Pass-Major Risk S-10-S-10-S-10 Out of range S-10-S-10A-S-10A Out of range S-10-S-10APB1-S-10APB1 Out of range S-100-S-100-S-100 368.17 350.00 257.67 5.29 252.38 Pass-Major Risk S-101-S-101-s-101 1,215.05 1,200.00 213.06 19.33 193.76 Pass-Major Risk S-101-S-101 PB1-S-101 PB1 1,215.05 1,200.00 213.06 19.33 193.76 Pass-Major Risk S-102-S-102-S-102 168.17 150.00 271.24 3.37 267.86 Pass-Major Risk S-102-S-102L1-S-102L1 168.17 150.00 271.24 3.37 267.86 Pass-Major Risk S-102-S-102L1 PB1-S-102L1 PB1 168.17 150.00 271.24 3.37 267.86 Pass-Major Risk S-102-S-102PB1-S-102PB1 168.17 150.00 271.24 3.37 267.86 Pass-Major Risk S-103-S-103-S-103 668.43 650.00 393.22 9.88 383.35 Pass-Major Risk S-104-S-104-S-104 368.43 350.00 466.53 6.49 460.05 Pass-Major Risk S-105-S-105-S-105 1,146.62 1,125.00 457.80 15.65 442.16 Pass-Major Risk S-106-5-106-S-106 287.29 275.00 422.18 5.55 416.63 Pass-Major Risk S-106-S-106PB1-S-106PB1 287.29 275.00 422.18 5.66 416.52 Pass-Major Risk S-107-S-107-S-107 462.76 450.00 377.57 8.54 369.03 Pass-Major Risk S-108-S-108-S-108 9,538.13 7,525.00 396.04 104.51 291.55 Pass-Major Risk S-108-S-108A'-S-108A 46.38 46.38 330.87 1.93 328.94 Pass-Major Risk S-109-S-109-S-109 689.70 675.00 285.17 11.49 273.70 Pass-Major Risk S-109-S-109PB1-S-109PB1 689.70 675.00 285.17 11.49 273.70 Pass-Major Risk S-110-S-110-S-110 511.19 500.00 297.19 9.62 287.58 Pass-Major Risk S-110-S-110A-S-110A 510.55 500.00 297.18 9.61 287.58 Pass-Major Risk S-110-S-110B-S-1109 497.80 500.00 297.01 9.32 287.70 Pass-Major Risk S-111-S-111-S-111 167.87 150.00 346.79 3.68 343.11 Pass-Major Risk S-111-S-111 PB1-S-111 PB1 167.87 150.00 346.79 3.68 343.11 Pass-Major Risk S-111-S-111 PB2-S-111 PB2 167.87 150.00 346.79 3.68 343.11 Pass-Major Risk S-112-S-112-S-112 4,089.45 4,025.00 67.25 43.68 23.74 Pass-Major Risk S-113-S-113-S-113 862.01 850.00 362.95 15.46 347.50 Pass-Major Risk S-113-S-113A-S-113A 862.01 850.00 362.95 15.90 347.06 Pass-Major Risk S-113-S-113B-S-113B 862.01 850.00 362.95 15.90 347.06 Pass-Major Risk 5-113-S-113C-S-113C WP1 862.01 850.00 362.95 15.90 347.06 Pass-Major Risk S-114-S-114-S-114 562.26 550.00 439.93 10.62 429.32 Pass-Major Risk S-114-S-114A-S-114A 562.26 550.00 439.93 10.62 429.32 Pass-Major Risk S-115-S-115-S-115 894.55 875.00 215.68 12.52 203.17 Pass-Major Risk S-116-S-116-S-116 843.72 825.00 87.45 12.83 74.63 Pass-Major Risk S-116-S-116A-S-116A 843.72 825.00 87.45 13.26 74.21 Pass-Major Risk S-116-S-116APB1-S-116APB1 843.72 825.00 87.45 12.82 74.64 Pass-Major Risk 5-116-S-116APB2-S-116APB2 843.72 825.00 87.45 12.82 74.64 Pass-Major Risk S-117-S-117-S-117 1,512.97 1,500.00 170.43 22.62 147.87 Pass-Major Risk S-118-S-118-S-118 1,575.56 1,575.00 56.86 20.01 37.06 Pass-Major Risk S-119-S-119-S-119 396.14 375.00 317.66 6.69 310.97 Pass-Major Risk S-120-S-120-S-120 643.77 625.00 179.52 11.60 167.93 Pass-Major Risk S-121-S-121-S-121 343.32 325.00 76.19 5.48 70.71 Pass-Major Risk S-121-S-121 PB1-S-121 PB1 343.32 325.00 76.19 5.48 70.71 Pass-Major Risk 7/9/2015 4:22:49PM Page 3 of 6 COMPASS 5000.1 Build 61 . • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well S-42 Project: Prudhoe Bay TVD Reference: S-42A actual©82.68usft(P273 actual) Reference Site: PB S Pad MD Reference: S-42A actual @ 82.68usft(P273 actual) Site Error: 0.00usft North Reference: True Reference Well: S-42 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore S-42A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: S-42A Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning,l -` Y4b m Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design ,, „ (usft) (usft) (usft) (usft) PB S Pad S-122-S-122-S-122 1,193.48 1,175.00 191.75 16.01 175.76 Pass-Major Risk S-122-S-122PB1-S-122PB1 1,193.48 1,175.00 191.75 16.01 175.76 Pass-Major Risk S-122-5-122PB2-S-122PB2 1,193.48 1,175.00 191.75 16.01 175.76 Pass-Major Risk S-122-S-122PB3-S-122P83 1,193.48 1,175.00 191.75 16.01 175.76 Pass-Major Risk S-124-S-124-S-124 Out of range S-125-S-125-S-125 293.75 275.00 46.80 4.80 42.01 Pass-Major Risk S-125-S-125PB1-S-125PB1 293.75 275.00 46.80 4.80 42.01 Pass-Major Risk S-13-S-13A-S-13A Out of range S-13-S-13APB1-S-13APB1 Out of range S-15-S-15-S-15 9,324.87 7,950.00 58.89 142.47 -79.79 FAIL-Major Risk S-16-S-16-S-16 9,678.67 8,000.00 241.35 175.31 72.66 Pass-Major Risk S-19-S-19-S-19 Out of range S-200-S-200-S-200 540.64 525.00 121.20 7.75 113.45 Pass-Major Risk S-200-S-200PB1-S-200PB1 540.64 525.00 121.20 7.75 113.45 Pass-Major Risk S-201-S-201-S-201 293.04 275.00 406.51 4.60 401.91 Pass-Major Risk S-201-S-201 PB1-S-201 PB1 293.04 275.00 406.51 4.60 401.91 Pass-Major Risk S-21-S-21-S-21 3,823.37 3,950.00 411.94 57.00 355.04 Pass-Major Risk S-213-S-213-S-213 2,630.49 2,625.00 131.05 30.88 100.22 Pass-Major Risk 5-213-S-213A-S-213A 2,610.86 2,600.00 130.72 30.50 100.25 Pass-Major Risk S-213-S-213AL1-S-213AL1 2,610.86 2,600.00 130.72 30.51 100.25 Pass-Major Risk S-213-S-213AL1-01-S-213AL1-01 2,610.86 2,600.00 130.72 30.51 100.25 Pass-Major Risk S-213-S-213AL2-S-213AL2 2,610.86 2,600.00 130.72 30.51 100.24 Pass-Major Risk S-213-S-213AL3-S-213AL3 2,610.86 2,600.00 130.72 30.51 100.25 Pass-Major Risk S-216-S-216-S-216 1,235.22 1,225.00 74.74 18.15 56.86 Pass-Major Risk S-22-S-22-S-22 Out of range S-22-S-22A-S-22A Out of range S-22-S-22B-S-22B Out of range S-23-S-23-S-23 11,340.65 8,200.00 295.73 177.40 127.92 Pass-Major Risk S-24-S-24-S-24 4,610.04 4,625.00 341.65 73.28 269.90 Pass-Major Risk S-24-S-24A-S-24A 3,578.14 3,750.00 214.18 58.25 158.33 Pass-Major Risk S-24-S-24B-S-24B 3,578.14 3,750.00 214.18 58.24 158.33 Pass-Major Risk S-31-S-31-S-31 3,791.81 3,975.00 64.17 67.57 -3.39 FAIL-Major Risk S-31-S-31A-S-31A 3,791.81 3,975.00 64.17 67.41 -3.24 FAIL-Major Risk S-32-S-32-S-32 8,123.22 7,425.00 232.73 112.26 121.10 Pass-Major Risk S-32-S-32A-S-32A 8,123.22 7,425.00 232.73 112.26 121.10 Pass-Major Risk S-34-S-34-S-34 10,099.82 7,975.00 457.64 194.45 283.75 Pass-Major Risk S-35-S-35-S-35 5,310.10 4,825.00 116.50 82.49 41.86 Pass-Major Risk S-400-S-400-S-400 493.09 475.00 58.15 7.57 50.58 Pass-Major Risk S-400-S-400A-S-400A 493.29 475.00 58.15 7.57 50.58 Pass-Major Risk S-401-S-401-S-401 642.56 625.00 12.80 10.55 2.33 Pass-Major Risk S-401-S-401 PB1-S-401 PB1 642.56 625.00 12.80 10.55 2.33 Pass-Major Risk S-41-S-41-S-41 486.13 475.00 30.07 7.00 23.07 Pass-Major Risk S-41-S-41 A-S-41 A 492.29 475.00 30.17 7.10 23.07 Pass-Major Risk S-41-S-41 AL1-S-41 AL1 492.29 475.00 30.17 7.10 23.07 Pass-Major Risk S-41-S-41 L1-S-41 L1 486.13 475.00 30.07 7.00 23.07 Pass-Major Risk S-41-S-41 PB1-S-41 PB1 486.13 475.00 30.07 7.00 23.07 Pass-Major Risk S-42-S-42-S-42 3,010.89 3,000.00 0.02 1.69 -1.62 FAIL-Major Risk S-42-S-42PB1-S-42PB1 3,010.89 3,000.00 0.02 1.69 -1.62 FAIL-Major Risk S-43-S-43-S-43 439.51 425.00 33.98 6.85 27.13 Pass-Major Risk S-43-S-43L1-S-43L1 439.51 425.00 33.98 6.85 27.13 Pass-Major Risk S-44-S-44-S-44 3,318.26 3,300.00 45.59 37.35 8.25 Pass-Major Risk S-44-S-44A-Plan#9 S-44A 2,849.14 2,850.00 63.86 31.66 32.26 Pass-Major Risk S-44-S-44A-S-44A 46.18 46.18 60.51 1.92 58.58 Pass-Major Risk 7/9/2015 4.•22:49PM Page 4 of 6 COMPASS 5000.1 Build 61 • S BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well S-42 Project: Prudhoe Bay TVD Reference: S-42A actual @ 82.68usft(P273 actual) Reference Site: PB S Pad MD Reference: S-42A actual @ 82.68usft(P273 actual) Site Error: 0.00usft North Reference: True Reference Well: S-42 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore S-42A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: S-42A Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB S Pad S-44-S-44L1-S-44L1 3,318.26 3,300.00 45.59 37.35 8.24 Pass-Major Risk S-44-S-44L1PB1-S-44L1 PB1 3,318.26 3,300.00 45.59 37.35 8.25 Pass-Major Risk S-504-S-504-S-504 128.75 120.00 89.18 3.97 85.21 Pass-Major Risk 7/9/2015 4:22:49PM Page 5 of 6 COMPASS 5000.1 Build 61 M i as w w a 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C N m y W F O = W O C a ci O mO.2 E F- O > N a UI co Q ❑ _oz w Z a) a) ^ C O 0 E co- O i 0 E _o 0) Z ZZ `-' O O LU oU) U TiloCa Z Co o E Co Co Z J a F > N 0 F- Z o 0 a I ct Co W M M n m 0 cc, 2 a a a o ai W ~ cc o cn U - tJ _ M m z w o 0 N CO W Y N Y Z o LLI cc 2 cc n. "LO d N �_ a Co O 97 T a l a �O NO LL j Q N r y O a O •-I1- U o a Ul .. E V .. N to 2 a Co d j C = n O N >> N C O ° > O 9 O) a a aa) a N a a d a` d U arw c..) ID i� c E Co c o W o aE) - F- F- U U D Co U m F- I v o, ry wP 4, • • THE STATE Alaska Oil and Gas ®f/� /� Conservation Commission !7. I� .ft _ sKA 333 West Seventh Avenue - � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 I� *,h Main: 907.279.1433 ALAS— Fax: 907.276.7542 www.aogcc.alaska.gov David Wages Well Interventions Specialist BP Exploration (Alaska), Inc. 0 5 P.O. Box 196612 , Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S-42A Sundry Number: 315-462 Dear Mr. Wages: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 147 Cathy P. Foerster Chair DATED this 3 day of September, 2015 Encl. vtgoteilki0 20 Ht,L; L • STATE OF ALASKA J 12 9 201 ALASKA OIL AND GAS CONSERVATION COMMI•N f� 7 3/Is l APPLICATION FOR SUNDRY APPROVALS ® / //s 20 AAC 25.280 O G C C 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate Q Pull Tubing 0 iii Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 215-055 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p 99519-6612Stratigraphic 0 Service ❑ 6. API Number: 50-029-22662-01-00 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes 0 Nom PBU$-42A Will planned perforations require a spacing exception? 9. Property Designation(Lease Number): 10. Field/Pools: s 4+2.'✓"-- ADL 0028258 PRUDHOE BAY,P E OIL !.. yS S° -- 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11250 6714 11200 6714 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 47-127 47-127 1490 470 Surface 3043 9-5/8"40#L-80 47-3089 47-3088 5750 3090 Intermediate 8435 7"26#L-80 45-8480 45-6770 7240 5410 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8340-11140 6690.36-6714.19 4-1/2"12.6# 13Cr85/13Cr80 43-6683 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program H Exploratory 0 Stratigraphic 0 Development m Service 0 14.Estimated Date for Commencing Operations: 8/10/15 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Wages,David Email David.Wages@bp.com Printed Name Wages,David Title Well Interventions Engineer Signatures \\ \ '.\..‘ hone 907.564.5669 Date 7/t1 &- COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: PjI i.-21; ,at/ on /—e•1.,./1;rfd fa fh-c Fr-acFoci--/5.. Ch<.� i''41 Ta- ,Se/),,svrr, !-�1 /'fir r� us- ,,vr�, r-i-a 4 (-7,6,1-.5- . ci.-. c45 c✓Cr-qI) %t5 ri'k-! ,,ir-,-r'f5 o-1 l ✓ .2 AA C z5- . 2 S 3 . Spacing Exception Required? Yes 0 No 0 Subsequent Form Required: /0 _ 40-/1-- APPROVED 0-/1-'APPROVED BYTHE Approved by: //' 95,..e.4.44. COMMISSIONER COMMISSION Date:9, 3'/5 VTf- q/3/, RBDMSc SEP U 4 2015 ORIGINALgilops- -3.,se- - .,_ Submit Form and Attachments in Duplicate Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. • • Date: July 20, 2015 Subject: S-42A Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: Chris Wallace Attached is BP's proposal and supporting documents to fracture stimulate the Kuparuk interval of well S-42A. Well S-42A is a Kuparuk producer with an undulating wellbore in the Cl, C2 and C4 sands. The well will be stimulated with 6 hydraulic fracture stages. There is a fault between the 2nd and 3rd stages that has been isolated with swell packers. The#6 sleeve will not be stimulated at this time. We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which require identification of fresh water aquifers and a plan for basewater sampling. Please direct questions or comments to David Wages • 0 Packers and SSV's Attachment PBU S-42A SW Name Type MD TVD Depscription S-42A PACKER 8318.69 6677.36 5" Baker ZXP Top Packer S-42A PACKER 8602.73 6823.1 4-1/2"Swell Packer S-42A PACKER 8738.84 6851.02 4-1/2"Swell Packer S-42A PACKER 9040.66 6801.9 4-1/2" Swell Packer S-42A PACKER 9592.01 6732 4-1/2"Swell Packer S-42A PACKER 9993.46 6737.23 4-1/2"Swell Packer S-42A PACKER 10226.97 6751.35 4-1/2"Swell Packer S-42A PACKER 10663.33 6737.35 4-1/2" Swell Packer • • m LQd00)'— 0 00 0 o v LO LO LC) LO L() o LC) CO "•-• r— co N- V y 0 0 0 o 0 o 0 0 - O) in d N M N co co N- N O O m a— LO N- C) O 00 C) CO CO N 00 N- r- a— a— CO M 00 O C` N- LO CO CO MCOCOCDCOCOCOCO N N. N. LO N. r CO CO M 'Cr [C CO N- t` LO CO CO CO CO CO CO alW CO CO CO ONO CO CO 111111111Q Q NJ- LO c.`,7) I� M L CO i M N Cl) 00 CO CO v • co LO O LC) O CO Co CO CO CO 1- 00 0U tit °I L. = J O M J CO r CD •� N t N N co co co - co M • N N N ✓ O) pp N O - O L ^ N N ' N N N N t Cr) LO CN1 C)O NI- M Cr) LO Cr) N Ca0O V 00 - N- CON- J M 00 N CO W C C W W U UOu_ CLCCR' QZZZ Z 111 W W W m m m Z Z Z OUCnZJJHF- I— • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF NOTICE OF OPERATIONS ^ ! Before me, the undersigned authority, on this day personally appeared 1-)4 U 1 "v c� e,5 , who being duly sworn states: 1. My name is David Wages. I am 18 years of age or older and I have personal knowledge of the facts stated in this affidavit. 2. I am employed as an Engineer by BP Exploration(Alaska) Inc. ("BPXA")and I am familiar with the Application for Sundry Approvals to stimulate the S-42a Well (the "Well") by hydraulic fracturing as defined in 20 AAC 25.283(m). 3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well, a true copy of which is attached to this Affidavit as Attachment 1 ("Notice of Operations"). 4. On July 23, 2015, the Notice of Operations was sent to all owners, landowners, surface owners ✓ and operators within a one-half mile radius of the current or proposed wellbore trajectory of the Well. The Notice of Operations included: a. A statement that upon request a complete copy of the Application for Sundry Approvals is available from BPXA; b. BPXA's contact information. Signed this 22nd day of July,2015. /// ((( A-3( / ' (Signature) r STATE OF ALASKA THIRD JUDICIAL DISTRICT Subscribed and sworn to or affirmed before me atm ps 0. on the day of \ , 20\V. Signature of Office u11q�I1 EvOP. ,.................. Title of Ocer _ .� �� VN\ber: \\\\0 ° C)0 "34-1C rpt - OF ,*t. .S • • Wellwork Procedure Request To: Well Services Operations Team Lead Date: 7/22/15 Wireline Operations Team Lead VER1 AFE: X3-016TH-C:PREPOST From: David Wages -Well Intervention Engineer Michael Hibbert -Well Intervention Engineer IOR: 1000 Est. Cost: $2,000K Subject: S-42a - Pre and Post Frac Procedure Please perform the following steps 1. S Pull DCRV, Install DGLV, pull B&R, Pull RHC, Install Evotrieve, MIT-T, MIT-IA, Pull Evotrieve. 7. F Hydraulic Fracture Treatment 8. C Post frac FCO, mill seats 9. S D&T, Install GLVs 10. T Post frac flowback Current Status: Operable Minimum ID: 3.813" at @ 1989', 8171', 8311' & 8238' MD. 4-1/2" X-Nipple Max Deviation: 111 deg at 9030' MD Top Perf Deviation: 63 deg at 8533' MD Last TD Tag: N/A New Well Last Downhole Op: N/A New Well SBHP/SBHT: New Well, 3300 est. Latest H2S: N/A New Well Program Contacts Contact Phone -Work Phone-Mobile/Home Interventions Engineer David Wages 907-564-5669 713-380-9836 Interventions Engineer Michael Hibbert 907-564-4351 907-903-5990 Page 11 of 7 • • **The well currently has 10.3 ppg NaCI/NaBr in the tubing and IA** Sfickt ne Pull DCRV, Install DGLV, pull B&R, Pull RHC, Install Evotrieve, MIT-T, MIT-IA, Pull Evotrieve. 1. Pull DCRV in st#4 @ 3718' 2. Install DGLV in st#4 3. Pull B&R in RHC @ tubing tail 4. Pull RHC 5. Install Evotrieve @ 8300' • Between X-nipples in tubing tail 6. MIT-T to 4500 psi • Do not hold pressure on IA per AOGCC requirements. 7. MIT-IA to 4000 psi • Hold 2000 psi on tubing during MIT-IA 8. Pull Evotrieve Fullbore Hydraulic Fracture Treatment 9. Frac treatment per pump schedule. Pressure testing Maximum Allowable Treating Pressure: 6500 psi Stagger Pump Kickouts between: 6175 psi and 5850 psi (90% to 95% of MATP) Global Kickout 6175 psi (95% of MATP) IA pop-off set pressure 3000 psi (75% of MIT-IA) Treating Line Test Pressure 7500 psi Sand Requirement 465,643# 20/40 Carbolite, 138,441# 16-20 RC Minimum Water Requirement 5,000 bbls (pump schedule: 4035 bbls) IA Hold Pressure 2700-2900 psi OA Monitor and maintain open to atmosphere • Coiled Tubing Post frac Mill seats See Appendix B for Mill out procedure S icichne D&T, Install GLVs 10. Drift and tag if necessary 11. Install Deep GL design if possible Testers Post frac flowback 12. Post frac flowback Page I 2 of 7 • Appendix A - CT FCO Procedure Notes: • This is a generic FCO procedure for a post frac FCO. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the job is pumped. • The objective of this procedure is to get the well cleaned to facilitate post frac well test or to continue frac operations. • Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure 1. MIRU CT 2. MU BHA. 3. RIH down to estimated sand top and begin cleaning out with slick 1% KCL. 4. Continue down to 8533' CTMD. At this point we are at the uppermost sliding sleeve. Ensure CT is clean as it is expected that returns will begin to fall off as the nozzle nears the sleeve. If returns begin to fall off, reducing BHP by lowering rate may keep returns at a manageable level. 5. Slowly continue to clean out until returns fall off to -80%. If returns are still good even after the nozzle is past the sleeve (not likely but possible), continue to clean out to TD a. If returns are too low, it may be necessary to mill the bridge plug without taking returns. 6. FP to 2500'. 7. Pump a gel pill at surface out to the tanks to ensure CT is clean if necessary. 8. RDMO. Page 13 of 7 • S Appendix B - CT FCO Procedure Notes: • This is a generic Mill out procedure for a post frac Mill/FCO. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the job is pumped. • The objective of this procedure is to get the well cleaned and the seats milled out to facilitate post frac well test. • Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure 9. MIRU CT 10. MU BHA to Mill Frac seats. 11. RIH down to estimated sand top and begin cleaning out with slick 2% KCL. 12. Continue down to 8433' CTMD. At this point we are —100' above the heel sleeve. Ensure CT is clean as it is expected that returns will begin to fall off as the nozzle nears the slots. If returns begin to fall off, reducing BHP by lowering rate may keep returns at a manageable level. 13. Slowly continue to clean out until returns fall off to -80%. If returns are still good even after the nozzle is past the slots (not likely but possible), continue to clean out until returns show trace amount of Carbolite. a. If necessary, we can mill the seats without taking returns. 14. FP to 2500'. 15. Pump a gel pill at surface out to the tanks to ensure CT is clean if necessary. 16. RDMO. Page 14 of 7 • S Appendix C -Test Separator Additional Flowback Procedure 1. MIRU ASRC. RU equipment to in a manner that allows CT to RU if an additional FCO is necessary. 2. POP the well to ASRC at minimum choke. Flow the initial returns to the flowline as long as the shake-outs meet the returned fluid/solids management guidelines. 3. Limit flow to 500 bpd 4. If solids are < 1%, increase the production rate to 1000 BLPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1%, allow well to flow to 1500 BLPD. Flow bottoms up and sample for solids production. If solids are still below 1% continue to increase the flow rate in 500 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1%; allow well clean up before choke is opened further. 6. Once at FOC, stabilize the well for 4 hrs. Obtain a 3 hr purge, 8 hr welltest. Page 15 of 7 0 0 TRH-= (110/4 1116 6500 1.19 ----I MEI I)I-AD. 1-1AE: S-42A 5.01-I IY NoT1S Wil l A/4611,?or a 15O0 '" ACTUATOR , BAKER C MAX OL 9.ar a 11741P "'"CHROME T90 A I MR CKB.13-13/= 11 (9' r I BF ELEN= 37 76' i KCP= 3013 20'COM/ - 10' Alm Anglo= 111"f:990307154 1010' i 14_1, - I',11.NP 13-3 813-_. Datum MD= 8505' u- , • I I ' Datum TVD=_ 8700 SS I g-sir&CR NNW%rocTK cTeno/115)7; 316.71-i'--. -- 8-CGS,404.L-90 TRS.ID=6830' --,- -3 tiTF---..... FALLOUT WtiDOW(S-42Al 3013-3030' I 6-srEr EWA CI3P406/2C415) l-r- ---1336--- _ Minimum ID=3.813"fa 1995' GAS LIFT WAICRELS , 0 t/13 ND DEV TYPE I VIV I_ATC11' RDRT (ATE 4-112" HES X NIPPLE . - -- 4 1/18 3668 27 KG/34-5 DCX-2 693( 0 07/37/15 3 6280 5097 47 ,KG134-S 0168/ BK , 0 07/07115 I. IL ,t-rAL-1,1, ',,,,i,i,, , 1 -4864' I -- . a ? 162 7171 If; 8 C*14-5.i LAN BK ' 0 07.07/15 7. ei 1 0057 I'C,' IC .-„clu.i 5. OW,., BK i_ 0 onom 5 .... I'''' r.. :7 8 36 --4-1/2"130/9M113•CA SINGLE DROP 7` SAPEHRE 04.U0E,D=3.884' 0.• I I I 8171' [14-112'FES X NP.D=3.014": Mr I I•8 4 io•vrir.nke-,k 14.ti 3 atos I: 1 I 1 I 8238" -4-1/2'Hes x rsr,0-3 613' I•!, I I 1 5311' H4.1/7 Hesx p,p,o-3.913" •'. - ,4 831W J-rxs84091410-EZXPLTP i 10P OF 4-1r2"LHR H 8319' 42 ',""1 ,Il ' - we/TEEK,0.4 3W 14 1/2"TBG.Vet 13CR-96 VAM TOP. H 832W ::::).: --. 83213' 14-1/2"%LEG,D.3.958-j ,0152 bpf,13=3 958* --si 8343" Hr x 5"&NOG RECLOCX I-CR,D=4.3407_1 I/'CSG,269,L 80 VAM TOP NC, L old.oi,o.. 1---A , 193H5'*4-112"x0,0=3.89'j I 0383 by', ID-8 279" - m -. ea' SCHLUM FRAC PORTS 1135 SWELL PACICERS .m.1 IC CEPTH SEAT SZ ACTUAL SIZE 0/C BATE 140 SE TOP DEPTH 111)' - •C4 7 8533 3.375' 5.630' C 07/07/15 7 i 4-112' 8603 3.97 m mi,no 6 5649 325' 5630' C 0/10015 6 i 4-117 8739 3.97 > -1 5 8981 3125' 5.630' C 07437115 5 1 4-112" 9041 asa. . . 1 9380 3.00' 5.630' C 07107/15 4 4-1/2' 9592 I 3.97 .r. ...z. 3 9837 2.875' 5.630' C 07107/15 3 4-1/2' 9993 1 3.92^ im m• :- 2 /0475 2375' 5.830' C 07107/15 2 4-1/2 10227 1 3.92 1 4-1/2' 10883 i_197 :• -3 1 10696 "138-1 5.630' C 07107/15 m NI CBI FRAC FORT,13-3.75' 3-14"A ICHOR PM.1111,, JD-2802' -. ..z. _--1 1 11121' k 1 0111W-1---fi:iii'-gy ECA-c-CLA iiii'FRA`EVATVP.:b--,--firs;] .. crn . o - -,....„.. 1...___--f 110w j4 1/7'8KR 5149T TOCi VFRPCATION SUB,0.1717 4-1/2"LIP,11'. .13CR-80 I-ND 521, --I. 11131' ------ ,,.. - 11171' 1 F1-1/7 SKR SOLAT1ON VALVE .0152 bp!,11.,- /'4-1' - 11131. 1-141/2"X 1-11'2"X0,I)=2 46' ----[ 4-1/7 LNR 13 59,1361141111-w it',...I 1 1 112411" ' -----: i 1172'143-1m x 4-10'X0,13-2 gar j .0152 W,ID=3.95W 1 _ DATE FE,0,7- wytura_ni I. 1 UM I et 1!..,1 BY COMMENTS PRUDHOE MY ANT 01/2591 ,0(50 MeV COMPLETION WELL: S 42A , _____ ..,.... ,...,„„ ...,.... 071015 P-273 1,SITEIRACK(5.4261 PERMIT No.2150550 ___ _ 0010115 AD ORLG1-13 CORRECTUNS AF1 N9. 50-029 22E82 01 0015/15, .11‘11/3 FTAL OCE APPROVAL SEC 35,T1 2M,R12E,4161FSI 8 4503'1-E1 07/22115 ..1483 AOOFL)BEE.(BET 1) orowis JR-3,43 MRS ID FRAOSIMELL sr hem ogiceR . 56)Expioration(Alasta) Page I 6 of 7 • • TubeMove Analysis: Force(Ibf)(+Tensile) d m W W N M 0 N Un V S! eln0 N CO v CV CO O 0 0 0 0 0 0 0 0 0 0 ? ' O O 0 0 0 0 0 0 0 0 n7 m No O O o co o o O O O 0 m 3 O d N 0 n 'O m o m — o oo m O1 — c— r 5 --- r r3 0N c o 0 A a c + o. o O FPaO 0 o G ` m 'D N co N c m mo O O "" It .7 O D O, m 4 - r0 4j. 3 0— a n J 'fl c co c W O co O a 0. d p c O n 0 • m 0 00'' 0 . 0 A m v CD o o— C r N H 07 o ♦ ■�y 0 m 0 o 1 N O O co D o O 0 a 0 (A co 0 O O Effective Differential Pressure(psi) 0 MD(ft) —I m 0 N O0 W 0 0 0 il.0 co N . o Co A N N A O� cD 0 O 0 0 0 0 0 0 0 0 0 0 N 0 0 0 0 0 0 0 0 0 0 r 0 0 0 0 0 0 0 0 0 O 0 d 0 0 0 0 0 0 0 0 0 0 0 3 o m Oo i • N O O• -n P. P N m ' o A ^ al to 3 4. o w o 0. o c n m0 3 c • .0 - 0 o 0 O 0 0 — 0 O N %-) 9 - t f.5i 1 L.1,.. $ _-..� co t o = co z 0/ f 0 m o t •m J r m ♦ 0 O % + C CD t O cs)^ N r Lo— I. c. i , r r • = T0 - ftv d lel ' m • a W O O N W r O j o I} ' N W O 11 I I N 0 V (v cm 0OINIV�7 '� '1 7 IYI� 71T2 '9.m 1 1 a o, mN -1 -1W ^ m mm n m0 In > r A m y 5O {' . _., 0 o 0-- r r r 0 O P.-.. , r m o a r1 - a v 0 O 0 CO co o 0 CM t 1 0 co 0 Page 17 of 7 • • Affidavit of Notification (20 AAC 25.283,a, 1) Partners notified 6/11/2015: • ConocoPhillips Exxon Mobil Chevron Department of Natural Resources Plat Identifying Wells(20 AAC 25.283,a,2,A-C) and Faults(20 AAC 25.283,a, 11) • 14 J1 i 1• .�_c • 111\ l60' N _ lam" 1,---...... 60' N• lir- <x s-1e lig • 4 3i: ih. S . / 11 50' W .j%' • _' A;s-li 411 :S-1" • ANN- 4s-i i '�I,„�, • .5-11: 1, a Red lines indicate approximate length and location of fracs. Producers within 1h mile of S-42a: S-108 S-31A S-112 S-105 S-110 B S-104 S-109 S-115 Per the plat above, there are no water wells within 1/z mile of the subject well. The above map shows 3 faults of concern: 1, 2 and 3. The remaining faults are well away from stimulation chemicals and/or on the other side of three main faults. Faults #2 and 3 are parallel to the primary stress plane (the direction our frac is going to grow) and should remain isolated from frac . fluids. Fault#1 is the primary fault of concern. In order to ensure the induced frac stays well away from this fault, a data frac is planned which will give information on the rock including closure / pressure, leak-off coefficient and will help determine more accurately the anticipated length and height of fracturing fluids. Given the above information, all fracturing fluids should remain within the matrix areas of C1-4. • • Exemption for Freshwater Aquifers(20 AAC 25.283,a,3-4) Well S-42a is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated July 11, 1986 where Standard Alaska Production Company requested the Alaska Oil and Gas Conservation Commission to issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II Injection activities. Findings 1-4 state: 1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are situated at a depth and location the makes recovery of . water for drinking water purposes economically impracticable. 3. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are reported to have a total dissolved solids content of 7000 ✓ mg/I or more. 4. By letter of July 1, 1986, EPA-Region 10 advises that the aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a non-substantial program revision not requiring notice in the Federal Registrar. Per the above findings, "Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC 25.440." thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283,a,5-6) Well S-42a was sidetracked on 6/14/15. After de-completing the well, a whipstock was set at 3035' and 9.3 ppg drilling fluid was circulated in the well. A window was milled in the 9-5/8" casing from 3013'-3049' with cement observed behind the casing. An 8-1/2" intermediate hole was drill where 7" 26#, L-80 Vam Top HC casing was run to 8480' and cemented in place with 50 bbls of 11 ppg Mudpush II spacer, 100.4 bbls of 11.5 ppg litecrete (40% excess) and19.1 bbls of 15.8 ppg Class G cement (40% excess). The casing was pressure tested to 3500 psi for 30 minutes for a passing test. The 6-1/8" production hole was drilled where a 4-1/2" 13.5#, 13Cr80 HYD 521 liner with sliding sleeves and swell packers was run and landed at 11,248' no significant issues were encountered while drilling the production hole. The 7" production casing has been tested to 3500 psi with 10.3 ppg brine in the well. 0 0 Accurate Pressure Ratings of Tubulars and Schematic(20 AAC 25.283,a,8) IE= CAP44-1116-6500 PS0 IAE11.101EA0= RC S-42A 5A4F TV 44011 S Will AWN.E 1.70*lig NOW ACTUATOR. BAKER C 144x C II it/4 1746—CHROME 110 A 16W"'" 71 T9 I I BF ELEV= 377 _..---- KIDP= 3013 20'COIC -f 80' 1 Mix Anglo= lit @IWO' 2164 i989 1-fc`i-Fr-ittixiaii-ii=iiii--1 U Datum IVO= 13700 SS 11-1.15/8"SKR 19.41FSTOCK(411/20/10) e- 3013' °Litz!"CG5,408.1-80 8TRS,ID=8135- -3013 ko_Lour 00116DOW(5-4241 3017-3030' 19-5,W ic,)ciiv,)0600115)_I- 11SS J Minimum ID=3.813 g lase' GAS LET MANLIPELS 5E, 1,13 IVO cer r TYPE' VLV LATai, FORT OA TE [4--12"HES X NIPPLE 4'3/18 3588 2/ iKGES4-51 DO(-7 184( 0 01.0(115 , 3 6280 5007 47 18034 9 CAN BA 0 07107115 IO,(A-r_.E.to-ro 06,2.5.-1,1 1 -4804' I I , 2 667 6121 36 18084-5, DIN 1311 0 07107115 • Po 1 1.,0057 6507 46 K004-50. CAR CH ,. 0 07007115 ...e -4c In 8138' 4 1.7 q(...14 iC44-1.CA SII•1111 i I COP I?, PI 1—11SAPPRIRT CJA LCA:,0-)804• 1i-1 14 lr2"re9 X MP,Df3,8137 j . CA 8702. It*x c fir Kis ne mot o.lacorl 1 171 :',11).„ 11 1111-23 kr I-4-1)2-HES)0 AP D=3 813' . ;64 , 0 83ii. 7-14 117'ICS X P4P , iii„,, . - 50 ce 8319',__ 7'X 5"0380 I-R11F TXR LIP 101-00F 4-Irr_RH H 8319' C v..t TIAN ID-4380' 4-1fr TOG,17 MP 13CR.415 VA MR* H 8328' 5", ,..,.13',.. _ _...._____ ...„_........ 0152 bpi,13-3.158' 8343 H7'X 5"SKR CG RECLOCX 1-CR,13 4.34r I / -47 ,„......„ 8353' X 4-1/2-80.13=3.99'•r.z‘..-,,264 L 80 VA M tOP HC, , 9480' • „ -0383 ow, 1)-8 778' MI MI NM ligl SWELL PACKERS Mill*:' SCHLU1A FRAC PORTS RD MYTH SEAT SZ ACTLAL SIZE OIC' DME NO SIZE TOP EPIH UN D ',. •-•-• 7 8533 3375' 5.6/7 C .137107.015 7 4-1/2' 8803 ! 192' 6 8649 325' 58:41' C 0(001/15 6 4-112- 8739 , 192" ,, ',.'MU5 8981 3.125' 5 637 C 07107)15 5 4-1/2. 9041 ' 3.97 4 9359 3_00' 5.630' C 071177/15 4 4-1/2" 9M2 3.97 •,,Mil,.. 3 90337 2.875' 5.830' C 07107115 3 4-1/7 9803 3.97 .-_-. .., 2 10475 2.375' 5.630' C 07107115 2 4-1/7 10277 3.97 . 1 101396 13611 5 630' C 07/07)15 1 Cyr 10883 3.97' 2-0'ANCHOR RR•1 1 WC U31FRAC FORT,13=3.75' JD-24901. 1 MN' 141/1'HYDLA314 DM FRA D VALVE,D.171'J WM 11121' lion. 4-1/7 6KR SHFT T501 V INFICATON SUL 0 r0 ,..1254,13C1140 I-A'D 521, -1 11131' ---- .... I 11121, 1-14-1/2'5484 GOLA11011 VALVE 152 W.ID=3958' '7. '7' NUM 4-1(2'S 3-112-110,1)=?11 14 Ifri P.413 41.13C6-/0.145821,1-f'-ifigttr Axe,e, 11172 3-1/2;44-trrA67-6; 27 1.0152w,D=3.6.58. .. COMICHTS PRUDHOE BAY INT 0412990 ONG HORIZ COMPLETION MAIL 5-42A 07M9r15 P-273 SCETRACX15.42A) REMIT Ilk, 2150550 , 0//10115 1.4C, C48_614J CORRECTORS API No. 50.024 22562 01 07'15115 3841,0•REAL 00E AFFROVAL . SEC 35.T1211,R12E,4551'I-:54 1 41,03'Hi 07122115 J0,A) .-5011-01.91,111-1 1.) 0)727115 44.3.0 Ears TO FRA12SIA431 SY!IDOL OFDER BP Exploration(A14444) Name/Size Weight Grade ID Burst, psi Collapse,psi 9-5/8" Production 40# L-80 8.835" 5750 3090 7" Liner Production #1 26# L-80 6.276" 7240 5410 4-1/2" Liner Production#2 13.5# 13Cr80 3.92" 9020 8540 ' 4-1/2" Tubing 12.6# 13Cr85 2.958" 8430 7500 • Wellhead: FMC manufactured wellhead, rated to 5000 psi. Tree: 4-1/16" 6,500psi Tubing head adaptor: 13-5/8" 5,000psi x 4-1/16" 6,500psi Tubing Spool: 13-5/8" 5,000psi w/2-1/16" side outlets Casing Spool: 13-5/8" 5,000psi w/2-1/16" side outlets • . Geological Frac Information (20 AAC 25.283,a,9) Formation MD MD TVDss TVDss TVD Frac Grad Lithological Desc. Top Bot top bot Thickness HRZ 8394 8455 6640 6650 10 0.75 Shale Kalubik 8455 8482 6650 6688 38 • 0.75 Shale TKC2B 8482 8493 6688 6694 6 . 0.585 Sandstone TKC2A 8493 8535 6694 6714 20 0.585 Sandstone TKC1C 8535 8571 6714 6729 15 . 0.65 Sandstone LCU 8571 8611 6729 6743 14 0.75 Shale TKA6 8611 8634 6743 6750 7 0.65 Silty Sandstone TKA5 8634 8712 6750 6766 16 , 0.6 Sandstone TKA4 8712 8781 6766 6770 4 • 0.65 Silty Sandstone Invert#1 8781 6770 TKA4(Invert) 8910 8781 6758 6770 12 0.65 Silty Sandstone TKA5(Invert) 8980 8910 6740 6758 18 0.6 Sandstone TKA6(Invert) 9008 8980 6731 6740 9 0.65 Silty Sandstone LCU(Invert) 9070 9008 6709 6731 22 0.75 Shale TKC1C(Invert) 9157 9070 6686 6709 23 0.65 Sandstone TKC2A(Invert) 9252 9157 6671 6686 15 0.585 Sandstone Revert#1(TKC2A) 9762 6644 Fault(TKC2A) 10130 10306 6663 6644 Invert#2(TKC2A) 10306 11190 6669 6663 Sandstone TKC1C 11190 6632 Not Drilled 0.65 Sandstone HRZ 8394 8455 6640 6650 10 0.75 Shale Kalubik 8455 8482 6650 6688 38 0.75 Shale TKC2B 8482 8493 -6688 6694 6 0.585 Sandstone bp 0 v.E.sx S-42A_Horizontal Borehole Profile _ —pin ORteell Parker •Fnc Port wesPelyeon _ East 6590 - _ ___—_ ___..._. __________. ...._______ _ __- 1 8500 — ®Q[^.'.y�.�� 6520 8580 ®CTT^!♦Rw•rtti T _... 6560 6580 ®M •'• / 8580 668 �rrr.,_ ®,1II®I �4 6560 6620�,�ore._-"a'�IIIIIQ]�1�� /,6600 8810 3'•�8 •_1 ---_'tea..,--4711.11 - 8820 6680I .._ ®� ._.�b �•.,.. ..�—� �{ 0 8606 ......_7_.......... .............. ..;A—�---� '`e1►�®��Ti�-am ee6o 6700 -W�i �L ...^ a �� - '�'r+� 5 W N 672 1 IIL�rMi� ,. A ,.s 8120 6760 ;n 8160 0790Illi „. p .._. . Enammie7eo .780 —.—.-. --�� 8780 66611111111M11 _,.,..___.__.........111=MMIN 686800. 7640 IM.111.M.01. Ill Mil 6840 8880 8781'.Blri' 6860 III MI 8680 6680 6900 Measured Depth • Mechanical Information of nearby wells(20 AAC 25.283,a, 10) Per plat above, the following wells have been reviewed for casing and cement information: • Well S-108 Spud Date 6/23/2001 Perforation Interval P&A'ed TD-MD(ft) Csg size/wt Comments/Cementing information Surface Casing: 2,857 7 S-108 is P&D'd to surface 29 7#,L-80 Intermediate Liner/Casing: Drilled intermediate section with 6-3/4"bit.Cemented with 87 Drilling/Production Liner. 5,497 5-1/2", bas of LiteCrete 12 ppg and 15.5#,1-80 57 abts of GasSiok cement at 15.8 ppg.Plug was bumped and casing was tested to 2700 psi. 3-1/2",9.3#, Ran as 3-1/7'x 5-1/2"tapered Drilling/Production Liner. 7:835 L-80 ging Tubing: 1,884 3-1/29 3#. Kill string 1-80 Production Packer N/A • Well S-31A Spud Date 12/20/1990 Perforation Interval 2 intervals from 8169'-7999'LID TD-MD(ft) Csg sizerwt Cementing information Surface Casing: 2708 13-3/8". 68#,NT-80 Intermediate Liner/Casing: 10,783 9-5/8",47#, NT-80 Drilling/Production Liner. 11,428 7",264,L- 80 3-1/2",9.24,. Tubing: 10.469 L-80 x 4- 1/2",12.6#, L-80 Production Packer 7,634 • Well S-112 Spud Date 8/7/2002 Perforation Interval 3 intervals from 8535'-6900'MD TD-MD(ft) Csg size/wt Cementing Information Surface Casing: 2,915 9-5/8".404, L-80 Drilled intermediate section with 8-3/4"bit.Cemented with 93 Intermediate Liner/Casing: 6,825 7",26#.L- bbLs of LiteCrete 12 ppg and 80 38 bbis of 15.8 ppg cement.Plug was bumped and casing was tested to 3500 psi Drilling/Production Liner. 8,535 4-1/2 12.6#,L-80 Tubing: 6,718 4-1/7' 12.6#_,L-80 Production Packer 6,658 • • Well S-106 Spud Date 11/10/2000 Perforation Interval 2 producing intervals from 7685'-7650'MD TD-MD(ft) Csg size/wt Cementing Information Surface Casing: 2,996 9-5/8",40#, L-80 Drilled intermediate section with 8-3/4"bit.Cemented with 115 Intermediate Liner/Casing: g 103 7",26#,L- bbls of 11.5 ppg cement and 55 80 bbls of 15.8 ppg cement.Plug was bumped and casing was tested to 3500 psi. Tubing: 7,630 3 1/2",9.2#, L-80 Production Packer 7,594 Well 5-11013 Spud Date RST'd 2/13/14 Perforation Interval 1 interval from 8770'-8728'MD TO-MD(ft) Csg size/wt Cementing Information Surface Casing: 2,716 9 '40#. L-80 Drilled intermediate section with 8-1/2"bit.Cemented with 85 Intermediate LinerlCasing: 8672 7",26#,L- bbls of LiteCrete at 11.5 ppg and 80 35 bbls of Class G at 15.8 ppg. Plug was bumped and casing was tested to 4000 psi. Drilling/Production Liner: 8,774 4-1/Z', 12.6#,L-80 Tubing: 8,594 4-112"' 12.6#,L-80 Production Packer 8,510 • Well S-104 Spud Date 2/9/2001 Perforation Interval 11 intervals from 8836'-6920'MD TD-MD(ft) Csg size/wt Cementing Information Surface Casing: 3.736 9-5/8°40#, L-80 Drilled intermediate section with 8-3/4"bit Cemented with 111 Intermediate Liner/Casing: 9,186 7" =L- bbls of LiteCrete at 12 ppg and 80 52 bbls of GasBlok at 15 8 ppg. Plug was bumped and casing was tested to 3500 psi Tubing: 8,736 4-1/2", 12.6#,L-80 Production Packer 6,853 • Well S-109 Spud Date: 1/17/2003 Perforation Interval: 8 intervals from 11428'-7858'MD TD-MD(ft) Csg size/wt Cementing Information Surface Casing: 3,030 9518,40#' L-80 Drilled intermediate section with 8-3/4"bit.Cemented with 131 Intermediate LinerCasing: 7820 7",26#,L- bbls of LiteCrete at 12 ppg and 80 19 bbls of Premium cement at 15.8 ppg.Plug was bumped and casing was tested to 4000 psi. Drilling/Production Liner: 11,470 4-1/7' 12.6#,L-80 Tubing: 7,651 4-1/2", 12.6#,L-80 Production Packer. 7,552 • • • Well 5-115 Spud Date 12/30/2002 Perforation Interval 2 intervals from 7400'-7250'MD TD-MD(ft) Csg sizeiwt Cementing Information 7-5/8", Surface Casing: 3,248 29 7#,S- 95/L-80 Dred intermediate section with 6-3/4"bit.Cemented with 81 5-1/2^ bits of LiteCrete at 12 ppg and Intermediate Liner/Casing: 5,382 155#—'L-8O, 40 bbls of Premium Class G cement at 15.8 ppg.Plug was bumped and IA was tested to 4000 psi. Drilling/Production Liner: 7,585 3-1f7,9.2#, L-80 Tubing: 5,399 3-1/7,9,2e. L-80 Production Packer 5,383 Summary Hydraulic Fracture Program (20 AAC 25.283,a, 12) (Detailed program included) Y.E=sx S-42A_Horizontal Borehole Profile 11111191 M...any —pin oll Swell Packer *Frac Pon 8900 Watt Paiy4on Fest 6500 8520 6540 6540 i : re6tn _ 8540 0580 TD:1335Y�6M}'TVW 'ret,/teeTlaoec 60,5An 8580 4T6T'/66M1TWu. 6620IIIMIIIM / 6560 6620� �--- ....11n11.5111111 ""' � 3 � 1r . ; 6820 6660 6640 �• © _ �+�..,� A _-.. __._..Laaetl@/Su873r8n/.___6640 - 6660 6880_' •-+v ia "ew/ .v.«:..,.,,®.«.. "�`-a- _... ._ ono moo. �..,...._ s,�. .. y ��..�'_moo 6720 T — �....." A_ ,-: 6740 A6 �� 7 suet 6740 0760 �� . . "' .r.'""- � •= v _ -8780 6760 6760�..-__----`- _._. ..._� ___,, r[_ 5 - 6780 6800 - _ _- L raaatty��..... _ trwa WU I1m8 rr �8800 6620;-- 'I _._._.__.___ —•-- 8820 8840 j i Imar1n 6860 47.3'/tTM'1Wee� 6640 6880 6680 0900 i8900 ._...__. o 3 a 0 0 Measured Depth Above is a cross-section of the wellbore. Sliding sleeves or fracports are labelled with Green diamonds and the swell packers (external casing swell packers) are labelled with the black rectangles, both of which are along the wellbore. Hydraulic fracture treatment schedule stage 1-5: FLUID PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT STAGE AVERAGE COMMENTS TYPE RATE STAGE CUM TOT JOB STAGE CUM TOT JOB STAGE STAGE CUM CUM SIZE I PPA IBPM) IBBL) (BBL) (BBL) (GAL) (GAL) (GAL) ILOS) 1L1351 Fr000wf' to 35 D Fracporr 65: Pad YF 728 200 : 200 ' 2933 :8,400: 8,400 123,165: 0 0 347 345 36 1 Fracport 65 Flat Prop add YF 128 40 50 250 2983 2,%0: 10,500 125,265:2 0'M! 2:014 349 359 '%-20 37 3 Fracpare 65: Flee Prop add YF 728 40 5D 300 3033 2,100: 12,600 127,3655,585: 7,599 354,944 s%-20: 38 6 Fracporr 65: Flat Prap add YF 128 40 50 350 3083 ; 2.100: 14,700 129,465 i 10,032 i 17,631 364.975 '%-20 i 39 8 Fracport 65 I Flat Prop add YF 128 40 n 100 450 3183 4,200: 18,900 133,665:25,049: 42.679 390,024 :%-20: 40 10 Fracporr*5: Flat Prop add : YF 128 40 ' 115(1.,,..; 600 3339 :6,300: 25,200 139,985:44,15 r 86,836 434,161 s%-20: 91 0 Fracport 65 i Drop Stage 2 Ball: YF 128 40 . : 615 ? 3348 630 25,830 140.595: 0 434,181 Hydraulic fracture treatment schedule stage 7: • • FLUID PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT STAGE AVERAGE COMMENTS TYPE RATE STAGE CUM TOT JOB STAGE CUM TOT JOB STAGE STAGE CUM CUM SIZE • PPA (BPM) (BBL) (BBL) IDSL) (GAL) (GAL) (GAL) (LBS) (LBS) Fra4port47: 3.375'meat ; 3.5''Ball (Val to Par: 130 42 0 Fra port•7: Pad YF 128 40 i 300 : 300 3646 12.600: 12,600 153,195 0 0 434.181 43 1 : Fraoport*7: Flat Prop add YF 126 40 75 375 3723 : 3,150 15,750 156,345 3,021: 3,021 437202 16-20 44 3 Frar;port*7: Flat Prop add YF 128 40 75 450 3798 : 3.150: 16,900 :153,495 8,378 11,333 445.579 116-20 45 6 Fraoport 47: Flat Prop add YF 126 40 100 550 3898 :4,200 23,100 163,695 20 063: 31,462 465,643 16-20 46 8 Fraoport*7: Flat NO,add YF 126 40 200 : 750 4098 :8,400 31,500 :172,095 50.097: 81,559 515,740 :16-20 47 10 Fraeport•7 Flat Prop add YF 126 40 300 1050 4398 :r::21; 2,600 44 100 184,695 08.314: 169.873 604,054 :16-20 48 0 :Fraopon•7 Flosh YF 128 40 130 . 1180 . 4527 5,452: 49,552 190 147 0 604,054 The maximum horizontal stress has been determined to be nearly perpendicular to the wellbore, this is based on image logs taken while drilling as well as historical information. The maximum horizontal stress means that the induced hydraulic fractures will be perpendicular to the wellbore. In order to insure the induced frac does not establish communication with Fault#1. Maximum Anticipated Treating Pressure: 5000 psi Stage 1-5: Anticipated half length: 300' Anticipated height growth: 75' Stage 7: Anticipated half length: 400' Anticipated height growth: 100' Due to the horizontal nature of the well, we are unable to specify a MD for the frac height. The above values were calculated using modeling software. Surface pressure is calculated based on a closure pressure of —0.57 psi/ft or —3800 psi, this combined with the anticipated net pressure to be built and the friction gives a surface pressure of 5000 psi at the time of flush. The frac height is primarily based on closure pressure differences between the confining shale layers harder, more brittle carbonate reservoir. Average confining layer stress is anticipated to be —0.7 psi/ft. Half length is based on confining layer stress as well as leak-off and formation modulus. Given the values, the above half lengths are calculated. Pressure Test Information (20 AAC 25.283,a,7) Per the frac program, the both the tubing and the IA will be pressure tested. The IA will be tested to 4000 psi and the tubing will be tested to 4500 psi (118% of max differential of 3800 psi). PRV setting procedures and annulus monitoring: Maximum Allowable Treating Pressure: 6500 psi (WH pressure limit) Stagger Pump Kickouts between: 6175 psi and 5850 psi (90%to 95%of MATP) Global Kickout: 6175 psi (95% of MATP) IA pop-off set pressure: 3000 psi (75%of MIT-IA) Treating line test pressure: 7500 psi Sand Requirement 465,643#20/40 Carbolite, 138,441#16-20 RC Minimum Water Requirement 5,000 bbls(pump schedule: 4035 bbls) IA Hold Pressure 2700-2900 psi (IA pop-off @ 3000 psi) OA Monitor and maintain open to atmosphere • There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. S-42a Rig Up vaMelau Timms mowed 011 Inner Annulus Lnn t 411 a icingpump for lApressnre control Boats Tick �� I (iislasa. . • I =nc Jtim L - - 1111 S Chemical Disclosure(20 AAC 25.283, a, 12) Fluid Description(s) YF128FiexD:WF128 168,126 Gal I Contains:Water,Surfactant,Breaker,Gelling Agent,Crosslinker,Scale Inhibitor,Clay Control Agent,Additive, Bactericide,Propping Agent The taro,+o:ume wired in to cables above rep.es..,,'e;ommo0on of water apo OGCreves. Notre,suppd.a by nr,-r. CAS‘,..ruder Chemical Name Mass Fraction } Water(Including Mix Water Supplied by Client)* ^68% 66402-68-4 Ceramic materials and wares,chemicals -30% 9000-30-0 Guar gum "2% 67-48-1 2-hydroxy-N,N,N-trimethylethanaminium chloride <1%___ 1319-33-1 Boronatroralcite <0.1% 107-21-1 Ethylene Glycol <0.1% 7727-54-0 Diammonium peroxidisulphate <0.1% 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1% 67-63-0 Propart-2 0l <0.1% 111-76-2 - 2-butoxyethanol <0.1% 34398-01-1 Alcohol,C11 linear,ethoxylated <0.1% 25038-72-66 Vinylidene chloride/met lacrylate copolymer <0,1%_ 68131-39-5 C12-15 alcohol etfiy oxylated <0.01% 1330-43-4 Sodium tetraborate <0.01% 7631-86-9 Non-crystalline silica(impurity) <0.01% 1310-73-2 Sodium hydroxide(impurity) <0.01% 7647-14-5 Sodium chloride <0.01% 110-17-8 Fumaric acid <0.01% 7704-73-6 Monosodium fumarate <0.01% 10043-35-3 Boric acid <0,01% 10043.52-4 _ Calcium Chloride <0.01% 91053-39-3 Diatomaceous earth,calcined <0.01% 112-42-5 1-undecanol <0.01% 14807-96-6 Magnesium silicate hydrate(talc) <0.001% 10377-60-3 Magnesium nitrate <0.001% 111-46-6 mm --___ .._.___._. 2.2"-oxydietfianol(impurity) c 0.001% 26172-55-4 5-chloro-2-diethyl-2h-isothiazolo4-3-one <0.001% 778630-3 Magnesium chloride <0.001% 9002-84-0 poly(tetrafluoroethyiene) <0.001% 125005-87-0 Diutan gum <0.0001% 7447-40-7 Potassium chloride(impurity) <0.0001% _....... 2682-20.4 2-meth 2h-Isothiazol-3-one <0.0001% 127-08-2 Acetic acid,potassium salt <0.0001% 14808.60.7 ..... _�Quartz,Crysta0ine silica <0.0001% 14464-46-1 Cristobaiite <0.0001% 64-19-7 Acetic acid impurity) <0.0001% 100% • • \.n \ r.. 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N O 1 o .�� cx o'a H 0en 0 N _6 1 I z o kn -0 v N 'Zr I 1 u, I v o •v IA N ' oiu .. o 0 0 N �' a l '" E a v OQ i V CO o i 01 Z Q 0- ti N v t3 O o .a Q a °' v U yi•. ° O N 1 1 I .n °' H Q OJ i N 0 IV 04., a . 4.-',aovOV 1 a c a o, ca c `� a a (n ' c, ._ E v t....= , U U -. t a C '- 0 • • Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Monday, August 31, 2015 2:20 PM To: Davies, Stephen F (DOA) Cc: Loepp, Victoria T (DOA) Subject: Updated well information Attachments: S-42a AOGCC Notification Suppliment V2 8-31-15.docx David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK 1 • • Unless othervise indicated,the TOC is calculated using the volumetric method. 30' W 30 E - —4. _....._ 5-105 40 N .11,4160' N 1 _- 60' N I - - 10' W' s-los • s-.1.1.0-03 50' W �. ..1111 4 0' NE '� -- S-110A . 30, W•� .� El S31 ) • S21 1-1,...0 �35 W - 532mem JS22B5115 50' x/ + 112 N'`,� �rid— 1 v _a-di;5 112H .5-109 .,T. • • riii---"'��1 S-25 5-117 `,,,� S-42 • .5-118 • 0 61 01 v 6) ) 61 6 W 6) v v v 4) 41 0. v 6) CC CO to 0C 00 to CO CO CO CO CO to co C C C C C C c c C C c 0 c cC C C C c q q q q q q q q q q 10 \ q q q 10 10 L L L L L L L L L L L L L L L L 6) 6) N6) 61 61 41 W 6) N 61 o N 6) 6) 6) 6) C_ C_ C C_ C C_ C_ C_ C_ C_ C_ - C_ C C_ C C_ )0 m 10 m 0 0 0 M m 0 n 0 m t0 to 0 •� N N N N N N N .2 N -an N N N N N aJ C C C C C C ` C �( C C ` N ` C C G ` 1y O n D > > D > r 7 7 O q D 7 D D D 1 C C C C C C C C C C C 0, '0' C CC C Ql 61 61 6) 61 6) 6) 4) 6) 6/ 6) CO 6) 0 N 6) L E E E E E E E E E E E FE E E E E 061 6 6) 61 rs. ) 6) 6) 41 6) 61 6) 6) N 61 6) 6) 4) 6) V+ 1, V LI V V V LI LI , LI V V m V V V V V 4) v N 4) Gl 61• 9) d`'yl 4) W 6) 6) 41 6) 6) 4) 6) C C C_ C_ C C_ C_ C C C C �_ C C C C C 1 J J� J J J N J J J J J �r\n A D O 'O U O V '0 \' 0 0 V 5 -0 a V O U N W QI 6, 41 41 Y 61 6l N O) V 6/ Y 6l G1 .1 C C C C C C C C a C C C 0 C C C C C V 6) 6) 6) 61 61 4) 61 41 4) 6) 4) r- 6! 4) 6) 4) 6) E E0.1 41 E Eo E E E E Fo E E E E41 4.1 E Een E o T > a > > T T J T _> T > _> T T O 7 D D O 7 7 J SO 7 O J > > 3 3 n. c 0 NO N N N N N N N N )0 N N N N N N N N N N N N N N N N N N N p N N N N N N N N N 4) 61 41 41 61 4.1 N 6) 61 6) 61 W v 4) 9) 41 0) W (U 41 41 61 6) 61 W 41 41 41 61 41 61 6) 41 61 61 41 W >- >- > >- > > > > > > > T. > > > >- >- > > >- > > > > r >- > > Z > )- > > >- > r >- > c 0 N TO DI 1 v > N 01 h ST h h a .D .D It Oh's Ohl 10 10 ul Inn tO .D .00 lD b � ID 111 tI) .D w Io lO w IL) w 7a 10 I. � IT N 2 O. 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N o V1 N Q eN-1 Z h ,n alY ,j, Vf 10 N III ,%f N to V, u, til Vl I%1 V1 ,h to ,i, 3 - . . • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Friday, August 21, 2015 10:11 AM To: 'Wages, David' Cc: Loepp, Victoria T (DOA); Wallace, Chris D (DOA) Subject: RE: S-42a additional wells (PTD #215-055) David, Checking the data provided with your email and within the application against the map displaying well intercepts within the area of review (AOR) surrounding PBU S-42A, I notice that no information was provided for PBU S-15. Could you please supply information for that well?Also, does the information provided for S-22b and S-42A also apply to 5-22 and S-42? Per 20 AAC 25.283(a)(10), additional information must also be provided for each of the 20 wells that intercept the confining zones within the AOR: 1. BP's determination for each well that it will not interfere with containment of the hydraulic fracturing fluid, and 2. Information to support each determination (measured depths to the top and bottom of the containment zones within each well, and proof that each well will not act as a conduit for the hydraulic fracturing fluid). Thanks for your help. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC From: Wages, David [mailto:David.Wages©bp.com] Sent: Thursday, August 20, 2015 4:50 PM To: Loepp, Victoria T(DOA) Cc: Davies, Stephen F (DOA) Subject: S-42a additional wells Victoria/Steve, Attached are the additional wells requiring casing and cement info. Thanks, please let me know if you need anything else. Right now we are planning on September 4-5 for the frac date. 1 • • David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK 2 • • Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Thursday, August 20, 2015 4:52 PM To: Davies, Stephen F (DOA); Loepp, Victoria T (DOA) Subject: Updated map Below is the updated map including the well names of the missed wells. Ilk 4 30' W 30' E litititha -S-105 jNKUPS • a 60' N . •" 510: S11j tN 1a' W S-0: . • `, 8th' NE 1 ��►5-1 3Q' tti' 35' tL' die 1 . S_? ii i litcdoopi Citi: �, \ I iLitt S-11 l: 000 � 50' W 5 112 • . '� 41L-112 5 104j; Aolis\ :\i\s,io\s: _ 46,4' 9gE .S-11: t s David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK 1 • • Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Thursday, August 20, 2015 4:50 PM To: Loepp, Victoria T (DOA) Cc: Davies, Stephen F (DOA) Subject: S-42a additional wells Attachments: S-42a AOGCC Notification Suppliment.docx Victoria/Steve, Attached are the additional wells requiring casing and cement info. Thanks, please let me know if you need anything else. Right now we are planning on September 4-5 for the frac date. David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK 1 • • • S-112i Spud Date: 8/7/2002 Production casing: 7" 26# L-80 set at 6825' in a 8-3/4" hole. Cemented with 218 sx of Litecrete and 184 sx of Class G. Production Liner: 4-1/2" 12.6#L-80 set from 6710'-8535' in a 6-1/8" hole. Cemented with 112 sx Class G. Tubing: 4-1/2", 12.6# L-80 set at 6718'with a packer at 6658' The 4-1/2" liner is slotted from 7650'-8533' • S-22bi Spud Date: 7/12/1997 Production Casing: 9-5/8" 47# L-80 set at 5402' in a 12-1/4" hole. Cemented with 2020 cu ft of Class G Production Lined: 7"26#L-80 from 5204'-9452' in a 8-1/2" hole. Cemented with 948 cu ft of Class G Production Liner2: 4-1/2" 12.6# L-80 from 9287'-12,221' in a 6" hole. Cemented with 348 cu ft of Class G Tubing: 4-1/2" 12.6# L-80 set at 9275'with a packer at 9218' The 4-1/2" liner is slotted from 11,927'-12,219' •S-21 Spud Date: 8/18/2002 Production casing: 7" 26# L-80 set at 9444' in a 9-7/8" hole. Cemented with 1236 sx PF 'L', 327 sx G and 88 sx class C. a top job of 96 sx of PF 'L'was also performed. Tubing: 3-1/2"9.3#L-80 set at 8903'with a packer at 8857' Perforations: 9140'-9160' 9214'-9234' . S-16 Spud Date: 7/6/1984 Production casing: 9-5/8"47# L-80 set at 10,693' in a 12-1/4" hole. Cemented with 2260 cu ft Class G and 230 cu ft of Class G and 279 cu ft of AS II Production liner: 7" 26# L-80 set from 10,436'-11,300' in a 8-1/2" hole. Cemented with 312 cu ft Class G Production ttubing: 3-1/2" 9.3#fo 10,381'with a packer at 10,381' and 2-7/8"tailpipe to 10,491' . S-10a Spud Date: 10/21/1991 Production Casing: 9-5/8" 47# L-80 set at 7900' in a 12-1/4" hole. Cemented with 1199 cu ft of Class G ans 130 cu ft of ArticSet I P&A'd • S-03 Spud Date: 1/18/1982 Production casing: 9-5/8" 47# L-80 set at 7302' in a 12-1/4" hole. Cemented with 287 cu ft of Class G and 575 cu ft of Class G Production Liner1: 7" 26# L-80 set from 6789' to 11,840' in an 8-1/2" hole. Cemented with 2300 cu ft Class G Production Liner2: 4-1/2" 12.6# L-80 set from 11,321'-12,860' in a 6" hole. Cemented with 360 cu ft Class G Tubing: 4-1/2"12.6# 13Cr80 set at 8619'with a packer at 8544' Perforations: • S 8692'-8712' S-25ai Spud Date: 11/6/1998 Production casing: 9-5/8" 47# NT80S set at 9153' in a 12-1/4" hole. Cemented with 1865 cu ft Class G Production Linerl: 7"26#L-80 set from 8912'-9650' in a 8-1/2" hole. Cemented with 263 cu ft Class G Production Liner 2: 2-7/8" 6.16# L-80 set from 8916' to 11,691' in a 3-3-4" hole. Cmeneted with 140 cu ft. Tubing: 4-1/2" 12.6# L-80 set at 8974' Perforations: 11,364-11,434' •S-32 Spud Date: 9/8/2012 Production casing: 9-5/8" 47# NT-80S set at 10,099' in a 12-1/4" hole. Cemented with 2078 cu ft Class G Production Linerl: 7" 26# 13Cr80 set from 9860'-10,113' in an 8-1/2" hole. Cemented with 332 cu ft Class G. Production Liner2: 3-1/2" x 3-1/4" x 2-7/8", 9.3/6.6/6.5# L-80 set from 9840'-11,845' in a 4-1/8" hole. Cemented with 133 sx Class G Tubing: 4-1/2" 12.6# 13Cr80 set at 9913'with a packer at 8603' and 9832' Perforations: 10,700'-11,730' • NKUPST Spud Date: 6/12/1969 Production casing: 7"23 and 26# N-80 and S-95 set at 9446' in a 8-1/2" hole. Cemented with 975 sx Well is P&A'd Old Perforations: 8892'-8984' • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday,August 12, 2015 3:22 PM To: 'Wages, David' Cc: Loepp, Victoria T(DOA); Wallace, Chris D (DOA) Subject: RE: Sundry Application to Hydraulically Fracture PBU S-42A(PTD#215-055) David, Thank you for the additional information. I count 19 well intercepts at the top of the Kuparuk that lie within a%2-mile radius of the proposed fracture interval within S-42A. Well integrity analyses for some of these 19 wells were included in BP's original application. Could BP please provide AOGCC the required integrity information for all 19 wells? That information will allow us to move this application along in the adjudication process. Thanks for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC From: Wages, David [mailto:David.Wages@bp.com] Sent: Tuesday, August 11, 2015 3:16 PM To: Davies, Stephen F (DOA) Subject: RE: Sundry Application to Hydraulically Fracture PBU S-42A (PTD #215-055) Sorry about that, Attached are the logs as well as some of the answers to your questions below. 1 • • Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Tuesday, August 11, 2015 3:16 PM To: Davies, Stephen F (DOA) Subject: RE: Sundry Application to Hydraulically Fracture PBU S-42A (PTD #215-055) Attachments: S-42A.las Sorry about that, Attached are the logs as well as some of the answers to your questions below. \ Top iiupari 10 vuple pO,PIS rtphes?ttt T i , 11 i 11 \` \ Tit'103:. F3[?' NJ�~-� _� l • 40' N •` 6)' NI% '��..+..' t_,QUO Ngig SO' W 20 W'4.,_ 80' NE , ��4� -iS - t 1 �� 3Q' r, .. ..s,5rtikligtfii�iiNl 2 i f'35 r'i• Ai „„ ® +-3 ,,, _,... LNN..... ..._________ ....__ PST' Pr !. - -------- it ! 50' W A. 112 _ .s-i i. w a • • • 5-11 c - , • • __. — Ar • 0 2630 5280 Fault throw decreases to the north mom moot mom U.S. surveyor's feet i i si, �..i I 1 b 11 I I I I I I I I I i 1.:..i f. I.'t:a:: r.=�-:,:. - ,,;:.-»', I ['.-'-,� a. .. ._ 423400 624000 David Wages o. 907.564.5669 c. 713.380.9836 W I E-AK 1 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, August 11, 2015 10:38 AM To: Wages, David Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA); Loepp, Victoria T(DOA) Subject: RE: Sundry Application to Hydraulically Fracture PBU S-42A (PTD #215-055) David, I haven't received a response to my email of August 6th (below). Please submit the requested information so that processing of BP's application can move forward. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC From: Davies, Stephen F (DOA) Sent: Thursday, August 06, 2015 2:17 PM To: david.wages@bp.com Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Subject: Sundry Application to Hydraulically Fracture PBU S-42A (PTD #215-055) David, 1. Could BP please provide digital well log data for the PBU S-42A well? Gamma ray, resistivity and (if recorded) porosity logs would be very helpful to expedite my review of this application. attached 2. What are the vertical displacements for Faults 1, 2 and 3? Per the map attached,fault throw and direction is indicated by 3. On the plat provided with the application,there are about 25 solid dots scattered, mainly in the southern half of the plat. What do those dots represent? You were right about these,they are in fact penetrations of the kuparuk(on their way to Ivishak), we are currently compiling the data required for them. 4. S-Pad is the site of many, many wells drilled to both the Aurora and Prudhoe Oil Pools. The table beneath the plat in the application appears to list only Kuparuk Pool producers How many wells(Kuparuk and Sag/Sadlerochit, producers and injectors) actually penetrate the Kuparuk sands within 1/2 mile of PBU S- 42A? Please provide an integrity analysis for every well that penetrates the Kuparuk sands within %2 mile of S- 42A. 2 • 5. I notice in the application that hydraulic fracture treatment schedules,fracture half-lengths and fracture heights are provided for Stages 1 through 5 and for Stage 7, but Stage 6 is not mentioned. Is Stage 6 an acid-only stimulation,or is this an oversight in the program? Or did I miss something? Stage 6 will be skipped at this time as it is expected that the fracs in stages 5 and 7 will access that portion of the reservoir. If we go back and open that sleeve up and find we get a jump in production,we may elect to go back and frac that zone as well. For now, and to not complicate stages 5 and 7, stage 6 will be skipped. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC 3 • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, August 11, 2015 10:38 AM To: david.wages@bp.com Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA); Loepp, Victoria T (DOA) Subject: RE: Sundry Application to Hydraulically Fracture PBU S-42A (PTD #215-055) David, I haven't received a response to my email of August 6th (below). Please submit the requested information so that processing of BP's application can move forward. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC From: Davies, Stephen F (DOA) Sent: Thursday, August 06, 2015 2:17 PM To: david.wages@bp.com Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Subject: Sundry Application to Hydraulically Fracture PBU S-42A (PTD #215-055) David, 1. Could BP please provide digital well log data for the PBU S-42A well? Gamma ray, resistivity and (if recorded) porosity logs would be very helpful to expedite my review of this application. 2. What are the vertical displacements for Faults 1, 2 and 3? 3. On the plat provided with the application, there are about 25 solid dots scattered, mainly in the southern half of the plat. What do those dots represent? 4. S-Pad is the site of many, many wells drilled to both the Aurora and Prudhoe Oil Pools. The table beneath the plat in the application appears to list only Kuparuk Pool producers How many wells (Kuparuk and Sag/Sadlerochit, producers and injectors) actually penetrate the Kuparuk sands within %z mile of PBU S- 1 • • 42A? Please provide an integrity analysis for every well that penetrates the Kuparuk sands within %2 mile of S- 42A. 5. I notice in the application that hydraulic fracture treatment schedules, fracture half-lengths and fracture heights are provided for Stages 1 through 5 and for Stage 7, but Stage 6 is not mentioned. Is Stage 6 an acid-only stimulation, or is this an oversight in the program? Or did I miss something? Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 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V a t n `.1 tit 6 V1 Vigu v d N d 7 i0 F O QI N '' N N ,r n m i V W 3 * a W >a • leI N . 2. ... r , .... w1.„. .„, x m ,__. A • f C 3 wi N 2 O V _d v in a u m 7 z ~ A W W – I I M–-——----(t."4 IS T1i d Y . A 1 ❑I 0_ O. E 0 Ce rn A - ,.. , v C .. ,. ). – N _-- c ..v a _, O N d P- :94•1 1) c C (A Q a ; v N H 2 "- C" C li ((1 ' C 2 ° o I- ly 13 i°1 G `,i �1! I\411 4 a = .a u p Ai J a .v. c (� WI ,n O n -- % -z' v T, b a d \T.1‘-‘1‘i'l m z a L. Ld 0 C-f • • Loepp, Victoria T (DOA) From: Wages, David <David.Wages@bp.com> Sent: Monday, August 10, 2015 1:44 PM To: Loepp,Victoria T(DOA) Subject: RE: PBU S-42A(PTD 215-055) Frac - Wellhead/treesaver schematic Victoria, The tree will be rated to 6500 psi,the wellhead is 5000 psi rated.There will be no treesaver as we intend to drop balls to shift the sleeves in the lower completion. 1 • • Wellhead: FMC manufactured wellhead, rated to 5000 psi. Tree: 4-1/16" 6,5OOpsi Tubing head adaptor: 13-5/8" 5,OOOpsi x 4-1/16" 6,5OOpsi Tubing Spool: 13-5/8" 5,OOOpsi w/2-1/16" side outlets Casing Spool: 13-5/8" 5,O00psi w/2-1/16" side outlets ii ', A tI t i ,,fir # ' , I:1 a .' AS.14 Z ,' Lw '�,,;,.r K x y v . IIP 411111.111"-Aim bair q 4 . N„.f ... David Wages o. 907.564.5669 c. 713.380.9836 W I E-AK From: Loepp, Victoria T(DOA) [mailto:victoria.loepo@alaska.gov] Sent: Monday, August 10, 2015 12:58 PM To: Wages, David Subject: PBU S-42A(PTD 215-055) Frac - Wellhead/treesaver schematic Dave, 2 • • Please send wellhead/treesaver schematic. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeDDaalaska.gov 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 Victoria Loepp 01(907)793-1247 or Victoria.Loeoo@alaska.gov 3 • • Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Monday, August 10, 2015 1:33 PM To: Wages, David <David.Wages@bp.com> (David.Wages@bp.com) Subject: RE: PBU S-42A(PTD 215-055) Frac -Wellhead/treesaver schematic Also, do you have intermediate casing cement information for Well S-31A? From: Loepp, Victoria T(DOA) Sent: Monday, August 10, 2015 12:58 PM To: Wages, David <David.Wages@bp.com> (David.Wages@bp.com) Subject: PBU S-42A(PTD 215-055) Frac-Wellhead/treesaver schematic Dave, Please send wellhead/treesaver schematic. Thanx, , ,)( Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeooi alaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria,Loeao4alaska.gov 1 yor Tki • • 0wP,���///js THE STATE Alaska Oil and Gas ��r�,,�I;,-s����, o A T � A T A Conservation Commission S . - . = 333 West Seventh Avenue O r rh;, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 F ALAS'' S Fax: 907.276.7 542 www.aogcc.alaska.gov Ken Allen Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU S-42A BP Exploration(Alaska), Inc. Permit No: 215-055 Surface Location: 4181' FSL, 4503' FEL, SEC. 35, T12N, R12E, UM Bottomhole Location: 1646' FSL, 291' FEL, SEC. 27, T12N, R12E, UM Dear Mr. Allen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, A , 10 ).,„v_ _ Cathy 5. Foerster Chair DATED this day of March, 2015. STATE OF ALASKA RECEIVED ALI)IL AND GAS CONSERVATION CON,ON MAR 1 7 2015 PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a.Type of work: 1 b.Proposed Well Class:.®Development Oil 0 Service-Winj . ®Single Zone 1 c.Specify if well is proposed for: 0 Drill 0 Lateral 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas ❑Gas Hydrates . 0 Redrill 0 Reentry 0 Exploratory ❑Service-WAG 0 Service-Disp 0 Geothermal 0 Shale Gas 2.Operator Name: 5.Bond ' 0 Blanket 0 Single Well 11.Well Name and Number: BP Exploration(Alaska) Inc. Bond No 6194193 . PBU S-42A • 3. Address 6. Proposed Depth: 12.Field/Pool(s) P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 11296' ' TVD 6752' . Prudhoe Bay/Aurora 0& 4a.Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: ADL 028257&028258 4181'FSL,4503' FEL, Sec. 35,T12N, R12E, UM • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 816'FSL,2890'FEL, Sec.26,T12N, R12E, UM July 20,2015 ' Total Depth 9.Acres in Property: 14.Distance to Nearest Property: 1646' FSL,291' FEL, Sec.27,T12N, R12E, UM 2560 9050' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 84.05' • feet 15.Distance to Nearest Well Open Surface: x 618930 • y-5980384 • Zone- ASP4 GL Elevation above MSL: 37.1' • feet to Same Pool: 1050' 16.Deviated Wells: Kickoff Depth: 3047' feet . 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 109 degrees • Downhole: 7�y'�3 /S.'S Surface: ,28,4 ' Z � ,,.5 ; /s-- 18. Casing Program Specifications Top Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 8-1/2" 7" 26# L-80/13Cr85 VT-HC 8439' Surface Surface 8439' 6757' 80 sx LiteCrete, 196 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 VamTop 3007' 8289' 6668' 11296' 6752' Uncemented Sliding Sleeves w/Swell Packers 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 10692' 8964' 9900' 10636' 8960' 9887' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 20" 260 sx Arctic Set(Approx.) 35'- 115' 35'- 115' Surface 3043' 9-5/8" 850 sx CS III, 300 sx Class'G',300 sx CS II 34'-3077' 34'-3076' Intermediate 9342' 7" 270 sx Class'G', 160 sx Class'G' 33'-9375' 33'-8780' Production Liner 1478' 4-1/2" 175 sx Class'G' 9214'- 10692' 8669'-8964' Perforation Depth MD(ft): 9378'-10530' Perforation Depth ND(ft): 8784'-8951' 20.Attachments: ®Property Plat 0 BOP Sketch 0 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and correct: Contact John Rose,564-5271 Printed Name Ken Allen Title Engineering Team Leader Email John.G.Rose@bp.com 4366 Signature ,2:„... 1C., ~------.-,,,,,, Phone 564- Date •--2��R1/45.- Commission Use Only Permit To Drill ..- API Number: Permit App I a See cover letter for Number: S �s 50-029-22662-01-00 X11 other requirements: Conditions of Approval: If box is checked,well may not be used to explore for,test,or pro uce coalbed methane,gas hydrates,or gas Er Other: �jp fr5 f ¢�, SU O 5 contained shales: �/ Samples Req'd: Oyes 12/No Mud Log Req'd: ❑Yes L�No -h yt v/a v pr-t-VE-Prfrr f-r,f f 2560 pS i H2S Measures: g Yes 0 No Directional Survey Req'd: DYes 0 No Spacing exception req'd: 0 Yes E(No inclination-only svy Req'd: 0 Yes lallo APPROVEDB`� APPROVED BY ? 5 S1 COMMISSIONER THE COMMISSION Dat G� Form 10-401 Revised 10/ 012 T p1 \i i al' o 24 m nths from the date ppr val(20 AAC 25.005(g)) Submit Form and Attachments In Duplicate Vrc. 3/t9/i5• � _ -e .077/ ,:1 3 -/ • • Ua To: Alaska Oil &Gas Conservation Commission From: John Rose, ODE Date: March 17, 2015 Re: S-42A Permit to Drill The S-42A well is scheduled to be spudded by Parker 273 in mid-July, 2014 as a Kuparuk producer. The planned well will be a 2 string RST with new 8-1/2" hole being drilled from a 9-5/8"whipstock at-3047' MD to the top Kuparuk casing point at 8439' MD where 7" casing will be run and cemented prior to drilling the 6-1/8" production hole to the final well TD at 11,296' MD where a final 4-1/2" swell packer / frac port completion well be run to that depth. With the well drilled and cased, a 4-1/2" single packer chrome completion will be run as the final completion for this well. The maximum anticipated surface pressure from the Kuparuk sands with a full column of gas from TD to surface is 2796 psi (assumes 9.9 ppg as pore pressure in the Kuparuk A sand). This well will be drilled by Parker 273 using their 5,000 psi four preventer BOP stack (3 rams and an annular). The BOP rams and annular will be tested to 3500 psi. A detailed operations summary is included with the permit application. Below is a brief summary of planned drilling operations: 1. P&A the parent well with 2 cement plugs and make tubing cut per the Sundry request. 2. Move in and rig-up Parker 273. 3. NU and test BOP's. 4. Pull 4-1/2" tubing. 5. Cut and pull 7" casing. 6. Make whipstock departure from the existing 9-5/8" surface casing at 3047' MD. 7. Drill 8-1/2" intermediate hole to top of the Kuparuk sands at 8439' MD. 8. Run 7" casing and cement to 500' MD above the top of the NA sands (TOC at-5661' MD). 9. Drill 6-1/8" horizontal Kuparuk production hole to TD at-11,296' MD. 10. Run a 4-1/2" swell packer/frac port production liner. 11. Run 4-1/2" chrome completion tubing. 12. Rig down and move off the well. In addition to a planned well summary, a directional plan and proposed completion diagram is attached to the permit application. If there are any questions concerning information on S-42A, please do not hesitate to use the contact information below. John Rose Office: 907-564-5271 Cell: 907-748-5223 Email: rose11@bp.com Attachments: Well Schematic Directional Plan BOPE Equipment Schematics S-42A PTD Page 1 3/17/2015 • i Planned Well Summary Well S-42A Well Kuparuk Target Kuparuk Type Producer Objective C-sands Current Status RST Estimated Start Date: 07/20/2015 Time to Complete: 30.7 Surface Northing Easting Offsets TRS Location 5,980,384 618,930 1099' FNL /4503' FEL. 12N 12E sec 35 Northing Easting TVDss Offsets TRS TKUP 5,982,325 620,510 -6670' 4464' FNL / 2890' FEL 12N 12E sec 26 BHL 5,983,112 617,815 -6668' 3633' FNL / 291' FEL 11N 12E sec 27 Planned 3047' MD/-2962' TVDss Planned TD: 11,296' MD / -6668' TVDss KOP: Rig: Parker 273 • BF-RT: 46.95' RTE (ref MSL): 84.05' . Directional — Schlumberger P3 KOP: 3047' MD Maximum Hole Angle: -64° 8-1/2" intermediate section -109° in the 6-1/8" production section Close Approach Wells: S-15, S-31 & S-112 (all wells to be SI with tubing tail plugs and minor risk to allow drill-by) Survey Program: 3050' MD to 3550' MD = GYD-GC-SS (single shot gyro) 3550' MD to 11,296' MD = MWD+IFR+MS-WOCA Nearest Property Line: 9050' • Nearest Well within Pool: 1050' ' S-42A PTD Page 2 3/17/2015 • S Casing/Tubing Program Hole Casing / Wt/Ft Grade Conn Length Top (ft) Bottom (ft) Size Tbg O.D. (ft) MD/TVDss MD/TVDss 8-1/2" 7" 26# L-80 VT-HC 8139 Surface 8139/-6492 8-1/2" 7" 26# 13Cr-85 VT-HC 300 8139/-6492 8439/-6673 6-1/8" 4 '/2" 12.6# 13Cr-85 VamTop 3007 8289/-6584 11,296/-6668 Tubing 4 1/2" 12.6# 13Cr-85 VamTop 8294 Surface 8294/-6589 Mud Program Intermediate Mud Properties: LSND 8-1/2"hole section Depth Interval Density PV YP API FL HTHP FL MBT pH (PPM 3047' (DrillOut)— g0-9.6 • 10 - 15 18 -25 <8 NC <20 8.5 - 9.5 7974' (TCM1) 7974' (TCM1)— 8439' (7" Csg Pt) 10.4 10 15 18 -25 <8 NC <20 8.5 9.5 Production Mud Properties: Water Based/Polymer/Calcium Carbonate DIF 6-1/8" hole section Density PV YP Low Shear Depth Interval API FL Rate MBT pH (ppg) (cp) (Ib/100ft2) Viscosity 8439' — 11,296' 10.4 • 10 - 15 12 - 18 <12 15000-30000 <4 8.5 -9.5 Logging Program 8-1/2"Intermediate: Sample Catchers—as required by Geology Drilling: Dir/GR/Res/PWD Open Hole: None Cased Hole: None 6-Y8" Production: Sample Catchers—as required by Geology Drilling: Dir/GR/Res/Neu/Den - Open Hole: None Cased Hole: None Cement Program Casing Size 7" 26#, L-80 & 13CR80 Intermediate Casing Basis: Lead: 1778' of open hole x 7" annulus + 30% excess Lead TOC: 5661' MD (500' above top NA) Tail: 1000' of open hole x 7" annuls + 30% excess + 80 ft shoe track Tail TOC: 1000' MD above casing shoe Total Cement Lead 40 bbls, 223 cuft, 80 sxs of 11.5 ppg LiteCrete, Yield: 2.77 ft3/sx (with gasblok) Volume: Tail 25 bbls, 143 cuft, 123 sks of 15.8 ppg Class G, Yield: 1.17 ft3/sx Surface Proximity Issues TBD Sub-Surface Proximity Issues 3 wells fail Major Risk analysis as follows: S-15, S-31 & S-112 (all wells to be SI w/deep-set plug and minor risk to allow drill-by). S-42A PTD Page 3 3/17/2015 I i Formation Tops S-42A wp03 - Estimated Most Likely Depth Fluid Formation Formation Top Pore Pressure Uncertainty Type (TVDss) (EMW ppg) (+I-TVD ft) (for sands) SV3 2,680 8.60 WA Hydrates SV2 2,850 8.60 WA Hydrates KOP 2,962 8.60 Wtr 9 518"Surface Csg(Parent 3,004 8.60 N/A Wtr Wellbore) SV1 3,175 8.60 N/A Free Gas UG4 3,510 8.85 +/-10 ft Wtr/Hvy Oil UG4A 3,560 8.85 +/-10 ft. Hvy OIlIWtr UG3 3,880 8.85 +/-20 ft. Hvy OIlNVtr UG1 4,440 8.70 +/-20 ft. Wtr/Hvy Oil UG_MA 4,720 8.70 +/-20 ft. Wtr/Hvy Oil UG_MB1 4,775 8.85 +/-20 ft. Hvy OiINVtr UG_MB2 4,820 8.70 +/-20 ft. Hvy OiINVtr UG MC 4,850 8.70 +/-20 ft. Hvy Oil!Wtr NA 4,930 8.70 +1-30 ft. Hvy Oil/Wtr NB 4,940 8.70 +/-30 ft. Hvy Oil/Wtr NC 4,980 8.70 +/-30 ft. Hvy OIINVtr OA 5,055 8.60 +/-30 ft. WtrNisc Oil OBA 5,085 8.60 +/-30 ft. WtrNisc Oil OBD 5,215 8.60 +/-30 ft. WtrNisc Oil OBF 5,295 8.60 +/-30 ft. WtrNisc Oil OBF_BASE 5,320 8.60 +/-30 ft. WtrNisc Oil CM2 6,290 9.40 +/-50 ft. Wtr/GCM CM 1 (Slump?) 6,350 10.00 +1-50 ft. Wtr/GCM TI-RZ 6,640 10.00 +/-30 ft. GCM TKLB 6,650 10.00 +/-30 ft. GCM TKUP 6,670 9.54 +/-30 ft Oil/Gas 7'casing(-5'MD 6,672 9.54 +/-30 ft. Oil/Gas below TKUP) TKC1C 6,705 9.54 +/-30 ft. Oil/Gas LCU(TKB1) 6,725 9.90 +/-30 ft. Oil/Gas TKA6 6,740 9.90 +/-30 ft. Oil/Gas TKA5 6,745 9.90 +/-30 ft Oil/Gas Invert 1 (lwr A5) 6,760 9.90 +/-30 ft. Oil/Gas TKA5-Inv 6,740 9.90 +/-30 ft. Oil/Gas TKA6-Inv 6,720 9.90 +/-30 ft. Oil/Gas LCU(TKB1)-Inv 6,700 9.90 +/-30 ft. Oil/Gas TKC1C-Inv 6,680 9.54 +/-30 ft Oil/Gas Revert 1 (C2E) 6,630 9.54 +/-30 ft. Oil/Gas Invert 2(CIC) 6,670 9.54 +/-30 ft. 011/Gas Revert 2(C2E) 6,620 9.54 +/-30 ft Oil/Gas TKC2A-rev2 6,642 9.54 +/-30 ft Oil/Gas TKC1 -rev2 6,655 9.54 +/-30 ft. Oil/Gas TD 6,668 9.54 +/-30 ft. Oil/Gas LCU(TKB1)* 6,670 9.90 +/-30 ft. Oil/Gas TKA6* 6,700 9.90 +/-30 ft. Oil/Gas TKA5* 6,710 9.90 +/-30 ft. Oil/Gas TKA4* 6,735 9.90 +/-30 ft. Oil/Gas TKA4* 6,735 9.90 +/-30 ft. Oil/Gas S-42A PTD Page 3 3/18/2015 4110 • Hydrogen Sulfide S-Pad is considered an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Level Reading Date Comments Parent Well(if sidetrack) S-42 66 / 9/25/2014 #1 Closest SHL Well H2S S-43 28 1/8/2015 Level #2 Closest SHL Well H2S S-41A 16 2/17/2013 Level #1 Closest BHL Well H2S S-15 None in Fault Separated Level Database #2 Closest BHL Well H2S S-16 10 6/8/2011 Fault Separated Level • #3 Closest BHL Well H2S S-109 12 2/13/2014 Level #4 Closest BHL Well H2S S-118 10 1/19/2013 Level Max.Recorded H2S on S-201 180 3/9/2012 Schrader Well Pad/Facility Other Relevant H2S Data S-27B 140 ppm on 1/10/2012 (H2S alarms from rigs,etc.) Faults Formation Where Encounter Fault MD Intersect TVDss Intersect Throw Direction Uncertainty Lost Circ Potential and Magnitude Fault#1 -Kuparuk production hole 10,050.0 6,653.0 West, 30-50 ft. +/-200 ft. MD Medium Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject - at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal/Contact the GPB Environmental Advisors (659-5893) for guidance. S-42A PTD Page 4 3/17/2015 • Well Control The 8-1/2"and the 6-W hole sections will be drilled with well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. BOP test frequency for S-42A will be 14 days with function test every 7 days. Except in the event of a significant operational issue that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. 8-1/2"Intermediate Interval Maximum anticipated BHP 3309 psi at @ TKUP at 6670' TVDss (9.54 ppg EMW) Maximum surface pressure 2642 psi (.10 psi/ft gas gradient to surface) 25 bbl KT with min 12.5 ppg LOT(50 bbl KT with min 13.5 ppg LOT) Kick tolerance Assumes a 9.54 ppg PP + .5 ppg kick intensity with 10.4 ppg MW. (13.8 ppg LOT on original 9-5/8"casing on 4/7/96) Planned BOP test pressure Rams test to 3500 psi/250 psi Annular test to 3500 psi/250 psi Integrity Test—8-1/2" hole LOT after drilling 20'-50' of new formation below mid-9-5/8" window 7" Casing Test 3500 psi surface pressure s 6-1/8" Production Interval �(�� °' Maximum anticipated BHP 3470 psi at @ TSat 6740' TVDss (9.9 ppg EMW) Maximum surface pressure 2796 psi (.10 psi/ft gas gradient to surface) Infinite with a minimum 10.7 ppg frac gradient Kick tolerance Assumes a 9.9 ppg PP + .5 ppg kick intensity with a 10.4 ppg MW. Planned BOP test pressure Rams test to 3500 psi/250 psi Annular test to 3500 psi/250 psi Integrity Test—6-1/8" hole FIT after drilling 20'-50' of new hole, target>10.8 ppg FIT 4-1/2" Liner Top Packer 3500 psi surface pressure Test Planned completion fluids 10.3 ppg Brine/6.8 ppg Diesel S-42A PTD Page 5 3/17/2015 I 0 Parker 273 BOPE Schematic PARKER 273 BOP STACK RAM TYPE BOP DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE BOP 13 5/8"-5M I fi 13 5/8"-5M STUDDED TOP 13 5/B"-5M FLANGED BOTTOM 411 - 'r?''' W/(2). 14" 1.1L2 OPERATOR, UPPER CAVITY ,t/ s.,. ANNULAR BOP AND (2) 14" SLK W/BSTR OPERATOR, T-5-`1- Intnnfl.ser-m SHAFFER LXT 13 5/8"-54, 13-5/8" 5M STUDDED TOP LOWER CAVITY 13-5/8" 5M FLANGED BOTTOM o 1 0 1 I DRILLING CROSS: I I 13 5/8"-5M FLANGED TOP ..tEr I 1 / ...• I t 13 5/8"-5M FLANGED BOTTOM ci,i w(2) 3 1/8"-5M SIDE OUTLETS i • .J.?..2.., • r ' .1 I ,21- . *0 _Li____I C 3 ii aV--- .,,,-;-.-•:,,., c)d,..E, H C 3 1 I t j... d KILL LINE: 2-1/16" 5M FLEX HOSE ----"" iT. . ' ' 1 S'' ,i--,. .„,-- . 2-1/16" 5M X 3-1/8" 51.1 D S.A. 3-1/8" 51.1 FLANGED MANUAL GATE VALVE I -- , 3-1/8" 5M FLANGED HYDRAUUC GATE VALVE . L..,. '-- IINNM= . '1...............m1................m1.1 . r 11 - 1 -1 CHOKE LINE: RAM TYPE BOP- 3-1/8" 5M FLANGED MANUAL GATE VALVE SHAFFER LAT SINGLE 13 5/8" 5M 13 5/8"-5M STUDDED TOP 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8"— 5M FLANGED BOTTOM 3-1/8" 5M FLEX HOSE W/(2) 14" UL2 OPERATOR S-42A PTD Page 6 3/17/2015 • S S-42A RST Operations Plan Pre-Riq Work 1. MIT-OA to 3000 psi. 2. Perform a cement P&A of existing production hole perforations by pumping/squeezing a volume of cement(-16 bbls) equal to the 4-1/2" liner/7" casing volume from 9092' MD to 9900' MD. 3. Through tubing punch at-9090' MD and circulate out the IA with seawater. 4. Full-bore DPZ isolation cement plug from 9092' MD to 6583' MD (both side of tubing / -96 bbls cement) leaving seawater and a 2000' diesel cap in well (on both sides of the tubing). 5. Cut tubing at 4500' MD. 6. CMIT-TxIA to 3500 psi, PPPOT-IC to 3500 psi and PPPOT-T to 5000 psi. 7. Function LDS. 8. Install TWC and test(2000 psi from below/3500 from above). 9. Configure annular valves and install DHT. 10. Remove well house. 11. Rhino line the cellar. 12. Level the pad and prepare location for rig move. Proposed Drilling Riq Operations: 1. MIRU Parker 273. 2. Test TWC from below to 3,500 psi for 30 minutes. 3. Nipple down tree. Nipple up and test BOPE to 3,500 psi. 4. Pull TWC with lubricator. 5. RU hard lines to BOP. Circulate out diesel freeze protection through choke to tiger tank with clean 8.5 ppg seawater. 6. RU and pull the 4-1/2"tubing from the pre-rig jet cut at-4500' MD. 7. RU E-Line USIT to confirm cut point for the 7" casing. 8. If USIT confirms, cut 7" casing at the existing 9-5/8" casing shoe (mechanical cut on DP at current WBS TD depth at-3077' MD) and circulate out the freeze protect fluids from the OA. 9. RU and pull 7" from cut. 10. RIH with 9-5/8" clean out assembly to just below the casing shoe at 3077' MD. 11. RU E-line w/GR/CCL log and set EZSV at-5' above the casing shoe at-3072' MD and pressure test to -3000 psi for 30 min (chart test). 12. PU 9-5/8"whipstock, bottom trip anchor and 8.5"window milling assembly(to include full gauge string mills) and RIH to the top of the EZSV and orient and set the whipstock. 13. Swap the well over to 9.0 ppg fresh water LSND milling fluid. 14. Mill window in the 9-5/8" casing plus 20' of new formation. • 15. Perform LOT and POH for drilling BHA. V 16. MU 8-1/2" rock bit and mud motor drilling BHA, GR/RES/PWD, UBHO (Gyro) or GWD, and RIH. 77-1,, 5 17. Kick off and drill ahead to end of the build section of the 8-1/2" hole (-4537' MD) and POH for new • BHA. PTD 18. MU 8-1/2" PDC bit and RSS drilling I3HA, GR/RES/NEU/DEN/PWD and RIH. 19. Drill 8-1/2" intermediate interval to section TD in TKUP at-8434' MD weighting-up the drilling fluid using spike fluid maintaining the following density ranges: • KOP-TCM1: 9.0 - 9.6 ppg S-42A PTD Page 7 3/17/2015 • TCM1 -TD: 10.4 ppg . 20. Circulate and condition the hole at TD, wiper trip as needed and TOH to run the7" casing. 21. Change upper VBR pipe rams to 7" casing rams and test to 250 psi low/3,500 psi high. 22. Run and cement 7", 26#, combination 13CR& L-80, VAM TOP HC casing to TD. 23. Change upper 7" casing rams to VBR pipe rams and test to 250 psi low/3,500 psi high. 24. MU 6-W drilling BHA with PDC bit on RSS with GR/RES/NEU/DEN. RIH to the landing collar and test the casing to 3,500 psi for 30 minutes. 25. Displace the well to 10.4 ppg Flo-Pro NT fluid (20% salinity) prior to fully drilling out shoe track. 26. Drill 20' of new formation and perform a FIT. 27. Drill 6-1/8" hole to TD at 11,495' MD. • 28. Circulate bottom ups, condition the hole as necessary and back-ream to the 7" shoe, MAD passing as required. 29. Trip in hole to TD and circulate/condition the hole as necessary until shakers clean up. POH on elevators. 30. MU and run 4-W 13.5# 13CR Hydril 521 frac port/"water" swellpacker liner to TD. 31. Displace the 10.4 ppg high salinity water based mud in the open hole around the liner with a 10.4 ppg low salinity water base mud. Drop a ball behind the required volume of low salinity water base mud volume and displace with 10.3 ppg brine to land the ball on the ball seat in the toe of the well. NOTE: The 10.3 ppg NaCl/Naar brine (-4 deg LCTD) is designed to provide -75 psi over-balance to the 9.9 ppg Kuparuk formation when the well is freeze protected with -100' diesel cap.) 32. When the ball lands, set liner hanger and liner top packer. Prior to pulling the running tool, perform a pressure test on the liner top packer by testing the 7" casing x drill pipe annulus to 250 psi low/3,500psi high for 5 min low/30 min high. 33. Pull liner running tool above liner top. Displace well to clean 10.3 ppg Brine. 34. POH, L/D the liner running tool. 35. R/U and run a 4-W, 13.5#, 13CR, VAMTOP tubing completion with GLMS. Space out and land the tubing with tubing tail inserted into the liner tieback sleeve. 36. Make up tubing hanger per Cameron Rep. Land the tubing hanger, and run in lock down screws. 37. Reverse circulate filtered 10.3 ppg brine and corrosion inhibitor into the tubing x casing annulus. 38. Drop ball/rod and set packer and individually test the tubing to 3,500 psi for 30 minutes. 39. Bleed tubing pressure to 2,000 psi and pressure test the IA to 250 psi low/3,500 psi high for 5 minutes low/5 minutes high. 40. Hold pressure on the IA and bleed tubing pressure to zero, shearing the DCK shear valve. Pump both ways to confirm circulation ability. 41. With landing joint still rigged up, reverse circulate diesel freeze protect using rig injection pump (freeze protect on both sides of the tubing to -100' MD). 42. Allow diesel to U-tube, drain stack, and rig down landing joint. Monitor well for 1 hour to confirm well is dead. 43. Install TWC and test from above to 250 psi low/3,500 psi high for 5 minutes each and from psi low/ psi high for 5 minutes low/30 minutes high. below to 250o 3,5009 9 44. Nipple down the BOPE. Nipple up the adaptor flange and double master valves and test to 5,000 psi with diesel. 45. Ensure"Heet" is left on top of the TVVC and only diesel (no water) is left in the tree. 46. Install all annulus valves and secure the well. Ensure T/IA/OA all have two barriers in place. 47. RDMO. S-42A PTD Page 8 3/17/2015 • s Planned Post-Riq Operations: 1. Pull TWC/BPV. 2. Pull B&R. 3. PT liner lap. 4. Frac well. 5. Contingent FCO. 6. Install LGLV's. 7. Perform ASRC flowback and well test. S-42A PTD Page 9 3/17/2015 i S-42A Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: A. De-completion Work: Cased hole work/ no issues as the P&A/ DPZ isolation cement plugs will be in place and the 7" casing tested to 2500 psi. B. Intermediate Hole: 8.6—8.85 ppg PP from KOP to TCM2—Mud weight specification 9.3 ppg • 9.4— 10.0 ppg PP from TCM2 to TKUP casing point— mud weight specification 10.4 ppg • C. Production Hole: 9.54 — 9.9 ppg PP through the Kuparuk sands — mud weight specification 10.4 ppg with 10.3 ppg completion brine. II. Lost Circulation/Breathing A. Intermediate Hole: Breathing and/or lost circulation associated with excessive circulating pressures - should be considered a possibility on this well. B. Production Hole: Breathing and/or lost circulation is a risk with the single anticipated fault crossing with —30-50 ft of throw. If lost circulation becomes a problem, follow the LCM decision tree provided in the drilling program. Utilize good hole cleaning practices to avoid high ECD and prevent pack-off potential which could induce losses. Ill. Integrity Testing Test Point Test Depth Test type EMW(Ib/gal) 9-5/8"Shoe 20'-50'from the 9-58"Shoe LOT 12.5 ppg minimum(25 bbls) 13.5 ppg target(50 bbls) 7"shoe 20'-50'from the 7"shoe FIT 10.7 ppg minimum(infinite) IV. Hydrogen Sulfide (H2S) A. S-Pad is an H25 site. Recent H2S data from the pad is as follows: Parent Well(if sidetrack) S-42 66 9/25/2014 #1 Closest SHL Well H2S Level S-43 28 1/8/2015 #2 Closest SHL Well H2S Level S-41A 16 2/17/2013 #1 Closest BHL Well H2S Level S-15 None in Database Fault Separated #2 Closest BHL Well H2S Level S-16 10 6/8/2011 Fault Separated #3 Closest BHL Well H2S Level S-109 12 2/13/2014 #4 Closest BHL Well H2S Level S-118 10 1/19/2013 Max.Recorded H2S on Pad/Facility S-201 180 3/9/2012 Schrader Well Other Relevant WS Data S-27B 140 ppm on 1/10/2012 (H2S alarms from rigs,etc.) V. Faults Formation Where Encounter Fault MD Intersect TVDss Intersect Throw Direction Uncertainty Lost Circ Potential and Magnitude Fault#1 -Kuparuk production hole 10,050.0 6,653.0 West,30-50 ft. +1-200 ft.MD Medium VI. Anti-Collision Issues CONSULT THE S-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. S-42A PTD Page 10 3/17/2015 . 4111 1141:= 4'ON VYELLIEAD= FMC i.Fri'No tsWAS:WILL S 1W A Noe'"" ACRAKNi= _:i PROPOSAL 4$'— ` E -585C $ — OMETH6aL t>ixit UE11= 71.79 ��I fie/ BF. = 37.1' KM= 304T 00MX-cTCR —I WM IMX Anpk= 1109'Qt 8883 24r 215.# ' I o" H4..117 WS X NP,D=3.813' DatunMD- 8506' Datum IVO- 6700'SS -- I9-618`BKR VAIPSTOCK(XX1XX/15) H 3047' 9-sre'OCia,400,L-80 81RS,0=a.e3Y H MST 9-sm.____ClIP(XWXX/15) -1 3022' I p I AK.LOUT WNIOW(S 42A) -304r--3083' Minimum ID=3813"(§ cis LFr Notes 4-1/2"HES X NIPPLE Sr rD TVD Der TYPE VLV 1ATT74 PORT DATE 5 4 1114'HOLEiip 3 2 1 ITOPOF CF f„,,„ ,,J15)H 9M1' . - •r +. 7"CSG.26N,L-80,VT HC --8139'MDi111• '`� 8148' 4-1/2'10S X NJ,D=&aril 4-112"NDPG Sapphire Gauge at-41161`MD r r IL` 8176' 7"X41/1'HES TNT AR.O=3.858' ir-4, 8206' 4.1/2"wFSXMP,D=3.813'I I I 7 ' :* , 8281' H4-1/2"HES X F1'.D=3.813"1 ir P.4 (TOP OF4-//2'LNt 9299' - ,`. 8299' H7'X5"eM61FIRD-EZXPLIP w/TEBFC,0=4:.340' I 4-1/2'TBG,12.e#,13CR-86 VAM TOP, 8295` -'•�4i! 1N%' 1/2"'ALBS,0=3.958'1 .0152hpf,D=3.958' eN ~'+s' g3zr I-irx5"SKRH521FLD0.Ot3a HER.D=4.320' I IN r` •,. r: 8322 5'X 4-12"XO,0=3.930'I N r CSG,2M,1301,VAN TOP 8439 k 5chkm FRAC PORTS .0383 bpr,ID=8278' 9-08HOLE (A1 pods but low ar frac port ba/activated w/low Or _INET port befog hydraric.) 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C) N N N N N N N �y CO N N N N N N N N N N N N N CO N N Q U o N N r r r O N O m m CO mm CD CD C " (n rl OOO mm C) COCA LO LO CO(nO rN 0)0)Oi m N O (O sisia a a4 a)rnrnmrnrnm CO mmmmmmm C (0 CL 0 .▪17. 0000 700 0) ON0000C CO UCD CD Cs)l UIa01 o ON r mm0)OONN 0 0 0 0 0 0 0 O O O O r r r p CO • co r N a C O H 0 E 2 o Z m CD U m m U O Z 0 iE U w U 0)F w0 to 0 r i o I , i , lI / ) ! a7 .0.()1-111105 1 I 1 1 ili gga gg g g &i 1 g S R S R ii. onam. 1 aNor, 1 Il� a :i I I8 Want. _ 0 _ - Nyy N - O -(N"1 _ N - 0 _...... __... ._.... __. ...._.. .. ..... _.. _..... _0 - N - i(1 N NN _ fA -No - N _.. O _ M O ....._. _.. ........_ ___..... ..._. ,...... _.___ ___._ .... ... _..,. ._.. ....... .......-O o ._ _. N _ O p _- d - - O - M - v - a A N M C N ,(d .4 N 0 Q 2 CSJ CC m 1 aati)aa m ` o a _ c 0 m• t_o n mB 1111 , 11'11111 ill I II I II I II 1111 III ' ' 11111111 ' ( 11 ' 11111111 I 0 N O N O N O N O N O O II) O t` (13 Lin U] O M M N N (uin}sn pi)uoijoiedag oijuao aquao 4111 • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ardnate Reference: Well S-42 Project: Prudhoe Bay TVD Reference: S-41A plan©84.05usft(P-273 plan) Reference Site: PB S Pad MD Reference: S-41Aplan @ 84.05usft(P-273 plan) Site Error. 0.00usft North Reference: True Reference Well: S-42 Survey Calculation Method: Minimum Curvature Well Error. 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan&42A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#3 S-42A Offset TVD Reference: Offset Datum Reference Plan#3 S-42A Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 5.00usft Error Model: ISCWSA Depth Range: 3,015.43 to 11,295.68usft Scan Method: Tray.Cylinder North Results Umited by Maximum center-center distance of 1,324.87usft Error Surface: Elliptical Conic Survey Tool Program Date 2/11/2015 From To (usft) (uslq Survey(Wellbore) Tool Name Description 223.66 3,015.43 S-42 Sry 1 MIND(S-42PB1) MWD MIND-Standard 3,015.43 3,050.00 Plan#3 S-42A(Plan S-42A) MWD MWD-Standard 3,050.00 3,550.00 Plan#3 S-42A(Plan S-42A) GYD-GC-SS Gyrodata gyro single shots 3,550.00 5,050.00 Plan#3 S-42A(Plan S-42A) MWD MWD-Standard 3,550.00 8,430.00 Plan#3 S-42A(Plan S-42A) MWD+IFR+MS-WOCA MWD+FR+Multi Station W/O Crustal 8,430.00 9,930.00 Plan#3 S-42A(Plan S-42A) MWD MWD-Standard 8,430.00 11,295.68 Plan#3 S-42A(Plan S-42A) MWD+IFR+MS-WOCA MIND+IFR+Multi Station W/O Crustal 2111/2015 12.'10:54PM Page 2 of 5 COMPASS 5000.1 Build 61 I • ' BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Weil S-42 Project: Prudhoe Bay TVD Reference: S-41A plan @ 84.05usft(P-273 plan) Reference Site: PB S Pad EV Reference: S-41A plan @ 84.05usft(P-273 plan) Site Error: 0.00usit North Reference: True Reference Well: S-42 Survey Calculation Method: Minimum Curvature Weil Error: 0 OOusft Output errors are at 100 sigma Ref erence Wellbore Plan S-42A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#3 S-42A Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance lush) horn Plan Offset Well-Wellbore-Design (us') (eat) (usft( (usft) PB S Pad Plan S-130-Plan S 130-Plan#11 5130 Out arrange S-03-S-03-8-03 3,191.28 3,285.00 209.51 44.37 165.22 Pass-Major Risk S-09-8-09A-S-09A 5,000.30 4,525.00 496.07 99.09 400.34 Pass-Major Risk 5-09-S-O9APB1-Plan#7 S-09A 5,000.30 4,525.00 496.07 99.15 40027 Pass-Magor Risk 8-09-S-09APB1-5-09APB1 5,000.30 4,525.00 496.07 99.09 400.34 Pass-Major Risk 5-09-S-09AP82-S-O9APB2 5,000.30 4,525.00 496.07 99.09 400.34 Pass-Major Risk 5-09-S-09APB3-S-09AP83 5,000.30 4,525.00 496.07 99.09 400.34 Pass-Major Risk S-10-5.10-S-10 4,999.71 4,515.00 701.30 136.14 585.13 Pass-Major Risk S-10-S-10A-5-10A 4,999.71 4,515.00 701.30 136.14 565.13 Pass-Major Risk S-10-5-10APB1-S-10APB1 4,999.71 4,515.00 701.30 136.25 565.02 Pass-Major Risk S-100-S100-8-100 Out arrange S-101-5101-5-101 3,016.55 3.465.00 1:305.86 69.80 1,263.92 Pass-Major Risk 5101-3-101P131-8-101PB1 3,015.55 3,455.00 1,305.86 69.80 1,263.92 Pass-Major Risk 5-102-S-102-8-102 Out of range S-102-S-102L1-S-102L1 Out arrange 5102-S-102L1 PB1-S-102L1 PB1 Out arrange 5-102-S-102PB1-S-102PB1 Out of range S-103-5103-5103 Out arrange 5104-8-104-5104 Out arrange 5105-5-105-5-105 10,475.00 7.055.00 1,091.11 111.37 982.60 Pass-Major Risk 5-106-8-106-8-108 Out of range 5106-S-106PB1-8-1 OBPB1 Out arrange 5107-S-107-8-107 Out or range S-108-5106-8-108 9.803.82 7,520.00 393,07 113.64 285.88 Pass-Major Risk S-109-S-109-5109 6.681.16 5,010.00 509.01 90.72 423.93 Pass-Major Risk • 5109-5109PB1-S-109P81 5.681.16 5,010.00 509.01 90.72 423.93 Pass-Major Risk 5110-S-110-8-110 Out arrange S-110-S-110A-S110A 5.955.13 6,375.00 516.43 264.37 449.73 Pass-Major Risk •• 8-110-8-1108-5-1108 6.435.83 5,690.00 1.118.33 244.86 1,054.83 Pass-Major Risk S-111-S-111-S-114 Out arrange S-111-S-111 PB1-5111 PB1 Out arrange • S-111-S-111 PB2-5-111PB2 Out array 8-112-S-112-5-112 4,075.09 4,000.00 55.46 52.60 2.85 Pass-Major Risk 0115-5-113-6-1iJ OUtot range S-113-S-113A-S-113A Out arrange 5113-8-1138-8-1138 Out of range • 5114-5114-8-114 Out arrange • 5-114-S-114A-S-114A Out arrange • • 5115-8-115-S115 3,018.96 3,330.00 1,187.62 50.86 1,149.59 Pass-Major Risk S-116-S-116-5-116 3,015.78 3,520.00 1,308.03 51.84 1,269.00 Pass-Major Risk 5-116-S-116A-S-116A 3,015.78 3,520.00 1,308.03 52.80 1,268.55 Pass-Major Risk 5116-S-116APB1-Plan 3 3,015.78 3,520,00 1,308.03 52.13 1,269.26 Pass-Major Risk 8-116-S116APB1-S-116APB1 3,015.78 3,520.00 1,308.03 52.36 1,268.98 Pass-Major Risk 5116-S-116AP82-S-116AP132 3,015.78 3,520.00 1,308.03 52.36 1,268.98 Pass-Major Risk S-117-S-117-5117 3,01543 3,280.00 917.96 49.51 878.05 Pass-Major Risk S-118-S119-S-118 3,018.65 3,266.00 881.77 44.17 845.81 Pass-Major Risk S-120-5120-5120 Out of range 5-121-8-121-5-121 Out of range S-121-S121 PB1-S-121PB1 Out ofrange 5122-8-122-8-122 9016.43 3,425.00 1,224.23 49.72 1,186.30 Pass-Major Risk 5-122-S-122P81-S-122P81 3,016.43 3,425.00 1,224.23 49.72 1,186.30 Pass-Major Risk S-122-S-122PB2-S-122P82 3,01643 3,425.00 1,224.23 49.72 1,186.30 Pass-Major Risk S-122-S-122P83-S122PB3 3,016-43 3,425.00 1,224.23 49.72 1,196.30 Pass-Major Risk 2/11/2015 12:10:54PM Page 3 of COMPASS 5000.1 Build 64 0 • BP Anticoiis:on Renori Company: North America-ALASKA-BP Local Co-ordinate Reference: Well S-42 Project: Prudhoe Bay TVD Reference: S-41A plan @ 84.05usft(P-273 plan) Reference Site: PB S Pad MD Reference: S-41A plan Q 84.05usft(P-273 plan) Site Error. 0.00usft North Reference: True Reference Well: S-42 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan 5-42A Database: EDM R5K-Alaska PROD-ANCPI Reference Design: Plan#3 S-42A Offset ND Reference Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Way SBe Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design lusft) (us ti (usft) (0310) PBS Pad S-124-S-124-S-124 Out of range 5-125-S-125-S-125 Out of range S-125-S-125PB1-5-125P81 Out of range 5-13-8-13A-S-13A 6,000.00 5,300.00 589.78 92.87 499.99 Pass-Major Risk S-13-S-13AP61-S-13APB1 6 000 00 55,30000 58978 92.97499.99 Pass-Major Risk S-15-S-15-5-15 9,329.14 7,915.00 89.63 139.29 -44.21 FAIL-Major Risk S-16-S-16-S-16 ---- 9,650.67 8,000,00 260-16 208.61 5/90 Pass-Major Risk S-19-S-19-S-19 3,058.78 3,045.00 518.60 40.40 476.20 Pass-Major Risk S-200-S-200-5-200 3,017.15 3,066.00 466.09 49.01 427.71 Pass-Moja Risk S-200-S-200P81-S-200PB1 3,017.15 3,065.00 466.09 49.01 427.71 Pass-Major Risk 5-201-5201-S-201 Out of range 5-201-5201 PB1-S-201 PBt Out of range S-21-521-521 3,821.01 3,950.00 407.74 59.62 348.86 Pass-Major Risk 5-213-5213-S-213 3,018.46 3,060-00 237.57 40.22 201.04 Pass-Major Risk 5-213-S-213A-S-213A 3,018.76 3,056.00 230.94 39.14 194.14 Pass-Major Risk 5213-S-213AL1-S-213AL1 3,018.76 3.055.00 230.94 39.14 194.14 Pass-Major Risk S-213-S-213AL1-01-S-213AL1-01 3,018.76 3,056.00 230.94 39.14 194.14 Pass-Major Risk S-213-S-213AL2-S-213AL2 3.018.78 3,05500 230.94 39.14 194.14 Pass-Major Risk 5213-S-213AL3-S-213AL3 3,018.76 3,055.00 230,94 39.14 194.14 Pass-Major Risk 5216-5216-5216 Out of range S-22-8-22-522 3,400.00 3,440.00 525.66 44.00 481.66 Pass-Major Risk 522-8-22A-S-22A 3,400.00 3,44000 525.66 44.00 481.66 Pass-Major Risk S-22-S-225-5226 3,400.00 3,44000 525.96 44.00 481.68 Pass-Major Risk S-23-S-23-523 11,294.06 8,115.00 301.10 181.06 141.56 Pass-Major Risk S-24-524-524 4,472.15 4,490.00 362.66 89.00 276,71 Pass-Major Risk S-24-S-24A-S-24A 3,593.46 3,775.00 211.96 59.01 155.19 Pass-Major Risk 524-S-24B-5-24B 3,593.46 3,775.00 211.96 59.00 155.19 Pass-Major Risk S-31-S-31-S-31 3,800.00 3,985.00 58.78 69.51 -1027 FAIL-Major Risk S-31-S-31A-S-31A 3,800.00 3,986.00 58.78 699.33 -10.12 FAIL-Major Risk, 532-S-32-S-32 8,123.12 7,420.00 205.90 119.92 86.10 Pass-Major Risk S-32-S-32A-S-32A 8,123.12 7,420.00 205.90 119.82 86.10 Pass-Major Risk S-34-S-34-534 10,147.76 8,020.00 453.79 172.73 303.69 Pass-Mor Risk S-35-535-5-35 5,282.81 4,800.00 102.04 91-02 17.62 Pass-Major Risk '-4teJ-6-4(51-`✓401,1 OUT OT range 8-400-S-400A-S-400A Out of range 5401-8-401-S-401 Out of range S-401-S401 PB 1-S-401 PB 1 Out of range S-41-S-41-S-41 6,300.00 5,555.00 939.35 174.96 812.97 Pass-Major Risk S41-S-41A-S-41A 6,300.00 5,550.00 9+9.37 178.75 810.80 Pass-Major Risk 5-41-S41AL1-S-41AL1 6,300.00 5,550.00 939.37 178.74 810.81 Pass-Major Risk S41-S-41 L1-S-41 L1 6,300.00 5,555.00 939.35 174.97 812.96 Pass-Major Risk S41-S-41 P81-S-41 PBI 6,300.00 5,555.00 939.35 174.95 812.97 Pass-Major Risk S-42-S-42-S-42 3,052.26 3,040.00 0.03 1.31 -1.25 FAIL-Major Risk S-42-S-42PB1-S-42P51 3,052.26 3,040.00 0.03 1.31 -1.25 FAIL-Major Risk S-43-S-43-S-43 4,530.41 4,325.00 290.92 93.32 206.14 Pass-Major Risk 543-S-43L1-S-43L1 4,530.41 4,325.00 _ 298.92 93.32 206.14 Pass-Major Risk S44-Plan S-44A-Plan#5 S-44A 3,034.44 3,035.00 57.21 33.87 23.36 Pass-Major Risk S-44-5-44-5-44 3,385.78 3,365,00 49.53 37.83 11.74 Pass-Major Risk S-44-S-44L1-S-44L1 3,385.78 3,365.00 49.53 37.73 11.84 Pass-Major Risk 8-44-S-44L1PB1-544L1PBI 3,385.78 3,365.00 49.53 37.83 11.74 Pass-Major Risk 2/11/2015 12:10.54PM Page 4 of 5 COMPASS 5000.1 Burst 61 1 'iiiiiii1111;1; ii'aillf: I IIIIIIIIIIIIIIIIII 00,1111 •; ,1-L.1114,-,/ ;$144.• * i { � I s II ir r• N a/ iN dZ I ts ,/ ,� osis ,N1t u o ao. 1414.1,k a J, a liililiillilli! , : n i 1 111111111111111 rf /I 'iiiiilM21ilii `,',,,-.,,,:- .>"5,,,Y1 .' ,i N� tk \ g r r, ye$a ,Sa d g�. $ k , I ,: tint. y g in v .° dYYY I E § s iiiii#@ MIlilll F - ! III1lllllllllllll ''`' x �� ; g `iiiiiiiiii:illlii r . / a $ u N . YsTa 9 mhi g Adati0N ,_ ; il pp Y y @41',14•0., ,a.i,yg, I" 1U Y 0 « 8 in I i 'r '. ary � p ? jF] g IIF ��i �Fl' q o = it 1.1‘-‘1„'� i i iiis11111 BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well S-42 Project: Prudhoe Bay TVD Reference: S-41A plan©84.05usft(P-273 plan) Reference Site: PB S Pad MO Reference: S-41A plan a 84.05usft(P-273 plan) Site Error. 0.00us11 North Reference: True Reference Well: S-42 Survey Caiculadon Method: Minimum Curvature Well Error. 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan S42A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#3 S-42A Offset ND Reference: Offset Datum Reference Ran#3 S-42A — _ ----_–_— Fitter type: GLOBAL FILTER APPLIED:All weilpaths within 200'+10011000 of reference Interpolation Method: MD Interval 5.00usft Error Model: ISCWSA Depth Range: 3,015.43 to 11,295.68usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center cfimance of 1,324.87us* Error Surface: Elliptical Conic Survey Tool Program Date 2/112015 From 'To Daft) (min Survey(Wellbore) -Paul wane Description 223.66 3,015.43 S-42 Se 1 MIND(S-42PB1) MWD MWD-Standard 3015A3 3,047.00 Plan#3 S-42A(Plan 342A) MIND MWD-Standard 3,047.00 3,550.00 Plan#3 S-42A(Plan S-42A) GYD-GC-SS Gyrodata gyro single shots 3550.00 5,050.00 Plan#3 S-42A(Plan S-42A) MWD MVVD-Standard 3.550.00 8,430.00 Plan#3 S-42A(Plan S-42A) MWD+IFR+MSVNOCA MWD+IFR+Molt Station W/O Crustal 8,430.00 9,930.00 Plan#3 S-42A(Plan 542A) MIND MIND-Standard 8,430..00 11,295.68 Plan#3 S-42A(Plan S-42A) MWD+4FR+MS-WOCA MIND+IFR+Mufti Station MO Crustal 2/11/2015 12:94:15PM Page 2 of 5 COMPASS 5000.1 Budd 61 • • BP Anti collision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 5-42 Project: Prudhoe Bay TW Reference: 2-41A plan @ 84.05u sft(P-273 plan) Reference Site: PB S Pad MD Reference: S-41A plan @ 84.05usft(P-273 plan) Site En-or: 0.00usft North Reference: True Reference Well: S-42 Survey Calculation Method: Minimum Curvature Weil Error: O.00usit Output errors are at 1.00 sigma Reference We88ore Plan S-42A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design Plan 63 S-42A Offset NO Reference Offset Datum y Reference Offset Centre to No-Go Allowable Measured Maastred Centre Distance Deviation Warning stir NOM Depth Depth Distance (unit) from Plan Olbet mitt-Wellbore-Design (usftj WWI) (usl1) (0511) PBS Pad Plan S-130-Plan S 130-Plan 1x11 S-130 Out of range 503-5-03-S-03 3,191.28 3,285.00 209.51 44.37 16522 Pass-Major Risk 5-09-S-09A-S-09A 5,000.30 4;525.00 496.07 99.09 400.34 Pass-Major Risk 5-09-S-09APB1-Plan#7 S-09A 5,000.30 4,525.00 496.07 99.15 400.27 Pass-Major Risk 509-S-09APB1-S-09APB1 5,000.30 4,525.00 496.07 99.09 400.34 Pass-Major Risk S-09-S-O9APB2-S-09APB2 5,000.30 4,525.00 496.07 99.09 400.34 Pass-Major Risk S09-S-09APB3-S-09APB3 5,000.30 4,525.00 496.07 99.09 400.34 Pass-Major Risk 510-510-5-10 4,990.71 4,515.00 70'30 138.14 565.13 Pass-Major Risk S-10-S-10A-S-10A 4,009.71 4,515.00 701.30 136.14 565.13 Pass-Major Risk 510-S-10APB1-S-10APB1 4,999.71 4,515.00 701 30 136.25 565.02 Pass-Major Risk 5-100-5-100-5-100 Out of range 5-101-5101-5101 3,015.56 3,456.00 1,305.86 00.60 1,263.92 Pass-Major Risk S-101-S-101PB7-S-101PB1 3,015.56 3,456.00 1.306 66 69.80 1,263.92 Pass-Major Risk S-102-8-102-5102 Out of range 5102-510211-8-10211 Out of range S-102-5-10211 PB1-S-102L1 P81 Out of range 5102-S-102PB1-8-102PB1 Out of range S-103-S-103-S-103 Out of range 5104-5104-8-104 Out of range 8-105-5105-S-105 10,475.00 7,055.00 1,091.11 111.37 902.80 Pass-Major Risk S-106-S-106-S-106 Out of range 5-106-S-106P81-S-108PB1 Out of range S-107-5-107-S-107 Out of range 5108-5-108-S-108 9,603.82 7520.00 393.07 113.64 285.96 Pass-Major Risk 5109-8-100-5109 5,681.16 5,010.00 509.01 90.72 423.93 Pass-Major Risk 5709-S-109P51-S-109PB1 5,681.16 5,010.00 509.01 90.72 423.93 Pass-Major Risk 5110-5110-5110 Out of range S-110-S-110A-S-110A 6,955.13 6,375.00 516.43 264.37 449.73 Pass-Major Risk 5110-57108-S-1108 6,435.83 5,690.00 1,119.33 244.86 1,054.63 Pass-Major Risk S-111-5-111-Sill Out of range 5111-5711 PB1-S-171 PB1 Out of range S-111-S-111P82-S-111PB2asof ran e 15-112-8- 5 112- 112 4,071.43 3,995.00 5542 7.15 4827 Ps-Minor l20 8-113-5-113-5113 Out of range S-113-S-113A-S-113A Out of range 8-113-S-11313-51138 Out of range S-114-8-114-8-114 Out of range 8-114-8-114A-S-114A Out of range S-115-S-115-5.115 3,019.96 3,330.00 1,187.62 50.88 1,149.59 Pass-Major Risk 5116-5118-8-116 3,015.78 3,520.00 1,300.03 51.84 1,269.00 Pass-Major Risk S-116-S-118A-S-116A 3,015.78 3,520.00 1,308.03 52.80 1,268.55 Pass-Major Risk 5-116-S-116AP61-Plan 3 3,015.78 3,520.00 1,308.03 52.13 1,269.28 Pass-Major Risk 5-116-S-116APB1-S-116APB1 3,015.78 3,520.00 1,308.03 52.36 1,268.98 Pass-Major Risk S-116-S-118AP82-5-116APB2 3,015.78 3,520.00 1,308.03 52.36 1,268.98 Pass-Major Risk S-117-S-117-S-117 3,015.43 3,280.00 917.96 49.51 878.05 Pass-Major Risk 5118-5118-5118 3,016.65 3,265.00 981.77 44.17 845.81 Pass-Major Risk 5120-5120-5120 Out of range 5121-5-121-5-121 Out of range 5121-S-121PB1-8-121PB1 Out of range 5122-5-122-5122 3,016.43 3,425.00 1,224.23 49.72 1,186.30 Pass-Major Risk S-122-S-122PB1-S-122PB1 3,016.43 3,425.00 1,224.23 48.72 1,186.30 Pass-Major Risk S-122-S-122P62-S-122PB2 3,016.43 3,425.00 1,22423 49.72 1,18630 Pass-Major Risk 5122-S-122P83-S-122P83 3,016.43 3,425.00 1,22423 49.72 1,186.30 Pass-Major Risk 2/11/2015 12:34:15PM Page 31,1 5 COMPASS 5000.1 Budki 61 • • BP Anticollision Report Company. North America-ALASKA-BP Local Co-ordinate Reference: Well S-42 Project: Prudhoe Bay TVD Reference: S-41A plan @ 84.05usft(P-273 plan) Reference Site: PB S Pad MD Reference: S-41A plan @ 84.05usft(P-273 plan) Site Error: 0.00usI North Reference: True Reference Well: 5-42 Survey Calculation Method Minimum Curvature Well Error: 0.00usft Output errors are at 100 sigma Reference Wellbore Plan S-42A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design, Plan#3 S-42A Offset IVO Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Nleasnled Centre Distance Deviation Warning Site Narne Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usrn (usf) (us11j (usC) PB S Pad 3-124-5124-5124 Out of range 5125-5125-5125 Out of range 5125-S-125P81-S-125P81 Out of range 513-S-13A-S-13A 6,000.00 5,300.00 569.78 92.87 499.99 Pass-Major Risk 513-S-13APR1-8-19APB1 6 000 00 690000 569 78 57 Bn _ 499 99 Pass-Major Risk_ 8-15-8-15-515 9,329.95 7,900.00 87.84 10.85 87.09 Pass-Minor 1120! 516-S-16-S-16 9,650.67 8,00000 260.16 208.61 57.90 Pass-Major Risk 519-S-19-8-19 3,058.78 3,046.00 516.60 40.40 47620 Pass-Major Risk 5200-5-200-S-200 3,017.15 3,065.00 488.09 49-01 427.71 Pass-Major Risk 8-200-S-200P81-S-200P131 3,017.15 3065.00 488.09 49.01 427.71 Pass-Major Risk 8-201-5201-5201 Out of range 8-201-S-201 P81-8-201P81 Out of range 8-21-521-521 3,821.01 3,950.00 407.74 59.92 348.86 Pass-Major Risk 5213-5213-8-253 3,018.46 3,060.00 237.57 40.22 201.04 Pass-Major Risk 5213-8-213*-8-2134 3,018.76 3,056.00 230.94 39.14 194.14 Pass-Major Risk S-213-S-213AL1-5213011 3,018.76 3,055.00 230.84 30.14 194.14 Pass-Major Risk 5213-5213AL1-01-8-213*1,1-01 3,018.76 3,055.00 230.94 39.14 194.14 Pass-Major Risk 5-213-S-213AL2-3-213012 3,018.76 3,055.00 230.94 39.14 194.14 Pass-Major Risk 5213-S-213AL3-5-213AL3 3,018.76 3,056.00 230.94 39.14 194.14 Pass-Major Risk 5216-5218-8-216 Out of range 522-S-22-8-22 3,400.00 3,440.00 525.66 44.60 48156 Pass-Major Risk 3-22-8-220-8-220 3,400.00 3,440.00 525.66 44.00 481.66 Pass-Major Risk 522-S-22B-5226 3,400.00 3,440.00 525.66 44.00 481.66 Pass-Major Risk 523-8-23-8-23 11,294.06 8,115.00 301.10 161.06 141.56 Pass-Major Risk 524-524-8-24 4,472.15 4,490.00 362.66 89.00 276.71 Pass-Major Risk 524-8-240-5240 3,593.46 3,775.00 211.96 59.01 155.19 Pass-Major Risk 8-24-52413-3-246 3,593.46 3,775.00 211.96 58.00 155.19 Pass-Major Risk 531-8-31-8-31 3,803.60 3,99000 58.79 10.61 48.45 Pass-Minor 120 8-31-8-310-5310 3,803.60 3,990.00 58.79 8.79 51.24 Pass-Minor 120 8-32-8--32-3-32 8,123.12 7,420.00 205.90 119.82 86.10 Pass-Major Risk 8-32-S32A-5-320 8,123.12 7,420.00 205.90 118.82 86.10 Pass-Major Risk 5-34-534-534 10,147.76 8,020.00 453.79 17273 303.69 Pass-Major Risk 13-35-8-35-3-35 5,282.81 4,800.00 102.04 91-02 17.62 Pass-Major Risk 5-400-5-400-5400 Out of range 5-400-5-4000-8-400A Out of range S-401-5401-5401 Out of range 5-401-S401 PB1-S-401P131 Out of range 5-41-8-41-5.41 6,300.00 5,555.00 939.35 174.96 812.97 Pass-Majw Risk 541-S-41A-S-41A 6,300.00 5,550.00 939.37 178.75 810.80 Pass-Major Risk 8-41-S-41011-S-41AL1 6,300.00 6,550.00 939.37 /78.74 810.81 Pass-Major Risk 541-54111-5-41 L1 6,300.00 5,555.00 939.35 174.97 812.96 Pass-Major Risk 5-41-S41 PB1-5-41 P81 6,300.00 5,556.00 939.35 174.95 812.97 Pass-Major Risk 5.42-S42-5-42 3,017.26 3,005.00 0.00 0.56 -0.80 FAIL-NO ERRORS 542-S42PB1-5-42P81 3,017.28 3,005.00 0.00 0.00 -0.80 FAIL-NO ERRORS 543-643-543 4,530.41 4,32.5.00 298.92 93.32 206.14 Pass-Majw Risk S-43-S43L1-54311 4,530.41 4,325.00 298.92 93.32 206.14 Pass-Major Risk 5-44-Plan S-44A-Plan#58-44A 3,034.44 3,035.00 5721 33.87 23.38 Pass-Major Risk 5-44-S44-S44 3,385.78 3,365.00 49.53 37.83 11.74 Pass-Major Risk 5-44-S44L1-S-44L1 3,385.78 3,365.00 49.53 37.73 11.84 Pass-Major Risk 5-44-54411 P61-8-4411 P81 3,386.78 3,385.00 49.53 37.83 11.74 Pass-Major Risk 2/11/2015 12:34:15PM Page 4 of 5 COMPASS 7000.1 Scl'd 61 • • Q 1a11ai&aia:a1 a1111 i 111111111111111111 1 °a11aa119a1saaaaaa '',,, • ' \y. 1 i i,/x f ' ElSfrk\ S i k , \ , , ,,, 0, ,._ L , 4, � x7 + 7 - E l LL O 1' L'z. 3 n :---.. 2 O W , . R i 1111111111111111111 - j *aaaaaYYaaaaaaaaaa v ' ,..� E R 8 Atoll , r, No S fir'plffrifr 'e f r� 4 i m c .' s _.a ',ry . �� k g c aid ti r,�l w Y: « 6 ft • 4 .1 r b \, i\\4. iii. l N S a pp e� Vic-\ y o f LLA bi f. i ----''' /a yy. iiiaieLf,ai:alaaaa! 5 I III 11111111111111 x.• € °aaiaalioaa::agiaa -< kE 9 4( •_� \l \ LIII =yin 1 4aRa..2 R Y iii 'hRR L /�4.ire ��j1ill -111 IB.' 8 8 N "' ry , E ;o 'R - %( rii �!4 z m z ro E iiit s i L \sem• 'ffi t 1 II «6 r P-a'i' It/ Y a.'6•... .at t `11. 2 • • 2E: 0 S PAD tb / 43 t 34 35 'IV- / 42 # N_ PLANT w THIS SURVEY 41 t ® ".\ ''----N ( T.12/4.i/y (T.11N. t VICINITY MAP N.T.S 0 _ •••••••••••••••• ••••• • 4L••••••••• • • :-.Ti 172 19 1 2013 371 24 415 26 5 17 E 6 30 7 31 33 B 19 936 32 10 36 35 1136i 3112A 13 14 •15 MON S-1 ■t6 IN40L9 me OF A4qS •to , 6)••. •, �+I . (--- S P A D t ♦ I F ROBERT BELL •; -` Az f• 3252—S • '.: , • ' esslarw �- �` I�1 `• NOTES SURVEYOR'S CERTIFICATE 1. DATE OF SURVEY: JANUARY 21, 1996. I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED 2. REFERENCE FIELD BOOK: TO PRACTICE LAND SURVEYING IN WOA96-02 (pgs.18-22). THE STATE OF ALASKA AND THAT 3. ALASKA STATE PLANE COORDINATES THIS PLAT REPRESENTS A SURVEY ARE ZONE 4, ALASKA, NAD 27. MADE BY ME OR UNDER MY DIRECT 4. PAD SCALE FACTOR IS 0.9999165. LEGEND SUPERVISION AND THAT ALL 5. HORIZONTAL/VERTICAL CONTROL BASED DIMENSIONS AND OTHER DETAILS ARE ON MONUMENTS S-3 AND S-4. + AS—BUILT CONDUCTOR CORRECT AS OF JANUARY 21, 1996. 6. ELEVATIONS ARE BP M.S.L. DATUM. • EXISTING WELL LOCATED WITHIN PROTRACTED SEC. 35, T. 12 N , R. 12 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC GROUND SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS '= 5.980,354.93 N. 1,010.12 70'21'17.932" 70.3549811' 37.0' 4,152' FSL 41 X= 618,930.12 E. 500.03 149'02'03.045" 149.0341792' 4,504' FEL Y=5,980,384.43 N 1,009 92 70'21'18.222" 70 3550617' 4,181' FSL S 42 X= 618,929 91 E 470.53 149'02'03.038" 149.0341772' 37.1' 4,503' FEL 5-43 Y= 5,980,414.71 N. 1,009.91 70'21'18.520" 70 3551444" 37.2' 4,211' FSL X= 618,929.89 E. 440.24 149'02'03.024" 149.0341733' 4,503' FEL F Robert °R^"" STOLL F-"� ' i (. CnECKEO:SELR BP BP EXPLORATION I Ulilli , DAIS: MMM 1/22/96 ' .. L1 � 01tAwNc. ..r W'OASWELL �41EEis JOB No: WOA S—PAD j f�S~S�OCa x, AS—BUILT CONDUCTORS I) 12.3/12.90KNAL AS-O,AT issue ss,es �"'m"" WELLS S—41, S—42 & S-43 1 Cr 1 $0. DATE _ REASON OY CNK m.o... MM. IOW 1�- 400 • • Davies, Stephen F (DOA) From: Rose, John G (ASRC) <John.G.Rose@bp.com> Sent: Wednesday, March 18, 2015 9:05 AM To: Davies, Stephen F (DOA) Cc: Lastufka, Joseph N Subject: RE: Emailing: S-42A MD INC AZ.xlsx Attachments: S-42A Formation Tops.pdf Steve, Per our phone conversation this morning, please note the following: 1. The pressure values on page 5 of the permit are the correct pressures and box 17 of the PTD application should be changed to: Downhole - 3470 psig Surface - 2796 psig NOTE: As this is a Kuparuk development well, this maximum pressure is from the TKA6, not the TSGR as indicated on page 5 for the 6-1/8"hole. 2. Note the attached "Formation Tops" which was omitted from the original PTD request. If you have any other questions or concerns, please advise. Thanks -jr John G. Rose GWO—Alaska Staff Engineer Office 907-564-5271 Cell 907-748-5223 Home 907-243-8813 Original Message From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, March 17, 2015 4:31 PM To: Lastufka,Joseph N Cc: Rose,John G (ASRC) Subject: RE: Emailing: S-42A MD INC AZ.xlsx Hi Joe, Thanks for the survey information. Quick question about the Permit application: The pressure values listed in Box 17 on the Permit to Drill form don't match those shown on page 5 of the application's supporting documents. Which pressure values are correct? Thanks, 1 • • Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Original Message From: Lastufka,Joseph N [mailto:Joseph.Lastufka@bp.com] Sent: Tuesday, March 17, 2015 2:06 PM To: Davies,Stephen F (DOA); Bettis, Patricia K(DOA) Subject: Emailing: S-42A MD INC AZ.xlsx Steve, This Permit to Drill will be delivered this afternoon. Please let me know if you have any questions. Thanks! Joe 2 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. Ill III TRANSMITTAL LETTER CHECKLIST WELL NAME: ,/ ./ti:" �5 - Vz14 PTD: -2--/C- pc fDevelopment _Service _Exploratory _Stratigraphic Test _Non-Conventional .., FIELD: (Z4L? e_- POOL: e 1-LtL C/ Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name)in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(dX2XB) 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 40 • ❑❑ To . , , , N , , a 0 a) a „ N u) L_) p C : 0) N a a t 3 o c I >.. us os cu o c' c • r ��, 3, o' in , p oy w..' O Y a o. E 0 N' X �, @ E` CO. a) p a ow O °) a) _ a ' N co Oj, N' Q; a d ca -0 to 3, o .- N, a), `�,. 0 N y, 0 D• o' c c a y 0N, 8I: Q -� � Gz m ; 0 d ar w: , z Q p D a o v, a) ° o r); ai o O as m W, To' N ' E .�. -0- N, v m. 0? a), wl O O, COLN• _, NCI) T N. Q M c a) O a) v. pw N E �' m a a m a 3' o', 0 o, L. a' p Ut c — Z N 3 aa> 0 Tu 2 co 07H ai 0, m 5, 6' fco 3 0 C, V, 0 O W m N a) -' in O O' (0 N co N E, vi, Ea C7 0. O �, o co a a v' > N y' E in a 3. v m. 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