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201-135
Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:201-135 6.50-029-21875-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12950 12948 9029 9568 8479 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 32 - 112 32 - 112 1490 470 Surface 4086 13-3/8" 30 - 4116 30 - 4020 5380 2760 Intermediate 10845 9-5/8" 28 - 10873 28 - 8915 6870 4760 Liner 883 7" 10564 - 11447 8845 - 9038 8160 7020 Perforation Depth: Measured depth: 11676 - 12917 feet True vertical depth:9028 - 9027 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 28 - 10639 28 - 8865 Packers and SSSV (type, measured and true vertical depth) Liner 3350 2-3/8" 9600 - 12950 8498 - 9030 11200 11780 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 40614501324152 2188594 1317 820 226 276 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson ryan.thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-5280 Treatment descriptions including volumes used and final pressure: 13. Sr Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9030 Sundry Number or N/A if C.O. Exempt: 4-1/2" AVA TRSV SSSV 2015 2015 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Install Patch Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028314 PBU 14-40A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:54 am, Jun 23, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.06.23 11:04:18 -08'00' Bo York , ADL 028312SFD 6/23/2021 SFD 6/23/2021MGR30JUL2021DSR-6/24/21 RBDMS HEW 6/24/2021 ACTIVITYDATE SUMMARY 5/4/2021 T/I/O = SSV/1250/470. Temp = SI. IA FL (Slickline). ALP = 1320 psi, SI @ CV. IA FL @ 4800' (3750' above sta # 6 SO). SV, WV, SSV = C. MV = O. IA, OA = OTG. 00:30 5/5/2021 ****WELL SHUT ON ARRIVING*** SET WHIDDON C-SUB ON LTP ASSY @ 9563'SLM PULLED RK-SO FROM STA# 6 @ 8521' MD PULLED RK-LGV'S STA# 4,3,1 SET DGLV IN STA# 1 3223' MD ********JOB IN PROGRESS CONTINUE IN AM ****************** 5/6/2021 T/I/O=1220/1220/480 Assist Slickline / CMIT TxIA **Inconclusive** (Load & Test) Pump 550 bbls crude down IA to load. Pump 225 bbls crude down tbg to load. Pumped 11 bbls crude down tbg to CMIT TxIA to 2500 psi. T/IA lost 12/15 psi 1st 15 min & GAINED 16/15 psi 2nd 15 min. Bled pressures back to 500 psi FWHPs=500/600/548 5/6/2021 *****CONTINUED FROM 5-5-21 WSR***** SET RK-DGLV IN STA# 3 @ 6024' MD SET RK-DGLV IN STA# 4 @ 7402'MD LOADED IA W/ 550 BBLS CRUDE SET RK-DGLV IN STA# 6 @ 8550' MD / 8524'SLM PULLED WHIDDON CATCHER SUB FROM LTP @ 9563' SLM / 9568' MD LOAD TUBING WITH 225 BBLS CRUDE SET 2.31" XX PLUG (45.5" OAL) W/ 28" FILL EXT IN THE LTP PSTA @ 9597' SLM ATTEMPT 1 CMIT-TXIA(inconclusive, see LRS) ******JOB IN PROGRESS, LDFN CONTINUE IN AM ****** 5/7/2021 ***** CONTINUED FROM 5-6-21 WSR ( LEAK DETECTION ) ***** PERFORM 2400psi CMIT TxIA (good) TEST TBG TO 2000PSI w/ HOLEFINDER @ 9550'SLM(btm of mandrel #8) **WSR CONT ON 5/8/21** 5/8/2021 **WSR CONT'D FROM 5/7/21** SET 3.70" BAITSUB AS CATCHER ON LTP @ 9559'SLM. LOCATE & GET LIB IMPRESSION OF RK LATCH IN GLM # 8 @ 9544'SLM **ABOVE PASSING TBG TEST w/ HOLEFINDER** MULTIPLE ATTEMPTS TO RETRIEVE BAITSUB **UNABLE TO LATCH, MARKS ON GR INDICATE BAITSUB NOT CENTERED IN TBG** **WSR CONT ON 5/9/21** 5/9/2021 **WSR CONT'D FROM 5/8/21** RECOVERED BAITSUB FROM LINER TOP @ 9559'SLM RAN 3.80" LIB TO LTP @ 9561 SLM RAN 2.80" LIB TO LTP AREA @ 9561'SLM IN MULTIPLE CONFIGURATIONS **IMPRESSIONS OF JAGGED, POSSIBLY SEPARATED TBG ON EACH RUN** **PARTED TBG IN TBG JOINT & 10' PUP BETWEEN ST#8 & 45KB LTP **JOB SUSPENDED, WELL S/I ON DEPARTURE** 5/13/2021 T/I/O=1200/1500/350. Inline rebuild on SV. Replaced all internal parts. Torqued bonnet flange and Pt'd SV. ***Job complete*** Daily Report of Well Operations PBU 14-40A Daily Report of Well Operations PBU 14-40A 5/14/2021 **WELL S/I ON ARRIVAL** RAN 23' PATCH ASSEMBLY w/ TTL BRASS TO LTP @ 9564'SLM** APPEAR TO BE ENGAGEING LTP AFTER 2ND ATTEMPT, 2.81" AVA SEALS HAVE DAMAGE RAN 3.5" LONG TAPERED SWAGE TO SAME DEPTH TO PROVIDE CLEARENCE FOR SEALS **WSR CONT ON 3/15/21** 5/15/2021 **WSR CONT'D FROM 5/14/21** RAN 3.50" TAPERED SWAGE ON BTM OF PATCH ASSEMBLY TO LTP @ 9564'SLM SET PATCH ASSEMBLY w/ AVA STINGER STUNG INTO LTP SET 4 1/2" D&D PACK-OFF STUNG INTO PATCH ASSEMBLY PT'D TUBING, IA TRACKING. PULLED PACK-OFF & PATCH ASSEMBLY - (new stinger being made with vee- packing seals) **JOB SUSPENDED, WELL S/I ON DEPARTURE** 5/27/2021 *******WELL PREVIOUSLY S/I ********** RAN PATCH ASSEMBLY W/ VEE-PACKING SEALS S/D 9571' SLM(seal damaged) RAN PATCH ASSEMBLY W/VEE-PACKING SEALS S/D 9571' SLM(slight seal damage) RAN PATCH ASSEMBLY W/ 2-7/8 STL BOWSPRINGS 10' UP FROM VEE PACKING STINGER ( 301.85" oal ) TO LINER TOP @ 9568' SLM STING IN 4-1/2 DDIC PACK OFF ASSEMBLY @ 9542' SLM TO UPPER PATCH RECEPTICAL MIT-T 2440 (pass) ****** JOB IN PROGRESS CONTINUE IN AM ******** 5/28/2021 *******CONTINUED FROM 5-27-21******* PULL DDIC PACK OFF ASSEMBLY @ 9511' SLM, LOST ELEMENT STA# 7 8660'SLM UNABLE TO RECOVER ELEMENT PULLED PATCH ASSEMBLY W/ 2-7/8 STL BOWSPRINGS 10' UP FROM VEE PACKING STINGER FROM LINER TOP @ 9568'(1 scar on pkg) SET PATCH ASSEMBLY W/ 2-7/8 STL BOWSPRINGS 10' UP FROM AVA PACKING STINGER TO LINER TOP @ 9568' SLM (lower ptsa plug will only pass thru AVA stinger) *****JOB IN PROGRESS CONTINUE IN AM ****** 5/29/2021 ********CONTINUED FROM 5-28-21 ******* SET 4-1/2 DDIC PACK OFF ASSEMBLY W/ STINGER INTO PATCH RECEPTICAL @ 9540'SLM, MIT-T 2650PSI (pass) SET 4-1/2 DDIC TBG STOP ON DDIC PACK OFF @ 9536' SLM(Tubing Integrity Good) MIT X IA (fail) TBG started tracking IA 300psi over TBG) MIT-T (fail) PULL 4-1/2 DDIC TBG STOP @ 9536' SLM, ***********JOB IN PROGRESS********* Daily Report of Well Operations PBU 14-40A 5/30/2021 ******* CONTINUED FROM 5-29-21 WSR ******** BEAT DOWN TO RESET DDIC PACKER @ 9540' SLM MIT-T 2,585 PSI(pass) SET 4-1/2 DDIC TBG STOP (OAL 20 1/4") @ 9540' SLM, TOP @ 9538' SLM, EQ & PULLED 2.313 XX PLUG FROM PTSA @ 9602' SLM(most DDIC element recovered in fill exstension) SET 4 1/2" WHIDDON SUB(undersize brass) TOP OF TBG STOP @ 9538' SLM, PULLED RK-DGLV FROM ST# 6 @ 8550' MD ***** CONTINUE JOB IN AM ****** 5/31/2021 *******CONTINUE FROM 5-30-21 WSR ********* PULLED RK-DGLV FROM STA# 1 @ 3223' MD, STA# 3 @ 6024' MD, STA# 4 @ 7402' MD SET RK-DOME 16/64, 1627 TRO STA# 1 @ 3223' MD SET RK-DOME 16/64, 1631 TRO STA# 3 @ 6024' MD SET RK-DOME 16/64, 1612 TRO STA# 4 @ 7402' MD SET RK-SO 24/64 STA# 6 @ 8550' MD PULLED 4 1/2" WHIDDON CATCHER SUB @ 9539' SLM(empty) *******JOB COMPLETE GAVE WELL BACK TO PAD READY TO POP ****************** • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMOION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing0 Plug for Redrill 0 Perforate New Pool 0 Repair Well H Re-enter Susp Well 0 Other Pulle &Re-SetS ProgramT0 Pull& LT Packer El 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 201-135 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21875-01-00 7. Property Designation(Lease Number): ADL 0028314 8. Well Name and Number. PBU 14-40A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12950 feet Plugs measured feet RECEIVED true vertical 9030 feet Junk measured 9600 feet SEP 2 5 2017 Effective Depth: measured 12948 feet Packer measured 9568 feet true vertical 9029 feet Packer true vertical 8478.95 feet OGCC Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 32-112 32-112 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 10843 9-5/8"47#L-80 30-10873 30-8915 6870 Production 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11676-12917 feet True vertical depth: 9028-9027 feet feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 28-10636 28-8864 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"AVA TRSV SSSV 2015 2015 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED DEC 1 4 2017, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 198 1025 1703 1376 264 Subsequent to operation: 500 5434 1492 1385 589 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ElGas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Vohra,Prachi Contact Name: Vohra,Prachi Authorized Title: Production Engr Contact Email: Prachi.Vohraro�bp.com Authorized Signature: (IP,,' et:.s- Date: I 1 I 1 4 Contact Phone: MI —/ /------------- j/ 2 +1 9075644677 Form 10-404 Revised 04/2017 V / h.10 ! //��/. (?n_ 1 ; 7 �� '2,' 7 RBE 1'A S I//lY a, — J L I I Submit Orininal nni. • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED SEP 252017 RE: BP Exploration (Alaska), Inc. AOGGC Report of Sundry Well Operations Summary September 18, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Pulling and Re-Setting of the Liner Top Packer to repair damaged tubing in Well 14-40A, PTD # 201-135. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • C) o• 0 0 0 C o 0 (4 Lis)) (O O N O - V r N- O U y 0 0 0 0 0 0 0 L C) LC) CO N- O CD CO • V 'CI' CS) CON CN.- 'Tr Ca r CO CD `- 00 CO N N- LC) O CO r r r r COC7 COC7 C r N O (T O O CO CO D) CO F- 00 d' N r r O O V 00 CO CO I- C7 co N CO 00 CD (h CO O N- CD N f- LC) r co rr co (A d' CD O N r O r r r ✓ o QEII III Il c N r r 0 0 CO gcr C � W a LD O O O O LO.zr00 O aD = Y J J J = CD *k CO co co N J • N (fl r r U cn � -• co- � N C (NI▪ ") r O N CO Cr) O O V LU CD J ,r o M CCO o W 01 0W W o NQQW 2 C7 U0WiL CC Z Z 0[ c W W W m O =3DF- ZZD UU) U) Z .JJH • ! Packers and SSV's Attachment PBU 14-40A SW Name Type MD TVD Depscription 14-40A SSSV 2015.15 2015.06 4-1/2"AVA TRSV SSSV 14-40A PACKER 9568 8478.95 3-1/2" Baker 45 KB Packer 14-40A TBG PACKER 10510.98 8830.23 4-1/2" Baker Mod DB Perm Packer • 0 _ - _ / 2 \ E o "`C,-,ee c3 5 4 7 = 0 F\ / O / V 0 � 4 = O '$ Eo e > 5 0- G / § a_ § i :—/ \ / / = 7 / y / 22 \ £ � � eo Q.) 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ACTUATOR D= 1 4-40A ACTUATOR= BAKER C "' EST CMT TOP BEAM PIPE 10400'. NT1AL KB.ELE 74' BE ELEV= NA I KOP= 2600 20"ODIC H ?? V 2020' I--{4-1/2"AVA SC-SSV TRSSSV,D=3.812' Max Angle= 97'@ 11670' 0 GAS LFT MANDRELS Datum MD= 10672' ST M) TVD DEV TYPE VLV LATCH FORT DATE Datum TVD= 8800'SS 1 3223 3200 18 MAG DOIuE RK 16 08/23/17 2 4760 4603 26 MMG DMY RK 0 02/28/03 13-3/8"CSG,72#,L-80, D=12.347" --I 4116' 3 6024 5703 31 MMG DOME RK 16 08/23/17 4 7402 6899 28 MMG DONE RK 16 08/23/17 Minimum ID = 1.92" 9609' '5 7976 7387 36 MNG DMY RK 0 12/05/01 6 8550 7825 46 MMG SO RK 24 08123/17 2-7/8" X 2-3/8" LNR XO 7 8660 7900 47 MNG DMY RK 0 08/10/13 8 9576 8484 55 MNG DMY RK 0 10/16/13 "9 9688 8547 56 MNG DMY RK 0 10/27/91 •STA*5 IS UNUSABLE-C Ot LDNT LATCH tP :. _. "STA#9 GLM BE}N3 CHIT LNR 3.70`BKR DEPLOY SLV,D=3.00" — 9600' j II ' 9668' H45 KB LTP w/PTSA ASSY,0=2.31'(08/21/17) I I I I 2-7/8"X 2-3/8"LNR XO,D=1.92" H 9609' 9602' H 2.31"X NP ID I 9673" I 4-1/2'TBG PATCH, =3.250' 'i ' *ACROSS GLM#9(SET 03/06/92) : I 9750" I—4-1/2"OTIS X NP,D=3.813" ESTIMATE)TOP OF CEME3NT H 10400' r V 4 11 1,•'11g gloM I 0 10616' —9-5/8"X 4-1/2"BKR DB PKR,D=4.75" I 4 0 ►4 II,►4 10664—I6'TNVTE$ACK SLEB/E I ►4 ►� 10670' H9-518"X 7"TIW LTP w/LNR HGR ', O. L10629' I-4-1/2"OTISXNNIP,D=3.725" BEHIND I ►4 % CT LNR 0 ►i 1063911—4-V2"BKR SHEAROUT SUB ►4 ►4 4-1r2"TBG PC, 12.6#,L-80, —I 10639' 40 44 4 ►►, 10648'.-1-14-1/2-WLEG,D=3.958' .0152 bpf,D=3.958" •�4 ►�•i 41•4 ►•�i 10649 —E M)LOGGED 04/21/94 ••4 ►i�4 9-5/8'CSG,47#,L-80,D=8.681" –I 10875' —'i to: sok , 40. ►••i �� �4►� 7'FALLOUTWNJOW(14-40A) 11447'-11452' • 44 PERFORATION SUMMARY �.•• 1.•• FU LOG:BEI MAD/GR ON 12/02/01 4* * ANGLE AT TCW PERF:96'@ 11651' *1 '0 *�4f t 0* ******0- Note:Refer to Production DB for historical perf data ********4 11111114 M1� SIZE SFF VAL Opn/Sqz SHOT SQZ 111111111111111 \ 2-3/8" SLID 11676-12917 0 12/05/01 111111111111111: ****1114 4.41.414� .\ .` PBID —1 12948' ********1******4N N *****1*****4 . 0 . . 7"LNR,29#,L-80,.0371 bpf,ID=6.184" H 11834' .� 2-3/8"LNR,4.7#,L-80,.0039 bpf,ID=1.92" — 12950' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/23/88 ORIGINAL COMPLETION 08/24/17 LLG/JMD SET LTPw/PTSA&X NP-PULL FISH WELL: 14-40A 01/07/89 LAST WORKOVEt 08/24/17 LLG/JM3 GLV GO(08/23/17) FERMI No:"2011350 12/05/01 CTD SIDETRACK API No: 50-029-21875-01 03/08/16 JFK/TLH GLV C/O(02/08/16) SEC 9,T1ON,R14E,2623'FSL&1574'FEL 03/15/17 PV/JM) ADDED LTP FROM 05/31/03 08/07/17 JMJM) PULL LTP/SET FISH(08/06/17) BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday,August 26, 2017 11:23 AM To: AK, GWO Well Integrity Engineer; Regg,James B (DOA);Wallace, Chris D (DOA);AK, OPS EOC Specialists;AK, OPS FS3 DS Ops Lead;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL;AK, OPS FS3 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;G GPB FS3 Drillsites;Odom, Kristine;Vandergon, Mark A; Vohra, Prachi;AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J Subject: OPERABLE: Producer 14-40 (PTD#2011350) Barriers Confirmed All, Producer 14-40 (PTD#2011350)was made not operable on 07/04/15 due to failed TIFL & surface piping issues. An extended liner top packer patch was set to restore tubing integrity. The well passed a MIT-T to 2488psi &MIT-IA to 2426psi on 08/21/17 indicting that the well has two competent barriers to formation. At this time the well is reclassified as OPERABLE. Please be aware of fluid packed annuli when bringing the well online. Plan Forward: 1. Testers: Flow back well through portable test unit. 2. DHD: Monitor for IAxOA communication. 3. Well Integrity Engineer: Additional diagnostics as needed Please respond with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering SCANNED '.;EP 1 5 2017 Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 d) J) o Iz • • ac) 0oz as w a) I 6' Ill -J tP co ,...) aj co .3 QI - Q o O L L C O Fjijtoco w r z _%cO a) E �; O V O a Q E .0 Q .O 15 (0 Y C >' C < C (is in W7.5 Q 0 L u a E V) to co tD N a.+ Q v) L O C Q F" O c6 ) co y f0 0 C 12 +- -o - C2 a) Q N N N co et O e O T Q U • cc Q F- D a) . ca c F- f0Cl.) aU 0 0 0 0 0 C c r \ o W J J J W J 40 >4 W W W W W v v) F- LL LL LL LL LL Q o ro C c Ia- Q Q Q Q Q N `o -o `n u a c:- O Z Z Z Z Z O C v s - o LL LL LL LL LL "" a) O IC N v c) L U K, Y 4ES *0 C ai ac) t- z C O _o v a) V - .. a) a) ,, O > > C Ce •0i at iO . 2 LL > "' U O N -) ce it cam, �+ 0 N Ce ce O 4) U � `.10 _1 -Jla IV Z CO CO axJ0 o . z ,, > N > C) 14 V o CD W0w `• O z fd f0 • W >, >, ` u a O O J O Z roc; > z E E E ,Z� a "' °` N d d w o W a a a a a 2 m m CO CO CO et W W W W W Z O o 0 0 0 c32222 = a) J 0 0 0 0 Cl 0 d d d a LL c ® •i X in � G co w r or) rn r o 0 co r o o p n C> o o o o c' — m N 0 0 ;: O> o O o O if ''V '' d' N O Q e,' 03 /IC N Cm) gQ x VI n. O CO s LLI s 8 MO O O C O O O O p;.. o Q Cr I ullN r IA In f0 "O r co r M > In co r CO In !Y1 O N N N m N. N N N N N E C N v Q T T ce cm C O Q1 NNNNN CO C O O O O O dr a O O O O O - m In In In In In 0 -0 C] WN Cm 00 C G) C o L `Z Q+ E cc o ami o� _ ri Y 8 C4 Q1 C .Q N CD +� a n v m o a .r+ co E N cc tt y !Q m N M N O Z (n 0 re• = Fe L re .. N W m O `i C R u C1 .�.. a 4 p Y ccc .- y c LL 8 C/9 E ig — ~ a` a 0 m 40 ! bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 January 6, 2012 i JAN ?012. Mr. Tom Maunder _ :. ,,;r144a ®trx�l Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 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 altemate, Gerald Murphy, at 659 -5102. Sincerely, St.iinitiEETEB 2, 7 0la Mehreen Vazir 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) DS-14 Date: 11105/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal 14-01A 1931850 50029203170100 14-02C 2071150 50029203180300 14-03A 1961290 50029203190100 14-04A 1961640 50029203200100 14-05A 1920010 50029203270100 14-06A 2040360 50029203280100 14-07 1780660 50029203290000 14-08A 2022100 50029203300100 14.098 1820340 50029205340200 14-10 1801300 50029205280000 14-11A , 2051260 50029205290100 14-12 1811090 50029206310000 14-13 1811010 50029206240000 14-14 1811020 50029206250000 14-15 1810840 50029206110000 14-16A 1971670 50029206080100 14-17A 2030010 50029205620100 14-188 2071290 50029205510200 14-19 1810450 50029205780000 14-20 1810700 50029205980000 14-21A 2051070 50029207560100 14-22A 1921230 50029207470100 14-23A 2090200 50029207570100 14-24 1830910 50029209700000 14-25 1831020 50029209810000 14-26 1811100 50029206320000 14-27 1831700 50029210460000 14-28 1820120 50029207080000 14-29 1811680 14-30 2050940 50029206790100 14-31 1831110 50029209890000 0 NA 0 NA 10.20 11/5/2011 14-32 1831220 50029209990000 14-33 1831250 50029210020000 14-34 1831330 50029210100000 14-35 1831420 50029210180000 14-36 1831630 50029210390000 14-37 1880490 50029218100000 14-38 1881030 50029218620000, 14-39 1881380 50029218880000 Dust Cover NA NA NA 6.80 11/5/2011 14-40A , 2011350 50029218750100 Dust Cover NA 0.0 NA 10.20 11/5/2011 14-41 1920960 50029222900000 , 14-43 1921080 50029222960000 14-44A 2021930 50029225730100 Producers with Sustained Casing Pressure During TAR • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Z Sent: Thursday, August 18, 2011 11:46 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug A; Daniel, Ryan Cc: King, Whitney; Stechauner, Bernhard; Bommarito, Olivia 0; Reynolds, Charles (ALASKA) Subject: Producers with Sustained Casing Pressure During TAR All, The following producers were found to have sustained casing pressure on the IA on 08/16/2011 during the shut down for turnaround activity. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 06 -13A (PTD #2061020) 14 -10 (PTD #1801300) The following producer was found to have sustained casing pressure on the OA on 08/15/2011 during the shut down for turnaround activity. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. 1 04-4 A (PTD #2011350) ' All the wells listed above will be classified as Not Operable until start -up operations commence and are stable or the well passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Mehreen Vazir • :. Y y �i F e s, o t!; , : (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 8/26/2011 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate El Other 121 ACID Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver[] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ 4 201 -1350 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 21875 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO - 028314 • PBU 14-40A 10. Field /Pool(s): 4 PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 1295 feet Plugs (measured) None feet true vertical 9029.5 feet Junk (measured) None feet Effective Depth measured 12948 feet Packer (measured) 10515 feet true vertical 9029.36 feet (true vertical) 8831 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 20" SURFACE - 133 SURFACE - 132 Surface 4086' 13 -3/8" 72# L -80 SURFACE - 4116 SURFACE - 4020 5380 2670 Intermediate 10845' 9 -5/8" 47# L -80 SURFACE - 10875 SURFACE - 8916 6870 4760 Production Liner 883' 7" 29# L -80 10564 - 11447 8844 - 9038 8160 7020 Sidetrack Liner 3350' 2 -3/8" 4.7# L -80 9600 - 12950 8496 - 9030 11200 11780 Perforation depth: Measured depth: O 11652 - 12917 True Vertical depth: 09031-9027 Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 SURFACE - 10639 SURFACE - 8864 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" X 4 -1/2" BKR DB PKR 10515 8831 QL&#f NOV Z010 A 12. Stimulation or cement squeeze summary: N 0 3 2010 Intervals treated (measured): ii Treatment descriptions including volumes used and final pressure: 0a O M G as Cons. Cnime. s Anchorage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 264 989 1195 201 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory E] Development ❑r Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 116. Well Status after work: Oil d Gas WDSPL I GSTOR ❑ WINJ ❑ WAGE] GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na 'e Jo astufka Title Data Manager Signatur J Phone 564 -4091 Date 11/3/2010 RBDAAS NOV / Form 10-404 Revised 10/2010 0 3 l /s'�o Submit Original Only 14 -40A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/23/2010 ASRC Test Unit #2, Move unit, S/B for snow removal, Snow removal complete, Spot .unit for rig up, S/B for weather >35 mph winds, DRIL conduct PSM well control drill, Conduct man down safety drill, ** *Job in progress * ** 10 /24 /2010iASRC Test Unit #2, S/B for winds, Complete rig up, S/B for CTU, ** *Job in j progress * ** I 10/24/2010 Load fluids, Road to location t I 1 _ _. 0/2- 15/2010 i CTU #9 w/ 1.5" CT Move from Z-13. RU on ASRC flow cross w/ returns to 14 -22. MU 1.875" milling BHA (to remove scale). SI 14 -22, LRS FP wellbore w/ 38 bbls .crude. ASRC bring WOL. RIH w/ motor /mill. * *job continued on WSR 10- 26 -10 ** E , 10/25/2010 ASRC Test Unit #2, S/B for well support/CTU, LRS complete freeze protect, CTU on I ocation, Divert well through test sep, Assist CTU, ** *Job in progress * ** I i I 25/2010 T /I /0= 90/1360/860 Freeze protect Tbg & FL for ASRC Test Unit. (PRE ACID) Pumped into FL w/ 5 meth, 119 bbls crude. DSO shut IGV. Pressured FL to 1500 psi. j Freeze protected Tbg w/ 38 bbls crude. FWHP= 500/1360/860 SV,WV,SSV shut. [ MV,IA,OA Open. Test unit on location upon departure i E 10/26/2010 CTU #9 W/ 1.5" CT (cont from WSR 10- 25 -10) Scope, Mill scale/ Acid stimulation. ,Cont RIH w/ 1.875" mill. Dry tag scale (a)_ 9805'. Mill thru w/ no motor work seen.Continue RIH, tag obstruction @ 11484, briefly sat down, then fell thru. Short trip to LNR top was clean. RIH w/ milling assy to PBD tagged at 12929' while seeing minor MW in a few spots due to DLS. Chase any solids OOH w/ used FloPro. POH. i LD milling assy. Perform weekly BOP test. MU nozzle assy. RIH w/ 1.75" nozzle. E � * *job continued on WSR 10- 27 -10 ** 10/26/2010ASRC Test Unit #2, Assist CTU with scale milling /acid treatment, DRIL conduct well ;control drill in safety meeting, ** *Job in progress * ** I 10/26/2010 &Ll #9 W/ 1.75" CT. (cont from WSR 10- 15 -10) Scope; Mill scale/ Acid stimulation. l ( Cont RIH w/ 1.875" mill. Dry tag scale @ 9805'. Mill thru w/ no motor work seen.Continue RIH, tag obstruction @ 11484, briefly sat down, then fell thru. Short trip to LNR top was clean. RIH w/ milling assy to PBD tagged at 12929' while seeing minor MW in a few spots due to DLS. Chase any solids OOH w/ used FloPro. POH. j LD milling assy. P erform weekly BOP test. MU nozzle assy *"job in progress ** [ I 10/27/2010 CTU #9 w/ 1.5" CT. (cont from WSR 10- 26 -10) Scope; Acid treatment. Continue RIH €w/ 1.75" JSN w/ well flowing. Stop @ 9565' shutin well and FP ASRC surface lines. Load well down CT backside w/ 150 bbls diesel. Continue RIH and swap to kcl down coil to displace meth. Sat down @ 11869, (dogleg) attempt to pass thru several times to no avail. Phone APE.decision made to bullhead acid from 11869'u Pump acid r ecipe; 30 bbls preflush/ 150 bbls 10% DAD acid/ 60 bbls overflush whi a recinrnraf� j from 11650 to 11869'. POOH and RD coil prior to flowback w /ASRC separator. 3 10/27/2010 ASRC Test unit #2, assist CTU w /acid stimulation, POP well, flow acid to tanks * *job 'in progress ** ? * *inlet well 14 -40, outlet 14 -22 ** 1 ___ _ _ 10/28/20101 ASRC Test unit #2, flow back acid stimulation to tanks, divert liquids to production pH 1 7.0, start increasing choke * *job in progress ** * *inlet well 14 -40, outlet 14 -22 ** 3 r � r 1 10/29/20101ASRC Test unit #2, complete 6 hour test, RDMO * *job complete" * *inlet welll 14 -40, outlet 14 -22 ** FLUIDS PUMPED BBLS 631 1% XS KCL 39 1% KCL +F103 +U067 156 10% 90:10 DAD ACID 70 1% KCL +2% F103 150 DIESEL 116 60/40 METH 158 CRUDE 1320 TOTAL TREE= 4- 1/16" CAM • 14-40A SASAFETY *** EST CMT TOP BEHIND PIPE@ WELL = FMC MC 10400'. ACTUATOR= BAKER C KB, R EV = 75.0' NA BF. =� 26 0 20" CONDUCTOR —� ?? 2020' 4 -1/2" AVA SC-SSV TRSSSV, ID = 3.812" Max Angle = 97° @ 11670' GAS LIFT MANDRELS Datum MD= 10672' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum TV D = 8800' SS 1 3223 3200 19 MMG DOME RK 16 06/22/03 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 1 2 4760 4603 25 MMG DMY RK 0 02/28/03 3 6024 5703 32 MMG DOME RK 16 06/22/03 4 7402 6899 28 MMG DMY RK 0 Minimum ID = 1.92" @ 9609' 5 7976 7387 34 MMG DMY RK 0 2 -7/8" X 2-3/8" LNR XO 6 8550 7825 45 MMG DMY RK 0 7 8660 7900 47 MMG SO RK 24 06/22/03 8 9576 8484 54 MMG DMY RK 0 * *9 9688 8547 56 MMG DMY RK 0 ** STA #9 GLM BEHIND CT LNR 3.70" BKR DEPLOY SLV, ID = 3.00" 9600' 2 -7/8" X 2 -3/8" LNR XO, ID = 1.92 9609' 9673' 4 -1/2" TBG PATCH, ID = 3.250" ACROSS GLM #9 (SET 03/06/92) 9750 — 4 - 1/2" OTIS X NIP, I D = 3.813" ESTIMATED TOP OF CEMENT 10400' 10515 9 -5/8" — X4-1/2' BKR DB PKR, ID 10564' 6' TM TIEBA S 10570 9 -518" X 7" TIW LTP w / LNR HGR 10629' 4 - 1/2" OTIS XN NIP, I = 3.725" BEHIND CT LNR 10639 4 -1/2" BKR S SUB 8 10640' 4 - 1/2" WLEG, ID = .958" 3 4 -112" TBG -PC, 12.6 #, L -8 � 10639' - 0152 bpf, ID = 3.958" 10649' ELMD LOGGED 0 1 , r 9 -5/8" CSG, 47 #, L -80, ID = 8.681 10875' 7" MILLOUT WINDOW (14 -40A) 11447'-11452 PERFORATION SUMMARY REF LOG: BHI MWD /GR ON 12/02/01 ANGLE AT TOP PERF: 96 @ 11651' Note: Refer to Production DB for historical pert data SIZE SPF I INTERVAL Opn /Sqz DATE 2 -3/8" 4 11651 - 12916 0 12/05/01 \ ~ PBTD 12948' 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" 11834' 2 -3/8" LNR, 4.7 #, L -80, .0039 bpf, ID = 1.92" 12950' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/23/88 ORIGINAL COMPLETION 04/01/10 JMO /SV TREE GO (03/31/10) WELL: 14 -40A 01/07189 LAST WORKOVER PERMIT No: 2011350 12/05101 CTD SIDETRACK API No: 50- 029 - 21875 -01 02/28/03 CAO /KK GLV C/O SEC 9, T1 ON, R1 4F- 2653' SNL & 1573' WEL 06/02/03 JRC/KK 1 WAIVER SAFETY NOTE REV. 06/22/03 JM/KAK I GLV C/O BP Exploration (Alaska) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 , , ,, ~~~1 ~4 k~ R~~~ ~~ r i by ~' ~: Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, ~ ?t ~~~e1~;~5BC4? ~- ., ~4~V f3~ ~- -~/'` Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 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 i0-404, 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) DS-14 Date: 12/05/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 14-01A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-o3A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-OSA 1920010 500292032701 Sealed Conductor NA NA 14-O6A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA is-08A 2022100 500292033001 Sealed Conductor NA NA 14-09B 1820340 500292053402 Sealed Conductor NA NA 14-t0 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conductor NA NA 14-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA t4-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-186 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 14-26 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 1a-3o 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-40A 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc Permit to Drill 2011350 f- J av- ^--~ ~ 1. DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Well Name/No. PRUDHOE BAY UNIT 14-40A Operator BP EXPLORATION (ALASKA) INC MD 12950 -----.- TVD 9030 .- Completion Date 12/5/2001 /' Completion Status 1-01L Current Status 1-01L Spv..6 ).(1 f\f'ðlfÀðð I API No. 50-029-21875-01-00 UIC N REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Med/Frmt ~" ~- D ~ Electr Dataset Number /- LAf)761 Log Log Run Scale Media No 1 Interval OH / Start Stop CH Received 11450 12950 Open 4/18/2002 Mud Log No Samples No Directional Survey ~"L~ -== (data taken from Logs Portion of Master Well Data Maint) 2 0 9888 Case 5/8/2003 Sample Set Number Comments Blu 1 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? y~ Chips Received? ,-.::LI N Analysis Received? y.' ~J Interval Start Stop Sent Received --". Comments ,,~~. .n Comments: Daily History Received? \J1/N GIN Formation Tops Compliance Reviewed By: ~ --,_.- -- m ~ r ~ ~ ß ) {"I S . Dale: Co J ""'- ¿~ ~ ~I~~ C5 "" MUd ~ fV1 ~ ~ ~ 1f"\vJ'~ IV D ¡I <.{jcs -J ,l'1}' ò {t y f"'~ - \ À ~ }'-~ ( STATE OF ALASKA ( ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanon D After Casinq D Change Approved Program D SuspendD Repair Well. Pull Tubing D Operation ShutdownD PerforateD VarianceD Annuar Disposal 0 Pluq PerforationsD StimulateD Time ExtensionD OtherD Perforate New PoolO Re-enter Suspended WellD LINER TOP PACKER 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 74.00 8. Property Designation: ADL 028314 11. Present Well Condition Summary: 4. Current Well Class: Development. ExploratoryD 5. Permit to Drill Number: 201-135 Stratigraphic 0 ServiceD 9. Well Name and Number: 14-40A 10. Field/Pool(s): Prudhoe Ba Field I Prudhoe Ba Oil Pool 6. API Number 50-029-21875-01-00 Total Depth measured 12950 feet true vertical 9030 feet Plugs (measured) Effective Depth measured 12948 feet Junk (measured) true vertical 9029 feet Casing Length Size MD TVD Burst Collapse Conductor 103\ 2011 1331 1321 40K 520 Surface 4086' 13-3/811 41161 40201 80K 2670 Intermediate 1 08451 9-5/811 108751 89161 80K 4760 Liner 883' 1" 105641-114471 88441-90381 80K 7020 Sidetrack Liner 33501 2-3/811 9600'-129501 84961-90301 80K 11780 Perforation depth: Measured depth: Slotted Liner 116511-129161. True vertical depth: Slotted Liner 9031'.9021'. Tubing: ( size, grade, and measured depth) 4-1/211 12.6# L-80 TBG @ 106391. r~¡~ì""""("'E' f'I' ~u.~"¡""~: .~"I: w ~,!t,"" .,~~"""'" Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2" Baker DB Packer @ 105151. 4-1/211 AVA SC-SSV TRSSSV @ 20201. JUl 0 2 inO3 ,\U')]I'"I!f'" nifi Pm C~I(' r.~!I:'" 8"'\\i(¡.',lôj¡~(!;!J UBi ~~:¡,( <¡';'~'"~'C~ t.".L.", 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Dailv Average Production or Injection Data Gas-Met Water-Bbl Casin Pressure ff,\ '"'ln~P.., !'.\~.", e"'" b"'~~i",~~f¡ji \I~b':; 13 Oil-Bbl Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: SHUT-IN SHUT-IN Copies of Logs and Surveys run - 15. Well Class after proposed work: ExploratoryD Development. 16. Well Status after proposed work: Oil. GasD WAG D GINJD Service 0 WINJ 0 WDSPLD Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWa e R. Schnorr Sundry Number or N/A if C.O. Exempt: N/A Title Techical Assistant Signature Date June 18. 2003 f f 14-40A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/30/2003 PACKERS/BRIDGE PLUGS/POGLMS: DRIFT/TAG 05/31/2003 PACKERS/BRIDGE PLUGS/POGLMS: PATCH TUBING / CASING 06/01/2003 ANN-COMM (AC-EVAL AND REPAIR): AC-MITIA 06/02/2003 ANN-COMM (AC-EVAL AND REPAIR): AC-MONITOR 05/30/03 05/31/03 06/01/03 06/02/03 EVENT SUMMARY (WELL SHUT IN ON ARRIVAL) (PRE IBP SET). DRIFT W/ 3.70 CENT 511 7/8 STEM 3.78 SWEDGE SB. TAG LINER TOP @ 96001 SLM POOH. SB EMPTY ( FL 1201 SLM). (LEFT WELL SHUT IN ). MIRU Coil #5, RIH WITH BAKER KB PACKER. SET LINER TOP PACKER @ 96181 CTMD. MIT TBG X COIL TBG ANNULUS TO 3000 PSI, LOST (62 PSI) IN 30 MINUTES. (THE TBG X CSG IA INCREASED, 606 PSI TO 667 PSI PSI, (61 PSI). DROPPED BALL, SHEARED OFF & POOH. FREEZE PROTECT TBG TO 22001 WITH 50/50 METHANOL. NOTIFIED DSO OF WELL STATUS, MAY NEED GL VALVES INSTALLED TO KICK OFF WELL. «< LEFT WELL SI »> T/I/O = 200/910/40. MITIA TO 3000 PSI --- PASSED. (POST LINER TOP PACKER). TBG FL @ 10301. IA FL @ SURFACE. OA FL @ 401. PRESSURED IA TO 3000 PSI WITH 6.6 BBLS DIESEL. FIRST 15 MINUTES IA LOST 30 PSI. SECOND 15 MINUTES IA LOST 10 PSI. TBG PRESSURE REMAINED THE SAME AND OAP INCREASED 20 PSI DURING TEST. BLED lAP TO 520 PSI. FINAL WHP's = 200/600/40. T/I/O=200/650/20 (POST MITIA) lAP INCREASED 50 PSI IN 24 HOURS. FLUIDS PUMPED BBLS 100 50/50 METHANOL WATER 167 20/0 KCL WATER 267 TOTAL Page 1 \ TREE = 4-1/16" FWC GEN IV WELLHEAD = FMC AC1UA TOR = AXRSON 1<8. RBI = 75.0' BF. REV = NA KOP= 2600' Wax Angle = 97 @ 11670' D3tum tvD = 10672' D3tum 1V D = 8800' SS 13-318" CSG, 72#, L-80, D = 12.347' 4116' Minimum ID = 1.92" @ 9609' 2-7/8" X 2-3/8" LN R XO 3.70" BKR DEPLOY SLV, ID = 3.00" 2- 7/8" X 2-318" LNR XC, ID = 1.92" 9600' 9609' 10564' 10570' 9-5/8" X T' llW LNR HGR 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 1 10639' 9-5/8" CSG, 47#, L-80, ID= 8.681" 10875' ÆRFORA llON SUMrv1ARY RB= LOG: BHI MlNCVGRON 12/02/01 ANGLE AT TOP PERF: 96 @ 11651' Note: Refer to Production 00 for historical perf data SIZE SIT INTERVAL Opn/Sqz DA. TE 2-318" 4 11651 - 12916 0 12/05/01 7" LNR 29#, L-80, 0.0371 bpf, ID = 6.184" 1 11834' 14-40A 8) (' SAFETY NOTES: EST CMT TOP BEHINDPIPE @ 10400'. **GLM #9 BEHND CT Lf'R.** *"POSSIBLE IA X OA COMM. OPERATIt\G LlM ITS: MAX lAP = 2000 PSI. MAX OAP = 1000 PSI. (06102103 WAIVER)** 2020' 4-1/2" AVA sCrssv TRSSSV, 10= 3.812" GAS LIFT MANœELS 1VD ŒV TYPE VLV LATCH 3200 19 MWG DMY RK 4603 25 MWG DMY RK 5703 32 MWG DMY RK 6899 28 MWG DMY RK 7387 34 MWG DMY RK 7387 40 MWG DMY RK 7825 45 MWG DMY RK 7900 47 MWG DMY RK 8484 54 MWG DMY RK 8547 56 MWG DMY RK ST MD 1 3223 2 4760 3 6024 4 7402 5 7976 5 7976 6 8550 7 8660 8 9576 **9 9688 FORT DATE 0 02/28/03 0 02/28/03 0 0 0 0 0 0 0 0 9673' 9750' 10515' 4-1/2"1BG PATCH, ID = 3.250" ACROSS GLM#9 (SEf 03106192) -I 4-1/2"OTISXNIP,ID=3.813" 1 9-518" X 4-1/2" BAKER DB PKR, Il) = 4.75" I 1 0629' 1 0639' 1 0640' I 10649' H 4-1/2" OTISXNNIp, ID= 3.725" 4-1/2" BAKER SHEA ROUT SUB 4-1/2"1UBNG TAL WLEG RMD LOGGED 04121/94 I 7' MLLOUT WINDOW 11447' -11452' (OFFCMf RArvP) I--¡TOP OF 2-3/8" 4.6# SL TO LNR, ID = 1.92" I 12948' I I B11\I1 OF 2-3/8" SL TD LNR H 2-318" LNR, 4.7#, L-80, .0039 bpf, ID = 1.92" 12950' DATE REV BY 00 MM ENTS DA.TE RBI BY COM'v1ENTS 11/23/88 ORIGINAL OOrvPLEfION 12/28101 Œi/W CORRECllO NS 01/07/89 LAST WORKOVER 02/09103 A TO/W DELETE WA IVER SAFElY NOTE 12/05/01 cm S IDETRA 0< 02/28/03 CAO/KK GLV ao 04/19/01 RN'TP OORRECnONS 06/02103 JRC/KK W AIV ER SA FETY NOTE REV. 05/04/01 JJ/KA K SET IBP 10/29/01 SRB/KK CEMENT & ALOT HOLES FRLDHOE BA Y UNIT WRL: 14-40A PERMIT No: 2011350 API No: 50-029-21875-01 SEC 9, T10N, R14E, 2653' SNL & 1573' WEL BP Exploration (Alaska) 14-40A (PTD #2011350) Class B3 producer - Return to Production ; , (" Jûj. Subject: 14-40A (PTD #2011350) Class B3 producer - Return to Production J? 1# ~ " Ib3 ~71. Date: Mon, 2 Jun 2003 17:01 :00 -0500 ,\ "'Y1 f 4 ï c. .J From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> To: "AOGCC Winton Aubert (E-mail)" <Winton_Aubert@admin.state.ak.us>, . \~O1 "AOGCC Jim Regg (E-mail)" <Jim_Regg@admin.state.ak.us> (() (] A'ir~ c C: "A DaCC Field Inspectors (E-mail)" <A DaCC ]rudhoe - Bay@admin.state.ak.us>, \~\ \ "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein@admin.state.ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> { J3: Hi Winton and Jim, 14-40A (PTD #2011350) was classified as a "137-B3" well due to TxIA comm and slow IAxOA comm. We recently installed a liner top packer in well 14-40A and ~ are planning to return the well to production. The recently installed liner top packer has eliminated the tubing x IA communication (as shown by the passing MITIA) and the slow IAxOA comm is addressed with the passing MITOA. A brief history of events is as follows: > 12/02/02: MIT-OA Passed to 3000 psi, AOGCC witnessed. v~ > 12/28/02: PPPOT-T and PPPOT-IC Passed / > 05/31/03: Coil Tubing set KB packer at liner top to repair T x IA corom. > 06/01/03: MITIA Passed to 3000 psi. V- > 06/02/03: Winton Aubert of the AOGCC waived the requirement for an AOGCC representative to witness the MITIA. Attached are the completed MIT forms and a wellbore diagram (the WBD shows the configuration of the wellbore prior to the installation of the linertop packer). Please let me know if you have any questions. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 «14-40A.pdf» «MITIAP PBU 14-40A 06-01-03.xls» PBU 14-40A 12-02-02.xls» «14-40 PPPOT 12-28-02.xls» «MITOAP I. . {~~~~~ Name: MITIAP PBU 14-40A 06-01-03 .xls / 0 MITIAP PBU 14-40A 06-01-03 .xls Type: Micr~so~t Excel Worksheet ( apphcatlon/vnd.ms-excel) Encoding: base64 "--..""-'-" ....."......_,---,..., .'-""-"-"'.""-"'.'."........-.--.....-... -..............,...-..,--..-....--..,...... r""'---'-""-'."'."'-'-'--""'-'."-'--'-"."'" """"""'. '.'."'--""""-"""'" -'.""."-'-""""""--"""."-"'.""""'-"'--"" "'--'.'."'.-"'-".."""'-"" "---""-1 I ¡ Name: MITOAP PBU 14-40A 12-02-02.xls . DMITOAP PBU l4-4OA l2-02-02.xls Type: Micr~so~ Excel Worksheet ( apphcatlon/vnd.ms-excel) Encoding: base64 ." ' "..".., 1 of2 6/18/2003 10:53 AM 14-40A (PTD #2011350) Class 83 producer - Return to Production . . (' ( Name: 14-40 MIT 12-28-02.xls D 14-40 MIT 12-28-02.xls T~pe: Microsoft Excel Worksheet (applicationlvnd.ms-excel) Encoding: base64 Description: 14-40 PPPOT 12-28-02.xls / 2 of2 6/18/2003 10:53 AM ( { STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU I DS-14 06/01/03 Patterson Packer Depths (ft.) Pretest Initial 15 Min. 30 Min. Well 14-40A Type Inj. N/A MD/TVD 10,515' 8,831' Tubing 200 200 200 200 Interva 0 P.T.D. 2011350 Type test P Test psi 3000 Casing 910 3000 2970 2960 P/F P Notes: Class B3 Producer. MITIA was performed to establish tubing and IA integrity prior to return to production. Well Type Inj. MD/TVD Tubing Interva P.T.D. Tvpe test Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interva P.T.D. Type tes Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interva P.T.D. Tvpetes Test psi . Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interva P.T.D. Type tes Test psi Casing P/F Notes: ¡,/ Test Details: MIT-IA was performed to confirm tubing and production casing integrity (two barriers) after setting a liner top packer. This well is a class B3 producer. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover a = Other (describe in notes) MIT Report Form Revised: 06/19/02 14-40A_MITIAP _6-01-03.xls ( ( WELLHEAD PACKOFF TESTING FORM [ WELL: Ds 14-40 DATE: 12/28/2002 TESTED BY: Moffitt TEST FOR: TYPE & GEN FMC IV INITIAL PRESSURE DATA Well Status: TBG: CONTROL: TYPE: 0 IA: 355 OA: 250 3250 BALANCE: 0 PASS Tubing Hanger Test Pressured To: 5000 Press. @ 15 min: 5000 Press. @ 30 min: Test Port Press. @: 0 Bled to 0 Psi YES I NO Were Lockdown Screws Tightened? YES I Torqued to Comments: Two gland nuts leaked. They were torqued and tested 5000 450 ft/lbs Inner Casing Hanger Test p.ass Pressured To: 3200 Press. @ 15 min: 3200 Press. @ 30 min: Test Port Press. @: 0 Bled to 0 Psi YES I NO Were Lockdown Screws Tightened? YES I Torqued to Comments: 3200 450 ft/lbs ~, ( lREE = 4-1/16" Ffv'C GEN IV WELLHEAD = Rv1C AClUA TOR= AX8.SON 1<8. 8.81 = 75.0' BF. B..EV = NA KOP= 2600' Wax Angle = 97 @ 11670' CI:Itum ~ = 1 0672' CI:Itum lV D = 8800' SS I 13-318" CSG, 72#, L-80, D = 12.347" 1 4116' Minimum ID = 1.92" @ 9609' 2-7/8" X 2-3/8" LN R XO 3.70" BKR [EPLOY SL V, ID = 3.00" 2-7/8" X 2-318" LNRXO, ID= 1.9Z' 9600' 9609' 6' TIW llEBACK SLV 9-5/8" X 7" 1lW LNR HGR 10564' 10570' 4-1/2"TBG-PG, 12.6#, L-80, .0152 bpf, ID= 3.958" 1 10639' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10875' PERFORA llON SUMIlAA.RY REF LOG: BHI MNQlGR ON 12/02101 ANGLE AT TOP PERF: 96 @ 11651' Note: Refer to Production œ for historical perf data SIZE 8FT INTERVAL Opn/Sqz DAlE 2-318" 4 11651 - 12916 0 12/05101 7"L NR, 29#, L-80, 0.0371 bpf, ID = 6.184" 1 11834' ( SAFETY NOTES: T xlAx OA COMM TO AIL. FTS WELL MITIA FAlLEn AOGCC FTS R~URES AIL OPERATION. 2- 3/S" LfIR IS PRE-DRLD WITH 318" IÐLES @ 41FT. WELL ANGLE> 70° @ 9975' & > goo @ 11491'. 2-3IS" LNR CMT'DWI15.8 PPG CMT. EST CMT TOPBÐlNDPFE@ 10400'. -GLM #9 BetlN> CT LNR- 14-40A (1\ 2020' ST MD lVD 1 3223 3200 2 4760 4603 3 6024 5703 4 7402 6899 5 7976 7387 5 7976 7387 6 8550 7825 7 8660 7900 8 9576 8484 **9 9688 8547 9673' 9750' 10515' 1 0629' 10639' 1 0640' I 10649' 4-1f2" AVA SG-SSV lRSSSV, ID= 3.812" GAS UFT MANCRB.S ŒV TYPE VLV LATCH 19 MM3 DMY ~ 25 MM3 DMY ~ 32 MM3 DMY ~ 28 MM3 DMY RK 34 MM3 DMY RK 40 MM3 DMY RK 45 MM3 DMY RK 47 MM3 DMY RK 54 MM3 DMY RK 56 MM3 DMY RK FORT DATE 0 02/28/03 0 02/28/03 0 0 0 0 0 0 0 0 4-1/2" lBG PATCH, ID = 3.250" ACROSS GLM #9 (SET' 03/06192) -I 4-1/2" OTIS X NIP,ID = 3.813" I -i 9-518" X 4-1/2" BAKER DB PKR, 10 = 4.75" I -i 4-1/2" OTIS XN NIP, ID = 3.725" -I 4-1/2" BAKER SHEA ROUT SUB I -i 1-1 4-1/2" lUBNG TAL WLEG B..MD LOGGED 04121/94 7" MLLOUTWINDOW 11447' - 11452' (OFF CMf RAtvP) ~11651' I-iTOP OF 2-3/8" 4.6#SL lD LNR, 10 = 1.92" I .... ...... .... ...... .... .... ...... ...... .... ...... ...... ...... ..... ..... ...... ...... "-"- "-"- 17 H 12948' I .... ..... ...... ...... ..... .... ...... ...... ..... ...... .... I B1M OF 2-3/8" SL TD LNR H 12916' r 2-318" LNR, 4.7#, L-80, .0039 bpf, ID = 1.92" DATE REV BY COMvlENTS DAlE REV BY COMvlENiS 11/23/88 ORIGINAL COtvPLET'ION 12/28101 a-I/lP CORRECllONS 01/07/89 LAST WORKOVER 02/09103 A lD/lP OELErE WA IVER SAFElY NOTE 12/05/01 CTD SIŒrRAO< 02/28103 CAO/KK GLV 00 04/19/01 RI\VTP CORRECTIONS 05/04/01 JJ/KAK SET lap 10/29/01 SRBlKK CEMENT & ALOT HOLES FRUDHOE BA Y UNIT WB..L: 14-40A PERMIT No: 2011350 A PI No: 50.029-21875-01 SEC 9, T10N, R14E, 2653' SNL & 1573' WEL BP Exploration (Alaska) Schlumberger 04/17/03 NO. 2751 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well MPS-30 1.n.d~a. ~~~ F-15 ¥ j -, ?ÿ) 2-18/L-16 I ~ n·-·o~l ~ 1-69N-19 I GJ{) -Q~ '1 0.5. 6-07 I Î ~ -Dei- I 0.5. 14-40Aqol- i ~ ~ 0.5. 15-02A 1'-10-11(13 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott,Milne Pt. Job # Color Date Blueline Prints CD 02/13/03 1 01/08/03 1 1 03/05/03 1 1 03/09/03 1 03/12/03 1 03/14/03 1 02/16/03 1 .~ Log Description 23078 CH EDIT (PDC) 23052 RST -SIGMA 23095 RST-SIGMA INJECTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG SBHP SURVEY .~ 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, Alaska 99508 Date Delivered: RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Receivedd~ (; ~ MAY 082003 A ia,.,J., .");; ') ..... . Ii ¢~ð f....ìI Q: lJas ConS. Co, . . AnC'homge ~n ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP' BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / 08-14 12/02/02 Jared Brake ,-~J - ~ ()i) ~S v~-e.,,> \'\0 t-r~ J 'w).~ ~P¥ ~ . /' Packer Depths (ft.) Pretest Initial 15 Mip/. 30 Min. Well 14-40A Type Inj. NIA MD/TVD 10,515' 8,831' IA 350 Interva 0 P.T.D. 2011350 Type test P Test psi 3000 OA 20 3000 2960 2940 P/F P Notes: MITOA was performed to establish OA integrity prior to return to production. Well Type Inj. MD/TVD Tubing Interva P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interva P.T.D. Type tes Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interva P.T.D. Type tes Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interva P.T.D. Type tes Test psi Casing P/F Notes: Test Details: MIT-OA was performed to confirm surface casing integrity. This well is a class B3 producer. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 14-40A_MITOAP _12-02-02.xls :{ MEMORANDUM ,f State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner ~ DATE: December 2, 2002 --" ~ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder A.O1fV ¡ BPX P.L Supervisor tð"i.r \').tSo7 DS 14 14-40A FROM: Chuck Scheve PBU Petroleum Inspector Prudhoe Bay NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 14-40A Type Inj. T.V.D. IA 350 400 400 400 Interval P.T.D. 201-135 Type test P Test psi OA 3000 2960 2940 P/F Notes: Class A-B3 producer Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casi ng P/F Notes: ' Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W~ Test during Workover 0= Other (describe in notes) Test's Details ' I traveled to BPXs Drill Site 14 and wi1nessed the :MITOA on well 14-40A. This well is in the A..B3category. The tub:ingappeared to be dead and the IA pressure stable. The outer annulus appeared to pass this 30 m:inute pressure test. M.LT.'s performed: 1 Attachments: Number of Failures:.Q Total Time during tests: 2 hours cc: M IT report form 5/12/00 loG. MITOA PBU 4-40A 12-2-02 CS.xls 12/5/2002 , ( STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG * 1. Status of Well Œa 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 :"~;:\,:' . ':¡ .:' 2653' SNL, 1573' WEL, SEC. 09, T10N, R14E, UM,; I. . At top of productive interval ", ,J.~-~$.~: QL . 2407' SNL, 2622' WEL, SEC. 16, T10N, R14E, UM: ':"';";.:" '..: . At t~tal depth , .~ ...._:;11>-.... :. 3958 SNL,3249 WEL, SEC. 16, T10N, R14E, UM :".".....",....,..,.." 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designatior:1 and Serial No. RKB = 74' ADL 028314 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 11/29/2001 12/2/2001 12/5/2001 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12950 9030 FT 12948 9029 FT Œa Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, CNL 23. CASING SIZE 20" 13-3/8" 9-518" 711 Classification of Service Well Ih ' ..,.,.; ~æ: :. \ s<,~~ J: I" '.\'4 ; ,:'. ¡'\. - '-:'¡~'~ .-,~,..-....-,.....,....... 7. Permit Number 201-135 8. API Number 50- 029-21875-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-40A 11. Field and Pool Prudhoe Bay Field 1 Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2020' MD 1900' (Approx.) WT. PER FT. 91.5# 68# 1 72# 47# 29# 4.7# GRADE H-40 K-55 1 L-80 L-80 L-80 L-80 CASING LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 1031 3011 260 sx Arctic Set (Approx.) Surface 41161 17-1/211 2500 sx CS lit, 600 sx 'G', 200 sx CS II Top Job Surface 10875' 12-1/411 600 sx Class 'GI 105641 11447' 8-1/211 350 sx 'G'. Lnr Lao Sqzd with 240 sx 'G' 9600' 12950' 3" 105 sx Class 'G' AMOUNT PULLED 2-3/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-3/8" Slotted Liner SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 1 0640' PACKER SET (MD) 10515' 25. MD TVD MD TVD 11652' - 12917' 9031' - 9027' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 20001 Freeze protected with 23 bbls of MeOH 27. Date First Production December 13, 2001 Date of Test Hours Tested 12/15/2001 8 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD OIL-BBL 3820 OIL-BBL GAs-McF 12982 GAs-McF WATER-BBL 761 WATER-BBL CHOKE SIZE GAS-OIL RATIO 90 2787 OIL GRAVITY-API (CORR) Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. R. "m:C~Er El) . "'1 ~'.l - Ji\N J II 2002 Form 10-407 Rev. 07-01-80 I/, ~,1 ?,~ ?n¡J') Alaska Oil & Gas Coos. Commission r'\ r\ , t" ~ ~\ I ^, ; Anchof:;:1l1e U K I u \ ¡ \ !-\ L R B OMS B FlC,¡-9AN 2 4 ~mit In Duplicate ( (' 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include inteNal tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River 109631 8878' Shublik 1 08031 89021 Sadlerochit / Zone 48 11238' 8991' HOT 11580' 9059' E' '" (Ç'" rt"';:p' ~ '\~,¡; E,;"O:; JJI1IIIJ" t'/iIi""I' .="",\1>" "Ii "",,," . ,.. I"J ",,", n f\ ~l,:¡) 1. ? Z 0 \) '2. ,jl ,.', i ~ C'\f\'fI'\~\'1i\C'S~O[~ : 'kaOU&GasCOOS. vm!III,~ A\as ~~ncho~age 31. List of Attachments: Summary of Daily Drilling Reports, SuNeys, Pre Rig Summary and Post Rig Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date Of. I {--O 14.40A Well Number 201-135 Permit No. / A roval No. 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 OR\b\r'!!~L Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/21/2001 11/22/2001 11/23/2001 11/24/2001 11125/2001 11/26/2001 ( ( BP EXPLORATION Operations Summary Report 14-40 14-40A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 16:00 - 00:00 From - To Hours Activity Code NPT WAIT PRE 00:00 - 00:00 00:00 - 06:00 06:00 - 06:45 06:45 - 18:00 18:00 - 18:45 18:45 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 14:30 14:30 - 14:45 14:45 - 17:00 17:00 - 21 :00 21:00-21:45 21 :45 - 00:00 00:00 - 00:45 00:45 - 01 :10 01: 1 0 - 01 :30 01 :30 - 05:30 05:30 - 08:00 08:00 - 10:00 10:00 - 20:30 20:30 - 21 :30 21:30-21:45 21:45 - 22:15 22:15 - 00:00 00:00 - 00:30 00:30 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 08:30 8.00 MOB N 24.00 MOB 6.00 MOB 0.75 MOB 11.25 MOB 0.75 MOB 5.25 MOB 0.50 MOB N N P N P N N WAIT PRE WAIT PRE PRE WAIT PRE PRE WAIT PRE WAIT PRE 0.50 MOB P PRE 13.50 MOB 0.25 MOB 2.25 MOB 4.00 MOB 0.75 RIGU 2.25 RIGU 0.75 RIGU 0.42 RIGU 0,33 RIGU 4.00 RIGU N P P P P P P P P P WAIT PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE 2.50 RIGU P PRE 2.00 RIGU P 10.50 BOPSUF P PRE DECOMP 1.00 BOPSUF P DECOMP 0.25 CLEAN P 0.50 CLEAN P DECOMP DECOMP 1.75 CLEAN P 0.50 CLEAN P 1.50 CLEAN P DECOMP DECOMP DECOMP 1,00 CLEAN P DEcaMP 1.00 CLEAN P DECOMP 1.00 CLEAN P DECOMP 1.00 CLEAN P DECOMP 2.50 CLEAN P DECOMP Phase Page 1 of 8 Start: 9/12/2001 Rig Release: 12/5/2001 Rig Number: Spud Date: 11/25/2001 End: Description of Operations Wait on Weather on DS 15. Wind to high to lay down wind walls. Wind at 20-265 mph. Continue to standby on weather on DS 15. Continue to wait on wind. Weekly safety meeting for night tour. Wait on wind. Weekly safety meeting for day tour. Continue to wait on wind. Winds 15 gusting to 30 at 18:00. Continue to wait on wind. windw moderating. Now at 14 gusting to 22 mph. Winds moderating, hold PJSM for laying over wind walls and derrick. Continue to wait on wind. Safety Meeting. Lay down wind walls. Scope down derrick, lay down derrick. Move from DS 15 to DS 14. Safety meeting prior to raising wind walls and derrick, Raise derrick, scope out same. Raise wind walls. Continue to raise derrick and wind walls. Move rig in over well. Nipple down tree cap. Nipple up BOP stack. Rig accept at 01 :30 AM. PU injecter, MU gooseneck. Berm crew set up berm and cuttings tank, and hard line to flowback tank. Changing packoffs. Stab CT into injecter. Cut off 150 ft of CT. Perform initial BOPE pressure I function test. Test Witnessed by AOGCC inspector John Crisp. Replaced leaking 3" low torque valve on drain line. Filled rig pits with 2% KCL water and 1/2 ppb Biozan. Serviced injector head. Pull test CTC to 26klbs, PT to 3500 psi. Fluid pack coil, PT Inner reel valve. safety meeting prior to picking up first drilling BHA. MU BHA #1 to clean out cement from old well bore. WF straight motor, Hughes bi centered 2.75x3.0" bit. RIH with BHA #1 Continue RIH with BHA #1. Weight check at 11 000'=29klbs. Tag up at 11158' CTM, correct to last tag of 11155', Pick up, free spin=1150 psi at 1.6 bpm. Begin milling from 11155'. 11160.5', 02:00 update. Drilling hard cement. 1.7 in/out, 200 psi motor work. Only making about 5 fph. Drilling 17 PPG Aggregate cement [20 PPB Agg.]. 11190', 03:00 update, Drilling ROP up to 30 fph now. 1.76/1.7/1335 psi. 11200',04:00 update. Drilling ROP now at 10 fph. 1.7/1.711300 psi. 272 bbls in pit. 11214', 05:00 update. Drilling ROP 15' for last hour. 1.6/1.5/1300 psi. 272 bbls in pits. 11221', 06:00 update. Drilling ROP 7' for last hour. 1.7/1.6/1380 psi. 268 bbls in pits. Drilled to 11,270 ft by 0830 Printed: 12/10/2001 11:17:38AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/26/2001 11/27/2001 d' ( ( BP EXPLORATION Operations Summary Report 14-40 14-40A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 06:00 - 08:30 08:30 - 14:00 14:00 -17:30 17:30 -19:30 19:30 -19:45 19:45 - 20:00 20:00 - 20:45 20:45 - 21:10 21:10-21:30 21 :30 - 22:55 22:55 - 23:15 23:15 - 23:45 23:45 - 00:00 00:00 - 01 :15 01:15-01:55 01 :55 - 02:20 02:20 - 02:30 02:30 - 04:00 04:00 - 04:25 04:25 - 06:30 06:30 - 09:30 09:30 - 10:30 10:30 - 11 :30 11 :30 - 12:00 12:00 -15:00 2.50 CLEAN P 5.50 CLEAN P 3.50 CLEAN P 2.00 CLEAN P 0.25 CLEAN P 0.25 STWHIP P 0.75 STWHIP P 0.42 STWHIP P 0.33 STWHIP P 1.42 STWHIP P 0.33 STWHIP P 0.50 STWHIP N 0.25 STWHIP N 1.25 STWHIP N 0.67 STWHIP N 0.42 STWHIP N 0.17 STWHIP N 1.50 STWHIP N 0.42 STWHIP P 2.08 STWHIP P 3.00 STWHIP P 1.00 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 3.00 STWHIP P Phase DECOMP DEcaMP DECOMP DEcaMP DEcaMP WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Page 2 of 8 Start: 9/12/2001 Rig Release: 12/5/2001 Rig Number: Spud Date: 11/25/2001 End: Description of Operations hrs. Ave. ROP = 20 FPH. Mill 17 PPG, Agg. CMT. Ave ROP = 11 FPH. 1.7/1.7 BPM, 1500 psi. Drilled to 11 ,330 ft. Mill 17PPG, Agg. CMT. Slow drilling, 15 FPH. Drill out of aggregate at 11,365 ft. ROP increased to 60 FPH. Full returns. Drill to 11,400 ft. CTD. Circ. 15 bbl high vis pill to clean hole. POOH for MWD Pilot hole BHA. Tag up at surface, lay down BHA #1. Safety meeting to discuss window milling operations. MU BHA #2, Pilot hole BHA with MWD, Sperry Orienter, 1.75 deg WF motor, D331 DSM. RIH with BHA #2 Shallow hole test of MWD and orienter. All ok. Continue to RIH. Tagged up at 11169', picked up heavy. RIH, tagged up at 11161'. Humm? Pick up. Kick on pumps to 1.7, Free spin=2300 psi. Ream top of pilot hole. Fell through easily. RIH to 11240'. Try to start tie in logging pass down at 11240'. No pulses from MWD tool. Try pumps down/up. No success. Pull up above top of pilot hole. Pumps downlup again. Still doesn't work, POOH for new pulser. POOH to troubleshoot MWD problems. POOH to troubleshoot MWD. Tag up at surface. Troubleshoot MWD. Found damaged piston in pulser. Change out pulser. RIH with BHA #2. Shallow hole test ok. Continue to RIH with BHA #2. No problems RIH through top of cement sheath. Ran down to 11240' easily. Log tie in pass down from 11240'. 1.7 bpm, 60 fph. Tag up at 11254'. Stop log, try to clean out hole to 11400'. Note - We are in interval of perforations. Could be hanging up on cement nodes at perfs? Hard to believe with a D331. Pickups have been clean. No Tie-in made. Mill down from 11253'. Tag up at 11255' and stall. Tool face 90L. Pick up, take 4 clicks. Tag uplmotor work again. Take 4 more clicks. Tag up at 11257'. Acts like a chunk of cement that we are chasing down hole. Keep after it. Very grabby on the stalls. Not getting much mill on bottom time. Keeps stalling. Last tool face 75R. Take 5 more clicks. TF 165R. Still stalling at 11254'. Assume it is a chunk of debris from the top of the cement sheath, Continue millinglstalling on it. Chasing debris down hole. Ream ahead at 1-3 FPM to 11,350 ft. Several stalls at 11,350 ft. Work thru spot at 11350 ft. Ream in hole to PBTD at 11402 ft. Back ream to 11240 ft. Log Tie-in with GR. Added 5.5 ft to CTD. Orient TF to Low side. Mill cement. 1.7/1.7 bpm, 2950 psi, TF = 170L, Rap = 25 Printed: 12/10/2001 11: 1 7:38 AM BP EXPLORATION Page 3 of 8 Operations Summary Report Legal Well Name: 14-40 Common Well Name: 14-40A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 9/12/2001 End: Contractor Name: NORDIC CALISTA Rig Release: 12/5/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/27/2001 12:00 - 15:00 3.00 STWHIP P WEXIT FPH. 3000# WOB. Mill cmt to 11424 ft, 15:00 - 17:00 2.00 STWHIP P WEXIT Mill cement. 1.7/1.7 bpm, 3000 psi, TF = 170L Mill to 11442'. 17:00 - 17:30 0.50 STWHIP P WEXIT Orient to 1 OL. 17:30 - 19:30 2.00 STWHIP P WEXIT Mill cement ramp wI HS TF from 11442' and contacted 7" @ 11449.5' 1.7/3200/10L. PUH and flag at 11300' EOP 19:30 - 21 :15 1.75 STWHIP P WEXIT POOH for window mill 21:15 - 22:00 0.75 STWHIP P WEXIT Change out motor and mill. Pilot mill gauged 2.77" 22:00 - 00:00 2.00 STWHIP P WEXIT RIH wI BHA #3 (2.5 deg motor wI 2.74" window mill) 11/28/2001 00:00 - 00:45 0.75 STWHIP P WEXIT RIH at min rate thru cement sheath at 40'/min, clean. Check depth at flag and no corr. RIH at min rate to tag at 11448.7' CTD. PUH and check TF at 30L. Start pump 1.6/2710 and tag at 11447.0'. PUH l' and chk TF @ 32L 00:45 - 01 :50 1.08 STWHIP P WEXIT Try one click and got 4. PUH 10' and orient around 01 :50 . 07:00 5.17 STWHIP P WEXIT Get 5L and will live with it. RIH and tag at 11446'. Flag CT. PUH 1'. Begin time milling by schedule 1.6/2540/5L 13.6k, Mill to 11447.0' at 5L-10R 07:00 - 08:35 1.58 STWHIP P WEXIT Milling window. 1.6/2750/9L 11.0K 08:35 - 09:00 0.42 STWHIP P WEXIT Milling window. At 11448.5', got back major weight from 9.8K# to 11,9K#. TF jumped from 7R to 25R. 09:00 - 10:30 1.50 STWHIP P WEXIT Mill ahead at 10' per hr to 11452'. Begin stacking weight again. Pump 10 bbls bio sweep. 1:1 rtns. Started stacking wt again at 11450'. Stack 6K# with 100-200 psi mtr work. Not drilling off. 10k# over pulls when picking up. 10:30 - 11 :00 0.50 STWHIP P WEXIT Back ream at 0.5'/min. 11 :00 - 11 :30 0.50 STWHIP P WEXIT RIH. Tag at 11452'. 200 dpsi mtr work, but no drill off. Only stacking wt 6k-7k down) 11 :30 - 13:00 1.50 STWHIP P WEXIT POOH to check window mill. 13:00 - 14:00 1.00 STWHIP N DPRB WEXIT Inspect mill. Clear evidence of having crossed center line. Re-run mill on 1.75 deg motor. 14:00 - 16:00 2.00 STWHIP N DPRB WEXIT RIH. Shallow test mwd. Continue in hole. Tag at 11450' 16:00 - 16:45 0.75 STWHIP N DPRB WEXIT Orient to 5L. RIH. Tag up short of flag. 16:45 - 17:15 0.50 STWHIP N DPRB WEXIT Log gr tie in down from 11240'. Add 4' correction. 17:15 - 17:30 0.25 STWHIP N DPRB WEXIT Tag at 11455.7' corrected. (1' from flag) TF at 60R. 17:30 - 18:30 1.00 STWHIP N DPRB WEXIT Orient around to HS, 18:30 - 19:15 0.75 STWHIP N DPRB WEXIT Ream window area to TD 1.6/2600/1 OL. Drill formation from 11455.7' to 11468.0' Unless otherwise verified TOW is 11447' and BOW is 11452' 19:15 - 21 :05 1.83 STWHIP N DPRB WEXIT POOH for tapered mill 21 :05 - 22:30 1.42 STWHIP P WEXIT LD motor and mill. MU new motor and used tapered mill. Change out BHI MWD tool 22:30 - 00:00 1,50 STWHIP P WEXIT RIH w/ BHA #5 (1.75 deg WF motor, 2.73" tapered mill with 1" OD bald cap) 11/29/2001 00:00 - 00:50 0.83 STWHIP P WEXIT Continue RIH wI BHA #5 00:50 - 01:10 0.33 STWHIP P WEXIT Tag at min rate at 11450' un corr. PUH and chk TF at 11 OL. Orient to HS 01:10-02:45 1.58 STWHIP P WEXIT 1.5/2460/8L Ream window area. Had 3 stalls at 11447.3', then RIH to TD at 11464' at 27L. See flag at 11458' which means we're on depth with previous run. Get a click and backream up. Repeat thru 42R. Dry run, clean 02:45 - 04:25 1.67 STWHIP P WEXIT POOH for drilling assy 04:25 - 05:40 1.25 DRILL P PROD1 Change motor, MHA, MWD probe and restrictor (' ( Printed: 12/10/2001 11:17:38AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/29/2001 11/30/2001 ( - (' BP EXPLORATION Operations Summary Report 14-40 14-40A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 05:40 - 07:45 07:45-08:15 08:15 - 08:45 08:45 - 09:00 09:00 - 09:45 09:45 -10:15 10: 15 - 11 :30 11:30-12:00 12:00 -12:30 12:30 - 13:30 13:30 -14:15 14:15 - 15:00 15:00-15:15 15:15 - 16:30 16:30 - 16:40 16:40 - 17:00 17:00-17:15 17:15 - 17:45 17:45 - 18:00 18:00 - 19:30 19:30 - 20:10 20:10 - 20:25 20:25 - 21 :05 21:05 - 21:45 21:45 - 22:10 22:10 - 22:50 22:50 - 23:10 23:10 - 00:00 00:00 - 01:10 01:10 - 02:00 02:00 - 02:30 02:30 - 03:10 03:10 - 03:40 03:40 - 03:50 03:50 - 04:15 04:15 - 05:10 05:10 - 06:00 06:00 - 07:00 07:00 - 07:15 07:15 - 08:00 2.08 DRILL 0.50 DRILL 0.50 DRILL 0.25 DRILL 0.75 DRILL 0.50 DRILL 1.25 DRILL 0.50 DRILL 0.50 DRILL 1.00 DRILL 0.75 DRILL 0.75 DRILL 0.25 DRILL 1.25 DRILL 0.17 DRILL 0.33 DRILL 0.25 DRILL 0.50 DRILL 0.25 DRILL 1,50 DRILL 0.67 DRILL 0.25 DRILL 0.67 DRILL 0.67 DRILL 0.42 DRILL 0,67 DRILL 0,33 DRILL 0.83 DRILL 1.17 DRILL 0.83 DRILL 0.50 DRILL 0.67 DRILL 0.50 DRILL 0.17 DRILL 0.42 DRILL 0.92 DRILL 0.83 DRILL 1.00 DRILL 0.25 DRILL 0.75 DRILL P P P P P P P P P P N P P P P P P P P P P P P P P P P P P P P P P P P P P P P P Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 HMAN PROD1 PROD1 PROD1 PROD1 . PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 4 of 8 Start: 9/12/2001 Rig Release: 12/5/2001 Rig Number: Spud Date: 11/25/2001 End: Description of Operations RIH w/ BHA #6 (1.15 deg motor) SHT Log GR tie in from 10810'. Add l' correction. RIH to previous tie in point at 11240'. Log gr again to verify on depth with orignal tie in point used to mill window. No correction. RIH. Tag TD at 11464'. TF at HS. Drilling. Begin displacement to mud. 1.7/1.6/2800 psi fs I TF:HS Drill to 11495'. Tool face flopping to low side. Orient several times. TF still erratic. Formation? Fault? Bad orienter? Finally stabilized at 80R. Drilling. 1.7/1.6/2650fs/TF: 120R 100-150fphROP Drill to 11610' Orient around to 80R. Short trip to window. Drilling. 1.6/1.6/33001 TF:120R 100-150 fph. Drill to 11710'. Re-Iog interval due to mwd problem. Drilling. 1.7/1.6/3200/TF:150R 100-150fph. Drill to 11775'. Orient to 80L at 11864' Drilling. 1.7/1.7/3200/TF:150L 100-130fph. Drill to 11900'. Orient to 105L Drilling. 1.7/1.6/3200/TF:150L 100-150fph. Drill to 11923'. Orient to 130L Drilling. 1.7/1.7/3200/TF:150L 100-150fph. Drillto 11955'. Short trip to window. Hole smooth. Drilling. 1.7/2700/90R 90-150'/hr Losing 3 bph PVT 230 Get down to 84 deg at 12016' and build back up. Drill to 12060' and stacking Wiper Log tie-in down from 10810' 1.6/2440/25R No corr, RIH. RIH thru window at 41 L, clean Drilling 1.6/2550/30L 60-90'/hr Went thru a shale at 12050' Drill to 12105' Orient around Drilling 1.7/2680/80L Drill to 12127' and stacking Wiper back thru shale area to 12000' Drill/spud/featherlstack Try to make some hole from 12127'. Drill to 12138' Continue attempting to make hole from 12138-43' and stacking Wiper to window from 12143' Resume drilling at same slow rate. Start new mud Love new mud. After 20 bbls new mud out of bit P rate was back to 1 OO'Ihr and string wt went from -5.2k to 4.2k, Drill to 12220' 1.7/2950/67L Orient around Drilling 1.7 /2800/130L to 12242' Orient around to right Drill to 12304' 1.7/2800/1 04R Wiper to window Drilliing. 1.7/2820/150R In shale. Slow drilling. Orient to 160R. Drilling. 1.7/1.7/2950/160R Drill to 12388'. 40-50 Rap. Printed: 12/10/2001 11: 1 7:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/30/2001 1211/2001 ( ( Page 5 of 8 BP EXPLORATION Operations Summary Report 14-40 14-40A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 07:15 - 08:00 08:00 - 09:45 09:45 - 10:00 10:00 - 11 :00 11:00-13:15 13:15 - 14:00 14:00 - 16:00 16:00 -16:15 16:15 - 16:45 16:45 - 17:00 17:00 - 18:00 18:00 -18:50 18:50 -19:50 19:50 - 21:40 21:40 - 00:00 00:00 - 00:30 00:30 - 00:40 00:40 - 01 :20 01:20 - 01:35 01 :35 - 02:30 02:30 - 03:45 03:45 - 04:00 04:00 - 04:30 04:30 - 04:45 04:45 - 06:00 06:00 - 06:45 06:45 - 08:30 08:30 - 09:30 09:30 - 09:45 09:45 -11:00 11 :00 - 12:30 12:30 - 12:45 12:45 - 13:30 13:30 -15:00 15:00 - 16:00 16:00 - 17:45 17:45 - 18:45 18:45 - 19:00 0.75 DRILL 1.75 DRILL 0.25 DRILL 1.00 DRILL 2.25 DRILL 0.75 DRILL 2.00 DRILL 0.25 DRILL 0.50 DRILL 0.25 DRILL 1.00 DRILL 0.83 DRILL 1.00 DRILL 1.83 DRILL 2.33 DRILL 0.50 DRILL 0.17 DRILL 0.67 DRILL 0.25 DRILL 0.92 DRILL 1.25 DRILL 0.25 DRILL 0.50 DRILL 0.25 DRILL 1.25 DRILL 0.75 DRILL 1.75 DRILL 1.00 DRILL 0.25 DRILL 1.25 DRILL 1.50 DRILL 0.25 DRILL 0.75 DRILL 1.50 DRILL 1.00 DRILL 1.75 DRILL 1.00 DRILL 0.25 DRILL P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P N Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 SFAL PROD1 Start: 9/12/2001 Rig Release: 12/5/2001 Rig Number: Spud Date: 11/25/2001 End: Description of Operations Having to stack 5K # to make it drill. Log shows clean sand. Short trip to tubing tail at 10640'. Window & hole smooth. Orient to 120L Drill to 12412', ROP very slow, not able to stall bit, stacking 6K# to drill. POOH to check BHA & bit. At surface. Bit 1/8 undergauge, otherwise ok. MWD bleed sub washed out. Replace bit, motor & bleed sub. RIH Log gr tie in from 10810'. No correction. RIH. Thru window at 20L. Very smooth, Orient to 120R Drilling. 1,7/2700/120R Took off drilling at 100-150 fph. So we don't know if it was the bit, motor, or bleed sub. Drill to 12495' Drilling slowed down again. Drill to 12515' and stacking Wiper to window Drilling from 12515' 1,8/3000/107R Got into a shale at 12500'. Required numerous PU's and 100' wipers to make any progress Drilling at 12560' w/-8k. GR is hot at 12540'. Samples show chert which indicates we're at btm of Shublik. Orient to 170R. Drill wI max neg wt and frequent PU's. Drill to 12604' wI 84 deg at bit and no sign of sand yet Orient around at 12604' to level out once we get thru Shublik Drill from 12604' to 12611' and P rate picked up. Had a stall and overpull Wiper to window while BHI works on depth recorder Log tie-in down from 10810' Add 2.0', RIH Drilling from 12611-637' 1.7/2850/124R. Started stacking again and going no where fast. GR is showing 40 API sand again from 12602' Wiper to 11480' Drill to 12650' wI -5k Orient to left side Drill to 12672' and penetration rate picked up Drilling 1.6/2900/1 OOL 50'/hr Drill to 12690'. Having trouble with wt transfer. Order new mud system. Short trip to tbg tail at 10660'. Drilling. 1.7/2850/80L. Drill to 12710' Orient to 45L Drilling. Having to stack a lot of weight. Back in shale (#*&!#) Start new mud down hole. Short trip to window while waiting to get new mud around. Orient to 75L Drilling. 1.7/2900/75L 75-125 fph. Drill to 12807'. Short trip to window. Drill to 12833'. Wiper trip to tbg tail. Hole smooth. Attempt to drill and not making headway-acts like possible BHA prob. Geo's want to get to 12950' Begin wiper and MP #2 traction motor fan quit. Swap pumps Printed: 12/10/2001 11:17:38AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/1/2001 12/2/2001 12/3/2001 ( ( BP EXPLORATION Operations Summary Report 14-40 14-40A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 18:45 - 19:00 19:00 - 19:40 19:40 - 21:25 21 :25 - 22:15 22:15 - 00:00 00:00 - 00:15 00:15 - 00:30 00:30 - 02:00 02:00 - 02:30 02:30 - 02:50 02:50 - 03:50 03:50 - 04:35 04:35 - 05:40 05:40 - 06:45 06:45 - 07:15 07:15 - 08:00 08:00 - 08:15 08:15 - 08:30 08:30 - 09:30 09:30 - 12:00 12:00 -12:30 12:30 -13:00 13:00 - 15:30 15:30 - 16:30 16:30 - 17:45 17:45 - 19:30 19:30 - 20:30 20:30 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 05:30 05:30 - 05:45 05:45 - 06:30 06:30 - 07:15 07:15 - 08:15 08:15 - 09:00 09:00 - 10:00 10:00 - 11 :45 11:45-12:15 12:15 -12:45 12:45 -13:45 0.25 DRILL 0.67 DRILL 1.75 DRILL 0.83 DRILL 1.75 DRILL 0.25 DRILL 0.25 DRILL 1.50 DRILL 0.50 DRILL 0.33 DRILL 1.00 DRILL 0.75 DRILL 1.08 DRILL 1.08 DRILL 0.50 DRILL 0.75 DRILL 0.25 DRILL 0.25 DRILL 1.00 DRILL 2.50 DRILL 0.50 DRILL 0.50 EVAL 2.50 EVAL 1.00 EVAL 1.25 EVAL 1.75 EVAL 1.00 EVAL 3.50 EVAL 2.50 EVAL 1.00 EVAL 2.00 EVAL 0.25 EVAL 0.75 EVAL 0.75 EVAL 1.00 EVAL 0.75 EVAL 1.00 EVAL 1.75 EVAL 0.50 EVAL 0.50 EVAL 1.00 CASE N P P P Phase SFAL PROD1 PROD1 PROD1 PROD1 P P P P P P P p P P P P P P P P P P P P P P P P P P P P P P P P P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 COMP Page 6 of 8 Start: 9/12/2001 Rig Release: 12/5/2001 Rig Number: Spud Date: 11/25/2001 End: Description of Operations and took a while to get up and running Wiper to window POOH to check BHA Change bit, motor, bleed sub, MHA. Bit was 2.62" 00 and had stator rubber in one jet. Bleed sub jet sli eroded RIH wI BHA #8 (1.15 deg motor) RIH wI BHA #8 Log tie-in down from 10810' Add 1.0', RIH. Clean thru window. Precautionary ream 12400-TD. Had trouble getting by shale at 12750' Tag at 12831'. Orient around Drilling 1.7/27 40/63L 60-11 O'lhr Drill to 12860' and had 20k overpulls Wiper to 12700' and pulled heavy from 12790-12740'. Can't get back down. Orient to drilled TF, Redri1l12740-TO at 5'/min Orient around-twice and then some Drilling 1.7/2760/40L 80-200'/hr. Good wt transfer. Drill to 12909'. Sticky at times on PU's, 10-20k overpulls Wiper to window Log gr tie in from 10810'. Add 3' correction. Wiper back to btm. Hole smooth, a few bobbles through shale at 12740'. Orient to 10L. Drilling. 1.5/2700/10L. Very sticky on btm. Drill to 12950' (TD) Wiper trip OOH to prep for logging tool. POOH at 80%. LD drilling BHA. MU PDS memory grlresistivity logging tools. RIH. Stop at 10600 for time stamp. Begin down pass at 10600' at 30 fpm. Stop at 12944'. Rest tool for time stamp. Log up pass at 30 fpm to 10600'. Stopr for time stamp. POOH with logging tool. LD logging BHA. Check tool and have data Begin weekly BOPE test. Witness waived by AOGCC. Geo's work wI PDS to get a log. Fax log at 2330 hrs Fin weekly BOPE test. Receive orders to run Bonzai compl @ 0030 hrs. Load slotted liner in pipeshed and prep MU drilling BHA for cleanout run RIH wI BHA #9 (#8rr) Tie-in logging down at 10810' No corr, RIH Ream and back ream tight spot at 12750-60'. Cleaned up pretty well. RIH. Tag TD at 12950'. POOH at 30 fpm. RIH to TD. Start hi vis pill down hole. Lay in hi vis pill of new flo pro 1: 1. POOH to run liner. LD drilling BHA. Test new windwall rigging with crane inspector MU and test Baker slip type coil connector. Circulate 1-5/16" ball through coil (running larger id hydraulic disconnect wI Printed: 12/10/2001 11: 17:38 AM (' ( BP EXPLORATION Page 7 of 8 Operations Summary Report Legal Well Name: 14-40 Common Well Name: 14-40A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 911212001 End: Contractor Name: NORDIC CALISTA Rig Release: 12/5/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/3/2001 12:45 -13:45 1.00 CASE P CaMP CTLRT). 13:45 - 14:00 0.25 CASE P COMP Hold pre job safety mtg. 14:00 - 18:00 4.00 CASE P CaMP MU 2-3/8" slotted/solid "bonzai" liner assy. 18:00 - 18:15 0.25 CASE P COMP Hold safety mtg at crew change. 18:15 - 19:30 1.25 CASE P COMP Fin MU liner assy. Set BOP slips 19:30 - 22:00 2.50 CASE P COMP MU Baker 10' slick stick on 1" CSH. MU 64 CSH singles 22:00 - 23:30 1.50 CASE P COMP Space out and add a 6' CSH pup. PT to 500 psi. Install Baker CTLRT 23:30 - 00:00 0.50 CASE P COMP RIH wI CT 12/4/2001 00:00 - 00:45 0.75 CASE P CaMP Continue RIH wI liner 00:45 - 01 :15 0.50 CASE P COMP Wt chk at 11400' 28k, 15k 0.2/1400. See flag is -16' off depth-did not correct. RIH thru window, clean. RIH to TD at 12979' CTD, hole was clean. Reciprocate 29.6k twice. Note: Solid liner top at 9600', slotted liner top at 11651' 01:15 - 01:55 0.67 CASE P CaMP Load 5/8" steel ball and circ to seat at 31.5 bbls. Sheared at 2900 psi. PUH 21 k and released from liner 01 :55 - 03:40 1.75 CASE P CaMP Begin displacement to KCI water. 1.7/3850 MIRU DS cementers. Cmt to wt at 0310 hrs. Safety mtg re: cementing 03:40 - 04:15 0.58 CASE P COMP PT DS @ 4000 psi. DS load CT w/21,5 bbls 15.8 ppg G cement w/ latex at 1.3/3000. Load dart and check 04:15 - 04:55 0.67 CASE P COMP Displace with 2% KCI at 1.8/3850. With 10 bbls around shoe 1.1/3800. Prior to dart latch up 1.0/4000. Dart latched at 40.4 bbls and sheared at 2600 psi. Displace additional 1,5 bbls. Unsting from O-ring sub 20.8k. Float held. CIP 0450 04:55 - 06:30 1.58 CASE P COMP POOH wI Baker CTLRT 06:30 - 07:00 0.50 CASE P CaMP UD CTLRT. 07:00 - 08:30 1.50 CASE P COMP Stand back 32 stands of 1" CSHydril & UD Baker slick stick. 08:30 - 08:40 0.17 CASE P CaMP Held PJSM on P/U cleanout assy. 08:40 - 11: 15 2.58 CASE P COMP P/U 1-7/8" D331 mill on 1-11/16" Weatherford motor & MHA. M/U 32 stands + 46 singles of 1" CSH. 11:15 -13:00 1.75 CASE P COMP Stab in injector. RIH wlmill & motor. 13:00 -13:30 0.50 CASE P COMP Tag O-Ring Sub @ 11586' correct depth to 11607.6' +21' 13:30 - 13:45 0.25 CASE P COMP Milled through O-Ring Sub RIH Tag Float Collar 13:45 - 14:30 0.75 CASE P COMP Tag Float Collar @ 11618.7' Mill out Float Collar STOP Milling Float Equip POOH to Liner top & wac Milling Slow milling maybe drilled .2' of float collar. 14:30 -15:00 0.50 CASE P COMP At liner top WOC 15:00 - 16:30 1.50 CASE P COMP Cement at 800 psi compressive strength at 16:30. Continue to WOC. Will continue operations when cement at 2000 psi. 16:30 - 23:45 7.25 CASE P COMP Continue to WOC. 23:45 - 00:00 0.25 CASE P COMP Cement at 1970 psi. SI @ choke and PT liner lap 12/5/2001 00:00 - 00:15 0.25 CASE P COMP Pressure 4-1/2" tbg to 250 psi with 14 bbls. IA rose from 950 to 1100 psi. Monitor for 5 min wI sli loss. Bleed off press and got back 8 bbls 00:15 - 00:55 0.67 CASE P COMP RIH from TOL 00:55 - 05:30 4.58 CASE P COMP Mill float collar from 11618.7' 0.9/2120 28.8k, 13.2k Mill divert sub baffel. Stack 5k WeB at 11620' and go no where fast for a while. Pump a sweep. Got first stall at 11620.2' 05:30 - 06:30 1.00 CASE P CaMP Start losing ground back to 11617.9' and getting more stalls-must be doing some good and getting close to being thru it. Re-mill from here 06:30 - 07:00 0.50 CASE P CaMP Bring rate up to 1.0 bpm, free spin 3600 psi. Resume milling Printed: 12/10/2001 11: 17:38 AM BP EXPLORATION Page 8 of 8 Operations Summary Report Legal Well Name: 14-40 Common Well Name: 14-40A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 9/12/2001 End: Contractor Name: NORDIC CALISTA Rig Release: 12/5/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/5/2001 06:30 - 07:00 0.50 CASE P COMP on divert plate @ 11620' CTM. 07:00 - 08:00 1.00 CASE P COMP Thru divert sub at 07:00, pump 10 bbls bio sweep. Backream thru jewalry 3 times to ensure free of burrs prior to continuing in hole. 08:00 - 09:15 1.25 CASE P COMP Finished with sweep. RIH at 30 fpm to clean slotted liner. Tag up at 11658', mill at 1500 Ibs wob, 300 psi motor work, 30 to 80 fph. Possibly cement? Waiting for bottoms up while continuing to mill. 09:15 -10:00 0.75 CASE P COMP 11755', Have milled 100' of cement. Pump 10 bbls bio sweep. Continue milling. Making 80 fph. 10:00-10:10 0.17 CASE P COMP 11790', Broke thru cement, RIH at 30 fph. Getting cement back in returns. 10:10 -10:25 0.25 CASE P COMP Sweep to bit, back ream up through cement washing with bio. 10:25 - 11: 15 0.83 CASE P COMP Continue RIH at 30 fph. Not seeing any work. 11:15 -12:30 1.25 CASE P CaMP Tag up at 12955' CTM (Should be 12948' ELM). Pump 30 bbls biozan sweep. 12:30 - 14:45 2.25 CASE P CaMP 30 bbl bio sweep out bit. POOH chasing sweep at 30 fpm. 14:45 - 15:15 0.50 CASE P COMP Tag up at surface, stand back injector. 15:15-16:00 0.75 CASE P COMP Safety meeting prior to laying down CS hydrill. 16:00 -18:30 2.50 CASE P COMP Lay down CS hydrill. 18:30 -18:50 0.33 CASE P COMP Shut down for changeout (all crews got caught behind Doyon 16 moving from Y to DS 13 at Pump 1). Safety mtg re: LD CSH 18:50 -19:10 0.33 CASE P COMP Resume LD CSH workstring 19:10 - 20:30 1.33 CASE P COMP MU nozzle/MHA. RIH to 2000'. Freeze protect wellbore wI 23 bbls MeOH 20:30 - 21 :45 1.25 RIGD P CaMP SI swab. Blow CT back wI air. Vac tanks and pits 21 :45 - 23:30 1.75 RIGD P COMP ND BOPE. NU tree cap and test. Load out misc equipment RREL @ 2330 hrs 12/5/01 ( (' Printed: 12/10/2001 11:17:38AM Well: Field: API: Permit: ( (' 11/25/01 11/29/01 12/05/01 Nordic 1 -------,-- -----... . --. ----. ----.---- - -- -.--..,..- -,--" ,-,--..".."" ----- --_..-_.-..--' "-.. - ----- --..--.-- - --- --'--""-- ----. -'--'-' ------. - - -" 14-40A Prudhoe Bay Field 1 Prudhoe Bay Pool 50-029-21875-01 201-135 Rig Accept: Rig Spud: Rig Release: Drilling.£!!g: 12/10/01 - 12/11/01 Ran 1.9" swage and S. Bailer to 9665' SLM - RET sample of Metal shavings and possibly sand/mud. Set Whiddon Catcher sub at 9547' SLM. Pulled DGLVS from GLMS #1 and #2 at 4735' SLM and 3198' SLM. Cement problems pulling DGLVS. Set 1-1/2" RK LGLV (1/4" PORT /1500 TRO) in GLM #1 at 3198' SLM. Set 1-1/2" RK OGLV in GLM # 2 at 4735' SLM. Ran 4-1/2" GS to OBST in tubing at 5050' SLM. Ran 4-1/2" Wire brush with 3.6 gauge ring to Catcher Sub at 9544' SLM. Pulled Catcher Sub latches on the Dummy valves pulled were packed with cement. POST - RIG WORK .",.~ VbP ~,. , BP Amoco Baker Hughes INTEQ Survey Report t IB~. 8AKD HUGIll. ---- --,-------- INTEQ Company: Field: Site: WeD: WeDpatlt: Field: BP Amoco Prudhoe Bay PB DS 14 14-40 14-40A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 11212002 TIme: 14:15:56 Page: I Co-ordlaate(NE) Refereace: Well: 14-40, True North Vertical (TVD) Refereace: 63: 4010/27/1988 00:0074.0 Section (VS) Refereace: Well (0.OON,O.OOE,200.00Azi) Survey Catcalatloa Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 PB DS 14 TR-10-14 UNITED STATES: North Slope Site Position: Northing: From: Map Eastlng: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5939577.43 ft 674150.48 ft Latitude: 70 14 26.346 N Longitude: 148 35 36.726 W Nortb Reference: True Grid Convergence: 1.32 deg Well: 14-40 14-40 Well Position: +N/-S -1918.39 ft Nortblng: +EI-W 739.66 ft Eastlng : Position Uncertainty: 0.00 ft 5937676.77 ft 674934.20 ft Latitude: Longitude: 40 70 14 7.478 N 148 35 15.230 W Slot Name: Wellpatb: 14-40A 500292187501 Current Datum: 63: 40 10/27/198800:00 Magnetic Data: 11/14/2001 Field Strength: 57500 nT Vertical Section: Depth From (TVD) ft 0.00 Survey: MWD Start Date: 14-40 11450.00 ft Mean Sea Level 26.53 deg 80.77 deg DIrection deg 200.00 12/2/2001 Helgbt 74,00 ft Drilled From: Tle-on Depth: Above System Datum: Declination: Mag DIp Angle: +EI-W ft 0.00 +N/-S ft 0.00 Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Engineer: Tied-to: From: Definitive Path Annotation MD. ft 11450.00 12950.00 TVD ft 9038.35 9029.50 KOP TD Survey MD Ine) Azlm TVD SSTVD N/S E/W MapN MapE DLS VS ft deg deg ft ft ft ft ft ft. deg/100ft ft 11450.00 79.58 197.73 9038.35 8964.35 -5227.02 -1099.56 5932425.99 673956.26 0.00 5287.87 11490.90 90.79 187,19 9041.79 8967.79 -5266.71 -1108.29 5932386.11 673948.45 37.53 5328.14 11527.08 91.41 193. 17 9041.09 8967.09 -5302.29 -1114.68 5932350.39 673942.89 16.61 5363.77 11570.67 94.92 195.28 9038.68 8964.68 -5344.47 -1125.38 5932307.98 673933.18 9.39 5407.06 11602.21 94.92 199.15 9035.98 8961.98 -5374.48 -1134.67 5932277.76 673924.58 12.22 5438.44 11639.91 96.24 201.26 9032.31 8958.31 -5409.69 -1147.63 5932242.26 673912.44 6.58 5475.96 11670.14 96.68 200.55 9028.91 8954.91 -5437.75 -1158.35 5932213.96 673902.38 2.75 5506.00 11723.52 96.42 206.18 9022.82 8948.82 -5486.42 -1179.37 5932164.83 673882.49 10.49 5558.91 11768.10 92.11 212,15 9019.50 8945.50 -5525.21 -1201.03 5932125.55 673861.74 16.48 5602.77 11801.70 93.43 215.32 9017.88 8943.88 -5553.11 -1219.66 5932097.22 673843.76 10.21 5635.37 11832.12 94.04 216.73 9015.89 8941.89 -5577.66 -1237.52 5932072.26 673826.49 5.04 5664.54 11864.25 91.58 220.24 9014.32 8940.32 -5602.78 -1257.48 5932046.70 673807.11 13.33 5694.97 11897.24 94.66 212.15 9012.52 8938.52 -5629.33 -1276.92 5932019.70 673788.29 26.20 5726.57 11928.19 93.78 206.53 9010.24 8936.24 -5656.23 -1292.04 5931992.46 673773.80 18.33 5757,02 11960.77 88,59 204,70 9009.57 8935.57 -5685.59 -1306.11 5931962.78 673760.41 16.89 5789.42 12003.52 84.29 200.55 9012.22 8938.22 -5724.95 -1322.52 5931923.05 673744.92 13.96 5832.03 12043.80 85.52 203.01 9015,80 8941.80 -5762.21 -1337.41 5931885.46 673730,91 6.81 5872.12 12079.42 90.18 203.72 9017,14 8943.14 -5794.87 -1351.52 5931852.48 673717.56 13.23 5907,65 ~~""'-. : '" ("',<[J 1- "", "I'" ......... { ~ BP Amoco Baker Hughes INTEQ Survey Report .i. IIAKD HUGMlS INTEQ Compa.y: BP Amoco Field: Prudhoe Bay Site: PB OS 14 WeD: 14-40 WeUpath: 14-40A Survey Date: 11212002 TIme: 14:15:56 Page: 2 Co-ordlaate(NE) Refereace: Well: 14-40, True North VertIcal (1VD) Refereace: 63 : 40 10/27/1988 00:00 74.0 SecUoa (VS) Refereace: Well (0.00N,O.00E,200.00Azi) Sarvey Calc:alatloa Metllod: Minimum Curvature Db: Oracle MD lad AzIm TVD SS TVD N/S E/W MapN MapE DLS VS ft deg deg ft ft ft ft ft ft deg/10OO ft 12116.36 90.88 198.44 9016.79 8942.79 -5829.33 -1364.80 5931817.73 673705.08 14.42 5944.57 12143.41 91.23 193.17 9016.30 8942.30 -5855.34 -1372.17 5931791.55 673698.32 19.52 5971.53 12201.78 94.66 185.79 9013.29 8939.29 -5912.79 -1381.77 5931733.90 673690.06 13.93 6028.80 12265.61 94.83 174.19 9008.00 8934.00 -5976.29 -1381.75 5931670.42 673691.54 18.11 6088.46 12327.09 92.64 180.51 9003.99 8929.99 -6037.54 -1378.92 5931609.26 673695.79 10.86 6145.05 12362.04 91.58 186.14 9002.70 8928.70 -6072.39 -1380.95 5931574.37 673694,58 16.38 6178.49 12422.71 89.56 200.55 9002.09 8928.09 -6131.26 -1394.92 5931515.20 673681.98 23.98 6238.59 12474.19 90.70 205.83 9001.98 8927.98 -6178.56 -1415.18 5931467.44 673662.82 10.49 6289.97 12514.37 89.38 211.45 9001.95 8927.95 -6213.81 -1434.43 5931431.76 673644.39 14.37 6329.68 12548.00 90.62 214.97 9001.95 8927.95 -6241.95 -1452.85 5931403.21 673626.64 11.10 6362.41 12574.26 88.77 218.13 9002.09 8928.09 -6263.04 -1468.48 5931381.76 673611.49 13.94 6387.58 12630.69 86.66 227.98 9004.34 8930.34 -6304.19 -1506.92 5931339.73 673574.02 17.84 6439.40 12688.16 83.32 213.21 9009.39 8935.39 -6347.52 -1544.08 5931295.55 673537.88 26.25 6492.82 12727.84 85.43 211.45 9013.28 8939.28 -6380.88 -1565.20 5931261.71 673517.55 6.91 6531.40 12769.11 86.84 208.64 9016.06 8942.06 -6416.52 -1585.81 5931225.60 673497.77 7.60 6571.94 12822.00 84.73 201.96 9019.95 8945.95 -6464.18 -1608.34 5931177.44 673476.35 13.21 6624.43 12846.60 85.61 200.20 9022.02 8948.02 -6487.05 -1617.16 5931154.37 673468.07 7.98 6648.93 12909.37 85.96 206.53 9026.64 8952.64 -6544.49 -1641.97 5931096.38 673444.59 10.07 6711.39 12950.00 85.96 206.53 9029.50 8955.50 -6580.75 -1660.07 5931059.71 673427.34 0.00 6751.66 WELLPATH DETAILS 74.00ft Starting From TVD 200,00" 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: 14-40, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Slot - 40 (O,OON,O,OOE) Measured Deplh Reference: 63,4010/27/198800:00 74,00 Calculation Method: Minimum Curvatur. ANNOTATIONS '"' .", ."~ ".." NO MD Ao""'at,oo :::g:;:,~"" '"~~~ ~m! :IU¡: ~::;"" 896435 1145000 KOP 695550 1295000 m 'F' ""-5800 JV . j .-6100 ' 0.' I i -6300 -6400 -6600 5950 6000 6050 6100 6150 6200 6250 Vertical Section at 200.00. LEGEND T Wellpalh (14-40/14-40A) Created By Brij Potoi, Data 1/2/2002 I <7, '00 I I <OM <"r "00 <Mn -900 -800 -700 -600 -500 -400 -300 -200 -100 CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL / EXPLORATION INJECTION WELL INJECTION WELL RED RILL ,I' fRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANS:MITT AL LETTER WELL NAME ~ i-\ - 40 ~ I CHECK WHA T APPLIES ADD-ONS (OPTIONS) MUL TI LA TERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ~ ANNULAR DISpfSAL ( , ð"NO ~ ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005({), 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 (name on permit). Annular disposal has not 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 <-> 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. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. ( ( ~i~iŒ (ID~ ~~~~[\~ AlAS KA 0 IL AND GAS COlVSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. pt AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John Cubbon CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit 14-40A BP Exploration (Alaska) Inc. Permit No: 201-135 Sur Loc: 2653' SNL, 1573' WEL, SEC. 09, TI0N, RI4E, UM Btmhole Loc. 3982' SNL, 3205' WEL, SEC. 16, TI0N, RI4E, UM Dear Mr. Cubbon: 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 14-40A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. 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. aniel T. Se ount, Jr. Commissioner . BY ORDER OF THE CO.MMISSION DATED this /t) A day of August, 2001 / jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( STATE OF ALASKA ..,- ALASKA ùlL AND GAS CONSERVATION COM~..-.)SION PERMIT TO DRILL 20 AAC 25.005 J1\;t t-( ~ ( I òf 6 f 4--911 1 a. Type of work 0 Drill II 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 2653' SNL, 1573' WEL, SEC. 09, T10N, R14E, UM At top of productive interval 1902' SNL, 24511 WEL, SEC. 16, T10N, R14E, UM At total depth 3982' SNL, 3205' WEL, SEC. 16, T10N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 047475, 20741 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 11450' MD Maximum Hole Angle 18. Casing Program Specifications ( ize Hole Casino Itv':iiull~ Grade CnlJnlinn Lennth 3" 2-3/811 4.6# L-80 ST-L 2350' 1 b. Type of well 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11835 feet 9086 feet 11786 feet 9081 feet Length Size 103' 4042' 20" 13-3/8" 10801' 1284' 9-5/811 7" 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 74' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028314 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 14-40A 9. Approximate spud date 08/15/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12950' MD / 8957' TVDss 17. Anticipated pressure {see 20 MC 25.035 (e) (2)} 0 95 Maximum surface 2235 psig, At total depth (TVD) 8800' I 3300 psig Setting Depth Tt n - MD TVD MD 1 0600' 8779' 12950' 11. Type Bond (See 20 AAC 25,025) Number 2S100302630-277 of :ømt: nt TVD linclude staae data) 8957.1 69 sx Class 'G' C~{"\)I-W\¡""'~ J 1'---- Plugs (measured) JUL 0 3 2001 Junk (measured) Alaska Oil & Gas Cons. Commission Anchorage MD TVD Cemented 2150# Poleset 2500 sx CS III. 600 sx 'G', 200 sx CS II, Top Job 103' 4116' 103' 4020' 600 sx Class IG1 350 sx Class 'G', 240 sx Class 'G' Liner Lap Sqz 10875' 10564' - 11834' 8916' 8845' - 9086' true vertical 10690' - 10800' 11235' - 11580', 11275' - 11300', 11400' - 114501 8877' - 8901', 89911 - 9059', 90011 - 90071, 9029' - 90381 181 Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements ~ Contact Engineer Name/Number: Jghn Ç"ubþa,n, j£{4}4158 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the f /.1 : is vand correct to the best of my kn~~ledge . / Signed John Cubbon I 'f:. /w r-vv1 Title CT Drilling Engineer Date 112 2£b / ',"",:' ",' ':. "', ':::':,',,;/"'::'çJ:::,:':',;::":':>".,'::,::;',::~:,:--::::,:;",:,,:i:,:C9ri1r(i'I.~Jqn:¡Vš~,Ôn~y::::"::':.:'::;::::'i:'",:;:I::?,',:i'<¡:>:"':',:':".;'::~:,X,,:I;<:';':' ¡",,:;,':: ,,: Permit Number (J API Number Appro)lal Date., See cover letter .20/ - / .5 -~ 50- 029-21875-01 ~ 1107 0 r for other reauirements Conditions of Approval: Samples Required 0 Yes 5 No Mud Log Required 0 Yes 181 No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K ~.5K psi for CTU OtherORIGINAL SIGNED BY by order of D Taylor Seamount Commissioner the commission Perforation depth: measured 20. Attachments Approved By Form 10-401 Rev. 12-01-85 ORIGINAL Date ~ I I\)I D ) Sui mit'ln Triplicate f ( BPX 14-40A Sidetrack Summary of Operations: A CTD sidetrack of well 14.40A will be drilled. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Isolate & integrity test inner annulus, (IA). Drift tubing and tag PBTD in liner, abandon current perforations and set cement plug for kickoff. Mill window if service coil is available. Planned for August 6, 2001 . Drift well and tag as deep as possible with slickline. . Liquid pack and integrity test the IA. . P&A the existing perforations at 10,690'-11,580' MD with cement. . Spot a cement plug from PBTD to approximately 100 feet above the kickoff point, which will be at approximately 11,450' MD (8,964' TVDss). . Mill window with service coil if available. Phase 2: Drill and Complete CTD sidetrack: Planned for August 15, 2001 2" coil will be used to drill a -1,500 foot, 3" open hole sidetrack, (as per attached plan) and run a solid, cemented & perforated 2-3/8" liner completion. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.6 - 8.7 ppg) Disposal: . No annular injection on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 2-3/8", l-80, solid liner will be run from 10,600'md (Tal, 8,779' TVDss) to TO at approximately 12,950'md. Liner will be cemented to approximately 200' above the window with approximately 14 bbls (annular volume plus 25% excess in OH) of 15.8ppg class G cement. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. . The annular preventer will be tested to 400 psi and 2,200 psi. Directional . See attached directional plan. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray log will be run over the open hole section. . A memory CNl will be run inside the liner. Hazards . An H2S concentration of 59 ppm was measured at well 14-40 on March 5, 2001. . The well path will not cross any mapped faults. However, the well path is in the proximity of mapped faults, which creates the risk of lost circulation along the proposed well path. ( ( Reservoir Pressure Reservoir pressure is estimated to be 3,300 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,235 psi. 2020' -i 4-1/2" AVA SSSV NIPPLE, 10 = 3.81" I -- GAS LIFT Mt\NOR8...S STA rvD TVD DEV 1YÆMt\N LATCH VLV 1 3223 3200 19 M'v1G RK 1-1/2" 2 4760 4603 25 M\1G RK 1-1/2" 3 6024 5703 32 MVG RK 1-1/2" 4 7402 6899 28 MWG RK 1-1/2" 5 7976 7387 34 MWG RK 1-1/2" 5 7976 7387 40 MMG RK 1-1/2" 6 8550 7825 45 MMG RK 1-1/2" 7 8660 7900 47 MMG RK 1-1/2" 8 9576 8484 54 MMG RK 1-1/2" 9 9688 8547 56 MMG RK 1-1/2" TREE = HAC G EN IV WELLHEAD= FMC .-..., ......--..,...,-.,..-,....-..,.., ---..."...,.....-.,.,..-...---.... A CTUA TOR= AXELSON --~--,-_.__.__....__...._.... --_..,-,_._~-- KB. ELEV = 75' "---""-~------'-------_"--'_.,--_......_-. BF. ELEV = '-----"_._-----~-'-'- KOP = 2330' --"'--". """"-"".---"'---"--.---'."--"-.--"""---- Max Angle = 85 @ 11724' " .. Datum tvÐ = 10672' ,--,-------------~-----~ Datum TVD= 8800' SS 14-40A PROPOSED CTD SIDETRACK I 13-3/8" CSG, 72#, L-80, ID = 12.347" I 4116' Minimum 10 = 3.250" @ 9673' 4-1/2" TBG PATCH I I TOP OF 7" LNR I 10550' I 4-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, ID = 3,958" I 10640' 9673' 9750' 10600' 1 0629' 10639' 10640' 10649' { ( SAFETY NOTES: WAIVERED WELL. T x LA. x OA COMMUNICATION TO AIL. FTS WELL MfT1A FAILED. AOGCC FTS REQUIRES A/L OÆRA TION 4-1/2" TBG PATCH, ID= 3.250" ACROSS GLM #9 (SET 03/06/92) -1 4-1/2" OTIS X NIPPLE, ID = 3.81" I 1-1 9-5/8" X 4-1/2" BAKER DB PKR, ID = 4.75" I -l Top of Proposed 2-3/8" Liner I -1 4-1/2" OTIS XN NIPPLE, ID = 3,72" I -1 4-1/2" BAKER SHEAROUT SUB I -1 4-1/2" TUBING TAIL I -i ELMO - LOGGED 4/21/94 I I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 10875' Squeezed Sag Perforations 10,690'-10,800' (Perf's to be P&A 'd prior to Sidetrack) ~ORA~ONSUMMARY REF LOG: rv1\IVD CNL on 11/19/1988 ANGLE AT TOP ÆRF: 76 @ 11240 Note: Refer to Production DB for historical perf data 15.8 ppg cement top at approx. 11,250' SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 10690-10800 0 01/05/89 4" 4 11235-11580 0 01/05/89 2-7/8" 4 11275-11300 0 02/17/01 2-7/8" 4 11400-11450 0 02/17/01 Perfs P&A'd w/ 17 ppg Cement 11450' - Cement Rarrp KOP (TOW) 13" ~Ole I I 2-3/8" L-80 LINER, Cemented & Perforated I 11830' -1 BROKEN LATCH I lAnD I 7" LNR, 29#, L-80, 0.0371 bpf , 10 = 6.184" I I TO I 11786' 11834' 11835' DATE REV BY COMMENTS DATE REVBY COMMENTS 11/23/88 ORIGINAL COMR..ETION 06/21/01 pcr 14-40A ST Proposal 01/07/89 LAST WORKOVER 1/10/2001 SIS-QAA CON\! ERTED TO CA N\! A S 02/27/01 SIS-MO FINAL 04/19/01 Rf\VTP CORRECTIONS 12950' PRUDHOE BAY UNIT WELL: 14-40A ST Proposal ÆRMIT No: API No: 50-029-21875-01 Sec. 9, T10N, R14E, 2804.68 FEL 2961.54 FNL BP Exploration (Alaska) l--',-: -4, :--, __l____-l_~-J----i-,==j-'n__'.1_--l_, ' --+- ---L_---l__---l---.l.-------1--- ---L--J.-I-- ,I -I I -, - I ! - - - I - -1- - - ,- 84 00 I" ----------I.- I I I I -j -! ! ! - - i I I I-! I I ~. I ' 1 I I ' , ' I 84 50-1. -+--L J- -1-, -l---L -L-l------L-L .... 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I' ,'!'. ¡ - - t~ ,~--i--+-+- : " -. . -. .. p' .... ' ,.,. .,.,. J: , , : , 1 ' : - I I , , ! , I , , , I I , I I I I I 1 I , , I I I , I I I 1 "'¡"::II't'!"I!'I'!I:II!'IIIIII'II'I'~' ..J: ; , : i : : I ¡ I I I ! ' I : ! : ' !, -" ' ,', ,.. " " "'" r.,..-. ',' -. "r-~-'--- .,'... ,_._-.,.-1,---'-' t-._~-'---- d_õT"'>L_~~r-LI~'-r+---____LTT1~-'-~.-!-_rr+-;--" r-r'-TTr1--n-r-'---;-lTT-J-~~, ' T1-~+TTTb.L.........LT,h,rTL ...L... , " ' :"'-,: ,-"',- i' - ,'- 1"";""1' .:t'" 1 ' 'I " 1""1 "'i""i" 'i""!" I -, ,~TTl'li1¡1 'TrnrllJII"III"" '1I I Fr'I"',' '1"11 I I 'I'" 5100 5150 5200 5250 5300 5350 5400 5450 5500 5550 5600 5650 5700 5750 5800 5850 5900 5950 6000 6050 6100 6150 6200 6250 6300 6350 6400 6450 6500 655066006650670067506800 6850 6900 6950 7000 Vertical Section at 200.000 [50ft/in] BP Amoco MLLI'ATH DETAIL. I'1."'11.-A 500212187501 ....-. w.JIpeth: TI. Oft MD: 1.- 11450.00 1I!r- II.'. Dawn.: V.- ...... 13 1.-0 10127111" 00.00 '4.0Oft ":11,~ D.otI ~~:; =::...~ 0.00 200.00' 0.00 REFERENCE INFORMATION ~rdinate (NÆ¡ Reference: Well Centre: 14-40, True North Vertical (TVD Reference: System: Mean Sea level Section (VS) Reference: Slot. 40 (O.OON,O.OOE) Measured Depth Reference: 63: 40 1012711988 00:00 74,00 Calculation Method: Minimum CUivatut9 IlCTtON on""," - MO 10. ..., TVO -..... -It." OLat Thc. va.. T...., , "-,,, TIM '"UO I".," ..."... .,_... 0.00 0.00 "7I.<M . "4S0.oo TI." ,,1.7, 1114.21 .52n... .""." '.n "..0' 1287,.. . "_.00 I"" ,.1.7. 1.....1 ..u.... ."0.," .0.00 0.00 ....... . ..181.20 - '87.72 "'0.71 ""'AO .""",. '0.00 0.00 .U',a. I ".,...20 ...... .....0 ....,.. .UII.O. .,....It '0.00 ...00 ....... I U.".'" ".00 '"'.'0 ""'"' ""'.72 .'atT." '0.00 "..00 oon... , 12871.'0 IU. 2tUa 1..'.tT ".".71 -'0"'" '0." ..... "".14 I '2171.'0 87.14 flU' ....... ""'.77 .'00"" '0.00 .0.... 0...... I "",.00 ..... ,OO... ......, ""'.N .'0'0'" ,.... 10." ....... ANHOTATIOHS TVD MD AR_. 1112.12 11_.00 TlI' '~I 11160.00 KO' IllS." 11160.00 1 1110.7111184.20 2 1112.00 118:14.20 ) '"u.t1 12212.10 . .U1.1' 12171.10 I Iln.21 12178.10 I 1.,..11 12""" TO TAROET DET"'S TV{) .",.s -El-W",,- ...... Hono ObP r&ií' BAKER HUGH! lNT EQ "J- .51~,_,-1-'" . ~-' .S2::ti~:k:4 .53 :13=-' :iC! .l -540 ~'-: ' i . I: I .550 ~ - C .56 ~ .57 0 ~'5 - + -.5 .c 1: 0.6 Z ~.61 ^^ - .c .. -6 :I 0 en.63 - 1- .1 I I , I 80u- 900-: 000- - j--- - - , ¡ ¡ 1 I 1 T,'=~- --'-- - -t-- - 0 ::t-~~I-:i-: ' -64 .6 .J .J 50o-! l:1 60~ . -6 LEGEND I T Azimuths to True North I PIIIn: PIan" (14-401P1anl1 14-40A) 14~(14~ l Magnetic North: 26,69° Created By: BrIj POInts Dille: 51141'2001 - Planl114 A - Plsn 11 MaRnetic Field Contact Information: Stre~ : 57480nT D~ ngle: 80.75° Direcl: (907) 267.6613 ate: 5/1412001 E.mail: br~:mtnISOlnteq.com Model: BGGM2oo0 Baker Hughes INTEO: (9 ) 267-6600 .1 - -,,- - 1 : - - , , ------, .- . ." ~.~'; :-:-:1 ~:_:-:L : - h;°~" I f :-:-:-:- --.. ,-. , - ... ... , .. . .o' ,-- u. .. , . - -. , ,- - .-. ,..-.,',' .-- I I ¡;- ~~~':-:-T ::~r:!~~- I , I ¡I' 1 I , II! , I 1 I f----~I- ~:-- .---+-. . . . i-' .. I 1 I . ,-.'-. I .-... ,.. - ¡ ..-"¡-... F I -- ,---- -I- I ~ --. . ':1' '1-11 :::- 14-40f14-40I'--.-..--"---- .,... .. .., , ' , ... . -. . .., " .. ---- .-, ' . - . , . - . . ,..... --O' --. - - í ---"- , , , . ". . , .. . --.-,--.----,-..-...,..,..--.,-.--.,-..- ,.. . , . . ' .., ." . ,. -.- , .- .. . - -- - _.- , - . --- ~ DlL:_=JL-:.::-.t:::.::J:.:-:::t:.:.-:::L..:.:-:, .0- ...,-.-...,-.-,.-,.-..,....,......,-.-.0-...."... .. -- - -- . -, .-- .- L L- 1 [n I I ,...,..-..... - - -- .- .....0 .-. -- ¡ I I I I 1 ¡ ~--J ----+-- 5 .. I ' -I - - i -- t- - -,I - - - - . - I-' I , I ! I ..-1-:_:1::::1::':'_,1:':'::1:'. I I d~ O' -, '. .-, . - . . , . . . . , . . . --, --. . - . ... . , .' -~--~t.~l.. .b,:-E :: -:-1::: ::::u::::: :.::::.t~~J:,:~::I:. 1 . II - - I - I ~ I :: I' .." -- .- ... ,'..-..,... .- ... .. . -. , . - .. --, . . . , , .- ~" - ,..., -- . - rn, t::,/1/1/'?rV'1 ~."a D~A ObP ( BP Amoco ( Baker Hughes INTEQ Planning Report 1'&.. BAKER HUGHES INTEQ :~y~\'ì3P ~}:" :,:>:~~, -" 'HeId.~-'~">~ÞiùdhÔåBa.y' ,'" ' , ~~13~~~lf<J,' ';;; ."~" , :';WeIlpå)h:~~;Pt~.1':14~A ' " " ' Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) S15 Datum: Mean Sea Level ~~~a'4~ "',' " ;;~i:;".:,-,;.,;.,,;,'Section'(V'S)Réterence:~,." ":, Wet! lO.OON O.OO,E,200.00Azi)~'~"",'i'.l.i' ,~;~", '~., , :.' ,'",~:">',~(,<"..t, ",,'-;":,',:.;'-- , "~",:"".,;::"""","':(:-"',~,"'"',;.......:,.,.¡.,,,k"~'".,,;,,:c,,,:,;:,,~, '::\;~:";'-~"""-.':~:':\: -", ,. :.; ,:.>'.,,~.. ',':","Ji;.urveyCalc:Îiþüonldethod~,::-,;';;MIr\irnumÇ.uryature,:: ,.'>:.~,Db:. :--,Qì'åCle-::!),: i;. , ""..', """."""""""""""""""'"","""",....,...""">'.,"" Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2000 Site: PB DS 14 TR-10-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5939577.43 ft 674150.48 ft Latitude: 70 14 26.346 N Longitude: 148 35 36.726 W North Reference: True Grid Convergence: 1.32 deg WeD: 14-40 14-40 WeD Position: +NI-S -1918.39 ft +FJ-W 739.66 ft Position Uncertainty: 0.00 ft Northing: Easting : 5937676.77 ft 674934.20 ft Slot Name: 40 Latitude: Longitude: 70 14 7.478 N 148 35 15.230 W Height 74.00 ft Wellpath: Plan#1 14-40A 500292187501 Current Datum: 63 : 40 10/27/1988 00:00 Magnetic Data: 5/14/2001 Field Strength: 57480 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +FJ-W ft 0.00 14-40 11450.00 ft Mean Sea Level 26.69 deg 80.75 deg Direction deg 200.00 Plan: Principal: Plan #1 Lamar's Plan #1 Yes Date Composed: Version: Tied-to: 5/14/2001 1 From: Definitive Path Targets Description ,C:.: :"':':,<' TVD +N/-S ,+FJ-W ft ft ft 8934.00 -5911.68 -1479.67 8970.00 -6752.65 -1667.08 , 'Name 14-40A T1.1 14-40A T1.2@TD Annotation >. ';'~~',~i:\¡?:<',,;:,i,~P\,'t' 11440.00 8962.52 11450.00 8964.35 11460.00 8965.98 11584.20 8970.76 11834.20 8952.00 12253.10 8934.91 12578.10 8941.17 12878.10 8953.25 12950.00 8956.91 , N~'\~: /':~ ~~." .,~'. ~~:"">~ '" ," , ' " " .",,', "",,',:,., ;"; " ,", "" 5931732.74 673592.16 70 13 9.335 N 148 35 58.198 W 5930887.70 673424.32 70 13 1.064 N 148 36 3.635 W TIP KOP 1 2 3 4 5 6 TD Plan Section Information " :',f:,:.{};-~"t~::' 11440.00 79.40 11450.00 79.58 11460.00 81.58 11584.20 94.00 11834.20 94.47 TVD".: ft " ',' 8962.52 8964.35 8965.98 8970.76 8952.00 ]+EI~W " ,';-:':,ft'" ' -1096.56 -1099.56 -1102.56 -1140.28 -1264.91 DLS" ,BUild :<\,~,<1'iín1, . .".:' TFO , deg/1 ÓOft,dåQì~oOft:~~jþÖij'>", ,: deg ',' 0.00 0.00 0.00 0.00 1.93 1.80 -0.70 339.07 20.00 20.00 0.00 0.00 10.00 10.00 0.00 0.00 10.00 0.19 10.03 88.00 ObP (' BP Amoco ( Baker Hughes INTEQ Planning Report W&íi8 BAKER HUGHES INTEQ ,;'\I;~~~'r~f!i'&~~~'1~t~~~~~~"l;~~'t~]gi.lIJ~lwj.~~ ':. ", z. . .w, eIlp"ath°;:PJah#1'14, "4OA'"~;¿:'":('~"",,,:"":?{<:;"~;,:i:."':'<";'-:,>;\',:"'~'l:"'::",,,;,:,,: "',',"'!Sùrv,""IiiV,:CaIëWà, ,""'tioïfMèd1" 00' ;~';',':MiriimuÌ11 Curvature ;.~,;~.~"';i":;D" boo Oracle ,""",'""",:,,,.""":"'."",,:';':":':',:"",;~O."":.';',' ..",¿,:\:::-,':",!"..-..",-.-, ";.., """""""""',",',;':"""""-"",,,,,,,"':::,:.""', "'" ,.' Plan Section Information 12253.10 90.00 181.10 8934.91 -5947.72 -1417.66 10.00 -1.07 -9.95 265.00 12578.10 87.85 213.54 8941.17 -6253.79 -1513.07 10.00 -0.66 9.98 94.00 12878.10 87.64 183.51 8953.25 -6534.77 -1607.23 10.00 -0.07 -10.01 269.00 12950.00 86.54 190.63 8956.91 -6605.98 -1616.06 10.00 -1.54 9.89 99.00 Survey ;,-:TFO.-,:,.:',."Toòl deg -- 11440.00 79.40 197.80 8962.52 -5217.66 -1096.56 5932435.42 673959.04 0.00 5278.04 0.00 TIP 11450.00 79.58 197.73 8964.35 -5227.02 -1099.56 5932425.99 673956.26 1.93 5287.86 339.07 KOP 11460.00 81.58 197.73 8965.98 -5236.42 -1102.56 5932416.52 673953.48 20.00 5297.72 0.00 1 11475.00 83.08 197.73 8967.98 -5250.58 -1107.09 5932402.26 673949.28 10.00 5312.58 0.00 BLIND 11500.00 85.58 197.73 8970.45 -5274.27 -1114.66 5932378.40 673942.26 10.00 5337.43 360.00 BLIND , 11525.00 88.08 197.73 8971.83 -5298.05 -1122.26 5932354.46 673935.21 10.00 5362.37 360.00 BLIND 11550.00 90.58 197.73 8972.13 -5321.86 -1129.88 5932330.48 673928.16 10.00 5387.35 0.00 BLIND 11575.00 93.08 197.73 8971.33 -5345.66 -1137.48 5932306.51 673921.10 10.00 5412.32 0.00 BLIND 11584.20 94.00 197.73 8970.76 -5354.40 -1140.28 5932297.71 673918.51 10.00 5421.49 360.00 2 11600.00 94.05 199.31 8969.65 -5369.34 -1145.29 5932282.65 673913.85 10.00 5437.24 88.00 BLIND 11625.00 94.13 201.82 8967.87 -5392.69 -1154.05 5932259.11 673905.64 10.00 5462.18 88.11 BLIND 11650.00 94.20 204.32 8966.05 -5415.63 -1163.82 5932235.95 673896.40 10.00 5487.07 88.29 BLIND 11675.00 94.27 206.83 8964.20 -5438.11 -1174.58 5932213.23 673886.16 10.00 5511.89 88.47 BLIND 11700.00 94.32 209.34 8962.33 -5460.11 -1186.31 5932190.97 673874.94 10.00 5536.57 88.66 BLIND 11725.00 94.37 211.84 8960.44 -5481.56 -1199.00 5932169.22 673862.76 10.00 5561.07 88.84 BLIND 11750.00 94.40 214.35 8958.53 -5502.45 -1212.61 5932148.03 673849.64 10.00 5585.34 89.03 BLIND 11775.00 94.43 216.86 8956.60 -5522.71 -1227.12 5932127.44 673835.61 10.00 5609.35 89.23 BLIND 11800.00 94.45 219.36 8954.66 -5542.32 -1242.50 59,32107.48 673820.68 10.00 5633.04 89.42 BLIND 11825.00 94.47 221.88 8952.72 -5561.24 -1258. 73 5932088.19 673804.90 10.01 5656.36 89.61 BLIND 11834.20 94.47 222.80 8952.00 -5568.02 -1264.91 5932081.27 673798.88 10.01 5664.85 89.81 3 11850.00 94.33 221.22 8950.79 -5579.72 -1275.45 5932069.32 673788.61 10.00 5679.46 265.00 BLIND 11875.00 94.10 218.73 8948.95 -5598.83 -1291.47 5932049.85 673773.04 10.00 5702.89 264.88 BLIND 11900.00 93.87 216.23 8947.21 -5618.62 -1306.64 5932029.72 673758.33 10.00 5726.67 264.70 BLIND 11925.00 93.63 213.74 8945.58 -5639.06 -1320.94 5932008.95 673744.51 10.00 5750.77 264.52 BLIND 11950.00 93.38 211.24 8944.05 -5660.10 -1334.35 5931987.60 673731.60 10.00 5775.13 264.36 BLIND 11975.00 93.12 208.75 8942.63 -5681.72 -1346.82 5931965.71 673719.63 10.00 5799.71 264.21 BLIND 12000.00 92.86 206.26 8941.33 -5703.86 -1358.36 5931943.31 673708.61 10.00 5824.46 264.07 BLIND 12025.00 92.59 203.78 8940.14 -5726.49 -1368.92 5931920.44 673698.58 10.00 5849.33 263.94 BLIND 12050.00 92.32 201.29 8939.07 -5749.56 -1378.49 5931897.16 673689.55 10.00 5874.28 263.82 BLIND 12075.00 92.05 198.80 8938.11 -5773.02 -1387.05 5931873.50 673681.54 10.00 5899.26 263.71 BLIND 12100.00 91.77 196.32 8937.28 -5796.84 -1394.58 5931849.51 673674.55 10.00 5924.23 263.62 BLIND 12125.00 91.48 193.83 8936.57 -5820.97 -1401.08 5931825.24 673668.62 10.00 5949.12 263.53 BLIND 12150.00 91.20 191.35 8935.99 -5845.36 -1406.53 5931800.73 673663.74 10.00 5973.90 263.46 BLIND 12175.00 90.91 188.86 8935.53 -5869.97 -1410.91 5931776.03 673659.93 10.00 5998.53 263,40 BLIND 12200.00 90.62 186.38 8935.19 -5894.74 -1414.23 5931751.19 673657.19 10.00 6022.94 263.36 BLIND 12225.00 90.33 183.89 8934.99 -5919.64 -1416.47 5931726.25 673655.53 10.01 6047.10 263.33 BLIND 12250.00 90.04 181.41 8934.91 -5944.61 -1417.62 5931701.26 673654.95 10.01 6070.96 263.31 BLIND 12253.10 90.00 181.10 8934.91 -5947.72 -1417.66 5931698.15 673654.99 10.01 6073.90 263.30 4 12275.00 89.85 183.28 8934.94 -5969.60 -1418.50 5931676.26 673654.66 10.00 6094.75 94.00 BLIND 12300.00 89.67 185.78 8935.04 -5994.52 -1420.47 5931651.30 673653.26 10.00 6118.84 94.00 BLIND 12325.00 89.50 188.27 8935.22 -6019.33 -1423.53 5931626.43 673650.78 10.00 6143.20 93.99 BLIND 1,2350.00 89.33 190.77 8935.48 -6043.98 -1427.66 5931601.69 673647.22 10.00 6167.78 93.97 BLIND 12375.00 89.16 193.26 8935.81 -6068.43 -1432.87 5931577.13 673642.58 10.00 6192.53 93.94 BLIND 12400.00 88.99 195.76 8936.22 -6092.63 -1439.13 5931552.79 673636.88 10.00 6217.41 93.91' BLIND 12425.00 88.82 198.25 8936.70 -6116.53 -1446.44 5931528.73 673630.13 10.00 6242.37 93.87 BLIND ObP (' BP Amoco ( Baker Hughes INTEQ Planning Report r&ii8 BAKER HUGHES INTEQ ;,:~~ý:\ap.Ârri9cO, '" .. " tl~t;~~:¡~tY \:"":; . ' :We1lpa~::~"PIan~11,4-40A " ')':', Survey :~:':~.~~~,l.:';, ,<:~~~' 12450.00 88.65 12475.00 88.49 12500.00 88.33 12525.00 88.17 12550.00 88.02 "'.', '. ,~,:, 'rk~e:,'5I1~1. <::, 1.uœ:15:08:39,", " , :' Page: ,3 , """, r._';;' ',,' ", "'W'et'114-40T Nrtf1' ",,',: :;.'.:', :, ~Ì"dÎi1atè(NE) Reference:, : ",: '., rue , 0..',' , " <,.':'\;~'~\:>;<",~~å1iCål(fVD)~~êreBa:: '. ,~.. }Sy~åm:Meanseà J-~vel"" , .' ','::;:);;:',:,;,. ;,;'~on(VSJRerêreô.tê(!:' 'Wêtl,(O~ooN.(j.ooE;200.Ö()AzQ " ,':\~'" , '.,,;~:':: '/sufveý"CalcuÌation~ethod::' Minimum Curvature " ' ,; 'Db: Oraclè' AziDi , .deg 200.75 203.24 205.74 208.23 210.73 ,'~«.'"":~~,~~",,,'ib~>~:~.">,::' , 8937.25 -6140.09 -1454.78 8937.87 -6163.26 -1464.14 8938.56 -6186.00 -1474.50 8939.33 -6208.27 -1485.83 8940.16 -6230.02 -1498.13 'Ma"E-, ,:'\DLS ,~ ':VS ". J,;."..::(j~~ÒOft:~, ft.' 673622.34 10.00 6267.36 673613.52 10.00 6292.34 673603.70 10.00 6317.25 673592.88 10.00 6342.05 673581.09 10.00 6366.69 TFO "Tool', " deg" 93.82 BLIND 93.77 BLIND 93.70 BLIND 93.64 BLIND 93.56 BLIND 'l.:faPN ' , :.,ft ' , " 5931504.98 5931481.60 5931458.63 5931436.11 5931414.08 12575.00 87.87 213.23 8941.05 -6251.21 -1511.36 5931392.59 673568.36 10.01 6391.13 93.51 BLIND 12578.10 87.85 213.54 8941.17 -6253.79 -1513.07 5931389.97 673566.71 10.01 6394.14 93.42 5 12600.00 87.81 211.35 8942.00 -6272.26 -1524.81 5931371.24 673555.40 10.00 6415.51 269.00 BLIND 12625.00 87.78 208.85 8942.96 -6293.87 -1537.34 5931349.34 673543.38 10.00 6440.10 269.08 BLIND 12650.00 87.74 206.35 8943.94 -6316.01 -1548.91 5931326.94 673532.32 10.00 6464.86 269.18 BLIND 12675.00 87.71 203.84 8944.93 -6338.63 -1559.50 5931304.09 673522.26 10.00 6489.74 269.28 BLIND 12700.00 87.69 201.34 8945.93 -6361.69 -1569.10 5931280.81 673513.20 10.00 6514.69 269.38 BLIND 12725.00 87.67 198.84 8946.95 -6385.15 -1577.68 5931257.16 673505.17 10.00 6539.67 269.48 BLIND 12750.00 87.65 196.34 8947.97 -6408.95 -1585.23 5931233.18 673498.18 10.00 6564.63 269.58 BLIND 12775.00 87.64 193.84 8949.00 -6433.07 -1591.73 5931208.93 673492.24 10.00 6589.51 269.68 BLIND 12800.00 87.63 191.33 8950.03 -6457.45 -1597.17 5931184.43 673487.36 10.00 6614.28 269.78 BLIND 12825.00 87.63 188.83 8951.06 -6482.04 -1601.54 5931159.75 673483.56 10.00 6638.88 269.89 BLIND 12850.00 87.63 186.33 8952.10 -6506.80 -1604.84 5931134.92 673480.84 10.00 6663.27 269.99 BLIND 12875.00 87.64 183.82 8953.13 -6531.68 -1607.04 5931110.00 673479.21 10.02 6687.41 270.13 BLIND 12878.10 87.64 183.51 8953.25 -6534.77 -1607.23 5931106.90 673479.10 10.02 6690.38 270.23 6 12900.00 87.30 185.68 8954.22 -6556.58 -1608.98 5931085.06 673477.85 10.00 6711.47 99.00 BLIND 12925.00 86.92 188.15 8955.48 -6581.36 -1611.99 5931060.21 673475.42 10.01 6735.79 98.85 BLIND 12950.00 86.54 190.63 8956.91 -6605.98 -1616.06 5931035.51 673471.92 10.01 6760.32 98.73 TD ~ ~ ( ~"CT 10,000 psi Pack-Off Lubricator Blind/Shear 71/16" Pipe/Slips Pipe/Slips 7 1/16" Pipel6li~ ( ... d-.." ... 3.1 1/ :;} l~ ... ~II SWAB OR MASTER VALVE , " .. - -~",~"""""""""<.~,~c">-"",-"-",-~,,~-~--,,~......~,",,,,+,,,,..,.~'., ""'-,,,,', ?~~'R,~ ( ,," , ", " '" """"""'-'--"""" ,', ",':":",""",', . '::,~:~~è:5~~~::.~:,:.:,..., ,'," :"" ';",.~,~'..,:; :",;..:><~.:*g~~("..:,:::~~',.:~:.-::..::::~~/:.",,: ',:"?:,<~':'-:<,)::'.~:-':~;:~~;~:,",' "".",'":','; ,';-::',:::: ,', '. ( , ':;~:-"::~;:\,::.,~;::,:,:"" '" " ",:,<"-::'-"" " ",:",:':.'~~'_~:':i~:~~~~:.':.;~~$.#:-'i.;~ "\'.' J{~,:~,~,~',~.\~,~".,,~:',',f,'~~.':',~,~~::;,',:':,»:',:"';,;:,',:.',:,':':"}':<, ,:,~~"".',' '," , " ":~""'~~c:'!;~~...' " , ',', ':'):'...\:.~~{;~~~;,~~~~, .' ",', ,,:: , ' .. ',.;'+ii~:t" " , , ".",'<, ,. ','" ,;?',":'-', , , . -- ,,-~.._--~;-~-,.....'--r "-.. '-", DATE 06/04/01 CHECK NO. 0191155 H 191155 DATE INVOICE I CREDIT MEMO GROSS VENDOR DISCOUNT DESCRIPTION NET 060101 CKO60101K PYMT OMMENTS: HANDL NG I NST : 100.00 100.00 PER IT TO DRILL EE S/H - TERRIE HUB LE X4628 \l{.l{oA- IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL .... " , : " '¡'::, ,', ",' " , ,', ", , FIRST NA'tIONAL' BÀNKOF ASHLÀND , AN AFFILIATE OF NATIONAL CITY BANK CLEVELANQ. OHIO ',","',',"',)',,',"',',',',:,',,:,,',',',',..,','.,,','.''"."",::"""""""""".",,c,'""",.,""','"'::.",,,,:,,,,"":':""',',','.:.,""",':...'.',",',',",':0<,:,',,'.:',',',',",,"',',""""':'5"","~,'"'," 'Nh,",'IL:J'" '1"'0'1 "1':',"'5', ,,' " ,,~~:n "'~"9'\.tj.>' '..' BP EXeLQ,RATlåN, (ALASKA) INC. P.O. BOX 196612 .. ANCHORAGErALASKA99519-6612 " , CONSOLIDATED,COMMERCIAL ACCOUNT.. ,.. , " ',' ," " " -;JAY , ,'" :-.:' ' "~I,', ' fa The J~QER Of' , '"," , ",,"),,' ,'i ',:ALASKà oit' AJ'JO, ~,t\6 ,'>; ,',,': ""'" " >~,~!~~';~~~ïJ~~~ïf;'t:;~~,f" ANCHORAQI;, . .AIoS99,::$,Õ.1",. 00/ 1 oö4i'~***************~*.~~*~~*J.¡}********** u~i, D~~LAR . .,"'.' "...'.,. "". . ," ~ " ~ . ,.., bbATE'::AMOð~T ., Q~Yoíì/Ol" .'I\:~;¡t. if' ~'ìÖO7¡:~¡tl N.üY:VALlQÂfTER12ò. DAYS"', . ;, " .. . ..':,; :: \î:;;~ì",:~~~J~~: ."i"",'i.':., " .,..'. ::i '.'.,' .".'. '.'.". ".","'" III . Ii ~ . 5 5111 I:O~ .'2038liSI: 0 0 a ~... . g III . - ....' -:... ',. .... .. ... .." ./.:. .. " . . WELL PERMIT CHECKLIST COMPANY ð WELL NAME/9 - 9ðA PROGRAM: exp - dev -X- redrll FIELD & POOL b c¡ ô) ~ ~ INIT CLASS 0 r!VV .J -ó#? GEOL AREA ¡? '7 d ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . Y N" 8. If deviated, is well bore plat included.. . . . . . . . . . . .'. . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can"be issued without administrative approval.. . . . . Y N 13. Can permit be approved before 15-day wait.. . . . . . . . . . 'VI N ~ i: ~a;:;l~~~E~,= ~~~:~~ i ~~rt "~g: : : ": ": ~ ~? ~~ ~~ ~'\ ~~ ~~ '- \ 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . i N ~ 18. CMT will cover all known productive horizons. . . . . '. . . . . . N 19. Casing designs adequate for C, T, 8 & permafrost. . . . . . . Y N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N 21. If a re-drill, has a 10-403 for abandonment been approved. . . Y N 22. Adequate well bore separation proposed.. . . . . . . . . . . . ~ N 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . . . . 25. BOP.ES, do they meet regulation. . . . . . . ">~. . . ':"" . . . 26. BOPE press rating appropriate; test to ~ 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. . . . .. 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . A PR -Pßi'!'5-' - 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y ~ 34. Contact name/phone for weekly progress reports [exploratory 5')ilyj Y ANNULAR DISPOSAL35. With proper cementing records, this plan. /' (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate frèshwater; or cause drilling waste. " to surface;. . . . (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: ENGINEERING: UIC/Annular COMMISSION: ~þ~~ ~ W WM ~ .R~S T JMFt ~R ~JAJ;/ ENGINEERING .~~E GEOLOGY APPR DATE serv well bore seg _ann. disposal para req - / / r; ç ò ON/OFF SHORE oAJ UNIT# c 0 Z ( 0 -I :E :0 - -I m - z -I :t: - en :Þ :0 ( m :Þ ~" N N ~. NB.~~~~ ~c)~ ;;>-;7l~-C;- ~\ N . . y &> b^. ~ '> ~~ ~~t' ~ ~ ~:)' ~ ~~U ~'<>~ .-.!>C$",i: CO ~"* Y N Y N /I~ /J N" , N Y N. Y N -,," / Com mentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ~: ~ Well H ¡story File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. , To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically", . organize this category of information. ( it " do/-/3S IO7tDt **** REEL HEADER **** MWD 02/03/28 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/03/28 228965 01 1. 75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: Idwg.las -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11382.0000: STOP.FT 12950.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 09 TOWN.N ION RANG. 14E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 74.00 DMF KB EKB .F 74.00 EDF .F N/A EGL .F N/A CASE.F N/A OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 14-40A was drilled as a sidetrak of the original on Well 14-40. (5) The sidetrack began at 11450' MD (8964' SSTVD). (6) Well 14-40A was drilled to TD at 12950' MD (8955' SSTVD) on Run 8. (7) ROP was lost due to depth tracking problems from 11672' MD (8955' 1.20 : NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration, Inc. 14-40A Prudhoe Bay Unit 2805' FEL, 2962' FNL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 02-Dec-01 500292187501 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 SSTVD) to 11712' MD (8950' SSTVD). Gamma was relogged for this section. 01) . { ( (8 ) (9) The interval from 12929' MD (8954' SSTVD) to 12950' MD (8955' SSTVD) was not logged due to sensor to bit offset. The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BPX (SWS, 02-Dec- (10) A Magnetic Declination correction of 26.53 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN 1 2 3 4 5 6 7 8 DIRECTIONAL 24.78 ft. 24.78 ft. 24.01 ft. 23.66 ft. 24.87 ft. 23.34 ft. 23.04 ft. 23.35 ft. G AMMA 20.32 ft. 20.32 ft. 19.55 ft. 19.20 ft. 20.41 ft. 18.88 ft. 18.58 ft. 18.89 ft. CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 11513.4, 11515.4, 2.01953 11517.6, 11518.0, 0.404297 11579.1, 11578.3, -0.807617 11618.5, 11621.6, 3.03027 11629.8, 11629.0, -0.807617 11657.5, 11657.9, 0.404297 11718.9, 11719.7, 0.807617 11827.7, 11827.7, 0 11871.7, 11868.1, -3.63672 11887.1, 11886.1, -1.01074 11944.1, 11941.3, -2.82812 12041.6, 12039.5, -2.02051 12082.9, 12080.5, -2.42383 12290.8, 12286.3, -4.44434 12303.7, 12300.5, -3.23242 12456.8, 12458.0, 1.21289 12488.8, 12489.0, 0.202148 12538.4, 12536.8, -1.61523 12611.6, 12606.1, -5.45508 12625.1, 12621. 3, -3.83887 12672.2, 12670.0, -2.22266 12739.8, 12735.9, -3.83789 12772.8, 12772.8, 0 12837.4, 12838.0, 0.606445 EOZ END ! BASE CURVE: GROH, OFFSET CURVE:'GRAX Tape Subfile: 1 103 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN 14-40A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 02-Dec-01. I{ ( *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX12 ROP ROP ROPS12 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool GR MWD ROP MWD 0.0 0.0 84 1 1 2 Code Samples Units 68 1 API 68 1 F/HR Size 4 4 Length 4 4 ------- 8 Total Data Records: Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU 38 11382.000000 12950.000000 0.500000 47 records... 54 bytes 4124 bytes ---------------------------- WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN 14-40A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX ROPS ROPS ROPS * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool GRAX MWD ROPS MWD 0.0 0.0 84 1 1 2 Code Samples Units 68 1 API 68 1 F/HR .Size 4 4 Length 4 4 ------- 8 Total Data Records: Tape File Start Depth Tape File End Depth 38 . 11382.000000 12950.000000 (' ( Tape File Level Spacing = Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 02/03/28 228965 01 **** REEL TRAILER **** MWD 02/03/28 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 0.500000 47 records... 54 bytes 4124 bytes 2 records... 132 bytes 132 bytes Tape Subfile: 1 217 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration, Inc. 14-40A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 02-Dec-01. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX12 ROPS12 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 I.{ .~ { FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 68 68 API F/HR 1 1 4 4 4 4 GR ROP MWD MWD ------- 8 Total Data Records: 38 Tape File Start Depth 11382.000000 Tape File End Depth 12950.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 47 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration, Inc. 14-40A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX ROPS ---------------------------------------------------- GRAX ROPS GRAX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 ,{ ( One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: 1 2 68 68 Code Samples Units 1 1 API F/HR Name Tool GRAX RaPS MWD MWD Total Data Records: 38 Tape File Start Depth 11382.000000 Tape File End Depth 12950.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/03/28 228965 01 **** REEL TRAILER **** MWD 02/03/28 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH 11382.0000 11382.5000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 GR -999.2500 31.0830 45.7630 17.8600 20.2904 28.1173 32.5985 25.0924 24.1938 47 records... 2 records... 132 bytes 132 bytes Rap -999.2500 -999.2500 -999.2500 74.9390 156.9953 -999.2500 149.1887 149.5542 116.4366 (' 1 Size Length 4 4 4 4 ------- 8 II. .. 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 12950.0000 ( 37.5906 23.5909 44.5007 30.5126 77.7634 40.6494 37.9371 25.2255 29.9639 -999.2500 , 66.3617 124.5056 143.2865 63.6263 81.3283 47.6777 48.3951 88.9111 127.6548 92.2039 Tape File Start Depth 11382.000000 Tape File End Depth 12950.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH 11382.0000 11382.5000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 12950.0000 GRAX 29.9970 29.6360 41.1570 20.1610 21.8350 27.2000 31.9220 25.4160 26.8850 46.7940 25.2060 30.1870 30.8270 65.7140 87.5780 43.0460 26.0460 28.9170 -999.2500 Raps -999.2500 -999.2500 -999.2500 78.6310 158.6250 -999.2500 149.1370 161.4290 115.5270 59.1100 97.2970 96.2100 74.2120 81.5040 53.5850 40.4490 88.7340 155.9230 101.9330 Tape File Start Depth 11382.000000 Tape File End Depth 12950.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet Tape Subfile 4 is type: LIS
