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217-137
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS R IL17;e%AZ.D 1AAI 4 r nn 1. Operations Performed a Gdd Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operation sh do ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ 1^-__ Alter Casing ❑ Cha,(1g e19p' ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Pull LTP m 2. Operator Name: BP Exploration (Alaska), Inc 4. Wel(Class Before Work Development 21 Exploratory ❑ 5. Permit to Drill Number: 217-137 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6API Number: 50-029-20414-03-00 1 7 Property Designation (Lease Number): ADL 028331 8. Well Name and Number: PBU 03-15C 9. Lags (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 9523 feet Plugs measured None feet true vertical 8987 feet Junk measured None feet Effective Depth: measured 9486 feet Packer measured8867 feet true vertical 8966 feet Packer true vertical 8390 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" 35-115 35-115 1530 520 Surface 2683 13-3/8" 35-2718 35-2718 5380 2670 Intermediate 2336 9-5/8" 1971 -4307 1971-4262 8150/6870 5080 / 4760 intermediate 9004 7" 32-9036 32-8662 7240 5410 Liner 271 4-1/2" 8806-9077 8487-8692 8430 7500 Liner 764 3-1/4" x 2-7/8" 8759-9523 8449-8987 Perforation Depth: Measured depth: 9340-9384 feet True vertical depth: 8882-8908 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr85 29-8812 29-8491 Packers and SSSV (type, measured and 4-1/2' HES TNT Penn Packer 8687 8390 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Pnorto well operation: 139 1585 4105 1593 276 Subsequent to operation: 131 1497 5082 1608 278 14. Attachments: (required per 20 MC 25.070.25.071, &26.2133) 15. Wei) Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Schultz, Kirsten L Contact Name: Schultz, Kirsten L Authorized Title: Engineer Contact Email: Kirsten.SchultzcCbp.com /Petroleum Authorized Signature: Date: Contact Phone: +1 907 564 5105 Form 10-404 Revised 04/2017 Submit Original Only �RnMS l� ieN � fi �n�n 12/24/2019 ***WELL FLOWING ON ARRIVAL***(profile modification) R/U SLICKLINE UNIT 4516 ***GO TO WEATHER TICKET*** ***JOB CONTINUED FROM 26 -DEC -2019*** (Profile Modification) DRIFTED W/ 10'x 3.70" DUMMY WHIPSTOCK, 3.50" LIB TO TOP OF LTP @ 8,723' SLM (impression of G -FN). PULLED 45KB LTP FROM 8,723' SLM (no flow cutting, missing 1/3 of top element). RAN 4-1/2" BRUSH, 3.50" WIRE GRAB TO TOP OF DEPLOYMENT SLEEVE @ 8,734' SLM (no recovery). 12/27/2019 ***LAY DOWN FOR WEATHER*** ***JOB CONTINUED FROM 28 -DEC -2019*** (Profile Modification) RAN 2.50" CENT, W/ 1-3/4" SAMPLE BAILER TO OBSTRUCTION @ 8,751' SLM (-8,787' MD) (no sample, bottom bent in). RAN 2.50" CENT, W/ 2.25" LIB TO 8,751' SLM (impression of obstruction, sent to APE). RAN 3.70" CENT, W/ 3.50" LIB TO 8,733' SLM (clean impression of dep sleeve f/n). 12/29/2019 ***WELL S/I ON DEPARTURE*** ELEV : 64' ELEV - 62.44' 20' CONDUCTOR, 94#,1+40, D = 19.1024" -EV = 27.78' - 3300' Ingle = 56-@9411' I" CSG, 72#, L-80 BTC, D = 12.347" H Minimum ID = 2.786" @ 8812' 3-1/2" X 3-114" XO 19-5/8" CSG. 47#. 5-95. ID = 8.681" 1 TOP OF 3-1/4" LNR/CMT OF 4-1/2" LNR 4-12' TBG, 12.6#, 13CR-85 VAM TOP, .0152 bpf, ID = 3.958' 8938'-8941'(04109115) 1� MG, 26#, L-80 VAM TOP HC, D = 6.276" 9036' 4-12" MONOBORE WHIPSTOCK (01/23/18) 9O7T 4-1/2' LNR 12.6#, 13 -CR HYD 521, —9077' .0152 bpf, D = 3.958' PBTD 9486' 13CR-85 TCI 1..0079 bpf, ID= 2.85' 9523' 03-1 5CSAFETY MAX DOGLEG: 21 —CHROME'. &LNR 5/8" UPPER FOC 5/8" LOWER FOC GAS LIFT MANDRELS ST PERFORATION StbA%RY I ND REF LOG: _ ON I TYPE ANGLE AT TOP PERF: 52" @ 9340' Note: refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz I SHOT SITZ 2" 6 9340 - 9360 O 03/05/18 4 2" 6 9373-9384 O 03/05/18 BK PBTD 9486' 13CR-85 TCI 1..0079 bpf, ID= 2.85' 9523' 03-1 5CSAFETY MAX DOGLEG: 21 —CHROME'. &LNR 5/8" UPPER FOC 5/8" LOWER FOC GAS LIFT MANDRELS ST MD I ND I DEV I TYPE I VLV LATCH PORT DATE 5 3620 3610 14 KBG DONE BK 16 07/07/18 4 5482 5270 20 KBG DONE BK 16 07/07/18 3 6763 6535 11 KBG DONE BK 16 07/07/18 2 7795 7552 8 KBG DOME BK 16 07/07/18 1 8619 8334 31 KBG SO BK 22 07/07/18 9-518"MLLOLIT WINDOW (03-158) 4307' - 4324' 868-17" X 4-1/2" HES TNT f 8724' 4-12' HES X NP, D = I 8801' I 3.70' DEPLOY SLV, D= 3.00" 3-12" W13LTEC SLM PKR D = 4-12" HES X NP, D = 3.813" BI 7' X 5' SKR HRD-E ZXP LTP w /TEBACK SLV D = 5.25" BEHIND CT LNR 8812' 8812' 4-1/2' WLEG, D= 3.958' BB11ND CT LNR 3-1/2'X3-1/4' XO, D = 2.786' 8830' 7" X 5" BKR RIX LOCK HGR D = 4240- 240"S"X4-1/2"XO, 0223/80 5'X 4-1/2"XO,D=3.870" BEHIND 03/05/18 STPTSALTP&X-NP(03/04/18) CT LNR MLLOUT WINDOW (03-15C) 9077'- 9084' SIDETRACK(03-15A) DATE REV BYT COMMENTS DATE COMMENTS 0223/80 OWAN 3 ORIGNAL COMPLETIN 03/05/18 STPTSALTP&X-NP(03/04/18) O3OM3 D-16 SIDETRACK(03-15A) 03/06/18 ADDED REF & BF ELEV 032797 N2E5 CTD SIDETRACK (03-15A L1) qREVBY 1218 GLV CO (03/03/18) 0423/15 D-14 SIDETRACK(03-15B) 03/12/18 ADPERFS (03105/18) 0210118 N-COR2 CTDST(03.15C 07/10/18 Fy MWJMDGLVCAD(07/07/181 2005/30/19 PULLED LTP w/ PTSA& XNP PRUDHOE BAYUNR WELL: 03-15C PERMITNo: 217-017 API No: 50-02420414-03 1, T10N, R15E,1131' FSL & 54' FEL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 2 8 2p19 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed n%� tuf/Gr(� Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Opemtio115LCC ❑ Suspend ❑ Perforate ❑ Other Stimulate ® Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Mud Acid Stimulation 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ® Exploratory ❑ 5. Permit to Drill Number. 217-137 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number. 50-029-20414-03-00 7. Property Designation (Lease Number): ADL 028331 8. Well Name and Number: PBU 03-15C 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: Total Depth: measured 9523 feet Plugs measured None feet true vertical 8987 feet Junk measured None feet Effective Depth: measured 9486 feet Packer measured 8687 feet true vertical 8966 feet Packer true vertical 8391 feet Casing: Length: Size: MD: TVD: Burst Collapse: Conductor 80 20" 35-115 35-115 1530 520 Surface 2683 13-318" 35-2718 35-2718 5380 2670 Intermediate 2336 9-5/8" 1971 -4307 1971-4262 8150/6870 5080/4760 Intermediate 9004 7" 32-9036 32-8662 7240 5410 Liner 271 4-1/2" 8806-9077 8487-8692 8430 7500 Liner 764 3-1/2" x 2-7/8" 8759-9523 8449-8987 Perforation Depth: Measured depth: 9340-9384 feet True vertical depth: 8882-8908 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr85 29-8812 29-8491 Packers and SSSV (type, measured and 4-1/2" HES TNT Perm Packer 8687 8391 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Pumped 1st acid stage of 15 bbls 12%HCL, 15 bbls 9'1 mud acid, and 6 tools 7.5% oil seeker. Pumped 2nd acid stage of 15 bis of 12% HCL, 17 bola 9:1 mud acid. Pumped 80 bbls NH4CI overflush and SO for 10 min w/oilseeker in the perfs. Resumed over0ush wl 110 bola of NH4 Cl during and performed injectivity test. Intervals treated (measured): 9340' - 9360' and 9373' - 9384' Treatment descriptions including volumes used and final pressure: 30 bbls 12% HCL, 32 bola 9:1 Mud Acid, 6 bola 7.5% Oil Seeker. Final pressures: OA = 454 psi, IA = 1227 psi, TBG = 243 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 173 9904 2107 1330 263 Subsequent to operation: 114 638 2538 1262 265 14. Attachments: (Mquimdpr20MC25.070.25.D71,&25,283) 15. Well Class after work: Daily Report of Well Operations Rl Exploratory ❑ Development ® Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 21 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Summers, Matthew Contact Name: Summers, Matthew Authorized Title: Production Engineer Contact Email: Matthew.SummersAbp.com q Authorized Signature: Date: S�a3/t / Contact Phone: +1 9075645066 Form 10.404 Revised 04/2017 A�O- 6^L"" "(SBDMSL'a"�MAY 2 9 2019 Submit Original Only Daily Report of Well Operations PBU 03-15C ACTIVITYI)ATF ci RARAAOV T/1/0= 890/10081140 (LRS Unit 70 Pre acid INJ test). Pumped 202 bbls 105*F crude down TBG to establish an injectivity rate of 4.3 bpm @ 2100 psi. After 5 minutes of shutting down TBG went on a vac. Returned well to DSO to POP before scheduled acid job. WV, SV= closed; SSV, MV, AL, & 4/21/2019 CV's= open. FWHP's vac/1057/417 T/1/0=300/1900/400 (LRS Unit 42 - Assist Well Testers: Freeze Protect) Temp=100 Freeze protect FL w/ 3 bbls 60/40, 45 bbls Crude. Freeze protect TBG w/ 40 bbls Crude. FWHP=1000/1900/400 4/29/2019 SV,WV,SSV shut. MV,IA,OA Open. ***Job Cont from 04-29-2019 WSR*** (LRS Unit 72 - Assist Well Testers: Acid Tubing Pickle) Pumped 5 bbls neat, 100 bbls NH4CL, 24 bbls 12% HCL, 3 bbls neat and 106 bbls NH4CL down Tbg for pickle. Well Testers in control of well per LRS pumpers departure. IA,OA=OTG 4/30/2019 FWHP's=200/1713A/ac ***Continued from 04/30/19 WSR*** Initial T/1/0= 2007/-4/6 Temp = SI. (SLB Unit 28803 - Acid) Loaded TBG w/160 bbls NH4CI+F103 and discovered potential TxIA communication. RU LRS to IA to pump crude at 0.5 bpm (minimum rate) while SLB executes remainder acid job (refer to LRS WSR). Resumed pumping down TBG to fill w/ 20 bbts NH4CL, once fluid packed, performed injectivity test @ .5 bpm @ -390 psi, 1 bpm @ -560 psi and 2 bpm @ -1023 psi.. Pumped 1st acid stage of 15 bbls 12%HCL, 15 bbls 9:1 mud acid, and 6 bbls 7.5% oil seeker. Pumped 2nd acid stage of 15 bls of 12% HCL, 17 bbls 9:1 mud acid. Pumped 80 bbls NH4CI overflush and SD for 10 min w/oilseeker in the perfs. Resumed overflush w/ 110 bbls of NH4 CI during and performed injectivity test @ .5 bpm @ -720 psi, 1 bpm @ -980 psi, 2 bpm @ -1480 psi. Log has more details. Well testers to flowback acid immediatly after RD. 5/1/2019 FWHP's=730/972/6 T/1/0=80/vac/vac Temp=Sl (LRS Unit 72 - Assist Schlumberger Acid Van: Load IA during Acid Job) Spear into IA with 5 bbls of 60/40 McOH. IA pressured up after 4 bbls. Pumped 101 bbis of crude into the IA at 0.5 bpm during the acid job to maintain a 400 psi DP above TBG pressure. Well Testers had conrol of the well upon departure. 5/1/2019 Final T/1/0= 0/0/0. LRS Test Unit 1, Continue from WSR 5/1/19, DS3-15 Full Bore Assist /Acid Flowback and Devert. Current Barriers: IL- vessel &hard-line, SSV / OL SSV, OSDV. Acid Flowback,Diverted to 5/2/2019 1production Continue on WSR 5/3/19. LRS Test Unit 1, Continue from WSR 5/2/19, DS3-15 Full Bore Assist /Acid Flowback and Test. Current Barriers: Inlet- Vessel/Hardline, SSV / Outlet- SSV, OSDV. Flow Well, Test. End WSR on 5/3/2019 5/3/19 WALIEAD FMC ACTUATOR I DEV OKB. BEV I VLV REF 4-B/ IDATE BF. E LLV = 27.76' KOP= 3300 Max Angle = 56'@9411' Datum MD= 93(18' Datum TVD• 8a00SS SAFETY -CHROME 03-15C MAX DOGLOEG:21.7•@91 6TBG8LNR 19.10 4" �- 116' T. K40. I 2011' 412' HE> X NP, D = 3.613' =19.1024' e:ae• �cm�i� i- CSG. 72#. L -BO BTC, D = 12.34f—H 2720' Minimum ID = 2.31" @ 8771' 2-718" X NIPPLE IN PTSA LTP 9-5/8' BKR VAO-STOCK (0312915) H 4307' 19-5/8• CSG. 47#. S-95. D = 8.681' 1 D = 2.31' (03/04/18 TOP OF3-1/4' 2-7/e' X NP, 1TOPOF4-1/2•LhRH 8806• 1-12' TBG, 12.6#, 13CR-95 VAM TOP, I 8812' .0152 bpf, D = 3.958' 7- CSG PUNCHES (CLOSED): 8835'- 8840' 8 8936' - 8941' (04ro9H5) 17- CSG, 269, L-80 VAM TOP HC, D = 6276' 1 4-112• LNR 12.6#, 13-CRHYD521, I -9077' .0152 bpf, D = 3.958' PERFORATION SUMMARY REF LOG: _ ON_/_/_ ANGLEAT TOP PERR 52' @ 9340' Note: Refer to Production OB for historical pert data SIZE SPF INTERVAL I Opn/Sgz I SHOT SOZ 2' 6 9340 - 9360 1 O 103105118 2' 6 9373 - 9384 1 O 03/05/18 13-1/4- LNR 6.6#,13CR-85 TC71, .0079 bpf, D= 2.85' 9-5/6' LOWER FOC GAS LFT MANDRELS ST MD I ND I DEV I TYPE I VLV I LATCH IDATE 04123115 0.14 SIDETRACK(03-15B) 5 3620 3610 14 KBG DOW BK 16 07/07/18 4 5482 5270 20 KBG DOME BK 16 07/07118 3 6763 6535 11 KBG DOME BK 16 07/07/18 2 7795 7552 8 KBG DOME BK 16 0X07/18 1 8619 8334 31 KBG SO BK 22 07/07/18 9-5/8'MLLOUT VWDOW (03456) 4307' - 4324' 8��—FT 1/2•HPS X NP. D=3.813- ) 7- X 41/2- HES TINT PAR D = 3.856- 14-112" FES X NP, D= 3.813' 3.70' DEPLOY SLV, D= 3.00- t-1/2- HES X NP, 93= 3.813' BEHIND CT LNR L7/2' HESX NP, D=2.812• X 5' BKR HRD-E ZXP LTP w /TEBACK SLV, D = 525' BENNO CT LNR t-12• WLEG, D = 3.958- BBINO CT LNR L12' X 3-1 /4' XO, ID = 2.786' •• X 5' BKR FLEX LOCK HGR D= 4 240• MLLOUT WINDOW (03-15C) 9077' - 9084' DATE REV BY COMMENTS DATE REV BY COMMENTS 02/23180 IDWAN 3 ORIGINAL COM PLErION 03/05/18BES/J SLTPTSALTP8X-NP(03ro4/18) 03/06/93 D-16 SIDETRACK(03-15A) 03/06/18 JNJ.MD ADD® REF 8 BF AEN 03/27197 NZE5 CTDSIDETRACK(03-15A L1) ON12118 BSE/JGLV CIO (03/03118) 04123115 0.14 SIDETRACK(03-15B) 03/12/18 BTNJMD ADP6ES(03/05/18) 02/10118 NCOM CTD ST (03-15C) 07110118 WJM) GLV C/O (07/07!18) 03/05118 ZB/JbD FNALODEAPPROVAL BEHIND CT LNR PRIDHOE BAY UNTT WELL: 03-15C PERMIT No: 217-317 AR No: 50-029-2041403 SEF 10, T10N, 1115E 1131' FSL a 54' SP Exploration (Alas ka) • • _ . oin .. O °) N m •J a ^ J , aI a 0 LL a LL > N n .. ° i ! ! 0 ji - 0 0 r) mI W N Tr i z 11 -- r O W J '1� p Z W1 Z >- >- >- i ti N _ a) roV Q Q w bN o Z LL u) t o o aso C > Z a Z, Z co UI r t o >- U d m Q N N m a) a) �O m In o O a) w w w 0 0 —1 A Si M W O — O O O O aII V O a) w1 a) co tl) 1 i w 1 Y vel 14= oaIU a� m •co co 2091—Ce 2O1i )0 E U �U�U �U�m �Q c a) } a 1X W�2I W�cI NZ C.) 0 O m LL O c0 a7 a w d w �) CL F• U N N E N £ rn co 0 W CO m CO Z - ai co IX 0 N N co a it. E Ii I W w a o cri N W J a) O) p. O m (7. a) €E 3 E ICC co w 0) .N cn to Ili a c_ a) v E •. a O &5 c 2 0 U a) 03 o 0 0 O a) ri Na r E Q 1 1 1 y V r oU Z a) o V 1 I . E in c E a orTi o .� C Z o3 CO o COQ L d 0 aa) E W CO M c o H E M 111 '_ co 0 1, v/ X p N °) c p a c 0 re o a O. m c O 2 U a o E 1 o t T Z o m vIIP 1 — 0 d U m coc co _ Ico m m 1 co n as m m -o N co a) C Z N, Wci N. .14 N O O O) O a) © e 0 M O G O O J E G c 13 M > U) )f) )c) c > m rc 1 to O O O W E a O a) N N N N M V O O F 3 d W -c c N m E E a) 1,) 1 1 w m a' N N Z ~ C C I— co ! Z = a3 O N o w Lo d Q O O li Q O D '++ C C °) 0 0 0 c t 5 11i a 6- a) ,a d ca £ 0 O a o a y E a rn — LL E O o E m E E a m ,w a _J 1 ? c� d cD 0 0 w 0 0 KEC:EIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N APR 0 4 2018 WELMPLETION OR RECOMPLETION REPRIF AND LOG la. Well Status: Oil RI ' Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 0 1b.Well Class: AOnn2OAAC 25.105 20AAC 25.11 o Jr!^�LY V CWINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: One Development ® Exploratory 0 Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc '3/5/2018 217-137 3. Address: 7. Date Spudded: 15 API Number: P.O.Box 196612 Anchorage,AK 99519-6612 . 2/8/2018 50-029-20414-03-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: .2/8/2018 PBU 03-15C Surface: 1131'FSL,54'FEL,Sec.10,T1ON,R15E,UM • 9 Ref Elevations KB •62.44 • 17. Field/Pool(s): Top of Productive Interval: 132'FSL,1049'FEL,Sec.10,T1ON,R15E,UM 'GL 26.06 . BF 27.78 . PRUDHOE BAY,PRUDHOE OIL • Total Depth: 27'FNL,1017'FEL,Sec.15,T1ON,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: ' 9486'/8966' • ADL 028328&028331 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 713213• y- 5937170 ' Zone - ASP 4 .9523'/8987' • 74-017 TPI: x- 712248 y- 5936143 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 712284 y- 5935985 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes Q (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) •9077'/8692' • 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. 11 Acronyms may be used.Attach a separate page if necessary MWD/GR/RES 23' CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT r FT. TOP BOTTOM TOP BOTTOM PULLED 20" 94# H-40 35' 115' 35' 115' 30" 417 sx Arctic Set 13-3/8" 72# L-80 35' 2723' 35' 2723' 17-1/2" 2350 sx Fondu 9-5/8" 47# S-951L-80 1971' 4307' 1971' 4262' 12-1/4" 500 sx Class'G',375 sx PF'C' 7" 26# L-80 32' 9036' 32' 8662' 8-1/2" 227 sx Class'G' 4-1/2" 12.6# 13Cr80 8806' 9077' 8487' 8692' 6-1/8" Uncmented Sliding Sleeves 3-1/4" 6.6# 13Cr85 8759' 9523' 8449' 8987' 4-1/4" 54 sx Class'G' 24. Open to production or injection? Yes IZI 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 8812' 8687'/8391' 2"Gun Diameter,6 spf •3/5/2018 9340'-9360' 8882'-8894' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 9373'-9384' 8902'-8908' Was hydraulic fracturing used during completion? Yes 0 No 121 • - Per 20 AAC 25.283(i)(2)attach electronic and printed N6/ig information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 2500' Freeze Protect w/40 Bbls Diesel 27. PRODUCTION TEST • Date First Production: March 16,2018 Method of Operation(Flowing,gas lift,etc.):Gas Lift Date of Test: 3/17/18 Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size Gas-Oil Ratio: 12 Test Period ...► 551 869 5 80 1578 Flow Tubing 220 Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(torr): Press 1410 24 Hour Rate 0. 1101 1737 10 N/A Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only Vrt, /z6/tg P11/ RBDMS j Al.-Y.-:: : 1 2 18G s 28. CORE DATA11110 Conventional Core(s) Yes 0 No 0 • Sidewall Cores Yes 0 No I 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 ND Permafrost-Top Well Tested? Yes 0 No l Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9322' 8871 separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit-Zone 4B 9150' 8749' 42SB-Zone 4A 9322' 8871' CGL-Zone 3 9451' 8947' Formation at total depth: Zone 3 9451' 8947' 31. List of Attachments: Summary of Daily Drilling Reports,Summary of Post-Rig Work,Survey,Cement Report,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka,Joseph N Contact Name: Browning,Zachary H Authorized Title: SIM S. st Contact Email: Zachary.Browning@bp.com Authorized Signature: 1` Date: �.'/�q` Contact Phone: +1 907 564 5220 INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and logon alltypes of lands and leases in Alaska.Submit P P ub t 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 1a. 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 lb.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only WEE= 1 WELLHEAD FMCY NOTE'S:"*CHROME TBG&LNR"* ACTUATOR • 0 3-15 C SMOGLEG:21.7-@ 9106'. OKB.ELEV= 64' 40 REF.ELEH 62.44' J '`i BF.ELEV= 27.78' I. s� KOP= 3300' 20 CONDUCTOR, —� 116' j t.� H40, I .t 2011' —I4-1/2"HES X NP,D=3.813" Max Angle= 56"@ 9411" I f �t♦. D=19.1024" 1t J Datum MD 9308 ' 2332' - I9-5/8"UPPER FOC Datum TVD' 8800 SS a 2461' J--H9-518"LOWER FOCI 9-5/8"CSG STUB(03/28115) 1973' GAS LFT MANDRELS 13-3/8'CSG,72#,1-80 BTC,13=12.347" }--I 2720' ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3620 3610 14 KBG DOME BK 16 03/03/18 Minimum ID =2.31" @ 8771' 4 5482 5270 20 KBG SO BK 20 03/03/18 2-7/8" X NIPPLE IN PTSA LTP 3 6763 6535 11 KBG DMY BK 0 04/23/15 9-5/8"BKR WHPSTOCK(03/2915) H 4307' 2 7795 7552 8 KBG DMY BK 0 04/23/15 1 8619 8334 31 KBG DMY BK 0 04/23/15 9-5/8"CSG,47#,S-95,D=8.681" H 4307' f 9-5/8"MLLOUT WINDOW(03-15B)4307'-4324' TOP OF CEMBYT(04/06/15) H —7736' '4 00"°I * 8666' —14-1/2'HES X NP,13=3.813" f lk- I I e 8687' 1-17 BS X 4-1/2"ITNT PKR D=3.856" 45KB NS LTP w/PISA/QCLL, — 8759' 4t W 8724' —14-1/2'HES X NP,D=3.813" m. 4. D=2.31"(03/04/18) r; LTOP OF 3-1/4"LNR/CMT —I 8769' F! .11 8769' —13.70"DEPLOY SLV,13=3.00" 2-7/8"X NP,D=2.31" H 8771• ►r gri mi j �.-, ��, 8786' --1 3-1/2"W�LTEC SLIM TKR,D=2854" r r ►l+ 4,-.III` 8796' —14-1/2"HES X NP,D=3.813"BEHIND CT LNR 4 1.4 r+ ,0 8801' I3-1/2"HES X NP,D=2.812" I t+ ri TOP OF 4-1/2"LNR 8806' ii ♦ r 4 r 8806' —7"X 5'BKR HRD-E ZXP LTP w/TIEBACK SLV, I N Pi `q D=5.25' BBIND CT LNR 4-1/2'TBG,12.6#,13CR-85 VAM TOP, -I 8812' .1 'j 'i S 8812' ---I4-112"WLEG,D=3.958"BOUND CT LNR .0152 bpf,D=3.958" #� •+1 J-' 7"CSG PUNCHES(CLOSED):8835'-8840'& 0'1 ,1-4• .-4�j • • North America-ALASKA-BP Page 1 of 6 Operation Summary Report Common Well Name:03-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2018 End Date:2/9/2018 X3-018R5-C:(1,032,928 00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:1/15/1980 12:00:00AM Rig Release:2/10/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001388 Active datum:KB @62.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 2/5/2018 21:00 - 22:15 1.25 RIGD P PRE RIG DOWN AND PREPARE FOR RIG MOVE. 22:15 - 22:30 0.25 RIGD P PRE PRE JOB SAFETY MEETING WITH CREWAND TRUCK DRIVERS. -EMPHASIS ON GOOD COMMUNICATION, VERIFY STOP COMMAND. I-STOP BLOCK IN PLACE TO PREVENT RIG FROM ROLLING FORWARD. -VALVES ON TREE SECURED AND ALL ANNULUS PRESSURES LESS THAN 50 PSI. -DRILL SITE OPERATOR NOTIFIED AND DECLINED WITNESSING RIG MOVE OFF OF WELL. COLD OUTSIDE,WATCH EACH OTHER FOR FROSTBITE AND WARM UPAS NEEDED. -ANYONE CAN STOP THE JOB AT ANYTIME.BE WATCHFUL 22:30 - 00:00 1.50 MOB P PRE HOOK UP TO PIT MODULE AND PULL FORWARD. -PULL SUB OFF OF WELL,PULL PIT MODULE OFF OF WELL. -WELL SITE LEADER AND NABORS TOOLPUSHER WITNESSED PULLING OFF OF WELL. ..HOOK UP JEEPS. 2/6/2018 00:00 - 03:00 3.00 MOB P PRE FINISH RIGGING UP TO JEEPS. -MOVE RIG TO DRILL SITE#3,(3 MILE MOVE). 03:00 - 05:30 2.50 MOB P PRE REMOVE JEEPS. -DRILL SITE OPERATOR ON LOCATION TO WITNESS MOVING OVER WELL. -WSLAND NABORS TOOLPUSHER WITNESS MOVING OVER WELL. -STOP BLOCK IN PLACE,STOP COMMAND AGREED UPON. -CHECK ANNULUS PRESSURES,ENSURE WELL IS SHUT IN AND SECURE. -SPOT UP ON WELL. 05:30 - 09:00 3.50 RIGU P PRE SUB AND PITS SPOTTED,START RU CHECK LIST.RIG ACCEPTED @ 05:30 HRS, 02/06/2018. 09:00 - 09:15 0.25 RIGU P PRE LTT MASTER&SWAB TO RU MPL 09:15 - 10:30 1.25 RIGU P PRE GOOD PT,MU MPL 10:30 - 11:00 0.50 RIGU P PRE REMOVE TREE CAP TO NU BOPE 11:00 - 14:45 3.75 BOPSUR P PRE NU BOPE....CONFIGURATION AS FOLLOWS: F/TOP DOWN. -7 1/16"X 5M ANNULAR PREVENTOR,BLIND/ SHEAR RAMS -2 3/8"PIPE/SLIPS,MUD CROSS,2 3/8"X 3 1/2"VARIABLE RAMS -2 3/8"PIPE SLIPS. -PJSM.C/O RISERS,R/U TEST JT AND GREASE VALVES. 14:45 - 15:15 0.50 BOPSUR P PRE SHELL TEST ON STACK,250/3500 PSI, GOOD. -ALL COMPONENTS ON BOPE FUNCTION TESTED WITH REMOTE STATION,GOOD. __ Printed 3/2/2018 2.17:33PM "'All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 2 of6 Operation Summary Report Common Well Name:03-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2018 End Date:2/9/2018 X3-018R5-C:(1,032,928.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:CDR-2 Spud Daterme:1/15/1980 12:00:00AM Rig Release:2/10/2018 Rig Contractor NABORS ALASKA DRILLING INC. BPUOI:USA0000138B Active datum:KB @62.44usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT Total Depth Phase Description of Operations (hr)_ (usft) 15:15 - 21:45 6.50 BOPSUR P PRE COMMENCE BOPE TESTAS PERAOGCCAND BP REQUIREMENTS -H2S AND LEL ALARMS TESTED BY ELECTRICIAN,GOOD. -AOGCC REP JEFF JONES WAIVED WITNESSING,24 HOUR NOTICE GIVEN. -TEST ALL COMPONENTS @ 250/3500 PSI,5 tMIN EACH/CHARTED. -TEST ALL RAMS,ANNULAR PREVENTOR, AND CHOKE VALVES. • -TEST HCR VALVES.ACCUMULATOR DRAW DOWN TEST. -NO FAILURES,(1)PASS/FAIL ON BLIND SHEAR RAMS. 21:45 - 22:45 1.00 BOPSUR P PRE UD TEST JT,M/U QTS SUB. -CHECK PACKOFFS,-PREP TO FILL COIL. 22:45 - 23:15 0.50 BOPSUR P C PRE H2S/RIG EVACUATION DRILL,FULL MUSTER. H2S RELEASE IN THE CELLAR.ALL HANDS 'MUSTERED TO THE BRM. --MUSTER TIME(4)MINUTES,ALL HANDS ACCOUNTED FOR.TRUCK DRIVERS TOO. '-(2)HANDS DONNED SCOTT AIR PACKS, WELL SECURED. GOOD AAR,NO SIGNIFICANT GAPS,DRILL SITE OPERATOR NOTIFIED. 23:15 - 00:00 0.75 BOPSUR P PRE PJSM.LINE UP TO DISLPACE COIL TO WATER. 1-DISPLACE COIL W/WATER,1.75 BPM/1100 PSI. 2/7/2018 '00:00 - 00:15 • 0.25 BOPSUR P 1PRE COMPLETE DISPLACEMENT OF COIL TO WATER. -PRE SPUD WITH CREW ON TOUR. 00:15 - 01:30 1.25 BOPSUR -- P 1 PRE PJSM.LINE UP TO TEST INNER REEL IRON. -TEST INNER REEL IRON AND PACKOFFS @ 250 3500 PSI,OK. -REVERSE PRESSURE TEST ON C9 AND C10 @ 250/3500 PSI,GOOD. 01:30 - 02:45 1.25 BOPSUR P PRE PJSM.VALVE CREW TIGHTENING TREE BOLTS,VERIFYING PROPER TORQUE. 02:45 - 03:15 0.50 RIGU P PRE 1 H2S RIG EVAC DRILL WITH COYNE CREW. •ALL PERSONNEL MUSTER AND ACCOUNTED FOR IN 4 MIN. CONDUCT AAR AFTERWARDS. 03:15 - 04:15 1.00 BOPSUR P PRE INSTALL CHECK VALVES AND MAKE UP UQC. PRESSURE TEST UQC CONNECTION TO 3,500 PSI,GOOD. PRESSURE TEST CHECK VALVES TO 3,500 PSI,FAIL. 04:15 - 04:45 0.50 RIGU P PRE i CHANGE OUT CHECK VALVES IN UQC. i RE-TEST UQC CONNECTION,GOOD. !TEST CHECK VALVES TO 3,500 PSI,GOOD. 04:45 - 06:20 1.58 RIGU P PRE INSTALL NOZZLE AND M/U RISER TO WELL, PT QTS. DISPLACE FRESH WATER OUT OF REEL AND OUT TO TIGER TANK WITH MEOH SPEAR FOLLOWED BY KCL. 06:20 - 07:00 0.67 I RIGU P PRE OPEN WELL UP TO A CLOSED CHOKE,NO PRESSURE. CHECK RISER AT RIG FLOOR, i NOTHING. FILL WELL WITH 1.5 BBLS MEOH. 07:00 - 08:00 1.00 STWHIP P • WEXIT OPEN RISER AND OBSERVE WELL,STATIC. C Printed 3/2/2018 2:17:33PM 'All depths reported in Drillers Depths* • North America-ALASKA-BP ` Page 3 of 6 Operation Summary Report Common Well Name:03-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2018 End Date:2/9/2018 X3-016R5-C:(1,032,928.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:1/15/1980 12:00:00AM Rig Release:2/10/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001388 Active datum:KB @62.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase l Description of Operations (hr) (usft) 08:00 - 12:00 4.00 STWHIP P 9,078.50 WEXIT RIH WITH 3.80"MILLING BHA#1 -RATE:0.3 BPM IN,0.7 BPM OUT. -MUD WEIGHT:8.34 PPG IN,8.41 PPG OUT -LIGHT TAG ON WHIPSTOCKAT 9,065' -PICK UP AND CIRCULATE REMAINING KCL FOLLOWED BY DRILLING MUD AT 3.70/3.70 BPM AT 2,100 PSI. -TIE IN DEPTH WHILE CIRCULATING WELL OVER,CORRECT+13.5'. 12:00 - 16:00 4.00 STWHIP P 9,079.60 WEXIT WITH MUD ALL THE WAY AROUND,CLOSE EDC. 10 MIN PUMPS OFF FLOWCHECK IS GOOD, WELL STATIC. MILL 3.80"WINDOW IN 4-1/2"LINER PER • BAKER REP FROM 9,077.5'MD TO 9,079.6'MD -RATE:2.88 BPM IN,2.89 BPM OUT -MUD WEIGHT:8.73 PPG IN,8.87 PPG OUT -DWOB'.1-3 KLBS CIRC PRESSURE:3,100-3,300 PSI 16:00 - 00:00 8.00 STWHIP P 9,084.30 WEXIT CONTINUE MILLING WINDOW F/9079.6'. -2.82 BPM IN/2.80 BPM OUT.3000 PSI FREE SPIN. -SAW STALL @ 9079.9'AND ACCOMPANIED BY 12-15 BPH LOSS RATE. -CONTINUE MILLING,LOSSES HEALED UP FAIRLY QUICKLY. -MILLING @ 1 FOOT/HR OR SLIGHTLY LESS. -MILL TO 9081.2'AND PUMP A 5 BBLS LO VIS/ 5 BBLS HI VIS SWEEP. -CONTINUE TO MILL WINDOW.2.82 BPM IN/ 2.80 BPM OUT,8.78 PPG MUD IN/8.73 PPG MUD OUT. -GEOLOGIST CHECKING SAMPLES REGULARLY. -MILL WINDOW TO 9084.3'AND OUT. 2/8/2018 00:00 01:00 1.00 STWHIP P 9,086.00 WEXIT MILLTHRU WINDOW W/STRING REAMER. -CATCH SAMPLE F/9086',40%CALCAREOUS SHALE,(SHUBLIK). -LOSS RATE IS LESS THAN 1 BPH. 01:00 - 03:30 2.50 STWHIP P 9,095.20 WEXIT MILLING RATHOLE....9084.3'-9095.2 -2.82 BPM IN,2,82 BPM OUT,3050 PSI FREE SPIN. -ON BOTTOM DRILLING PRESSURE-3100 PSI-3300 PSI. -WOB 2-4K.@ 9091.5'START A 5 BBLS LO VIS/5 BBLS HI VIS SWEEP AROUND. 03:30 - 04:45 1.25 STWHIP P 9,095.20 WEXIT COMMENCE DRESSING WINDOW.UP WT- 52K DOWN WT 26K. • -2.84 BPM IN/2.84 BPM OUT/3050 PSI. -MAKE(3)PASSES.UPREAM ONCE EACH @ 162 LOHS,147 LOHS AND 177 LOHS. -REAM DOWN EACH TIME AT AS MILLED TF 4' (162 LOHS).NO ISSUES. -DRY DRIFTED,OK,NO ISSUES. -TOW 9077.5', BOW 9084.3'. 04:45 - 07:00 2.25 STWHIP P 9,095.20 WEXIT PERFORM DYNAMIC FLOW CHECK. -8.75 PPG MUD IN AND OUT,WELL BORE STABLE,NO LOSSES. -PAINT FLAG @ 9032',(8900'EOP). -POOH W/WINDOW MILLING BHA. Printed 3/2/2018 2:17:33PM *AII depths reported in Drillers Depths* iNorth America-ALASKA-BP • 7: r t -� Page 4 of�. Operation Summary Report Common Well Name:03-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2018 End Date:2/9/2018 X3-018R5-C:(1,032,928 00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:1/15/1980 12:00:00AM Rig Release:2/10/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001388 Active datum:KB @62.44usft(above Mean Sea Level) Date From-To Hrs Task Code j NPT Total Depth Phase Description of Operations (hr) (usft) 07:00 - 08:00 1.00 STWHIP P 9,095.20 WEXIT STOP AT 200 FT FOR FLOW CHECK. TRIP SHEET SHOW 0.3 BBL LOSS TO THIS POINT. -EXTENDED FLOW CHECK,20 MIN. -WELL BORE STABLE,8.75 PPG MUD IN/8.75 PPG MUD OUT. 08:00 - 09:00 1.00 STWHIP P 9,095.20 WEXIT CONTINUE WITH UD BHA. OPEN RISER AND CHECK LAST 70 FT OF CT FOR FLAT SPOTS,NONE SEEN. L/D BHAAND 2 JTS OF PH6. BOTH MILL AND STRING REAMER ARE 3.79"NO-GO. INJECTOR OFF AT 08:30. CLEAN AND CLEAR RIG FLOOR. 09:00 - 10:00 1.00 STWHIP P 9,095.20 PROD1 MAKE UP 4.25"DRILLING BHA#2 -PICK UP 2-7/8"ULS MOTOR(1.3 DEG AKO) AND 3"COILTRAK TOOLS -MAKE UP 4.25"HYC BICENTER BIT WITH TC BUTTONS -SURFACE TESTED COILTRAK TOOL.GOOD TEST. -PRESSURE TEST QTS TO 3,500 PSI HIGH FOR 5 MINUTES -INJECTOR ON:10:00 10:00 - 12:45 2.75 STWHIP. P 9,095.20 PROD1 RIH WITH 4.25"DRILLING BHA#2 -RATE:0.27 BPM IN,0.72 BPM OUT.CIRC PRESSURE:925 PSI -MUD WEIGHT:8.76 PPG IN,8.77 PPG OUT -LOG DOWN FOR TIE-IN FROM 8,970' (FORMATION)WITH-10'CORRECTION 12:45 - 18.15 5.50 DRILL P ,9,095.2G PROD1 PASS THROUGH WINDOW WITH NO ISSUES AT 160L,12 FT/MIN,0 PUMP. DRILL 4.25"LATERAL FROM 9,095'MD TO 9,320'MD -FREE SPIN:3,200 PSI,2.81 BPM -RATE:2.86 BPM IN,2.87 BPM OUT.CIRC PRESSURE:3,200-3,450 PSI -MUD WEIGHT:8.73 PPG IN,8.78 PPG OUT, ECD:10.1 PPG WITH OPEN CHOKE -ROP:10-80 FT/HR,WOB:2-3.5 KLBS 18 15 - 20:45 2.50 DRILL P 9,095.20 PROD1 DRILL 4.25"LATERAL FROM 9,320' to 9380'MD -ENTERING 42N SHALE,ABOUT 40-45' VERTICAL FEET OF SHALE HERE. -FREE SPIN:3,200 PSI,2.81 BPM -RATE:2.79 BPM IN,2.81 BPM OUT.CIRC !PRESSURE:3,200-3,450 PSI -MUD WEIGHT:8.83 PPG IN,8.83 PPG OUT, ECD:10.1 PPG WITH 90 PSI WELLHEAD PRESSURE. -ROP:15-30 FT/HR,WOB:2-3.5 KLBS OUT OF 42N. Printed 3/2/2018 2 17 33PM *All depths reported in Drillers Depths* North America ALASKA BP Page 5 of 6 Operation Summary Report - Common Well Name:03-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2018 End Date:2/9/2018 X3-018R5-C:(1,032,928.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:1/15/1980 12:00:OOAM Rig Release:2/10/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001388 Active datum:KB @62.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 20:45 - 00:00 3.25 DRILL P 9,520.00 PROD1 DRILL 4.25"LATERAL FROM 9,380' to 9400'MD -THRU THE 42P SECTION IN SHORT ORDER, ROP 100 PLUS FPH. -DRILL ON INTO ZONE 3 F/9400'-9520' FREE SPIN:3,200 PSI,2.81 BPM -RATE:2.79 BPM IN,2.81 BPM OUT.CIRC PRESSURE:3,200-3,450 PSI -MUD WEIGHT:8.83 PPG IN,8.83 PPG OUT, ECD:10.1 PPG WITH 105 PSI WELLHEAD PRESSURE. i -ROP:25-50 FT/HR,WOB:2-3.5 KLBS GEOLOGIST CALLED TD @ 9520'MD.(8923' . TVD) 2/9/2018 00:00 - 03:45 3.75 DRILL P 9,520.00 PROD1 WELL IS TD'D.10 BBLS LO VIS/10 BBLS HI VIS SWEEP OUT AT THE BIT. -CHASE TO WINDOW,PERFORM 100'JOG DOWN AND BACK UP. -2.8 BPM @ 3300 PSI,NO LOSSES.BRING DOWN TO MIN RATE AND THRU WINDOW. -THRU WINDOW,SMOOTH AND BRING PUMPS BACK UP TO RATE. -PULL UP 50'AND BACK DOWN.OPEN EDC AND COMPLETE BOTTOMS UP. -3.19 BPM/2950 PSI,3.19 BPM OUT,NO LOSSES. -8.82 PPG MUD IN/8.79 PPG MUD OUT. -LOG GAMMA TIE IN,PLUS 3 1/2' CORRECTION. -LOG CCL F/8650'-8850'. -NO SIGNIFICANT INCREASE IN CUTTINGS WHEN SWEEP BACK. -CLOSE EDC AND BACK DOWN THRU WINDOW,NO ISSUES. -UP WT 61K,DOWN WT 22K W/PUMPS OFF AT THE WINDOW. -RUN IN HOLE TO TD,HOLE IS CLEAN W/NO ISSUES. -TAG TD,CORRECTED TD IS 9523'.10 BBLS LO VIS X 10 BBLS HI VIS SWEEP OUT AT THE BIT. -CHASE SWEEP OUT,100'JOG DOWN BEFORE PULLING THRU WINDOW@ MIN RATE. -THRU WINDOW,OPEN EDC AND GET(3) PICK UPS W/PUMPS OFF. -DISTANCE TRAVELLED F/DOWN WT TO I BREAK OVER=3'AVERAGE. -W/EDC OPEN,RUN BACK DOWN THRU WINDOWAND JET WHIPSTOCK TRAY,NO ISSUES. 03:45 - 06:15 2.50 DRILL P 9,520.00 PROD1 POOH.CHASING SWEEP TO SWAB.3.2 BPM/ 2950 PSI. -PAINT TD FLAG,(WHITE),@ 8679.5',(8600' EOP) -DYNAMIC FLOW CHECK,(10 MIN),WELL BORE IS STABLE. -8.82 PPG MUD IN,8.8 PPG MUD OUT. -PAINT WINDOW FLAG,(YELLOW), @ 8179.5', (8100'EOP). -CONTINUE TO POOH PUMPING 3.2 BPM/ 2925 PSI. Printed 3/2/2018 2:17:33PM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 6 of 6 Operation Summary Report Common Well Name:03-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2018 End Date:2/9/2018 X3-018R5-C:(1,032,928.00) Project:Prudhoe Bay Site:PB DS 03 • Rig Name/No.:CDR-2 Spud Date/Time:1/15/1980 12:00:00AM Rig Release:2/10/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001388 Active datum:KB @62.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT ' Total Depth Phase Description of Operations (hr) (usft) 06:15 - 08:00 1.75 DRILL P 9,520.00 PROD1 PERFORM 200'JOG AT SURFACE. FLOW CHECK AT 200 FT,WELL STATIC. OPEN RISER AND CHECK LAST 50 FT OF CT, NO FLAT SPOTS SEEN. LAY DOWN BHA#2. BIT IS 2-1. INJECTOR OFF AT 06:45. WHILE MOVING INJECTOR CART CONDUCT --KICK DRILL WITH COYNE CREW. CREW SECURES WELL AS PER STANDING ORDERS THEN GO TO ASSIGNED STATIONS. WELL IS SECURE IN 2 MIN 45 SEC. I CONTINUE WITH LID BHA. IFINISH RON EVENT,SWITCH TO CON EVENT. Printed 3/2/2018 2.17:33PM `AII depths reported in Drillers Depths* • S North America-ALASKA-BP Page 1 of 4 Operation Summary Report Common Well Name:03-15 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/9/2018 End Date:2/10/2018 X3-018R5-C:(692,172.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:1/15/1980 12:00:00AM Rig Release:2/10/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001388 Active datum:KB @62.44usft(above Mean Sea Level) Date I From-To Hrs Task Code I NPT Total Depth Phase Description of Operations (hr) (usft) 2/9/2018 08:00 - 10:00 2.00 CASING P 9,523.00 RUNPRD CLEAR RIG FLOOR.REMOVE BHI UQC AND BOOT E-LINE.MAKE UP 1 JT OF BTS-6 AND GET ON WELL,PUMP OUT CABLE SLACK. CUT OFF 248 FT OF E-LINE SLACK. 10:00 - 11:00 1.00 CASING P 9,523.00 RUNPRD PJSM AND REVIEW PROCEDURE FOR DROPPING BALL. DROP 7/8 BALLAND LAUNCH WITH 3,500 PSI. BALL IS HEARD ROLLING AND GOING OVER THE GOOSENECK. 11:00 - 12:00 1.00 CASING P 9,523.00 RUNPRD OPEN RISER,RECOVER 7/8"BALL. RIG UP ELEVATORS AND DRESS TONGS FOR !3-1/4". 1 GREASE ELEVATORS. GET XO READY FOR SAFETY JOINT. VERIFY PIPE COUNT IN SHED. 12:00 - 13:00 1.00 CASING P 9,523,00 RUNPRD CONDUCT PJSM AND REVIEW PROCEDURE FOR MAKING UP LINER. START MAKING UP SHOE TRACK AND I JEWELRY. PROBLEM WITH LITTLE JERKS,NOT _ PROVIDING ENOUGH TORQUE. 13:00 - 14:30 1.50 CASING N 9,523.00 RUNPRD -SPARE LITTLE JERKS IS BOUGHT FROM _SHOP,CHANGE OUT. -SWAP OUT HYDRAULIC FITTINGS. 14:30 - 18:00 3.50 CASING P 9,525.00 RUNPRD LITTLE JERKS WORKING,CONTINUE MAKING 1 UP SHOE TRACK EQUIPMENT AND 3-1/4" LINER. FILL FIRST 3 JTS THEN EVERY 10.SHOE 'TRACK MADE UP.MAKE UP WELL TEC LINER TOP PACKER. -MAKE UP(6)JTS BT-6 AND MAKE UP TO COIL CONNECTOR.INJECTOR ON©18:00 HRS. 18:00 - 21:00 3.00 CASING P 9,523.00 RUNPRD RIH W/LINER ASSEMBLY..26 BPM/1225 PSI. -CORRECTED DEPTH AT WINDOW FLAG, MINUS 12.6'CORRECTION. -25K DOWN WT,56K UP WT.GET(2)PICK UPS FROM DOWN WT TO UP WT. -DISTANCE TRAVELLED 4.6'AND 4.4',(4 1/2' AVERAGE). -CONTINUE IN HOLE,35 FPM,RIGHT TO I BOTTOM,NO BOBBLES. -NO CORRECTION NECESSARY @ TD FLAG. TAG @ 9522'.SET DOWN 10K. -CONDUCT(2)BREAKOVER DISTANCE OPS. FROM 10K STACKED W/NO PUMPS. -PICK UP©30 FPM,25K DOWN WT,61K UP WT.3X AVERAGE 9'TRAVEL TO BREAKOVER. Printed 3/2/2018 2:25:04PM `AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 2 of 4 Operation Summary Report Common Well Name:03-15 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/9/2018 End Date:2/10/2018 X3-018R5-C:(692,172.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:1/15/1980 12:00:00AM Rig Release:2/10/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001388 Active datum:KB @62.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 21:00 - 22:45 1.75 CASING P 9,523.00 RUNPRD PJSM FOR DROPPING BALL AND CIRCULATING. -REVIEW OF PRESSURE CROSS CHECK LIST. POSITION COIL AND DROP 5/8"BALL. PRESSURE UP TO 3300 PSI. -LAUNCH BALL AND CIRCULATE AROUND @ 2 BPM/2450 PSI. -SET DOWN 10K DOWN,(15K ON WT INDICATOR). -PUMP 34 BBLS,SHOULD BE OVER GOOSENECK,SLOW PUMP TO 1/2 BPM,1375 PSI. -PUMPED TOTAL OF 67 BBLS,DID NOT SEE BALL GO ON SEAT. 22:45 - 23:30 0.75 CASING P 9,523.00 RUNPRD RELAUNCH SEQUENCE.SHUT DOWN PUMP, BLEED PRESSURE. -VERIFY BALL IS NOT AT THE LAUNCH SITE. REPRESSURE,3400 PSI. -OPEN UP AND LAUNCH AND PUMP @ 2 BPM 2450 PSI,32 BBLS. -DROP RATE TO 1/2 BPM @ 1375 PSI.W/42 BBLS AWAY,BALL ON SEAT. -PRESSURE UP AND SHEAR BALL SEAT @ '3500 PSI. -PICK UP AND SEE BREAK OVER AFTER 8', (51 K UP WT).REPEAT,OK. 23:30 - 00:00 0.50 CASING P 9,523.00 RUNPRD CIRCULATE KCLAROUIND @ 2 BPM/2100 PSI. 2/10/2018 00:00 - 01:30 ' 1.50 CASING P 9,523.00 RUNPRD CONTINUE TO CIRCULATE KCL AROUND. -2 BPM @ 1700 PSI,NO LOSSES DURING CIRCULATION. SLOW RATE TO 1 1/2 BPM/725 PSI,OK. -BRING PUMP BACK UP TO 2 BPM 1175 PSI. 01:30 - 02:45 1.25 CEMT P ' 9,523.00 RUNPRD PJSM W/SCHLUMBERGER TO PT LINES. -SCHLUMBERGER CEMENTERS PT LINES TO 4700 PSI,FAILED. -2ND ATTEMPT TO PT LINES,FAILED. DETERMINED FAILURE POINT IS ON THE CEMENTERS SIDE. -GREASE VALVES AND PUMP A LITTLE FLUID TO KEEP FROM FREEZING UP. -PT CEMENT LINE TO RIG @ 4700 PSI,GOOD TEST.BREAK CIRCULATION @ 2 BPM/1200 PSI. 02:45 - 03:00 0.25 CEMT P 9,523.00 RUNPRD PJSM WITH ALL PARTIES INVOLVED. -EMPHASIS ON PROPER VALVE ALIGNMENT. -EMPHASIS ON GOOD COMMUNICATION TECHNIQUE. -REVIEWED PRESSURE CROSS CHECK LIST, BARRICADES UP. Printed 3/2/2018 2.25:04PM *AII depths reported in Drillers Depths* • North America-ALASKA BP • Page 3 of 4 Operation Summary Report Common Well Name:03-15 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/9/2018 End Date:2/10/2018 X3-018R5-C:(692,172.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:1/15/1980 12:00:00AM Rig Release:2/10/2018 Rig Contractor:NABORSALASKA DRILLING INC. BPUOI:USA00001388 Active datum:KB @62.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 03:00 - 04:45 1.75 CEMT P 9,523.00 RUNPRD BATCH UP CEMENT. -CEMENT WET @ 03:02 AND UP TO WEIGHT @ 03:12 HRS.(15.3 PPG). -PUMP CEMENT 1.3 BPM/825 PSI,UP TO 1.5 BPM @ 1050 PSI ICP. -PUMP 12.6 BBLS 15.3 PPG CEMENT,SHUT DOWN,CLOSE CHOKE AND INNER REEL VALVE. -LINE UP AND WASH UP LINE TO CEMENTERS. -LINE UP AND DISPLACE CEMENT @ 2BPM/ 1933 ICP. -DISPLACE W/8.4 PPG KCL W/1.25 PPB GEO VIS. 68.7 BBLS AWAY,SHUT DOWN,PICK UP TO 9502',DOGS OUT. -SLACK BACK OFF W/10K DOWN @ 9514'. (10'HIGHER).ROLL PUMPS TO LAND PEE WEE DART -PICK UP AND DUMP PRESSURE,SIDE EXHAUST 5 BBLS CEMENT AND 3 BBLS GEO VIS. '-OPEN BLEEDER AND SET BACK DOWN W/. 10K @ 9514'.CLOSE BLEEDER.SHEAR LWP W/4100 PSI. - RESUME PUMPING @ 1.5 BPM AND SEE PLUG BUMP W/5.7 BBLS PUMPED. CALCULATED 5.6 BBLS TO BUMP). - BLEED OFF PRESSURE. CHECK FLOATS, FLOATS HOLDING.CLOSE IN BLEEDER.CIP @ 04:25. EST 6.5 BBLS CEMENT BEHIND PIPE.NO LOSSES TO FORMATION DURING CEMENTING OP.. - PRESSURE UP TO 2700 PSI TO BEGIN SETTING WELL TEC PACKER. -HOLD 5 MIN AND PRESSURE UP TO 4700 PSI &HOLD 5 MIN TO COMPLETE SETTING PACKER. - BLEED PRESSURE TO 1500 PSI.PICK UP AND SEE PRESSURE DROP,BRING ON PUMPS. 04:45 - 06:30 1.75 CEMT P 9,523.00 RUNPRD PUMP 5 BBLS AT TOP OF LINER AND START PULLING OOH PUMPING MAX RATE. -3.5 BPM @ 2800 PSI.NO LOSSES WHILE CIRCULATING HOLE CLEAN. -CEMENT COMES BACK IN A SINGLE AMOUNT,RETURNS GO TO 11.4 PPG BRIEFLY. -CONTINUE POOH PUMP 3.7 BPM/2,000 PSI. Printed 3/2/2018 2:25:04PM *All depths reported in Drillers Depths* • North America ALASKA-BP • Page 4 of 4 Operation Summary Report Common Well Name:03-15 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/9/2018 End Date:2/10/2018 X3-018R5-C:(692,172.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:1/15/1980 12:00:00AM Rig Release:2/10/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001388 Active datum:KB @62.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations +06:30 - 08:00 1.50 CEMT P 9,523.00 RUNPRD PULL UP TO 3,000 FT AND DROP 3/4"BALL TO TEST SECONDARY BALL SEAT MECHANISM IN THE SELRT. BALL IS LAUNCHED AS PER CDR IPROCEDURE. PUMPAT2 BPM,BALL IS HEARD ROLLING, HOWEVER IT IS NOT HEARD GOING OVER THE GOOSENECK. AFTER 70 BBLS AWAY NO SIGN OF 3/4"BALL. LAUNCH A SECOND TIME WITH 2,000 PSI AND CHASE AT 2 BPM,NOTHING HEARD. TRY RIH/POOH WHILE PUMPING,NOTHING SEEN. INCREASE'RATE TO 3 BPM,CONTINUE CYCLING REELAND PUMP. BALL GOES ON SEAT AT 140 BBLS AWAY (REEL VOLUME IS 60). SHEAR OUT BALL SEAT AT 3,900 PSI. 08:00 - 10:00 2.00 WHSUR P 9,523.00 RUNPRD MOVE TO 2,500 FT FOR FREEZE PROTECT. LRS IS ALREADY RIGGED UP,CONDUCT PRESSURE XCHECK VERIFICATION AND PT LINES. WSL WITNESS LOW PRESSURE PUMP TRIPS. POOH REMAINING 2,500 FT FREEZE PROTECT WITH DIESEL. 10:00 - 11:20 1.33 WHSUR P 9,523.00 RUNPRD 10 MIN FLOW CHECK AT SURFACE IS STATIC. INJECTOR OFF AT 10:30 UD 6 JTS BTS6 AND LINER RUNNING TOOL, TOOL HAS FUNCTIONED NORMALLY. RECOVER 5/8"AND 3/4"BALLS. 11:20 - 12:00 0.67 RIGD P 9,523.00 POST CLEAR RIG FLOOR. OFFLOAD LINER RUNNING TOOLS. WELLS SUPPORT GREASE AND SERVICE TREE VALVES,REMOVE FUSIBLE CAP FROM SSV. 12:00 - 14:30 2.50 RIGD P , 9,523.00 POST REMOVE CT CONNECTOR. PUMP SLACK BACKWARDS. RIG UP HYDRAULIC CT CUTTER,CUT OFF 300 FT OF CT AND OFFLOAD FROM RIG. THIS GIVES 1.8%EXCESS CABLE. 14:30 - 18:00 3.50 RIGD P 9,523.00 POST INSTALL CT CONNECTOR,PULL TEST AND PRESSURE TEST,GOOD -REHEAD&BOOT E LINE. 18:00 - 00:00 6.00 RIGD P 9,523.00 POST END OF WELL OPERATIONS. -BLOW DOWN COIL W/AIR.GREASE BOPE STACK. -REMOVE MANAGED PRESSURE DRILLING LINE. -LTT SWAB AND MASTER VALVES @ 3500 PSI,GOOD. -PJSM.N/D BOPE.MAKE UP TREE CAP AND LTT @ 3500 PSI,GOOD. -RIG RELEASED @ 23:59 HRS,02/10/2018. Printed 3/2/2018 2:25:04PM `All depths reported in Drillers Depths* i r Daily Report of Well Operations 03-15C ACTIVITYDATE SUMMARY T/I/O=0/0/156 Temp=SI LRS Unit 46 - Pressure Test Liner Lap/ LTP (CTD) Pumped 8 bbls of DSL down TBG, unable to reach test pressure pulling off of DSL pup, LLR of 2 bpm at 1800 psi Bled down tubing to 50 psi to relax packer elements. Pumped 4 bbls of DSL down TBG, slowly ramped up to 1890 psi, LLR of 2.5 bpm at 1890 psi Bled down tubing to 200 psi to relax packer elements. Pressured up at 3 bpm to max pressure of 2500 psi, S/D to allow pressure to leak off to 1100 psi Pressured up at 4 bpm to max pressure of 2300 psi, no improvement, Roll into Injectivity Test- See log for details 2/13/2018 SV,WV,SSV=closed IA,OA=OTG FWHP=892/0/134 ***WELL S/I ON ARRIVAL***(ctd) DRIFTED WITH 20' OF 2" DMY GUNS. TAG STICKY BOTTOM AT 9475' SLM. 3/1/2018 ***MOVE TO WEATHER TICKET*** ***CONT'D FROM 3/1/18 WSR***(ctd) RAN PDS 24 ARM CALIPER PER PROGRAM (Missing bottom 400') SET 4 1/2"WHIDDON C-SUB AT 8758' SLM PULLED BK-DUMMY GLVS FROM STA#5 . 3/2/2018 ***CONT ON 3-3-18 WSR*** WHP= 0/0/192 Temp= SI Assist SL as directed. Pump 35 bbls crude down tbg while slickline worked brush. Pumped 22 bbls crude to assist SL with drift run. Pumped 35 bbls 3/3/2018 crude down tbg while slickline worked brush. ***WSR continued on 03-04-2018*** ***CONT FROM 3-2-18 WSR***(ctd) SET 1" BK-DOME VLV(16/64"tro:1500. ser:A16G-00548R) IN STA#5 AT 3620' MD. SET 1" BK-S/O VLV(20/64" tro:1500. ser: J16A-0056T) IN STA#4 AT 5482' MD. PULLED WHIDDON C-SUB FROM 8758' SLM. BRUSHED DEPLOY SLV @ 8769' MD W/4-1/2" BRUSH, 3.80" GAUGE RING & 3-1/2" BRUSH.(no issues) MADE MULTIPLE DRIFT ATTEMPTS WITH 45 KB DRIFT& PTSA STINGER. UNABLE TO STING IN COMPLETELY. 3/3/2018 ***CONT ON 3-4-18 WSR*** ***WSR continued from 03-03-2018*** Assist SL (LTP PT) Pumped 3.87 bbls crude down tbg to reach test pressure. 15 min T lost 144 psi. 30 min T lost 33 psi. Total loss of 177 psi in 30 min. Bleed TP back to 55 psi/Bled back 3.3 bbls. Slickline still on well at LRS departure. 3/4/2018 FWHP=55/0/196 ***CONT FROM 3-3-18 WSR***(ctd) SET PTSA W/QCLL IN DEPLOY SLV @ 8769' MD. SET BKR 45KB LTP W/QCLL IN PTSA, TOP OF LTP @ 8759' MD. ***(OAL OF 45KB-QCLL-PTSA IS 12.81', X-NIPPLE © 8771' MD)*** EQUALIZE & PULL 2-7/8"XX PLUG FROM 2.31" X-NIPPLE IN PTSA @ 8771' MD. DRIFTED TO 9475' SLM W/20' x 2" DUMMY GUNS.(no issues) 3/4/2018 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** • • Daily Report of Well Operations 03-15C ***ELINE PERFORATING*** WELL SHUT IN ON ARRIVAL, INITIAL T/I/O = 30/0/150, SSV CLOSED RIH W/2"X 11' POWER JETS, 6 SPF AND 60 DEGREE PHASING. PERFORATED FROM 9373'-9384'. RIH W/2"X 20' POWER JETS, 6 SPF AND 60 DEGREE PHASING PERFORATED FROM 9340'-9360'. CORRELATED TO BAKER GAMMA RAY LOG DATED 9-FEB-2018 WELL LEFT SHUT-IN ON DEPARTURE, FINAL T/I/O = 120/0/150 3/5/2018 ***JOB COMPLETE*** • • ED W `° a IX 8 W�� m 0 m I Q 0 Q J 0 Q I a. 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TS 3 ' 711685 40 - - 711685 A 711620 - 711620 711555 •100 ppp - Op F711555 711490 Q 711490 J 711425 < :000 M RI Q- 711425 co co Lc) ,0 711360 N p .ppp r-- :2 'n Mo- 711360 'm CO co Lo 711295 o c7 � .‘11 0 �� co 711295 o` �,, o 711230_inn _� � , mi .. ...... ...... - p___._...____ iF 711230 N ' S 2 N N 2 N E 0 1 I i i bpi ii iigi (noon S9)�uigtaoN m Y • r 0 by Post Drilling North America - ALASKA - BP Prudhoe Bay PB DS 03 03-15 03-15C 03-15C Anticollision Summary Report 13 February, 2018 BAER UGHES a GE company AOGCC 0 GCC `0.0,Z • BP • BA by Anticollision Report IFrUER GHES y� a GE company Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 03-15 Project: Prudhoe Bay TVD Reference: KB @ 62.44usft(03-15B actaul) Reference Site: PB DS 03 MD Reference: KB @ 62.44usft(03-15B actaul) Site Error: 0.00usft North Reference: True Reference Well: 03-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 03-15C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 03-15C Offset TVD Reference: Offset Datum Reference 03-15C Filter type: NO GLOBAL FILTER:Using user defined selection&filtering criteria Interpolation Method: MD Interval 25.O0usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 500.00usft Error Surface: Elliptical Conic Survey Program Date 2/13/2018 From To (usft) (usft) Survey(Wellbore) Tool Name Description 98.44 4,298.44 03-15 Srvy 1 BOSS-GYRO(03-15) BOSS-GYRO Sperry-Sun BOSS gyro multishot 4,325.04 4,605.53 03-15B Srvy 1 INC+TREND(03-15B) INC+TREND Inclinometer+known azi trend 4,636.76 8,973.52 03-15B Srvy 2 MWD+IFR+MS(03-15B) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 9,072.87 9,072.87 03-158 Srvy 3 MWD+IFR+MS(03-15B) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 9,077.00 9,470.62 CoilTrak MWD 3-1/4"(03-15C) MWD MWD-Standard Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB DS 03 03-15-03-15-03-15 4,646.50 4,650.00 41.05 169.48 -91.67 FAIL-Major Risk 03-15-03-15A-03-15A 4,646.50 4,650.00 41.05 169.48 -91.67 FAIL-Major Risk 03-15-03-15AL1-03-15AL1 4,646.50 4,650.00 41.05 169.48 -91.67 FAIL-Major Risk 03-15-03-158-03-15B 9,373.08 9,400.00 107.00 5.36 102.09 Pass-Major Risk 03-16-03-16-03-16 2,823.11 2,825.00 104.36 37.49 66.87 Pass-Major Risk 03-16-03-16A-03-16A 2,823.11 2,825.00 104.36 37.49 66.87 Pass-Major Risk 03-17-03-17-03-17 3,265.37 3,275.00 223.73 47.62 176.13 Pass-Major Risk 03-18-03-18-03-18 2,771.77 2,775.00 365.89 36.54 329.36 Pass-Major Risk 03-18-03-18A-03-18A 2,751.99 2,750.00 365.58 36.23 329.36 Pass-Major Risk 03-25-03-25-03-25 2,291.66 2,300.00 100.07 39.14 60.96 Pass-Major Risk 03-25-03-25A-03-25A 2,274.41 2,275.00 99.64 38.74 60.92 Pass-Major Risk 03-26-03-26-03-26 2,026.06 2,025.00 241.43 28.59 212.88 Pass-Major Risk 03-27-03-27-03-27 3,564.06 3,625.00 77.83 52.80 25.30 Pass-Major Risk 03-27-03-27A-03-27A WP05 3,564.06 3,625.00 77.83 52.80 25.30 Pass-Major Risk 03 28 03 28 03 28 4,137.99 4,250.00 89.63 99.42 -8.36 FAIL-Major Risk 03-29-03-29-03-29 5,568.87 5,700.00 336.82 300.59 70.80 Pass-Major Risk 03-29-03-29A-03-29A WP06 5,568.87 5,700.00 336.82 300.61 70.77 Pass-Major Risk 03-32-03-32B-03-32B 7,606.36 8,675.00 363.07 320.40 74.44 Pass-Major Risk 03-37-03-37-03-37 904.55 900.00 297.60 16.15 281.45 Pass-Major Risk 2/13/2018 11.36:09AM Ao .,ge 2 of 3 COMPASS 5000.1 Build 81D • BP 111, 0 bp Anticollision Report BAII<UGHES a GE company Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 03-15 Project: Prudhoe Bay ND Reference: KB @ 62.44usft(03-15B actaul) Reference Site: PB DS 03 MD Reference: KB©62.44usft(03-15B actaul) Site Error: 0.00usft North Reference: True Reference Well: 03-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 03-15C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 03-15C Offset TVD Reference: Offset Datum Reference Depths are relative to KB©62.44usft(03-15B actaul) Coordinates are relative to:03-15 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones,NAD27*OGP-Usa AK Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:1.62° 2/13/2018 11:36:09AM A ge 3 of 3 COMPASS 5000.1 Build 81D N • 1 0 0 t I I L N O1 N C j _ N a. 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Z E U E Q E ` ea m a y A' g z 0 0 Z > a 0 ti o = .2 a t Lit- O s .c cn cn < U :: E ra u 2.~ M S = NaQi7 Fr) m N co J 67 O --E oO ri O a E E = m o w � x K .0 OJ c w 7 (0 a - 0) 3 01 O LI a o co - o w w � O x Oc O o Oa o) �' N l0 ~ w Q O Q n 1 a z y m CJ W m Z a m c cp N o 0 E a- 8 v z = E aa _ o z O Q > a 7 - O J U > Z z Z U a W c Y1 >. O W tl .-. ^ O1 41 a _ c 41 10 CO 1- Z c a tel E 2 m= m x m w O Z ¢ m co 22W C o ti O C/) N W a U -J v m 'g 0 O 7 v Z , � d Uo a a m o mZ a . ti n T0 c a >' t7 a, 5mLL N m > > v > c ` ocf QQ t ~ e d c ad > d o m a d m d— E ^ mc 7 m o a dm aa o L > o a U a w 0 m pc m E E -I -a 0 co IT- .H 0 0 D m 0 m I- _ • 21 7137 BA ER 29 058 UGHES ' PRINT DISTRIBUTION LIST a GE company Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. ��` BP Exploration(Alaska)Inc. DATA LOGGED RIME! M Petrotechnical Data Center,LR2-1 /1G/201% iK BENDER WELL NAME 03-15C 900 E.Benson Blvd. FEBU 1 6 2018 Anchorage,Alaska 99508 or AKGDMINTERNAL@bp.com FIELD Prudhoe Bay Unit tl to acknowledge receipt of this data. COUNTY PRUDHOE BAY AOGCC LOG TYPE CR- RES BHI DISTRICT Alaska LOG DATE February 9,2018 AUTHORIZED BY Patrick Rider EMAIL Patrick.Riderbhqe.com TODAYS DATE February 15,2018 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF I'RIN I S #OF COPIESr #OF COPIES #OF COPIES 1 BP North Slope. 0 1 0 1 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aides Attn:Benda Glassmaker&Peggy O'Neil 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 1 1 0 Attn:Ricky Elgarico ATO 708 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 1 0 0 Attn:Lynda M.Yaskell andlor Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 1 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** I 0 0 1 1 0 Attn:Resource Evaluation 550 West 7th Avenue,Suite 1100 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 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N coCa sxs C CO a N Eryy >- ;,.•:`i)»)1100 ' m Q &fie. C -O O T UT C f7 O CO CO E O H fa__ 'U N N WSW RIN co o Cl- O °) a a U H Y n. 0) L 0_ C) O O V Cf U) C� • M• M • 7 7 N CD Ec5.";? a,");) ;milawag w +LI- v m + c O U • N (O M � 0 • M Cn n V V N CO (11 E O O Z .) + 3. COri N Cr) I� Cr) O O) Cn M CO 7.3 = Lrn O r-M 2 O. N CO CO Q 0 0 = W O CO O N 0 T iN m E w MO r O V O O aO O CO O Q o m U U ` t cri Sic, L U) O Lo r O N U N d .-O O O Z d d 0 0 0 C N O` OGC-' 0 0 0 O 2M co Q O N T C C . .0 a co C it Wo) a v a m m o C• O ad+ ' N y d M U aino ---.'s > • 0 / • Pro 2,17 --1 7 7_ Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday, December 07, 2017 9:53 AM 'Lastufka,Joseph h N'p Cc: zachary.browning@bp.com Subject: RE: Updated BOPE Schematic for the following wells Approval is granted for the change in BOP stack for CDR2 for the listed wells outlined below. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepi:aalaska.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.Loepo@alaska.gov From: Lastufka,Joseph N [mailto:Joseph.Lastufka@bp.com] Sent:Wednesday, November 29, 2017 9:57 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: Updated BOPE Schematic for the following wells Victoria, As Zach Browning indicated on Monday,we are changing the BOP stack for Nabors CDR2.This change will affect the approved and out for approval Permit to Drills. Please see list below for well name and PTD#(if available): 03-15C(PTD#217-137) 03-27A(PTD#216-169) 07-03B(currently out for approval) 16-21A(currently out for approval) 17-11A(PTD#217-001) P-04L2 (PTD#217-120) Q-06B(currently out for approval) Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 1 • . Well Bighole CDR2-AC 4 Ram BOP Schematic Date 21-Nov-17 Quick Test Sub to Otis Top of7"Otis I 0.0ft 4-m---CDR2 Rig's DAP Pan Distances from top of riser Excluding quick-test sub 4-- 7-1/16"5k Flange X 7"Otis Box Top of Annular I 6.0 ft ' Hydril71/16' � Top of Annular Element 6.7 ft Annular Bottom Annular 8.0 ft ► „� „„ Blind/Shear CL Blind/Shears 9.3 ft 2-318"Pipe/Slips CL 2-318"Pipe/Slips 10.1 ft ► 61 I 82 83 B4 Choke Line Kill LineMO AO Frr ik"4 art 5 ueiMta�' � +1irrS ts: MM 1 cross 11/ 111 2 3,8"r 3-112"VBRs CL 2-3/8"x 3-1/2"VBRs 12.6 ft ► 2-318"PipelSlips CL 2-3/8"Pipe/Slips 13.4 ft ► „! ti CL of Top Swab 16.0 ft �► 4"'"'""^'Swab Test Pump Hose T1 It T2 CL of Flow Cross 17.4 ft • • •�• + Master CL of Master I 18.8 ft I LDS 1:4 yrIA II 11 II 1 II ►:, II II I ` OA II LDS Ground Level I i • # 4,1"��������6, THE STATE Alaska Oil and GJas ti's +i AsKA of TT Conservation Commission . 2 333 West Seventh Ave ue k � Anchorage, Alaska 99501-3 72 pp,. � GOVERNOR BILL WALKER g +�' Main: 907.279.1 33 ALAS,' Fax: 907.276.742 www.aogcc.alaska.gov Uchenna Egbejimba Engineering Team Leader BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-15C BP Exploration (Alaska), Inc. Permit to Drill Number: 217-137 Surface Location: 1131' FSL, 54' FEL, SEC. 10, T1ON, R15E,UM Bottomhole Location: 108' FNL, 958' FEL, SEC. 15, T1ON, R15E, UM Dear Mr. Egbejimba: Enclosed is the approved application for permit to 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, LOOC \"...,__ Hollis S. French A-L Chair DATED this(4 day of October, 2017. 1 N p WPM WO,Wows N w 11Wit STATE OF ALASKA O C T 0 2 2017 .ASKA OIL AND GAS CONSERVATION COMMIS• PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory-Gas 0 Service-WAG 0 Service-Disp❑ lc.Specify if well is proposed for: Drill 0 Lateral 0 Stratigraphic Test 0 Development-Oil IZI• Service-Winj 0 Single Zone R• Coalbed Gas 0 Gas Hydrates d Redrill Q •Reentry ❑ Exploratory-Oil 0 Development-Gas 0 Service-Supply 0 Multiple Zone 0 Geothermal 0 Shale Gas d 2. Operator Name: 5. Bond Blanket Il 'Single Well 0 11. Well Name and Number: BP Exploration(Alaska),Inc Bond No. 29E105380 • PBU 03-15C - 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O.Box 196612 Anchorage,AK 99519-6612 MD: 9630' TVD: 8982'ss' PRUDHOE BAY,PRUDHOE • 4a. Location of Well(Governmental Section): OIL ) 7. Property Designation(Lease Number): ADL 028328&028331 • Surface: 1131'FSL,54'FEL,Sec.10,T1ON,R15E,UM • 8. DNR Approval Number: 13. Approximate spud date: 233'FSL,1031'FEL,Sec.10,T1ON,R15E,UM 74-017 January 15,2018 Top of Productive Horizon: Total Depth: 108'FNL,958'FEL,Sec.15,T1ON,R15E,UM 9. Acres in Property: 2560 14.Distance to Nearest Property: 21140 ' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: 62.44'feet 15. Distance to Nearest Well Oppn Surface:x- 713213' y- 5937170 • Zone - ASP 4 GL Elevation above MSL: 28.30 feet to Same Pool: 670 16. Deviated wells: Kickoff Depth: 9080 ' feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 55 degrees Downhole: 3378 • Surface: 2498 ' 18. Casing Program: Specifications Top-Setting Depth-Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade • Coupling Length MD TVD MD ND (including stage data) 4-1/4" 3-1/2"x3-1/4" 9.2#16.5# 13Cr80 STUTCII 865' 8765' 8392'ss 9630' 8982'ss 61 ax Class'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) ' Total Depth MD(ft): Total Depth ND(ft): I Plugs(measured): I Effect.Depth MD(ft): I Effect.Depth ND(ft): I Junk(measured): 13749 8715 9240 9240 8795 None Casing Length Size Cement Volume MD TVD Conductor/Structural 80 20" 417 sx Arctic Set 35-115 35-115 Surface 2688 13-3/8" 2350 sx Fondu 35-2723 35-2723 Intermediate 2336 9-5/8" 500 sx Class'G',375 sx PF'C' 1971-4307 1971 -4262 Intermediate 9004 T' 227 sx Class'G' 32-9036 32-8662 Liner 4943 4-1/2" Uncemented Sliding Sleeves w/Swell Packers 8809-13752 8489-8715 Perforation Depth MD(ft): 9194-13599 I Perforation Depth ND(ft): 8770-8717 Hydraulic Fracture planned? Yes 0 No 0 ; 20.Attachments Property Plat 0 BOP Sketch VI Drilling Program Il Time v.Depth Plot 0 Shallow Hazard Analysis 6 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program a 20 AAC 25.050 requirements O I 21.Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Name Browning.Zachary H from without prior written approval. Authorized Name Egbejimba,Uchenna J Contact Email Zachary.Browningt bp.com Authorized Title Engineering Team Leader-CTD&RWO / ./jC3'Contact Phone +1 907 564 5220 Authorized Signature 4` . /_ Date ) O/ I?" / Commission Use Only / Permit to Drill / Permit Approval See cover letter for other Number: �" ( API: 50- 029-20414-03-00 Date: requirements: �x'1'1 � �` Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: J U� p.51 4 Samples req'd: Yes —❑ No L'1'tMud log req'd: Yes �❑ No L°r 36 p rr5�t0 t1-nr /la v pti c v�r" tri-' H2S measures Yes LN No 0 . Directional svy req'd: Yes hd/ No 0firs r to z5-067 p -i-5 . Spacing exception req'd: Yes 0 No © Inclination-only svy req'd: Yes 0 No (8( Post initial injection MIT req'd: Yes 0 No APPROVED BY 1 Approved by: COMMISSIONER THE COMMISSION Date: I 0 11. I(4 3 -m 1 2 evised 5/2017 0 RTIli i al 24 months from the date of approval(20 AAC 25.005(g)) Submit Form and Attachments in Duplicate '4e141107 N It"'C('li7 • • To: Alaska Oil & Gas Conservation Commission From: Zach Browning ID CTD Engineer Date: September 28, 2017 Re: 03-15C Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack lateral from well 03-15B with the Nabors CDR2 Coiled Tubing Drilling rig on or around January 15th, 2018. Proposed plan for 03-15C: The 03-15C will be a short coil slant well near the parent that will be drilled through the logged oil and will TD in the Victor Package (Z4A/Z3/Z2C). It will TD in the victor package to provide an offtake point in in the area for the current MIST injectors 03-36Ai and 03-07Ai, and access the Victor oil pad that has been mapped and sits under the thick, continuous 42N shale that is in the area. The sidetrack will be drilled with the Nabors CDR2 rig on or around January 15th 2018. A 4-1/2" whipstock will be set pre-rig inside the production liner. The rig will move in, kill the well (if needed) and mill a 3.80" window, —10' long. The well kicks-off in the Shublik and will be drilled down into Zone 2C. The proposed sidetrack is a —550' '4 horizontal Ivishak producer to be completed with a 3-1/4" 13Cr solid liner, cemented in place and selectively perforated (post-rig). The whipstock, liner cement job or liner top packer will isolate all parent production.* Rig Work(scheduled to begin January 15th, 2018) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,498 psi). 2. Mill 3.80"Window. 3. Drill slant production lateral: 4.25" OH, —550' (14 deg DLS planned). ' 4. Run 3-1/4" 13Cr liner leaving TOL at—8765' MD. 5. Pump primary cement job: 12.6 bbls, 15.3 ppg Class G, TOC at TOL (-8765' MD)*. 6. Freeze protect well to a min 2,200' TVDss. 7. Close in tree, RDMO. *Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. V: Tree work as necessary. 2. D: Liner lap test. 3. S: Drift w dummy perfs guns. Set LGLVs. 4. S: LTP set post rig if needed, and test.* 5. E: Perforate well -60'. Mud Program: • • • Drilling/Completion: a min EMW of 8.4 ppg KCL with Geovis for drilling (466 psi over-balance). Disposal: • All Class I & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3 at DS 6. • Fluids >1% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. • Fluids with solids that will not pass through 1/4" screen must go to GNI. • Fluids with PH >11 must go to GNI. Hole Size: • 4.25" for production hole section from the KOP at 9080' MD to TD at 9630' MD. - Liner Program: • 3-1/4", 6.5 lb/ft, TCII, 13Cr solid liner: 8795' MD—9630' MD • 3-1/2", 9.2 lb/ft, STL, 13Cr solid liner(TOL): 8765' MD—8795' MD • A planned 12.6 bbls of 15.3 ppg cement will be used for liner cementing (TOC = TOL at—8765' MD). • The primary barrier for this operation: a minimum EMW of 8.4 ppg (466 psi over-balance). • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional: • See attached directional plan. Maximum planned hole angle is 55°, inclination at kick off point is 44°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property— 21,140' • • Distance to nearest well within pool— 670' (03-20A) Logging: • MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. - Perforating: • Perforating planned Post-rig: -V60' of perforations, 2-7/8", 60 deg random phasing, 6 spf, perf guns. Anti-Collision Failures: • None. All offset wells pass BP anti-collision scan criteria. - • No wellbores have been minor risked. Hazards: • DS 3 is considered an H2S pad. Latest H2S reading on the 03-15 was 80 ppm on 2/18/2017. • No fault crossings planned. Lost circulation risk in 03-15C is considered to be LOW, Reservoir Pressure: • The reservoir pressure on 03-15C is expected to be 3,378 psi at 8,800' TVDSS (7.38 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,498 psi. • A min EMW of 8.4 ppg for this well will provide 466 psi over-balance to the reservoir. Zach Browning CC: Well File CTD Engineer Joseph Lastufka 564-5220 VELLLtfAD 41t16FM • 03-15B - S NOTES: WELL ANGLE>70°@ 9336'. ACTUATOR BAKER C CHROME TBG&LIR'""MAX DOGLEG:13.1"@ OKB.ELEV- 64' 9224'"' BF.ELEV= 30.62' . KOP= 3300' 20"CONDUCTOR, - 116' Max Angle= 109"@9859' 94# E{40 ; g ' , : 2011' H4-1/2"FES XImo,D=3.813" Datum 1/3 , 8800 SS r= 9458 D=19.1024" 4- Datum TVD ,2332' H 9-5/8"UPPER FOC 9-5/8"CSG STUB(03/28/15) -- 1973' 2461' H9-5/8"LOWER FOC GAS LFT MANDRELS 13-3/8"CSG,72#,L-80 BTC,D=12.347" --I 2720' ST MD ND DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.813" @ 2011' El 5 3620 3610 14 KBG DOME BK 16 04/25/15 4 5482 5270 20 KBG SO BK 20 07/27/17 4-1/2" HES X NIPPLE 3 6763 6535 11 KBG DMY BK 0 04/23/15 9-5/8"BKR WHIPSTOCK(03/2915) A 4307' 2 7795 7552 8 KBG DMY BK 0 04!23!15 1 8619 8334 31 KBG DMY BK 0 04/23115 9-5/8"CSG,47#,S-95,D=8.681" - 4307" f / `/\ 9-518"MLLOUT WIDOW(03-156)4307'-4324' TOP OF CE NT(04106/15) H -7736' I-- 1 % t. . ' 0 AF:; I 8656' -4-1/2"FES X MP,D=3.813" f" #' 8687' H7-X 4-112"FESS TNT PKI ,D=3.856" v ' v , ' 8724' --I 4-1/7 FEBX Nom',D=3.813" :r F1 8795' H4-1I2'IES X fes,D=3.813" TOP OF 4-1/2"LNR H 8806' i 8806' -7"X 5"BKR l D E ZXP LTP w ITEBACK SLV, D=5.25" 4-112"TBG, 12.6#,13CR-85 VAM TOP, - 8812' '--• 881 {4-i/2" LEG,D=3.958" 0152 bpf,D=3.958" - P. 2' - V4 8830' --17"X 5"BKR FLEX LOCK HGR,13=4.240" 7"CSG PUNCHES(CLOSED):8835'-8840'& ® � ''' 8840' S'X 4-112"XO,ID=3.870" 8936'-8941'(04109115) -t --- -- XD SLIDING SLV,ID=3.813" r CSG,26#,L-80 VAM TOP HC, D=6.276" ---19036' 1 I NO DEPTH OIC DATE MN D 7 9194 0 01/03/16 3.813" FES SWELL PACKERS 9240'-4-1/T BKR CIBP 6 10215 0 05/27/15 3.813" NO SIZE TOP DEPTH M,i D ® ;_ (07/27/17) 5 10594 0 05/27115 1813" 6 4-1/2" 9277 3.958" 4 10933 0 05/27/15 3.813" 5 4-1/2" 9908 3.958" 1 I I 3 12004 C 11/05/15 3.813" 4 41/2" 10067 3.958" I I 2 12598 C 11105/15 3.813" 3 4112" 10767 3.958" 1 13599 C 11/05/15 3.813" 2 41/2" 11441 3.958" I I O=OPEN C=CLOSED 1 4-112" 12323 1958" PERFORATIONI I i PERFORATION SUMMARY ® 1€7,41 REF LOG:PDCL ON 05/19/15 I I I ANGLE AT TOP FRE57'@ 9220' I I Note:Refer to Rod uction DB for historical pert data SCE SPF MHR1/AL Opn/Sqz SHOT SOZ RIM - 13719' 9 3-3/8" 6 9220-9230 0 08/24/16 4-1t2"LIR, 12.6#,13-CR HYD 521, - 13749' a'!' 0152 bpi,D=3.958" + 13697' -41/T BKR SHIFTING TOOL VERFICATION SUB, 0=3.880" DATE REV BY COMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/23/80 ktOWAN 3 ORIGINAL COMPLETION 01/12/16 SW/JMDCLOSED SLD SLV(01/03/16) WELL 03-158 03/06/93 D-16 SIDETRACK(03-15A) 08/25/16 BTWJMD ADFERFS(08/24/16) PERMIT No '2150020 03/27/97 N2ES CTD SIDETRACK(03-15A L1) 08/29/16 BTNYJMD ADDED PERF REF LOG AR Nb: 50-029-20414-02 04/23/15 D-14 SIDETRACK(03-158) -08/02/17 GJB/JM)GLV C/O(07/27/17) SEC 10,T10N,R15E,1131'FSL&54'FEL 06/19/15 Mtv F/JMD OPEN SLD SLVS(05/27/15) 08/02/17 BSE/JM)SET CEP(07/27/17) 12/07/15 ALMIJMMJ CLOSED SLD SLVS(11/05/15) BP Exploration(Alaska) TREE= W_aL_FEAD _ _ Bic PROPOS SA OTES: WELL ANGLE>70"@ ACTUATOR -11— _ N O _ ""CHROME TBG&LNR'"MAX DOGLEG: @ '. : OKB.ELEV - -_64' � • BF.ELEV= 30.67 / =w '4 FOP= 3300' 20"CONDUCTOR, - 116' C6 Max Angle= "@ 94#,H 40, .. a ' + 2011' -{4-1/2"HES X NP,D=3.813" Datum K43= D=19.1024" ' Datum TVD: 8800 SS y 2332' H9-5/8"UPPER FOC + 2461' -19-5/8"LOWER FOC 9-5/8"CSG STUB(03/28/15) H 1973' 2 GAS LFT MANDRELS 13-3/8"CSG,72#,L-80 BTC,D=12.347" N 2720' ST MD TVt° DEV TYPE VLV LATCH PORT DATE 5 3620 3610 14 KBG DOME BK 16 04/25/15 Minimum ID = 4 5482 5270 20 KBG SO BK 20 04/25/15 N / 3 6763 6535 11 KBG DMY BK 0 04/23/15 2 7795 7552 8 KBG DMY BK 0 04/23/15 9 518"BKR WHIPSTOCK(03/2915) H 4307 1 8619 8334 31 KBG DMY BK 0 04/23/15 9-5/8"CSG,47#,S-95,D=8.681" - 4307' 9-5/8"MLLOUT WINDOW(03-15B)4307'-4324' TOP OF CEMENT(04/06/15) H -7736' _ 8656' -14-1/2"HES X NP,D=3.813" 8687" -17"X 4-1/2"HES TNT PKR,D=3.856" # 8724' -14-1/2"HES X NP,D=3.813" TOP OF ' '':' -i # 8765' -13.70"DEPLOY SLV,D=3.00" r 4t 8785' H 3-1/2"1 IM NP,D=2.813" 3-1/2"LNR, #,L-80 STL, -1 8795' * 8795" -13-1/2"X 3-1/4"XO,D=2.786" .0087 bpf,D=2.992" ; 8795' -I4-1/2"HES X NP,D=3.813" TOP OF 4-1/2"LNR 8806' ' r. 8806' 7"X 5"BKR HRD-E ZXP LTP w/TEBACK SLV, r } i! D=5.25" 4-1/2"TBG,12.6#,13CR-85 VAM TOP, 8812' ; 8812' �4 1/2"WLEG,D=3.958" .0152 bpf,D=3.958" / ' '� 8830' -17"X 5"BKR FLEX LOCK HGR,D=4240'1] + 7"CSG PUNCHES(CLOSED):8835'-8840'& - II QBEHIND 8936'-8941'(04/09/15) \ # 8840" 5"X 4-1l2"XO,D=3.870" CT LNR 7"CSG,26#,L-80 VAM TOP HC, D=6.276" -I 9036' L I4-1/2"MONOBORE WHESTOCK(XX/XX/XX) -{ 9080" MLLOUT WINDOW(03-15A)9080'- 4-1/2"LNR, 12.6#,13-CR HYD 521, - -9080' t .0152 bpf,ID=3.958" PRORATION SUMMARY REF LOG: ON / / ANGLE AT TOP PERF: "@_ Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 13-CR TC11,.0079 bpf,ID=2.85" H I—' " DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/23/80 tOWAN 3 ORIGINAL COMPLETION WELL: 03-15 03/06/93 D-16 SIDETRACK(03-15A) FERMI-No: 03/27/97 N2ES CTD SIDETRACK(03-15A L1) AR No: 50-029-20414-0 04/23/15 D-14 SIDETRACK(03-15B) SEC 10,T10N,R15E, 1131'FSL&54'Fa _ CTD ST(03-15C) 13/17 JMD MILT PROPOSED BP Exploration(Alaska) I • • Ca M O. m Q CO t Q 0 J 0_ Q G) W I co cp V c L .0 c z E a. i. 0 N Q U m p -0 t M� V � 0_ .0 'm ' ca ET) a a o o a m N • • o z .;-0- T., z z �' O V o o OO 3 CO �y r:-- . a0 n o ii N r N N c. 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R23"F'. 84111111111, 1 O _ c 0 n N v O '. m d �� -9> T 2 U N N • • by North America - ALASKA - BP Prudhoe Bay PB DS 03 03-15 USA00001388 03-15C 03-15C WP03 Travelling Cylinder Report 26 September, 2017 BAER UGHES a GE company • • ,t0loot BP BAER bp Travelling Cylinder Report UGHES ''''0444. a GE company Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 03-15 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 03 MD Reference: KB @ 62.44usft(03-15B actaul) Site Error: 0.00 usft North Reference: True Reference Well: 03-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 03-15C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 03-15C WP03 Offset TVD Reference: Offset Datum Reference 03-15C WP03 Filter type: NO GLOBAL FILTER:Using user defined selection&filtering criteria WARNING:There is hidden tight data in this project Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,973.52 to 9,630.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,159.53 usft Error Surface: Elliptical Conic Survey Tool Program Date 9/26/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description 98.44 4,298.44 03-15 Srvy 1 BOSS-GYRO(03-15) BOSS-GYRO Sperry-Sun BOSS gyro multishot 4,325.04 4,605.53 03-158 Srvy 1 INC+TREND(03-15B) INC+TREND Inclinometer+known azi trend 4,636.76 8,973.52 03-15B Srvy 2 MWD+IFR+MS(03-15B) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 9,072.87 8,973.52 03-15B Srvy 3 MWD+IFR+MS(03-15B) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,973.52 9,630.00 03-15C WP03(03-15C) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 2,718.44 2,655.89 13 3/8" 13.375 17.500 4,307.00 4,199.17 9 5/8" 9.625 12.250 9,036.03 8,599.79 INTERMEDIATE CASING 1 7.000 8.500 9,080.00 8,631.70 4-1/2"Planned TOWS 4.500 4.500 9,630.00 8,982.45 3 1/4" 3.250 4.250 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB DS 03 03-07-03-07-03-07 Out of range 03-15-03-15-03-15 Out of range 03-15-03-15A-03-15A Out of range 03-15-03-15AL1-03-15AL1 Out of range 03-15-03-15B-03-158 9,288.87 9,300.00 55.07 0.14 55.07 Pass-NOERRORS 03-16-03-16-03-16 Out of range 03-16-03-16A-03-16A Out of range 03-20-03-20-03-20 9,598.52 9,000.00 961.99 197.84 869.66 Pass-Major Risk 03-20-03-20A-03-20A 9,608.49 9,275.00 715.66 161.36 620.63 Pass-Major Risk 03-21-03-21-03-21 Out of range 03-21-03-21 A-03-21 A Out of range 03-25-03-25A-03-25A Out of range 03-32-03-326-03-32B Out of range 03-37-03-37-03-37 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/26/2017 10:24:36AM Page 2 COMPASS 5000.1 Build 81D • • Northing(65 usff/in) .n il a i n n m n w u .o m � Ai n .n Al n 'O FA AA w m � Ai w w w w w w w w m w w w m .n m m w m r� w w w Ai m Mf �, w h w w w w w w w w w w u� w w w h w w w w W['� 713635 _ 713635 713570 ---713570 713505_.... --_- --713505 71344.....- -. __.. _ 713440 713375 m --- -- - p 713375 N G 713310 O a .-._..: 713310 N O 713245 o --- --- - --- - A 713245 I o; rA e N E 71318.- 0009 0 01 713180 4 L.nmo`<' oN= g 'IA 713115 713115 O 36Sm �i`syY3 Sg $1182 713050 - - -- 713050 �� ppp 000 n p �_ 60 c2,22 S yi 712885 000L 'fig 712985 3 Zo"g 0? 0 d �>A� 712920 00 �� a 712920 g 4 6� A J 712855 ------ ---- -- ` -_--_ '-___ --.. __.:-._ ._..-712855 CIS 712790 -_ - _-_-. _—- .__._. .___ _ i-'712790 N 712725 _-.. —__-_. ---. 712725 M N a}.J 77 0 U ,ra. 712660 `~ -.. 712660 I u,QA W o a 712595 ��0 _ 3. - _ -_... §o a C) 712595 0 c LO NL. 3 H 712530 y/� a - 712530 0 GO m y ^ I a n 712465 o 3 712465 S CLO _ 712400 323£1,,-' o y o 712400 c 1E1a m “., m �¢ m W 712335 1p 0 712335 IL ai gYoaj , m 11 712270- ` - 712270 111 712205_ NO- - 000 _... 712205 000 712140- L/1 ... H J 712140 712075-- --- 712075 712010 712010--- ® --- a 711945_ _-- -__. ___ _.._.711945 g m44 S 711880- - -- 711880 8^ o 0 re.eF-1 711815- . 711815 LL d o __711750 t$ Ea 711750- -_.. 4 63}j 2 - .----. p .t 711685- .000 ---. 711685 b a 711620- 711820 C 9 s 711555- 711555 711490-. Q 711490 711425 oo `3 711425 Ili 0 711360. .. - ---- - -.,- 0 ---711360 --. -. - A CI 711295- .n N pOp 711295 o_ u.n 0 '8 m m 711230 _.... _... _..-. -.o-m- .vo c 0 711230 3 9 4 app _ �r n ti fY 0 711165 - -_. _._ O O.` rrA_.� .-_..- o ___711165 b bw 6 b b b ig a .` - J. 2(51y56 99)6u91IJON ! • Qbp North America - ALASKA - BP Prudhoe Bay PB DS 03 03-15 03-15C 03-15C WP03 Plus 500ft AOGCC Offset Well Report 28 September, 2017 BAER HUGHES a GE company • S ,•, BP BAER ` '' Anticollision Report UGHES r044* aGE company _ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 03-15 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 03 MD Reference: KB @ 62.44usft(03-15B actaul) 1 Site Error: 0.00usft North Reference: True Reference Well: 03-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 03-15C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 03-15C WP03 Plus 500ft Offset TVD Reference: Offset Datum Reference 03-15C WP03 Plus 500ft Filter type: NO GLOBAL FILTER:Using user defined selection&filtering criteria WARNING:There is hidden tight data in this project Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,973.52 to 10,130.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 200.O0usft Error Surface: Elliptical Conic Survey Tool Program Date 9/28/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description 98.44 4,298.44 03-15 Srvy 1 BOSS-GYRO(03-15) BOSS-GYRO Sperry-Sun BOSS gyro multishot 4,325.04 4,605.53 03-15B Srvy 1 INC+TREND(03-15B) INC+TREND Inclinometer+known azi trend 4,636.76 8,973.52 03-158 Srvy 2 MWD+IFR+MS(03-158) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 9,072.87 8,973.52 03-15B Srvy 3 MWD+IFR+MS(03-15B) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,973.52 10,130.00 03-15C WP03 Plus 500ft(03-15C) MWD MWD-Standard Summary Reference Offset Centre to Measured Measured Centre Site Name Depth Depth Distance Offset Well-Wellbore-Design (usft) (usft) (usft) PB DS 03 03-15-03-15B-03-158 9,288.87 9,300.00 55.07 03-15-03-15C-03-15C WP03 9,625.00 9,625.00 0.00 9/28/2017 10:11:21AM Page 2 of 5 COMPASS 5000.1 Build 81D • • BP0 BAER by Antico(Iision Report UGHES a GE company Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 03-15 Project: Prudhoe Bay ND Reference: Mean Sea Level Reference Site: PB DS 03 MD Reference: KB @ 62.44usft(03-15B actaul) Site Error: 0.00usft North Reference: True Reference Well: 03-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 03-15C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 03-15C WP03 Plus 500ft Offset ND Reference: Offset Datum Offset Design PB DS 03- 03-15-03-15B-03-15B Survey Program: 98-BOSS-GYRO,4325-INC+TREND,4637-MWD+IFR+MS-WOCA,9073-MWD+IFR+MS-WOCA,12356-MWD+IFR Reference Offset Measured Vertical Measured Vertical Offset Wellbore Centre Centre to Depth Depth Depth Depth +N/-S +E/-W Centre (usft) (usff) (usft) (usC) Iusff) (usft) (usft) 8,975.00 8,554.41 8,975.00 8,554.41 -787.09 -903.72 0.00 9,000.00 8,573.15 9,000.00 8,573.15 -800.58 -913.30 0.00 9,025.00 8,591.68 9,025.00 8,591.68 -81432 -922.94 0.00 9,050.00 8,610.00 9,050.00 8,610.00 -828.30 -932.62 0.00 9,075.00 8,628.11 9,075.00 8,628.12 -842.51 -942.36 0.01 9,099.99 8,646.14 9,100.00 8,645.81 -857.24 -952.11 0.49 9,124.82 8,664.61 9,125.00 8,662.99 -872.85 -961.72 2.59 9,149.30 8,683.47 9,150.00 8,679.71 -888.77 -970.96 6.40 9,173.85 8,702.47 9,175.00 8,695.69 -905.70 -980.07 11.55 9,198.18 8,720.79 9,200.00 8,710.72 -923.29 -989.54 17.62 9,222.06 8,738.20 9,225.00 8,724.68 -941.38 -99967 24.98 9,245.36 8,754.60 9,250.00 8,737.55 -959.95 -1,010.36 33.67 9,267.63 8,789.72 9,275.00 8,749.34 -979.04 -1,021.38 43.66 9,288.87 8,783.70 9,300.00 8,759.98 -998.62 -1,032.70 55.07 9,309.13 8,796.58 9,325.00 8,789.47 -1,018.61 -1,044.33 87.85 9,328.42 8,808.43 9,350.00 8,777.77 -1,039.08 -1,056.03 81.78 9,348.69 8,819.24 9,375.00 8,784.91 -1,059.88 -1,067.92 98.82 9,362.23 8,828.23 9,400.00 8,790.92 -1,080.76 -1,080.29 113.18 9,373.52 8,834.76 9,425.00 8,795.85 -1,101.76 -1,092.98 130.93 9,388.33 8,843.37 9,450.00 8,799.17 -1,122.81 -1,106.00 149.80 9,398.52 8,849.30 9,475.00 8,801.47 -1,143.84 -1,119.32 169.74 9,409.12 8,855.48 9,500.00 8,802.57 -1,164.88 -1,132.78 190.50 9/28/2017 10:11:21AM Page 3 of 5 COMPASS 5000.1 Build 81D • • °°" BPER • I bp AO IIA Anticollision Report BA4(UGHE.S asq*° a GE company Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 03-15 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 03 MD Reference: KB @ 62.44usft(03-15B actaul) Site Error: 0.00usft North Reference: True Reference Well: 03-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 03-15C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 03-15C WP03 Plus 500ft Offset ND Reference: Offset Datum Offset Design PB DS 03- 03-15-03-15C-03-15C WP03 Survey Program: 98-BOSS-GYRO,4325-INC+TREND.4637-MWD+IFR+MS-WOCA.9073-MWD+IFR+MS-WOCA,8974-MWD Reference Offset Measured Vertical Measured Vertical Offset Wellbore Centre Centre to Depth Depth Depth Depth *NIS 4.E/-W Centre �7 (usft) (usft) (usft) lust[) (usft) (usft) (usft) ' r '. '.'4; ,..,�e .rt0k77. ..v;,�'"'fs„n h}r:Ne l.a f>,<.`*"m+,-7"^IAZM:`^7. + 8,975 00 8,554.41 8,975.00 8,554.41 -787.09 -903.72 0.00 9,000.00 8,573.15 9,000.00 8,573.15 -800.58 -913.30 0.00 9,025.00 8,591.68 9,02500 8,591.68 -814.32 -922.94 0.00 9,050.00 8,610.00 9,050.00 8,610.00 -828.30 -932.62 0.00 9,075.00 8,628.11 9,075.00 8,628.12 -842.51 -942.36 0.01 9,100.00 8,648.15 9,100.00 8,646.15 -857.00 -951.85 0.00 9,125.00 8,664.75 9,12500 8,664.75 -871.43 -96024 0.00 9,150.00 8,684.02 9,150.00 8,684.02 -885.71 -967.28 0.00 9,175.00 8,703.35 9,175.00 8,703.35 -900.44 -973.13 0.00 9,200.00 8,722.14 9,200.00 8,722.14 -916.19 -978.01 0.00 9,225.00 8,740.30 9,225.00 8,740.30 -932.92 -981.87 0.00 9,250.00 8,757.79 9,250.00 8,757.79 -950.55 -984.72 0.00 9,275.00 8,774.62 9,275.00 8,774.62 -968.95 -986.44 0.00 9,300.00 8,790.83 9,300.00 8,790.83 -987.97 -986.90 0.00 9,325.00 8,806.36 9,325.00 8,806.36 -1,007.54 -986.11 0.00 9,350.00 8,821.16 9,350.00 8,821.16 -1,027.58 -984.08 0.00 9,375.00 8,835.62 9,375.00 8,835.62 -1,047.68 -980.67 0.00 9,400.00 8,850.16 9,400.00 8,850.16 -1,067.42 -975.78 0.00 9,425.00 8,864.72 9,425.00 8,864.72 -1,086.72 -969.44 0.00 9,450.00 8,879.25 9,450.00 8,879.25 -1,105.51 -961.65 0.00 9,475.00 8,893.70 9,475.00 8,893.70 -1,123.72 -952.45 0.00 9,500.00 8,908.00 9,500.00 8,908.00 -1,141.28 -941.88 0.00 9,525.00 8,922.28 9,525.00 8,922.28 -1,158.86 -931.30 0.00 9,550.00 8,936.63 9,550.00 8,936.63 -1,177.14 -922.08 0.00 9,575.00 8,951.00 9,575.00 8,951.00 -1,196.03 -914.25 0.00 9,600.00 8,965.35 9,600.00 8,965.35 -1,215.47 -907.85 0.00 9,625.00 8,979.61 9,625.00 8,979.61 -1,235.39 -902.90 0.00 9,630.00 8,982.45 9,630.00 8,982.45 -1,239.43 -902.08 0.00 9/28/2017 10:11:21AM Page 4 of 5 COMPASS 5000 1 Build 810 • BP *�a Anticollision Report HUGHES a GE company Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 03-15 Project: Prudhoe Bay ND Reference: Mean Sea Level Reference Site: PB DS 03 MD Reference: KB @ 62.44usft(03-15B actaul) Site Error: 0.O0usft North Reference: True Reference Well: 03-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 03-15C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 03-15C WP03 Plus 500ft Offset TVD Reference: Offset Datum Reference Depths are relative to KB©62.44usft(03-15B actaul) Coordinates are relative to:03-15 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones,NAD27*OGP-Usa AK Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:1.62° 9/28/2017 10::11:21AM Page 5 of 5 COMPASS 5000.1 Build 81D Well Blank •R2-AC BOP Schematic `ate _ Quick Test Sub to Otis -1.1 ft - - - - Topof7"OtisMr 1 4 CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub Top of Annular j 0.0 ft ylirD 7I \ 7.1/16"5k Flange X 7"Otis Box ,r;' Hydril 7 1/16 Top Annular Element 0.7 ft Annular Bottom Annular 2.0 ft io. Blind/Shear CL Blind/Shears 3.3 ft I ► liewl 2-3/8"Pipe/Slips CL 2-3/8"Combi's 4.1 ft 1111111 Bs ' B6 " "" c7 I$ :: De to mentLine a► ar 71/76rA ""p Y 4 1�5k Md F41 C..4WilkOW1Y 11 Cs .. IY YY IF Ill III Choke Line 3"Pipe/Slips CL 3"Pipe/Slips 6.6 ft 2-3/8"x 3-1/2"VBR CL 2-3/8"x3-1/2"VBRs 7.4 ft 81 ,r I. B2 B3 / B4 Choke Line .A� s ��er� 4 a�.A Kill Line -i rk l0S:4)- u ...6.rr rte6 IIll Blind/Shear III CL Blind/Shears 10.0 ft ► w1 2-3/8"Pipe/Slips ii ►1 vi CL 2-3/8"Combi's 10.7 ft 7:..-A. ` a �► • CL of Top Swab 13.3 ft ��� Swab 2 Test Pump Hose 4/swab 1 CL of Bottom Swab 14.8 ft ��� It T1 i T2 CL Flow Tee 16.2 ft •�• _ �• _ _ BOP2 CL of SSV 17.5 ft M 1 Master 2 } Fusable 11111 CL of Master Valve 19.0 ft BOP1 .4 Master 1 LDS 20.5 ft moi,_ _ 171 N fl 11 II 11 II II II II II Gound Level V4 n u n It n • • AOGCC Permit to Drill No. 217-137 4 October 2017 INPUT OUTPUT Geographic,NAD27 State Plane,NAD27 5004-Alaska 4,U.S.Feet PBU 03-15C 1/1 Latitude: 70 13 52.805 Northing/Y: 5937169.793 Longitude: 148 16 43.581 Easting/X: 713212.999 Convergence: 1 37 11.43963 Scale Factor: 0.999951642 Remark: Corpscon v6.0.1,U.S.Army Corps of Engineers • • TRANSMITTAL LETTER CHECKLIST � WELL NAME: , � PTD: -_/ ! i 3 I/ Development _Service Exploratory Stratigraphic Test Non-Conventional FIELD: i� taC v-�— POOL: t-c.e,el Ci, , 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 I well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. 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