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202-056
STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMIS ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing El Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Susp Well 0 Other:OA Cement Squeeze Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-056 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-23074-00-00 7. Property Designation(Lease Number): ADL 0028241 8. Well Name and Number: BRLS V-101 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,BOREALIS OIL 11.Present Well Condition Summary: 9Vr0 , _ ,....,,,k...�� E Total Depth: measured 9480 feet Plugs 9 measured feet MAR i K 03 1 01 6 true vertical 7135 feet Junk measured feet Effective Depth: measured 9367 feet Packer measured feet �r� true vertical 7025 feet Packer true vertical feet �? ,t Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 32-112 32-112 1490 470 Surface 2994 7-5/8"29.7#L-80 31 -3025 31 -2719 6890 4790 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner Perforation Depth: Measured depth: 8914-8930 feet feet 8930-8950 feet 8950-8960 feet 8960-8990 feet True vertical depth: 6590-6605 feet feet 6605-6624 feet 6624-6634 feet 6634-6662 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#L-80 - .2Q-8681 26-6371 Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): OA Surface :SCANETreatment descriptions including volumes used and final pressure: "" " 3 Bbls Methanol,23 Bbls 60/40 Methanol/Water,55 Bbls Fresh H2O w/F103&U067,48 Bbls Neat Class G Cement,30 Bbls Cement w/12 ppb Aggregate,5 Bbls MudPush,1050 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 650 0 978 1344 351 Subsequent to operation: Shut-In 40 360 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run El 16.Well Status after work: Oil Q Gas ❑ WDSPL El Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG El GINJ 0 SUSP 0 SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-157 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name y�Caattron,Garry R(Wipro)° Title PDC Principal Engineer Signature .0 1 (o)�C�� Phone +1 907 564 4424 Date 3/2/16 Form 10-404 Revised 5/2015 IrTt- Ai M 3/)1/1.6 RBDMS LL MAR 0 4 2016 Submit Original Only • • d w a 0 O O O O CO CO rn g,'C v o 0 U y o 0 0 0 0 � rnrno (s) (Lo cvco0 mN- cor-- cr)- N CA r-- f� CO N CO N- CO 1 1 1 1 1 H N N "- CO CO CO CO M N CO N CO CDC N N rCO CO O co co co co O) CO ✓ p 4-1 Qo r' N O CO C)> M CO N CO N CO __ • J m O 0 CO0 CO 0�0 000 J J J * N •N CA 1.6 RS c r N r O) O U _ eo CV N N ON M M Ca O 0)) - LU C co o) co O CO G) N O (D -J co O O O Ti 0000 U a u_ U U Z Z O O m O D D U a 0 F- • • o 73 ai E >� �- Q m o Q o m a > O a) 5' a) Cl_ N .c Q ai .c ,- O .c c w o N N E 0 �. ° o co 3 O ° Q o o ° 5 0) u 3 u) a) a ° r` tl M Q 'n c 3 0 3 O co ° O p a) cs m00O c — (n .� Ow m o Zm cs O cis cn II -0 w CD Y 0 • 'c SZ v) CD L 0- .N N j LO N CD L m E 0 N II a) ill a) E g Q v II L >,a E a) 'c o) O 2 'O ° Q N a) 7 Q D 'C � \- a) U NQ O U DN O ggO a) c U n3 ai a 5 co u > co o a y O o E o u, c o coo ai a a > > ) 3 a) Q U I _ di 'Es)k- a) Q L (n ai o 2 ©= c 3 — ° z O p n o -a L Q)O ` o) •(0 O m c a) 4 '� O 42 -w to O z ch 2 0 II co Y N p d w v c U) QLO c . • a) o L — L �` co co u� a) a) co O U o O05 a) -O U t Lm N V LO CC c1 ns O- O- N . 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"a �- a- d EH o � u- u) H * HH- a � EooaH * cou_ H > cu co m CO co CO CO CO ✓ r r r r r r co O o o CD o 0 N N N N N N N ✓ - NO I- co r r r r r r r N N N N N N N N • S N C � 0 b'' E a) Q CD c Q. cn 0 %— a o 5 d u_ N 0 Ce O CO Q. 0 is o rn o a) L L 0) t4 m �S c co co (1) Q m o E O LI- 0 U C 3 U C Cn c 2 I c a) a) c° o _cU a) d ,v, Biu E -0 a) L m co m (t) a) n 0UZU2 co O LC) CO O Lo m ' O M N " !HEE= 3.-118"5M CMI • SAFETY NOTES: WELLHEAD= 11-RAC ACTUATOR= NA V 1 grit 1 NTIAL KB.131 82.30' BE REV= 5360' KOP= 3W Max Angle= 57° 558T Datum PAD= 9011' Datum 1VD= 6600'SS 2206' —3-1/2.FES X NP,ID=2.813' '(10 7-5/8'CSG,29.7#,L-80,ID=6.875H 3023' -A GAS LFT MANDRELS ST WI tV V DEV TY FE VLV LATCH PORT DATE Minimum ID =2.813" @ 2206' 3 4141 3509 45 KBG2-9 COME NT 16 07/24/15 31/2" HES X NIPPLE 2 7062 5304 55 KBG2-9 DMY INT 0 07/16/13 - 1 8580 6281 29 KBG2-9 DMY 0 07/24/15 PERFORATION SUIMARY FEF LOG: BI-CS ON 04/25/02 ANGLE AT TOP PERF: 18*©8914' Nbte:Refer to Production DB for historical pert data SIZE SPF WTERVAL Opn/Sqz SI-10T SQZ 2-1/7 6 8914-8950 0 05/04/02 2-1/2" 6 8930-8990 0 06/22/11 8635' H3-1/2-BKR CMD SLUNG SLV,10=2.813" 8888. —BKR LOC SEAL ASSY.ID=2.992' 5-lir CSG,15.5#,L-80,BTC, =4.950' H 8656' 8888. 3-1/2'TBG,9.24,L-80,137-M,.0087 bpf, =2.992" — 8859. HTOP OF BKR PBR,ID=4.00' 4-3/4'X 3-1/7 CSG X0, =3.000" — .16-14 8678. BTM OF 3-1/7 BKR SEAL ASSY. ID=3.00' 8698' H3-1/2"I C.,X NE,ID=2.813" r 8718' —3-1/2"FES X NED=2.813" 8819' —20'PUP JT W/RA TAG 9256' —20'PUP JT W/RA TAG PBTD H 636T •••••••••• 0.0•••••.0 3-1/7 CSG,9.24,L-80,ID=2.997 3467 1411.6.14 DA lh REV BY COL043.1TS DATE REV BY COW.43.4TS BOREALIS UNIT 04/29/02 TWA/KK ORIGINAL COMPLETION 06/26/11 11W/PJC A DPERF(06/22/11) WELL V-101 05/04/02 JIDMICK DR3RFS 08405/13 WEGJIC SET I3X PLUG/GLV(70(07/16/13) pErogr No:. 020560 04/10/03 DRS/TP TVD/M)CORRECTIONS 02/12/15 JTG/JW)GLV GO(02/10/15) AR No: 50-029-23074-00 1W29/03 JCPV/ILH GLV(70(10/04/03) 08/12/15 13.1K/JM)GLV CJO&FU_LEI)PLUG(07/24/15) SEC 11,T11N,R11E,468'RI_&1877'Fa 01/27/04 JUMP'GLV GO 12/08/05 KDC/RIC GLV GO BP Exploration(Alaska) ti OF T4, 0.,1%%i s, THE STATE Alaska Oil and Gas ���-►,"s���, of L A S KA Conservation Commission ' 't' iT 4_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 111014,7� Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov 05 r_004EtI a L 1 `L Jessica Sayers Well Integrity Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 cQoA"0 S6 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, BRLS V-101 Sundry Number: 315-517 Dear Ms. Sayers: 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 I. Foerster Chair DATED this day of September, 2015 Encl. RBDMS4, SEP 2 2 2015 STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMMAPPLICATION FOR SUNDRY APPRO S 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 z Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 'j V0"Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ • Repair Well ®Re-enter Susp Well 0 Other OA Cement Sqz fir®• it e))I cc. 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 202-056. 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development Ea 99519-6612Stratigraphic 0 Service El6. API Number: 50-029-23074-00-00 • 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 Nom BRLS V-101 • RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028241' PRUDHOE BAY,BOREALIS OIL• A U G 2 4 2015 11. PRESENT WELL CONDITION SUMMARY p7S 7 /8 Li Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): AO e 9480 ' 7135 • 9367 7025 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"91.5#H-40 29-109 28-108 1490 470 Surface 2994 7-5/8"29.7#L-80 28-3023 28-2717 6890 4790 Intermediate Production 8662/774 5-1/2 x 3-1/2 26-9462 26-7117 7000/10160 4990/10530 Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8914-8990 6589.94-6662.24 3-1/2"9.2#L-80 L-80 23-8678 Packers and SSSV Type: No Packer Packers and SSSV MD(ft)and ND(ft): No Packer No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal [' 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development ® - Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ® • Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sayers,Jessica Email Jessica.Sayers@bp.com Printed Name Sayers,Jessica Title Well Integrity Engineer Signature ) Phone +1 907 564 4281 Date v 1114/6--COMMISSION USE ONLY Conditions of appro Ili ify Commission so that a re entative may witness Sundry Number: 316 — 5 I Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Spacing Exception Required? Yes 0 No Q' Subsequent Form Required: Jo --40 4 / APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: 9-4/...I - VTI-- 4/6'-) i5 ORIGINAL RaDMS 4,1EP 222015 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate , Vis-' /'.fA 8z�.�c • by i • • V-101 OA Cement Squeeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: James Shrider (907) 564-4755 History V-101 is a vertical, frac'd producer in the Kuparuk formation. V-101 was completed in 2002 and has been a competitive producer. In Octoberr 2012 bubbling was observed from the conductor. The OA pressure was then bled to 0. The bubbling then stopped. V-101 was shut in and classified as Non- Operable in January 2013. Further investigation confirmed a leak in the SC at 93" below the top of the conductor. V-101 was scheduled for a SC Excavation program to weld and fix the leak in May 2015. This was delayed, while a WeIlLock treatment was performed by pouring well lock into the Conductor to try and fix the leak. In July 2015 the WeIlLock treatment was performed but leaking persisted from the SC persisted. The proposed plan forward is to cement the OA to seal off the leak. Current Status The well is currently classified as "Non Operable" by BP due to the OA x Conductor leak. The well is therefore currently shut-in until the leak is fixed. Objective The objective of this job is to cement the OA (7-5/8" x 5-1/2") annulus and make this well operable. Cement will be pumped down the OA from surface in two stages (if needed). The goal is to have cement in the OA from the 7-5/8" casing shoe to surface. Any voidage in the OA left after the cement jobs will be filled/squeezed with well lock or Squeezecrete. Procedural steps Fullbore 1. Establish injectivity rate and pressure down the OA with diesel. Cementers 1. RU to the OA. 2. Pump enough Class G cement to fill OA to surface, SI and allow cement level to reach equilibrium. 3. WOC to build strength. 4. Pump a second cement job to refill OA to surface (if needed). Special Projects 1. WOC to build strength. 2. Strap the TOC in the OA. 3. Fill and squeeze the remaining void in the OA with well lock or squeezecrete. DHD 1. MITOA to 1200 psi. Tom= 3-1/8"5MCAN WELLHEAD= 11"FMC V-1 0 1 SAFETY NOTES: ACTUATOR= NA N 11AL KB.ELE u 8230' BF.ELEV= 53.80' KOP= 300' Max Angie= 57"@ 5587' imp 3 • Datum MD= 9011' / Datum TVD= 6600'SS ' —31/2"HESXMP,0=2.813' } 2.7 7-5/8"CSG,29.7#,L-80,ID=6.875" H 3023' Ha GAS LFT MADS ST M) TVD DEV TYPE VLV LATCH PORT GATE Minimum ID=2.813"@ 2206' 3 4141 3509 45 KBG2-9 DONE Nr 16 07124115 3-1/2" HES X NIPPLE 2 7062 5304 55 KBG2-9 DAY Nr 0 07/16/13 1 8580 6281 29 KBG2-9 DW NT 0 07/24/15 PERFORATION SUMMARY REF LOG: BRCS ON 04/25/02 ANGLE AT TOP PERF: 18"@ 8914' Note:Refer to Roduction D6 for historical perf data SIZE SPF INTERVAL Opn/Sgz SEDT SQZ 2-1/2" 6 8914-8950 0 05/04/02 2-1/2" 6 8930-8990 0 06/22/11 8638' —3-1/2"BKR CND SLIDING SLV,D=2.813" 5-1/2"CSG,15.5#,L-80,BTC,D=4.950" H $836' 86w" —BKR LOC SEAL ASSY,D=2.982' 3-1/2"TBG,9.2#,L-80,BT-M,.0087 bpf,D=2.992" 8659• $66$' —TOP OF BKR PBR ID=4.00' 4-3/4"X 3-1/2"CSG XO,D=3.000' H 8687' 1-716:—.17w _BTM OF 3-117 BKR SEAL ASSY,ID=3.00' I »----� 8698' I—3-1/2"NES X NP,D=2.813" ' I I 871W j—3.1/2"I IM X NP,D=2.813" 8819' 1—20'PUP JT IN/RA TAG �--� 9266' 1—20'PUP JT Wt RA TAG PBTD I.or*11**14 .�. 011..4 3-1/2'CSG,9.24,L-80.D=2.992" — 9467 i 1t 4 a•• DATE REV BY OOM ENTS RATE REV BY COMLENTS BOREALIS UM' 04/29/02 TWA/KK ORIGINAL COMPLETION 06/26/11 PJC ADPERF(06/22/11) WE.,L•V-101 05/04/02 JOM'KK ADPERFS 06/05/13 VEE/JM]SET PX PLUG/GLV GO(07/16/13) PERMIT No:`2020560 04/10/03 CRS/TP TVD/!VD CORRECTIONS 02/12/15 JTG/JM)GLV GO(02/10/15) AA No: 50-029-23074-00 10129103 JCNYILH GLV GO(10104/03) 08/12/15 RJK/JMD GLV C/O&PULLED PLUG(07/24/15) SEC 11,T11N,R11E,468'FM_&1877'FEL 01/27/04 .LMTLP GLV GO 12/08/05 KDCYPJC GLV GO BP Exploration(Alaska) 2 STATE OF ALASKA , ALASKA OIL AND GAS CONSERVATION COMM' N REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Rednll ❑ Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other:Welllock Treatment m 2 Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-056 3. Address' P O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23074-00-00 7. Property Designation(Lease Number): ADL 0028241 8. Well Name and Number BRLS V-101 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools' PRUDHOE BAY,BOREALIS OIL 11.Present Well Condition Summary: RECEIVED Total Depth' measured 9480 feet Plugs measured None feet 8 true vertical 7135 feet Junk measured None feet AUG 1 2015 Effective Depth: measured 9367 feet Packer measured None feet r� true vertical 7025 feet Packer true vertical None feet AG C C Casing: Length: Size: MD: TVD: Burst' Collapse' Structural Conductor 80 20"91 5#H-40 29-109 29-109 1490 470 Surface 2994 7-5/8"29.7#L-80 28-3023 28-2717 6890 4790 Production 8662 5-1/2"15.5#L-80 26-8687 26-6377 7000 4990 Production 774 3-1/2"9.2#L-80 8687-9462 6377-7117 10160 10530 Liner Perforation Depth: Measured depth: 8914-8930 feet 8930-8950 feet 8950-8960 feet 8960-8990 feet True vertical depth: 6590-6605 feet 6605-6624 feet 6624-6634 feet 6634-6662 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9 2#L-80 23-8678 23-6368 Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 28'-3023' Treatment descriptions including volumes used and final pressure: 40GALS WELLLOCK B SatA 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation' 142 2028 874 32 1602 Subsequent to operation: 986 100 1290 1368 369 14.Attachments:(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations m Exploratory 0 Development I1 Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil fv7 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-142 Contact Summerhays,Nita M(WI-R0Technologies) Email Nita.Summerhays@bp.com Printed Name Su`merhays,Nita IPRO Technologies) Title Petrotechnical Data Manager Signat r- / ":j�jJ/,i , ,_ - ,i Phone +1 907 564-4035 Date 08/18/2015 _�— Form 10-404 Revised 5/2015 V/f'e, I/�// /f�� 9/2.,,,' RBDM nal�rJ� 1 9 2015 Daily Report of Well Operations BRLS V-101 ACTIVITYDATE SUMMARY T/I/O = SSV/170/0+. Temp= SI. Remove gravel from conductor(Wellock). AL SI @ casing valve, ALP = 1700 psi. Installed heater in wellhouse, tree cap bled to 0 psi. Collected gravel sample from conductor. Marking on SH @ 9 Oclock indicates SC leak is @ 8 Oclock 61"from top of conductor. The cellar is 46"to the floor grating&has spray in liner. The bottom of the flutes are 4 3/8"above the top of the conductor. 20"conductor. Strapped the conductor @ 54"deep. Frozen bottom in conductor. Outer wall of OA and Inner wall of conductor appear to be fairly clean. 3/30/2015 SV, WV, SSV= Closed. MV= Open. IA&OA= OTG. 16:00 T/I/O= SSV/170/0+. Temp= SI. Remove gravel from conductor(Wellock). AL SI @ casing valve, ALP = 1700 psi. Heater installed in wellhouse, tree cap bled to 0 psi. Used hotsy pressure washer and cusco to achieve a depth of 100"in conductor still gravel. Took 3 videos. 4/1/2015 SV, WV, SSV= Closed. MV= Open. IA&OA= OTG. 16:00 T/I/O = SSV/320/0. Temp= SI. Water Wash Conductor(Pre Wellock Treatment). AL SI @ CV. ALP= 1970 psi. Used Hotsy pressure washer to wash down casing and conductor, sucking water returns with Kusco. Sprayed Musol on washed surface. Repeat conductor wash. 4/1/2015 **Continued on 04-02-15 WSR** **Continued from 04-02-15 WSR** Water Wash Conductor(Pre Wellock Treatment). Performed hot water wash on conductor. Soaked conductor and casing with Musol and rinsed. Pumped N2 down OA and @ 6 psi heard leaking gas down in conductor. Used intrinsically safe video camera on a measuring stick to record leak depth at—93". Gravel in bottom of conductor —100". FWHPs= SSV/320/0. 4/2/2015 SV, WV, SSV= C. MV= 0. IA, OA=OTG. NOVP. 0500 T/I/O= SSV/320/0. Temp= SI. Water Wash Conductor(Pre Wellock Treatment). AL SI @ CV. ALP = 1970 psi. Job postponed due to hot water plant swapping out heat exchanger, unable to get water. SV, WV, SSV=C. MV=0. IA, OA=OTG. 13:45. 4/2/2015 T/I/O = SSV/880/0. Temp = SI. Power wash conductor(Pre Wellock). AL SI @ casing valve= 880 psi. DELAY due to equipment availability. 4/13/2015 SV, WV, SSV= C. MV=0, IA, OA= OTG. 15:30. T/I/O= SSV/1420/0. Temp= SI. Pressure Wash Conductor(Pre Wellock). AL SI @ casing valve = 1420 psi. Used Hotsy and cusco to water wash and remove material in conductor. Hit cement in conductor, from top of conductor to cement = 112". Took video and saw cement. Heater removed from well house. See log for details. SV, WV, SSV=C. MV=0. IA, OA= OTG. 18:00 hrs. 4/14/2015 T/I/O= SSV/1500/0. Temp= SI. Eval surface casing (pre Wellock). AL SI @ casing valve, ALP = 1700 psi. Took multiple videos of SC. Pumped 5 gallons red dyed diesel into OA and only saw returns from previously known SC leak point @ 5 o'clock position 93" below top of conductor(from top of conductor to bottom of OA casing valve=21"). Rigged up N2 and evacuated fluid from OA taking returns in conductor. While fluid was coming out of known leak, could also hear gas coming from higher leak on SC reported on 7/7/13. Final WHPs= SSV/1500/0. 4/16/2015 SV, WV, SSV= C. MV= 0. IA, OA=OTG. 14:00 hrs. 1600/1700/0. Temp= SI. Apply BakerLok to SC leak(SC leak). AL SI @ casing valve, ALP= 1700 psi. IA FL near surface. Applied Bakerlok over SC hole @ 93" below top of conductor or 114" below bottom of OA casing valve @ 5 o'clock position. While monitoring with camera could see Bakerlok bubble. Bled IAP and ALP to 0 psi and held open bleed on OA while Bakerlok sets up. Bleeding IAP and holding open bleed on OA mitigated Bakerlok bubbling. Held open bleed for 9.5 hrs. 5/7/2015 ***JOB CONTINUED ON 5/8/15 WSR*** Daily Report of Well Operations BRLS V-101 ***JOB CONTINUED FROM 5/7/15 WSR*** Apply BakerLok to SC leak(SC leak). Continued open bleed on OA for 6 hrs(15.5 hrs total). Job complete. Final WHPs= 0/8/0. 5/8/2015 SV, WV&SSV=C. MV=O. IA&OA=OTG. 0630 hrs. T/I/O= SSV/8/1. Temp= SI. Load OA w/diesel (SC leak). AL SI @ lateral and casing valve,ALP = 1700 psi. Lowered flashlight on rope to see bottom of conductor is dry and no wet spots on SC. Bled IAP to 0 psi in 1 min (gas). Opened OA needle valve and OA bled to 0 psi in 10 seconds. Pulled bull plug from OA casing valve. Inserted 1/4"hose through casing valve and into void. pumped 10 gallons diesel into OA to fill. Re-installed OA bull plug. Monitored 1 hr. Bottom of conductor still dry and no wet spots on SC. Job complete. Final WHPs= SSV/0/0. 5/8/2015 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 16:00 hrs T/I/O= SSV/1/0. Temp= SI. Bleed IAP &OAP to 0 psi(pre welllock). AL SI @ casing valve (1700 psi). IA FL near surface, OA FL @ surface. IAP decreased 7 psi, OAP unchanged overnight. Bled IAP from 1 psi to 0 psi in 5 sec. Monitor 30 min. WHP's& FL's unchanged. Bottom of the conductor is dry w/no wet spots. Final WHP's= SSV/0/0. 5/9/2015 SV, WV, SSV= C. MV= 0. IA, OA=OTG. 0930. T/I/O= SSV/0/0. Temp= SI. WHP's(pre wellock). AL SI @ casing valve(1700 psi). WHP's unchanged overnight. 5/10/2015 SV, WV, SV= C. MV= 0. IA, OA= OTG. 1220. T/I/O = SSV/0/0. Temp= SI. WHP's(Pre Wellock). AL SI @ casing valve (1840 psi). 5/11/2015 SV, WV, SSV= C. MV= O. IA, OA=OTG. 1430 hrs. T/I/O = SSV/0/0. Temp= SI. WHP's(pre Wellock). AL SI @ casing valve,ALP = 1840 psi. Did not get TP due to nature of call out. AFE sign hung on tree. 5/12/2015 SV, SSV= Closed. WV= LOTO'ed. MV= Open. IA&OA= OTG. NOVP. 03:40 T/I/O= SSV/0/0. Temp= SI. WHPs (Pre Wellock) Bleed OA if needed. AL SI @ casing valve. ALP= 1840 psi. 5/13/2015 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 0940 hrs. T/I/O = SSV/0/14. Temp= SI. Install heater in cellar(Wellock). AL SI @ casing valve (1730 psi). Installed heater in cellar. Door open&Bled tree cap bled to 0 psi. 5/31/2015 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 0030. T/1/0= SSV/0+/10. Temp= SI. Vac out conductor(Wellock). ALP= 1740 psi, SI @ casing valve. Heater installed in cellar. Cellar has spray-in liner. Vac'd out-17"of fluid from conductor& -1 bbl water from cellar. Above SSV @ 0+ psi. Doors left open. 6/2/2015 SV&SSV=C. WV=LOTO. MV=O. IA&OA=OTG. 1420 hrs. T/I/0 = SSV/0/0. Temp= SI. Measure subsidence. AL SI @ casing valve(1740 psi). Pipes are buckling the backing on wellhouse. Centralizer is 4.5"above top of conductor. 2"gap between VSM &pipes. Cellar has spray in liner. 6/4/2015 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 0010 T/1/O= SSV/0+/13. Temp= SI. Assist WellLock treatment(WellLock). ALP= 1740 psi, SI ©casing valve. Cellar has spray-in liner. Heater installed on conductor. Above SSV @ 0+ psi. Vac'd out -10"of water from conductor. Bled OA to 0 psi (all gas)to slop tank in about 5 secs&held open bleed throughout remainder of work. Treated conductor w/20 gals WellLock. Maintained open bleed&monitored for 5 hrs 45 mins. SI OA bleed&monitored for 15 mins. OAP increased to 0+ 6/6/2015 psi. Job complete. Final WHPs= SSV/0+/0+. T/I/0=SSV/5/5. Temp= SI. Eval Post WELLOCK treatment. (WELLOCK). Centralizer(flutes) is -4.5"above SC ring, Hard bottom in SC is 104"with 9"of fluid on top of hard bottom. Heaters in well house, tree cap is @ 0 psi. Cellar has spray in liner with -20 gallons of water. 6/12/2015 SV, WV&SSV= C. MV= O. IA&OA= OTG. NOVP. 01:15. Daily Report of Well Operations BRLS V-101 T/I/O = SSV/0/0+. Temp= SI. Strap FL in conductor and Vac out, Video SC repairs(Pre Wellock treatment). Tagged hard bottom of conductor @ 97"at multiple spots with strap stick. 13"of fluid din conductor covering Bakerlok patch. Vac'd fluid out. Used camera to see BakerLok patch is above Wellock 2"-3". Could not see any active leaks or runs of fluid anywhere from SC. Made !several attempts to wipe excess diesel off BakerLok patch with absorb. Re-applied BakerLok over previous patch and installed heater in wellhouse to help Bakerlok cure. Treecap bled to 0 psi, wellhouse doors left open. 6/14/2015 SV, WV, SSV= C. MV= O. IA, OA=OTG. 14:00 hrs. T/I/O = SSV/0/0+. Temp= SI. Strap FL in conductor and Vac out, (Pre Wellock treatment). Tagged hard bottom of conductor @ 97"at multiple spots with strap stick. —7"of diesel in conductor @ bakerLok Bakerlok patch with some bubbling. Vac'd fluid out. Used musol and water to clean SC x conductor. Installed heater on conductor and tree cap was bled to 0 psi from SSV up, wellhouse doors left open. SV, WV, SSV= C. MV=O. IA, OA= OTG. 17:00 6/20/2015 T/I/O = 0/6/3. Temp= SI. Cellar prep(collect conductor sample and vac out conductor). AL SI @ casing valve, ALP= 1760 psi. Removed heater. Bled OAP to 0 psi in 10 seconds. Strapped fluid 'in conductor at 1"and collected sample of oily water. Vaced out conductor and poured —1"of Musol in the conductor to clean the top of the Wellok. 6/21/2015 SV, WV, SSV= C. MV=O. IA, OA=OTG. 16:00 T/I/O = SSV/4/5 Temp =SI. WHPs(Eval fluid in conductor). AL SI @ casing valve,ALP = 1760 psi. Strapped fluid in conductor @ 4". OAP increased 5 psi since 6/21/15. 6/24/2015 SV, WV, SSV= C. MV=O. IA, OA=OTG. 10:00 T/I/O = SSV/4/5 Temp= SI. Wellock treatment AL SI @ casing valve, ALP = 1760 psi. Strapped fluid in conductor @ 5". Hold open bleed on OAP. Circulate conductor with — 30 bbls of 160°water to warm up. Heater installed on conductor treecap bled to 0 psi. 13:00 hrs halliburton arrive conductor temp @ bottom = 103°. Poured 20 gallons of wellock down conductor using funnel and hose filling from bottom up. Top of wellock to top of conductor @ 12 oclock position is 77"@ 15:00 hrs. Holding open bleed for 24 hrs While maintaining 85°to 120°. conducted well control!drill 6/26/2015 SV, WV, SSV=C. MV=O. IA, OA=OTG. 15:00 T/I/O=SSV/4/0. Temp=SI. Assist with Wellock. AL SI @ casing valve,ALP = 1760 psi. Held open bleed on OA for 5.5 hrs tell midnight. 6/26/2015 **WSR continued on 06-27-2015. **WSR continued from 06-26-2015. T/I/O =SSV/4/0. Temp= SI. Assist with Wellock. AL SI @ casing valve,ALP= 1760 psi. Held open bleed on OA for 24 hrs. 6/27/2015 ***JOB CONTINUED ON 6/28/15 WSR*** ***JOB CONTINUED FROM 6/27/15 WSR*** Hold open bleed on OA&monitor WH temps (WeIlLock). Heater installed in wellhouse. Maintained open bleed on OA&monitored WH temps throughout 6/28/2015 shift. 2nd stage of wellock complete @ 14:00 hrs, hold open bleed for next 24 hrs. ***JOB CONTINUED FROM 6/27/15 WSR*** Hold open bleed on OA&monitor WH temps (WeIlLock). Heater installed in wellhouse. Maintained open bleed on OA&monitored WH temps throughout shift. 2nd stage of wellock complete @ 14:00 hrs, hold open bleed for next 24 hrs. 6/28/2015 ***WSR continued on 06-29-2015. ***JOB CONTINUED FROM 6/28/15 WSR*** T/I/O=SSV/14/0. Temp =S1. Hold open bleed on OA&monitor WH temps(WellLock). AL SI @ casing valve, ALP= 1760 psi. Heater installed in wellhouse. Maintained open bleed on OA& monitored WH temps throughout shift. 2nd stage of wellock complete @ 14:00 hrs, hold open bleed for next 24 hrs. Conductor started smoking called DSO, WIE, 5104, FIRE DEPT, evac to pad entrance, stand by. discolored. Continue to monitor. 6/29/2015 ***JOB CONTINUED ON 6/30/15 WSR*** Daily Report of Well Operations BRLS V-101 ***JOB CONTINUED FROM 6/29/15 WSR*** Hold open bleed on OA&monitor WH temps (WellLock). Held open bleed on OA&monitored conductor/WellLock temps throughout shift. Vac truck vac'd out 23.4 bbls of fluid out of the cellar. 6/30/2015 ***Job continued on 07-01-15 AWGRS WSR*** ***JOB CONTINUED FROM 6/30/15 WSR*** Hold open bleed on OA&monitor WH temp (WellLock). AL SI @ CV. ALP =660 psi. Held open bleed on OA& monitored conductor/WellLock temp throughout shift. SI open bleed on OA @ 1600 per WIC. OAP unchanged in 30 min. FWHPs= SSV/12/0. 7/1/2015 SV, WV, SSV= C. MV= O. IA, OA= OTG. NOVP. 1630 T/I/O = SSV/17/0. Temp= SI. WHPs. (Post Well lock). OAP unchanged since day shift(-7 hrs). 7/2/2015 SV, WV, SSV= C. MV= O. IA&OA=OTG. 00:45 T/I/O = SSV/17/0. Temp=SI. WHP's(Wellock Sample from conductor). Wellock samples taken from conductor, all around. Discolored Wellock taken from the side of the conductor @ 5 o'clock position. Hollow void from the 4 to 7 o'clock positions depth =—2.5'funneling down to to the 3 o'clock circ port. 7/2/2015 SV, WV, SSV=C. MV= O. IA, AO =OTG. 1000. T/I/O= SSV/27/0. Temp= SI. Strap OA FL. Removed bull plug from OA casing valve to strap for FL. Was unable to obtain FL due to residual grease in void. 6" below the OA port was the maximum obtainable depth reached. (see log for details). 7/3/2015 SV,WV,SSV= C. MV= O. IA, OA= OTG. T/I/O = SSV/40/5. Temp= SI. IA&OA FLs. (APE request). ALP= 1670 psi, AL SI @ casing valve. IA FL near surface. OA cemented to surface. 7/9/2015 SV, SSV= C. WV= LOTO. MV= O. IA&OA= OTG. 00:30 T/I/O=S1/80/5. Bleed OA down to 0 PSI. Monitor OA for 1 hour to verify no flow(PASSED). Remove 2" FMC OA Valve. DHD Straped OA for Fluid. Set VR plug with T-Bar. Install 2" FMC OA Valve. Torque flange to API SPECS. P/T Valve to 300 low, 3500 high for 5 min each (PASSED). Pull VR Plug. Install tapped blind flange. Torque to API SPECS. P/T Flange to 2500 PSI (PASSED). SEE 7/11/2015 LOG FOR DETAILS. RDMO ***JOB COMPLETE***Final T/I/O=S1/80/0. T/I/O = SSV/80/0. Temp= SI. OA LDD (Eval Wellock). AL SI @ casing valve(1700 psi). Valve crew removed OA casing valve. Strapped OA fluid level @ 3' 3"from the bottom lip on the casing. Unable to pass below 43' without hitting a solid bottom. FWP's SSV/80/0. 7/11/2015 Valve crew in charge of wellhead valves upon departure. 1800 hrs. T/I/O = SSV/40/4. Temp= SI. MIT-OA to 1200 psi FAILED (Eval Wellock). AL SI @ CV. ALP = 1700 psi. Used Suitcase Pump with 100L(26.5 gallons) DSL to increased OAP from 4 psi to 722 psi. Fill up volume on OA was 20L(5.25 gallons). Pressure began to fall off during pumping. Used 40.2L(10.6 gallons) DSL in 30 min to establish LLR of 1.34L/min (.35 gpm)@ 700 psi. Pumped a total of 140.2L(37 gallons) DSL down OA. OAP decreased 280 psi in 30 min after pump SD. Bled OAP to 0 psi (46L/ 12.2 gallons). OAP increased 2 psi in 30 min. Tags hung. FWHPs= SSV/ 40/2.. 7/12/2015 SV, WV, SSV= C. MV= O. IA, OA=OTG. NOVP. 1730 T/l/O=SSV/0/0, Temp=Sl. PPPOT-T(PASS), PPPOT-IC (PASS). post well lock. PPPOT-T: Stung into test port(100 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 300 psi in 15 min. Bled void to 0 psi. Torqued LDS to 450 lb/ft. Pressured void to 5000 psi, lost 100 psi in 15 min, lost 25 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port(0+ psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 7/12/2015 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Daily Report of Well Operations BRLS V-101 T/I/0=SSV/40/6. Temp= SI. WHP's. (Eval SC Leak). ALP @ 1700 psi &SI @ IA casing valve. No fluid can be see in the SC post Failed MIT-OA. No change in IAP &OAP increased 4 psi overnight. Job Complete. 7/13/2015 SV, WV&SSV= C. MV= 0. IA&OA= OTG. NOVP. 14:55 ***WELL S/I ON ARRIVAL***(JOB SCOPE) R/U SICKLINE EQUIPMENT AND P/T 7/23/2015 ***CONTINUE ON WSR 7-24-15*** ***CONTINUE FROM 7-23-15*** (GLV C/O) SET WHIDDON @ 8,685' SLM PULLED INT-FLWSLV STA#1 FROM 8573' SLM/8580' MD (btm latch broken off, missing btm pavking stack) PULLED INT-DGLV STA#3 FROM 4129'SLM/4141' MD, SET STA#3 INT-DOME GLV(ports 16/64", tro 1300), STA#3 @ 4,129'SLM/4,141' MD RAN 1" POCKET POKER TO STA#1 @ 8573' SLM/8580' MD (tattle tail pins sheared, indicating clear pocket). SET ST#1 INT-DGLV @ 8,580' MD. PULLED 3-1/2"WHIDDON C-SUB FROM 8,698' MD (ST#1 int-latch assembly from int-flwslv in catcher). PULL 2.813" PX PLUG FROM 8,698' MD. 7/24/2015 ***WELL S/I ON DEPARTURE*** PAD OP NOTIFIED ***CONTINUE FROM 7-23-15*** (GLV C/O) SET WHIDDON @ 8,685' SLM PULLED INT-FLWSLV STA#1 FROM 8573'SLM/8580' MD (btm latch broken off, missing btm pavking stack) PULLED INT-DGLV STA#3 FROM 4129' SLM/4141' MD, SET STA#3 INT-DOME GLV(ports 16/64", tro 1300), STA#3 @ 4,129' SLM/4,141' MD RAN 1" POCKET POKER TO STA#1 @ 8573' SLM/8580' MD (tattle tail pins sheared, indicating clear pocket). SET ST#1 INT-DGLV @ 8,580' MD. PULLED 3-1/2"WHIDDON C-SUB FROM 8,698' MD (ST#1 int-latch assembly from int-flwslv in catcher). PULL 2.813" PX PLUG FROM 8,698' MD. 7/24/2015 ***WELL S/I ON DEPARTURE***PAD OP NOTIFIED T/I/O= SSV/40/3. Temp=Sl. Strap depth of Wellock in Conductor for Fill volume. GLT is connected, SI @ casing valve. GLTP=1700 psi. Wellock is vacated from the 4:00-8:00 position. Bottom of Wellock varies from 28'to 40"at those positions. 7/25/2015 SV,WV,SSV=Closed. MV=Open. IA,OA=OTG. (1630 hrs) T/I/O=480/1640/100. Temp=68*. Assist OPs w/POP Open bleed OA. (wellock). AL is on line. Monitor OAP during POP. OAP rapidly increased to 647 psi (40 min), then decreased. Bubbling fluid noticed in conductor at 494 psi. Bubbling is coming from the 5:00&8:00 positions. Fluid is also coming out of plastic bull plug at the 3:00 position (Bull plug was pushed out by the Wellock reaction). Held open bleed, with well on line, for x hrs. Fluid sporadically flowing into BT. Maintained open bleed on OA for 12 hrs. SI bleed for BUR. 7/26/2015 AWGRs continued on 7/27/15. AWGRs continued from 7/26/15. Assist Ops w/POP. OA SI for BUR. Monitored WHPs&temp during well tests until 1700 hrs. SI &monitored WHPs for 1 hr. Job complete. See log for details. Final WHPs= 1170/1620/0. 7/27/2015 SV&WV=C. SSV& MV=O. IA&OA=OTG. 1815 hrs. T/I/O = 1500/1640/vac. Temp= SI. WHPs(post wellock). AL open @ casing valve. TP increased 330 psi, IAP increased 20 psi and the OAP went on a vac overnight(Well is SI). No fluid in conductor. No new fluid in the cellar. Wing valve in leaking by, grease crew notified. 7/28/2015 SV= C. WV, SSV, MV=0. IA , OA=OTG. 0030 hrs. Daily Report of Well Operations BRLS V-101 T/I/O= SSV/1640NAC. Temp=SI. WHP's(Eval SC leak). AL open @ CV(1640 psi). No new fluid in cellar or bubbling in conductor. 7/30/2015 SV, WV, SSV= C. MV= O. IA, OA=OTG. 20:45. Fluids Summary BBLS Type 27 FRESH WATER 1 DIESEL 28 Total Fluids Summary GALS Type 40 WELLLOCK 37 DIESEL 77 Total TREE y 3-1/8"5M CAN WELL EAD= 11"FIAC I 101 I S Y NOTES: ACTUTO AR= NA IIIIAL KB.RE 82.30' BE(IP/= 53-80' KOP= Max Angle= 57°@ 5587' Datum MD= 9011' Datum TVD= 6600'SS 22°6' H3-1/2'HIES XNP,D=2.813' 7-5/8"CSG,29.7#,L-80,D=6.875' H 3023' -, ' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =2.813" 2206' 'I 3 4141 3509 45 KBG2-9 DOLE NT 16 07/24/15 3-1f2" HES X NIPPLE �1. 2 7062 5304 55 KC3G2-9 DAY NT 0 07/16/13 1 8580 6281 29 KBG2-9 DMY NT 0 07/24/15 PERFORATION SUMMARY REF LOG: BHCS ON 04/25/02 ANGLE AT TCIP PERF: 18'Cp 8914' Note:Refer 10 Roduction DB for historical pert data SIZE SPF SITBRVAL C n/Sgz SEDT SQZ 2-1/2" 6 8914-8950 0 05/04/02 2-1/2* 6 8930-8990 0 06122/11 1 I 8135' H3-1/2-BKR CMI SLIDING SLV,D=2.81r 5-12"CSG,15.5#,L-80,BTC,D=4.950' H 11666' �---� I 8666' -BKR LOC SEAL ASSY,D=2.992" 3-1/2"TBG,9.2#,L-80,BT-M,.0087 bpf,D=2.992" 66&9' ti $' ITGP OF BKR PBR ID=4.00' 4-3/4"X 3-12"CSG XO,D=3.000' 8687' 8678. BTM OF 3-112'BKR SEAL ASSY.D=3.01? 1 I e69B' H3-1/2"HES X NP,D=2.813' 1 I----{ s718' H 3-112"HES X NP,D=2.813" 8819' H20'PIPJT W/RA TAG 0 9266' H 20'FUP JT W/RA TAG I PBTD F- 9367' 44444 •4444 44.444.4.44 31/2'CSG,9.2#,L-a0,D=2.992' H 9467 ) DATE REV BY CONSENTS NTS DATE RPV BY CONSENTS BOREALIS UNT 04129102 TWAMO(ORGlNAL COMPLETION 06/26/11 11W PJC1ADPERF(06/22/11) 1NB-L V-101 05/04/02 JDIII1O( ACFERFs 08/05/13 WEC/JMD SET PX R-UG/GLV CIO(07/16/13) PEFMT Pb:'2020560 04/10/03 DRS/TP TVD/MD CORRECTIONS 02/12/15 JTG/JMD GLV 00(02/10/15) AR No: 50-029-23074-00 10/29/03 JIIWILH GLV CTO(10/04/03) 08/12/15 RJK/JMD GLV C/0&PULLED PLUG(0724/15) SEC 11,T11N R11E,468'FNL&1877'FEL 01/27/04 JLJITLP GLV CIO 12/08/05 KDCIPJC GLV(70 BP Ecploration(Alaska) Fit V -/0 Pr-t) Z62-OSbG Regg, James B (DOA) From: Noble, Robert C (DOA) Sent: Monday, June 29, 2015 7:58 AM �6 62(7.rnic To: Regg, James B (DOA) \ Cc: Hill, Johnnie W (DOA) Subject: PBU, V-101 Jim I just received a call from BPX, Len Seymour, telling me they had an issue last night. They had done a Well Loc job on the conductor yesterday. An epoxy that is put down the conductor to repair surface casing leaks. They had the well maned overnight. Surface casing had an open bleed and was at 0 psi. During the night the man watch noticed some white smoke coming out of the conductor and reported it. Follow later by Dark black liquid coming out of the conductor. Followed later by black smoke coming out of the conductor. Enough black smoke to fill the wellhouse. Fire dept. was called and the sprayed foam in the cellar. Len said they fill it was a chemical reaction and as of now things are normal. Bob ph1 (4,t( ?czn, )c e( (U KA) 617-1lis — C4 , 1 Cs i rtiii•eS Bob Noble AOGCC > a t( G Ln C>l l cec_J 1"ck- 6 6= 333 W. 7th Ave. Ste. 100 cMtut,* '. kcV Anch AK. 99501 SCANNED AUG 0 32015 Cell 907-299-1362 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 Bob Noble at 907-299-1362 or bob.noble@alaska.gov p- O ZOZ- O5 c Loepp. Victoria T (DOA) From: Regg,James B (DOA) Sent: Monday,June 29, 2015 11:36 AM To: Loepp, Victoria T (DOA) Subject: FW: PBU, V-101(PTD 202-056) Follow Up Flag: Follow up Flag Status: Flagged FYI; had a follow-up call from Ryan Daniel this morning as well.Suspended all remaining Well Loc jobs pending investigation. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From: Noble, Robert C (DOA) Sent: Monday, June 29, 2015 7:58 AM To: Regg, James B (DOA) SCANNED JUL 2 12Di5 Cc: Hill, Johnnie W (DOA) Subject: PBU, V-101 Jim I just received a call from BPX, Len Seymour,telling me they had an issue last night. They had done a Well Loc job on the conductor yesterday.An epoxy that is put down the conductor to repair surface casing leaks. They had the well maned overnight. Surface casing had an open bleed and was at 0 psi. During the night the man watch noticed some white smoke coming out of the conductor and reported it. Follow later by Dark black liquid coming out of the conductor. Followed later by black smoke coming out of the conductor. Enough black smoke to fill the wellhouse. Fire dept. was called and the sprayed foam in the cellar. Len said they fill it was a chemical reaction and as of now things are normal. Bob 1 Or, or Tye sTHE STATE Alaska Oil and Gas • yw\� �j,� � - i ofA A S KA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OA, ALAS"- Fax: 907.276 7542 www.aogcc.alaska.gov Travis Montgomery s�D >>1.a,. Well Interventions Engineer BP Exploration(Alaska), Inc. 5� P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, BRLS V-101 Sundry Number: 315-142 Dear Mr. Montgomery: 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, 17)0E Cathy . Foerster Chair DATED this / day of March, 2015 Encl. RECEIVED ED STATE OF ALASKA MAR 13 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other Well Lock Technology 0- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number SGL'/,gJt V— BP Exploration(Alaska),Inc. Exploratory ❑ Development 2 - 202-056-0 ' 3.Address. Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23074-00-00 • 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? BRLS V-101 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9 Property Designation(Lease Number). 10.Field/Pool(s): ADL0028241 ' PRUDHOE BAY, BOREALIS OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9480 7135 - 8698 6387 8698 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 28.5-108.5 28 5-108.5 Surface 2994 7-5/8"29.7#L-80 28.45-3022 64 28.45-2716.82 6890 4790 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None - Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 3-1/2"9.2#L-80 L-80 23.25-8677.76 Packers and SSSV Type: No Packer Packers and SSSV MD(ft)and TVD(ft) No Packer No SSSV Installed _ _ No SSSV Installed 12.Attachments. Description Summary of Proposal ❑ 13.Well Class after proposed work. Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development 0 • Service ❑ 14.Estimated Date for '15.Well Status after proposed work: Commencing Operations. Oil 0 . Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval. Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jessica Sayers Trow is ML 6 4430nn�ry Email Jessica.Sayers@BP.Com Printed Name .f,Q,tin9 ft r Jessica Sayers Title Well Intervetions Engineer Signature ,— Phone 564-4281 Date Prepared by Garry Catron 564-4424 1C4- . �'G J'�y✓ Shy-9I l7 W211 Infarve,,#,'otu En.94441c 3l12-//j COMMISSION USE ONLY 1 Conditions of approval: Notify Commission so that a representative may witness Sundry Number S 15 — \Li 2_ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other Spacing Exception Required Yes ❑ No [in Subsequent Form Required: /d — 4124 Ai THPROVED BY Approved by: / �....aCOMMISSIONER THE COMMISSION Date: j-//�—L�v7L3/1015— /7/.I3d/f'A RINGdIaNcAnLvalid Form 10-403 Revised 10/2012 0 for 12 months f the date of approval. Sub 't Form and Attachments in Duplicate RBDMS MAR 20 2015 — y - ,c,- ;s' Perforation Attachment ADL0028241 Well Date Perf Code MD Top MD Base TVD Top TVD Base V-101 7/16/13 BPS 8914 8930 6590 6605 V-101 7/16/13 BPS 8930 8950 6605 6624 V-101 7/16/13 ' BPS 8950 8960 6624 6634 V-101 7/16/13 BPS 8960 8990 6634 6662 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF O o 0 co 0 Co CO CO LU 0 = J J J J a) c lili O U in O O O O O '.- C) C 00000 co a) U) m r` N- N- co co cr) co N f� CO > = CO f� N CO F- C2 O O O f� CO CO Q N N CO N N EN O f— N M 00 00 m o CO CO N CV Tco � OCD co (/) O Q co rn M CO O O 2 C J •- o N- U Q N N CO N N 00 0 CO o CO o CO CO J J J J W NN Cn • O N CS) 6) CV N o NLO M M .�. LO O) o CO 0)) Lo 00 O N" 6) Co J CO N CO Z Z 0)OOOw (7) 0 0 0 0 O Q Q Q LLZ Z O O c m 0_o_ ci bp Imo�+' To: Ken Bulloch / Dan Scarpella; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 03-12-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Travis Montgomery, Well Interventions Engineer (office: 564-4127, cell: 918-281-9663) Subject: V-101 WeIlLock Conductor Treatment Objective This program is for treating surface casing response to pressure by external repair with WeIlLock. The well fails MIT-OA to 500 psi with nitrogen. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to place the WeIlLock between the conductor and surface casing to mitigate the leak. Before treatment, pump 900 bbls of 180°F crude down IA to warm well to aid in treatment/curing of resin. Please reference the waste management plan, at the end of this document for disposal practice and approval. Ensure the slop trailer is clean prior to arrival. Do not mix non-exempt hydrocarbons with WeIlLock (this is to avoid taking WellLock to the facility). Well Detail Current Status: Not Operable — P . Previous Test: 1-6-2013 MIT-OA to 500 psi (nitrogen) failed Integrity Issues: Surface casing leak at 81" Last H2S Reading: 02-12-2012 82 ppm Well Operation Detail Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WeIlLock at or above 85°F) Musol A: 7.5 ppg Diesel: 6.8 ppg Temperature: Maintain 75°-80° F throughout the entire job, leave heater trunks in well during cure period (one week) Relevant History: > 1/6/13: MIT-OA w/ N2 failed to 500 psi, LDD identified SC leak depth @ 81" below OA casing valve 1 of 3 Procedure 1 D Thoroughly clean the conductor by surface casing annulus to remove any deleterious material. This include steam washing the annulus and cleaning with detergent. 2 F Load IA with 900 bbls of 180°F crude to warm well to aid in treatment/curing. 3 D Run open bleed on OA during the entire job. 4 D ***Pump WellLock into conductor by casing annulus. 5 D Allow WellLock to cure for one week. 6 D MIT-OA to 500 psi. *** Collect approximately one cup sample of WellLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. Leave sample during seven day cure period and record temperature and observable viscosity of sample. 2 of 3 THEE= 3-V8'SM OW M1LFLAD- 11•f►ACV_J /ti SAFETY NOTES- ACTUATOR= NA 7 V MINE KH HF 8730' BF REV= 5380' KOP= 300' Max Angle- 57°@ 5587' Datum MD= 9011' Datum NO= 6607SS 2206' `--13-12'ELS X VP.D-2.813" 11-5/8"CSG,29.70, -80,0=6.815' H 3023' GAS I.FT k(ANT7RET.S ST MO IN(1 DEV TYPE VLV 'LATCH PORT (GATE Minimum ID=2.813" 2206' 'r 3 +147 3509 45 KBG2-9 DIM err 0 0711613 3-112"HES X NIPPLE l� 2 7062 5304 55 K8G2 9° 47/14 PO 0 0//16113 1 8580 6281 29 KBG2-9 FLWSLV NT - 02110415 1414-0F'A TION SLIMMRY REF LOG BEIM 0140425/02 ANGLEAT TOP PERE. @ 8914' Nate:Refer to Produ:tion OB for historical pert data SIZE SPT INTERVAL OpnlSgt 5t4)T 932 2-1/2' 6 8914-8850 C 05/04102 2-1/7 6 8930-8990 C 06/22/11 8635' I—Is-1YY BKR CFO SLUNG SLY,ID-2.813' ; 711 G 3G,15.5*,L 80 BTC,b-4 950" 8651- 8699' _...OKR LOC SEAL ASSY.18 2982' 0087 - 766' 1—me Of BKR PBR,10-401' 41 bpi,D=2 992'��----� 8656" � - ' 3-1+2'7'80.9�.L-80,BT-t4-314-X 3 117'GSD%O V=3.004'. H 8887' 1 8678' BTM OF 3 1/7 BKR SEAL ASSY,IO=3.00" I3-1!Z'PX PLUG(07776773) H 8i98' 8698' I—{3-iPl'Hps)t M.ill`7 813".1 8718' H3-117"WSX IW,In-7813' 8819' I t20'PUP JT WI RATAC;• a L 8266' H 20'RPM"W/RA TAG L�—M" PBTD 9367' — 11411/1111 s. 111111104 13112'CSG,920 L-88,0=2.987 I— 9f1+4i♦ DATE REV BY COMMENTS DATE T REV BY f 0366,64TS BOREALIS UW 94/29462 TWN10(01 144.COMPLETM?M 4524541ItPW!PKI AOPEPF(06/22'I1) WELL v-101 05/04/02 JDFMWC ADIERFS 08R)y93"IhFCJJI ISET FDC ftUG/GLV C/0(07/16/13)' 113,61T Na:X020560 04/10133 l7FLi/1P f VT]M)CXNEIFCTEMLS 07/17/15 JIG d.9UIGI V CO(02/10/15) AP No 50-029-73014-00 10/29103 Jr3WTU1 GLV(70(10/04(03) SEC 11,71111 R11E 468'FTC 8 1877'FE. 0127104 JUITLP GLV CTO 12/08/05 KDCIPJC GLV(YO j BP6rpioralion(Alaska) 3 of 3 Image.}oject Well History File Cover f .be XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ ()~- oslo '.Well History File Identifier Organizing (done) RES CAN 0 Two-Sided 0 Rescan Needed Color items: D~ITAL DATA ~ Diskettes, No. OVERSIZED (Scannable) 0 t 0 Maps: Other items scannable by large scanner 0 Grayscale items: 0 Other, Norrype 0 0 Poor Quality Originals: Other: OVERSIZED (Non-Scannable) 0 0 Logs of various kinds NOTES: BY: BEVERLY ROBIN VINCENT SHERYL ~INDY .; D, Other¡/) DATE:~ J~~ 6l.f Isl \It(T~ , Project Proofing BY: BEVERLY ROBIN VINCENT SHERYLF'YINDY , ,~" ,~) DATE:b.JR 6u'1 I V11 f./ ~ , 7. i s ....1-f7. J yY. ~ + I , 7 TOTAL PAGES ~ I DATE(P~ð~SI IMP ~ ¿f Qr~ ~~ CtdkJ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION:, ¿ YES - NO tMP I x 30 = 30 Scanning Preparation BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY Production Scanning Stage 1 P AGE COUNT FROM SCANNED FILE: lj~ BY: BEVERLY ROBIN VINCENT SHERy6~~INDY DATE:~ :)..0 I_I , Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY DATE: Is/ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReS can ned (Ìln/ividoi)1 pJ9': I f.I'(,r:ia/ ;'t1MUOI1) $(.òonillg W1I?p/elod) RES CANNED Bt: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /s/ General Notes or Comments about this file: Quality Checked (rlollI:1 12/10102Rev3NOTScanned,wpd OF 'Ti • t \ I'/� SA THE STATEAT li a ,).L ,. r � 7 ..,:.,-,=-_,.N t!Wt ___�----- _ / — 333 West Sovenih Avenue 1 GOVERNOR SEAN PARNEl i. Anchorage, Alaska 99501 3572 ® r ua ,. Mom. 907 27c 1433 \�_°A— 9',7 27 7 4'2 Aaron Ramirez SCANNED MAY 2 0 , 024 Well Intervention Engineer - A g........05;4, BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, BRLS V-101 Sundry Number: 314-035 Dear Mr. Ramirez: 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, _ /4° ,,,,,,c,/,— Cathy P. , oerster Chair DATED this ZZday of January, 2014. Encl. coi.it_ .,,,, Ak '1'; STATE OF ALASKA v1,~ < , ALASKA OIL AND GAS CONSERVATION COMMISSION r, '' APPLICATION FOR SUNDRY APPROVALS o�s ) /2( 9- 20 AAC 25.280 AC's 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well . Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development Q. 202-056-0 - 3.Address: Stratigraphic ❑ Service ❑ 6.API Number P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23074-00-00• 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? BRLS V-101 , Will planned perforations require a spacing exception? Yes ❑ No E 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028241 • PRUDHOE BAY, BOREALIS OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9480 • 7135 • 8698 6387 8698 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 29-109 29-109 Surface 2995 7-5/8"29.7#L-80 28-3023 28-2717.08 6890 4790 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 3-1/2"9.2#L-80 L-80 23-8978 Packers and SSSV Type: No Packer Packers and SSSV MD(ft)and TVD(ft): No Packer No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑] Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 7/15/14 Oil Q • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned [I] Commission Representative: GSTOR ❑ SPLUG p 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aaron Ramirez Email Aaron.Ramirez@BP.Com Printed Name Aaron Ramirez Title Well Intervention Engineer Signature Phone 564-5943 Date og J 14 Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Z k'4.- c;,2- 5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDM MAY 0 9 2014 Phyto GlaGtimevt rel3x1-1--- Spacing Exception Required? Yes El No d Subsequent Form Required: /0 �D4 APPROVED BY Approved by: - ILL.., 10 • ' COMMISSIONER THE COMMISSION Date:(- ?Z ( Form 10-403 Revised 10/2012 Appibvlcl�pi �r r�i v. ',, onths from the date of approval. Submit Form nd A chments in Du tie 1A V it /O 7/�I ���......!!!!!! 1 ` 044 `-, -o 0 0 0 0 0 covooaoco0? 0 = J J J J N CO• O� O) t O) mit) O O O U N O O CD O CD co •cra0cc) 0 m x_ CO (Dm r m• O OM — r•-• CC) Q `— CO N- N CO Q O O) co ti CO M Q N N NCD (U C C " N O N- rd M O CNI m O OD CD co (0 0 Q •— Oocs)) Map p 2 CD•N1-1 C1 C H C) CO CO CO M U Q N N N N 2 OO Oo co ODI OD i J J J J N 4* N N CA N CA O CV (V CD (V M M Lc)L LO CA O (OInO) C[) C N c CD N CA OCA O O O O CA F- p LJ.I ( » > Qco 0 0 0 0 Z Z O O m o = Uaav) f- A Perforation Attachment ADL0028241 Well Date Perf Code MD Top MD Base _ TVD Top TVD Base V-101 7/16/13 BPS 8914 8930 _ 6590 6605 V-101 7/16/13 BPS 8930 8950 _ 6605 6624 V-101 7/16/13 BPS 8950 8960 6624 6634 V-101 7/16/13 BPS 8960 8990 6634 6662 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF TREE! 3-1/8"5M CNV WELLHEAD= 11"FMC SAFt TY NOTES: ACTUATOR= NA V 101 MIAL KB.ELE 82.30' BF.ELEV= 5380' - KOP= 300' Max Angle= 57°@ 5587' Datum MD= 9011' Datum TVD= 6600'SS 0 2206' H 3-1/2"FES X NP,ID=2.813" 7-5/8"CSG,29.7#,L-80,ID=6.875' H 3023' GAS LFT MANDRELS ST MD IVU DEV TY FE VLV LATCH FORT DATE Minimum ID =2.813" @ 2206' i3 4141 3509' 45 KBG2-9 DMY NT 0 07/16/13 3-1/2" HES X NIPPLE 2 7062 5304 55 KBG2-9 DMY NT 0 07/16/13 1 8580 6281 29 KBG2-9 DMY NT 0 10/03/03 PERFORATION SUMMARY REP LOG: BHCS ON 04/25/02 ANGLE AT TOP PERF: "@ 8914' Note:Refer to Production D8 for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 2-1/2' 6 8914-8950 C 05/04/02 2-1/2" 6 8930-8990 C 06/22/11 8635' H3-1/2"BKR CMDSLDPIGSLV,ID=2.813" 8659' —BKR LOC SEAL ASSY,ID=2.992' 5-1/2"CSG,15.5#,L-80,BTC,ID=4.950' H 8656' - 3-1/2"TBG,9.2#,L-80,BT-M, .0087 bpf,D=2-992" H 8659' 8668' —TOP OF BKR PBR,ID=4.00" 4-3/4"X 3-1/2"CSG XO,D=3.000" —I 8687' ' 8678' 4BTM OF 3-112'BKR SEAL ASSY, ID=3.00" 3-1/2"PX PLUG(07/16/13) H 8698' 1111,--1 8698' H3-1/2"FES X NP,ID=2.813" 8718' H 3-1/2"HES X NP,ID=2.813" l 8819' H 20'PUP JT W/RA TAG 9256' —120'RJP JT W/RA TAG PBTD H 9367' 3-1/2"CSG,9.2#,L-80,ID=2.992" —i car ----- DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 04/29/02 TWA/KK ORIGINAL COMPLETION 06/26/11 11W/PJC ADFERF(06/22/11) WELL. V-101 05/04/02 JDNYKK ADPERFS 08/05/13 WE(/JMD SET PX PLUG/GLV C/O(07/16/13 PERMT Nb '2020560 04/10/03 DRS/TP 1V DIM)CORRECTIONS AR No. 50-029-23074-00 10/29/03 JCM/TLH GLV C/O(10/04/03) SEC 11,T11N,R11E,468'FTS&1877'FEL 01/27/04 JLJ/TLP GLV C/O 12/08/05 KDC/PJC GLV C/O BP Exploration(Alaska) l)p Date: January 2, 2014 To: AOGCC From: Aaron J. Ramirez, Well Intervention Engineer Subject: Sundry Notice 10-403 Approval Request BPXA Well GPB V Pad, Well 101 (V-101) This application for Sundry approval for BPXA Well V-101 is for the inspection and repair of surface casing. Currently, part of the surface casing on this well is exposed to atmosphere, most likely due to corrosion. Well V-101 has been determined to have a surface casing leak at an estimated 7 feet from surface. BPXA requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will follow the general, outlined procedure below: 1. Secure the well from the reservoir with plug(s), kill weight fluid and BPV. 2. Remove the cellar, wellhouse, tree, flowline and other equipment necessary for repair. 3. Survey existing utilities and other critical infrastructure, including the wellhead. 4. Drive piles to support the wellhead and well support frame. Drive sheet piling for excavation around well. 5. Install wellhead and well support frame. 6. Excavate inside the parameters of the sheet piling, to an estimated bottom depth of 20 feet. 7. Install nitrogen purge equipment for conductor (and OA if needed) so that hot work may be conducted in a safe manner. 8. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC inspector for opportunity to inspect. 9. Install repair patch needed to return the casing to operational integrity. 10. Patch will be inspected for acceptance. 11. Perform MIT-OA. 12.Install external wrap on casing to safeguard against future, potential corrosion. 13.Backfill and compact around well and install cellar. 14.Demobilize wellhead and well support frame. 15.Reinstall tree, flowline and wellhouse. Remove plug(s), BPV and hand well over to well integrity for evaluation. 16.File 10-404 with AOGCC post repair, complete with pictures demonstrating repair. 1 • • 0,t,\�jj,:s, THE STATE Alaska Oil and S N �� °fl is Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage ALAS Y. Main: 0 Main: Fax: 907.276.7542 �t� Joleen Oshiro SC�� Production Engineer BP Exploration (Alaska), Inc. � �n P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU V-101 Sundry Number: 313-503 Dear Mr. Oshiro: 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, P4e4—' Cathy P. Foerster Chair, Commissioner DATED this of September, 2013. Encl. 0 � RECEIVED ' STATE OF ALASKA te S EP t 1 r ���3 ALASKA OIL AND GAS CONSERVATION COMMISSION �` QT`'$ �) Z,s`j/3 APPLICATION FOR SUNDRY APPROVALS AO `x 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well 0 • Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. 5ta/I r6 Er 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. 141"C - BP Exploration(Alaska),Inc. Exploratory ❑ Development 0 202-056-0 ' etiv,. � 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23074-00-00 • 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? BRLS V-101 . Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028241 • PRUDHOE BAY, BOREALIS OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9480 7135 . 8698 6387 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 29-109 29-109 Surface 2995 7-5/8"29.7#L-80 28-3023 28-2717.08 6890 4790 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): 8914-8930 6589.94-6605.16 3-112"9.2#L-80 L-80 24-8978 Packers and SSSV Type: No Packer Packers and SSSV MD(ft)and ND(ft): No Packer No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joleen Oshiro Email Joleen.Oshiro@BP.Com Printed Name Joleen Oshiro Title Production Engineer Signature 04..\...., Phone 564-4606 I Date Prepared by Garry Catron 564-4424 COMMISSION USE ONLY �2 Conditions of approval: Notify Commission so that a representative may witness Sundry Number. S k �J S 0 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RsiMS OCT 1 0 20 Other: Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: /0 —40 `T APPROVED BY Approved by: p COMMISSIONER THE COMMISSION Date: f/.J Form 10-403 Revised 10/2012 r �� Approv from the date of approval. Submit Form and Attachments in Duplicate t V iN Casing Summary ADL0028241 Casing Length Size MD Top MD Base ND Top ND Base Burst Collapse Grade CONDUCTOR 80 20" 91.5# H-40 29 109 29 109 1490 470 H-40 PRODUCTION 8661 5-1/2" 15.5#L-80 26 8687 26 6377 7000 4990 L-80 PRODUCTION 775 3-1/2" 9.2# L-80 8687 9462 6377 7117 10160 10530 L-80 SURFACE 2995 7-5/8"29.7# L-80 28 3023 28 2717 6890 4790 L-80 TUBING 8954 3-1/2"9.2#L-80 24 8978 24 6651 10160 10530 L-80 • • • i • Proposed Procedure for BP Alaska Diagnostics and Repair of Casing Leak Prepared by Seal-Tite International Field: Borealis Unit Well: V-101 Date: September 19, 2013 Objectives 1. Confirm leak site and leak rate. 2. Cure the leak using Seal-Tite sealants and procedures. Mechanical Considerations This well (shown below) is reported to have a corrosion leak in the 7 5/8" surface casing 81" below the surface casing valve. 3-1110"BILFC100 WEWIE.40- 111-PiC SAiETY taOTEB: —._.1 Ba1AL KB.0E *230• SOP _..____._.._. MIS Ewe Angle.- ST®•�• Oaplm./�0- 9011• °Nunnlv6- OBOO`ffi fa, H3, MBE MP;ID=zany. r:-Bl.-.oa.25.7*.C-SE..0..s.Brs- H aofa [■A.S LET NANCOREMS MYrinuBn ID.•2.813•• 2208• .f L1i3�� m®! ► -1 1 . 8 07115Y13 3-112'•HES X NIPPLE ',. 11J tif.4 t1114 .._W.o Di7iaoiwa: PERFORA DON SUMMARY ._ REF Lcxr 3aOa ON 04.23102 AA101.E AT TOP FHA. Alp 8914' Moo Roles to PMduoMioo CB Per Moon)al Port dale STrE SPF Ba7SxVAAL ClpalSege savor 3102 AAA,1/10 2-1J2- B BOtm-0900 C 0622111 MaB' 1-13-us-awn aw9Lal9a aLV..B3-2.013•,. 3-'10£010.1 2..810.100 100 aT-C.aw maw- WO lama O1 SF I C B SKEA L 3.120 Tom S:2/ LAID.11R-114.SET IBC O-2.1152 .Mr ' .aa2- �BT.OF 3-11..MOO aawu.AMOY.IDs 1.11? ' 42JM X 3- coo XG1,d-3.,006 MbT �. '� 13-1SY IFX PLIIG 10711a/13p BBBd' BBM• HS-112.NES X NP.fo- .013-2 1 "—I *71W H3.1dk'*Oa x r OM-2,1113^.I Bret 1--120 P',17 VV w\TAO LI I 92839• '--'.20r fSJPS VA,pM TAO �3-lrr ca..v.s.L41D.a-2.s4r �.._.. 11,402. as•• DOME TY@I B11- COMMENTS DATE REV ST COMMENTS I BOREALIS ENT BASSOONS moans OtrfiWt.COMM.!Riff. 1111112B/11 TTW P.IC 411IFTS(P11403111} Nei I-V-101 0$041012 .*0KIC AGP®.Pc Of 1Uid13 VVEC/Be0 SET PX.PL1W0LV 00(0705113 PIBSUT NO.' B0 SOMISMO many 7YO9CCOPIRECTIONS API N c 90-i02*-23074-00 10r2BO3 JCM'0J1'C LV CSO(10'04I03) SEC 11.111111,11111E,4SE FM 6.EMT-PE. 0173700/ JL.1171.P ELY COO 12041I0.5 1(00PJC ELV CT. BP tram on 4A1aaaa) Figure 1 Wellbore Schematic Page 1 of 2 • • The leak rate is reported to be 2.9 gal/min @ 150 psi. The 5 %" x 7 5/8" 29.7# annulus capacity is 0.6942 gal/ft. The annulus volume above the leak site is approximately 5 gallons. Intended Diagnostic Procedure 1. Meet with field personnel; review field history and verify condition of well as matching information provided. 2. Perform Job Safety Analysis with all concerned personnel. 3. Record all tubing and casing pressures. 4. Confirm depth of surface casing leak to be 81" below the surface casing valve. 5. Fill the OA with diesel and pump diesel down OA while vacuuming returns from conductor to confirm reported 2.9 gal/min @ 150 psi leak rate. 6. Report diagnostic information to the office for evaluation and potential changes to the following repair procedure. Intended Repair Procedure 7. Prepare Gel-Seal sealant with Platelets in the appropriate volume (- 5 gal) to attempt to cure the leak. Note: Sealant to float on the diesel in the OA. 8. Inject sealant into the OA via the surface casing valve to create an initial seal. 9. Increase OA/sealant pressure with diesel and triplex in 200 psi steps to 1000 psi casing test pressure. 10. Hold 1000 psi on OA overnight to allow sealant to cure. 11. Bleed off pressure in the OA. 12. Record WHPs and perform MIT-OA with diesel to 1000 psi. Note: Have vac-truck ready to evacuate fluids from the conductor. If test fails make note in AWGRS of any fluid response at surface. 13. Rig down equipment and clean work area. END - Gary Webb Page 2 of 2 TREE= 3-1/8"5MQW • IUD= WRAC V 101 Hit NOTES: -ACTUATOR= NA INITIAL KB.ELE 82.30' BE REV= 5180' - - KOP= 300' 10116 Max Angle= 57° r,5587' Datum MD= 9011' Datum1VD= 6600'SS I 2206' —I3-1/2"I-ES X NP,ID=2.813" u I7-518"CSG,29.7#,L-80,ID=6.875' H 3023' I---, GAS LFT MANDRELS ST MD TVt) DEV TYPE VLV LATCH PORT DATE Minimum ID =2.813" @ 2206' 3 4141 3509 45 KBG2-9 DMY NT 0 07/16/13 3-1/2" HES X NIPPLE 2 7062 5304 55 KBG2-9 DMY NT 0 07/16/13 1 8580 6281 29 KBG2-9 DIW NT 0 10/03/03 PERFORATION SUMMARY RE=LOG: BHCS ON 04/25/02 ANGLE AT TOP FEW: @ 8914' Note:Refer to Roduction DB for tvstorical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 2-1/2" 6 8914-8950 C 05/04/02 2-1/2" 6 8930-8990 C 06/22/11 8635' —13-1/2"BKR CMD SLIDING SLV,0=2.813" I 5-1/2'CSG,15.5#,L-80,BTC,ID=4.950" H 8656' 8669' {BKR LOC SEAL ASSY,ID=2.992 I • TOP OF BKR PBR ID=4.00' I 13-1/2'TBG,9.2#,L-80,BT-M,.0087 bpf,D=2.992" —{ 8659' 866r 4-3/4"X 3-1/2"CSG XO,O=3.000" H 8687' $67$' �BTM OF 3112'BKR SEAL ASSY,ID=3.00" 3-1/2"PX PLUG(07/16/13) H 8698' 111111 8691r —13-1/2"I-ES X Imo',D=2.813" I I , I 8718' H3-1/2"I-ES XNP,U=2.813" I I 8819' I—20'PUP JT W/RA TAG 9266' I-120"PUP JT W/RA TAG PBTD H 9367' to r*r* 3-1/2'CSG,9.2#.L-80,U)=2.992" --- 9462' ■••••• DATE REV BY COPMENTS DATE REV BY (X4/ ENTS BOREALIS UNIT 04129/02 TWAAO( ORIGINAL COMPLETION 06/26/11 T1W/PJC ADPERF(06/22/11) WELL V-101 05/04/02 JDMKK ADPERFS 08/05/13 WECIJMD SET PX PLUG/GLV C/O(07/16/13 PERMIT No:"2020560 04/10103 DRS/TP TVD!MD CORRECTIONS API No: 50-029-23074-00 10/29103 JaViTLH GLV C/O(10/04/03) SEC 11,T11N,R11E,468'FM_&1877'FEL 01/27/04 .LJ/TLP GLV CIO 12/08/05 KDCIPJC GLV C/O BP Exploration(Alaska) STATE OF ALASKA ALASKA OAND GAS CONSERVATION COMMISSI. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate IS Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory p - 202 -0560 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 — 50- 029 - 23074 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028241 _ V -101 10. Field /Pool(s): PRUDHOE BAY FIELD / BOREALIS OIL POOL 11. Present Well Condition Summary: Total Depth measured 9480 feet Plugs (measured) None feet true vertical 7134.52 feet Junk (measured) None feet Effective Depth measured 9340 feet Packer (measured) feet true vertical 6998.32 feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 29 - 109 29 - 109 1490 470 Surface 2995' 7 -5/8" 29.7# L -80 28 - 3023 28 - 2717 6890 4790 Production 8661' 5 -1/2" 15.5# L -80 26 - 8687 26 - 6377 7000 4990 Production 775' 3 -1/2" 9.2# L -80 8687 - 9462 6377 - 7117 10160 10530 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ - True Vertical depth: _ _ _ _ _ - Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.2# L -80 24 - 8978 24 - 6651 Packers and SSSV (type, measured and true vertical depth) NONE , 12. Stimulation or cement squeeze summary: ;, I S b Intervals treated (measured): Treatment descriptions including volumes used and final pressure: :„Pti:4_1:::,;9fT11,164; 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 610 232 2139 339 Subsequent to operation: 567 216 1989 331 14. Attachments: 15. Well Class after work: 1 Copies of Logs and Surveys Run Exploratory Development IS • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 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: NA Contact Joe Lastufka Printed Na : • - Lastu -/K I Title Petrotechnical Data Technologist Signatu 11111111111 AIIK Phone 564 -4091 Date 7/9/2011 Ilir Form 10 -404 Revised 10/2010 RBDMS JUL 1 1 1011 . /3 it Submit Original Only V -101 202 -056 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base V -101 5/4/02 PER 8,914. 8,950. 6,589.94 6,624.18 V -101 6/22/11 APF \ T r 8,950. 8,960. 6,624.18 6,633.69 V -101 6 - APP 8,960. 8,990. 6,633.69 6,662.24 V -101 6/22/11 RPF 8,930. 8,950. 6,605.16 6,624.18 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 41111 • • v -1o1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/22/2011 ` ** *WELL FLOWING ON ARRIVAL * ** (ELINE RE -PERF / ADD PERF) INITIAL T /I /0= 400/1400/150. WELL SHUT IN AND FLAGGED, GLT, CHEM INJ SHUT IN AND FLAGGED ;2.5" PJ GUNS 2 X 30 FT RUNS. ENT HOLE 0.31" PENETRATION 24.4" MAX GUN ' SWELL 2.66" IN FLUID RUN 1 PERFORATE 8960 - 8990 BEFORE T /I /0= 1000/1400/150 AFTER T /I /0= 1000/1400/150. RUN 2 PERFORATE 8930 - 8960 BEFORE T /I /0= 1100/1360/150, AFTER T /I /0= 1100/1360/150. WELL TURNED OVER TO PRODUCTION WITH SWAB, SSV, GLT, WING, CHEM INJ = CLOSED, MASTER = OPEN, TREE CAP ON AND TESTED. • FINAL T /I /0= 1100/1360/150. : ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL TREE = 3-1/8" 5M CIW • SAFETY NOS: • WELLHEAD 11" FMC V ACTUATOR = NA - 101 KB. ELEV = 82.30' - BF. ELEV = 53.80' KOP = 300' Max Angle = 57° @ 5587' Datum MD -=' 9011' Datum TVD = 6600' SS 1 2206' H3-1/2" HES X NIP, ID = 2.813" 1 • 17 -5/8" CSG, 29.7 #, L -80, ID = 6.875" H 3023' I---A • GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 2.813" @ 2206' L 3 4141 3509 45 KBG2 -9 LGLV NT 16 12/08/05 3 -1/2" HES X NIPPLE 2 7062 5304 55 KBG2 -9 SO NT 20 12/08/05 "� � 1 8580 6281 29 KBG2 -9 DMY NT 0 10/03/03 PERFORATION SUMMARY REF LOG: BHCS ON 04/25/02 ANGLE AT TOP PERF: 18° @ 8914' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/2" 6 8914 - 8950 0 05/04/02 2 -1/2" 6 8930 - 8990 0 06/22/11 I I 8635' 1- 13 -1/2" BKR CMD SLIDING SLV, ID = 2.813" 1 I 8659' 1--1 BKR LOC SEAL ASSY, ID = 2.992" 1 1 5-1/2" CSG, 15.5 #, L -80, BTC, ID = 4.950" H 8656' { 13 -1/2" TBG, 9.2 #, L -80, IBT -M, .0087 bpf, ID = 2.992" H 8659' 8668' 1-1TOP OF BKR PBR, ID = 4.00 "' 14 -314" X 3-1/2" CSG X0, ID = 3.000" H 8687' 1 8678' I_IBTM OF 3-1/2" BKR SEAL ASSY, ID = 3.00" 1 1 8698' H 3 -1/2" HES X NIP, ID = 2.813" 1 I 8718' H3 -1/2" HES X NIP, ID = 2.813" 1 1 8819' H20' PUP JT W / RA TAG 1 = 1 9256' H20' PUP JT W / RA TAG 1 1 PBTD H 9367' f fl' fi• 13 -1/2" CSG, 9.2#, L -80, ID = 2.992" H 9462' 1.64.1.1A DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 04/29/02 TWA /KK ORIGINAL COMPLETION 06/26/11 TTW/ PJC ADPERF (06/22/11) WELL: V -101 05/04/02 JDM/KK ADPERFS PERMIT No: 2020560 04/10/03 DRS/TP ND /MD CORRECTIONS AR No: 50 -029- 23074 -00 10/29/03 JCM/TLH GLV C/O (10/04/03) SEC 11, T11 N, R11 E, 4812' NSL & 1877' WEL 01/27/04 JLJ/TLP GLV C/0 12/08/05 KDC/PJC GLV C/O BP Exploration (Alaska) ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage,Alaska 99519-6612 ~~~~~!~?.' `,~',' ~ ~ ~D~~ August 14, 2009 ~ bp ~~~;~~'~/~~ ocT o ~ 2aa~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7'" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, ~Slca Oi! & Gas Cons. ~amm~~~in~ Anehorape ~.p ~-; p`~~ i~' ~ ~ 1 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date V-pad 8l13/2009 Well Name PTD # API # Initiai top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al V-Ot 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 v-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8I7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-1o9 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 ~ NA 11.9 7/12/2009 V-112 206U200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9l2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 v-201 2012220 500292305a000o SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA t3.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA t8.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-2t6 2041300 50029232160000 NA 1.5 NA 13.6 6l29/2009 V-2t7 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-2i9 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 u~e 2080200 50029233830000 NA 1.75 NA ~ 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9I7l2008 e e '" "o.:·r········'.·····,·, >. ,:,',:.. ,', ·'i.' .~ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_ Inserts\Microfilm _ Marlœr.doc ~ I \ - \ '"J "Y"¡"~"-- DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 >(1 ~ I ) ILp ~(,~ L. Permit to Drill 2020560 Well Name/No. PRUDHOE BAY UN BORE V-101 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23074-00-00 MD 9480 ,-- TVD 7135 - Completion Date 5/4/2002 r' Completion Status 1-01L Current Status 1-01L UIC N --- REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey Yes~. --- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log ¡Log Name Interval Start Stop Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 25 Blu 1 107 9423 Open 6/21/2002 25 Blu 107 9423 Open 6/21/2002 100 9480 Open 6/21/2002 5 Col 8500 9288 Case 7/26/2002 5 Col 8500 9288 Case 7/26/2002 5 Col 8500 9288 Case 7/26/2002 5 Col 8500 9288 Case 7/26/2002 5 Col 8500 9288 Case 7/26/2002 Sample Set Sent Received Number Comments -- L..-I;D C !r(Óg . Log / Log ~2 GarnmaHay Cement EvalQatioh ¡Log ; Log Casing collar locator Temperature .~-~- Well Cores/Samples Information: Well Cored? ADDITIONAL INFORMATION y~ "--' Daily History Received? f;N &N Chips Received? VIN Formation Tops Analysis Received? -~ ----~--- ------------ ~---------- Comments: ------- -~-- -------- - DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020560 Well Name/No. PRUDHOE BAY UN BORE V-101 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23074-00-00 MD 9480 TVD 7135 ~etion Date 5/4/2002 Completion Status 1-01L Current Status 1-91L C?J UIC N - Date: ;¿ ð ,{¡it- Æ ~ L.( Compliance Reviewed By: -"'_/ ~- Sc~lullbepgep Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth - Well Log Description Date Job# V-101 ~Od.-OS(O 222308 SCMT 05/03/02 -" PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. R. :;..~ C. ,. r: i' ¡ ~... D Anchorage AK 99508-4254 .. t:.. }' k 'i I"J Date Delivered: JUL 2. 6 2.002 Alæka. 01\ & Gaz Cons. v~mmjssion Anchorage 7/19/2002 NO. 2243 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Color BL CD Sepia 2 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Sherrie Receiv~;2f~LL Ch r '-' ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ') .) 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ;'êõMpCdIÖN 1 4812' NSL, 1877' WEL, SEC. 11, T11N, R11E, UM ~ OA1E t At top of productive interval ¡; ç. "'1,0'"1- ~ 1825' NSL, 1397' WEL, SEC. 03, T11 N, R11 E, UM 1 VEHiieD." .. ~.". At total depth Ii ~ A(;>' ~ 1862' NSL, 1549' WEL, SEC. 03, T11N, R11E, UM !~..~.. ~1...;:~~'-;~þ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB = 82.3' ADL 028241 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 4-17 -2002 4-25-2002 5-4-2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9480 7135 FT 9340 6998 FT a Yes 0 No 22. Type Electric or Other Logs Run RES I AIT, DT I BHC, CNL, LDL, GR, Caliper, SP, MRES, MWD , LWD , PWD, SONIC, CBL ?~. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 34" X 20" 91.5# H-40 29' 109' 42" ,260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 29' 3023' 9-7/8" 365 sx AS Lite, 178 sx Class 'G' 5-1/2" x 3-1/2" 15.5# x 9.2# L-80 26' 9462' 6-3/4" 141 sx Lite Crete, 206 sx Class 'G' Classification of Service Well 7. Permit Number 202-056 8. API Number 50- 029-23074-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number V-101 11. Field and Pool Prudhoe Bay Field I Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2206' MD 1900' (Approx.) AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 6 SPF MD TVD SIZE 3-1/2",9.2#, L-80 TUBING RECORD DEPTH SET (MD) 8678' PACKER SET (MD) None 25. MD TVD 8914' - 8950' 6590' - 6624' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8914' - 8950' Frac'd: Placed 135,300#'s of 16/20 Carbolite behind Pipe. Freeze Protected with 140 Bbls Diesel and 20 Bbls Methonal 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 15, 2002 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL 7-7-2002 4 TEST PERIOD 3154 Flow Tubing Casing Pressure CALCULATED OIL-BBL Press. 24-HoUR RATE 28.. .... . CORE DATA. . f' u~. r r ! \/ r ~) Bnef descnptlon of lithology, pOroSity, fractures, apparent dips and presence of oil, gas or water. Submit cdì'è dbi¡js.. '.,.. ~ I,' ¡,~.~. GAs-McF 3396 GAs-McF WATER-BBL 8.97 WATER-BBL CHOKE SIZE 176 OIL GRAVITY-API (CORR) GAS-OIL RATIO 1077 No core samples were taken. 1\ n '1 5 2002 v....- ,Alaska Oil & Gas Cons. ComffiiSSIOI! Anchorage Form 10-407 Rev. 07-01-80 G~ n\. p ~ h I \\~I A L B F L JUL , 8 2'~ubmit In Duplicate ',.' .. I, ''''. ~ ~ 'J ~ RBDMS uuz: ') 29. Geologic Markers Marker Name Measured Depth Top of Schradder Bluff 'M' 4887' Top of Schradder Bluff 'N' 5240' Top of Schradder Bluff '0' 5492' Base of Schradder 'DB' Top of Colville 6125' CM2 6721' CM1 7712' Top of Kalubik 8762' Top of Kuparuk ID1 8880' Top of Kuparuk 'C' 8904' Top of Kuparuk 'B' 9084' Top of Miluveach 9179' 31. List of Attachments: ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4042' 4285' 44381 4783' 5113' 5664' 6446' 6558' 6580' r"~ ru ("'" U",'"'' M , '.. ~ltJ ['~" ta a ~ l t'" ¡II" . I ,~, t,,;.; 'f. 1,,,... 6752' 6843' J'II "1 r" l)Of'1/) L:... J L Ih:" Alaska Oil & Gas Gons. COmmiSSIQ¡, Anchorage Summary of Daily Drilling Reports, Surveys, Post Rig Summary and a Leak-Off Integrity Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed T.rri.Hubbl.~~.~ nle Technical Assistant V-101 202-056 Well Number Permit No. / Approval No. Date 07. {S.O~ Prepared By Name/Number: Sondra Stewman, 564-4750 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. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 () [1 r (, .:~ ~ t ':, \ , u_- Legal Name: V-101 Common Name: V-101 Test Date 4/20/2002 Test Type LOT Test Depth (TMD) 3,060.0 (ft) BPEXPLORATION Leak-Off Test Summary TestDepth (TVD) 2,730.0 (ft) AMW 9.30 (ppg) Suñace Pressure 625 (psi) Leak Off Pressure (BHP) 1,944 (psi) EMW 13.71 (ppg) ''-'' ~ Printed: 4/30/2002 3:17:37 PM BP EXPLORATION Operations Summary Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-101 V-101 DRILL +COMPLETE NABORS NABORS 9ES Activity Gód$ NPT Start: 4/16/2002 Rig Release: 4/29/2002 Rig Number: 9-ES Spud Date: 4/17/2002 End: 4/29/2002 4/16/2002 12:00 - 13:00 1.00 MOB P PRE 13:00 - 16:00 3.00 MOB P PRE 16:00 - 17:00 1.00 MOB P PRE 17:00 - 18:00 1.00 MOB P PRE 18:00 - 20:00 2.00 MOB P PRE 20:00 - 21 :00 1.00 RIGU P PRE 21 :00 - 22:00 1.00 RIGU P PRE 22:00 - 23:00 1.00 RIGU P PRE 23:00 - 00:00 1.00 RIGU P PRE 00:00 - 06:00 6.00 RIGU P PRE 4/17/2002 06:00 - 10:00 4.00 RIGU P PRE 10:00 - 10:30 0.50 BOPSUR P SURF 10:30 - 12:00 1.50 DRILL P SURF 12:00 - 12:30 0.50 DRILL P SURF 12:30-13:30 1.00 DRILL P SURF 13:30 - 16:30 3.00 DRILL P SURF 16:30 - 17:00 0.50 DRILL P SURF 17:00 - 00:00 7.00 DRILL P SURF 4/18/2002 00:00 - 05:00 5.00 DRILL P SURF 05:00 - 06:00 1.00 DRILL P SURF 06:00 - 07:30 1.50 DRILL P SURF 07:30 - 09:00 1.50 DRILL P SURF 09:00 - 13:30 4.50 DRILL P SURF 13:30 - 15:00 15:00 - 16:00 1.50 DRILL P 1,00 DRILL P SURF SURF 16:00 - 20:00 4,00 DRILL P SURF CLEAR CELLAR AREA, BLOW D'N STEAM I WATER, DISCONNECT LINES, BRIDLE UP, LOWER CHUTE. MOVE SHOP, CAMP, PITS TO V PAD. MOVE SUB AWAY FROM WELL L-119 PJSM, LOWER MAST. MOVE SUB BASE TO V PAD. LAY MATS, SPOT SUB OVER WELL V-101 PJSM, INSPECT AND RAISE MAST SPOT PITS, CONNECT LINES, RAISE CHUTE SPOT CAMP, SHOP, CONNECT SERVICE LINES, TAKE ON WATER. ACCEPT RIG @ 00:01 hRS. CONT. TAKING ON WATER, BRIDLE DOWN & SECURE DERRICK, MIU HYDRAULIC LOOP ON TOP DRIVE., MIX SPUD MUD, DP & BHA IN SHED, NIU DIVERTER SPOOL & RISERRIU FLOOR, STRAP DP IN SHED. P/U 90 JTS, 4" DP & STAND BACK. P/U HWDP. FUNCTION TEST DIVERTER. WITNESS OF TEST WAIVED BY LOU GRIMALDI, AOGCC. BRING BHA JEWLRY TO FLOOR, SERVICE TOP DRIVE, CLEAN RIG. PRE SPUD MEETING WI TIEDEMANN'S CREW, DIR. DRLR, LWD, MUD MAN, PEAK DRIVERS, HERB WILLIAMS & CO REP. MIU BHA #1 SPUD WELL @ 107 FT, 1330 HRS. DRILL AHEAD 9 7/8 HOLE DRCTNL, 107 - 350 FT. STAND BK 2 STDS 4" HWDP, PU JARS RESUME DRILL AHEAD 9 7/8 HOLE DRCTNL, 350 - 1125 FT. AVE ROP = 168 FPM UP 70, DN 66, ROT 71, WOB 25, RPM 80, PRESS 1980, SPM 220, GPM 652 ART = 4 HRS, AST = 2 HRS CONTINUE DRILLING FROM 1125' TO 1745'. AVG ROP = 132 FPH 652 GPM @ 2650 PSI PU = 83K DN = 75K ROT = 76K WOB = 30 TO 40K RPM = 80 AST = 2.68 HRS ART = 2.02 HRS CIRCULATE LO-VIS I HI-VIS WEIGHTED SWEEP. HOLE CLEAN. POH 10K TO 20K DRAG - NO SWABBING. CIO BIT. RIH. 10 - 25K DRAG FROM 500' TO 1650'. REAM LAST STAND TO BOTTOM @ 1745' DRILL FROM 1745' TO 3040'. (TO) UP 98, DN 81, ROT 92, AVE ROP 415 FPM AST =.7 HRS, ART = 1.1 HRS WOB 35, RPM 80, PRESS 3485, SPM 220, GPM 652 CIRC HI I LOW SWEEPS, NORMAL RETURNS AT SHAKER. FLOW CHECK, POH 5 STDS. RETURN TO BTM DUE TO SWABBING COMMENCE BACKREAM OUT OF HOLE. Printed: 4/30/2002 3:17:45 PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-101 V-101 DRILL +COMPLETE NABORS NABOR,S 9ES Start: 4/16/2002 Rig Release: 4/29/2002 Rig Number: 9-ES Spud Date: 4/17/2002 End: 4/29/2002 From-To Hoürs ..AbtiVity 4/18/2002 20:00 - 21 :30 1.50 DRILL P SURF 21 :30 - 22:00 0.50 DRILL P SURF 22:00 - 22:30 0.50 CASE P SURF 22:30 - 00:00 1.50 CASE P SURF 00:00 - 00:30 0.50 CASE P SURF 00:30 - 05:00 4.50 CASE P SURF 4/19/2002 05:00 - 05:30 0.50 CASE P SURF 05:30 - 08:00 2.50 CASE P SURF 08:00 - 10:30 2.50 CEMT P SURF 10:30 - 11 :00 0.50 CEMT P SURF 11 :00 - 13:00 2.00 CEMT P SURF 13:00 - 13:30 0.50 BOPSUR P SURF 13:30 - 15:30 2.00 BOPSURP SURF 15:30 - 19:30 4.00 BOPSURP PROD1 19:30 - 23:00 3.50 BOPSUR P PROD1 FLOW CHECK, LAY DN BHA #2 CLEAR RIG FLOOR ALL 9 7/8 DRLG EQUIP. MAKE DUMMY CSG HGR RUN, MARK LDG JT, INSURE CONNECTION ABOVE FLOWLINE. ' PLACE 7 5/8 CSG TOOLS ON FLOOR. MAKE UP 7518 GUIDE SHOE, 2 JTS 7 5/8 CSG, FLOAT SHOE, TEST FLOATS. HOLDING. RIH 7 5/8 29.7# L-80 BTC-MOD CSG. OBSTRUCTION AT 916 FT. WILL NOT PASS. WORK CSG VARIOUS METHODS, ROTATE, CIRC, SPUD THRU, CONT RIH, TIGHT HOLE TO 1300 FT, MUST RECIP TO PASS. RESUME RIH TO 2992 FT. INSTALL SPLIT LDG JT, LAND MANDREL HGR WITH SHOE AT 3022.64 FT. NO FILL. LAY DN FRANKS TOOL, MAKE UP CMT HD, COMMENCE CIRC I COND DRLG FLUID FOR CMT. STAGE UP TO 8 BPM @ 620 PSI. CONT CIRC I RECIP PIPE. NO LOSSES. 100% RETURNS. PJSM, BEGIN CMT 7 5/8 AS FOLLOWS: PUMP 5 BBL CW1 00, CLEAR LINES TEST LINES TO 3500 PSI PUMP 5 BBLS CW100 PUMP 75 BBLS MUDPUSH XL, 10.2 PPG DROP BTM PLUG, VERIFIED. PUMP 288 BBLS 10.7 PPG ARCTIC SET LITE III @ 6 BPM PUMP 37 BBLS 15.8 PPG, "G" TAIL SLURRY. DROP TOP PLUG, VERIFIED. FOLLOW WITH 1 0 BBLS WATER DISPLACE WITH RIG PUMP 125 BBLS @ 9 BPM. BUMP PLUG WITH 1465 PSI ( 1021 HRS) 65 BBLS CONTAMINATED CEMENT AND 95 BBLS GOOD 10.7 PPG CMT RETURNS AT SURFACE. NO LOSSES, RECIP UNTIL TAIL AROUND SHOE. BLEED PRESS, CHECK FLOATS HOLDING. OKAY. FLOW CHECK. LAY OUT CMT HD, LDG JT, CLEAR FLOOR ALL RELATED CSG EQUIP. CLEAN AREA BENEATH ROTARY TABLE NIPPLE DN DIVERTER SYSTEM, LAY OUT AND SECURE SAME. NIPPLE UP SPEED HD, TEST TO 1000 PSI I 15 MIN. NIPPLE UP BOPE, ALL RELATED COMPONENTS. SIM-OPS - CIO PUMP LINERS TO 5". TEST BOPE, RAMS, ALL LINES, VALVES, CHOKE MANIFOLD, STANDPIPE I PUMPS TO 250 I 4500 PSI. ANNULAR TO 250 I 3500 PSI. PERFORM ACCUMULATOR TIME I VOLUME I PRESS TEST. ALL TESTS SUCCESSFUL. NO RE-TESTS. WITNESS WAIVED BY CHUCK SHEVE AOGCC Printed: 4/30/2002 3:17:45 PM ) ~) I BP EXPLORATION Operations Summary Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-101 V-101 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/16/2002 Rig Release: 4/29/2002 Rig Number: 9-ES Spud Date: 4/17/2002 End: 4/29/2002 Date From - To Hours Activity Code NPT Phase Description of Operations 4/19/2002 23:00 - 23:30 0.50 BOPSUR P PROD1 REMOVE TEST PLUG, INSTALL WEAR RING, LAY OUT ALL TEST EQUIP. 23:30 - 00:00 0.50 BOPSUR P PROD1 PREPARE PICK UP 4" DP FROM SHED. 4/20/2002 00:00 - 00:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE, BLOCKS & CROWN. 00:30 - 07:00 6.50 DRILL P PROD1 P/U 4" DP FROM SHED & STAND BACK IN DERRICK. BRING BHA TOOLS TO FLOOR. 07:00 - 08:30 1.50 DRILL P PROD1 PJSM. MIU BHA # 3 08:30 - 09:00 0.50 DRILL P PROD1 RIH WITH HWDP. 09:00 - 09:30 0.50 DRILL P PROD1 SHALLOW TEST PWD & MOTOR. 09:30 - 10:00 0.50 DRILL P PROD1 RIH P/U DP SINGLES FROM SHED TO 1500'. 10:00 - 11 :00 1.00 DRILL P PROD1 HOLD KICK WHILE TRIPPING AND STRIPPING DRILLS. 11 :00 - 13:00 2.00 DRILL P PROD1 CONTINUE RIH WI DP FROM SHED TO 2900' 13:00 - 14:00 1.00 DRILL P PROD1 CUT & SLIP DRILLING LINE. 14:00 - 14:30 0.50 DRILL P PROD1 PRESSURE TEST CASING TO 3500 PSI FOR 30 MINUTES. 14:30 - 18:30 4.00 DRILL P PROD1 DRILL OUT CMT I FLOAT EQUIP (2910 - 3040), NEW FORMATION TO 3060 FT. 18:30 - 19:00 0.50 DRILL P PROD1 FLOW CHECK, DISPLACE WELL WITH 9.3 PPG DRLG FLUID. SHAKER CLEAN. 19:00 - 19:30 0.50 DRILL P PROD1 PERFORM LOT AT 2730 FT TVD. RESULTS = 625 PSI I 13.7 EMW. 19:30 - 20:00 0.50 DRILL P PROD1 ESTABLISH BENCHMARK ECD VALUES. 330 GPM 160 RPM = 10.72, 80 RPM = 10.74, 100 RPM = 10.75, 110 RPM = 10.76 ECD 20:00 - 00:00 4.00 DRILL P PROD1 RESUME DRILL AHEAD 6 3/4 HOLE DRCTNL, 3060 - 3595 FT. RECIP 3 - 5 STROKES I CIRC INITIAL THREE CONNECTIONS TO REMAIN WITHIN ECD LIMITS. THEREAFTER TO 3595 FT, ECD CONTROL WITH ONE BACKREAM PER CONNECTION. UP 95, ON 77, ROT 85 WOB 15, RPM 60, PRESS 2100, GPM 333, SPM 136 AST = 0 HRS, ART = 1.8 HRS 4/21/2002 00:00 - 02:30 2.50 DRILL P PROD1 DRILL FROM 3595' TO 4060'. BACKREAM EACH CONNRCTION WI 110 RPM @ 330 GPM. REAM DOWN WI 110 RPM @ 245 GPM. PU = 100K, DN = 79K, RT= 91 K. TQ = 2500 DRL @ 60 RPM & 330 GPM. SWEEP EVERY 200'. ART = 1.5 HRS AST = 0.2 HRS 02:30 - 03:30 1.00 DRILL P PROD1 CIRC. SWEEP - RECIP. 110 RPM & 330 GPM UP - 245 GPM DN. ECD = 11.5 PPG. 03:30 - 04:30 1,00 DRILL P PROD1 POH TO SHOE. SLIGHT SWABBING & INTERMITTANT OVERPULLS TO 15 K FROM 3800' 04:30 - 05:00 0.50 DRILL P PROD1 SERVICE TOP DRIVE, BLOCKS, & CROWN. 05:00 - 06:30 1.50 DRILL P PROD1 RIH. TAG UP AT 3415'. REAM TO 3498' OK. CONT. RIH. TO 3970'. WASH TO BTM @ 4060'. 06:30 - 15:00 8.50 DRILL P PROD1 DRILL FROM 4060' TO 5179'. SAME PARAMETERS, PU = 122K DN = 89K, RT = 103K TQ = 4800. 337 GPM @ 2950 PSI. ART = 3.22 HRS AST = 1.27 HRS 15:00 - 16:00 1,00 DRILL P PROD1 CIRCULATE HI-VIS SWEEP. CALC. ECD = 11.29 PPG ACTUAL ECD = 11.6 PPG 16:00 - 17:30 1.50 DRILL P PROD1 POH TO SHOE. NO PROBLEMS. 17:30 - 18:00 0.50 DRILL P PROD1 SERVICE RIG, TOP DRIVE. 18:00 - 18:30 0.50 DRILL P PROD1 FLOW CHECK, RIH TO BRIDGE AT 3720 FT. TAKE MAX Printed: 4/30/2002 3:17:45 PM Legal Well Name: V-1 01 Common Well Name: V-101 Spud Date: 4/17/2002 Event Name: DRILL +COMPLETE Start: 4/16/2002 End: 4/29/2002 Contractor Name: NABORS Rig Release: 4/29/2002 Rig Name: NABORS 9ES Rig Number: 9-ES Date From-To Hours . Activity Code NPT Phase 4/21/2002 18:00 - 18:30 0.50 DRILL P PROD1 ALLOWED WT, WILL NOT PASS. 18:30 - 19:30 1.00 DRILL P PROD1 REAM I BACKREAM 3720, 3870, 4300 FT. 19:30 - 20:00 0.50 DRILL P PROD1 RESUME RIH TO 5090 FT. PRECAUTION WASH TO BTM, NO FILL. TIGHT AT 5005 FT. 20:00 - 00:00 4.00 DRILL P PROD1 DRILL AHEAD 6 3/4 HOLE DRCTNL, 5179 - 5489 FT. ECD WITHIN LIMITS. AVE ROP 306 WOB 10, RPM 60, PRESS 2800, SPM 136, GPM 333 AST = .75 HRS, ART =.1 HR 4/22/2002 00:00 - 08:30 8.50 DRILL P PROD1 DRILL AHEAD 6 3/4 HOLE DRCTNL 5489 - 6391 FT. 08:30 - 09:00 0.50 DRILL P PROD1 CIRC, RECIP PIPE, REDUCE ECD (12.5) TO ACCEPTABLE LEVEL (11.4) 09:00 - 12:30 3.50 DRILL P PROD1 RESUME DRILL AHEAD 6391 - 6672 FT. WOB 10-12, RPM 80, PRESS 3300, GPM 333, SPM 136 UP 144, DN 95, ROT 113 12:30 - 14:00 1.50 DRILL P PROD1 CIRC SWEEPS, ECD 11.6 14:00 - 15:00 1.00 DRILL P PROD1 FLOW CHECK, POH FOR WIPER TRIP TO 4992 FT. WELLBORE GOOD CONDo 15:00 - 15:30 0.50 DRILL P PROD1 FLOW CHECK, RIH TO 6582, PRECAUT. WASH TO BTM, NO FILL. 15:30 - 20:00 4.50 DRILL P PROD1 DRILL AHEAD 6 3/4 HOLE DRCTNL 6672 - 7140 FT, NOTE LOSSES 20 BPH 20:00 - 21 :00 1.00 DRILL P PROD1 CIRC LCM, REDUCE LOSSES TO 3 BPH. 21 :00 - 22:00 1.00 DRILL P PROD1 RESUME DRILL AHEAD 7140 -7233 FT. NOTE PRESS INCREASE SPP. WOB 10-12, RPM 80, PRESS 3300, GPM 333, SPM 136 UP 144, DN95, ROT113 AST = 2.33 HRS, ART = 8.95 HRS 22:00 - 23:30 1.50 DRILL N DFAL PROD1 TROUBLESHOOT FOR PLUGGED JETS I LOCKED MOTOR. POSSIBLE MOTOR FAILURE. 23:30 - 00:00 0.50 DRILL N DFAL PROD1 FLOW CHECK, POH FOR MOTOR. 4/23/2002 00:00 - 03:00 3.00 DRILL N DFAL PROD1 Cont poh for motor, work pipe at 6775,6460. 15 - 20 drag. 03:00 - 04:00 1.00 DRILL N DFAL PROD1 Flow check. Layout drctnl assy, motor I mwd I pwd. Motor damaged I locked up. 04:00 - 04:30 0.50 DRILL N DFAL PROD1 Clear rig floor. 04:30 - 05:30 1.00 DRILL N DFAL PROD1 Make up new drctnl assy, orient motor to mwd. 05:30 - 06:00 0.50 DRILL N DFAL PROD1 Rih hwdp, shallow test drctnl equip. 06:00 - 07:00 1.00 DRILL N DFAL PROD1 Flow check. Follow hwdp with 4' DP to shoe at 3122 ft. 07:00 - 08:30 1.50 DRILL N DFAL PROD1 Service top drive, blocks, crown. Slip / cut drlg line. Inspect I adjust brakes. 08:30 - 10:00 1.50 DRILL N DFAL PROD1 Flow check, resume rih 4" dp to 7143 ft. Precaut. wash 90 ft to btm. No fill. 10:00 - 00:00 14.00 DRILL P PROD1 Resume drill ahead 6 3/4 hole drctnl 7233 - 8131 ft. ECDs within limits. WOB 10, RPM 80, PRESS 2830, GPM 326, SPM 133 Up 175, Dn 94, Rot 124 AST = 3.67 hrs, ART= 4.83 hrs 4/24/2002 00:00 - 05:30 5.50 DRILL P PROD1 Cont drill ahead 6 3/4 hole drctnl, 8131 - 8442 ft. 05:30 - 07:00 1.50 DRILL P PROD1 Circ I cond, pump sweeps, reduce ECD to acceptable levels for wiper trip. 07:00 - 08:00 1.00 DRILL P PROD1 Flow check, poh to 7130 ft. Slight swabbing to 7474, wellbore good condo Printed: 4/30/2002 3:17:45 PM Legal Well Name: V-1 01 Common Well Name: V-101 Spud Date: 4/17/2002 Event Name: DRILL +COMPLETE Start: 4/16/2002 End: 4/29/2002 Contractor Name: NABORS Rig Release: 4/29/2002 Rig Name: NABORS 9ES Rig Number: 9-ES From-To Hours ActivitYCÖde NPT Phase 4/24/2002 08:00 - 08:30 0.50 DRILL P PROD1 Flow check, rih to 8352 ft. No down drag. 08:30 - 09:00 0.50 DRILL P PROD1 Precaut. wash 90 ft to btm, no fill. Pump sweep with wash. 09:00 - 00:00 15.00 DRILL P PROD1 Resume drill ahead 6 3/4 hole, 8442 - 9376 ft with sweeps I ECD control. Up 201, Dn 112, Rot 144 WOB 17, RPM 80, Press 3250, SPM 133, GPM 326 AST = 3.97 hrs, ART = 11.03 hrs. 4/25/2002 00:00 - 01 :30 1.50 DRILL P PROD1 Drill ahead 6 3/4 hole drcntl 9376 - 9480 ft (TD), as confirmed by on site geologist. WOB 12, RPM 80, PRESS 3270, SPM 123, GPM 326 AST = 0 hrs, ART = 1 hr Up 203, Dn 116, Rot 147 01 :30 - 03:00 1.50 DRILL P PROD1 Circ I cond, pump sweeps, reduce ECD. 03:00 - 03:30 0.50 DRILL P PROD1 Flow check, poh wiper trip to 8345 ft. 20 - 25 over pull. No swabbing. Recip first 3 stands, work free. 03:30 - 04:00 0.50 DRILL P PROD1 Flow check, rih to 9399 ft. Wellbore good condo 04:00 - 06:00 2.00 DRILL P PROD1 Precaut. wash 180 ft to btm, no fill. Circ I cond, spot logging pill, wt pill. 06:00 - 10:00 4.00 DRILL P PROD1 Flow check, drop dp drift, poh to shoe. Tight at 8920 ft, recip, work free. Resume poh to hwdp. 10:00 - 11 :30 1.50 DRILL P PROD1 Handle bha, layout drctnl equip. 11 :30 - 12:00 0.50 DRILL P PROD1 Clear rig floor. 12:00 - 13:30 1.50 DRILL P PROD1 Service top drive, "grabber", service crown. 13:30 - 15:00 1.50 EVAL N WAIT PROD1 Wait on arrival Schlum, can not pass wide load. 15:00 - 16:00 1.00 EVAL P PROD1 PJSM (Wireline Work), place Shclum. equip on rig floor, rig up same. 16:00 - 19:00 3.00 EVAL P PROD1 Rih wireline, PEX I Sonic. Had minor set downs @ 3850', 5580',5860', & 6075'. Appeared to be pushing something ahead of tools. Set down @ 6150' and worked -45 min to make any headway. Free to 6900'. Can not pass 6900 ft, work back to 6670 ft. Loosing ground. 19:00 - 23:30 4,50 EVAL P PROD1 Commence log from 6630 - 3023 ft (Shoe). Logs successful. Poh to surface, layout, prepare for DPC logs. 23:30 - 00:00 0.50 EVAL P PROD1 PJSM (DPC Logging) 4/26/2002 00:00 - 02:00 2.00 EVAL P PROD1 Assemble tools for DPC logs. 02:00 - 03:30 1.50 EVAL P PROD1 Make up logging equip to hwdp, rih same, (PEX - SONIC) 03:30 - 04:00 0.50 EVAL P PROD1 Break circ at shoe, 3022 ft., hang SWS sheaves. 04:00 - 06:00 2.00 EVAL P PROD1 Flow check, rih, slo-go, caution with log tools. 06:00 - 07:30 1.50 EVAL P PROD1 Circ at 5600 ft to stop dp overflow. 07:30 - 08:30 1.00 EVAL P PROD1 Resume rih to 6574 ft. No overflow. 08:30 - 10:00 1.50 EVAL P PROD1 Assemble XOs, side entry sub, latch up, test tools. 10:00 - 16:00 6.00 EVAL P PROD1 Commence log well 6582 - 9411 ft. 3 min per stand. Begin log up, 9411 - 6572 ft. No problems. 16:00 - 20:00 4.00 EVAL P PROD1 Attempt unlatch, numerous pulls, pull free with rig blocks I "T" bar 1 0,000 pull. Poh wireline. Wire parted in correct area, "weak point", leaving 2 ft stub top of tooling. Attempt circ, no-go. DP plugged at logs. 20:00 - 21 :30 1.50 EVAL P PROD1 Poh 4" dp to shoe 3022 ft. Flow check. 21 :30 - 22:00 0.50 EVAL P PROD1 Layout sheaves I all Schlum equip. 22:00 - 23:00 1,00 EVAL P PROD1 Resume poh, handle hwdp. 23:00 - 00:00 1,00 EVAL P PROD1 PJSM, Remove "source" from log tools, break out remainder, Printed: 4/30/2002 3:17:45 PM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-101 V-101 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/16/2002 Rig Release: 4/29/2002 Rig Number: 9-ES Spud Date: 4/17/2002 End: 4/29/2002 From-To HoUrs Activity Code NPT 4/26/2002 23:00 - 00:00 1.00 EVAL P PROD1 4/27/2002 00:00 - 03:00 03:00 - 04:30 3.00 CASE P 1.50 CASE P PROD1 COMP 04:30 - 05:30 1.00 CASE P COMP 05:30 - 06:30 1.00 CASE P COMP 06:30 - 07:00 0.50 CASE P COMP 07:00 - 08:30 1.50 CASE P COMP 08:30 - 12:30 4.00 CASE P COMP 12:30 - 15:30 3.00 CASE P COMP 15:30 - 20:30 5.00 CASE P COMP 20:30 - 21 :30 1.00 CASE P COMP 21 :30 - 22:00 0.50 CASE P COMP 22:00 - 23:00 1.00 CASE P COMP 23:00 - 00:00 1.00 CASE P COMP 4/28/2002 00:00 - 04:00 4.00 CASE P COMP 04:00 - 04:30 0.50 CASE P COMP 04:30 - 05:30 1.00 CASE P COMP 05:30 - 08:30 3.00 CASE P COMP 08:30 - 10:30 2.00 CASE P COMP 10:30 - 12:30 2.00 CASE P COMP 12:30 - 13:30 1.00 CASE P COMP 13:30 - 17:30 4.00 CASE P COMP 17:30 - 18:00 0.50 CASE P COMP 18:00 - 21 :00 3.00 CASE P COMP 21 :00 - 21 :30 21 :30 - 22:30 22:30 - 23:30 23:30 - 00:00 0.50 CASE P 1.00 CASE P 1.00 RUNCOrvP 0.50 RUNCOrvP COMP COMP COMP COMP discover formation particles top of latch, layout same, clear floor. Clear I clean rig floor. Install test plug, test bope as per Co specs: (Rams) 250 I 4500 psi - 5 min. (Annular) 250 I 3500 - 5 min. (Kill, choke, standpipe, pumps, floor safety valves) 250 I 4500 - 5min. Perform accumulator time I volume / press test. All tests successful, no retests. Witness waived by John Spaulding AOGCC. Pull test plug, blow dn lines. Make up 6 3/4 hole opener assy, rih on hwdp. Follow with 4"dp, to shoe at 3022 ft. Circ btms up. Slip I cut drlg line, service top drive, crown. Flow check, rih, break circ 10 std intervals. Circ btms up a 6250. Rih to 9390 ft. Wellbore exc condo Circ I cond sweeps, spot liner pill. Pump wt pill. Flow check, poh std bk 25 stds, lay dn remainder 4" dp. Stand bk hwdp, layout hole opener. Perform "dummy" run with 5 1/2 csg hgr. PU csg run equip, place on rig floor, rig up same. PJSM (CSg run procedure), begin PU float equip. Cont rih 3 1/2, 5 1/2 csg. to 7 5/8 shoe at 3022 ft. Pick up 200 ton elevators, install "Franks" tool. Circ 1.5 times csg volume. 100% returns. Resume rih 5 1/2 csg, break circ 1000 ft inervals. Note csg csg giving improper displacement. Losing fluid. Circ, string in Barafiber, regain 100% returns. Flow check, resume rih to 6900 ft. Break circ 1000 ft intervals. Atempt break circ 6900 ft, minimal returns, cont circ losing returns completely. Resume rih, make Idg jt, land csg at 9462 ft. Attempt break circ various depths, no returns. Remove "Franks" tool, install cmt hd, blow dn top drive. PJSM (Cmt procedure), commence cmt 5 1/2 X 3112 csg as follows: Pump 5 bbl CW 100, test lines, pump 20 bbl CW100, pump 40 bbl Mudpush Mix I pump 67 bbls Litecrete 11.8 ppg lead, pump batch mixed 43 bb115.8 ppg "G" tail slurry. Drop latched top and btm plugs, verified drop. clear lines. Displace with rig pump, 213 bbls sea water, 170 bbls 3.5 bpm, 20 bbls 3 bpm, 12 bbls 2.5@ bpm, 11@ 2 bpm. Bump plug correct displacement (2 bpm 1600 psi.) Build to 2100 psi, hold 5 min, bleed, floats holding. Recip csg entire job, no returns at any time. Bump plug 2040 hrs, FCP 1600 psi @ 2 bpm Lay dn cmt hd, bk out Idg jt, flush stack. Install 5 1/2 pkf, test to 5000 psi. Test sucessful. Place tbg run equip on rig floor, rig up same. PJSM, function test bope, flow test, assemble completion bha. Printed: 4/30/2002 3:17:45 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-101 V-101 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/16/2002 Rig Release: 4/29/2002 Rig Number: 9-ES Spud Date: 4/17/2002 End: 4/29/2002 Hpurs Activity Gode NPT 4/29/2002 00:00 - 08:00 08:00 - 13:30 8.00 RUNCOrvP 5.50 RUNCOrvP COMP COMP 13:30 - 15:30 2.00 RUNCOrvP COMP 15:30 - 18:00 2.50 RUNCOrvP COMP 18:00 - 19:30 1.50 RUNCOrvP COMP 19:30 - 20:00 0.50 RUNCOrvP COMP 20:00 - 22:00 2.00 RUNCOrvP COMP 22:00 - 22:30 0.50 RUNCOrvP COMP 22:30 - 00:00 1.50 RUNCOrvP COMP Cont rih 3 1/2 tbg. Circ, stab into PBR, note press buildup, bleed, cont into PBR, take space out measurements. Make up tbg hgr I pups, dbl check spaceout. Sting out PBR, displace with seawater I inhibitor. Stab into PBR, land tbg hgr, run in LDSs. Test hgr seals. Brk out Idg jt, blow dn lines. LOT performed 7 5/8 X 5112 annulus ( 12.77 ppg ) during this period. Bullhead 60 bbl mud I freeze protect with 39 bbls crude. Test tbg to 4500 psi / 30 min. Bleed tbg to 3000 psi. Test annulus to 4500 psi I 30 min. Bleed annulus, RP shears at 2700 psi. Install TWC, test from below check to 2800 psi. All tests successful. No re-tests. Nipple dn bope Nipple up prod tree, test all components to 5000 psi 115 min. Test good. Remove TWC Freeze protect with 115 bbls diesel. Allow "U" tube. Flow check. "0" psi. Install bpv, test to 1000 psi. Secure well, remove secondary annulus valve. RELEASE NABORS RIG 9-ES THIS DATE, 2359 HRS BPV IN PLACE Printed: 4/30/2002 3:17:45 PM ) ') V-101 Prudhoe Bay Field / Borealis 50-029-23074-00 202-056 Rig Accept: 04/17/02 Rig Spud: 04/17/02 Rig Release: 04/29/02 Nabors 9ES POST RIG WORK 05/03/02 DRIFT WI 2.511, 10. DUMMY GUN & SAMPLE BAILER TO 92941 WLMD. POOH WI SMALL BITS OF CEMENT IN BAILER. CEMENT BOND LOG AND JEWERL Y LOG RAN FORM TD@ 93081 TO 85001. BOND LOG RAN @ 0 AND 1000 PSI WHP. FIELD EVALUATION IS BOND LOOKS GOOD FOR KUPARUK C SAND ISOLATION. 05/04/02 PERFORATED INTERVAL 8914 - 8950 FT WITH 2.511 HSD GUNS, 6 SPF, BH, POWERFLOW CHARGES. ---- INJECTIVITY TEST RESUL T- 1.5 BPM @ 2450 PSI. PUMP DIESEL DOWN TUBING TO TRY TO FREE SCHLUMBERGER PERF GUN. 05/06/02 S-LlNE ASSIST - PUMP DIESEL TO TRY FLUSH METALLlCS WHILE BRUSHING. PUMPED 10 BBLS DIESEL @2.1 BBLS/MIN 2775 PSI, S-LlNE STARTED IN - SLOWED RATE TO .5 BBUMIN, INCREASED RATE TO 1 BBUMIN AT 15 BBLS, INCR. RATE TO 2 BBUMIN AT 30 BBLS @ 2800 PSI, PUMPED TOTAL OF 83 BBLS DIESEL. DRIFT TBG & TAG FILL @ 9282' WLMD, WI 2.7 CENT & SAMPLE BAILER @ 92821 WLMD -- RUN PETRODAT STATIC SURVEY -- PULL RIP SHEAR VALVE FROM GLM # 1 -- SET DGLV IN SAME 05/07/02 ASSIST WI FRAC I HOLD 3300-3500 PSI ON IA. FRACID KUPARUK C4/C3 SDS WITH YF125LG SYSTEM AND 159.6K# 16/20 C-LlTE. SCREENED OUT 64 BBLS INTO 16/20,10 PPGA STAGE TO 7485 PSI. PLACED 88 BBLS OF 9 PPGA (135.3K#) BEHIND PIPE LEAVING 24.3K# IN TBG/CSG. LOAD TO RECOVER IS 1000 BBlS. WELL NOT FREEZE PROTECTED, HEATER APPLIED TO TREE. LOST 1/4 OF ONE TREESAVER CUP ( 211 X 1.7511 X 1/411) IN HANGER. SAND NEAR SURFACE. 05/08/02 MIRU DS CTU #8. PERFORM WEEKLY BOP TEST. MU AND RIH WITH 2.2511 JSN. DRY TAG TOP OF SAND AT 1170 CTMD. CLEAN OUT TO 8700 CTMD. 05/09/02 CLEANED OUT FRAC SAND TO PBTD 93401 CTMD. PULLED UP HOLE ABOVE THE PERFS PUMP STARTED KICKING OUT. PULLED UP HOLE TO 70881 CTMD. FIGURING OUT PROBLEM. GOT PUMP RUNNING HAVING TO HOLD IN MURPHY SWITCH, RBIH TO 9340' CTMD, HAD JUST GOT SLK 1 % KCL TO NOZZLE AND STARTED POOH ON FINAL SWEEP. STARTED OUT OF HOLE, HUNG UP AT 93001 CTMD. UNABLE TO GET FREE, ORDER OUT N2. WORKED PIPE, PUMPED N2, FREE UP PIPE AFTER 15 HRS. POOH JETTING WHILE FLOWING WELL. WAIT ON ADDITIONAL WATER. RIH WITH 2.2511 NOZZLE PUMPING KCL WIHEC SWEEPS TO 8600' CTMD. POOH AT 80% JETTING THROUGH GLM1S TO 4500'. GETTING A LOT OF SAND BACK, RUN BACK IN HOLE TO 75001 AND MAKE ONE MORE SWEEP THROUGH THE BUILD SECTION OF THE HOLE WITH HEC GEL. 05/10/02 RAN IN HOLE TO 7500' CTMD, POOH AT 80% JET WASHING GLM1S. FREEZE PROTECT TUBING TO 3000' WITH NEAT MEOH. 05/11/02 D&T, UNABLE TO PULL SPMG IN # 1 GLM COVERED WITH FRAC SAND. ') ,I ') V-101, Post Rig Summary Page 2 05/12/02 ATTEMPT TO PULL CATCHER SUB, UNABLE TO LATCH FISHING NECK, START BAILING FRAC SAND OFF TOP OF C.S 05/13/02 BAILING FILL TO RETRIEVE CS. CS LEFT IN WELL AT 8574' SLM. 05/15/02 ATTEMPT TO PULL 3 1/211 WIDDEN CS.*** PRESSURE LUBRICATOR TO 400 PSI EACH TIME BEFORE OPENING TO WELL. 05/16/02 BAIL FRAC SAND, ATTEMPT TO PULL WHIDDON CS (W/O SUCCESS) 06/11/02 LAY RIG MATS ON LOCATION. SPOT UNIT. MU & RIH WITH BHA #1 (2.7011 G-SPEAR). START JETTING DOWN WITH GEL DIESEL AT 8000" CTMD. SET DOWN SOLID AT 8633' CTMD, LATCHED AND PULL WL CATCH SUB, POOH. TURN WELL OVER TO APe TEST UNIT. 06/17/02 PUMP 140 BBLS OF 180 DEG DIESEL AND 20 BBLS OF METHANOL DOWN THE INNER ANNULUS. 06/18/02 PULL SPMG FROM STA.# 1 & LGLV"S FROM STA. # 2 & 3 -- SET LGLV IN ST'S 2 AND 3 -- SET OGLV IN ST # 1 -- PULL CATCHER SUB. ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field........... .........: Prudhoe Bay / Borealis Well. . . . . . . . . . . . . . . . . . . . .: V-101 API number....... ........: 50-029-23074-00 Engineer.................: St. Amour Rig: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions. ....: Minimum curvature Method for DLS.. ....... ..: Mason & Taylor ----- Depth reference ----------------------- Permanent datum... .......: Mean Sea Level Depth reference...... ....: Drill Floor GL above permanent.... ...: 53.85 ft KB above permanent.......: Top Drive DF above permanent.......: 82.30 ft ----- Vertical section origin---------------- Latitude (+N/S-)..... ....: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-) .... .....: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 295.46 degrees [(c)2002 Anadrill IDEAL ID6_1C_10] 25-Apr-2002 15:43:44 Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey..... ...: Page 1 of 5 17-Apr-02 25-Apr-02 104 0.00 ft 9480.00 ft '--- ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date.. ..........: 17-Apr-2002 Magnetic field strength..: 1149.51 HCNT Magnetic dec (+E/W-) .....: 26.07 degrees Magnetic dip..... ........: 80.76 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: H..............: Dip. . . . . . . . . . . . : of G...........: of H...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.51 HCNT 80.76 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 26.07 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 26.07 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ... .....: No degree: 0.00 -- ANADRILL SCHLUMBERGER Survey Report --- -------- -------- Seq Measured # depth (ft) 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 -------- -------- 1 2 3 4 5 0.00 104.76 195.83 291.90 383.97 477.80 570.78 664.18 758.17 851.33 936.47 1030.54 1122.63 1217.13 1311.61 1405.32 1498.95 1591.76 1687.13 1775.70 1870.22 1963.30 2055.57 2149.50 2242.50 2336.88 2430.75 2524.26 2617.12 2710.30 ------ ------ Incl angle (deg) ------ ------ 0.00 0.10 0.68 1.08 1.30 2.27 3.00 3.85 5.23 5.63 5.41 6.47 7.48 9.36 12.26 14.21 16.47 19.40 19.44 22.63 25.30 28.77 31.55 35.32 38.12 41.87 42.72 44.63 44.50 44.60 ------- ------- ------ ------ Azimuth Course angle length (deg) ( f t ) ------- ------- 0.00 62.80 62.94 60.48 348.37 336.22 338.93 339.75 331.85 325.72 323.54 310.34 296.79 288.67 290.83 288.71 290.68 294.78 294.65 294.16 295.19 293.36 294.03 294.85 293.73 293.51 295.55 296.71 296.77 297.15 ------ ------ 0.00 104.76 91.07 96.07 92.07 93.83 92.98 93.40 93.99 93.16 85.14 94.07 92.09 94.50 94.48 93.71 93.63 92.81 95.37 88.57 94.52 93.08 92.27 93.93 93.00 94.38 93.87 93.51 92.86 93.18 -------- -------- TVD depth (ft) -------- -------- 0.00 104.76 195.83 291.89 383.94 477.72 570.61 663.84 757.53 850.27 935.02 1028.59 1120.00 1213.48 1306.27 1397.49 1487.78 1576.08 1666.02 1748.68 1835.04 1917.94 1997.71 2076.08 2150.62 2222.91 2292.35 2359.98 2426.14 2492.54 25-Apr-2002 15:43:44 -------- -------- Vertical section (ft) -------- -------- 0.00 -0.06 -0.43 -1.30 -1.17 0.88 4.04 8.06 13.77 21.13 28.28 37.32 48.33 62.11 79.74 101.08 125.72 154.25 185.96 217.74 256.13 298.41 344.74 396.48 452.07 512.68 575.84 640.40 705.55 770.89 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 0.00 0.04 0.32 1.03 2.48 5.22 9.18 14.40 21.14 28.66 35.34 42.34 48.40 53.63 59.66 66.89 75.26 86.37 99.63 112.75 128.79 146.15 164.79 186.21 209.06 233.36 259.59 288.04 317.36 346.99 0.00 0.08 0.63 1.93 2.47 1.51 -0.11 -2.07 -5.19 -9.76 -14.50 -21.18 -30.48 -43.25 -59.91 -80.11 -103.41 -129.72 -158.53 -187.48 -222.35 -260.93 -303.37 -350.47 -401.15 -456.72 -514.18 -572.14 -630.34 -688.60 Page --------------- --------------- Total displ (ft) At Az im (deg) --------------- --------------- 0.00 0.09 0.71 2.19 3.50 5.44 9.18 14.55 21.77 30.28 38.20 47.34 57.20 68.90 84.55 104.36 127.90 155.85 187.23 218.77 256.96 299.07 345.23 396.86 452.36 512.88 575.99 640.56 705.72 771.09 0.00 62.80 62.91 61.91 44.92 16.12 359.33 351.81 346.22 341.19 337.69 333.43 327.80 321.11 314.88 309.86 306.05 303.66 302.15 301.02 300.08 299.25 298.51 297.98 297.53 297.06 296.79 296.72 296.72 296.74 2 of 5 ----- DLS (deg/ 100f) 0.00 0.10 0.64 0.42 1.53 1.10 0.80 0.91 1.61 0.76 0.36 1.83 2.09 2.35 3.10 2.14 2.48 3.44 0.06 3.61 2.86 3.83 3.03 4.04 3.10 3.98 1.72 2.21 0.15 0.31 ------ ------ Srvy tool type Tool qual type ------ ------ TIP INC. Only MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - --- MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - -' MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - ANADRILL SCHLUMBERGER Survey Report 25-Apr-2002 15:43:44 Page 3 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2803.73 44.26 297.31 93.43 2559.26 836.27 376.92 -746.76 836.49 296.78 0.38 MWD_IFR_MSA - 32 2897.08 43.96 296.84 93.35 2626.29 901.22 406.50 -804.61 901.46 296.80 0.48 MWD - IFR_MSA - 33 2979.64 43.69 296.91 82.56 2685.85 958.37 432.34 -855.61 958.63 296.81 0.33 MWD - IFR_MSA - 34 3069.03 44.70 299.63 89.39 2749.95 1020.59 461.86 -910.47 1020.91 296.90 2.40 MWD- IFR_MSA - 35 3162.72 45.05 298.41 93.69 2816.34 1086.57 493.92 -968.27 1086.97 297.03 0.99 MWD_IFR_MSA - 36 3257.26 44.60 298.31 94.54 2883.39 1153.13 525.58 -1026.92 1153.60 297.10 0.48 MWD - IFR_MSA - 37 3350.80 44.51 298.89 93.54 2950.05 1218.66 556.99 -1084.54 1219.21 297.18 0.45 MWD IFR_MSA - ~ - 38 3444.53 44.08 299.38 93.73 3017.14 1283.98 588.86 -1141.71 1284.63 297.28 0.59 MWD _IFR_MSA - 39 3536.74 43.21 299.06 92.21 3083.86 1347.48 619.93 -1197.26 1348.23 297.37 0.97 MWD - IFR_MSA - 40 3628.38 44.54 300.05 91.64 3149.92 1410.83 651.26 -1252.50 1411.70 297.47 1.63 MWD _IFR_MSA - 41 3720.60 45.99 298.09 92.22 3214.83 1476.20 683.08 -1309.76 1477.18 297.54 2.18 MWD_IFR_MSA - 42 3812.73 45.76 297.90 92.13 3278.97 1542.27 714.12 -1368.15 1543.31 297.56 0.29 MWD- IFR_MSA - 43 3906.13 45.09 298.16 93.40 3344.52 1608.74 745.39 -1426.88 1609.84 297.58 0.74 MWD- IFR_MSA - 44 3999.08 45.39 296.09 92.95 3409.98 1674.70 775.47 -1485.62 1675.83 297.56 1.61 MWD - IFR_MSA - 45 4092.16 45.54 296.00 93.08 3475.26 1741.05 804.60 -1545.23 1742.16 297.51 0.18 MWD_IFR_MSA - 46 4185.75 45.37 295.98 93.59 3540.91 1807.75 833.83 -1605.18 1808.84 297.45 0.18 MWD - IFR_MSA - 47 4280.19 44.91 296.66 94.44 3607.53 1874.68 863.51 -1665.19 1875.77 297.41 0.71 MWD- IFR_MSA - 48 4373.57 44.36 295.92 93.38 3673.97 1940.28 892.57 -1724.01 1941.36 297.37 0.81 MWD_IFR_MSA - 49 4466.94 44.43 293.89 93.37 3740.69 2005.59 920.08 -1783.25 2006.62 297.29 1.52 MWD_IFR_MSA - 50 4560.23 44.38 294.21 93.29 3807.34 2070.85 946.68 -1842.86 2071.79 297.19 0.25 MWD _IFR_MSA - 51 4652.80 44.44 293.47 92.57 3873.47 2135.60 972.86 -1902.11 2136.46 297.09 0.56 MWD _IFR_MSA - '-'" 52 4746.62 44.03 293.88 93.82 3940.69 2201.02 999.14 -1962.05 2201.80 296.99 0.53 MWD- IFR_MSA - 53 4839.56 43.55 293.36 92.94 4007.78 2265.30 1024.91 -2020.98 2266.01 296.89 0.65 MWD- IFR_MSA - 54 4932.80 43.60 294.67 93.24 4075.33 2329.55 1051.07 -2079.68 2330.20 296.81 0.97 MWD_IFR_MSA - 55 5026.32 45.95 293.03 93.52 4141.72 2395.38 1077.68 -2139.92 2395.97 296.73 2.80 MWD- IFR_MSA - 56 5119.51 47.90 293.99 93.19 4205.36 2463.41 1104.84 -2202.34 2463.93 296.64 2.22 MWD_IFR_MSA - 57 5213.97 49.04 293.25 94.46 4267.99 2534.08 1133.17 -2267.13 2534.55 296.56 1.34 MWD_IFR_MSA - 58 5307.86 51.52 292.81 93.89 4327.98 2606.23 1161.41 -2333.58 2606.63 296.46 2.67 MWD - IFR_MSA - 59 5401.19 53.68 294.37 93.33 4384.67 2680.32 1191.10 -2401.52 2680.67 296.38 2.67 MWD _IFR_MSA - 60 5493.19 54.64 294.49 92.00 4438.54 2754.89 1221.94 -2469.42 2755.21 296.33 1.05 MWD- IFR_MSA - ANADRILL SCHLUMBERGER Survey Report --- -------- -------- Seq Measured # depth (ft) 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 -------- -------- 5587.03 5679.22 5772.70 5866.49 5957.81 6052.38 6144.92 6238.96 6332.60 6426.12 6519.48 6613.19 6706.69 6799.88 6893.32 6987.56 7080.70 7174.07 7269.16 7361.28 7452.26 7545.16 7638.65 7732.05 7826.15 7918.69 8012.27 8104.07 8197.97 8290.20 ------ ------ Incl angle (deg) ------ ------ 57.35 57.37 57.26 57.34 57.15 56.54 55.58 56.73 56.45 56.28 56.09 57.36 56.56 56.26 55.55 55.70 55.13 55.93 54.97 56.60 57.13 57.22 57.13 56.92 55.35 50.84 49.24 45.11 42.70 40.27 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 295.19 296.09 295.29 294.26 293.87 294.15 293.30 293.09 292.69 291.53 291.37 293.70 293.24 295.63 295.54 296.75 296.86 297.87 296.89 297.26 298.53 296.55 296.83 297.16 296.51 295.73 295.86 294.11 292.96 292.48 ------ ------ 93.84 92.19 93.48 93.79 91.32 94.57 92.54 94.04 93.64 93.52 93.36 93.71 93.50 93.19 93.44 94.24 93.14 93.37 95.09 92.12 90.98 92.90 93.49 93.40 94.10 92.54 93.58 91.80 93.90 92.23 -------- -------- TVD depth (ft) -------- -------- 4491.01 4540.74 4591.22 4641.89 4691.30 4743.02 4794.69 4847.06 4898.62 4950.42 5002.38 5053.80 5104.77 5156.34 5208.72 5261.93 5314.79 5367.64 5421.57 5473.37 5523.10 5573.46 5624.14 5674.97 5727.41 5782.96 5843.06 5905.46 5973.10 6042.19 25-Apr-2002 15:43:44 -------- -------- Vertical section (ft) -------- -------- 2832.67 2910.30 2988.98 3067.90 3144.67 3223.82 3300.55 3378.60 3456.68 3534.41 3611.79 3690.02 3768.36 3845.96 3923.34 4001.11 4077.77 4154.71 4232.98 4309.12 4385.24 4463.24 4541.79 4620.11 4698.22 4772.20 4843.92 4911.23 4976.30 5037.32 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) Page --------------- --------------- Total displ (ft) ---------------- ---------------- 1254.62 1288.21 1322.32 1355.39 1386.71 1418.93 1449.82 1480.58 1510.98 1540.29 1568.65 1598.69 1629.90 1662.01 1695.43 1729.70 1764.28 1799.66 1835.68 1870.36 1906.00 1942.09 1977.38 2012.95 2048.22 2080.80 2112.01 2140.48 2166.49 2190.09 -2540.00 -2609.99 -2680.89 -2752.55 -2822.67 -2895.00 -2965.28 -3037.07 -3109.08 -3181.21 -3253.41 -3325.76 -3397.65 -3468.32 -3538.11 -3607.93 -3676.37 -3744.73 -3814.27 -3882.10 -3949.43 -4018.64 -4088.83 -4158.65 -4228.37 -4294.79 -4359.37 -4420.36 -4480.05 -4536.40 At Azim (deg) --------------- --------------- 2832.97 2910.59 2989.26 3068.16 3144.91 3224.03 3300.73 3378.74 3456.80 3534.49 3611.83 3690.05 3768.37 3845.97 3923.35 4001.13 4077.79 4154.73 4233.02 4309.17 4385.30 4463.32 4541.87 4620.21 4698.33 4772.31 4844.03 4911.34 4976.40 5037.40 296.29 296.27 296.25 296.22 296.16 296.11 296.06 295.99 295.92 295.84 295.74 295.67 295.63 295.60 295.60 295.61 295.64 295.67 295.70 295.72 295.76 295.79 295.81 295.83 295.85 295.85 295.85 295.84 295.81 295.77 4 of 5 DLS (deg/ 100f) 2.95 0.82 0.73 0.93 0.42 0.69 1.29 1.24 0.47 1.05 0.25 2.48 0.95 2.16 0.76 1.07 0.62 1.24 1.32 1.80 1.31 1.79 0.27 0.37 1.76 4.92 1.71 4.71 2.70 2.66 ------ ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - '-" MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 91 92 93 94 95 96 97 98 99 100 101 102 103 -------- -------- 8384.12 8478.42 8572.08 8665.56 8758.51 8852.57 8946.91 9039.19 9132.22 9225.78 9318.98 9411.22 9425.00 ------ ------ Incl angle (deg) ------ ------ 36.74 32.33 28.88 25.01 20.99 17.90 18.00 17.73 16.90 15.22 ------- ------- ------ ------ Azimuth Course angle length (deg) (ft) ------- ------- 292.35 291.02 290.66 292.19 291.94 289.36 286.27 284.66 284.11 280.71 14.21 281.78 13.40 283.37 13.24 283.58 Projected to TD: 104 9480.00 12.66 289.74 ------ ------ 93.92 94.30 93.66 93.48 92.95 94.06 94.34 92.28 93.03 93.56 93.20 92.24 13.78 55.00 [(c)2002 Anadrill IDEAL ID6_1C_10] -------- -------- TVD depth (ft) -------- -------- 6115.68 6193.34 6273.94 6357.26 6442.80 6531.49 6621.24 6709.07 6797.88 6887.79 6977.93 7067.51 7080.92 7134.52 25-Apr-2002 15:43:44 -------- -------- Vertical section (ft) -------- -------- 5095.71 5149.04 5196.56 5238.80 5275.05 5306.24 5335.05 5362.92 5390.10 5415.31 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 2212.38 2232.16 2249.13 2264.57 2278.21 2289.30 2298.19 2305.74 2312.62 2318.22 -4590.44 -4640.09 -4684.65 -4724.08 -4757.73 -4787.00 -4814.67 -4841.95 -4868.77 -4894.03 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 5095.76 5149.08 5196.59 5238.82 5275.06 5306.25 5335.05 5362.92 5390.10 5415.32 295.73 295.69 295.65 295.61 295.59 295.56 295.52 295.46 295.41 295.35 5438.25 2322.83 -4917.25 5438.28 295.29 5459.71 2327.61 -4938.73 5459.75 295.23 5462.81 2328.35 -4941.82 5462.86 295.23 5474.97 2331.87 -4953.61 5475.03 295.21 5 of 5 ----- DLS (deg/ 100f) ----- 3.76 4.74 3.69 4.21 4.33 3.41 1.01 0.61 0.91 2.06 ----- ------ ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA MWD_IFR_MSA - MWD_IFR_MSA - MWD_IFR_MSA - 1.12 MWD_IFR_MSA- 0.97 MWD_IFR_MSA- 1.21 MWD_IFR_MSA- 2.72 Projected ~ bp V-101 Schlumberger Survey Report - Geodetic Report Date: 01-May-2002 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 295.460° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: V-Pad / V-101 TVD Reference Datum: KB Well: V-101 TVD Reference Elevation: 82.300 ft relative to MSL Borehole: V-101 Sea Bed I Ground Level Elevation: 55.000 ft relative to MSL UWVAPI#: 500292307400 Magnetic Declination: +26.065° Survey Name I Date: V-101 I April 23, 2002 Total Field Strength: 57474.856 nT Tort I AHD I DDlI ERD ratio: 152.41 r 15496.14 ft I 6.047 I 0.770 Magnetic Dip: 80.755° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: April 23, 2002 --- Location Lat/Long: N 70 1940.579, W 14915 59.941 Magnetic Declination Model: BGGM 2001 Location Grid N/E YIX: N 5970058.080 ftUS, E 590424.580 ftUS North Reference: True North Grid Convergence Angle: +0.69055186° Total Corr Mag North -> True North: +26.065° Grid Scale Factor: 0.99990929 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (° 11 OOft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5970058.08 590424.58 N 701940.579 W 149 1559.941 104.76 0.10 62.80 104.76 -0.06 0.04 0.08 0.10 5970058.12 590424.66 N 70 1940.580 W 149 1559.939 195.83 0.68 62.94 195.83 -0.43 0.32 0.63 0.64 5970058.41 590425.21 N 701940.583 W 149 1559.923 291.90 1.08 60.48 291.89 -1.30 1.03 1.93 0.42 5970059.13 590426.50 N 70 1940.590 W 149 1559.885 383.97 1.30 348.37 383.94 -1.17 2.48 2.47 1.53 5970060.59 590427.02 N 70 1940.604 W 149 1559.869 477.80 2.27 336.22 477.72 0.88 5.22 1.51 1.10 5970063.32 590426.03 N 70 1940.631 W 149 1559.897 570.78 3.00 338.93 570.61 4.04 9.18 -0.11 0.80 5970067.26 590424.36 N 70 1940.670 W 149 1559.944 664.18 3.85 339.75 663.84 8.06 14.40 -2.07 0.91 5970072.45 590422.33 N 70 1940.721 W 149 16 O.OO? 758.17 5.23 331.85 757.53 13.77 21.14 -5.19 1.61 5970079.15 590419.14 N 701940.787 W 149 16 O.OS 851.33 5.63 325.72 850.27 21.13 28.66 -9.76 0.76 5970086.62 590414.47 N 701940.861 W 149 16 0.22(j"" 936.47 5.41 323.54 935.02 28.28 35.34 -14.50 0.36 5970093.24 590409.66 N 701940.927 W 149 160.364 1030.54 6.47 310.34 1028.59 37.32 42.34 -21.18 1.83 5970100.15 590402.90 N 70 19 40.996 W 149 160.559 1122.63 7.48 296.79 1120.00 48.33 48.40 -30.48 2.09 5970106.10 590393.52 N 70 1941.055 W 149 160.831 1217.13 9.36 288.67 1213.48 62.11 53.63 -43.25 2.35 5970111.18 590380.69 N 70 19 41.107 W 149 161.204 1311.61 12.26 290.83 1306.28 79.74 59.66 -59.91 3.10 5970117.01 590363.96 N 70 19 41.166 W 149 16 1.690 1405.32 14.21 288.71 1397.49 101.08 66.89 -80.11 2.14 5970123.99 590343.68 N 70 1941.237 W 149162,280 1498.95 16.47 290.68 1487.78 125.72 75.26 -103.41 2.48 5970132.08 590320.28 N 701941.320 W 149 162.960 1591,76 19.40 294.78 1576.08 154.25 86.37 -129.72 3.44 5970142.87 590293.84 N 70 19 41 .429 W 149 163.728 1687.13 19.44 294.65 1666.02 185.96 99.63 -158.53 0.06 5970155.78 590264.88 N 701941.559 W 149 164.569 V-101 ASP Final Survey.xls Page 1 of 4 5/13/2002-10:41 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI-S EI-W DLS Northing Easting Latitude Longitude (ft) n (°) (ft) (ft) (ft) (ft) (° /1 OOft) (ftUS) (ftUS) 1775.70 22.63 294.16 1748.68 217.74 112.75 -187.48 3.61 5970168.55 590235.77 N 701941.688 W 149 165.414 1870.22 25.30 295.19 1835.04 256.13 128.79 -222.35 2.86 5970184.17 590200.71 N 70 1941.846 W 149 166.432 1963.30 28.77 293.36 1917.94 298.41 146.15 -260.93 3.83 5970201.06 590161.94 N 701942.017 W 149167.558 2055.57 31.55 294.03 1997.71 344.74 164.79 -303.37 3.03 5970219.18 590119.28 N 70 19 42.200 W 149 168.797 2149.50 35.32 294.85 2076.08 396.48 186.21 -350.47 4.04 5970240.04 590071.93 N701942.411 W1491610.172 2242.50 38.12 293.73 2150.62 452.07 209.06 -401.15 3.10 5970262.28 590020.98 N 701942.635 W 1491611.652 2336.88 41.87 293.51 2222.91 512.68 233.36 -456.72 3.98 5970285.90 589965.12 N 70 1942.874 W 149 16 13.274 2430.75 42.72 295.55 2292.35 575.84 259.59 -514.18 1.72 5970311.43 589907.36 N 701943.132 W 149 1614.952 2524.26 44.63 296.71 2359.98 640.40 288.04 -572.14 2.21 5970339.18 589849.06 N 701943.412 W 149 1616.644 2617.12 44.50 296.77 2426.14 705.55 317.36 -630.34 0.15 5970367.79 589790.52 N 701943.700 W 149 16 18.3L 2710,30 44.60 297.15 2492.54 770.89 346.99 -688.60 0.31 5970396.72 589731.91 N 701943.992 W 149 1620.044'-" 2803.73 44.26 297.31 2559.26 836.27 376.92 -746.76 0.38 5970425.94 589673.40 N 70 1944.286 W 149 1621.742 2897.08 43.96 296.84 2626.29 901.22 406.50 -804.61 0.48 5970454.81 589615.20 N 701944.577 W 149 1623.431 2979.64 43.69 296.91 2685.85 958.37 432.34 -855.61 0.33 5970480.04 589563.91 N 70 1944.831 W 149 1624.920 3069.03 44.70 299.63 2749.95 1020.59 461.86 -910.47 2.40 5970508.89 589508.70 N 701945.121 W 149 1626.522 3162.72 45.05 298.41 2816.34 1086.57 493.92 -968.27 0.99 5970540.25 589450.51 N 70 19 45.436 W 149 16 28.209 3257.26 44.60 298.31 2883.39 1153.13 525.58 -1026.92 0.48 5970571.20 589391.50 N 701945.748 W 149 1629.922 3350.80 44.51 298.89 2950.05 1218.66 556.99 -1084.54 0.45 5970601.91 589333.51 N 701946.057 W 149 1631.604 3444.53 44.08 299.38 3017.14 1283.98 588.86 -1141.71 0.59 5970633.09 589275.96 N 70 19 46.370 W 149 16 33.273 3536.74 43.21 299.06 3083.86 1347.48 619.93 -1197.26 0.97 5970663.48 589220.05 N 701946.675 W 149 1634.895 3628.38 44.54 300.05 3149.92 1410.83 651.26 -1252.50 1.63 5970694.14 589164.44 N 701946.983 W 149 1636.508 3720.60 45.99 298.09 3214.83 1476.20 683.08 -1309.76 2.18 5970725.26 589106.81 N 701947.296 W 149 1638.180 3812.73 45.76 297.90 3278.97 1542.27 714.12 -1368.15 0.29 5970755.59 589048.05 N 701947.601 W 149 1639,885 3906.13 45.09 298.16 3344.52 1608.74 745.39 -1426.88 0.74 5970786.15 588988.95 N 70 1947.909 W 149 1641.600 3999,08 45.39 296.09 3409.98 1674.70 775.47 -1485.62 1.61 5970815.52 588929.86 N 701948.205 W 149 1643.31'- 4092.16 45.54 296.00 3475.26 1741.05 804.60 -1545.23 0.18 5970843.93 588869.91 N 701948.491 W 149 1645.05----' 4185.75 45.37 295.98 3540.91 1807.75 833.83 -1605.18 0.18 5970872.43 588809.61 N 701948.778 W 149 1646.806 4280.19 44.91 296.66 3607.53 1874.68 863.51 -1665.19 0.71 5970901.38 588749.26 N 701949.070 W 149 1648.558 4373.57 44.36 295.92 3673.97 1940.28 892.57 -1724.01 0.81 5970929.73 588690.10 N 701949.356 W 1491650.275 4466.94 44.43 293.89 3740.69 2005.59 920.08 -1783.25 1.52 5970956.51 588630.54 N 701949.626 W 149 1652.005 4560.23 44.38 294.21 3807.34 2070.85 946.68 -1842.86 0.25 5970982.39 588570.62 N 701949.888 W 149 1653.746 4652.80 44.44 293.47 3873.47 2135.60 972.86 -1902.11 0.56 5971007.86 588511.06 N 701950.145 W 149 1655.476 4746.62 44.03 293.88 3940.69 2201.02 999.14 -1962.05 0.53 5971033.41 588450.81 N 701950.403 W 149 1657,226 4839.56 43.55 293.36 4007.78 2265.30 1024.91 -2020.98 0.65 5971058.47 588391.59 N 701950.657 W 149 1658.947 4932.80 43.60 294.67 4075.33 2329.55 1051.07 -2079.68 0.97 5971083.91 588332.58 N 70 1950.914 W 149 170.661 V-101 ASP Final Survey.xls Page 2 of 4 5/13/2002-10:41 AM Grid Coordinates Geographic Coordinates Station 10 MO Incl Azim TVO VSec Nf-S EJ-W OLS Northing Easting Latitude Longitude (It) n (°) (It) (It) (It) (It) (° /1 OOft) (ftUS) (ftUS) 5026.32 45.95 293.03 4141 .72 2395.38 1077.68 -2139.92 2.80 5971109.79 588272.02 N 70 19 51.175 W 149 172.420 5119.51 47.90 293.99 4205.36 2463.41 1104.84 -2202.34 2.22 5971136.20 588209.29 N 70 1951.442 W 149 174.243 5213.97 49.04 293.25 4267.99 2534.08 1133.17 -2267.13 1.34 5971163.74 588144.17 N 70 1951.721 W 149 176.135 5307,86 51.52 292.81 4327.98 2606.23 1161.41 -2333,58 2.67 5971191.18 588077.39 N 701951.998 W 149 178.075 5401.19 53.68 294.37 4384.67 2680.33 1191.10 -2401.52 2.67 5971220.04 588009.11 N 701952.290 W 149 1710.059 5493.19 54.64 294.49 4438.54 2754.89 1221.94 -2469.42 1.05 5971250.06 587940.84 N 701952.593 W 149 1712.042 5587.03 57.35 295.19 4491.01 2832.67 1254.62 -2540.00 2.95 5971281.89 587869.88 N 701952.914 W 149 1714.103 5679.22 57.37 296.09 4540.74 2910.30 1288.21 -2609.99 0.82 5971314.63 587799.50 N 701953.244 W 149 1716.147 5772.70 57.26 295.29 4591.22 2988.98 1322.32 - 2680.89 0.73 5971347.88 587728.20 N 701953.580 W 149 1718.217 5866.49 57.34 294.26 4641.89 3067.90 1355.39 -2752.55 0.93 5971380.08 587656.15 N 70 1953.905 W 149 1720.3"' 5957,81 57.15 293.87 4691.30 3144.67 1386.71 -2822.67 0.42 5971410.55 587585.66 N 70 1954.212 W 149 17 22.35'ð-' 6052.38 56.54 294.15 4743.02 3223.82 1418.93 -2895.00 0.69 5971441.88 587512.96 N 70 1954.529 W 149 1724.470 6144.92 55.58 293.30 4794.68 3300.56 1449.82 -2965.28 1.29 5971471.92 587442.32 N 70 19 54.832 W 149 17 26.522 6238.96 56.73 293.09 4847.06 3378.60 1480.58 -3037.07 1.24 5971501.81 587370.17 N 701955.135 W 1491728.619 6332.60 56.45 292.69 4898.62 3456.69 1510.98 -3109.08 0.47 5971531.35 587297.81 N 70 1955.433 W 149 1730.722 6426.12 56.28 291.53 4950.42 3534.41 1540.29 -3181.21 1.05 5971559.78 587225.33 N 70 1955.721 W 149 1732.828 6519.48 56.09 291 :37 5002.38 3611.79 1568. 65 -3253.41 0.25 5971587.27 587152.81 N 701956.000 W 149 1734.937 6613.19 57.36 293.70 5053.80 3690.02 1598.69 -3325.76 2.48 5971616.42 587080.11 N 70 1956.295 W 149 1737.050 6706.69 56.56 293.24 5104.78 3768.36 1629.90 -3397.65 0.95 5971646.77 587007.85 N 701956.602 W 149 1739.149 6799,88 56.26 295.63 5156.34 3845.96 1662.01 -3468.32 2.16 5971678.02 586936.80 N 701956.917 W 149 1741.213 6893.32 55.55 295.54 5208.72 3923.34 1695.43 -3538. 11 0.76 5971710.59 586866.62 N 70 1957.246 W 149 1743.251 6987.56 55.70 296.75 5261.93 4001.12 1729.70 -3607.93 1.07 5971744.01 586796.40 N 70 1957.582 W 149 1745.291 7080,70 55.13 296.86 5314.80 4077.77 1764.28 -3676.37 0.62 5971777.76 586727.55 N 70 1957.922 W 149 1747.290 7174,07 55.93 297.87 5367.64 4154.71 1799.66 -3744.73 1.24 5971812.32 586658.78 N 70 1958.270 W 149 1749.286 7269.16 54.97 296.89 5421.57 4232.98 1835.68 -3814.27 1.32 5971847.50 586588.81 N 701958.624 W 149 17 51.3r 7361.28 56.60 297.26 5473.37 4309.12 1870.36 -3882.10 1.80 5971881.35 586520.58 N 701958.964 W 149 17 53.2S~ 7452.26 57.13 298.53 5523.10 4385.24 1906.00 -3949.43 1.31 5971916.17 586452.84 N 701959.315 W 149 1755.265 7545,16 57.22 296.55 5573.46 4463.25 1942.09 -4018.64 1.79 5971951.42 586383.20 N 701959.669 W 149 1757.286 7638.65 57.13 296.83 5624.14 4541.79 1977.38 -4088.84 0.27 5971985.86 586312.59 N 70200.016 W 149 1759.337 7732.05 56.92 297.16 5674.97 4620.12 2012.95 -4158.65 0.37 5972020.58 586242.36 N 70 20 0.365 W 149 18 1.376 7826.15 55.35 296.51 5727.41 4698.23 2048.22 -4228.37 1.76 5972055.01 586172.23 N 70 20 0.712 W 149 183.412 7918.69 50.84 295.73 5782.96 4772.20 2080.80 -4294.79 4.92 5972086.78 586105.43 N 70201.032 W 149 185.352 8012.27 49.24 295.86 5843.06 4843.92 2112.01 -4359.37 1.71 5972117.21 586040.48 N 70201.338 W 149 187.239 8104.07 45.11 294.11 5905.46 4911.23 2140.48 -4420.36 4.71 5972144.93 585979.15 N 70 201.618 W 149 189.020 8197.97 42.70 292.96 5973.11 4976.30 2166.49 -4480.05 2.70 5972170.22 585919.16 N 70 201.873 W 149 1810.764 V-101 ASP Final Survey.xls Page 3 of 4 5/13/2002-10:41 AM Grid Coordinates Geographic Coordinates Station 10 MO Incl Azim TVO VSec N/-S E/-W OLS Northing Easting Latitude Longitude (ft) r) (°) (ft) (ft) (ft) (ft) (" /1 DOft) (ftUS) (ftUS) 8290.20 40.27 292.48 6042.19 5037.33 2190.09 -4536.40 2.66 5972193.14 585862.54 N 70202.105 W 149 18 12.409 8384.12 36.74 292.35 6115.68 5095.71 2212.38 -4590.44 3.76 5972214.78 585808.23 N 70 20 2.324 W 149 18 13.988 8478.42 32.33 291 .02 6193.34 5149.04 2232.16 -4640.09 4.74 5972233.96 585758.36 N 70202.518 W 1491815.438 8572.08 28.88 290.66 6273.94 5196.56 2249.13 -4684.65 3.69 5972250.39 585713.60 N 70202.685 W 14918 16.739 8665.56 25.01 292.19 6357.26 5238.80 2264.57 -4724.08 4.21 5972265.34 585673.99 N 70202.837 W 149 18 17.891 8758.51 20.99 291.94 6442.80 5275.05 2278.21 -4757.73 4.33 5972278.58 585640.18 N 70202.971 W 149 18 18.874 8852.57 17.90 289.36 6531.49 5306.24 2289.30 -4787.00 3.41 5972289.32 585610.78 N 70 20 3.079 W 149 1819.729 8946.91 18.00 286.27 6621.24 5335.05 2298.19 -4814.67 1.01 5972297.87 585583.01 N 70203.167 W 1491820.537 9039.19 17.73 284.66 6709.07 5362.93 2305.74 -4841.95 0.61 5972305.09 585555.64 N 70203.241 W 149 1821.334 9132.22 16.90 284.11 6797.89 5390,10 2312.62 -4868.77 0.91 5972311.65 585528.74 N 70203.308 W 149 1822.11' 9225.78 15.22 280.71 6887.79 5415.31 2318.22 -4894.03 2.06 5972316.94 585503.42 N 70 20 3.363 W 149 18 22.85~ 9318.98 14.21 281.78 6977.94 5438.26 2322.83 -4917.25 1.12 5972321.27 585480.15 N 70 20 3.408 W 149 1823.533 9411 .22 13.40 283.37 7067.51 5459.71 2327.61 -4938.73 0.97 5972325.79 585458.61 N 70203.455 W 1491824.161 9425.00 13.24 283.58 7080.92 5462.81 2328.35 -4941.82 1.21 5972326.50 585455.52 N 70 20 3.463 W 149 1824.251 9480.00 13.24 283.58 7134.46 5475.14 2331.31 -4954.06 0.00 5972329.30 585443.24 N 70 20 3.492 W 1491824.608 '---- V-101 ASP Final Survey. xis Page 4 of 4 5/13/2002-10:41 AM Sc~Itn~.1I8P Alaska Data and Consulting Services 3940 Arctic Blvd. Suite 300 Anchorage, AK 99503-5711 A TIN: Beth ,..--- Well Job# V-101 V-101 V-101 ~~-051o 1, 22230 GR & ROP5 DATA 22230 MD IMPULSE-GR 22230 TVD IMPULSE-GR ~-;- Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED JUN 2 1 L')()Q? I "'- Ala&~aOiI & Gas ConS. Commission Anchorage Date 04/25/02 04/25/02 04/25/02 6/12/2002 NO. 2142 Company: Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Field: Borealis Color BL CD Sepia Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Receiv~)}~~~j~~ .) ) MWD/L WD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No V-101 Date Dispatched: 2-May-02 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Su rveys 2 dOd- 050 Received By: ~~ r~ LWD Log Delivery V1.1, Dec '97 RECEiveD r{~Y 0 6 2002 AlaskaOiJ & Gas Cons. Conuniaion Anchorage Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 ) ) ~~IÆ~E : f /Æ~R,~~~JJ AIßA~1iA. OIL AlO) GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276.7542 Lowell Crane Senior Drilling Engineer , BP Exploration Alaska, Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit V-I 0 1 BP Exploration Alaska, Inc. Permit No: 202-056 Sur Loc: 4812' NSL, 1877' WEL, Sec. 11, T11N, RIlE, UM Btmhole Loc. 1882' NSL, 1533' WEL, Sec. 03, T11N, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit V-101. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ((JMlAI\A ~~/~J~. ~fd ~;~chsli Tayl~~~ð~- Chair BY ORDER OF THE COMMISSION , DATED thisEi,\day of March, 2002 jj c/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASt STATE OF ALASKA ):>IL AND GAS CONSERVATION CO~ PERMIT TO DRILL 20 AAC 25.005 )SSION yJ6A 3/ (lfJ~ þ- <3(\{ -0") 1 a. Type of work 181 Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4812' NSL, 1877' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval 1821' NSL, 14021 WEL, SEC. 03, T11 N, R11 E, UM At total depth 1882' NSL, 15331 WEL, SEC. 03, T11 N, R11 E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028240, 1533' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weiaht Grade Coupling 42" 34" x 20" 91.5# H-40 Weld 9-7/811 7-5/8" 29.7# L-80 BTC 6-3/411 5-1/2" x 3-1/2" 15.5# x 9.2# L-80 BTC-M / IBT-M Lenath 80. 3109' 94271 0 Exploratory 0 Stratigraphic Test 181 Development Oil 0 Service, 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 83.8' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) ADL 028241 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number I' V-101 9. Approximate spud date 04/01/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9427' MD / 7111' rvD 0 17. Anticipated pressure {o/ee 20 AAC 25.035 (e) (2)} 57 Maximum surface 2792 psig, At total depth (TVD) 65501/3447 psig Setting Depth Top Bottom MD rvD MD TVD Surface Surface 80' 801 Surface Surface 3109' 2754' Surface Surface 9427' 71111 11. Type Bond (See 20 AAC 25.025) 1 b. Type of well Number 2S100302630-277 Quantitv of Cement (include staae data) 260 sx Arctic Set (Approx.) 301 sx AS Lite, 140 sx Class 'GI 151 sx Lite Crete, 145 sx Class IGI 19. To be completed for Red rill , Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED FES 2 8 2002 Perforation depth: measured Alaska Oil & Gas Cons. Commission Anchorage true vertical 20. Attachments 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Robert Odenthal, 564-4387 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that tþi..e fore ing is true ~ ~orrect to the best of my ~. nowl~. ~g.e . . Signed lowellCrane " .~( I~ Title Senior Dnlllng Engineer Date) -;)..1,- <) L , . Co~mission Use Only Permit Number API Number ~n, . røral P-a~ See cover letter Z-ð 2.- - 0 S6 50- 02. '7- 2. 30 / "7J-\-j \J)\ for other requirements Conditions of Approval: Samples Required ~Yes 0 No Mud Log Required' ø Yes 0 No Hydrogen Sulfide Measures 0 Yes B No Directional Survey Required )šJYes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: '-\ SoD ~ \. ~ ~-\\':c:;-\.é~1"}v( Original Sìgnod BV Commissioner Camn~~I~ , f\J ð I by order of the commission Date ~' ('À ÎJ d-, ~u Jmif'Ín Triplicate Approved By Form 10-401 Rev. 12-01-85 ) ') IWell Name: IV-101 Drill and Complete Plan Summary I Type of Well (service I producer I injector): Surface Location: As-Built Target Location: I Producer x = 590,424.52' Y = 5,970,058.12' 48121 FSL, 18771 FEL, Sec. 11,T11N, R11E X = 585,590' Y = 5,972,290' 18211 FSL, 1402'FEL,Sec.03,T11N, R11E X = 585,458.91' Y = 5,972,349.88' 18821 FSL, 15331 FEL, Sec.03,T11N, R11E Bottom Hole Location: I AFE Number: 15M-4047 I Estimated Start Date: 1 April 1 ,2002 I I I MD: I 9427' I TVD: 17111' I Well Design (conventional, slimhole, etc.): I Objective: Kuparuk Formation Mud Program: 9-7/8" Surface Hole (0-3109'): Densitv (ppg) 8.5 - 8.6 9.3 - 9.5 I,' 9.6 max Viscosity (seconds) 300 200-250 200-250 Initial below Permafrost interval TD / I Rig: I Nabors 9ES ,/ I Operating days to complete: 114.7 I RKB: I 83.8' I BF/MS: 1 53.8' I Microbore (Iongstring) Yield Point (Ib/1 OOft:¿) 50 - 70 45 - 60 45-60 Spud Mud PH 8.5- 9.5 8.5- 9.5 8.5- 9.5 API FL (mls/30min) , 15 - 20 <10 <8 6 %" Intermediate I Production Hole (3109' - 9427': : Interval Density Tau 0 YP PV pH (ppg) Upper 9.3-9.5 4-7 20-25 8-12 8.5-9.5 Interval 10.3 / Top of HRZ 5-8 20-25 1 0-18 8.5-9.5 API Filtrate 6-8 LSND HTHP Filtrate 4-6 <10 by HRZ Hydraulics: Surface Hole: 97/8" (0-3109') Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-2,976' 620 4" 17.5# 190 2300 9.8 N/A 18,18,18,12 .856 Production Hole: 6 %" (3109-9427') Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 2976' -9406' 295 4" 17.5# 240 3300 11.7 N/A 5x12 .552 Directional: V-101 Permit to Drill- Version 1.1 Page 2 Ver. (Sperry) WP-03 KOP: 300' Slot ND Maximum Hole Angle: Close Approach Wells: Logging Program: Surface Hole (0-3109' MD) Production Hole (3109'.9427' MD) Formation Markers: Formation Tops SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma Na Oa Obf Base CM3 CM2 THRZ BHRZ K-1 TKUP Kuparuk C LCU Kuparuk B Kuparuk A TML V (Miluveach) CasinglTubing Program: Hole Size Csgl Tbg O.D. 34 x 20" 7 5/8" 5-1/2" 3-1/2" 3-1/2" 42" 9-7/8" 6-3/4" 6-3/4" Tubing Integrity Testing: Test Point Surface Casing Shoe '~ J ) I 57.27 degree~ at 5591-7825' MD All wells pass major risk criteria. v' Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: Note: MWD/LWD (GR/Directional) Gas Detection None MWD/LWD (Dir/GR/RES) PEX, BHC Sonic, Gas Detection, Cuttings samples None Logs to be run over Schrader and Kuparak. MDbkb TVD Pore Press (EMW) Hydrocarbon bearing 1646 1619 8.4 No 1790 1749 8.4 No 1830 1757 8.4 No 2236 2124 No 2463 2289 No 2894 2599 No 3339 2919 No 3818 3264 No 4472 3734 No 4882 4029 8.5 Yes 5215 4269 8.5 Yes 5454 4434 8.5 Yes 5933 4704 Yes 6133 4814 No 6714 5134 No 8496 6229 No 8718 6429 No 8771 6479 No 8846 6550 10.0 Yes 8871 6574 10.0 Yes 9054 6751 No 9197 6889 10.0 Yes 9277 6997 No Wt/Ft Grade Conn Length Top Btm MDITVD MDITVD bkb 91.5# H-40 WLD 80' GL 80/80 29.7# L-80 BTC 3109' GL 3109'/2754' ./ 15.5# L-80 BTC-m 8595' GL 8595'/6316' 9.2# L-80 IBT -mod 832' 8595'/6316' 9427'/7111' / 9.2# L-80 IBT-mod 8595' GL 8595'/6316' Depth Test Type EMW 20' min from LOT 14.6 ppg target surface shoe V -101 Permit to Drill - Version 1.1 Page 3 ) ) Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. The production cement calculation assumes cement will be required to cover 500' above the top of the Schrader with 1000 psi compressive strength and covering the entire Kuparuk interval with 2000 psi compressive strength cement. If logs indicate the Schrader not to be oil bearing, the program will be amended to provide 2000 psi compressive strength cement above the top of the Kuparuk only. Casing Size 17-5/8" Surface I Basis: Lead: Based on 1736' of annulus in the permafrost @ 250% excess and 1240' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ',/ Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2476' MD / Total Cement Volume: Lead 209 bbl I 93? ft::S I 301 sk,s of Dowell ARTICSET Lite at 10.7 ppg and 4.44 fe1sk. ...- 24.9 bbl 040.7 ft::S I 140 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 ft3/sk. Tail 5-1 12"x3-1 12" Production Longstring Basis: Lead: Based on TOC 500' above top of Schrader formation & 30% excess + 80' shoe. // Lead TOC: 47441 MD ~ Total Cement Volume: Lead 64 bbls I 351 ft::S 1151 sks of Lite Crete at 12 ppg and 2.33 ft::S/sk. Tail 30 bbls I 161 ft I 14~, sks of Dowell Premium 'G' at 15.8 ppg and1.17fe/sk. ./ Casing Size Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 ' psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test for future frac considerations, the BOP equipment will be tested to 4500 psi. The diverter, BOPE and drilling fluid system schematics are on file with the AOGCC. Production Interval- . Maximum anticipated BHP: . Maximum surface pressure: . Planned BOP test pressure: Planned completion fluid: 3447 psi @ 6550' TVD (sub-sea) - Kuparuk Sands 2792 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) 4500 psi / 8.6 ppg filtered seawater or brine I 6.8 ppg Diesel . Disposal: . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Hydrogen Sulfide: / . H2S has not been recorded on V-Pad wells. As a precaution, Standard Operating Procedures for H2S are followed at all times. V-101 Permit to Drill- Version 1.1 Page 4 ') J' ) DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: - The twenty inch conductor. 1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugslwell shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: 1. MIRU Nabors 9ES. (Slot NO). ./ 2. Nipple up diverter spool and riser. Function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3109' / MD/2754' TVD. Surface hol~TD will be +1-100' TVD below the top of the SV1 sand. POH LD BHA. 4. Run and cement the 7-5/8", 29.7# surface casing back to surface. Port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations depending on the Port guidelines established January 2002. 5. NO diverter spool and NU casing I tubing head. NU BOPE and test to 4500 psi. 6. MU 6-3/4" drilling assembly with ~D/GR/NEUT/DEN/RES and RIH to float collar. Test the 7 5/8" casing to 3500~i for 30 minutes. 7. Drill out float equipment and displace well to LSND drilling fluid. / 8. Drill new formation to 20' below 7-5/8" shoe and perform Leak Off Test. g. Drill to :t100' above the HRZ, ensure mud is condition to 10.3 ppg and perform short trip as needed. During this time hold the 'Pre-Reservoir' meeting highlighting kick tolerance and detection. 10. Drill ahead to ....150' of rat hole into the Miluveach formation(TD .... 9427' MD/7111' TVD). / 11. Make wiper trip as required by hole conditions, circulate and condition hole for logging. POOH 12. Perform open hole logging program. Run PEX/BHC Sonic (wireline attempt only) logs. If logging time /' is excessive, RIH with 6-3/4" cleanout assembly and condition hole for running the 5 V2" x 3 V2" casing. POOH laying down excess 4" DP. 13. Run and cement the tapered production casing as required from TO to 500' above the Schrader. / Displace the casing with heated seawater during cementing operations and freeze protect the 5 V2" x 7-5/8" annulus as required. (Annular Disposal Requirement - Prior to freeze protecting annulus, perform second leak off test below the 7 5/8" shoe. Record on chart and submit to town.) 14. Run the 3-1/2",9,2#, L-BO gas lift completion assembly, Circulate around corrosion inhibitor, / / 15. Sting seal assembly into tieback receptacle and test to 4500 psi for 30 minutes both the tubing and annulus. Release tubing pressure and shear RP valve. / 16. Install TWC and test from below to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 17. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to freeze protect both the tubing and annulus to lower GLM. 18. Rig down and move off. V-101 Permit to Drill - Version 1.1 Page 5 ) ') V-101 Job/Operational Breakdown 1Ji.~~.-"..\. ...-.-lW,lIiII,UIIIN:.I.II.J,iI, Job 1: MIRU Hazards and Contingencies ./' >- V-Pad is not designated as an H2S site. In the wells drilled to date on this pad there has been no report H2S as being present. As a pre-caution, follow at all times the Standard Operating Procedures for H2S. /" ~ The closest surface location is V-201. V-201 will be -60' wellhead to wellhead from the proposed well location. The well does not require a surface shut-in. ~ Check landing ring height on V-120 conductor, the BOP stack may need to be run with a double flange on bottom (13-5/8" x 11") Reference RP's .:. Operational Specifics . ~Yl1'tm...,'.".','.~:"-:.-:':":':'~':"'-::.''-.:';":~~ 'wn---.;..¡,..¡.¡.~:~,:;~.'1¥$MiIo'1M't:Y4'f:¥_\f't:_'t:'i't't-'f.~--..-.1/'1/';1\f,-,'t,'r:Y.i'.'jf-~--'W,W""WI'fW:"i'ffI\\\'I.W'M'-:".''''~'1\\-¡,'t,)~'þ;Iw;.;.¡~N.ION~;' ,""::......,\,\"............................",......, -~'f~\'rf'-~':'I:r'c\f-:\ .. .....'fm'f:l:'I~',y¡.J:_nl-"':"--,';W.',,,~J:t:I;t)'!"IJ..J,'.~~~W1- --'_\:--:-.-'f;'!~'fI'flm'i'.+\\f\'T'f:\'\'YI'fI':"1~':':':"~ Job 2: Drillina Surface Hole Hazards and Contingencies >- In this interval, no faults should be penetrated. >- Drilling Close Approach: All wells pass BP Close Approach Guidelines. The nearest close approach well is V-201 (actual) which will have a center-center distance of 81'@ 1038' MD. All well pass under Major Risk Rules. >- There has been consistent observation of gas hydrates while drilling wells off this pad. Expect to encounter hydrates from the base of permafrost to the shoe setting depth. To combat the hydrate problem, appropriate mud products will be implemented at surface. Refer to Baroid mud recommendation >- Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) Reference RP's .:. Operational Specifics . .~..'....'..~.-"'w..' "'*'i~"~~~":.~"".'. ,,"-" ~-'... '.... ~'.)\"'.'f'l( -"'\'\'"\f¡l;,1 w,.,'.m_~;~'t,_.fi.. .mm_m1!~!\. \_m,'''m:'1Y1~\') I .;I I'IWmm.''''''':,.''.mm!\flm O:l!'.\ .",., _¥:t ~,. '- ¥ -""~"':'~"'N'r:'i'~ -~;:~, :1I'\'m,..,..n"'fI""~I'L"~ln'- \"T~~~ _n:~ - ~ - -:.IT::P':!,"'-'''''''''\I'lm\l'~Tf~I_' IT ~:~:In"'H;.¡;". ""1_~_'1':I'n,_n';,-\ \ . ~ Job 3: Install Surface CasinQ Hazards and Contingencies / >- It is critical that cement is circulated to surface for well integrity. Plan of 2500/0 excess cement through the permafrost zone and 300/0 excess below the permafrost. A 7-5/8" port collar positioned at :t1 OOO'MD to allow a secondary circulation as required. >- "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement. 2. Cement - Top of tail >500' TVD above shoe, (using 30% excess.) 3. Casing - Shoe set -100' TVD below SV1 sand. Reference RPs .:. V-101 Permit to Drill - Version 1.1 Page 6 ) ') Operational Specifics . ~~-""~..",.."...,,~~'ir.~~);,-¥~~>~~, m ..,:oto< ""~"'~;";'~"'.'."'-:Do¡¡;-~ . ~;_L'_"~~~~",,,,,..~¡'i*'NI~"~_""I1'~':'1rM':\'':''/fr:~''/:\'W:'t.':''I~;"."..~",..~,,\,';"~W~.~I<X"'"': .;¡¡¡.~~,,~.,:..;;;;:: Job 7: DrillinQ Production Hole Hazards and Contingencies ~ KICK TOLERANCE: In the worst case scenario of 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 14.6 ppg at the surface casing shoe, 10.3 ppg mud in the / hole, kick tolerance is 25.3 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 14.6 ppg. ~ Faults: The well trajectory is expected to intersect a fault at approximately 5350' TVD ss (Colville Formation). The fault has an estimated throw of 80'. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. This is not considered a high risk for lost circulation while drilling, however, losses maybe encountered when running the production casing string. ~ V-Pad development wells have kick tolerances approaching 25 bbl s. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. ~ There is a minor "close approach" issue with the production hole interval of V-101. It is with the P&A'd well (1970). The referenced depth of V-101 would be 9401' MD with a center to center distance of 313.72' Reference RPs .:. OperaUonalSpecifics . ~1f,m'fi1:~'."'m\"/.'.\'--~' , -~ .mm~m"':"/:,mY1nm!WIW.nm'.':Yf.~_"/_~~w~':,m't.""\'~W;'1\~"""""'''''~;'"',¡'¡'>¡¡>:,""~~~W¡"~)<-)<-"''''''-''''''''''''''»~'f;~;~'iIAAW:.~~~~'?'''.-':òJ~~'¡1~~''''''''''''''''.'.>><~~,'':-'''''A~.''''~I:''~''M' Job 8: LOQ Production Hole Hazards and Contingencies ~ Ensure the hole is in very good condition to avoid a stuck tool string ~ If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 5 Y2" x 3 Y2" longstring casing. Reference RPs .:. Operational Specifics . " ,.IV.,', .1..1-' Job 9: Case & Cement Production Hole Hazards and Contingencies // ~ The 5-1/2" casing will be cemented to 500' above the Schrader Bluff sand. The top of the hydrocarbon interval should be verified with open hole logs. ~ If losses are encountered while running the production casing, be prepared to treat with Barafiber when circulating on bottom prior to the cement displacement. Consider increasing cement volume if 100% returns are not established. V-101 Permit to Drill- Version 1.1 Page 7 ) ') »> Freeze protect the 5 Y2" x 7-5/8" casing annulus to 2976' TVD (base of surface casing) with diesel. It is essential that freeze protection of the 7" annulus be performed only after the UCA indicates 500 psi compressive strength is indicated. A second LOT may be required prior to displacing freeze protect. This would be to satisfy AOGCC for future annular pumping permits.) »> The well will be under-balanced after displacing the cement with heated sea water. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. »> Ensure a minimum hydrostatic equivalent of 1 0.3 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes »> The X-Nipples, with an I.D. of 2.813" is the tightest tolerance for the Weatherford Dual - Plug system, (tapered cement plugs to be used in the 5 Y2" X 3 Y2" tapered casing string.) Caliper and confirm the I.D. of all X-Nipples prior to make-up to ensure conformity with proposed design. The By-Pass plug head has been modified for a maximum O.D. of 2.5". Caliper to confirm, prior to use. Reference RPs .:. OperaüonalSpecifics . ;';~Q,.;;.),..+ø~"J.~OOOO1l'miWWi'!'IIIff1:'i'~J.J+.I ~.~~'tN'f;;.y-:lj " ~;;.;.~~. 'Ii',""" 'fII,mMm'/Qf.;X'f'lii~ ¥',W:':X~~\N-~~¥i"'~V"jt»¡¡"~¡"-:.I_'j ,~',' ' Io¡'t'¡j,'¡,\':-":\'l':'fflW l 'f1\'\::¡: '1m'i 'iffl'f'ilt~'~.;##tt'j''i'iT)-.N1i:\fI~''i~;'''' ",.'\'*11. ,\. ,'\'ffl""N.\ffI'ffT\I*tr'l'l,¡;';';¡;P;..."U;M-;i4;::~)Irl~¡~...mfl:'if-:r;'1'/1I1/#. Job 12: Run Completion Hazards and Contingencies »> No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. "Completion Design and Running" .:. "Freeze Protection of Inner Annulus" Operational Specifics . ~m!;,-.,:J!i:',-..:ml!'-'-J¡!:;~ mmmmmmmmmmmmmmm;¡¡m;Jmmu,:.-¡.;m¡,;!!:~!.-!!;¡¡,,-¡,¡,, m¡:¡'¡!.¡,:¡'iIm!,I;;mmmmmmmJ¡ .¡,',:,:mm:.-¡U-!:,-:'-¡',-,-::!;¡'¡;,-J:¡¡;:.-,-m»!m!J,-mJm;;!m;¡¡~¡;¡m¡.;m¡!mm;;;¡.;m~Þ'J'¡"I Jm¡"-;-~!/Jm¡.-;>i:..);;m,-,-J:¡mmm.-,-¡,-¡¡;,-mm.m~;¡m;¡AAAi¡;m¡¡¡m.-¡,:¡m;.:~U!~:!;::!¡J¡¡J;m,;Þ,mmÞ,I!J~!::¡::,-~mmmmmm!n-:m. Job 13: ND/NU/Release RiQ Hazards and Contingencies »> No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Operational Specifics . V-101 Permit to Orill- Version 1.1 Page 8 ) ) Borealis V-1 01: Proposed Completion TREE: 3-1/8" - 5M CIW Carbon WELLHEAD: 11" - 5M FMC G5 Cellar Elevation = 51.7' RKB - MSL = 82' I . 3-1/2" 'X' Landing Nipple with 2.813" seal bore. I 2200' I 7-5/8",29.7 #/ft, L-80, BTC 12,976' Ij ~ 3-1/2" x 1" Gas Lift Mandrels with handling pups installed. L -----_._...~-,---- --'--~-'----"--'---- GAS LIFT MANDRELS TVD Size ._-_._,~_. .--.-- -------."-.--. .--....'" "'-'-.---' # 1 2 3 ----,.-..-------. Valve Type -------'-'_.'--"-"'--'-'-~"-"-'-"-- TDB TDB TDB 1 " 1" 1 " RP DV DV L ---.-.-----..------..--..-------. ---'----'--'-'-"----" ~_.__._,., n___,- -~ 3-1/2" 9.2# IBT Mod L-80, Tubing L 0 ------3-1/2" Baker CMD Sliding Sleeve 5-1/2", 15.5 #/ft, L-80, BTC-Mod "'" ..4- 3-1/2" Seal Stack Asembly -...-:- 3-1/2" PBR ,,7 5-1/2"x3-1/2" XO /' . . 3-1/2" 'X' Landing Nipple with 2.813" seal bore / Plug Back Depth I 9,326' 3-1/2",9.2 #Ift, L-80, IBT Mod 19,406' ] C 3-1/2" 'X' Landing Nipple with 2.813" seal bore +/- 150' above Kuparak. ~ Date 1/17/02 Rev By RSO Comments Borealis WELL: V-101 API NO: 50-029-XXXXX-XX Proposed Seal Bore Completion BP Alaska Drilling & Wells bp V-101 Schlumberger Proposed Well Profile - Geodetic Report Report Date: January 18, 2002 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 295.460° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: V-Pad / V-101 ilit tu TVD Reference Datum: KB Well: V-101 l1li TVD Reference Elevaüon: 83.5 ft relative to MSL Borehole: V-101 Feasl Sea Bed 1 Ground Level Elevaüon: 55.000 ft relative to MSL UWI/API#: 50029 Magnetic Declination: 26.110° Survey Name I Date: V-101 (P3) / January 18, 2002 Total Field Strength: 57472.849 nT - Tort I AHD I DOli ERD ratio: 100.183° 15476.72 ftl 5.862 10.77C Magnetic Dip: 80.753° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: March 05, 2002 Location Lat/Long: N 70.32793905, W 149.26665096 Magnetic Declination Model: BGGM 2001 Location Grid N/E Y/X: N 5970058.200 ftUS, E 590424.500 ftUS North Reference: True North Grid Convergence Angle: -+D.69055127° Total Corr Mag North .> True North: +26.110° Grid Scale Factor: 0.99990929 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates I Station ID MD Incl I Azim TVD I VSec N/-S I EI-W I DLS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 0 Oft) (ftUS) (ftUS) KBE 0,00 0.00 345.00 0.00 0.00 0.00 0.00 0.00 5970058.20 590424.50 N 70.32793905 W 149.26665096 KOP Bid 1/100 300.00 0.00 345.00 300.00 0.00 0.00 0.00 0.00 5970058.20 590424.50 N 70.32793905 W 149.26665096 Base Gubik 323.50 0.24 345.00 323.50 0.03 0.05 -0.01 1.00 5970058.25 590424.49 N 70.32793919 W 149.26665104 400.00 1.00 345.00 399.99 0.57 0.84 -0.23 1.00 5970059.04 590424.26 N 70.32794135 W 149.26665283 500,00 2.00 345.00 499.96 2.26 3.37 -0.90 1.00 5970061.56 590423.56 N 70.32794826 W 149.26665826 600.00 3.00 345.00 599.86 5.10 7.58 -2.03 1.00 5970065.75 590422.38 N 70.32795976 W 149.26666742 Bid 2/100 700.00 4.00 345.00 699.68 9.06 13.48 -3.61 1.00 5970071.63 590420.73 N 70.32797588 W 149.26668024 800.00 5.00 322.60 799.37 15.20 20.31 -7.16 2.00 5970078.42 590417.10 N 70.32799454 W 149.26670902 ~ 900.00 6.47 308.96 898.88 24.55 27.31 -14.19 2.00 5970085.33 590409.98 N 70.32801366 W 149.26676603 SV6 975.20 7.74 302.38 973.50 33.70 32.69 -21.76 2.00 5970090.62 590402.35 N 70.32802836 W 149.26682742 1000.00 8.17 300.66 998.06 37.11 34.48 -24.69 2.00 5970092.38 590399.40 N 70.32803325 W 149.26685118 1100.00 9.99 295.27 1096.80 52.87 41.81 -38.65 2.00 5970099.54 590385.35 N 70.32805327 W 149.26696438 Bid 2.5/100 1100.71 10.00 295.24 1097.50 52.99 41.86 -38.76 2.00 5970099.59 590385.24 N 70.32805341 W 149.26696527 1200.00 12.48 295.24 1194.88 72.34 50.12 -56.26 2.50 5970107.63 590367.65 N 70.32807597 W 149.26710718 1300.00 14.98 295.24 1292.01 96.08 60.24 -77.73 2.50 5970117.49 590346.06 N 70.32810362 W 149.26728129 1400.00 17.48 295.24 1388.02 124.03 72.16 -103.02 ,--2.50 5970129.11 590320.63 N 70.32813618 W 149.26748637 1500.00 19.98 295.24 1482.71 156.14 85.85 -132.06 2.50 5970142.44 590291.43 N 70.32817358 W 149.26772186 1600.00 22.48 295.24 1575.92 192.35 101.29 -164.82 2.50 5970157.49 590258.49 N 70.32821576 W 149.26798752 V-101 (P3) report.xls Page 1 of 3 1/18/2002-11 :28 AM Grid Coordinates Geographic Coordinates I Station 10 MO Incl Azim TVD VSec NI-S E/.W I OLS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) SV5 1646.28 23.64 295.24 1618.50 210.48 109.02 -181.22 2.50 5970165.02 590242.00 N 70.32823688 W 149.26812051 1700.00 24.98 295.24 1667.46 232.60 118.45 -201.22 2.50 5970174.21 590221.89 N 70.32826264 W 149.26828270 SV4 1790.26 27.24 295.24 1748.50 272.32 135.39 -237.15 2.50 5970190.71 590185.76 N 70.32830891 W 149.26857406 1800.00 27.48 295.24 1757.15 276.80 137.30 -241.20 2.50 5970192.57 590181.69 N 70.32831413 W 149.26860691 End Bid 1801.52 27.52 295.24 1758.50 277.50 137.60 -241.83 2.50 5970192.86 590181.05 N 70.32831495 W 149.26861201 Base Permafrost 1829.71 27.52 295.24 1783.50 290.52 143.15 -253.62 0.00 5970198.27 590169.20 N 70.32833011 W 149.26870762 Bid 2/100 1857.90 27.52 295.24 1808.50 303.55 148.71 -265.40 0.00 5970203.69 590157.35 N 70.32834530 W 149.26880315 1900.00 28.36 295.24 1845.69 323.27 157.12 -283.24 2.00 5970211.88 590139.41 N 70.32836827 W 149.26894782 Bid 4/100 1957.90 29.52 295.24 1896.36 351.29 169.06 -308.58 2.00 5970223.51 590113.93 N 70.32840089 W 149.26915332 - 2000.00 31.20 295.24 1932.68 372.57 178.14 -327.83 4.00 5970232.36 590094.58 N 70.32842569 W 149.26930942 2100.00 35.20 295.24 2016.34 427.32 201.48 -377.36 4.00 5970255.10 590044.77 N 70.32848945 W 149.26971108 2200.00 39.20 295.24 2095.97 487.78 227.26 -432.04 4.00 5970280.22 589989.79 N 70.32855987 W 149.27015451 SV3 2235.90 40.64 295.24 2123.50 510.81 237.09 -452.87 4.00 5970289.79 589968.85 N 70.32858672 W 149.27032343 2300.00 43.20 295.24 2171.19 553.64 255.35 -491.61 4.00 5970307.58 589929.89 N 70.32863660 W 149.27063760 End Bid 2319.89 44.00 295.24 2185.60 567.35 261.20 -504.02 4.00 5970313.28 589917.42 N 70.32865258 W 149.27073824 SV2 2462.95 44.00 295.24 2288.50 666.73 303.57 -593.91 0.00 5970354.56 589827.03 N 70.32876831 W 149.27146722 SV1 2893.90 44.00 295.24 2598.50 966.09 431.22 -864.69 0.00 5970478.93 589554.76 N 70.32911697 W 149.27366320 7 -5/8" Csg Pt 3109.37 44.00 295.24 2753.50 1115.77 495.05 -1000.08 0.00 5970541.12 589418.62 N 70.32929130 W 149.27476122 UG4A 3338.75 44.00 295.24 2918.50 1275.11 562.99 -1144.21 0.00 5970607.31 589273.69 N 70.32947685 W 149.27593014 UG3 3818.35 44.00 295.24 3263.50 1608.27 705.06 -1445.56 0.00 5970745.72 588970.68 N 70.32986483 W 149.27837421 UG1 4471.73 44.00 295.24 3733.50 2062.14 898.59 -1856.10 0.00 5970934.27 588557.88 N 70.33039330 W 149.28170401 Ma 4881.83 44.00 295.24 4028.50 2347.01 1020.07 -2113.78 0.00 5971052.63 588298.78 N 70.33072498 W 149.28379409 WS2 5215.47 44.00 295.24 4268.50 2578.78 1118.89 -2323.42 0.00 5971148.91 588087.98 N 70.33099478 W 149.28549455 Bid 4/100 5289.15 44.00 295.24 4321.50 2629.96 1140.72 -2369.72 0.00 5971170.17 588041.42 N 70.33105438 W 149.28587012 5300.00 44.43 295.24 4329.28 2637.53 1143.95 -2376.56 4.00 5971173.32 588034.55 N 70.33106320 W 149.28592560 .-...-- 5400.00 48.43 295.24 4398.18 2709.97 1174.84 -2442.09 4.00 5971203.42 587968.66 N 70.33114753 W 149.28645715 WS1 5454.41 50.61 295.24 4433.50 2751.35 1192.48 -2479.52 '-4.00 5971220.60 587931.02 N 70.33119569 W 149.28676077 5500.00 52.43 295.24 4461.87 2787.04 1207.70 -2511.81 4.00 5971235.43 587898.55 N 70.33123724 W 149.28702269 5600.00 56.43 295.24 4520.02 2868.37 1242.38 -2585.37 4.00 5971269.22 587824.59 N 70.33133191 W 149.28761939 End Bid 5603.76 56.58 295.24 4522.10 2871.51 1243.72 -2588.21 4.00 5971270.52 587821.73 N 70.33133557 W 149.28764243 CM3 5933.17 56.58 295.24 4703.50 3146.46 1360.98 -2836.91 0.00 5971384.77 587571.66 N 70.33165567 W 149.28965985 Obf Base 6132.91 56.58 295.24 4813.50 3313.19 1432.07 -2987.72 0.00 5971454.03 587420.02 N 70.33184972 W 149.29088323 CM2 6713.99 56.58 295.24 5133.50 3798.21 1638.91 -3426.43 0.00 5971655.55 586978.89 N 70.33241428 W 149.29444220 Drp 4/100 7830.94 56.58 295.24 5748.61 4730.52 2036.49 -4269.72 0.00 5972042.90 586130.94 N 70.33349925 W 149.30128384 7900.00 53.82 295.24 5788.02 4787.23 2060.67 -4321.01 4.00 5972066.46 586079.37 N 70.33356523 W 149.30169998 V-101 (P3) report. xis Page 2 of 3 1/18/2002-11 :28 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NJ-S EI.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 8000.00 49.82 295.24 5849.81 4865.82 2094.19 -4392.10 4.00 5972099.11 586007.89 N 70.33365669 W 149.30227677 8100.00 45.82 295.24 5916.94 4939.91 2125.78 -4459.12 4.00 5972129.89 585940.50 N 70.33374288 W 149.30282054 8200.00 41.82 295.24 5989.08 5009.14 2155.30 -4521.74 4.00 5972158.65 585877.53 N 70.33382343 W 149.30332862 8300.00 37.82 295.24 6065.87 5073.16 2182.61 -4579.65 4.00 5972185.26 585819.30 N 70.33389794 W 149.30379849 8400.00 33.82 295.24 6146.93 5131.68 2207.56 -4632.58 4.00 5972209.57 585766.08 N 70.33396601 W 149.30422795 Top HRZ 8496.10 29.98 295.24 6228.50 5182.45 2229.21 -4678.51 4.00 5972230.66 585719.90 N 70.33402508 W 149.30460062 8500.00 29.82 295.24 6231.88 5184.40 2230.04 -4680.27 4.00 5972231.47 585718.13 N 70.33402734 W 149.30461490 8600.00 25.82 295.24 6320.31 5231.06 2249.94 -4722.47 4.00 5972250.86 585675.70 N 70.33408164 W 149.30495731 8700.00 21.82 295.24 6411.77 5271.44 2267.16 -4759.00 4.00 5972267.63 585638.97 N 70.33412862 W 149.30525371 - Base H RZ 8717.98 21.10 295.24 6428.50 5278.02 2269.96 -4764.95 4.00 5972270.36 585632.98 N 70.33413626 W 149.30530199 K-1 8771.20 18.97 295.24 6478.50 5296.26 2277.74 -4781.45 4.00 5972277.94 585616.39 N 70.33415748 W 149.30543587 8800.00 17.82 295.24 6505.82 5305.35 2281.62 -4789.67 4.00 5972281.72 585608.13 N 70.33416807 W 149.30550256 Top Kuparuk 8845.65 16.00 295.24 6549.50 5318.62 2287.28 -4801.68 4.00 5972287.24 585596.05 N 70.33418351 W 149.30560001 Kup C 8870.55 15.00 295.24 6573.49 5325.27 2290.11 -4807.69 4.00 5972289.99 585590.01 N 70.33419123 W 149.30564878 End Drp I Tgt 8870.56 15.00 295.24 6573.50 5325.28 2290.12 -4807.70 4.00 5972290.00 585590.00 N 70.33419126 W 149.30564886 LCU I Kup B 9053.80 15.00 295.24 6750.50 5372.70 2310.34 -4850.60 0.00 5972309.70 585546.86 N 70.33424642 W 149.30599695 KupA 9196.67 15.00 295.24 6888.50 5409.68 2326.11 -4884.04 0.00 5972325.07 585513.24 N 70.33428945 W 149.30626828 Top Miluveach 9277.42 15.00 295.24 6966.50 5430.58 2335.02 -4902.95 0.00 5972333.75 585494.22 N 70.33431375 W 149.30642172 TO 15-1/2" Csg Pt 9427.42 15.00 295.24 7111.39 5469.40 2351.57 -4938.06 0.00 5972349.87 585458.92 N 70.33435890 W 149.30670661 LeQal Description: Surface: 4812 FSL 1877 FEL S11 T11N R11E UM Target: 1821 FSL 1402 FEL S3 T11N R11 E UM BHL: 1882 FSL 1533 FEL S3 T11N R11E UM NorthinQ (Y) rftUSl EastinQ (X) rftUSl 5970058.20 590424.50 5972290.00 585590.00 5972349.88 585458.91 ~ V-101 (P3) report. xis Page 3 of 3 1/18/2002-11 :28 AM -2000 _....... .............................. 0-......,.................. .- -- C)) .- C)).....I """CJ) 8~ 0 C)) C\/ > II ,g c: CO :;:~ _0 .c:~ --C"') c..co C)) - 000 -~ CO .. 0""" .- Q) ~o::: Q) > > Q)~ :JW !... I- 2000 - 4000 -' '1 I I I 6000 - 'I' 8000-,,: " ¡ I I I ) VERTICAL SECTION VIEW Client: Well: Field: BP Exploration Alaska V-l0l (P3) Schlumberger Prudhoe Bay Unit - WOA Structure: V-Pad Section At: 295.46 deg Date: January 18, 2002 ,..........~"".....,... i ! i 1 i I .......................................,¡.............,....,................., I i i I i ! .......","'.....", ,..."....", ,.I.. "I, KOP Bid 1/10~300 MD 300 TVD // 0,00' 345,00'1 az 0 departure / Bid 2/100700 MD 700 TVD // //4,00' 345,06' az 9 departure ..~~..:::;~;> ~,q,oo,~,,; 4~"az ,~,3 d~part,~f,e / / End Bid 1~02 MD 1759 TVD / ,,/ /1 27,52' 29~,24' az 277 departure ,/ ", Bid 2/10Q 1858 MD 1809 TVD "/ //;/}'~2~~î~5;~t8 ~~Ö~~~1~~~ "" b/ // 29,52' 1295.24' az 351 departure e "/0~/~::C~:);~;;.--~t?~!d2W~~~:~z~;!6d~~t:ùr~:::f~~f¡: ---: : " , , <j.5i~;; Call Pt3109ï0D¿754TVpi 44,00' 295.24' az 1116 departure! ,,' .., ...., ...., ....¡ .... ...., ...., ...., J-IQld,Angl.~ 44,.9Q~ i J. ~,Id 4I~,OO 5289,,~D " 432~,TVD I " ",// I 44.00' 295,24' az 2630 departre // j. End Bid 5604 MD 4522 TV ) ;/ <' ':1'/56:58' '295,24' aj: 2872 diì"rrtÙre /<'1"'1 :::1 . .... . .' 'ïä~w'MD "'1''Iô4''1"VC; i i ..........,i......,.... I I .."..'..'.."....'..'..........."]'..'......".. ""i(J.(i;~'~ Óü'Gih '~:',>4 ~;ib ~:,:?4 ivo .....1 ! I ¡ ..,¡ .. 'j~:WQ' 9?~~ MD"97~I'TVIY I I ~W1 ;¡SMiii!() '2r;¡'!j"tv,:r" (jÔM\'''3'ì:\';)' MIJ'[::9H'i 'I'vlj 1::(;:\')(1 Hf'¡v1D ,j:!(;4'NI)' i I d(:1,¡:j,i1.1[} +~J<ÏTVÔ' ,. t;i¡;:i~W~K1ì5;ï6>5f(ji)'" .j "" ...., HOJd'An.'g I~" ~~.$,8~" ...., '''''' ...., ....' ""'I ...., ...., i ..,I V-101 Fit P2 ! I Drp 41100 7831 MD 5749 TVD ---'-----T 56,58' 295.24' az 4731 departure ! / End Drp 1 TII18871 MD 6573 TVD ,:":i"' ""1'5':OO""'2~5~'24"'äi"53'25'âëþarture m.. ~ '.....1 m.. ..... n,n .."...'" /, ...};\f;1 :" ..... "~ TD (5-1/2" Call PI 9427 MD 7111 TVD 15,Oþ' 295.24' az 546~ departure ""[ ~:iVt~ "6? 1 fK~D "~ '13.rrtví5'" ...¡. I IV-101 Fit P1 ;f\~~0f!~~~(~:!:f~!'~::'d An~ie 15.00" 10000 - ..j... I I I I I -2000 0 2000 4000 6000 Vertical Section Departure at 295.46 deg from (0.0, 0.0). (1 in = 2000 feet) -6000 I 3000 - ^ ^ ^ I l- e:: 0 z 2000 - 1000 - I I- :::J 0 en v v v 0-- -1000 - I -6000 -5000 I TD I 5-112" Csg . 942iMD 7ÚÙVD 15,00' 295,24' az 2352 N 4938 W ---- - - --- ._- - - ---------~-~-- I -5000 Client: Well: Field: Structure: Scale: Date: PLAN VIEW BP Exploration Alaska V-IOI (P3) Prudhoe Bay Unit - WOA V-Pad 1 in = 1000 ft 18-Jan-2002 -4000 I _.-!õru!PIP.1I.!lL.....L........ 8871 MD 6573 T\JD 15.00' 295,24° '* 2290 N 4808 W I : Drp 41100 : 7831 MD 5749 TVD : 56,58° 295,24' az : 2036 N 4270 W no --..u..------.....-.- .. _..._-----_.--~-..- .. -3000 I -2000 , -1000 I Schlumbepuep 0 I 1000 I True North Mag Dee ( E 26.11° ) ,-,,° .--n-_-----n---------------m- .- - 3000 -----___.__hm____n-_-'.- _n ............ .--!;.I!I!..!!.!I!._L_._..__-----.. 5604 MD 4522 ND 56,58° 29~,24' az 1244 N 25þ8 W Bldj41100 / 5289 MD 4322 TVD / 44,~O 29524° az I 1141 N 2370W I ' / I _._--_.._.__.__..__.._m~--..---.---- 7-5IS" Csg Pt 3109 MD 2754 TVD 44,00' 295,24' az 495N 1OO0W , , I -k---< í , // Bid 411b~ /' 1958MD 1896TVD / 29,52' ¡ 295,24'/ 169 N 1309 W Bldj21100 18$ MD 1609ND 27,$2° 295,24' az 149)N 265W ~ ...-..-... - 2000 End Bid; 2320 MD: 2186ND 44,00' ~95,24' az 261 N 5þ4W / ' ~~~~ 1759TVD ¡ / Y¡ 27.52° 295,24' az 1... 1 138N 242W : : Bid 2.51100 ¡ ¡ --------- 1101 MD 1097tvD ~ 10,00° 295,24' az r'~ 42N 39W ' ,\ ~ Bid 21100 ! 700 MD 700 ND '\ ~30~0 ~,ooo az \ KOP Bid 11100 300 MD 300 ND 0,00° 345,00' az 0 N OE !------ - 1000 --.-/ 0 ~---_.__.......__.__.m.._..._..__.m._._...- ------------_...._______n.__m_--'--___-------""-,,----,'''m----._-_.-"."",---..-.-..--_..--.-- . ..~---,--- -1000 t t I I t -4000 -3000 -2000 -1000 0 «< WEST EAST »> I 1000 ) Schlumberger Anticollision Report ') ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,-,,,,,,,,,,,,,,,,,,,,,,,,,-,,,,,-,,,,,,,,"-"''''''''''''''''~'''''''.'''_h''''',''''''''''''''''--''''''''~''''''''''''''''''''''''''''~''''''''''''''-'~'''''''''''~''''','''''''',''''''''''''''''''--''~~~........m..'~..........~_......_--~..-'-. . . . . . . .. . . .. CQmpany: ,BRAmocQ . Dâte: l"it~ld:, " PrlJqhoe, Bay , " , Reference Site:' , 'PBV Pad Co-oJ;dinått\(NE) Ref~rerice: . ReferellceWell: 'V-'101,' , Verticål (TVD) Reference: ,Refe'ren~eWeuþåt~: PlanV-t01', :_--'---~--~~_""::"'_---_._--'-'""':"'_--':':_._":"'~----'--'----'-~._----'----'----,--, "Db: $y~ase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 9427.42 ft Scan Method: Trav Cylinder North Maximum Radius: 2000.00 ft Error Surface: Ellipse + Casing Time: 13:t7:19 ' Survey Program for Definitive Wellpath Date: 9/11/2001 Validated: No Planned From To Survey ft ft 28.50 500.00 500.00 9427.42 Version: Toolcode 6 Tool Name Planned: Plan #3 V1 Planned: Plan #3 V1 CB-GYRO-SS MWD+IFR+MS Camera based gyro single shots MWD + IFR + Multi Station Casing Points ,MD ft' 2993.29 2670.00 9427.42 7111.59 7.625 5.500 9.625 6.750 75/8" 5 1/2" X 3 1/2" Summary -""--'-~'-''''''~_''''H'~''''''-'''-',,,-,~,-~,,,,-~-,,-"~"--'-"""''''~''-''-~'-'''--''''''''-''-'--'''''~~--~''~-.._.._.....~,..._...._.._-_.....- " , -'---'''~''~''---''''~'''''''''---'~'-~-'-'----'--''--'~_'_'_h_~_~_--_'''''''''.~.r.~~ , , , <;";';'~;'~-~"'--;";';'~;'()ffs~tWenpatb I Site " 'Well EX WKUPST-01 PB V Pad PB V Pad WKUPST-01 V-100 V-201 WKUPST-01 V1 V-100 V7 V-201 V8 Reference' MD" ft ' 9401.72 396.83 1039.75 Offset , .MD ft 7050.00 400.00 1050.00 , Ctr~Ctr . No;'Go Distance ,Area ft ft 313.72 0.00 359.73 7.92 80.81 17.25 . Allowable, ' Deviation Warlling , ft 313.72 Pass: Minor 1/200 351.81 Pass: Major Risk 63.71 Pass: Major Risk -_.._,._M___-ri Polygon 1 2 3 4 Site: PB V Pad \ Drilling Target Conf. Yo Centre Location: Map Northing: 5972290.00 ft Map Easting : 585590.00 ft Latitude: 70020'03.088N +N/-S ft 286.09 -126.19 -305.25 122.10 Target: V-I 0 1 Tgt +E/-W ft -86.55 -316.58 16.31 241.52 ") Well: V-IOl Based on: Planned Program Vertical Depth: 6490.00 ft below Mean Sea Level Local +N/-S: 2290.33 ft Local +E/-W: -4807.58 ft Longitude: 149°18'20.336W Northing ft 5972575.00 5972160.00 5971985.00 5972415.00 Easting ft 585500.00 585275.00 585610.00 585830.00 800 2100 2500 2500 24-00 2300 2200 2100 2000 1900 1800 ~ C) C) C) C) D C) C) C) D D ~ C) C) C) C) D C) C) C) D C) ~ N C) CT CD I LD LJ) -=I- (I) ~ Ln Ln LJ) -=I- -=I- -=I- -=I- -=I- -=I- -=I- ~ I I I I I I I I I I ~ ~ ,¡. ) ) V-101 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates were observed in offset wells. These are expected to be encountered near the base of the Permafrost at 1736' MD and near the TD hole section as well. . Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: . The production section drilled with a recommended mud weight of 10.3 ppg to ensure shale stability in the HRZ shale. Read the Shale Drilling Recommended Practice. . Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. . In the worst case scenario of 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 14.6 ppg at the surface casing shoe, 10.3 ppg mud in the hole, kick tolerance is 25.3 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 14.7 ppg. . The faults expected to be penetrated by V-1 01 in the Colville at ....5350' TVDss. The throw is ....ao' down to the south. There is not a high risk for lost circulation while drilling, however, losses maybe encountered when running the production casing string. . A majority of the L-Pad development "Microbores" will have "kick tolerances" in the 25-40 bbl range. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells drilled on L-pad did not report H2S as being present. As a precaution Standard Operating Procedures for H2S precautions should be followed. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 1 of 1 ) i 205533 DATE 02/15/02 CHECK NO. 00205533 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 )21302 CK021302B PYMT COMMENTS: HANDLING INST: 100.00 100. 00 Per~it to Drill 7ee S/H - Sandra Stellman X4750 . . . r. . ' r.~.,.."). E. "". '.l' ,\~'~~ ~ '\,f?,'. ~,', ' ",,^' ~.,..,. ~. f'" I" ~~ t",. t ':,', V' \D\ A\aS\\ó Oil (j. ,~)~~~.: " l\.. f:C,~, ~~. ..,,:::! ,'i~' ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100. 00 BP EXPLORATION, (ALASKA) INC. P.O, BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 205533 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 4'1'2 00205533 r.:iAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 02/15/02 AMOUNT $100.00 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 J ,~, ì'¡ I ,- . f~} ..~ ~., \ L- 0 /J;; l >' ",,: Al ~ t.I!." '~'''''\~ III 2 0 5 5 ~ ~ III I: 0 ~ . 2 0 ~ B Ii 5 I: 0 0 B ~ ~ . Ii III ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER WELL NAME /¡fa CHECK 1 ST ANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL / (If api number last two (2) digits are between 60-69) DEVELOPMENT REDRlLL PILOT HOLE (PH) EXPLORA TION ANNUL~POSAL NO INJECTION WELL ANNULAR DISPOSAL L-J YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL' LI-/ð/ "CLUE" The permit is for a new wellbore segment of existing wen --'---' Permit No, ,API No. . " Production should continue to be reported as a function of the original API number stated above. . In accordance with 2,0 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly , differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (na,me on permit). , Annular disposal has ~ot been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. . ANNULUS L-J YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved . subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY If';? l' WELL NAME /¿!/-/ tV -/ð/ FIELD & POOL ¡:; ÝO/3 0 INIT CLASS /)~ /-'ð,// ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . ~, R p~TE 12. Permit can be issued without administrative approval.. . . . . ffé f/~ ¿ 13. Can permit be approved before 15-day wait.. . . . . . . . . . ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. ,CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate well bore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to 4500 psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y N 31. Data presented on potential overpressure zones. . . . . . . Y N Á ). /J I 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . I' \,.../. T1 APPR P~T9 '33. Seabed condition survey (if off-shore). . . , . . . . , . . . . Y N ¡f// . r l' C) 2- 34. Contact name/phone for weekly progress reports [exploratory 0 y} Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . Y N ~ J - J d " I +t/ (8) will npl cpnl¡lminate freshwæer; pr œuse drilling w¡¡ste. " Y N ¡v,.::J ~uJ.p~.r Yt S(~ t \"(4 ú.QL,,~ , to surface; (J (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGIf1A=RING: UIC/Annular: COMMISSION: RP~ TEMffJ.-'lil3{ ccOe.,. COT ;¿ SFD- WGA W6k' DTs05 '/zIo L JMH H- .11,2 }D"J.. APPR DATE '\J..uí/\ ~ I it f 0"2- !ß1fn3(u-O-::> GEOLOGY APPR DATE G:\geology\templates\checklist.doc PROGRAM: Exp - Dev 2( Redrll - Serv - Wellbore seg - Ann. disposal para req - GEOL AREA 1? / ð UNIT# ~ Á.. ~ ON/OFF SHORE "11) æN Æ~ C/4d:~/ /,CP/ /:~~~Ø/ Üþ;¿ -u-. &W)I!~//.nT r..-y>£;!-A, ,r;:,'X'¿Á ~4-/ /'1/J7<> Æ ~ a.--l'". ,rZu)r~J &----4P', -4-. ~'/'é.-l ~-ç... ¡;, ~~/~/~ r>. /'7~~ ~ þ,?~~ ~~~-,u ØN(~/_--'C". -#c ~N L0N @ N ~ t € {O' 'l'IÞ . Y N @ N t'i-CRS<; ~c4 i . ~~ q 3 bhÎs \is '-It! htit:... ~ ~ /l.kkf~ 9G<; -¥::-N- /\LIlt , (J Q~ Clot-ü-,","f- """f(~L ~ bD @ ~ar\' j ~ "'1.$ p :: 1..1 q 'L P ~, ~ ~ ;þ<. t- =- '/f){)O l' ~ , éPN ~~ ( I "\ Comments/Instructions:
