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Home My WebLink About215-2017. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 09-18A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-201 50-029-20259-01-00 10265 Conductor Surface Production Liner Liner 8697 80 2685 9419 715 1590 9730 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-1/4" x 2-7/8" 8903 34 - 114 33 - 2718 31 - 9450 8639 - 8977 8675 - 10265 34 - 114 33 - 2718 31 - 8990 8413 - 8740 8448 - 8697 none 520 2670 5080 7020 11160 9730 1530 4930 8150 8160 10570 9416 - 10225 7" 29# x 4-1/2" 12.6# L-80 29 - 8401 8990 - 8701 Structural 4-1/2" Baker Model D , 8607 , 8382 No SSSV 8606 8382 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028327 29 - 8183 0 0 9809 5295 0 0 470 420 2813 3111 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 10:25 am, Oct 09, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.10.08 13:47:50 - 08'00' Bo York (1248) J.Lau 11/10/25 RBDMS JSB 100925 ACTIVITYDATE SUMMARY 9/14/2025 LRS #1 1.5" 0.134WT HT-110 Objective: Log/Drift, Set Plug Road unit from DS1 to Ds9. Spot Unit and Rig up. MU BOP's & Function. MU NS CTC & MHA.(Drifted) MU HES logging tools w/ 2.20 Carrier and 2.5" Nozzle *** Job In Progress*** 9/15/2025 LRS #1 1.5" 0.134WT HT-110 Objective: Log/Drift, Set Plug Cont MU HES logging tools with 2.20" carrier & 2.5" nozzle. Stab on. Full Body PT. Verify Checks. Open well with ~1800 psi WHP. Load well with 425 bbls Diesel/KCL. RIH for Drift/Log. Interval Logged from 9800' - 8500'. POOH. MU Northern Solutions 3-1/4" CIBP Setting BHA. RIH. Set 3-1/4" CIBP at 9730'. POOH. BD Northern Solution Tools. RDMO. Head off to maintenance. *** Job Complete*** Daily Report of Well Operations PBU 09-18A MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 09-18A PRUDHOE BAY UNIT 09-18A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 09-18A 50-029-20259-01-00 215-201-0 G SPT 8380 2152010 2095 2249 2257 2253 2268 228 267 269 272 4YRTST P Guy Cook 8/25/2024 Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 09-18A Inspection Date: Tubing OA Packer Depth 380 2784 2730 2713IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC240824185921 BBL Pumped:3.2 BBL Returned:3.2 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 99 999 99 9 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 13:40:56 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/18/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU 09-18A (PTD 215-201) Injection Profile 09/26/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/20/2021 By Abby Bell at 2:35 pm, Oct 20, 2021 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:215-201 6.50-029-20259-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10265 2148 2148 8607 none none 8382 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 94# H-40 34 - 114 34 - 114 1530 520 Surface 2685 13-3/8" 72# N-80 33 - 2718 33 - 2718 4930 2670 Production 9-5/8" 31 - 9450 31 - 8990 8150 5080 Liner 7" 8639 - 9354 8413 - 8986 8160 7020 Perforation Depth: Measured depth: 9416 - 10225 feet True vertical depth:8990 - 8701 feet Tubing (size, grade, measured and true vertical depth)7" 29# x 4-1/2" 12.6# L-80 29 - 8401 / 29 - 8491 8607 8382Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker Model D Liner 3-1/2" x 3-1/4" x 2- 8675 - 10265 8448 - 8697 10570 11160 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0000 00 0 0 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Torin Roschinger Torin.Roschinger@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(406) 570-9630 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8697 Sundry Number or N/A if C.O. Exempt: n/a no SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028327 PBU 09-18A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:27 am, Apr 20, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.19 17:48:24 -08'00' Bo York RBDMS HEW 4/20/2021DSR-4/20/21 SFD 4/20/2021MGR30JUL2021 ACTIVITYDATE SUMMARY 3/24/2021 **WELL S/I ON ARRIVAL*** (HES E-Line Perforating) PERFORATE 9660' - 9680' w/ 2" MAXFORCE, 6 SPF, 60 DEG PHASE GUNS (5 bpm pump down). LOG CORRELATED TO BAKER HUGHES MPR LOG DATED 12-FEB-2016. ***JOB CONTINUED ON 25-MAR-2021*** 3/24/2021 T/I/O= 0/90/90 Temp= S/I (TFS Unit 1 Assist E-Line with Perforating) Pumped 2 bbls of 60/40 followed by 340 bls of Safe Lube down TBG pre E-Line run. Further pumped 385 bbls of 1% KCL down TBG to Assist E-Line with making target depth. Freeze Protected TBG and Surface lines with 40 bbls of Crude. E-Line in control of well upon departure. Final whps = 400/100/90 3/25/2021 T/I/O=0/100/90 (Assist E-Line with Perforating) pump 3 bbls 60/40 followed by 344 bbls 1% kcl with safe lube, pump 6.2 bbls crude followed by 2 bbls 60/40 for freeze protect. final WHP's 900/100/90 3/25/2021 ***JOB CONTINUED FROM 24-MAR-2021*** (HES E-Line Perforating) PERFORATE 9626' - 9646' w/ 2" MAXFORCE, 6 SPF, 60 DEG PHASE GUN (5 bpm pump down). PERFORATE 9520' - 9550' w/ 2" MAXFORCE, 6 SPF, 60 DEG PHASE GUN (5 bpm pump down). ALL LOGS CORRELATED BAKER HUGHES MPR LOG DATED 12-FEB-2016. ***JOB CONTINUED ON 26-MAR-2021*** 3/26/2021 T/I/O= 10/100/75 (Assist E-line with Perforating) pump 10 bbls 60/40 followed by 10 bbls crude, pump 2 bbls 60/40 followed by 117 bbls 1% HCL with safe lube and then pump 2 bbls 60/40, pump 2 bbls 60/40 followed by 156 bbls 1% KCL with safe lube and then 5 bbls 60/40 final WHP's 800/100/75 3/26/2021 ***JOB CONTINUED FROM 25-MAR-2021*** (HES E-Line Perforating) PERFORATE 9435' - 9476' w/ 2" MAXFORCE, 6 SPF, 60 DEG PHASE GUN (5 bpm pump down). PERFORATE 9416' - 9436' w/ 2" MAXFORCE, 6 SPF, 60 DEG PHASE GUN (5 bpm pump down). ALL LOGS CORRELATED TO BAKER HUGHES MPR LOG DATED 12-FEB-2016. ***JOB COMPLETE ON 26-MAR-2021*** Daily Report of Well Operations PBU 09-18A MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggC tI �I -Z,'Zo DATE: Monday, August 17, 2020 P.I. Supervisor � SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 09-18A FROM: Bob Noble PRUDHOE BAY UNIT 09-18A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry JT3Iz— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-18A API Well Number 50-029-20259-01-00 Inspector Name: Bob Noble Permit Number: 215-201-0 Inspection Date: 8/10/2020 Insp Num: mitRCN200811131704 Rel Insp Num: Packer Well 09-18A Type Inj TVD PTD 2152010 Type Test'I SPT -Test psi BBL Pumped: 2.5 BBL Returned: Interval 4YRTST -jP/F Notes: Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 8380 Tubing 1591 1593 1586- 1577 2095 IA 489 2284 2249 2239 ' 2.5 OA 294 _ 464 459 " 457 - - -- P ✓; - Monday, August 17, 2020 Page I of 1 STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMI, ` REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate RI Alter Casing 0 Change Approved Program �❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well CI Re-enter Susp Well 0 Other: a C/Cl5. j/ rtf--- 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 215-201 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20259-01-00 7. Property Designation(Lease Number): ADL 0028327 8. Well Name and Number: PBU 09-18A 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 10265 feet Plugs measured feet SEP 06 2016 true vertical 8697 feet Junk measured feet Effective Depth: measured 10226 feet measuredPackerp� �/� 8607 feet P`�e�O'�.�s!G true vertical 8701 feet Packer true vertical 8381.53 feet !4R_ Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 34-114 34-114 1530 520 Surface 2686 13-3/8"72#N-80 33-2718 33-2718 4930 2670 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10140 10225 feet �rr� True vertical depth: 8719-8701 feet feet SCANNED `"! . 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: Intervals treated(measured): 10140'-10225'. Treatment descriptions including volumes used and final pressure: 424 Bbls 1%Slick KCL,290 Bbls 2%KCL,35 Bbls 3%NH4CL w/0.2%Losurf,35 Bbls 12%HCL,35 Bbls 9:1 Mud Acid,168 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: New Well 0 0 10 1 Subsequent to operation: 3938 1260 1820 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development 0 Service RI Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 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: 316-364 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer SignaturePhone +1 907 564 4424 Date 9/2/16 vr Form 10-404 Revised 5/2015 S <!l0 46 RBDMS 1/VC v ,..:�(� - 7 2016 Submit Original Only �j • • 0 0 0 0 0 0 0 0 0 0 0 O O O ON ti CO 00 CO 00 CO 00 CO 00 N CMC) O QD N- O I"- O 1- O N O O C D O N V Ln V' Ln - LU V LU N- u N- U y 0 0 0 0 0 0 0 0 0 CD 0 0 O O O M M N- Lf) I- Ln I- Ln 1- LU co � L 7 , M 3 LU CD CO r CO v- CO CO m Nr CO CO CO CO CO a) CO aO co O N- 00 00 M V- c CO M O M v- r- 1` N 00 N CD V Ln O) CD 00 CD CD CD CD O) I- N M cr up O CO CO CD CD N- N- CO V V N N N N N 1- CO CO CO 00 00 CO CO CO 00 O N OD M v- M 00 r- T- C- • M V- (NJ 00 N O Nr Lf) CD Nr 0 CD CD O M M M N M t u) O CO CO V N- N N V N N N N N- 00 00 00 CO CO 00 00 a a) co M .--- V cr cr r- N- Ln V U) LCD N- O N 00 N O O 00 N M Ln M N M N N I- N M rt Ln N 00 CD V M CA NN CO N- N N N N N N- 00 00 Ci) CA CO O O 00 00 C- o , 111111111111111 QO VV V N- CD uO cr op V- N OD N O O CO N M N- M N CI) N L M M M N M cr LC) N 00 CA CO CO O) N N CO _ 0) N N N N ti 00 CO 00 00 OD 00 o M W O CD CA Ln LU Ln LU CD a O 00 CD , , CA CD00 O Op CD CO • O O O D U O ' Z J 0 J 0 Z Z a0 M M J 00 d = 4# 4k U) *k U) l# U) CO J r J 0 pp pp V a0 V N CD (O - N 34. U1• _ U O M L o oD oD Ln L6 N cr• I� N O 40 O) Lf) O) , CD , c- CV CD• CA CA CA M 00 t 'W CO NO M CA OD OO 0 O 00 C)) M O O 00 O 00 O O) N C co co •- M cr 00 N- CO cr. O ' UD N 't LU 0) C) N N ' cr r Ln 1- N OO J Z Z Z Z Z Z Z Z 0 00000000 F- WF- F- F- SHF- F- E- 'N UVUC.) 000UUU U � (La0000000 Ct Z Z c 0 0 0 0 0 0 0 0 W W W W m m C) 2D CC CC OC CC OC OC CC Ct Z_ ZZZ2D2D U U) 0 0 CL d O O Q J J J J }- F- • • Packers and SSV's Attachment PBU 09-18A SW Name Type MD TVD Depscription 09-18A TBG PACKER 8607.07 8381.53 4-1/2" Baker Model D Packer 09-18A PACKER 8706.14 8477.37 9-5/8" BOT External CSG PKR 09-18A PACKER 9094.69 8849.27 7" Baker ECL Packer 09-18A PACKER 9147.3 8891.27 7" Baker ECL Packer • • d ° o H o o o- o c °) a) ami U ami �U c a) 0U) c 0 .c O .E o QU) m o 0) O o ° c N -6 0 D U o U a U �j L o °� .*k a. *k O U) LU * (o a) L (o r * 6) * c * () (n O .*k > a) a) a) - o i O . i O 6 o - o OC 7 D. 0) > a) o N- -) 0 a 0) O o N >i Q 0 a) 33 * co N OQ L a. n -6 -a CY o * C 6) (o (A * U) O � a (i) a) a o_ ` N N F- CL � Y -6 (/) - U in 0 %O - C OFO (o * Z 2 O . * * Z U * Z� pp J O0 ( NNa)Cr) > Oc E ; N ai u) C o o O C - N m CO __ O N LU o M °° N C a-' O O o a) E O _ E '6 co a .� � U c.) o) x N U Y ° x (n 0 c ° c E L m 0 o c o co O W 0 ° E a) d . CZ U U Q 0_ c .- co 0I- O o D O 0 6) -a2 v a) Z Cl)wF_ O D o c 0 — O 0 C o 0 C C 0 -6 0 c C o Q U) c o c N c _ C \ (� C70 (o (o (o � oo Q o06 C C ° o -CO co G) , a) 0 I) 5 4) m 7 0 6 a) N , o O V) O o a) * L U * U U � o U U ° � U U = aW � a U U0U a) 0 O O C O - ` O 00 O o O Q p C c L0 a) U U U N (00 O o (o .o ° W c a) a) c a o « c .o aa)) E m cH c c� o .- c > * aa) 2 as � � « (o avis _ ° E * o f n 3 c E E U o o T v § _a >+ U 0 - - U J M U ate. H cocU NO cNi E o c' U a) U * z 12 D .SQ 0 .S N off > .E' p N 6)F- > •E H c a > c N v o 0 coo NF- a D co U = U 0 cine UYU 0 -c1- aZSU ru 0 Q•inY J Q � Q U � Q H 6) I- .- a) w < (o a) F- (a m E in f- - o Q m _ � N * c * - 0 oZ � a) _ Oar N E O 'E c 'E F_ (n O a) .O 6)`J N L 1-1(). 6) 0 0 •- a) •_..1 O � 0D >- 0DaCO ,— > 5ocI- (nr '� > N oh > � c5 U 3 Do 6 U Q o c a U Q r 0 3 (o D J U in in !- a) in a) ,- 3 a) � - 0) a) ` -- a) - �. 0 a) U J Q a) N a) U) 7 a) 4O 6 • •- a) C 7 a N '(n .o () .0 a) -o QU) c U J V U -6 ~ c ~ = c ~ � � a °' O �• -0E- 0 C rn0 c O 0 fl �� 0 �0 a) F- 0 =- 0I0 i u) U) �c (nm c � D � _a � � (n � a � (000 '6 O O � c- � (� YZ � 2 a : a () O a F- O >> F- O * a (n o >,> I- O N coo 00 o CO s ? I- O O a CO o 0 o N `- J * J CO 0 J Cl) 0 > 0 * J < 0 > 0 ) 0 c- J c- v * 0 -) Z J (V (r) c- 0) W H Q CI O _O _O _O C° _O O CO ›- O O O O O O O O F- N N N N N N N N N in 1° I° 5 CO O 6) O _O m V (N M CO M U 35 Q I KEE= ow WELLHIAD= RC Sal NOTES:H2S READINGS AVERAGE 125 ' ACTUATOR= BAKER C 09-18A ppm WHEN ON MI. WELL REQUIRES A SSSV OKB.I3_EV= 54' WHEN ON MI. CHROME LNR"WELL AN( F> REF.ELB/= 54' -70°IS 9287"**MAX DIS:252 @ 9212**** BE 13..EV= 21.37 KOP= 4001. 20"GOND, 4. - 111' 2148' -7"CAM BAL-O SSSV NIP,ID=5.937" 1 Ilax Angle= 126°@§737; 0 Datum MD= 9100' Datum TVD= 8800'SS 13-3/8"CSG,72#,Rits1-80,ID=12.347" - 2713' —A k Minimum ID =2.786" @ 8937' 3-1/2" X 3-114" XO 8603' I-7"X 4-1/2"X0,ID----3.958' -----. 7'TBG,28#,L-80, 0383 bpf,ID=6.276' H 8603' 8606' -9-5/8"X 4-1/2"BAKER MODE3_D PKR I TOP OFT LM R H 8638' wLa 7:4, TOP OF 3-1/2"X3-1/4"X2-7/8"LNR/CMT H 8675' i I 8675' -3,70"DEPLOY MENT SLV,ID=3.00" I I 869T -3-1/2"FES X 11P,ID=1812" i1 8706' -4-1/2"OTIS XN MP PALLED TO 3.80"(12/2/15) 4-1/2"TBG, 12.6#,L-80, .0152 bpf,1-.)=3.958" 8718' 1 8717' -4-1/2"BAKER SFEAROUT SUB FEf2FORATUN SUMIARY e i $ 7 8718" --4-1/2"WIC, (3=3.958' REF LOG BFI ON 02J13/16 0&• it ANGLE AT TOP PERF. 106'@ 10140' AA 8702' I-ELM)TT LOGGED 06/13/91 Note;Refer to Production DB for historical perf data 0144 SIZE SW INTERVAL ' Opn/Sqz SI-10T SQZ : 2" 6 10140- 10161 0 02/15/16 2" 6 10161 - 10183 0 02/15/16 41 1 r 6 10183- 10204 0 02/15/16 ' 0 *J 2" 6 10204 13937 -3-1/2 X 3-1/4"XO,D=2..788' - 10225 0 02/15/16 ir iive . vi kvf. M Or , MILLOUT WINDOW(09-18A) 8977'-8988' 3-1/2"LNR,9.3#,13CR-85 STL, -- 893T 1' 1/ 001, .0087 bpi, ID=2.992' 7'BKR DELTA W-1'STOCK(12/03/15) 8972' 4,444.4;74.4„. .. .*L.‘ 41411. NN., 9318' -PIP JT w/RA TAG DUMPED CMT(12/03/15) -9005 -........-- - 9961' -PUP JT w/RA TAG - 4•44.0, 7"FOSEET PLUG(12/02/15) 9010" 404/ *z.", 10225" -3-1/4'X 2-7/8" : K XO ID=2.377' .41.44•4.4.'''Ir. 9-5/8"X 7"BKR ECL PKR 90434' 414111040. "Nispi. "1 r`k Nub 9-5/8"X T BKR ECL PKR I 9146- - 3-1/4"LP.,6.8#, - 10225. -44%.442;1114c40. - 13CR-8$TCI,.0079 Elt#44V 4•4 4 bpf,ED=2.850" Firm H 10226' 7"LNIR,29#,L-80, 0371 bpf,ID=6.184" -{ 9353' A 2-718"LNR,6.5#,L-80 STL, .0058 bpf, 10265' MID H 9371' ID=2 441' 44.4ASS440.0.4 ...01.0** 9-5/8"CSG,47#,N-80,.0733 bpf,ID=8,681" - 9437 '•••••••••04 1.•444••440 0.4.6.4.8.4.•.•.•.4... TD - 9450' DATE REV BY COIMPAENTS , DATE REV BY COkAWT11-S PRUDHOE BAY MT 12/01177 ORIGINAL COMPLETION 04/19/16 JO/JM) A(X )3-1/2'NP(MISSED) WEIL. 09-18A 06/01/91 LAST WORKOVER FERMT No,' 152010 02115/16 NOROIC1 GTO(09-18A) . , AR No: 50-029-20259-01 02/19/16 AC DRLG HO CO ,RRECTIONS SEC 1,T1ON,R15E,641'FSL&224'RM.. 02/22/16 RRCI.lkoti FTIAL 00E APPROVAL 03/01/16 TR/J14,4) A DEED REF.ELEV BP Exploration(Alaska) L • • Link, Liz M (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Monday,August 29, 2016 10:23 AM To: AOGCC Reporting (DOA sponsored) Subject: PBU 09-18A/PTD#215-201 Hello, Please reference the following well: Well Name: PBU 09-18A Permit#: 215-201 API #: 50-029-20259-01-00 This well began Injection on: 8/12/16 Method of Operations on this date: Water Injection SCANNED JAN a 8i P , 1 RBDMS I,V Alt& Z.9 2016 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg —� DATE: Tuesday,August 23,2016 ZO P.I.Supervisor NIV,2 ' ��' SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 09-18A FROM: Bob Noble PRUDHOE BAY UNIT 09-18A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv3P,e__ NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-18A API Well Number 50-029-20259-01-00 Inspector Name: Bob Noble Permit Number: 215-201-0 Inspection Date: 8/21/2016 Insp Num: mitRCN160821152237 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-18A ' [Type Inj W TVD 8380 ' Tubing 1767 - 1768 - 1806' 1851 • PTD 2152010 Type Test SPT Test psi 2095 - IA 229 2502 - 2483 - 2482 -� rOTHER P ✓ 165 422 . 417 - 414 Interval ; P/F OA Notes: MIT-IA to max of 2500 psi post CTD salitiED MAY 0 1 a17 Tuesday,August 23,2016 Page 1 of 1 • • yOF r� • 41I yy THE STATE Alaska Oil and Gas o fALAS <:A Conservation Commission 333 West Seventh Avenue 2'— rAnchora e, Alaska 99501-3572 GOVERNOR BILL WALKER Anchorage, ** Main: 907.279.1433 ALAS jitQ' Fax: 907.276.7542 www.aogcc.alaska.gov Alex Youngmun SCAN ° FEB 0 8 Z0i17, Pad Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-18A Permit to Drill Number: 215-201 Sundry Number: 316-364 Dear Mr. Youngmun: 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, Cathy . Foerster A Chair DATED this � day of July, 2016. RBDMS t,L JUL 2 2 2016 STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMM,N APPLICATION FOR SUNDRY APPRO S 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 • Pull Tubing 0 Change Approved Program ❑�r - Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other .ff 1/in vagC to )06„..„...- ✓J 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 215-201 ' 3• Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic ❑ • Service 0 6. API Number: 50-029-20259-01-00 • 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No 0 PBU 09-18A , 9. Property Designation(Lease Number): 10. Field/Pools: RECEIVED ADL 0028327 ' PRUDHOE BAY,PRUDHOE OIL ' ill! 1 R ?nig nig 11. PRESENT WELL CONDITION SUMMARY ?S ' /1 h Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plus MD: J gO c 10265 • 8697 , 10226 8701 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"94#H-40 34-114 34-114 1530 520 Surface 2686 13-3/8"72#N-80 33-2718 33-2718 4930 2670 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10140-10225 8719-8701 See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: 7/23/16 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG 0 • GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 OpShutdown0 Abandoned0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Youngmun,Alex be deviated from without prior written approval. Email younak@BP.com Printed Name Youngmun,Alex Title NWD PE,DS-12 and DS-17 Pad Engineer w , JLQ 1 Signature / f J y /fit,,.- s--,, Phone +1 907 564 4864 Date 7/ I / !/„ COMMISSION USE ONLY W Conditions of approval:Notify Commission so that a representative may witness Sundry Number: \CR.— CQI.( Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 Nole Subsequent Form Required: d 0—4 O Li— lef4.7 Approved by: /4.4e1C74.....„_— VTI 7/Is/I - l(s COMMISSIONER APPROVED BYTHE COMMISSION Date / 20_ / ORIGINAL ,74/7; Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate RBDMS w JUL 2 2 2016 • . m Q,o 0 0 0 0 0 0 0 0 0 0 (0 00 al N N- CO CO CO CO CO 00 CO CO N (.0 M CO c-- O - to CO N- O N- O N O t` O O V LO p CV .1- 1 V ID - 1 V 10 t- o = LO 0 N 0 0 0 0 0 0 0 0 0 0 0 0 O O O i CO M t- LO t` IC) N- LO ti LC) CO CO lN. 'sr M = IC) 6) CO N . CO - CO e- CO ,- r m ,— V co coOOoCOCOCOCOCo ° c) tico v. CO co N- ..;r .;r CO Cr) O CO V N._ r- ,- N- N M 10 0 O co co LO 03 C) CO 0r--- - N CO V N N N N N t- 00 O CO CO CO CO CO CO CO I O V CO r N CO N O CO CO - CO 00 ,- c- N- V' Cr) CO N CO V LO O C.0 Co V C C N C N N N N tom- CO CO CO CO CO CO CO 4.0 CD CO CO r in (C) O E - N co N O O co N co to CO N O N N N. N M co N CO O) �Y co O) N N co L N N N N N N- CO CO O) O) CO O O O M C.) 2 I I Q O4- �r � NIN- 0) IC) t- � t� 'CrI M M N M V tco N 00 0 CO CD CO CO O) N CO 0) N N N N N- CO 0 0o C0 CO _ CO m MM I— WIC) LO LO 1C) �' OO O C) O O 00 00 O a0 co 0 0) Oft 1 ' MOMOMiMI ' 000C° 0 ' Z 0J0Z Z coMMJO 1 C et _ * k (n It Cn * CO * CO J * J ** co .(n CO .- d' f` �' `- N. N M CCOO N O 0\O -co v' 00 -4' 00 'Cr co N CA CO - N U O M t j 00 t o co in CO 00 - - N- N N Ch s s to t! to ti N V O LO CS) tO O i O) , c- N O O) O O M co .0 °"' CO N O CO CO CO CV C N N cf CO CO 0CO COC) N V c J CO J c[ zZzzzzzz C)0 0 0 0 0 0 0 0 0 _ I- W H - t- F- 1- H- 1- 17)ccoD < DDDDDDDD 00 Oau_ 00000000XtYrtfrzz Z rr 0 0 0 0 0 0 0 0 W W W W m m O p rxw erct frctr z z z z D - U (n_W o_ do_ o_ dt1ra. JJJ =, 1— h- • • I Packers and SSV's Attachment PBU 09-18A SW Name Type MD TVD Depscription 09-18A TBG PACKER 8607.07 8381.53 4-1/2" Baker Model D Packer 09-18A PACKER 8706.14 8477.37 9-5/8" BOT External CSG PKR 09-18A PACKER 9094.69 8849.27 7" Baker ECL Packer 09-18A PACKER 9147.3 8891.27 7" Baker ECL Packer • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: 09-18A Well Type: WAG Injection Well API Number: 50-029-20259-01 Well Activity Conventional 4 Classification: Activity Description: Clean-up Injector(CO, stim, N2 lift) Cost Code/AFE: X3-017GY-C:PREPOST Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: POST CTD Estimated Cost, $K: AWGRS Job Scope: CTD Other regulatory requirements? none Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Alex Youngmun Contact numbers: (907)564-4864 (907)250-1228 Well Intervention Engineer: Tyson Shriver Contact numbers: (907)564-4133 (406)690-6385 Lead Engineer: Danielle Ohms Contact numbers: (907)564-5759 (907)440-9082 Date Created: June 30, 2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR FTP or Injection g Gas Lift Rate Date Choke SettinPressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (Mscf/Day) (psi) N/A-New CTD sidetrack injector Current Status: Operable Shut In Inclination>70°at Depth(ft) 9,300' MD Recent H2S (date,ppm) NA 0 Maximum Deviation (Angle and ppm Depth)Depth) 9,737' MD Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 9,212' MD Reservoir pressure(date, PPFG psig) prediction @ 3,400 psi Minimum ID and Depth 2.786" 8,937' MD 8800' TVDss Reservoir Temp,F Offset wells suggest 182 de F Shut-in Wellhead Pressure —550 psi 9 Known mech.integrity problems(specifics) None Last downhole operation (date, operation) 6/22/2016 SL drifted for hydrates or obstruction... No obstructions encountered. Most recent TD tag(date,depth, toolstring OD) 6/22/2016 8,675' MD 3.24"cent&2.50"sample bailer. Surface Kit Fit-for-Service? YES If No,Why? •• Comments,well history, 09-18Ai is a 2016 CTD sidetrack completed as a cement and•completion.The ST drilled down through background information, 2BL and 2A (finding mainly oil filled sands), and back up through Victor in 4B (with 20+ resistivity). 85' of etc: perfs were initially shot in 4B to establish injection at the toe. Nordic cemented as per plan,bumping the wiper plug within 0.3 bbls of what was calculated placing -24.5 bbls of cement behind pipe. Calculated ToC is at ToL. Drilling reports noted -10 bbls excess cement to be circulated out of the wellbore. There was no mention of actually seeing cement at surface. It is likely that the excess cement was not adequately cleaned out due to the 7" tubing, leaving cement as fines behind. Nordic left fresh water w/1.5 ppb PowerVis in the liner and 1% KCI/seawater with a diesel freeze protect cap in the tubing. Nordic conducted a passing LL test to 2400 psi losing 40 psi followed by 25 psi. Operations attempted to PO1 to PWI on 6/19/16, but was unable to establish injection as the WHP was higher than the PWI header pressure.The high WHP was due to testing the surface equipment with lift gas prior to placing on injection.The pressure was not bled down prior to attempting to PO1. FB was called out to pump on the well to knock down WHP, but locked up after only-2bbls of fluid pumped. SL arrived and drifted clean to the ToL at 8675' MD. FB returned on 6/23 to attempt to establish injectivity. FB was able to inject at 1 bpm at -2200 psi WI-HP pumping a total of -390 bbls. FB was not able to establish adequate injection rates below the PWI header pressure of-1900 psi. The objective of this job is to ensure we get the well to take the expected injection rates of -5000 bwpd. Cost was estimated with 2 contingency options due to the unlikely probability of all 3 contingencies being executed. • • Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Wit not take PWI. Specific Intervention or Well Objectives: 1 Ensure no mechanical blockage above/across downhole perf set. 2 Contingency to break/degrade diutan polymer and dissolve any filter cake left over from drilling by pumping an oxidizer.Contingent acid stim to remove any acid soluble particulates from cementing. 3 Contingent N2 lift and flowback to clean wellbore/perfs of drilling fluids and perf debris to improve injectivity. Key risks,critical issues: Mitigation plan: Pump large high vis pill during initial circulation and 1 7"tubing making hole cleaning challenging. additional sweeps as necessary to aide in the clean-out. 2 V High H2S.Offset wells suggest reservoir fluids could have Follow H2S SOP. H2S values between 100—550 ppm. 3 Pumping oxidizer. Follow RP. Follow RP. Flowback acid fairly quickly if pumped. Recommend to keep flowback fluids separate at surface or add a neutralizer to the previous fluids before it hits the tanks. Flowing back 5 tubing+liner 4 Pumping acid after oxidizer wash. volumes should be enough to dilute and segregate the fluids.If there is any residual oxidizer in the wellbore, the pre-flush for the acid should segregate the two fluids adequately. Summary Ste # Service Line Activity P 1 C Drift, cleanout wellbore, injectivity test,contingent perf wash w/oxidizer,acid stim and N2 lift. 2 T Assist CTU w/cleanout,flowback of stimulation fluids and N2 lift if necessary. Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: 5000 Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Handover to Ops post job. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • • •No • 09-18A Measured Depth Profile =s�Ner PM r 4B HRZ I.�a.ene Wen0ea a'. 0440 4444.._ �.;r TO 09.18A HRZ 04m 10,265'MO,.86031VOss -85W aew 2004046 4444 0,8090 .}H. 44P _.._. 4444.` 26M 93P T.L0nB4A App O{pD.15 DTW Bn T.02N 438 NOP 'T.2B0u.6A. 3648 4ZN IIN 0040 42P QS 2CG SC6t % n� < � 0 j F Zone 3 Zone 3 m 3-40 BCGI Zone 2C eC vt y m 26P d� \ �'r Zone 2C g Zone$8 225N26P B 36P S LSP Lone 28 4444. 20N � 24N wn� 22P 24N 4880 21N 22N sgao 11 SLP Zone 2A 22v ren 2o402A IIN ZiN .540 Lav 21v xM.IZ/14/2026®0600hn '0060 44 N 4M6 a a s 8 s g "s s' a Measured Depth • • 09-18A CT/Testing Procedure Drift, cleanout wellbore, injectivity test, contingent perf wash w/ oxidizer, acid stim and N2 lift. Notes: - 09-18A is an injector with no GLV's. Rig-up will need to incorporate a portable test separator for the flowback. - 09-18A has —8600' of 7" tubing. If a cleanout is necessary, use gel sweeps as necessary to aide in the cleanout. - Offset wells suggest reservoir fluids could have H2S values between 100—550 ppm. - MIT-IA passed on 6/22/15 to 3000 psi. - Filter all fluids possible that will enter the formation to 3 microns onsite immediately prior to pumping downhole. - Do not add friction reducer to stimulation fluids that will enter the perforations. - Recommend to request tubing FL shot and WHP reading prior to arrival per N2 lift RP. - Wellbore volume to bottom perf = 333 bbls (tubing volume = 320 bbls, liner volume = 13 bbls). 1. MU and RIH with —2.25" JSN BHA. 2. Drift to PBTD. POOH while jetting liner clean and chasing all debris to surface. Take returns through ASRC. Do not fluff and stuff. • If any blockages or set downs are seen, please note the nature of the set down. • If blockage feels hard / mechanical, may elect to pick up a motor/mill and cleanout to PBTD. • When jetting liner or milling, please capture a sample of what comes OOH and send to the lab to aide in understanding the plugging mechanism. • At the ToL, circulate a large high vis pill, then jet the 7" tubing at max rate all the way to surface. 3. Once at surface post cleanout or milling, close in choke and perform a short (10 — 15 bbl) injectivity test to see if blockage/damage has been swept from the liner. • If injectivity has not improved, contingent steps will need to be executed. Consult with APE to determine which contingency steps are to be executed. 4. Contingency 1 (Oxidizer Wash): If set downs felt sticky and minimal cement returns were seen while cleaning liner, wash perf interval with 85 bbls of oxidizer (sodium persulfate, supplied by Halliburton). This will help to break/degrade any diutan polymer and dissolve the filter cake left over from drilling. Let soak for 1 hr. • Perf interval: 10,140'— 10,225' MD. 5. Jet the liner from TD with KCI at max rate. 6. At the ToL, circulate a large high vis pill, then jet the 7" tubing at max rate all the way to surface. 7. Perform an injectivity test to determine if the wells injectivity has improved. • Close in the surface choke and perform an injectivity test down the CT. Pump 2% KCI at max rate not to exceed WHIP of 1900 psi for 10 minutes and record the stabilized injection rate. (Should be <50 bbls total). Okay to go above frac P. Please step up rate/pressure in increments to determine if the well can take >3.5 bpm below the frac P (-1800 WHIP) before going above frac P. o Discuss results with APE. If able to establish injection rates >3.5 bpm at <1900 psi WHIP, may elect to cancel the contingent N2 lift. - Have the option to handover to Operations to temporarily place on injection to determine if the well can meet the 5000 bwpd injection target. o 8720'of TVD to perfs, so estimated BHP = 1900 +3835 = 5735 psi o Estimated frac P = 5665 psi (assuming 0.65 psi/ft gradient) • • 8. Contingency 2 (Acid Soak): If significant cement returns were seen at surface while cleaning out liner, reciprocate across perfs while pumping 3000 gallons of acid (1500 gal HCI and 1500 gal 9:1 Mud Acid). This will help dissolve any cement fines and remove any near wellbore formation damage. Displace acid with one coil volume of NH4CI and let soak 1 hr. 9. After soaking, attempt to perform injectivity test per Step 7. 10. If infectivity has improved to acceptable rates, pump an additional 150 bbls of fluid to displace the acid away from the near wellbore area. No flowback will be necessary as this well is an injector. 11. Contingency 3 (N2 Lift): If injectivity has not improved after pumping bleach or acid, an N2 flowback will need to be executed. 12. RIH with the same or different nozzle and N2 lift through portable test separator per RP. • RIH to just above top perf when N2 lifting to give the perfs the best chance to clean- up. • Flowback 1700 bbls (-5 tubing + liner volumes). 13. Once 1700 bbls are flowed back. S/I and displace to 2% KCI water w/freeze protect cap. This is to displace all Fgas out of the wellbore to reduce risk of hydrates when well is placed on PWI. 14. Handover to Operations to place on PWI. Portable Test Separator Flowback Notes: • Recommend to flowback well through 09-21's flowline. 09-21 is currently S/I awaiting a PMP repair on the AL line. Rates: • Expected rates: 1000 oil, 500 water, 10 mm Fgas. • Worst case expected: 1000 oil, 5000 water, 30 mm Fgas. 15. Assist CT with the FCO and bleach/acid soak and N2 flowback per RP. • CTU will end the N2 lift once —1700 bbls of fluid have been recovered. • Do not flow to tanks once tubing + liner volume has been unloaded given the H2S potential of the well. • If flowing back acid, WSL discretion to produce well back until pH is above —6.5 to 7 or displace acid away from near wellbore area after —5 tubing + liner volumes are flowed back. TREE= OW WELLHEAD= FMC • SibrY NOTES:H2S READINGS AVERAGE 125 ACTUATOR= BAKER C 09-18A 9-18A ppm WHEN ON MI. WELL REQUIRES A SSSV +OKB,ELEV= 54' WHEN ON ML CHROME LNR**WELL ANGLE> REF.aEv_ i --70*©9287 " **MAJ DLS:26.2*@ 9212'* BF.ELEV= 21.32' KOP= 4001' 20°COND,__#, —1 111' I Max Angle= 126°@ 9737' _ — 2145' —r CAM BALA SSSV NP,D=5.937" I Datum MD= 9100' D= " Datum TVD= 8800'SS 1 13-3/8"CSG,72#,MN-80,D=12.347" IH 2713' -411 Minimum ID =2.786" @ 8937' 13-1/2" X 3-1/4" XQ 17"TBG,26#,L-80,.0383 bpf,D=6.276" I I 8603' I 1 8603' 7"X 4-1/2-XO,D=3.958' >< $606' ,—9-5/8"X 4-1/7 BAKER MODEL.0 Fit 1 !TOP OF r LNR H 8638' I _ ITOP OF 3-112"X3-114"X2-718'LNR/CMT 1—I 8675• I i i 8675' I-13.70^t7FJ'LOYh� D YT BLV, =3.00" j• 86.9r I-I3-1/2"HES x NIP,D=2,812" 8718' 5 8706' I---{4-1/2"OTIS XN NIP MLLE') 3.80"C12/2/15) I 1 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" PERFORATION SUMMARY 8717' H4-1/2"BAKER ShEAROUT SI u I REF LOG:BEI ON 02/13/16 ' . - 8718' -I4-1/2"WLEG,D=3.958" I ANGLE AT TOP PERF-106°@ 10140' r )K 8702' 1-1E10 TT LOGGED 06/13/91 Note:Refer to Production D8 for historical pert data �' ,.' cr I SCE SPF INTERVAL Opn/Sgz SHOT SQZ y Y 2" 6 10140-10161 0 02/15/16 ,r Y`/' x • -4 2" 6 10161-10183 0 02115/16 \";y.. 2" 6 10183-10204 0 02/15/16 h�'4 {.. 2" 6 10204- 10225 I 0 ' 02/15/16 v' } , . • 8937' -I3 112"X 3-114"XO,D=2.786" I r.:�f`5 3-1(2"LNR,9.3#,13C R-85 STL, — 8937" K „ .' A LOUT W'0OW(09-18A) 8977'-8988' 1.0087 bpf, D=2.992" 17"BKR DELTA\M IPSTOCK(12/03115) H 8972' 4.*`*!sb.,„ 9318' --IPUPJTw/RA TAG , 1DUMFEDCMT 12/03/15 �� C } .90�' ,=_ s� F 9961' H PUP.IT w/RA TAG 1 17"POSISET PLUG(12/02/15)i— 9010' - ..- 411%.47,0410225' 1—3O(4"=2-7(8" '`b►� XO,0=2.377" 19-5/8"X 7"BKR ECL 1 (R H 8094' I _ Ark I9-5/8"X 7"BKR ECL PKR 9146' -1� 3-1/4"LNR,6.6#, - 10225' "' � ft13CR-85 TCI,.0079 bpf,D=2.850" I PBTD H I 10226' 17"UR,29#,L-80,.0371 bpf,0=6.184" H 9353' J 2-7/8"LNR,6 5#,L-80 SE.,.0058 bpf, N 10265' I I parr) I-1 9371' I f D=2.441" I 19-5/8"CSG,47#,N-80,.0733 bpf.ID=8.681" I—) 9432' 4.44�.1..44�4 ITD I—_ 9450' .♦.�.*1�4+4�*♦***4 DATE REV BY COMMENTS DATE REV BY CO Q1 PRUDHOE BAY Q 12/01/77 ORIGINAL COMPLETION 04/19/16 JO/JMD ADM)3-1Q-NIP(MISSED) WELL 09-18AUNIT 06101/91 LAST WORKOVER I 02/15/16 NOROIC1 CTO(09-18A) PEWIT No:'2152010 02/19/16 AD DRLG HO CORRECTIONS API No: 50-029-20259-01 02/22/16 RRC/J140 FTWL ODE APPROVAL SEC 1,T10N R15E 641'FSL&224'F1/111_ 03/01/16 TR/A0 ADDED REF ELEV BP Exploration(Alaska) • • • 0 . — o • NW I W oN o W ❑ LL ❑ LL in (J) N W �I LU -1 H o N >- c 1 LLI z LLI z • ' UI d N N c6 H '° Q L.T. 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N I c 0 0 D O J E 1 G c \/ I c F o 0 0 0 m1co co1 V O mco N IG I N a) a• = w d E O w 0 ui r4 Z 0 cco p O co 0 Q 0 c0 Q 0 D 0 C 1 I C U w U U 0 U C v J y Q N U £ I0 a m 0 a 0- co v E a C7 0 0 0 0 °) I- Z E o2 U) 0 E ami G E E 04 a 2 w w w � > 0 a 0 1 0 0 0 10 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday,June 19, 2016 7:56 AM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OIL; AK, OPS FS2 Field OIL; AK, OPS PCC EOC IL; AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr;AK, OPS EOC Specialists; G GPB FS2 Drillsites; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; McVey, Adrienne; Regg, James B (DOA); Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: OPERABLE:Injector 09-18A (PTD #2152010) Coil Sidetrack and Surface Work Complete All, Injector 09-18A(PTD#2152010) underwent a Coiled Tubing Drilling sidetrack on 02/15/16.The post-rig surface work was recently completed, and the well is ready to be brought online. Once the well stabilizes, an AOGCC-witnessed MIT- IA will be performed.The well is reclassified as Operable. Use caution when bringing the well online, as the annuli are fluid-packed. Plan Forward: 1. Operations: Put well on injection 2. Downhole Diagnostics: AOGCC-witnessed MIT-IA to 2500 psi Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWellIntegrityCoordinator@BP.com 1 STATE OF ALASKA WELLLLASKA OIL AND GAS CONSERVATION COMM! RECEIVED MPLETION OR RECOMPLETION REPO AND LOG Wr 1 5 2016 la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 DevelGft�'® tory 0 GINJ 0 WINJ ❑ WAG ElWDSPL 0 No.of Completions: One ' �? - p Service D Sfratigrap is Test 0 2. Operator Name: 6. Date CoSusp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 2/15/2016 215-201• 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 2/9/2016 • .4 50-029-20259-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 2/12/2016 PBU 09-18A ' Surface: 642'FSL,224'FWL,Sec.01,T1ON,R15E,UM • 9 Ref Elevations KB 54 17. Field/Pool(s): Top of Productive Interval: 1257'FSL,1115'FEL,Sec.02,T1ON,R15E,UM GL 19.32 BF 21.32 • PRUDHOE BAY,PRUDHOE OIL • Total Depth: 1294'FSL,2167'FEL,Sec.02,T10N,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 10226'/8701' ADL 028327 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD). 19. Land Use Permit: Surface:x- 718627' y- 5942116 - Zone - ASP 4 • 10265'18697' • 74-017 TPI: x- 717269 y- 5942694 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 716217 y- 5942700 Zone - ASP 4 2148'(Nipple) 1900'(Approx.) 5. Directional or Inclination Survey: Yes El (attached) No 0 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MDTTVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 8977'/8740' • 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD/GR/RES 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT PULLED TOP BOTTOM TOP BOTTOM 20" 94# H-40 33' 111' 33' 111' 30" 258 sx Arctic Set II 13-3/8" 72# N-80 33' 2713' 33' 2713' 17-1/2" 5500 sx Arctic Set 500-95/N-80 9-5/8" 47# SM-95 31' 9435' 31 8990' 12-1/4" 1000 sx Class'G',180 sx Arctic Set 7" 29# L-80 8638' 8977' 8411' 8740' Scab Liner 175 sx Class'G' ' 3-1/2"x 3-1/4" 9.3#/6.6# 13cr85/L-80 8675' 10265' 8447' 8697' 4-1/4" 121 sx Class'G' x 2-7/8" /6.5# 24. Open to production or injection? Yes El No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 7",26#x 4-1/2",12.6#,L-80 8719' 8607'/8381' 2"Gun Diameter,6 spf 10140'-10161' 8719'-8714' COMPLETION 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 10161'-10183' 8714'-8708' DATE 10183'-10204' 8708'-8704' Was hydraulic fracturing used during completion? Yes 0 No • 10204'-10225' 8704'-8701' Z/�s//( l Per 20 AAC 25.283(i)(2)attach electronic and printed VERIFIED information L-L DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 2500' Freeze Protect w/95 Bbls Diesel 27. PRODUCTION TEST Date First Production: Not on Injection 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(con'): Press 24 Hour Rate ••••0 Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only v'rL 3/i7/1-4, 4,477,E RBDMS - - G MAR 16 2016 , •��.% 28. CORE DATA Conventional Core(s) Yes 0 No • Sidewall Cores Yes 0 No l If Yes to either question,list formations and interva s 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 IZI Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 8934' 8698' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. SADLEROCHIT-Zone 4B 8934' 8698' 42SB-Zone 4A 8951' 8715' Kicked off from Parent Well 8977' 8740' CGL-Zone 3 9011' 8773' Base of CGL-Zone 2C 9066' 8824' 23SB-Zone 2B 9128' 8877' 21TS-Zone 2A 9240' 8949' 23SB-Zone 2B(Invert) 9632' 8952' Base of CGL-Zone 2C 9765' 8882' CGL-Zone 3 9870' 8826' 42SB-Zone 4A 9969' 8778' Sadlerochit-Zone 4B 10145' 8718' Formation at total depth: Zone 4B(From Base) 10145' 8718' 31. List of Attachments: Summary of Daily Drilling Report,Well Schematic Diagram,Survey,Cement Report Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ciolkosz,RyanRyR Email: Ryan.Ciolkosz@bp.com Printed Name: Joe LasttRka ; Title: Drilling Technologist Signature: Phone: +1 907 564 4091 Date:�jl1al 10 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 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 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only I Hth= UN 1AELLHEAD= FMC III SOY NOTES:H2 S READINGS AVERAGE 125 ACTUATOR= BAKER c 09-1 8A ppm WHEN ON MI. WELL REQUIRES A SSSV OKB.ELEV= 54. WHEN ON MI. CHROME LNR**WELL ANGLE> REF.B_EV= 54' [ —70°@ 9287"*MAX ELS:252°@ 9212'm BF.ELEV= 21.32' KOP= 400ii 20'COND, #, — 111' 2 2148' —T CAM BAL-0 SSSV NIP,ID=5.937" Max Angle= 126*@ 9737' f.i Datum MD= 91W D= " Datum TVD 8800'SS 13-3/8'CSG,72#,MN-80,D= 12.347' I— 2713' -1 Minimum ID = 2.786" @ 8937' 3-1/2" X 3-1/4" XO 1 8603' —17"X 4-1/2"XO, ID=3.958' 7"TBG,26#,L-80,.0383 bpf,0=6.276" — 8603' \ ">< >< 8606' —9-5/8"X 4-1/2"BAKER MODE_D FKR TOP OF T LINER H 8638' TOP OF 3-1/2"X3-1/4"X2-7/8"LNR/C.MT —I 8675' - 8675' H3.70"DEPLOY MENT SLV,ID=3.00"-.... 1 1 8706' H4-1/2"OTIS XN NIP MLLED TO 3.80"(12/2/15) I, 4-1/2"TBG, 12.64,L-80, .0152 bpf,ID=3.958' 8718' 0 871T —4-1/2'BAKER SHEAROUT SUB FTTTORATION SUMMARY .4 8718' —4-1/2"WLEG,ID=3.958" II REF LOG:ea ON 02/13/16 4 N, ANGLE AT TOP PEW:106°a 10140' •41 .410 .4 40 8702' —ELMD TT LOGGED 06/13/91 Note:Refer to Production DB for historical perf data • r••4 SIZE SFF NTERVAL Opn/Sqz SHOT SQZ . 4 _ ii 2" 6 10140- 10161 o 02/15/16 ' 0:p Nor. 2" 6 10161 - 10183 o 02/15/16 . ON 7 6 10204 10225 o 02/15/16 2" 6 1o1a3- 10204 o 02/15/16 . . tio. ' 8937 —3-1/2"X 3-1/L1"XO,ID=2.786" - ,..„.4„.. i v:itP1;$ • 4' _ - • 4 MLLOUT WINDOW(09-18A) 8977'-8988' 3-1/2"LNR,934,13CR-85 STL, — 8937 • b• „Al .0087 bpf,ID=2.992" 7'BKR DELTA W-IPSTOCK(12/03/15) 8972' 1141.1._ —"NIP *, 9318' —PUP Tr w IRA TAG 14.142CIPAPAPAPA 0. . ..."4410,. DUMPED CMT(12/03/15) —9005' --" mow•-- — • Ittp szitii. .0. 9961 —PUP JT w/RA TAG 41411,1*in. 7'POSISET PLUG(12/02/15) 9010' "r•Ar.,.. ,,, 10225' —3-1/4'X 2-7/8" 4T1P'4 '''• 7. ' XO,p=2.377" 9-5/8"X 7'BKR ECL FKR H 9094' „.......„..../..„..--"13 ..: 42?-"NIP4ra. 4.4.* 4461. 9-5/8"X 7"BKR ECL PKR H 9146' — 3-1/4"LW,6.64, —I 10225 '14.414•411/Ityp,„. — 13CR-85 TCI,.0079 "‘411114,pAigir "r4i7,47`44 W,0=2.850" PBTD — 10226' T LM,29#,L-80,.0371 bpf,ID=6.184" H 9353' I 2-7/8"LNR,6.54,L-80 SU,.0058 bpf, 4 10265' PBTD H 9371' D-.-2.441" ***......• ••••••••••••••••••• • 9-518"CSG,47#,N-80,.0733 bpf,D=8.681" H 9432 .••••••••••4 ••••••••••• '••••••••401 1D H 9450' DATE REV BY COMANTS - DATE REV BY CONAENTS PRUDHOE BAY UNIT 12/01177 ORIGINAL COMPLETION WELL: 09-18A 06/01/91 LAST woRmov ER 1±J2MIT No:*2152010 02/15/16 NORDIC1 CTD(09-18A) AFI 143: 50-029-20259-01 . . 02/19/16 JM) DRUG HO CORRECTIONS SEC 1,T1ON,R15E,641'FSL 8.224'FM 02/22/16 RRC/JM) FlN1AL ODE APPROVAL 03/01/16 TR/JM) ADDED REF,B_EV BP Exploration(Alaska) i North America-ALASKA-B m' Operation Summary Report '1 !J ` . Common Well Name:09-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date.2/6/2016 End Date.2/13/2016 X3-017GY-C.(3,511,086.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor:NORDIC CALISTA UWI:500292025900 Active datum:21 :18 11/3/1977 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/6/2016 19:00 - 20:30 1.50 MOB P PRE RIG DOWN AND PREPARE TO MOVE RIG OFF WELL 20:30 - 21:30 1.00 MOB P PRE MOVE RIG FROM 09-02ATO 09-18A -HOLD PJSM FOR MOVING OFF WELL 09-02A WSL VERIFIED THE FOLLOWING PRIOR TO MOVING OFF WELL 09-02A PHYSICAL BARRIERS ARE IN PLACE TO PREVENT THE RIG FROM ROLLING BACK TOWARDS TREE/WELLHEAD ESD IN CELLAR IS OPERABLE AND MANNED BY THE TOOLPUSHER RADIO COMMUNICATION VERIFIED FOR ALL INDIVIDUALS INVOLVED IN THE MOVE THE AGREED"COMMAND"TO STOP THE RIG MOVE IS UNDERSTOOD BY ALL -PULL RIG OFF WELLAND MOVE TO 09-18A 21.30 - 22:00 0.50 MOB P PRE MOVE RIG ONTO 09-18A -HOLD PJSM FOR MOVING ONTO WELL 09-18A -WSL VERIFIED THE FOLLOWING PRIOR TO [MOVING ONTO WELL 09-18A PHYSICAL BARRIERS ARE IN PLACE TO PREVENT THE RIG FROM ROLLING BACK TOWARDS TREE/WELLHEAD ESD IN CELLAR IS OPERABLE AND MANNED BY THE TOOLPUSHER RADIO COMMUNICATION VERIFIED FOR ALL INDIVIDUALS INVOLVED IN THE MOVE THE AGREED"COMMAND"TO STOP THE RIG MOVE IS UNDERSTOOD BY ALL ***RIG ACCEPTED AT 22:00*** 22:00 - 00.00 2.00 MOB P PRE RIG UP -RIG UP CELLAR AND CYCLE TREE VALVES -TAKE RKB MEASUREMENTS -INSTALL SLB SSV PANEL HOSES AND STROKE OPEN SSV,INSTALL AND ADJUST FUSIBLE CAP AND DUMP SSV AGAINST FUSIBLE CAP -BLEED OFF TREE CAP PRESSURE -LEAK TIGHT TEST TREE VALVES-GOOD -NIPPLE DOWN TREE CAP FLANGE 2/7/2016 00:00 - 02:30 2.50 BOPSUR P PRE RIG UP AND NU BOPE -NIPPLE UP BOPE,INSTALL HOT TUB -SPOT IN CUTTINGS BOX,TIGER TANK,FUEL TRAILER,MU AND PT HARDLINE MOVE SATELLITE OFFICE AND CONNECT POWER CABLES 02:30 - 05:00 2.50 BOPSUR P PRE PRESSURE TEST BOP -FLOOD LINES -PERFORM SHELL TEST TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINS -HOLD H2S/RIG EVACUATION DRILL W/AAR -AOGCC REP CHUCK SCHEVE WAIVED WITNESS BY EMAIL AT 14:28 ON 02/06/2016 Printed 2/29/2016 9:11:37AM • North America-ALASKA-BP "' �� Page 2 of 9 Operation Summary Report Common Well Name:09-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2016 End Date:2/13/2016 1X3-017GY-C:(3,511,086.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor NORDIC CALISTA UWI:500292025900 Active datum:21 :18 11/3/1977 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 10:45 5.75 BOPSUR P PRE PRESSURE TEST BOP -PRESSURE TEST BOP TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES PER NORDIC, BP AND AOGCC 10:45 - 11:00 0.25 BOPSUR P PRE I PJSM TO PU THE INJECTOR,STAB ON AND TEST THE IRV AND PACK OFF 11:00 - 12:30 1.50 BOPSUR P PRE TEST IRV&PACK OFF 12:30 - 13:05 0.58 BOPSUR P PRE GOOD TEST,HOLD A PJSM TO PRESSURE TEST HARDLINE TO 4700 PSI 13:05 - 13:25 0.33 BOPSUR P PRE PRESSURE UP TO 250 LOWAND 4700 HIGH 13:25 - 13.35 0.17 BOPSUR P PRE GOOD TEST TO 4700 PSI,BLEED OFF PRESSURE 13:35 - 13:50 0.25 BOPSUR P PRE HOLD A PJSM TO PUMP SLACK,CUT COIL AND HEAD UP BHI 13:50 - 14:30 0.67 BOPSUR P PRE DISPLACE DIESEL OUT OF COIL WITH FRESH WATER 14:30 - 15:05 0.58 BOPSUR P PRE SLACK PUMPED,PU THE INJECTOR,RU THE CUTTER AND CUT PIPE 15:05 - 16:10 1.08 BOPSUR P PRE CUT 290',DRESS THE END OF THE COIL MU THE DIMPLE CTC PULL TEST CTC TO 44K 16:10 - 16:30 0.33 BOPSUR P PRE -STAB ON LUBRICATOR AND PUMP SLACK FORWARD 16:30 - 17:40 1.17 BOPSUR P PRE HEAD UP 17:00 GREASE CREW ON LOCATION TO TORQUE TREE BOLTS PT CTC&BHI UQC 17:40 - 18:00 0.33 BOPSUR P PRE HEADED UP,PERFORM RIG EVAC DRILL WITH THE DAY CREW 18:00 - 18:30 0.50 BOPSUR P PRE HOLD A PJSM WITH THE VALVE CREW TO LOAD THE VC LUBRICATOR ON THE RIG TO PULL THE TWC PT BHI UQC FLOATS 18:30 - 18:45 0.25 BOPSUR P PRE GOOD TEST,RD THE TEST EQUIPMENT 18:45 - 19:30 0.75 BOPSUR P PRE LOAD VC HANDLING TOOLS AND LUBRICATOR ON THE RIG 19:30 - 20:15 0.75 BOPSUR P PRE PULL TWC -HOLD PJSM -INSTALL LUBRICATOR ON RISER -PT LUBRICATOR 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MINUTES EACH- GOOD TEST 20:15 - 21:30 1.25 BOPSUR N SFAL PRE MASTER VALVE IS PRESSURE LOCKED- CANNOT OPEN -HOLD PJSM GREASE CREW ATTEMPTED TO BLEED PRESSURE FROM BLEED PORT AND STEM PACKING PORT BUT UNABLE TO BLEED -PRESSURE UP ABOVE TWC WITH TEST PUMP TO 3500 PSI AND OPEN MASTER VALVE,BLEED OFF 3500 PSI FROM LUBRICATOR Printed 2/29/2016 9:11:37AM ::::;c::: :: A- Page 3 of 9 f �r- Sy r rt Common Well Name:09-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2016 End Date:2/13/2016 X3-017GY-C:(3,511,086.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor:NORDIC CALISTA UWI:500292025900 Active datum:21 :18 11/3/1977 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 2130 - 22:30 1.00 BOPSUR P PRE PULL TWC -HOLD PJSM I-STROKE IN AND ENGAGE TWC -PULL TWC,ZERO PRESSURE ON TUBING -CLOSE MASTER VALVE AND PERFORM LEAK TIGHT TEST-GOOD -POP OFF LUBRICATOR AND RETRIEVE TWC --ALL COMPONENTS RECOVERED -RIG DOWN LUBRICATOR,CLEAR RIG FLOOR 22:30 - 00:00 1.50 BOPSUR P PRE PREPARE TO BULLHEAD KILL WELL -HOLD PJSM -INSTALL INJECTOR AND PT QTS LOW 250 PSI/HIGH 3500 PSI FOR 5 CHARTED MINUTES EACH-GOOD TEST -DISPLACE COIL WITH WARM KCL AT 3.1 BPM AND 1930 PSI 2/8/2016 00:00 - 02:30 2.50 BOPSUR P PRE BULLHEAD KILL WELL -SPEAR IN WITH 10 BBLS MEOH -PUMP DOWN KILL LINE AND COIL AT 7 BPM, 3170 PSI WHP FOR 350 BBLS -WHEN KCL REACHED PERFORATIONS,WHP DROPPED TO 2900 PSI AT 7 BPM -TOTAL KCL PUMPED=520 BBLS SHUT DOWN,10 MIN FLOWCHECK-STATIC -PUMP ACROSS THE TOP TO DETERMINE LOSS RATE,NO LOSSES OBSERVED 02 30 - 04:00 1.50 BOPSUR P PRE BULLHEAD 9.5 PPG MUG -PUMP DOWN KILL LINE AND COIL AT INITIAL PRESSURE OF 2600 PSI AT 6 BPM,4000 PSI CIRC PRESSURE -PUMP 350 BBLS MUD,FINAL CIRCULATING PRESSURE=2500 PSI AT 6 BPM,4300 PSI CIRC PRESSURE 04:00 - 05 15 1.25 STWHIP P WEXIT MU 3.80"WINDOW MILLING BHA -HOLD PJSM FOR MAKING UP BHA -MU WINDOW MILLING BHA -STAB ON INJECTOR -PT QTS LOW 250 PSI/HIGH 3500 PSI FOR 5 CHARTED MINUTES EACH-GOOD TEST **INJECTOR ON WELL AT 0500** 05:15 - 07:00 1.75 STWHIP P WEXIT RIH WITH 3.80"WINDOW MILLING BHA -CIRCULATE THROUGH MGS WHILE RIH -MM IN/OUT: 1.70/1.70 BPM -MW IN/OUT:9.54/9.54 PPG -PVT=240 BBLS -LOSSES<1 BPH 07:00 - 07:35 0.58 STWHIP P WEXIT LOG TIE IN 07:35 - 07:50 0.25 STWHIP P WEXIT CORRECT DEPTH-16.5',CLOSE THE EDC AND RIH TO TAG THE PINCH POINT PINCH POINT IS 5.3'FROM THE TOWS AT 8972' 07:50 - 08:00 0.17 STWHIP P WEXIT TAG PINCH POINT AT 8977.9' PU AND START PUMPING WORK DOWN TO FIRST MOTOR WORK Printed 2/29/2016 9.11.37AM • North America-ALASKA-BP • Page 4 of 9 Operation Summary Report Common Well Name:09-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2016 End Date:2/13/2016 X3-017GY-C:(3,511,086.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor NORDIC CALISTA UWI:500292025900 Active datum:21 :18 11/3/1977 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 11:50 3.83 STWHIP P WEXIT FIRST MOTOR WORK AT 8976.8' START MILLING WINDOW AS PER PLAN FREE SPIN=2750 PSI AT 2.75 BPM RATE IN=2.71 BPM RATE OUT=2.69 BPM MW IN=9.53 PPG MW OUT=9.46 PPG ECD =10.30 PPG ROP=1 FPH WOB=1.11 K CIRC PSI=2842 PSI IAP=27 PSI OAP=29 PSI PVT=278 BBLS 08:20 STOP MILLING,WOB NOT READING,BHI IS REBOOTING THEIR MWD COMPUTER 08:40 WOB WORKING,CONTINUE MILLING 11:50 - 14:00 2.17 STWHIP P WEXIT CONTINUE MILLING WINDOW FREE SPIN=2750 PSI AT 2.75 BPM RATE IN=2.67 BPM RATE OUT=2.69 BPM MW IN=9.53 PPG MW OUT=9.47 PPG ECD =10.06 PPG ROP=1 FPH WOB=1.74 K CIRC PSI= 2736 PSI IAP=45 PSI OAP=60 PSI PVT=284 DRAINED MUD FROM MGS INTO THE PITS AFTER FIRST BOTTOMS UP MAGNETS GETTING PRETTY FURRY WITH METAL 14:00 - 17:20 3.33 STWHIP P WEXIT CONTINUE MILLING WINDOW STOPPING WHEN WOB REACHES 4.4K WOB AS PER BTT FREE SPIN=2750 PSI AT 2.75 BPM RATE IN=2.68 BPM RATE OUT=2.70 BPM MW IN=9.52 PPG MW OUT=9.48 PPG ECD =10.08 PPG ROP=1 FPH WOB=3.78 K CIRC PSI= 2823 PSI IAP=68 PSI OAP=100 PSI PVT=281 17.20 - 21:00 3.67 STWHIP P WEXIT CONTINUE MILLING WINDOW STOPPING WHEN WOB REACHES 4.4K WOB FREE SPIN=2750 PSI AT 2.75 BPM RATE IN=2.70 BPM RATE OUT=2.68 BPM MW IN=9.52 PPG MW OUT=9.47 PPG ECD =10.09 PPG ROP=1 FPH WOB=4.29 K CIRC PSI= 2959 PSI IAP=114 PSI OAP=182 PSI PVT=279 BOTTOM OF WINDOW 8988'(UNCORRECTED) 21:00 - 00:00 3.00 STWHIP P WEXIT MILL RATHOLE -CONTROL MILL TO 8989'FOR REAMER EXIT -MILL 10'RATHOLE TO 8999' -IN/OUT RATE=2.70/2.71 BPM -IN/OUT DENSITY=9.52/9.46 PPG 2/9/2016 00:00 - 02:15 2.25 STWHIP P WEXIT DRESS AND DRIFT WINDOW BACKREAM WINDOW WITH AS-MILLED TFO AT 1 FPM -BACKREAM WINDOW 15°LEFT AT 1 FPM -BACKREAM WINDOW 15°RIGHT AT 1 FPM -DRY DRIFT WINDOW,PICK UP AND OPEN EDC TD SAMPLE CONFIRMS KICKOFF WITH 80% SHALE/COAL AND 20%SAND Printed 2/29/2016 9:11:37AM • North America-ALASKA-BP • Page 5 of 9 4 Operation Summary Report Common Well Name:09-18 AFE No • Event Type:RE-ENTER-ONSHORE(RON) I Start Date:2/6/2016 End Date:2/13/2016 X3-017GY-C:(3,511,086.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor:NORDIC CALISTA UWI:500292025900 Active datum:21 :18 11/3/1977 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:15 - 04:00 1.75 STWHIP P WEXIT POH WITH MILLING ASSEMBLY -FLOW CHECK AND POH AT 120 FPM -IN/OUT RATE=3.78/3.20 BPM -IN I OUT DENSITY=9.52/9.46 PPG 04:00 - 04:45 0.75 STWHIP P WEXIT LAY DOWN MILLING ASSEMBLY -HOLD PJSM FOR HANDLING BHA -LAY DOWN BHAAND GAUGE MILLS 04:15 INJECTOR OFF BOTH MILLS GAUGED 3.79 GO 3.78 NO GO 04:45 - 05:20 0.58 DRILL P PROD1 MAKE LIP DRILLING BHA 05:00 INJECTOR ON 05:20 - 06:55 1.58 DRILL P PROD1 RIH WITH THE BUILD BHA 06:55 - 07:20 0.42 DRILL P PROD1 8830'LOG TIE IN 07:20 - 07:30 0.17 DRILL P PROD1 CORRECT DEPTH-16',CLOSE THE EDC AND RIH 07:30 - 11:15 3.75 DRILL P PROD1 ON BOTTOM DRILLING FREE SPIN=2750 PSI AT 2.80 BPM RATE IN=2.76 BPM RATE OUT=2.78 BPM MW IN=9.52 PPG MW OUT=9.48 PPG ECD 10.07 PPG WOB=2-4 K CIRC PSI=3179 PSI IAP=133 PSI OAP=225 PSI PVT=274 BBLS SLOW ROP TO START,8999 20 FPH THEN SLOWED TO<10FPH AT 9007 9010'ROP PICKING UP 11:15 - 12:45 1.50 DRILL P PROD1 STOP DRILLING PU FOR LONG TIE IN 12:45 - 13:30 0.75 DRILL P PROD1 CONTINUE DRILLING TO 9080' 13:30 - 14:00 0.50 DRILL C PROD1 SUSPEND OPERATIONS AND RIG ACTIVITY WHILE NORDIC RIG 2 MOBILIZES FROM DS 09 TO DS 03 ACCESS ROAD(FLUID SUPPORT AND EMERGENCY SERVICES WILL BE BLOCKED COMING FROM DEADHORSE UNTIL NORDIC RIG 2 CLEARS ENDICOTT ROAD); CIRCULATE AND WAIT ON NORDIC 2 14:00 - 18:00 4.00 DRILL P PROD1 CONTINUE DRILLING 4.25"BUILD SECTION FREE SPIN=2750 PSI AT 2.80 BPM RATE IN=2.57 BPM RATE OUT=2.57 BPM MW IN=9.49 PPG MW OUT=9.47 PPG ECD =10.05 PPG WOB=2-4 K CIRC PSI=2900 PSI IAP=275 PSI OAP=500 PSI PVT=267 BBLS REDUCE RATE TO BUILD PLANNED 21°DLS 18:00 - 00:00 6.00 DRILL P PROD1 'CONTINUE DRILLING 4.25"BUILD SECTION FREE SPIN=2750 PSI AT 2.80 BPM RATE IN=2.85 BPM RATE OUT=2.87 BPM MW IN=9.50 PPG MW OUT=9.47 PPG ECD =10.11 PPG WOB=2-4 K CIRC PSI=3300 PSI IAP=350 PSI OAP=600 PSI PVT=260 BBLS Printed 2/29/2016 9:11.37AM lec • North America-ALASKA BFB • Page 6 of 9 Operation Summary Report ,/4.1';-"-/ - Common Well Name:09-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2016 End Date:2/13/2016 IIX3-017GY-C:(3,511,086.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor:NORDIC CALISTA UVVI:500292025900 Active datum:21 :18 11/3/1977 00.00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/10/2016 00 00 - 03:50 3.83 DRILL P PROD1 CONTINUE DRILLING 4.25"BUILD SECTION FREE SPIN=2950 PSI AT 2.84 BPM RATE IN=2.85 BPM RATE OUT=2.86 BPM MW IN=9.51 PPG MW OUT=9.48 PPG ECD =10.11 PPG WOB=2-4 K CIRC PSI=3300 PSI IAP=515 PSI OAP=756 PSI PVT=260 BBLS 03:50 - 05:45 1.92 DRILL P PROD1 PERFORM WIPER TRIP TO WINDOW POOH TO 8,965' OPEN EDC,PUMP SWEEP AT MAX RATE OF 4.0 BPM CIRCULATE SWEEP AROUND HOLE STARTED UNLOADING CLAY AND SHALE AT 80 BBLS INTO CIRCULATION, MODERATE AMOUNT OF CUTTINGS UNLOADED. *BLEED DOWN OA PRESSURE FROM 812 PSI TO 100 PSI 05:45 - 06:30 0.75 DRILL P PROD1 CLOSE EDC,RIH AND TIE IN AT RA TAG AT BOTTOM OF WINDOW WITH 1.5' CORRECTION RIH TO BOTTOM 06:30 - 09:00 2.50 DRILL P PROD1 I'DRILL 4.25"BUILD SECTION F/9,410'-9,485' 1MD MM IN/OUT:2.91/2.91 CIRC PSI:3235 FS:3120 1-MW IN/OUT:9.52 PPG/9.48 PPG -IA/OA/PVT:138/165/252 -WOB/ECD:2-4K/10.16 PPG 09:00 - 09:30 0.50 DRILL P PROD1 POOH F/9,485'-8960'MD -MM IN/OUT:2.91/2.91 CIRC PSI:3120 -MW IN/OUT:9.52 PPG/9.48 PPG -PUMP 18 BBLS HIGH VIS SWEEP ON BOTTOM 09:30 - 11:00 1.50 DRILL P PROD1 CIRCULATE BOTTOMS UP AT 8960'MD -MM IN/OUT:4.0/4.0 CIRC PSI:3622 -MW IN/OUT:9.55 PPG/9.50 PPG 1-ECD:10.28 PPG ***CONSISTANT VOLUME OF CUTTINGS ACROSS SHAKERS FOR THE ENTIRE DURATION OF BOTTOMS UP INTERVAL (25-35%OVER AS DRILLED PERCENTAGE). ***CUTTINGS RATE REDUCED-60%AFTER BOTTOMS UP COMPLETED. ***POOH CHASING CUTTINGS OUT OF HOLE. 11:00 - 12:40 1.67 DRILL P PROD1 POOH F/8960'-200'MD -MM IN/OUT:2.91/2.91 CIRC PSI:3265 -MW IN/OUT:9.52 PPG/9.48 PPG 12:40 - 12:55 0.25 DRILL P PROD1 FLOW CHECK AT SURFACE -HOLD PJSM FOR LD DIRECTIONAL TOOLS -NO FLOW Printed 2/29/2016 9.11:37AM • North America-ALASKA-BP Operation Summary Report Common Well Name.09-18 AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:2/6/2016 End Date.2/13/2016 X3-017GY-C:(3,511,086.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor NORDIC CALISTA UWI:500292025900 Active datum:21 :18 11/3/1977 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:55 - 14:15 1.33 DRILL P PROD1 LD DIRECTIONAL TOOLS -STAND INJECTOR BACK(1300) -BLOW DOWN DIRECTIONAL TOOLS -LD BUILD ASSEMBLY GRADE BIT(2-1) -CHANGE MOTOR AKO SETTINGS TO 1.2 -MU LATERAL ASSEMBLY -GET ON WELL(1400) INITIALIZE MWD TOOLS -PRESSURE TEST QTS 14:15 - 16:30 2.25 DRILL P j PROD1 RIH F/80'-8950'MD -MM IN/OUT:3.15/3.75 CIRC PSI:2650 -MW IN/OUT:9.52 PPG/9.48 PPG -LOG TIE-IN(-18.5')CORRECTION -RIH TO BOTTOM 16:30 - 00:00 7.50 DRILL P PROD1 DRILL 4.25"LATERAL SECTION F/9,485'-9,650' MD MM IN/OUT:2.91/2.91 CIRC PSI:3350 FS:2950 -MW IN/OUT:9.53 PPG/9.50 PPG -IA/OA/PVT:157/226/225(ADD 30 BBLS TO ACTIVE SYSTEM(LO-VIS SWEEPS)) -WOB/ECD:2-4K/10.10 PPG SURFACE WEIGHT CONTINUES TO DECREASE;SHORT WIPERS ONLY IMPROVING SLIDE TEMPORARILY 2/11/2016 00:00 - 02:15 2.25 DRILL P PROD1 CIRCULATE BOTTOMS UP -PUMP 10 BBLS LOW-VIS SWEEP AND CHASE TO WINDOW PULL INSIDE WINDOW,OPEN EDC AND CIRCULATE CUTTINGS OUT AT MAX RIG POWER -TIE-IN TO RA MARKER(+0.5')CORRECTION 02:15 - 05:00 2.75 DRILL P PROD1 DRILL 4.25"LATERAL SECTION F/9,650'- 9,750'MD -MM IN/OUT:2.91/2.91 CIRC PSI:3350 FS:3000 -MW IN/OUT:9.53 PPG/9.50 PPG -IA/OA/PVT:265/375/218 -WOB/ECD:3-4K/10.18 PPG SLOW ROP AND DIFFICULTY SLIDING THROUGH 24N 05:00 - 12:00 7.00 DRILL P PROD1 DRILL 4.25"LATERAL SECTION F/9,750'-9966' MD -MM IN/OUT:3.01/3.02 CIRC PSI:3550 FS:3000 -MW IN/OUT:9.56 PPG/9.52 PPG -IA/OA/PVT:265/375/218 -WOB/ECD.3-4K/10.18 PPG ***PERFORM COMPLEX D2 DRILL. SIMULATED 2 BBLS PIT GAIN WITH LOW METHANE GAS ALARMS IN PITS,ON RIG FLOOR AND FAILURE OF INJECTOR PACK-OFF AND ANNULAR.DRILLER RESPONDED IN THE CORRECT SEQUENCE TO SECURE THE WELLBORE.DRILL TIME:5 MINS 32 SEC Printed 2/29/2016 9:11:37AM • North America-ALASKA-BP . Page 8 of 9 Operation Summary Report Common Wet Name:09-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2016 End Date:2/13/2016 'X3-017GY-C:(3,511,086.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor:NORDIC CALISTA UWI:500292025900 Active datum:21 :18 11/3/1977 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 15:00 3.00 DRILL P PROD1 DRILL 4.25"LATERAL SECTION F/9,966'-9982' MD -MM IN/OUT:3.01/3.02 CIRC PSI:3250 FS:3000 -MW IN/OUT:9.57 PPG/9.53 PPG -IA/OA/PVT:365/508/215 -WOB/ECD:3-4K/10.19 PPG 15:00 - 15:45 0.75 DRILL P PROD1 PERFORM WIPER TRIP TO WINDOW F/9982' MD MM IN/OUT:3.15/2.95 CIRC PSI:3311 -MW IN/OUT:9.56 PPG/9.52 PPG 15:45 - 17:15 1.50 DRILL P PROD1 CIRCULATE BOTTOMS UP -MM IN/OUT:4.06/4.00 CIRC PSI:3658 -MW IN/OUT:9.56 PPG/9.52 PPG 17:15 - 18:00 0.75 DRILL P PROD1 RIH F/8850'-9982'MD -LOG TIE-IN(+1')CORRECTION -RIH TO BOTTOM 18:00 - 19:15 1.25 DRILL P PROD1 ATTEMPT TO CONTINUE DRILLING;NO SLIDE. PUMP 15 BBLS LOW/15 BBLS HIGH VIS SWEEP 19:15 - 22:00 2.75 DRILL _P PROD1 POH FOR AGITATOR -CHASE SWEEP TO WINDOW AND OPEN EDC IN/OUT RATE=3.84/3.45 BPM IN/OUT DENSITY=9.56/9.52 PPG -POH AT 80 FPM(PULL SPEED 80%OF AV WHILE CHASING SWEEP OUT OF THE HOLE) 22:00 - 22:45 0.75 DRILL P PROD1 BHA CHANGE -FLOW CHECK,HOLD PJSM AND TAG UP -UNSTAB INJECTOR(2200 HOURS)AND PULL BHA '-MAKE UP AGITATOR AND 4.25"HYC C3 BIT i(RE-RUN) -STAB INJECTOR(2245 HOURS) HOLD D1 KICK WHILE TRIPPING DRILL AND AAR WITH NORDIC,BAKER AND SCHLUMBERGER 22:45 - 00:00 1.25 DRILL P PROD1 RIH WITH DRILLING ASSEMBLY -PRESSURE TEST QTS TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES RIH TO 300'AND TEST AGITATOR -RIH AT 100 FPM IN/OUT RATE=3.61/4.15 BPM -IN/OUT DENSITY=9.55/9.51 BPM 2/12/2016 00:00 - 02:00 2.00 DRILL P PROD1 CONTINUE RIH WITH DRILLING ASSEMBLY 1-RIH AT 100 FPM -IN/OUT RATE=3.61/4.15BPM -IN/OUT DENSITY=9.55/9.51 BPM 1-TIE-IN TO RA MARKER(-16')CORRECTION AND RIH TO BOTTOM 02:00 - 06:00 4.00 DRILL P PROD1 DRILL 4.25"LATERAL SECTION F/9,983'- 10,070' -MM IN/OUT:2.80/2.81 CIRC PSI:3700 FS:3400 -MW IN/OUT:9.59 PPG/9.51 PPG -IA/OA/PVT:360/475/221 -WOB/ECD:2-4 K/10.18 PPG Printed 2/29/2016 9:11:37AM • North America-ALASKA-BP * Page 9 of 9 Operation Summary Report Common Well Name:09-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2016 End Date:2/13/2016 X3-017GY-C:(3,511,086.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor:NORDIC CALISTA I UWI:500292025900 Active datum:21 :18 11/3/1977 00:00©54.0ousft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 12:00 6.00 DRILL P PROD1 DRILL 4.25"LATERAL SECTION F/10,070'- 10,200'MD -MM IN/OUT:2.90/2.89 CIRC PSI:3889 FS:3400 -MW IN/OUT:9.59 PPG/9.51 PPG -IA/OA/PVT:400/562/221 -WOB/ECD:2-4 K/10.21 PPG 12:00 - 13:45 1.75 DRILL P PROD1 DRILL 4.25"LATERAL SECTION F/10,200'- 10,265'MD -MM IN/OUT:2.75/2.75 CIRC PSI:3889 FS:3300 -MW IN/OUT:9.62 PPG/9.55 PPG -IA/OA/PVT:400/562/221 -WOB/ECD:2-4 K/10.21 PPG 13:45 - 15:15 1.50 DRILL P PROD1 TD WIPER TO W1NDOW(#1) MM IN/OUT:2.80/2.75 CIRC PSI:3535 MW IN/OUT:9.62 PPG/9.57 PPG -PUMP SWEEPS:20 BBLS LOW VIS/20 BBLS HIGH VIS 15:15 - 17:00 1.75 DRILL P PROD1 CIRCULATE BOTTOMS UP -MM IN/OUT:3.95/3.95 CIRC PSI:3475 -MW IN/OUT:9.63 PPG/9.55 PPG -LOG TIE-IN(0.5')CORRECTION 17:00 - 17:45 0.75 DRILL P PROD1 LOG CCL F/8400'-8700'MD -RIH TO WINDOW -TIE-IN(+0.5')CORRECTION 17:45 - 18:30 0.75 DRILL P PROD1 TD WIPER FROM WINDOW(#1) -MM IN/OUT:2.87/3.12 CIRC PSI:3593 -MW IN/OUT:9.62 PPG/9.56 PPG -CONFIRM CORRECTED TD OF 10,265' 18:30 - 19:15 0.75 DRILL P PROD1 TD WIPER TO WINDOW(#2) -MM IN/OUT:2.87/2.78 CIRC PSI:3810 -MW IN/OUT:9.62 PPG/9.55 PPG 19:15 - 20:00 0.75 DRILL P PROD1 TD WIPER FROM WINDOW(#2) -MM IN/OUT:2.87/3.03 CIRC PSI:3850 -MW IN/OUT:9.62 PPG/9.55 PPG 20:00 - 20:45 0.75 DRILL P PROD1 POH WITH DRILLING ASSEMLBY POH,LAYING IN 20 BBLS ALPINE BEAD LINER RUNNING PILL 20:45 - 22:15 1.50 DRILL P PROD1 PULL INTO WINDOW,OPEN EDC AND CIRCULATE 20 BBLS SWEEP TO SURFACE AT 4 BPM 22:15 - 00:00 1.75 DRILL P PROD1 POH WITH DRILLING ASSEMBLY -POH AT 80 FPM(80%AV) -MM IN/OUT:3.82/3.40 CIRC PSI:3280 -MW IN/OUT:9.59 PPG/9.55 PPG 2/13/2016 00:00 - 00:30 0.50 DRILL P PROD1 CONTINUE POH WITH DRILLING ASSEMBLY -MM IN/OUT:3.82/3.40 CIRC PSI:3280 -MW IN/OUT:9.59 PPG/9.55 PPG 00:30 - 01:00 0.50 DRILL P PROD1 LAY DOWN DRILLING BHA -HOLD PJSM FOR LAYING DOWN DRILLING BHA -UNSTAB INJECTOR(0030 HOURS),BLOW DOWN DIRECTIONAL TOOLS AND LAY DOWN DRILLING BHA ***SEE 09-18A CON REPORT#1 FOR REMAINDER OF REPORT*** Printed 2/29/2016 9:11:37AM • • North America-ALASKA-BP Operation Summary Report r Common Well Name:09-18 AFE No Event Type:COM-ONSHORE(CON) Start Date.2/13/2016 End Date:2/15/2016 X3-017GY-C.(1,492,036.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor:NORDIC CALISTA UWI:500292025900 Active datum:21 :18 11/3/1977 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task j Code NPT NPT Depth Phase Description of Operations (hr) i (usft) 2/13/2016 01:00 - 02:15 1.25 CASING P RUNPRD SLACK MANAGEMENT -HOLD PJSM FOR PUMPING SLACK AND MAKING UP CTC -PICK UP INJECTOR,BREAK UQC AND BOOT ELINE -STAB ON,PUMP SLACK,UNSTAB,RECOVER AND CUT 256'ELINE&10'COIL RE-BOOT ELINE 02:15 - 02:45 0.50 CASING P RUNPRD MAKE UP,PULL TEST AND PRESSURE TEST BAKER COIL TUBING CONNECTOR 02:45 - 03:15 0.50 CASING P RUNPRD LOAD,PUMP AND RECOVER 3/4"DRIFT BALL 03:15 - 03:30 0.25 CASING P RUNPRD FUNCTION TEST BOP FROM RIG FLOOR CONTROL PANEL 03:30 - 04:00 0.50 CASING P RUNPRD PREP FOR MAKING UP LINER -HOLD PJSM WITH NORDIC,BAKER AND SCHLUMBERGER -WSL,BAKER REP AND DRILLER VERIFY RUN TALLY AND FLAGGED JOINTS IN PIPE SHED -RIG UP AND PREP RIG FLOOR FOR MAKING UP LINER 04:00 - 06:00 2.00 CASING - P RUNPRD MAKE UP 3-1/4"X 3-1/2"PRODUCTION LINER 06.00 06.30 0.50 CASING P RUNPRD CREW CHANGE INSPECT TOOLS AND EQUIPMENT -VERIFY PIPE SHED LINER COUNT W/WSL, TOOLPUSHER&DRILLER -HOLD PJSM FOR MU PRODUCTION LINER 06:30 - 10:45 4.25 CASING P RUNPRD I MAKE UP 3-1/4"X 3-1/2"PRODUCTION LINER -MAKE-UP LINER BHA GET ON WELL WITH INJECTOR VERIFY PIPE SHED LINER COUNT 10:45 - 13.00 2.25 CASING P RUNPRD 1 RIH WITH PRODUCTION LINER F/1792'- 10,265'MD(UNCORRECTED) -MM IN/OUT:0.55/1.01 CIRC PSI:784 -MW IN/OUT:9.48 PPG/9.55 PPG -IA/OA/PVT:12/22/131 -STOP AT PIPE FLAG:(-22')CORRECTION -RECORD PU WEIGHT:42K -CONTINUE RIH TO BOTTOM -STACK OUT AT 9930'MD WHILE RUNNING IN HOLE -BEGIN WORKING LINER TO BOTTOM(1245) -TAG BOTTOM AT 10,266'MD (UNCORRECTED) -RECORD PU WEIGHT:45K AT 10,252'MD -RECONFIRM TAG DEPTH/PU WEIGHT 2 TIMES 13:00 - 14:00 1.00 CASING P RUNPRD RELEASE 5/8"BALL PER SLB BALL DROP PROCEDURE CIRCULATE BALL DOWN TO RELEASE FROM LINER -BALL ON SEAT W/36.5 BBLS AWAY PRESSURE UP SHEAR PIN AT 4195 PSI 1.7 14:00 - 17:00 3.00 CASING P RUNPRD SWAP WELL TO 8.4 PPG KCL -MM IN/OUT:2.56/2.56 CIRC PSI:2330 -MW IN/OUT:8.4 PPG/9.56 PPG Printed 2/29/2016 9.13:21AM North America-ALASKA-BP Page 2 of 5 Operation Summary Repo '> Common Well Name:09-18 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/13/2016 End Date:2/15/2016 X3-017GY-C:(1,492,036.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00.00AM Rig Release:2/15/2016 Rig Contractor:NORDIC CALISTA UWI:500292025900 Active datum:21 :18 11/3/1977 00:00 @54.00usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 00:00 7.00 CASING N WAIT 10,265.00 RUNPRD STANDBY ON RIG OPERATION DUE TO WEATHER CONDITIONS -CIRCULATE ON BOTTOM AT MAX RATE -RELEASE SLB CEMENTERS UNTIL FURTHER NOTICE -RELEASE BTT SERVICE REP UNTIL FURTHER NOTICE 2/14/2016 00:00 - 02:30 2.50 CASING N WAIT 10,265.00 RUNPRD STANDBY ON RIG OPERATION DUE TO WEATHER CONDITIONS -CIRCULATE ON BOTTOM AT MAX RATE -WEATHER BEGINNING TO CLEAR UP; MOBILIZE TRUCKING,CEMENTERS AND BAKER REP BACK TO LOCATION 02:30 - 03:45 1.25 CASING ! N WAIT 10,265.00 RUNPRD WAIT ON PERSONNEL -WAIT ON TRUCKING(EXHAUST PILL, CONTAM PILL,KCL AND FRESH WATER), CEMENTERS AND BAKER REP -CONTINUE CIRCULATING MAX RATE WHILE MOBILIZING CREWAND EQUIPEMENT FOR CEMENT JOB 03:45 - 04:30 0.75 CEMT P RUNPRD PRESSURE TEST CEMENT LINES HOLD PJSM AND DISCUSS PRESSURE CROSSCHECK WITH CEMENTERS BLOW DOWN AND FLUID PACK CEMENT LINES -PRESSURE TEST HARDLINE TO 4700 PSI AND VERIFY TRIP SETTINGS ON PUMP TRUCK 04:30 - 08:30 4.00 CEMT N WAIT 10,265.00 RUNPRD WAIT ON PERSONNEL -EMPTY DIRTY BACK ON LOCATION;PREP PITS AND CUTTINGS BOX FOR CEMENT AND CLEAR PAD OF SNOW -CONTINUE WAITING ON TRUCKING (EXHAUST PILL,CONTAM PILL,KCL AND FRESH WATER)FOR CEMENT JOB 08:30 - 11:30 I 3.00 CEMT N WAIT 10,265.00 RUNPRD CLEAR SNOW FROM LOCATION WITH RIG LOADER -REQUEST ADDITIONAL LOADER SUPPORT FROM ROADS AND PADS -POSITION TRUCKS AT RIG FOR CEMENT JOB 11.30 - 13.00 1.50 CEMT P RUNPRD HOLD PJSM FOR PUMPING CEMENT -VERIFY MAX PRESSURE 4700 PSI ON SLB CEMENT TRUCK -RIG TRIPS SET AND VERIFIED TO 4700 PSI -CALL PAD 3 DISPOSAL TO ENSURE CH2 VAC TRUCKS WILL BE ABLE TO OFFLOAD Printed 2/29/2016 9:13:21AM 4111) North America-ALASKA-BP Page 3 of 5 Operation Summary Report f �� Common Well Name:09-18 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/13/2016 End Date.2/15/2016 X3-017GY-C:(1,492,036.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor:NORDIC CALISTA UWI:500292025900 Active datum:21 :18 11/3/1977 00:00 @54.00usft(above Mean Sea Level) Date From To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 14:30 1.50 CEMT P RUNPRD -BATCH UP CEMENT. CEMENT WET AT 1317 HOURS,UP TO WEIGHT AT 1320 HOURS -ZERO IN MM ONCE DENSITY HITS 14.0 PPG. LOAD 25.2 BBLS OF 15.8 PPG CEMENT IN I REEL. -PUSH EXHAUST TO CEMENTERS,SWAP TO I RIG PUMP AND INCREASE RATE TO 2.5 BPM. -CEMENT TO SHOE AT 68.7 BBLS. ZERO OUT MM,TAKE RETURNS TO PIT 1 FOR MANUAL STRAP. -SHUT DOWN PUMPS AT 79.27 BBLS AWAY I(10.5 BBLS BEHIND PIPE). -PICK UP TO BREAKOVER+13'(10,243'MD), PER BTT REP AND EXPOSE DOGS,STACK BACK DOWN AT 10,256'(+10') -SHIFT LINER WIPER PLUG DOWN,PICK BACK UP TO 10,245'AND SIDE EXHAUST 2 BBLS CEMENT/3 BBLS EXHAUST. -SET DOWN AT 10,256'AND LAUNCH PEE WEE DART. ZERO IN MM AND PRESSURE UP ON WIPER PLUG. LINER WIPER PLUG SHEARED AT 3860 PSI(0.6 BBLS) DISPLACE LINER WIPER PLUG AT 2.5 BPM/ 2500 PSI. PLUG BUMPED AT 12.8 BBLS/2575 PSI(12.5 BBLS CALCULATED). -OPEN BAKER CHOKE AND CHECK FLOATS. -CLOSE BAKER CHOKE,PRESSURE UP ON COIL,PICK UP AND CONFIRM PRESSURE DROP. -PLUG BUMPED AND FLOATS HELD AT 1430 HOURS -PIT 1 MANUAL STRAP FROM CEMENT EXIT I SHOE SHOWS-24.5 BBLS BEHIND PIPE[25.2 PUMPED-(85 END STRAP-60.5 START STRAP-5 EXHAUST)] NO LOSSES OBSERVED.ESTIMATED TOP OF CEMENT= TOP OF LINER. 14:30 - 17:00 2.50 CEMT P RUNPRD CIRCULATE EXCESS CEMENT OUT OF WELLBORE -ESTIMATED 10 BBLS CEMENT TO CIRCULATE OUT OF WELLBORE 17:00 - 18:45 1.75 CEMT P RUNPRD POOH WITH LINER RUNNING TOOLS -MM IN/OUT:3.0/2.4 CIRC PSI:1325 -MW IN/OUT:8.37 PPG/8.58 PPG 18:45 - 19:30 0.75 CEMT P RUNPRD LAY DOWN LINNER RUNING TOOLS -FLOW CHECK AND HOLD PJSM FOR LAYING DOWN BHA -LAY DOWN LINER RUNNING TOOLS AND MOBILIZE FROM RIG FLOOR -RECOVER 5/8"DISCO BALL 19 30 - 20:15 0.75 CEMT P RUNPRD MAKE UP SWIZZLE STICK AND JET BOP 20:15 - 21:00 0.75 PERF P OTHCMP HEAD UP BTT CTC -CUT EXTERNAL CTC MAKE UP BTT INTERNAL DIMPLE COIL CONNECTOR -PULL TEST AND PRESSURE TEST CTC Printed 2/29/2016 9.13:21AM North America-ALASKA-BPA';( Page 4 of 5 Operation Summary Report Common Well Name:09-18 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/13/2016 End Date:2/15/2016 X3-017GY-C:(1,492,036.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor:NORDIC CALISTA UWI:500292025900 Active datum:21 :18 11/3/1977 00:00©54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 22:00 1.00 PERF P OTHCMP MAKE UP PERF GUNS -HOLD PJSM FOR MAKING UP BHAAND HANDLING PERF GUNS -VERIFY GUN LAYOUT IN PIPE SHED WITH TCP REP -MAKE UP(4)GUNS AND(1)BLANK SAFETY JOINT 22 00 - 00:00 2.00 PERF P OTHCMP RIH =STAB INJECTOR AND PRESSURE TEST QTS TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES -RIH WITH PERF GUNS AT 100 FPM IN/OUT RATE=0.32/0.82 BPM -IN/OUT DENSITY=8.31/8.34 PPG__ 2/15/2016 00:00 - 01:00 1.00 PERF P OTHCMP WAIT ON COMPRESSIVE STRENGTH -TAG PBTD AT 10,235 AND PICK UP TO BREAKOVER WEIGHT(BULLNOSE DEPTH= PBTD) -WAIT FOR PRODUCTION CEMENT TO REACH 500 PSI COMPRESSIVE STRENGTH -CIRCULATE MINIMUM RATE DOWN COIL 01:00 - 02:00 1.00 PERF P OTHCMP TEST LINER LAP -REMAIN AT SHOT DEPTH AND LINE UP TO _TEST LINER LAP -TEST LINER LAP TO 250 PSI LOW FOR 5 MINUTES/2400 PSI HIGH FOR 30 MINUTES -PASSING TEST-LOST 65 PSI TOTAL(40 PSI IN FIRST 15 MIN&25 PSI IN FINAL 15 MIN WITH<5 PSI/MIN LOSS RATE IN FINAL 15 MIN) 02:00 - 02:30 0.50 PERF P OTHCMP PERFORATE PER MEMO -BEGIN FIRING SEQUENCE -FIRE 85'GUNS IN STATIONARY POSITION -MINIMAL LOSSES OBSERVED;SURFACE WEIGHT COMES BACK,CIRC PRESSURE DROPPPED,AND GOOD VIBRATION INDICATES SHOTS FIRED ON DEPTH 02:30 - 04:30 2.00 PERF P OTHCMP POH -POH WITH PERF GUNS,HOLDING 250 PSI BACKPRESSURE TO TOP OF LINER IN/OUT RATE=1.72/1.09 BPM -IN/OUT DENSITY=8.36/8.35 PPG 04:30 - 05:30 1.00 PERF P OTHCMP LAY DOWN BHA -FLOW CHECK AND HOLD PJSM FOR LAYING DOWN BHA AND HANDLING PERF GUNS -LAY DOWN BHAAND SPENT PERF GUNS -MOBILIZE GUNS FROM RIG FLOOR 05:30 - 05:45 0.25 BOPSUR P POST MAKE UP NOZZLE BHA FOR FREEZE PROTECT 05:45 - 08:30 2.75 BOPSUR P POST RIH -PRESSURE TEST QTS TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES -RIH WITH NOZZLE AND DUAL BPV FOR DIESEL FREEZE PROTECT -LAY IN DIESEL FREEZE PROTECT-POOH 08:30 - 09:00 0.50 BOPSUR P POST FREEZE PROTECT TREE CLOSE MASTER/SWAB VALVES Printed 2/29/2016 9:13:21 AM North America-ALASKA-BP • ', 71:` Page�. ... �� 5of5 Operation Summary Report 1: Common Well Name:09-18 AFE No Event Type.COM-ONSHORE(CON) Start Date:2/13/2016 End Date:2/15/2016 X3-017GY-C:(1,492,036.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:11/3/1977 12:00:00AM Rig Release:2/15/2016 Rig Contractor.NORDIC CALISTA UWI.500292025900 Active datum:21 :18 11/3/1977 00:00 @54.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 11:00 2.00 BOPSUR P POST HELD PJSM FOR PRESSURE TESTING/ BLOWING DOWN REEL -PRESSURE TEST 250 LOW/3800 HIGH -CIRCULATE 7 BBLS MEOH/50 BBLS WATER TO WASH REEL I-BLOW DOWN REEL WITH 1800 SCFM TO TIGER TANK BLEED DOWN REEL PRESSURE 111:00 - 11:45 0.75 BOPSUR P POST SERVICE TREE -HOLD PJSM FOR SERVICING TREE -RU SLB CONTROL PANEL TO SSV -FUNCTION SSV AND REMOVE FUSIBLE CAP -STAND INJECTOR BACK 11:45 - 14:00 2.25 BOPSUR P POST PULL COIL ACROSS TO REEL -CUT OFF BTT COIL CONNECTOR -INSTALL SLB GRAPPLE -HOLD PJSM FOR PULLING COILACROSS 1-PULL COILACROSS AND SECURE TO REEL WITH SHIPPING BAR. 14:00 - 17:00 3.00 BOPSUR P POST i INSPECT BOP'S OPEN BOP DOORS FOR INSPECTION I-CLEAN OUT EXCESS DEBRIS FROM BOP RAMS INSPECT RAMS AND SEVICE AS NEEDED 17:00 - 18:00 1.00 BOPSUR P POST ND BOP'S -REMOVE HOT TUB -ND BOP FROM TREE AND SECURE 18:00 - 19:00 1.00 BOPSUR- P POST NIPPLE UP TREE CAP AND LEAK TIGHT TEST TO 3500 PSI 19:00 - 21:00 2.00 RIGD P POST RIG DOWN AND PREP TO STAGE RIG ON PAD FOR PLANNED MAINTENANCE AND REEL SWAP 21:00 - 21:30 0.50 RIGD P POST HOLD PJSM WITH NORDIC CREWAND SUPERINTENDANT FOR MOVING RIG -PHSICAL BARRIERS(CHOCKS)ARE IN PLACE TO PREVENT THE RIG FROM ROLLING BACK TOWARDS TREE -ESD IN CELLAR IS OPERABLE AND MANNED BY THE TOUR PUSHER -RADIO COMMUNICATION VERIFIED FOR ALL INDIVIDUALS INVOLVED IN THE MOVE -THE AGREED COMMAND,"STOP"IS UNDERSTOOD TO BY ALL INVOLVED TO STOP MOVEMENT 21:30 - 22.30 1.00 RIGD P POST MOVE RIG -MOBILIZE RIG FROM 09-18AAND STAGE ON PAD -COMPLETE NORDIC PLANNED MAINTENANCE 22:30 - 00:00 1.50 RIGD N WAIT 10,265.00 POST WAIT ON ICE ROAD CLEARING FOR TRAILER SUPPORT TO SWAP REELS "'RELEASE RIG AT 23:59 HOURS"' Printed 2/29/2016 9'13:21AM • • 111 W 01 NOwz Ewe Ma a. m Q 0 Q J � Q + I a W co Ce •v L >+ E Q �+ O < c4 O o m O N C O "' a, O O 2cn a N a o � o � � N N —2 Z aaooE o LL v i i IN W turn I a oil E E > m �Si = = z CON e- 0 -0 � 0 � 01 CO 1 I U U pp CO (`') N 0 g X N N N 7 ;Cr CO o a) a) O O °O Lb COQ n n 0 - 0 O O Z OU a) ,a- ❑ cO 0 0 0 �o .6 0 0 x I o o a 8 p l 0 0 ,,i_) Y N N_ 2 m w r W W U 71) • E In ra p a O N O (J) > Ol N N O E c 1T Olhi J • 'p sW N N H ❑W2 D Do , C p En R O • • y J J 0 N > iv3o cd) .o 1•=. c a I (n 2t J J (7 1, t a) 2 m 0) o2 c a' m c d p N c c hi• c U _,13 m E I n ti c o I m Ai N Fa d 61 • ❑ N N LL O O w `m d O g W 3 c L1 a' a1 L > d OOD 0 0 , V o O (ij ❑ ,- t' co W Ofo co- N f0 O F 2 fn ❑ y o — 0 > > 3 I a N J CO N I o O N44. 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AOGCC o BAKER AOGCC OFFSET RF?OR _ HUGHES 0 BP • 4 1tip Anticollision Report BAKER "0` HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-18 Project: Prudhoe Bay TVD Reference: 21 :18 11/3/1977 00:00 @ 54.Oousft(generic drilling rig) Reference Site: PB DS 09 MD Reference: 21 :18 11/3/1977 00:00 @ 54.O0usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-18A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-18A Offset TVD Reference: Offset Datum Reference 09-18A Filter type: NO GLOBAL FILTER:Using user defined selection&filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 500.00usft Error Surface: Elliptical Conic Survey Program Date 2/17/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 620.00 8,931.00 1 :Camera based mag multi sho(09-18) CB-MAG-MS Camera based mag multi shot 8,972.00 10,233.11 CoilTrak MWD 4-1/4"(09-18A) MWD MWD-Standard AOo `JCC OFFSET REPORT 2/17/2016 10:41:35AM Page 2 of 4 COMPASS 5000.1 Build 61 .., • BP • VPI `* :!gig) Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-18 Project: Prudhoe Bay TVD Reference: 21 :18 11/3/1977 00:00©54.00usft(generic drilling rig) Reference Site: PB DS 09 MD Reference: 21 :18 11/3/1977 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-18A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-18A Offset ND 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 DS 09 09-05-09-05-09-05 Out of range 09-05-09-05A-09-05A Out of range 09-06-09-06-09-06 5,050.46 5,125.00 239.67 147.93 92.25 Pass-Major Risk 09-13-09-13-09-13 3,822.42 3,925.00 495.22 123.11 372.23 Pass-Major Risk 09-14-09-14-09-14 2,824.82 2,825.00 481.34 80.78 400.56 Pass-Major Risk 09-15-09-15-09-15 3,073.61 3,075.00 354.88 89.88 265.00 Pass-Major Risk 09-15-09-15A-09-15A 3,079.11 3,075.00 355.03 89.99 265.05 Pass-Major Risk 09-15-09-15A-09-15A Wp#8 3,079.11 3,075.00 355.03 89.72 265.32 Pass-Major Risk 09-16-09-16-09-16 3,268.96 3,275.00 236.40 99.77 136.68 Pass-Major Risk 09-17-09-17-09-17 3,199.25 3,200.00 130.24 1,313.64 -1,183.38 FAIL-Major Risk 09-18-09-18-09-18 8,999.99 9,000.00 0.55 3.88 -2.73 FAIL-Major Risk 09-19-09-19-09-19 2,899.75 2,900.00 118.36 60.67 57.69 Pass-Major Risk 09-20-09-20-09-20 2,724.59 2,725.00 233.09 1,191.16 -958.08 FAIL-Major Risk 09-21-09-21-09-21 1,551.20 1,575.00 318.40 40.44 277.96 Pass-Major Risk 09-22-09-22-09-22 1,146.32 1,150.00 475.81 29.60 446.21 Pass-Major Risk 09-29-09-29-09-29 Out of range 09-30-09-30-09-30 Out of range 09-30-09-30P81-09-30PB1 Out of range 09-31-09-31-09-31 Out of range 09-31-09-31A-09-31A Out of range 09-31-09-31B-09-31B Out of range 09-31-09-31 C-09-31 C Out of range 09-31-09-31 D-09-31 D Out of range 09-31-09-31 D-Plan#9 09-31 D-update Out of range 09-32-09-32-09-32 Out of range 09-33-09-33-09-33 Out of range 09-33-09-33A-09-33A Out of range 09-34-09-34-09-34 Out of range 09-34-09-34A-09-34A Out of range 09-37-09-37-09-37 3,706.25 3,700.00 446.16 72.62 373.58 Pass-Major Risk 09-38-09-38-09-38 Out of range 09-46-09-46-09-46 1,958.67 1,975.00 294.59 62.47 232.15 Pass-Major Risk 09-48-09-48-09-48 1,741.47 1,750.00 432.12 57.90 374.24 Pass-Major Risk 09-49-09-49-09-49 Out of range 09-49-09-49A-09-49A Out of range 09-51-09-51-09-51 3,076.12 3,125.00 284.28 75.85 208.46 Pass-Major Risk AOGCC OFFSET RE POo RR 2/17/2016 10:41:35AM Page 3 of 4 COMPASS 5000.1 Build 61 *by Anticollision Report BAKER -"°"a HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-18 Project: Prudhoe Bay TVD Reference: 21 :18 11/3/1977 00:00 @ 54.00usft(generic drilling rig) Reference Site: PB DS 09 MD Reference: 21 :18 11/3/1977 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.O0usft North Reference: True Reference Well: 09-18 Survey Calculation Method: Minimum Curvature Well Error: 0.O0usft Output errors are at 1.00 sigma Reference Wellbore 09-18A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-18A Offset TVD Reference: Offset Datum Reference Depths are relative to 21 : 18 11/3/1977 00:00 @ 54.00usft Coordinates are relative to:09-18 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:1.66° Ladder Plot 600— - 1 I 1 1 1 I 1 1 1 1 I I 1 450 -- - ..jjj,...: a. 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COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE February 13,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider• bakerhu•hes.com TODAYS DATE February 26,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF I'RIN I S #OF COPIES #OF COPIES #OF COPIES 4 LI LI LI U U U 1 BP North Slope 1 0 1 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 1 1 1 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4'State of Alaska -AOGCC 1 I 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 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CD U) U) O 0000 (0 6 _ >0 ''. 00 N V h 0 CO (O CO N 0 OD M CO v) r 0) C00 M M 0000 N N N d 0 N -.y. ❑ - M 0) M 0) 000000000 O '0^ O c p 00 0 .. „��, a a a 0) R w . a rn ate+ ) a) o s a X54 cq p •o .a). m m y a c m N. ✓ Q t0 s ❑ CO 0 0 N i ) • • HW gm'° 2' NZ • • W; a ` a= m U a a OO OOU 0z 0 vQ OO co o OO OO 0 OO 00 1- a N- m a 06' mm U Q 4- CO m U E mo m m CC E .. 2E 0 N N F- W co 0, z I L. O) c Y ✓ 'Q (Q � 4 m L9 w 15 L d K Cd d di p N ro • U 7_,4 d V o :'. d w ro O w • flH c -"- 2z08 ii cc- � "A z L o C p N @ N CC ---400„zefv0 tai co cD To Cj m 03 22 VI d m com U >. ▪ N E m • d O s a a co co co Z• n. 0 0 0 0 Q co ,oa N o . 2 • U O C 41" O m C' as N C7 drn Q I A , oFro • 5 �w\�,1//�,SA THE STATE Alaska Oil and Gas 1,. ....--"IL, —'1, ofAT dASKA Conservation Commission •iii' - a. 333 West Seventh Avenue "" , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O� ALASY'Q. Fax: 907.276.7542 www.aogcc.alaska.gov John McMullen Engineering Team Lead BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool, PBU 09-18A BP Exploration(Alaska), Inc. Permit No: 215-201 Surface Location: 642' FSL, 224' FWL, Sec. 01, R1ON, R15E,UM Bottomhole Location: 1078' FSL, 2227' FEL, Sec. 02, T1ON, R15E,UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced service 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 , ,071,„4, • Cathy i'. Foerster Chair DATED this kelay of December, 2015. gft/L'V STATE OF ALASKA •ASKAOILANDGASCONSERVATIONCOMMI• NOV 0 9 2015 PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1 b. Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single Zone. 0 1 c.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone 0 Colabed Gas ❑ Gas Hydrates❑ Redrill - Q Reentry ❑ Exploratory ❑ Service-WAG 0- Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond Blanket 2 -Single Well ❑ 11. Well Name and Number: BP Exploration(Alaska),Inc Bond No. 6194193 - PBU 09-18A 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O.Box 196612 Anchorage,AK 99519-6612 MD: 10313' - TVD: 8645'ss - PRUDHOE BAY,PRUDHOE OIL • 4a. Location of Well(Governmental Section): y 7. Property Designation(Lease Number): E j'(>i 1 1 t ADL 028327 • Surface: 642'FSL,224'FEL,Sec.01,T1ON,R15E,UM' 8. Land Use Permit: 13. Approximate spud date: 1258'FSL,1116'FEL,Sec.02,T10N,R15E,UM March 1,2016 - Top of Productive Horizon: Total Depth: 1078'FSL,2227'FEL,Sec.02,T10N,R15E,UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 16932 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: 54 feet 15. Distance to Nearest Well Open Surface:x- 718627- y- 5942116 • Zone - ASP 4 GL Elevation above MSL: 20.5 feet t1 Same Pool: 1397 16. Deviated wells: Kickoff Depth: 8972 - feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 114 degrees Downhole: 3407 Surface: 2543 -. 18. Casing Program: Specifications Top-Setting Depth-Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-1/2" 3-1/2"x3-1/4" 9.3#/6.6# L-80 STL 1663' 8650' 8369'ss 10313' 8645'ss 116 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): I Plugs(measured): I Effect.Depth MD(ft): I Effect.Depth TVD(ft): I Junk(measured): 9450 9199 None 9371 9122 None Casing Length Size Cement Volume MD TVD Conductor/Structural 78 20" 258 sx Arctic Set II 33-111 33-111 Surface 2701 13-3/8" 5500 sx Arctic Set 33-2734 33-2734 Intermediate Production 9404 9-5/8" 1000 sx Class'G',180 sx Arctic Set 31 -9435 31 -9185 Liner 715 7" 175 sx Class'G' 8638-9353 8411 -9105 Perforation Depth MD(ft): None I Perforation Depth TVD(ft): None 20.Attachments Property Plat ❑ BOP Sketch El Drilling Program El Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program RI 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and correct. Contact Ciolkosz,Ryan R - • Email Ryan.Ciolkosz@bp.com Printed Nam- Joon;,c -n ./.41 Title Engineering Team Lead Signa re iiriPhone +1 907 564 4711 Date / f (7, . Commission Use Only Permirto Drill2157- � / ---2‘..)/ ��, / Permit Approval Number: -C / API Number: 50- 029-20259-01-00 - Date: 1 '"'1 l ila) i5 See cover letter for other Q requirements: Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: [e Other: 80 p ¢r5 f to 35-0(... /05 7 , Samples mre'd: Yes ❑ No li Mud log req'd: Yes ❑ No Iii 4 n n (//a!- pre-V.e rz tr f-1;5 94 LS rr‘asure Yes li No ❑ Directional svy req'd: Yes O No ❑ 5ta-t'G j/VJ ftp)C$5 •-d Spacing exception re d: Yes 0 No Inclination-only svy req'd: Yes ❑ No 111/VtJT-14- refr,�'rtc) a ffcr 5tabr1J cJI .7jre7-,ov Approved by: a(647 van_ /Z"4,/lc rCOMMISSIONER APPROVED BY THE COMMISSION Date/2./ —/[ Ji ORIGINAL Form 10-401 Revised 10/2012 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit Form and Attachments in Duplicate '/�77 .7S-.4\-- 7 • • To: Alaska Oil &Gas Conservation Commission From: Ryan Ciolkosz Rig: Nordic 1 0 bp CTD Engineer Target Reservoir: Ivishak Zone 2&4 Date: November 4, 2015 Well Type: MI Injector Re: 09-18A Permit to Drill Request History and current status: 06/01/91: RWO to mitigate IAxOA communication. Ran 7" L80 scab liner to get better injection conformance. Also ran 7" x 4.5" L80 tubing. After RWO, Z1 was frac'd (160k prop behind pipe) and Z4 frac'd (29.5k lbs prop behind pipe). 09-18 is a currently actively producing waterflood pattern in the central drill site 09 area of the field. Historically this well was perfed in zone 1 and 2 during the period of pre- production and has since had perfs in all 4 Ivishak zones during its long injection history. Currently injection is dominated by at least 90% of injection into the zone 3 with average injection rates of —10,000 bwpd prior to being shut-in in 2012. Wellwork was discussed to isolate zone 3 to re-direct injection into lower watercut zones (2 and 4) rather than side-track the well. However, the QCLL scab liner that is the most effective way to isolate the perfs, requires cement behind it to insure isolation. Previous experience with cement squeezes in zone 3 indicate that there is a reasonable chance that we would not be able to get cement all the way to the top of the liner(and would not be able to get complete isolation from zone Proposed plan: Drill a through tubing sidetrack with the Nordic 1 Coiled Tubing Drilling rig on or around March 10th, 2016. E-line service unit will mill XN Nipple, Set Posiset Plug to isolate perforations below and set whipstock pre drilling rig. Nordic 1 will a mill a 3.80"window in the 7"x9-5/8" liner and drill a Zone 2&4 well to 10,313 MD. The lateral will be completed with a 3-1/2"x 3-1/4"x2-7/8" 13CR-80 liner which will be cemented and perforated. Pre-Rig Work Mill XN nipple. Set 4-1/2" x 7" Posi-Set plug. Set 4-1/2" x 7" Delta 1. E Whipstock 2. V Pre CTD Tree Work. Set TWC Rig Work: 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. Maximum expected surface pressure with gas (0.10 psi/ft)to surface is 2,543 psi. 2. Mill 3.80"window plus 10' of rathole. Swap the well to 8.5 ppg drilling mud. 3. PU drilling BHA with GR/Resistivity 4. Drill 4.25" hole to TD at 10,313' MD 5. Run 3-1/2"x 3-1/4" L-80 liner leaving TOL at—8,650 MD. 6. Pump primary cement bringing TOC to TOL, 24 bbls of 15.8 ppg liner cmt planned* 7. Test liner lap to 2,400 psi. 8. Perforate liner per asset instructions 9. Freeze protect well, RDMO Post Rig: 1. V: Tree work as necessary. 2. S: Drift. LTP if necessary.* 3. F: Pressure test Liner top packer. AOGCC MITxIA *Approved alternate plug placement per 20 AAC 25.112(i) Mud Program: • Well kill: 8.4-8.6 ppg brine. • Milling/drilling: 8.4-9.5 ppg Power Pro for milling window and drilling (>400 psi over-balance ). • Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.25" Liner Program: • 3-1/2", 9.3# L-80 STL Liner 8,650 MD—8,872 MD • 3-1/4", 6.6# L-80, STL Liner 8,872 MD- 10,313 MD • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. • Magnetic and inclination surveys will be taken every 30 ft. • Distance to nearest property— 16,932' • Distance to nearest well within pool 1,397' Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. Perforating: • SWS 2", 6 spf, perf guns • The primary barrier for this operation: a minimum EMW of 8.4 ppg. An EMW of 8.4 ppg for this well will provide over-balance to the reservoir. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti-Collision Failures • There are no wells that fail "Major Risk"with the 09-18A wellpath. - Hazards • DS 09 is an H2S pad • Low Risk of lost circulation • No anticipated fault crossings Reservoir Pressure • The reservoir pressure on 09-18A is expected to be 3407 psi at 8,645' TVDss. (7.58 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,543 psi. Ryan Ciolkosz CC: Well File CTD Engineer Joseph Lastufka ) • S 0.40r .44 140.044 09-18A Area of Review 09-18A is planned as an Ivishak injection well targeting Zone 4 and Zone 2 sands. The following wellbores are within % mile of the planned 09-18A wellbore within the Ivishak/Sag formation. (See attached map for reference) The primary cement jobs for each wellbore and current well status are provided. 1) 09-31(185-161) a) -1320 ft from 09-18A in Ivishak/Sag reservoir b) Well Status: Abandoned Production Zone/Sidetracked c) Production Casing: 9-5/8", 47#, L-80 Top set Ivishak/Sag at 8,923 ft MD, 8,636 TVD. i) (8/3/85) Cemented with 500 sxs Class G and 299 sx CS 1. Estimated TOC: 7,765' MD/7,530' TVD ii) (8/3/85) FIT/LOT to 11.2 ppg iii) (4/6/93) CTU set cement plug from 9042- 8740' MD. 140 cuft Class G Cement. Pressure tested to 1500 psi and tagged at 8470' MD iv) (1/19/15) Pumped 53 bbls of 15.8 Class G cement plug through tubing. Bottom of - Plug: 7093' MD. Tagged top of cement at 7,039' MD 2) 09-31A (193-053) a) -1320 ft from 09-18A in Ivishak/Sag reservoir b) Well Status: Abandoned Production Zone/Sidetracked c) Production Casing: 9-5/8", 47#, L-80 Top set Ivishak/Sag at 8,923 ft MD, 8,636 TVD. i) (8/3/85) Cemented with 500 sxs Class G and 299 sx CS 1. Estimated TOC: 7,765' MD/7,530' TVD ii) (1/19/15) Pumped 53 bbls of 15.8 Class G cement plug through tubing. Bottom of Plug: 7093' MD. Tagged top of cement at 7,039' MD d) Production Liner: 7" 26# L-80 set in the Ivishak at 9394 ft MD/8989' TVD. i) (4/19/93)47 bbls 15.7 ppg cement. Estimated TOC at TOL 8234' MD ii) (7/12/94) Squeezed 8 bbls cement from 9,350'. Tagged hard cement inside 7" at 9,370' MD/8,973' TVD (7/16/94) 3) 09-31B (194-083) a) -1320 ft from 09-18A in Ivishak/Sag reservoir b) Well Status: Abandoned Production Zone/Sidetracked c) Production Casing: 9-5/8", 47#, L-80 Top set Ivishak/Sag at 8,923 ft MD, 8,636 TVD. i) (8/3/85) Cemented with 500 sxs Class G and 299 sx CS 1. Estimated TOC: 7,765' MD/7,530' TVD ii) (1/19/15) Pumped 53 bbls of 15.8 Class G cement plug through tubing. Bottom of Plug: 7093' MD. Tagged top of cement at 7,039' MD d) (4/11/96) Lay in 2 bbls of Neat Cement followed by 20 bbls 17 ppg Class G Cement and squeeze for 1 hour. Tagged top of cement at 9026' MD 4) 09-31C (196-064) a) -1320 ft from 09-18A in Ivishak/Sag reservoir b) Well Status: Abandoned Production Zone/Sidetracked c) Production Casing: 9-5/8", 47#, L-80 Top set Ivishak/Sag at 8,923 ft MD, 8,636 TVD. i) (8/3/85) Cemented with 500 sxs Class G and 299 sx CS 1. Estimated TOC: 7,765' - MD/7,530' TVD bp • • ii) (1/19/15) Pumped 53 bbls of 15.8 Class G cement plug through tubing. Bottom of Plug: 7093' MD. Tagged top of cement at 7,039' MD d) Production Liner: 2-7/8" 6.5# L-80 set in the Ivishak at 10,945 ft MD i) (4/27/96) 17.5 bbls 15.8 ppg cement. Estimated TOC at TOL 8816' MD ii) (1/10/15) Set CIBP at 8922' MD. (1/10/15,1/14/15) Dump bail 25 bbls cement on top of CIBP. 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E0Ocn LoI a a O O dw d y a m a N V o ;; o .touo uo4eJeagaivaoo)aliu93 20Am d E wd — h u O U a a'' y K K K 8 O (°') • • U) W a CdI u 8 W� o `v 0 41 0 co f,o' a c I a o z N _ _ _ _ _ ___._._ _ -_ 0 0 • D • O Q 8 S 4 , f° .8. m U rn y u rn g o m E o w • m N r c N � o � N iia ,, � � O2O E 28 0 m a ! w LC 8 mm m o g AL _ 8 o syrL OO • 8 „ c o a A v u ihi 2 LL yu`> N.o ` `C Z m U uo 0 C N haoo '� . a .E alt— _. to J c CO v 5, a e a) _5 v 'A co CO C V, g OD a 0 m 8 w ¢ E m0 8 � p .� m a, o f v i E oo t ¢ N . m d0o U 1 0 m _ I I I -n° = 8 8 8 8 ti y - a m o of ai of o n n 3 3 8 ° ' 10��Bj ua;BIBth o a d w °' W ` ;72 w E w 1 e _ ` ° a O U V a C N C K K 9 0 @ fili ■I 21 \ ® \ § ) & } y ) ! ) / a ] § : a o ( -7 / !} 2 S . k ! : ! E ' -8 . . $ ) j; ƒ & 5 § ! 3 ^ I \ o a . - ) r`l / . » y _ ! | ill : : A ( L § ) | | c f = { * kE � # � ) ■ k \ _ ' \ q § a � § v a ` 2 q / ) [ � 0 \ } 0 \ \}k / \ o \ ° � © _ . . ' •• Co© InE.) &\ ) - a_ 0 ( - E \ } \ E co iii Q k - ) ƒ! & ; « n . , ! <i } ! 8 ) ) 2 ) o _ _ o 2 _ - z » ; g / \\ \ \ ` ` � | | § _ 0 66 ( . ) ) kk \ 8 *} ` 2 ! « | ! 2 ! ! ! ! • • ( :: bP North America - ALASKA - BP Prudhoe Bay PB DS 09 09-18 09-18A 09-18 WP03 Plus 500ft Anticollision Report 03 November, 2015 BAKER HUGHES ! i r- ...aaew.raa WELLBORE DETAILS:CS-18A IaFB aaUAW11CN in Project:Prudhoe9000Bay ^' ware..taa' �4 Wal8Itel: PB DS 09. C9-18A C 3r9(750)RS,,ce Wal�te.Tan Nom j Wall:09.18 sSTme.rt `.blial(M11 Ptleaa'.Math Baa LwM 0WNroore'09-18A Il't' t/21M1 Parent Waghoro'0&10 IaOi i9//00a0®seaWSllga'eieiMgig) BAKER Pma*Nan maw. PIan:09-1aWPo3PW560aR X09-18109-19A) wetmumt! TiRM MD:BBIQDOyqua tlglod MmvnCurawe HUGHES Easing(45 usNin) s w w w w $ p 3 q q w 8 Y' w o 1 _ i ,4�3' w 1 1 w w e w u � o r u 5942880 \ 7�,. � -- .- ._—.._.. ..-_.�.— _.—..._____,Lt__-- _� .. _- �._ ___._ _ $_5942330 NI 5942335 ° ^-- -5942335 59427901 _-4__ i '. �-- j - --- ( I ---5902790 . 1i 1--- --_ --—1 ! _—- • , a -_-59427055942745 - —r- i - — - '--594270089427 ! - F - ��- I —1- — x-59426555&12%5 rt--F I� L - . _ — • +- ^ 2810-59423,3 fi • : 0 AlI i 1 59425651—1 T -- --- .'- 5942520 .- 4.--1. I :—1 I —- +.—.�- _—.� —_.�...� —3902520 F. 1 Z- 5942475 -- —'—t-. I .__i942075m ;9942430 .. -}—_._._. �__II– • —I— _ _."-5942030 pd 6942335 -_.—,i' 0� =�.._ f — --- - 69423/0 ' I1 —.--.L_ .l,_._..1._ —5942300 5847295 �� —� - — - - 5942295 59422501- i. •_ - (--- I------5942250 59422051 ._ ._..at __, . � —_ .--____ — +____ ---5942205 5902180-� .�-. '3 I �f•► III ._i i. .—. bg1.y� I —.�-_.�._ _.-5842180 5902115 - 1 —. +..-- ---'— ■ S• --I11-1—L-- - 1— — -- - - ----5942115 594x0702_ ( ! i ISM. � —. -_.__..59020 0 5942025_ I I I .—_— — —, -- —.-5942025 1 x 6 a 3 g e i g g a Eaeang(45 ue3lln) Mean Sea Level .„s" • BP 4 Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-18 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 09 MD Reference: 21 :18 11/3/1977 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-18A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-18 WP03 Plus 500ft Offset TVD Reference: Offset Datum Reference 09-18 WP03 Plus 500ft Filter type: GLOBAL FILTER APPLIED:All welipaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,840.00 to 10,813.O0usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 200.00usft Error Surface: Elliptical Conic Survey Tool Program Date 11/3/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 620.00 8,840.00 1:Camera based mag multi sho(09-18) CB-MAG-MS Camera based mag multi shot 8,840.00 10,813.00 09-18 WP03 Plus 500ft(09-18A) MWD MWD-Standard 11/3/2015 12 59:02PM Page 2 of 7 COMPASS 5000.1 Build 61 rBP I Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-18 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 09 MD Reference: 21 :18 11/3/1977 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-18A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-18 WP03 Plus 500ft 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 DS 09 09-03-09-03-09-03 Out of range 09-03-09-03A-09-03A Out of range 09-03-09-03A-Plan#7 09-03A Approved Out of range 09-04-09-04-09-04 Out of range 09-04-09-04A-09-04A Out of range 09 05 09 05 09 05 Out of range 09-05-09-05A-09-05A Out of range 09-06-09-06-09-06 Out of range 09-14-09-14-09-14 Out of range 09-15-09-15-09-15 Out of range 09-15-09-15A-09-15A Out of range 09-15-09-15A-09-15A Wp#8 Out of range 09-16-09-16-09-16 Out of range 09-18-09-18-09-18 8,850.00 8,850.00 0.00 0.60 -0.59 FAIL-NOERRORS 09-18-09-18A-09-18 WP03 8,950.00 8,950.00 0.00 0.32 -0.32 FAIL-NOERRORS 09-26-09-26-09-26 Out of range 09-28-09-28-09-28 Out of range 09-28-09-28A-09-28A Out of range 09-29-09-29-09-29 Out of range 09-30-09-30-09-30 Out of range 09-30-09-30PB1-09-30PB1 Out of range 09-31-09-31-09-31 Out of range 09-31-09-31A-09-31A Out of range 09-31-09-31 B-09-31B Out of range 09-31-09-31C-09-31C Out of range 09-31-09-31D-09-31 D Out of range 09-31-09-31D-Plan#9 09-31D-update Out of range 09-32-09-32-09-32 Out of range 09-33-09-33-09-33 Out of range 09-33-09-33A-09-33A Out of range 09-34-09-34-09-34 Out of range 09-34-09-34A-09-34A Out of range 09-35-09-35-09-35 Out of range 09-35-09-35A-09-35A Out of range 09-38-09-38-09-38 Out of range 09-39-09-39-09-39 Out of range 09-40-09-40-09-40 Out of range 09-41-09-41-09-41 Out of range 09-42-09-42-09-42 Out of range 09-42-09-42A-09-42A Out of range 09-42-09-42APB1-09-42APB1 Out of range 09-45-09-45-09-45 Out of range 11/3/2015 12.59:02PM Page 3 of 7 COMPASS 5000.1 Build 61 • Waite .0,. s BP • •.�'°' Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-18 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 09 MD Reference: 21 :18 11/3/1977 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-18A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-18 WP03 Plus 500ft Offset TVD Reference: Offset Datum Offset Design PB DS 09- 09-18-09-18-09-18 Offset Site Error 0.00 usft Survey Program: 620-CB-MAG-MS Rule Assigned:NOERRORS Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +WS 5-E1-W Hole Size Centre Distance Deviation lust) (usftj (usft) lusft) lusft) (usft) P) (usft) (usft) (usft) (use) (usft) (usft) 8,650.00 8,562.93 8,850.00 8,562.93 0.04 007 -14.34 60078 -1,32728 7.062 0.00 0.60 -0.59 FAIL-NOERRORS,ES,SF 8,875.00 8,587.19 8,875.00 8,587.19 0.14 0.24 -14,34 605.48 -1,331.09 7.062 0.00 0.59 -0.59 FAIL-NOERRORS 8,900.00 8,611.45 8,900.00 8,611.45 0.24 0.41 -14.34 610.18 -1,334.89 7.062 0.00 0.60 -0.59 FAIL-NOERRORS 8,925.00 8,635.71 8,925.00 8,635.71 0.27 0.58 -14.34 614.88 -1,338,70 7.062 0.00 0.60 -0.59 FAIL-NOERRORS 8,950.00 8,659.96 8,950.00 8,659.96 0.31 0.75 -14.23 619.57 -1,342.51 7.062 0.00 0.61 -0.59 FAIL-NOERRORS,CC 8,975.00 8,684.22 8,975.00 8,684.22 0.34 0.92 105.98 624.25 -1,346.35 7.062 0.01 0.62 -0.58 FAIL-NOERRORS 8,999.97 8,708.31 9,000.00 8,708.48 0.37 1.09 105.96 628,91 -1,350.20 7.062 0.66 0.63 0.07 Pass-NOERRORS 9,024.69 8,731.80 9,025.00 8,732.74 0,41 126 90.53 633.55 -1,354.08 7.062 3.15 0.65 256 Pass-NOERRORS 9,048.78 8,754.15 9,050.00 8,756.99 0.46 1.43 84.73 638,19 -1,357.96 7.062 7.84 0.68 7.25 Pass-NOERRORS 9,071.89 8,774.94 9,075,00 8,781.25 0.51 1.60 81.68 642.85 -1,361.81 7,062 14,66 0.72 14.07 Pass-NOERRORS 9,093.77 8,793.90 9,100.00 8,805.51 0.56 1.77 79.70 647.53 -1,365.64 7,062 23.46 0.77 22.87 Pass-NOERRORS 9,114,26 8,810.89 9,125.00 8,829.77 0.61 1,94 78.27 652.23 -1,369.45 7.062 34.08 0.82 33.49 Pass-NOERRORS 9,133.27 8,825.92 9,150.00 8,854.02 0.67 2.12 77.14 656.93 -1,37326 7.062 46.30 0.88 45.72 Pass-NOERRORS 9,150.00 8,838.50 9,175.00 8,878,28 0.72 2.29 76.25 661.63 -1,377.07 7.062 59.97 0.94 59.38 Pass-NOERRORS 9,166.89 8,850.53 9,200.00 8,902.54 0.78 2.46 75.45 666.33 -1,380.87 7.062 74.89 1.01 74.30 Pass-NOERRORS 9,181.61 8,860.44 9,225.00 8,926.80 0.84 2.63 74.77 671.03 -1,384,68 7.062 90.92 1.08 90.33 Pass-NOERRORS 9,195.05 8,868.98 9,250.00 8,951.05 0.89 2.81 74.18 675.73 -1,388.49 7.062 107.92 1.14 107.33 Pass-NOERRORS 9,207.32 8,876.35 9,275.00 8,975.31 0.94 2,98 73.65 680.43 -1,392.29 7.062 12577 1.21 125.18 Pass-NOERRORS 9,218.51 8,882.70 9,300.00 8,999.57 0.99 3.15 73.17 685.13 -1,396.10 7.062 144.35 1.28 143.76 Pass-NOERRORS 9,225.00 8,886.21 9,325.00 9,023.82 1.02 3.33 72.86 689.83 -1,399.90 7.062 163.64 1.34 163.05 Pass-NOERRORS 9,238.08 8,892.90 9,350,00 9,048.08 1.08 3.50 72.35 694.53 -1,403.71 7.062 183.35 1.42 182.76 Pass-NOERRORS 11/3/2015 12:59:02PM Page 4 of 7 COMPASS 5000.1 Build 61 h« • BP 1 • b Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-18 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 09 MD Reference: 21 :18 11/3/1977 00:00 @ 54.Oousft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-18A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-18 WP03 Plus 500ft Offset ND Reference: Offset Datum Offset Design PB DS 09- 09-18-09-18A-09-18 WP03 Offset Site Error: 0.00 usft Survey Program: 620-CB-MAG-MS.8840-MWD Rule Assigned:NOERRORS Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +NIS +E1-W Hole Size Centre Distance Deviation lust') (usft) (usft) (use) (usft) (usft) (°) (usft) (usft) (usft) (usft) (usft) (usft) 8,850.00 8,562.93 8,850.00 8,56293 0.04 0.04 -39.00 600.78 -1,327.28 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 8,875.00 8,587.19 8,875.00 8,587.19 0.14 0.14 -39.00 60548 -1,331.09 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 8,900.00 8,61145 8,900.00 8,61145 0.24 024 -39.00 610.18 -1,334.89 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 8,925.00 8,635.71 8,925.00 8,635.71 0.27 0.27 -39.00 614.88 -1,338.70 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 8,950.00 8,659.96 8,950.00 8,659.96 0.31 0.31 -39.20 619.57 -1,342.51 3.875 0.00 0.32 -0.32 FAIL-NOERRORS,ES,SF 8,975.00 8,684.22 8,975.00 8,684.22 0.34 0.34 -39.99 62425 -1,346.35 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,000.00 8,708.34 9,000.00 8,708.34 0.37 0.37 -47.92 629.08 -1,350.82 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,025.00 8,732.09 9,025.00 8,732.09 0.41 041 -60.62 633.55 -1,357.17 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,050.00 8,75527 9,050.00 8,755.27 0.46 0.46 -69.43 637.44 -1,365.67 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,075.00 8,777.69 9,075.00 8,777.69 0.51 0.51 -75.72 640.70 -1,37622 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,100.00 8,799.15 9,100.00 8,799.15 0.57 0.57 -80.39 643.31 -1,388.76 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,125.00 8,819.47 9,125.00 8,819.47 0.64 0.64 -84.02 645.26 -1,403.17 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,150.00 8,838.50 9,150.00 8,838.50 0.72 0.72 -86.93 646.52 -1,419.32 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,175.00 8,856.06 9,175.00 8,856.06 0.81 0.81 -89.35 647.08 -1,437.10 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,200.00 8,872.00 9,200.00 8,872.00 0.91 0.91 -91.41 646.94 -1,456.34 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,225.00 8,886.21 9,225.00 8,886.21 1.02 1.02 -93.22 646.10 -1,476.89 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,250.00 8,898.55 9,250.00 8,898.55 1.14 1.14 -94.84 644.56 -1498.56 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,275.00 8,908.92 9,275.00 8,908.92 1.27 1.27 -96.31 642.35 -1,521.19 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,300.00 8,917.23 9,300.00 8,917.23 1.41 1.41 -97.69 639.47 -1,544.59 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,325.00 8,923.42 9,325.00 8,923.42 1.56 1.56 -98.99 635.96 -1,568.54 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,350.00 8,927.44 9,350.00 8,927.44 1.71 1.71 -100.25 631.83 -1,59286 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,375.00 8,929.24 9,375.00 8,929.24 1.87 1.87 -101.47 627.14 -1,617.34 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,400.00 8,929.04 9,400.00 8,929.04 2.03 2.03 -101.85 622.03 -1,641.81 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,425.00 8,927.48 9,425.00 8,927.48 2.20 2.20 -101.85 616.90 -1,66622 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,450.00 8,924.62 9,450.00 8,924.62 2.36 2.36 -101.85 611.80 -1,690.53 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,475.00 8,920.47 9,475.00 8,920.47 2.53 2.53 -101.85 606.74 -1,714.65 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,500.00 8,915.03 9,500.00 8,915.03 2.70 2.70 -101.85 601.73 -1,738.53 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,525.00 8,908.32 9,525.00 8,908.32 2.88 2.88 -101.85 59678 -1,762.10 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,550.00 8,900.36 9,550.00 8,900.36 3.05 3.05 -101.85 591.91 -1,785.29 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,575.00 8,891.17 9,575.00 8,891.17 3.22 3.22 -101.85 587.14 -1,808.04 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9600.00 8,881.06 9,600.00 8,881.06 3.39 3.39 -99.59 582.75 -1,830.48 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,625.00 8,870.91 9,625.00 8,870.91 3.57 3.57 -96.31 579.59 -1,853.10 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,650.00 8,860.81 9,650.00 8,860.81 3.75 3.75 -93.03 577.73 -1,875.89 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,675.00 8,850.79 9,675.00 8,850.79 3.94 3.94 -89.77 577.17 -1,898.78 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,700.00 8,840.86 9,700.00 8,840.86 4.13 4.13 -86.51 577.91 -1,921.71 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,725.00 8,831.07 9,725.00 8,831.07 4.33 4.33 -83.28 579.96 -1,944.62 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,750.00 8,821.43 9,750.00 8,821.43 4.53 4.53 -80.06 583.30 -1,967.44 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,775.00 8,811.98 9,775.00 8,811.98 4.73 4.73 -76.86 587.93 -1,990.11 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,800.00 8,802.68 9,800.00 8,802.68 4.93 4.93 -78.10 59324 -2,012.70 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,825.00 8,793.41 9,825.00 8,793.41 5.13 5.13 -81.33 597.38 -2,035.55 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,850.00 8,784.18 9,850.00 8,784.18 5.33 5.33 -84.55 60024 -2,058.60 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,875.00 8,775.02 9,875.00 8,775.02 5.54 5.54 -87.77 601.79 -2,081.81 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,900.00 8,765.95 9,900.00 8,765.95 5.75 5.75 -90.98 602.05 -2,105.10 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,925.00 8,757.01 9,925.00 8,757.01 5.96 5.96 -94.17 601.00 -2,128.42 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,950.00 8,748.20 9,950.00 8,748.20 6.17 6.17 -97.35 598.65 -2,15170 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 9,975.00 8,739.56 9,975.00 8,739.56 6.38 6.38 -100.51 595.01 -2,174.87 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,000.00 8,731.07 10,000.00 8,731.07 6.59 6.59 -103.69 590.08 -2,197.86 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,025.00 8,72260 10,025.00 8,722.60 6.80 6.80 -106.88 583.88 -2,220.54 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 11/3/2015 12:59:02PM Page 5 of 7 COMPASS 5000.1 Build 61 00.04,,,,, 11) d. `op Anticollision Report BAKER o' HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-18 Project: Prudhoe Bay ND Reference: Mean Sea Level Reference Site: PB DS 09 MD Reference: 21 :18 11/3/1977 00:00 @ 54.00usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-18A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-18 WP03 Plus 500ft Offset ND Reference: Offset Datum Offset Design PB DS 09- 09-18-09-18A-09-18 WP03 offset Site Error: 0.00 usft Survey Program: 620-CB-MAG-MS,8840-MWD Rule Assigned:NOERRORS Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Too[face+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +NI5 +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (risk) (°Iusft usft usft (usft)) (usft) (usft) (usft) 1 ) (usk) 10,050.00 8,714.17 10,050.00 8,714.17 7.01 7.01 -110.06 576.43 -2,242.86 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,075.00 8,705.80 10,075.00 8,705.80 721 7.21 -113.24 56774 -2,264.76 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,100.00 8,697.52 10,100.00 1697.52 7.41 7.41 -116.41 557.84 -2,286.16 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,125.00 8,689.35 10,125.00 8,689.35 7.61 7.61 -119.57 546.75 -2107.02 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,150.00 8,681.31 10,150.00 8,681.31 7.80 7.80 -122.72 534.51 -2,327.28 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,175.00 8,673.41 10,175.00 8,673.41 7.98 7.98 -125.85 521.15 -2,346.88 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,200.00 8,665.70 10,200.00 8,665.70 8.15 8.15 -12872 506.70 -2,365.77 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,225.00 8558.79 10,22500 8,658.79 8.32 8.32 -12872 491.68 -2,384.51 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,250.00 8,653.14 10,250.00 8,653.14 8.49 8.49 -128.72 476.45 -2,403.51 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,275.00 8,648.78 10,275.00 8648.78 8.66 8.66 -128.72 461.05 -2,422.71 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,300.00 8,645.71 10,300.00 8,645.71 8.84 8.84 -128.72 445.53 -2,44207 3.875 0.00 0.32 -0.32 FAIL-NOERRORS 10,313.00 8,644.63 10,313.00 8,644.63 8.94 8.94 -128.72 437.43 -2,452.17 3.875 0.00 0.32 -0.32 FAIL-NOERRORS,CC 11/3/2015 12:59:02PM Page 6 of 7 COMPASS 5000.1 Build 61 0 BP 0 Ir/iAl 1,0)bp Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 09-18 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 09 MD Reference: 21 :18 11/3/1977 00:00©54.00usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 09-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 09-18A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 09-18 WP03 Plus 500ft Offset TVD Reference: Offset Datum Reference Depths are relative to 21 : 18 11/3/1977 00:00 @ 54.00usft Coordinates are relative to:09-18 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:1.66° Ladder Plot 180- -- I I I I I 1 1 ' 1 1 -Ji • _J J ____J. J J __ 1 - I I cri 135 ---- 1 = • i I i 1 I I I ! 1 I I 9 1 1 C J J I 1 1 1 _- f6 I Y 1 1 RI Y I 1 0- 9 1 1 • 90 I 1 1 1 Ili 1 I 1 1 I N 1 1 I O J J J J J Q i 1 I 1 N 1 C 1 I 1 a) 45 I U I 1 / I J -----ILE-GNO_ __ J J 1 I 1 I ! I $ 09-01,09-01,09-01 V1 -)E- 09-19,09-19,09-19Y1 i - - 0•, ,09-34,09-34 V1 -1-- 9941,09-01A,09-01AWP01 VO -i-- 09-20,09-20,09-20411 I -46- 0934,09-34A109-34AV1 1 -4-- 09-612,09-02,09-02 V1 20009-21,09-21,09-AGN0 800 09-35,09-3159Me V4 12000 -A-- 09-02,09-02A,09-02AWP15 V0 -e- o9-/21,eas21,e91-ietpth(2000 usft/in) -4- 09-35,09-35A,09-35A V7 -8- 09-03,09-03,09-03 V1 -9E- 09-23,09-23,09-23 V1 -4- 09-37,09-37,09-37 V1 -A- 09-03,09-03A,09-03A VO $ 09-23,09-23A,09-23A V4 ner- 09-38,09-38,09-38 V1 - 09-03,09-03A,Plan#709-03AApprovedVO -A- 09-23,09-23APB1,09-23APB1V3 44E- 09-39,09-39,09-39 V1 -4- 09-04,09-04,09-04 V1 -e- 09-23,09-23APB2,09-23APB2V2 -9- 09-40,09-40,09-40 V1 -341- 09-04,09-04A,09-04A V2 -_- 09-26,09-26,09-26 V1 -9- 09-41,09-41,09-41 V1 -e- 09-05,09-05,09-05 V1 - 09-28,09-28,09-28 V1 -4- 09-42,09-42,09-42 V1 -a- 09-05,09-05A,09-05A V1 -6- 09-28,09-28A,09-28A V1 -e- 09-42,09-42A,09-42A V2 -II- 09-06,09-06,09-06 V1 $ 09-29,09-29,09-29 V1 -XE- 0942,09-42AP81,09-42APB1V2 -B- 09-11,09-11,09-11 V1 -9- 09-30,09-30,09-30 V1 -0- 09-45,09-45,09-45 V1 -e- 09-12,09-12,09-12 V1 -e- 09-30,09-30PB1,09-30PB1V1 -6- 0946,09-46,09-46 V1 -4- 09-13,09-13,09-13 V1 $ 09-31,09-31,09-31 V1 - 09-47,09-47,09-47 V1 -et- U9-14,09-14,U9-14 V1 -4- 09-31,09-JiA,U9-31AV1 -9 UPJ-4/,Uy-4/A,U9-4/AVU 11/3/2015 12:59:02PM Page 7 of 7 COMPASS 5000.1 Build 61 TREE= FMC GEN 411 \ LI-FAD= FMC SA NOTES:H2S READINGS AVERAGE 125 ACTUATOR= AXELSON 09-'1 8 ppm WHEN ON/ ON MI. WELL REQUIRES A SSSV OKB_ELEV= 4 BF.BEV= ? I i KOP= 4001' Max Angle= 20"@ 6232' 2148' (—7"CAM BAL-O SSSV NP,ID=5.937" Datum MD= 9094' ' Datum TVD= 8800'SS 13-3/8"CSG,72#,MN-80,ID=12.347" H 2713' Minimum ID =3.725" @ 8706' 4-1/2" OTIS XN NIPPLE 8603' —7"X 4-1/2"XO,D=3.958" 7"TBG,26#,L-80,.0383 bpf,D=6.276" —I 8603' < 8606' H9-5/8"X 4-1/2"BAKER MODEL 0 RCR TOP OF 7"LNR8638' C — I I 8706' H4-1/2"/2"OTIS XN NP,ID=3.725" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" — 8718' 8717' BAKER BAKSHEAROUT SUB / 8718' 4-1/2"WLEG,D=3.958" PERFORATION SUMMARY REF LOG:BHCS ON 11/16/77 8702' —{ELMD TT LOGGED 06/13/91 ANGLE AT TOP PERF:14°@ 8935' Note:Refer to Reduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 18 8935-8950 S 12/08/95 11/28/13 3-1/8" 4 8982-9002 S 04/06/84 11/28/13 2-1/2" 5 9015-9055 S 05/26/03 01/02/14 3-1/8" 4 9020-9038 S 06/01/91 01/02/14 3-3/8" 4 9050-9060 S 05/26/03 01/02/14 g 9093' H9-5/8"X 7'BAKER ECL PKR 3-3/8" 6 9070-9101 S 11/24/91 01/02/14 3-1/8" 4 9126-9142 5 02/16/78 01/02/14 3-1/8" 4 9170-9177 S 02/16/78 01/02/14 g 9146' H9-5/8"X 7"BAKER ECL PKR 3-1/8" 4 9186-9190 S 02/16/78 01/02/14 3-1/8" 4 9209-9218 S 09/02/85 01/02/14 3-1/8" 4 9228-9241 S 09/02/85 01/02/14 3-1/8" 4 9259-9267 S 09/02/85 01/02/14 3-3/8" 4 9276-9290 S 06/13/91 01/02/14 3-3/8" 6 9290-9292 S 06/01/91 01/02/14 7"LNR,29#,L-80,.0371 bpf,ID=6,184" ---I 9353' --J 9353' —j 7"BAKER V SET SHOE f1•wtt'1ftt 9371' —FBTD 9-5/8"CSG,47#,N-80,.0733 bpf,ID=8.681" H 9432' 44444444444444444441 ,444444444444444444444 TD — 9450' 0.............0.6. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/01/77 ORIGINAL COMPLETION 05/30/06 DTM WELLHEAD CX)IZR-CTIONS WELL: 09-18 06/01/91 LAST WORKOVER 02/04/14 ALMJM)COIL RESOUEEZZE PEI2FS(01/01/11 PERMT No:"1770390 12/21/00 SIS-SLT CONVERTED TO CANVAS AR No: 50-029-20259-00 01/10/01 SIS-LG REVISION SEC 1,T1ON,R15E,642"FSL&223'FWL 09/26/01 RN/TP CORRECTIONS _ 05/26/03 BJMTLP ADD PERF BP Exploration(Alaska) TREE= FMC GEN1 W�LHEAD= FMC • SA f NOTES:H2S READINGS AVERAGE 125 ACTUATOR = A 09-18A Proposed ppm WH 54' WHEN OENMI.NMI. WELLREQUIRESASSSV BF.ELEV= ? I [ KOP= 4001' Max Angle= 20`@ 6232' 2148' �}-I 7"CAM BAL-O SSSV NP,D=5.937" Datum MD= 9094' 1 O j (— — - PERFORAT8DN SUMMARY Datum TVD= 8800'SS REF LOG'BRCS ON 11/16/77 ANGLE Al TOP PERF:14'® 8935' Note,Refer to Production DB for historical pert data 13-3/8"CSG,72# P4-80,U=12.347' H 2713' I—SUE SPF MTERVAL Opn/Saz SHOT SO2 3-3/8' 18 8935-8950 S 12/08/95 11/28/13 i 3-1/8' 4 8982 -9002 S 04/08/84 11/28/13 1 2-1/2' 5 9015-9055 S 05/26/03 01/02/14 3-1/8' 4 9020-9038 S 08/01/91 01/02/14 Minimum ID =3.726" @ 8706' 3-3/8' 4 9050 -9060 S 95/26/63 x,1927„ p� 1-3r8' 6 9070-9101 S 11/24/91 01/02/14 4-1/2" OTIS XN NIPPLE 3-1/8' 4 9120 -9177 S 02/16/78 01/02/14 �L 3-1/8' 4 9170 ,9177 S 02/18/78 01/02114 3-1/8' 4 9186 -9190 S 02/16/78 01/02/14 3-1/8' 4 9209-9218 S 09/02/85 01/02/14 3-1/8' 4 9228-9241 S 09/02/85 01/02/14 3-1/8' 4 9259-9287 S 09/02/85 01/02/14 3-J/8- 4 9278-,9290 S 08/13/91 01/02/14 7"TBG,26#,L-80,-0383 bpf,D=6 276" -I 8603' _ / 3-378' 6 8290-x494 S 06/01191 01/02/14 8603' -17"X 4-1/2"XO,13=3.958' TOP OF 7'LW? - 8638' 1 86060 H9-5/8"X 4-1/2"BAKER MODE_D FKR 3.70"BKR DEPLOY SLV,ID = 3.00"@ 8,650'M D M 111outXN to 3.813"ID 8706' H4-1/2"OTIS XN NP,ID=3.725" 41/2"TBG,12.6#,L-80, .0152 bpf,D=3-958" H x71$' j 8717' -I4-112"BAKER BREAKOUT SlB 8718' H4-1,2"WLEG,D=3.958" 8702' H ELMD TT LOGGED 06/13/91 1/2"93`#STL 13CR-80 III 3-1/2'5(3-1/4"X0 @ -8872'MD 4 1/2"x7"BakerTTwhi3siDck@ 8,972'MD II 41 7"Posiset@ 9,000'MD •��. is I TD@ 10,313t- - RA TAG @ TBD 3-1/4"13C r-8 0 Liners. ti TD mi 9093' -19-5/8"X r BAKER ECL PKR 1 us -I 9146' 9-5/8"X 7"BAKER BCL PKFT—JS ilii ■ - 7"LW,29#,L-80, .0371 bpf,D=6.184" H 9353' —, III1 9353' -I"BAKER V SET SHOE 'Pt 41111.11111.9.11-1 9371' -PBTD 111111111111111111111 9-5/8"CSG,47#,N-80,.0733 bpf,D=8.681" 9432' .14...414.4614.4•64•4 .141.4.441114.........4 TD—� 0. 1.4.0.4.4.4.11.4.0, DATE REV BY COMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/01/77 ORIGNAL COMPLETION 05/30/06 DTM VVELLFEAD CORRECTIONS WELL 09-18 06/01/91 LAST WORKOVER _02/04/14 ALM_Y_JMD (OIL RESQUEEZE PEFFS(01/01/14 PERMT No: 1770390 12/21/00 SIS-SLT•CONVERTED TO CANVAS API No: 50-029-20259-00 01/10/01 SIS-LG REVISION SEC 1,T1ON,R15E,642"FSL&223'FWL 09/26/01 RN/TP CORRECTIONS 05/26/03 BJMTLP ADOFERF BP Exploration(Alaska) H i rrl °I LL I M , a 2.4 O m = o U _ w Sf I d n w r u. 9 y it, . H 'I m U x 2 2=.c mV v W f a E .v X il.1 . o e IIJP1L : :x .. 'CO oi —11 N ME g 1 1 i lin t--, ,.. oN c y g m L Y NH I rc Q _ 1 I! 111 o �1 �".".""" """ I'1 J — O RI0 - i111 Um "' _ a 11 11 z u I . n Q c 1 . e- 111 '111 d 111 a 2 . 1 a I1 1 'J > 1 1'0 lily II! O m 1 U C 7 . 0 U U 0 QI m _ 1 1111 IH U if $J �• _ • tll V rll E ' L J E E W -2, a 9 W 4 > e m U E f C‘ e O W a O I , I t ; Z > 2 rt U 0 ~ '' 111!)" I 11(r2 cn v m J =�c� Q 1 V 1 1 1 U 1 1 COii I ® mg c,`' 2i ;)'4` a mV g 1 m N. ,..„ fm 1.. v m ,_...., r .z I Iii 1n I a I : p h'IW1* i- :20 o°° I i� II 1/ Ir r 5 1 ¢ . ut c o p , 1 0il I; I : 1 • • Davies, Stephen F (DOA) From: Ciolkosz, Ryan R <Ryan.Ciolkosz@bp.com> Sent: Tuesday, November 17, 2015 8:38 AM To: Davies, Stephen F (DOA) Subject: RE: PBU 09-18A(PTD#215-201) Steve, 09-18A will not be pre-produced, besides maybe some flow back to clean the wellbore up, Let me know if you have any other questions Ryan Ciolkosz From: Davies, Stephen F (DOA) [mailto:steve.davies©alaska.gov] Sent: Friday, November 13, 2015 10:01 AM To: Ciolkosz, Ryan R Subject: PBU 09-18A(PTD #215-201) Ryan, Will the planned PBU 09-18A injection well be pre-produced for a period longer than 30 days, or will it be briefly flowed back for clean up only? Thanks, 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 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • TRANSMITTAL LETTER CHECKLIST WELL NAME: O l /l PTD: 0/S` Development v Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: r(1J`,{'� �,, POOL: /� GL.6 .. lel Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 0 • L Ta 0) 0) 0 a) 0- (f) U) 0 `o m . - C , ay Ni a:fi , CO a a7 O.. uWj .c a N. W' O. O p o co U, , o, c ° :. o. a c, U. ai v°' Cr gr m' .- co COQ U 4)' �� N, ••t-°, y a a O �� 4 O� L a) O Co o �, N W -O O N. -2, Q, m, 'O' 3, >O m ^' ate) ' �. O, W , Z O ° c ri ua °, Q E 6 o , 'E, E. a s ' M J O , N' O' , N. I'D'., , 03 c� p, , a� mi. N� �� gyp, Q o 0' a Oo o' a) , o O ii, O' 2. ao r a). W c) O, c c' a' v', aro a N ci a M, °� �i o o, O ¢ O. a)' Q' 4 0, CO' 0'' 3' a, $, •a), . :� a a) of - a) a m 0 D▪ co cc co t, d H, p, co, da co a m, c, @, $, , • 'a N; 3, 3 co. �, m m 3. >' C'i' -, , E. 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