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189-033
STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMISION • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations WE Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change?proved Pr r Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Sus Well 0 i4 Sr Ce ..)1,-- Plug POther:U derream Ce ent g IZI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 189-033 3. Address: P.O.Box 196612 Anchorage, Development D Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21930-00-00 7. Property Designation(Lease Number): ADL 0028278 8. Well Name and Number: PBU F-32 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: ED Total Depth: measured 10975 feet Plugs measured See Attachment feet ` , "� true vertical 9171 feet Junk measured feet AUG U(_U 0 3 2016 Effective Depth: measured 10540 feet Packer measured See Attachment feet U U true vertical 8949 feet Packer true vertical See Attachment feet j GCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20"Conductor 31 -110 31-110 Surface 2631 13-3/8"68#L-80 30-2661 30-2661 5020 2260 Intermediate 10001 9-5/8"47#L-80 28-10030 28-8661 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10050 10080 feet 10610-10650 feet True vertical depth: 8673-8691 feet feet 8985-9006 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED j'�� 2C,17., 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 486 21670 8 565 924 Subsequent to operation: 670 51183 820 1995 1386 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations IZI Exploratory 0 Development lI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil a Gas 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 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature F. Phone +1 907 564 4424 Date 8/3/16 Form 10-404 Revised 5/2015 `.�� VT�- RBDMS V"AUf - 4 2016 Submit Original Only ..iL/ X136 / rk • • Plugs Attachment PBU F-32 SW Name Date MD Description F-32 07/02/2016 10540 SAND PLUG F-32 07/02/2016 10550 5-1/2" SLB Posiset Plug F-32 10/16/1994 10700 Sand Plug • Packers and SSV's Attachment PBU F-32 SW Name Type MD TVD Depscription F-32 PACKER 3546.51 3546.35 7" Baker ZXP Top Packer F-32 TBG PACKER 9438.5 8272.58 4-1/2" Baker S-3 Perm Packer F-32 TBG PACKER 9647.31 8417.87 4-1/2" HCM Packer • • m Ix 000000 ca co co .— a000 N f� d N LC) LC) C N O O I- N- C) 4 N O� q `4 C) C) OONf� � [T CO O O N- CO CO r- In c- •14 - • co co cm N.. co N. cococo t N CO CO 0) CO CO I I I . I , H O N- CO - O co d' co O co ch N to N CO CI CO CO G) O co co S - N O CO O CO 0)) C.) 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Z2 .17-O N- N 2 o ° CO 06 M a < coo ; coo= io -Ja � 0 Z 4, [:.. 17) ° J N- - UIQ OX , P, 1- 20 O CO E O. o Oa 2w p) w� > _ J = Y 'i � W W co 2E rn < w g W Ian cvowam , -1 - ocnmZ O N -aa .0 0 W JZ - E N > QoW d' p N20JO CW ) J a) Co Q > U ih Q MazCli 0 V) ( %w ZIX WO m N c _0oZ F- W RI▪ Co d CLoo = a71OZ,, Q > ODO J _+- � NO c'- 0i Q-� , J QLo a) aZM � = ooa ; � � wwap � Q ° nQ � w � E o � ui ZM o �WZ_ aocooctOO � 1- mcDwow oFo- oo p2 pv � � F- �� QZZ � � a �OLO _I odd a) � Op @� pl= Hww2oz � a * o "' = tn -II— 0 W JCA o p_U) F. I > OWOO 0Do00UYYu_ 2 J .-�J O a) J J O — W ojf N e-- U) F- U WF- < - W II OJ < SOcnJmmJUW II JJm ;_, II m0 ? E CIO f— aa—M < WOH5M7 � WO < Owz M � WO > : 0 co J E2 : F- V) z * - W' (n O 1i : „ J J 2 F- IL : U) F- 0 ce U) O Co Co Co Co ar O r r O O 0 N N N N MN N Co N- N- • k 0 \ 0 R / / Etre « E E W \ O w ƒ O 2 0 I cn 0- % co 2 p 0 0. @ o ak E \ % . a 3 � \ m $ -J / g f U0 f _Q W : o $ 0 2c.) o 5 c _ 2 —ILo 0 ;55 ® 0 / \ ƒ 0_ d / / CL \ $ cD k / kk / � (N (NU) TREE= 41!16"FMC • t NOTES: ***4-1/2"CHROME TBG' WELLHEAD= McEVOY F-32 •ACTUATOR= BAKER OKB.ELEV= 65.3 BF.ELEV= 37.22' KOP= 4300 2015' 4112"FES X NP,D=3.813" Amax Angle= 60°@ 10700' I I Datum MD= 10385' Datum ND= 8800'SS 13-3/8"CSG,72#,L-80,ID=12.347" —I 2680' J 3542' - I9-5/8"X 7"BKR C-2 Z.XP LIP,D=6.34" I 3581' —19-5/8"X 7"BKR FLEXLOCK LNR HGR D=6.23" *+ 41 GAS LFT MARELS IP I) NDST MD TVD DEV TYPE VLV LATCH FORT DATE 1 � WI 2 3920 3920 1 KBG2 DOME BK 15 04/23/09 Minimum ID = 3.725" @ 9721' 1 r7057 '6508 ' 42 KBG2 SO BK ' 20 04/23/09 II 4-1/2" OTIS XN NIPPLE i I I *,,i 9403' -j4-1/2'HES X NP,D=3.813" car 9434' --I r X 4112"BKR S-3 FKR D=3.870" I1 A I I !J 9510' -�41/2"FES XNP,D=3.813" R1 Iibl 4-1/2"TBG,12.6#,13CR80,.0152 bpf,ID=3.958" H 9564' 4 ►r i 9564' —141/2"FLUTED WLEG,ID=4.00" 7"SCAB LAIR 26#,L-80,ID=6.276" —1 9572' ,IP! • ��'� I% I 9577 7"X 4 ®112"XO PORTPUP JT(4X1 HOLES) 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 9595' jam'` rk+� 9600' T� STUB(TAGGED 04/2009) 11 Wit, 9610' —19-5/8"X 4-1/2"UNIQUE OVERSHOT 1 di r -1 9632' —118G SEAL ASSY :l11,1e.. *� 1.11 �� 9649' H9-5/8"OTIS PKR,D=3.85" I I 9700' —4-1/2"OTIS X NP,D=3.813' I I 9721' —I4-1/2"OTIS XN MP,D=3.725' 4-1/2"TBG,12.6#,L-80,.0152 bpf,I)=3.958" — 9733' / ' 9733' H4 V2"OTIS TBG TAL D=3.958" TOP OF 5-1/2"LNR —1 9752' — 9730' --I ELM)TT LOGGED 04/25/89 9-5/8"X 7"LNDSEY LNR HGR,ID=" —1 9765' 7"X 5-1/2"XO,D=4.892" —1 9770' 9-5/8"CSG,47#,L-80 NSCC,ID=8.681" H 10031' • PERFORATION SUMMARY REF LOG:BHCS ON 04/04/89 I ANGLE AT TOP FEF:53 @ 10050' Note:Refer to Production DB for historical perf data 10223' —15-1/2"MARKER JO4N SCE SPF INTERVAL OpMSgz DATE 3-3/8" 6 10050- 10080 0 10/19/94 444441'1 —10640'ELM -DUMP BAL CMT(07/02/16)) 3-3/8" 4 10610-10650 C 07/05/90 10550'ELM H5-1/2"SLB P'OSISET FLOG(07/02/16) [10700'CTM 1-1-8ANDBACK (03/29/16)1 PBTD —j 10849' 1-- 5-1/T 5.1/2"LNR 17#,L-80, 0232 bpf,ID=4.892" — 10975' .1.A TD H ? e A A A•A•. DATE REV BY COMMENTS DATE REV BY C MM,NTS PRUDHOE BAY UNT 04/14189 N-18E ORIGINAL COMPLETION 04/01/16 JTM IJMD PLUGS/CMT/SAND UFDE REAP WELL: F-32 04/10/09 N4ES MVO 07/05/16 BTWJMD SET POSISEr PLUG/CMT(07/02/16) PERMIT No: 1890330 04/11/09 MSR/TLH DRLG DRAFT CORRECTIONS API No: 50-029-21930-00 04/23/09 MSR/TLH DRLG FINAL CORRECTIONS SEC 2,T11N,R13E,2243'FNL&2409'RM. 04/29/09 TLI-VPJC 5-1/2"LNR CORRECTION 05/31/09 SEINN/TLH GLV C/O(04/23/09) BP Exploration(Alaska) STATE OF ALASKA ALA OIL AND GAS CONSERVATION C011~SION REPORT OF SUNDRY WELL OPERATIONS -Z!GG~- .S• ~~ 1. Operations Performed: ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing - ®Pull Tubing , ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ ®Development ^ Exploratory 189-033- 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21930-00-00 7. KB Elevation (ft): 65 3' - 9• Well Name and Number: . PBU F-32 - 8. Property Designation: 10. Field /Pool(s): _ ADL 028278 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary RE~ E I V E Total depth: measured 10975' ~ feet true vertical 9171' ' feet Plugs (measured) None MAY 0 1 20Q9 Effective depth: measured 10187' feet Junk (measured) Yes, See Diagram n laska Oil & Gas Cons. Commission true vertical 8753' feet Anchorage Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2680' 13-3/8" 2680' 2680' 4930 2670 Intermediate 10031' 9-5/8" 10031' 8662' 6870 4760 Production Liner 1223' 5-1/2" 9752' - 10975' 8487' - 9171' 7740 6280 Scab Liner 6068' 7" 7240 5410 354 2' - 8393' 3542' - 961 0 ' ~~ ~~~ ia ~.~ `/ )) t~'~~ ~'i.by'{r~~D~' ~Y1 ~\t is -- d.114 w~ Perforation Depth MD (ft): 10050' - 10650' Perforation Depth TVD (ft): 8673' - 9006' 4-1/2", 12.6# 13Cr80 / L-80 9733' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packer; 9434'; 9-5/8" Otis packer 9649' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut, pull and dress tubing stub to --9579'. Run 7" scab li ner and cement w/ 176 Bbls Class 'G' (Yield 1.16). Run new Chrome tubing. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram - ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 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: Contact Mackie Derrick, 5645891 309-072 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number ~ ~~ Signature Phone 564-4628 Date Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 ~,~- Submit Original Only TREE= 4-1/16" FMC WELLHEAD = McEVOY ACTUATOR = BAKER KB. ELEV = 65.25' BF. ELEV - 37.22' KOP = 4300' Max Angle = 60 @ 10700' Datum MD = 10385' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" S~TES: ***4-1 /2" CHROME TBG*** ~ F-32 5' ~~4-1/2" HES X NIP, ID = 3.813" 3542' 9-5/8" X 7" BKR G2 ZXP LNR TOP PKR, ID = 6.34" 3561' 9-5/8" X 7" BKR FLEXLOCK LNR HNGR, ID = 6.23" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3920 7057 3920 6508 1 42 KBG2 KBG2 DCK DMY BEK BK 0 0 04/10/09 04/10/09 Minimum ID = 3.725" @ 9720' 4-1 /2" OTIS XN NIPPLE 9403' ~ 4-1/2" HES X NIP, ID = 3.813" 9434' 7" X 4-1/2" BKR S-3 PKR, ID = 3.870" 9510' 4-1/2" HES X NIP, ID = 3.813" 4-1/2" TBG, 12.6#, 13CR80, .0152 bpf, ID = 3.958" ~ 9564' 9564' 4-1/2" FLUTED WLEG, ID = 4.00" 7" SCAB LNR, 26#, L-80, ID = 6.276" 9572' 9572' 7" X 4-1/2" XO PORTED PUPJT (4X1 HOLES) 9600' TUBING STUB (TAGGED 04/2009) 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9595' 9595' 9-5/8" X 4-1 /2" UNIQUE OVERSHOT 9632' TBG SEAL ASSY 9648' 9-5/8" OTIS PKR, ID = 3.85" ID = 3 813' 9699' 4-1/2" OTIS X NIP , . 1/2" OTIS XN NIP ID = 3 725" 9720' 4 12 L 80 f ID = 3 4 1/2" TBG 6# 0152 b 958" 9733' , . - 1/2" OTIS TBG TAIL ID = 3 958" ' 4 - , . , . - , . , p TOP OF5-1/2"LNR 9751' ,;„,,3 - . 9732 9730' ELMD TT LOGGED 04/25/89 UNKNOWN FISH: FASDRILL REMNANTS, MILLED 04/08/09 9-5/8" CSG, 47#, L-80, ID = 8.681" FISH: 2 HES FASDRILL PLUGS (03/12/09) PERFORATION SUMMARY REF LOG: BHCS ON 04/04/89 ANGLE AT TOP PERF: 53 @ 10050' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10050 - 10080 O 10/19/94 3-3/8" 4 10610 - 10650 C 07/05/90 PBTD 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" TD 10187' -~SANDBACK WffH CEMENT CAP 1n2~ MARKERJOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 04/14/89 ORIGINAL COMPLETION 04/10/09 N4ES RWO 04/11/09 MSR/TLH DRLGDRAFTCORRECTIONS 04/23/09 MSR/TLH DRLG FINAL CORRECTIONS PRUDHOE BAY UNff WELL: F-32 PERMff No: 1890330 API No: 50-029-21930-00 SEC 2, T11 N, R13E, 2243' FNL & 2869' FEL BP Exploration (Alaska) F-32, Well History (Pre Rig Workover) Date Summary 03/04/09 T/I/O =SSV/5/150. T, I & O FL's pre-rig. Unable to open SSV. IA FL @ 360' (20 bbls). OA FL @ surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 03/05/09 T/I/0= 150/0/160 Temp= SI CMIT TxIA to 3000 psi FAILED (RWO Prep). Pumped 49 bbls 100° crude down TBG and @ 2940 psi TBG and IA pressure dropped to 0 psi. Called PE, Pumped an additional 25 bbls down TBG at 3.5 bpm @ 75 psi. Final WHP's Vac/0/160. Valve positions @ departure -Swab, Wing = SI /SSV, Master, IA & OA = SI. 03/12/09 WELL S/I ON ARRIVAL. TAGGED FASDRILL PLUG @ 10043' SLM, (10050' MD) WITH 3.70" CENTRALIZER, SAMPLE BAILER (no sample). TAGGED TT @ 9723' SLM, 9730' ELMD, (+ 7' CORRECTION). WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. 03/13/09 T/I/0=2180/2080/180. Temp=Sl. T and IA FL (pre CMIT. No A/L. No Flowline. TBG & IA FL @ 9123'. 03/13/09. WELL SHUT IN ON ARRIVAL. MASTER OPEN, SSV =OPEN, WING CLOSED. INITIAL T/I/O = 2200 / 2100 / 200 PSI. STAND BY FOR LRS TO KILL WELL. 03/14/09 T/I/0=2200/2250/200 Assist E-Line CMIT TxIA to 3000. (RWO prep) Loaded IA w/ 10 bbl meth spear, 370 bbls 1 %KCL. Freeze protected w/ 117 bbls Diesel. Loaded Tbg w/ 5 bbl meth spear 236 bbls 1 KCL. Freeze protected w/ 28 bbls diesel followed with 5 bbls meth. E-Line set fast drill Plug. Pumped into tbg w/ 65 bbls crude. Tbg fell from 820 to 380, IA climbed from 1030 to 1100 psi. E-Line to RIH w/ LDL. 03/14/09 INITIAL T/I/O = 2200/2100/200 PSI 370 BBLS 1 %KCL AND 170 DIESEL DOWN IA, 236 BBLS 1% KCL AND FREEZE PROTECT DIESEL DOWN TUBING. HALIBURTON FASDRILL PLUG SET AT 9670' PLUG PT TO 3000 PSI. RIG UP FOR LDL, RIH AND TAG PLUG TO VERIFY PLUG SET. 03/15/09 INITIAL T/I/O = 500/1000/0 LDL FOUND FLUID LEVEL FOUND AT 2000'. 03/16/09 WSR Assist E-Line w/ LDL. Pumped into IA w/ 276 bbls crude to reach 3000/2620/0 psi. CMIT-TxIA FAILED 3 attempts. Loss of 70/60 Psi 1st 15 min, 40/40 psi 2nd 15 min, 40/20 psi 3rd 15 min. Leak too small for big pump. Pressured back up to 3000/2580, held pressure while E-Line POOH w/ LDL. 03/16/09 INITIAL T/I/O = 500/1000/0 CONTINUE LEAK DETECT LOG. 03/17/09 CONTINUE LEAK DETECT LOG. PERFORMED WARMBACK PASSES AND FOUND ANOMALIES AT 4800'. 5200', 7600' AND 7840'. PACKER SHOWED INDICATIONS OF HAVING A SMALL LEAK. BLED PRESSURES DOWN TO T/I/O = 500/200/0 PSI. CUT 4.5" TUBING WITH 3.65" POWER CUTTER AT 9585', IN MIDDLE OF FIRST FULL JOINT ABOVE PACKER. IA/OA OPEN TO GAUGES, SWAB SHUT, MASTER OPEN. WELL SHUT IN ON DEPARTURE. FINALT/I/0=700/300/0 JOB COMPLETE. 03/17/09 T/I/O = 1450/650/0 Assist E-Line. Bled IAP down from 650 psi to 500 psi in 30 min. Final WHP's = 1330/500/0 03/21/09 T/I/0=740/420/0 CMIT-TxIA FAILED to 3000 psi, MIT-OA FAILED to 2000 psi. Established a LLR of 3 bpm @ 1800 psi (RWO Prep). Loaded IA with 112 bbls crude to reach test pressure for CMIT TxIA. T/IA lost 320/330 psi in 15 mins. Injection rate very slow. MIT-OA FAILED to 2000 psi. Pumped a total of 54 bbld of crude down OA. SD monitored pressures. 03/22/09 Shut, SSV, MV, IA, OA Open. 03/23/09 T/I/0=720/450/60. Temp=S1. Bleed WHPs to 0 psi (pre PPPOT). TBG 912'. Bled TBGP from 770 psi to 530 psi (fluid to surface). IA FL @ 192'. Bled IAP from 450 psi to 230 psi (fuid to surface). Monitor 30 mins, TBGP increased 20 psi, IAP increased 30 psi. NOTE: Hardline on site to RU for Circ out. Final WHPs 550/260/60. SV =Closed SSV, MV =Open IA, OA = OTG, NOVP. Page 1 of 3 C~ F-32, Well History (Pre Rig Workover) Date Summary 03/23/09 T/I/O = 830/300/520. Temp = SI. Bleed WHPs to 0 psi pre PPPOT (RWO). No Flow line, no AL. TBG FL @ 2385' (above sta #1). IA FL @ 720'. OA FL @ surface. Bled OAP to 0 psi in 40 min (1/2 bbl). Bled IAP to 120 psi in 1 hr, 5 min (gas/fluid). Bled TBG pressure to 530 psi in 1 hr, 25 min. FL rose to surface (3 bbls). SI, monitored WHPs for 30 min. OAP increased to 160 psi. IAP increased to 200. TBG pressure increased to 550 psi. Will come back tomorrow. Final WHPs = 550/200/160. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 03/24/09 T/I/0=550/300/60, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: External check installed. Stung into test port (50 psi), bled to 0 psi. Functioned LDS, all moved freely (2.5"). Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in 2nd 15 min (PASS). Bled void to 0 psi. PPPOT-IC: External check installed. Stung into test port (100 psi), bled to 0 psi. Functioned LDS, all moved freely (2.5"). Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 20 psi in 2nd 15 min (PASS). Bled void to 0 psi. 03/24/09 T/I/0=880/500/80 temp=S1 Circ-out (RWO Prep). Pumped 15 bbls crude and 28 bbls diesel down TBG to attempt a CMIT, didn't pressure up. Went to 9.8 ppg NACL brine. 03/25/09 Pumped 350 bbls of 9.8 ppg NaCL brine capped with 5 bbls diesel down Tbg taking returns up IA thru hardline jumper to flowline of well #11. SD and rigged up IA in attempt to bullhead IA. Pumped 5 bbls neat methanol and 25 bbls 9.8 brine before pressuring up T/IA to 2000 psi. Monitored and attempted to bullhead IA once more in a 25 min span. Pressures slowly decreased to 700 psi in that time frame. Rigged down from IA and rigged back up to Tbg. Began to circulate well pumping down Tbg thru cut up IA to well #11 flowline. Pumped 622 bbls (total 990 bbls) of 9.8 ppg brine capped with 5 bbls diesel. Took a balance weight test at 750 bbls away on returns and 9.8 ppg brine was the result. RU to IA and bullheaded 10 bbl diesel at 0.6 bpm. RU to OA. Bullheaded 2 bbls neat methanol, 180 bbls 9.8 inhibited brine capped withl0 bbls diesel down OA. Freeze protected F-11 flowline on WOA recipe and surface lines. Pumped 101 bbls of crude 7 bbls neat and 4 bbls of diesel to pressure flowline to 1000 psi. RDMO. Final WHP's = 100/90/260. DHD to bleed pressures and shoot FL's SV, WV =closed, SSV, MV = open, IA/OA = OTG. 03/25/09 T/I/0=70/200/Vac. Temp=Sl. Bleed WHPP's to 0 psi. (Pre-RWO) TBG FL @ 1722' (27 bbl). IA FL @ 1692' (91 bbl). Bled IAP from 200 psi to 50 psi in 3 hours. TP increased 180 psi to 250 psi during IA bleed. Bled TP from 250 psi to 150 psi in 1 hour, fluid to surface. IAP increased 100 psi to 150 psi during TP bleed. Bled IAP from 150 psi to 120 psi in 30 minutes, Fluid to surface. Monitor WHP's for 30 minutes. TP increased 160 psi to 310 psi in 1 hour during monitor. IAP increased 40 psi to 160 psi in 30 minutes during monitor. No change in OAP during bleeds or monitor. Final WHP's = 310/160/Vac. WV, SV =CLOSED. SSV, MV =OPEN. IA & OA = OTG. NOVP. 03/25/09 T/I/0=180/200/220. Temp=S1. Bleed WHP's to 0 psi, post-Circ (pre-RWO). T & IA FL's near surface. OA FL @ surface. Bled OAP from 220 psi to 0 psi in 20 mins (all fluid), bled TP from 180 psi to 0+ psi.in 75 mins, bled IAP from 200 psi to 180 psi in 15 mins (all gas). Monitor 30 mins. TP increased 30 psi, IAP increased 10 psi, OAP remained the same. Final T/I/O = 30/190/0. SVNVV = C. SSV/MV = O. IA, OA = OTG. NOVP. 03/26/09 T/I/0=600/310/Vac. Temp=Sl. Bleed WHP's to 0 psi. (Pre-RWO). RU jumper from TBG to IA to equalize and get gas to surface (TBG is cut @ 9585). T & IA Pressures equalized @ 530 psi each. TBG FL @ 3064' (94' below top station) (47 bbl). IA FL Q 1872' (101 bbl). Bled IAP from 530 psi to 420 psi in 45 minutes. TP increased 60 psi to 590 psi during IA bleed. Bled TP from 590 psi to 410 psi in 1 hour, fluid to surface. IAP increased 30 psi to 450 psi. Bled IAP from 450 psi to 350 psi in 1 hour 15 minutes, fluid to surface. Rig down and monitor for 30 minutes. TP increased 90 psi to 500 psi during IA bleed and monitor. IAP increased 60 psi to 410 psi during monitor. OAP increased from Vac to 22 psi during Bleeds and monitor. Final WHP's = 500/410/ 22. SV & WV =CLOSED. SSV & MV =OPEN. IA & OA = OTG. NOVP. Page 2 of 3 • F-32, Well History (Pre Rig Workover) Date Summary 03/26/09 Tll/O = 470/320/vac. Temp = SI. Bleed WHPs to 0 psi (RWO prep). TBG FL C~ 1035'. IA FL C~ 1850'. Bled TBG &IAP simultaneously to 300 psi in 4 hrs. TBG FL rose to surface. SI bleeds, monitored for 30 min. TBG pressure increased to 400 psi. No change in IAP. Re bled TBG pressure. During bleed, TBG pressure increased to 420 psi. SI TBG bleed. Re bled IAP for 1 hr to 280 psi. During bleed, TBG pressure increased to 520 psi. Re bled TBG pressure to 460 psi in 30 min. FL rose to surface. Out of time. SI, monitor for 30 min during rig down. TBG pressure increased to 500 psi. IAP increased to 380 psi. Final WHPs = 500/380/vac. SV = C. SSV, MV = O. IA, OA = OTG. 03/27/09 T/I/0=800/560/0 Circ -Out (RWO) Speared into Tbg with 2 bbls meth followed by 1022 bbls 9.8# brine taking returns up IA to F-11 flowline. Freeze protect F-11 flowline with 7 bbls neat & 99 bbls crude & 1 bbls diesel to flush hardline per WOA freeze protect recipe. SV, WV = SI SSV, MV = O IA, OA = OTG. Operator Notified. FWHP's = 0/0/0. 03/28/09 T/O/0=vac/0/0 Set 4 1/16" CIW H BPV #147 Thru tree 4ES. 1-2' ext used tagged C~ 96". Page 3 of 3 • BP EXPLORATION Operations Summary Report Legal Well Name: F-32 Common Well Name: F-32 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date 'From - To Hours Task Code NPT 3/30/2009 18:00 - 19:00 1.00 MOB P 19:00 - 20:00 1.00 MOB P 20:00 - 22:00 2.00 MOB P 22:00 - 23:30 1.50 MOB ~ P 23:30 - 00:00 0.50 MOB P 3/31/2009 00:00 - 06:00 6.00 MOB P 06:00 - 08:30 2.50 MOB P 08:30 - 10:30 2.00 MOB P 10:30 - 12:00 1.50 MOB P 12:00 - 14:00 2.00 WHSUR P Start: 3/26/2009 I Rig Release: 4/10/2009 Rig Number: Page 1 of 9 Spud Date: 3/20/1989 End: Phase Description of Operations PRE Service Rig. Perform Pre-tour checks. RD Mud lines and Beaver Slide. PRE Hold weekly safety meeting with rig crew, BP WSL and Nabors tourpusher. PRE Scope derrick down. Lay derrick over. Prepare to move rig off of well. PRE Hold PJSM with rig crew and Peak drivers about moving rig. Move rig off of P-17. PU rig mats and herculite around well. PRE Move rig off of P-pad, headed to F-pad. PRE Move rig from P-pad to F-pad. PRE Spot rig over F-32. PRE Raise and scope derrick. Connect mud lines. ACCEPT RIG AT 10:00-HRS. PRE RU all lines on tree to circulate out well. Install secondary valve on IA. Hook up lines to the tiger tank. DECOMP Hold PJSM on pulling BPV. PU DSM lubricator and pressure lubricator. 14:00 - 15:30 1.50 WHSUR P DECOMP Wait on 9.8-ppg brine due to truck availability. 15:30 - 16:00 0.50 WHSUR P DECOMP Hold Pre-well meeting with Rig crew, Nabors toolpusher and BP WSLs. Discuss all upcoming operations and review well kill procedure. Pressure test lines to 3500-psi. 16:00 - 20:30 4.50 KILL P DECOMP Line up to pump down annulus, taking returns out tubing. Pressure on the IA = 150-psi. Pressure on the tubing = 30-psi. Pump at 3-BPM with 100-psi. Pump 36-bbls without returns, venting gas to the tiger tank. Swap over and pump down tubing, taking returns from annulus. Pump 204-bbls without returns and then catch ressure. Con't to circulate well. Pump 4 BPM C~ 320-450 psi. Pumped total of 675 bbls. Lost 36 bbls Burin circulation. SI well & swap to circulate into pits. Pumped add'I 250 bbls; 4 BPM @ 340 psi. Lost 13 bbls. S/D & monitor well. Tbg on vac & IA intermittant flow then died w/ v. slight vacuum. Max OAP = 500 psi. 20:30 - 22:00 1.50 WHSUR P DECOMP Install TWC. Pressure up from below to 1000 psi. Rolled pump Ca? -1/4 BPM to hold 1000 psi. Test for 10 min. Pumped total of 5.9 bbls (includes filling IA) during 10 min test. SD. Bled down to 500 psi in 5 min. Pressure up from top to 3500 psi & held for 10 min. Charted testin . 22:00 - 00:00 2.00 WHSUR P DECOMP Bleed off ports & N/D Adapter Flange & Tree. Installed X-Over in hanger & checked threads. 4 1/2" BTC, made up 7 1/2 rounds, threads good. Checked LDS. 4/1/2009 00:00 - 02:00 2.00 BOPSU P DECOMP N/U BOPE & line to IA. 02:00 - 03:30 1.50 BOPSU P DECOMP Fill IA w/ 25 bbls of brine (in 5 hrs). Service choke manifold & mud cross. R/U test equip. 03:30 - 06:00 2.50 BOPSU P DECOMP Begin testing BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Jeff Jones w/ AOGCC C~ 19:50 hrs, 3/31/2009. 06:00 - 11:00 5.00 BOPSU P DECOMP Crew change - PTSM. Continue testing BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Completed testing. Rigged down all test equipment and blew down lines. 11:00 - 12:00 1.00 WHSUR P DECOMP Rig up Dutch lubricator lockdown mandrel. Make up Valve Shop lubricator to lockdown mandrel and pressure hest to Printed: 4/20/2009 12:11:02 PM • BP EXPLORATION Operations Summary Report Page 2 of 9 'i Legal Well Name: F-32 Common Well Name: F-32 Spud Date: 3/20/1989 Event Name: WORKOVER Start: 3/26/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Releaser 4/10/2009 Rig Name: NABOBS 4ES Rig Number: Date 'From - To ', Hours ~ Task ~ Code NPT Phase Description of Operations 4/1/2009 11:00 - 12:00 - _ - - - 1.00 WHSUR P DECOMP 1500-psi. pull TWC. Lay down lubricator and lockdown 12:00 - 13:30 1.50 PULL P DECOMP PJSM -review unlanding tubing hanger procedure and assign tasks and leader. Makeup landing Joint with closed TIW valve, 3-1/2" IF x 4-1/2" BTC XO to tubing hanger. Cameron wellhead tech. BOLDS. Unland tubin han er with 122K upweight. Pickup weight = 115K. POH and disconnect dual encapsulated control line and lay down tubing hanger. Makeup TIW valve with headpin to 4-1/2" tubing. 13:30 - 16:00 2.50 PULL P DECOMP Break circulation at 3.0-bpm at 250-psi to fill hole._Took ND tree, NU BOPE and testing BOPE. Circulated bottoms up at 5.0-bpm at 240-psi. Rigged up control line spooler and floor with 4-1/2" pipe handling tools while circulating. 16:00 - 17:00 1.00 PULL P DECOMP POH la in down 4-1/2" tubin 1 x 1 through pipe shed. Fill. hole with 15 jts. laid down. Pipe displacement = 2.9-bbls. Hole fill = 12.0-bbls. Losses = 9.0-bph. 17:00 - 19:30 2.50 PULL P DECOMP Continue POH laying down 4-1/2" tubing 1 x 1 through pipe shed. Continuously filling hole. 19:30 - 20:00 0.50 PULL P DECOMP RD Schlumberger / Camco control line spooling unit and remove from rig floor. Recovered a total of 4-SS bands and 26-rubber control line clamps. Although there was no information, this appears to be the correct amount of clamps & bands that would be run per procedure (2-SS bands at hanger and also at SSSV and 1-clamp every other joint). 20:00 - 00:00 4.00 PULL P DECOMP Continue to POH laying down 4-1/2" tubing through pipe shed. Maintain continuous hole fill. OOH w/ 190 jts. 4/2/2009 00:00 - 03:00 3.00 PULL P DECOMP Con't to POOH & UD 4 1/2" 12.6# L-80 TDS com letion. Pulled & UD total of 249 jts + 1 SSV Assy, + 5 GLM Assys, +1 - 20.47' Cut off Jt. Noted holes from Jts 120 to 178. Worst jt was # 136 (had 1 1/2" dia, holes). Tubing v. badly scaled from 137 to cut Jt. Pins were badly corro a ut off Jt had good clean cut & belled out to 4.85". Fluid losses = 3.1-bph. 03:00 - 04:00 1.00 PULL P DECOMP Clear & clean rig floor. 04:00 - 05:30 1.50 PULL DECOMP R/D tubing tools. R/U floor to P/U & run 3 1/2" DP. 05:30 - 06:00 0.50 WHSUR P DECOMP P/U running tool & set Wear Bushing. RI 2 LDS. UD running 06:00 - 06:30 0.50 CLEAN P DECOMP Service rig, daily PVT checks and derrick inspection. 06:30 - 08:30 2.00 CLEAN P DECOMP PUMU BHA #1 to dress off 4-1/2" tubing stub as follows:8-1/2" dress-off shoe, 3 x Washpipe Ext., 8-1/8" washover boot basket, 6-1/8" double pin sub, 9-5/8" casing scraper, bit sub, 4-3/4" LBS, 4-3/4" oil jar, 3-1/2" pump-out sub and 9 x 4-3/4" drill collars = 324.62' 08:30 - 16:30 8.00 CLEAN P DECOMP RIH w/BHA #1 on 297 jts. of 3-1/2" 15.5# Grade "E" IF drillpipe 1 x 1 from pipe shed. Tag top of 4-1/2" tubing stub 17' in on jt. #298. Lay down jt. #298. 16:30 - 17:30 1.00 CLEAN P DECOMP RIH w/10' 3-1/2" DP pup. Kelly up and establish milling parameters: P/U wt. = 146K, S/O wt. = 124K, 3.0-bpm C~? 550-psi, 51 RPM and -7000 ft-Ibs. torque. Wash over stub with dress-off shoe. Swallowed 14' of stub and then milled off -6" of stub. Worked dress-off BNHA on and off stub without rotating or circulating. Top of stub ~ 9579'. 17:30 - 21:00 3.50 CLEAN P DECOMP Circulate 40-Bbl. Hi-Vis sweep surface to surface at 5.0-bpm at Printed: 4/20/2009 12:11:02 PM • • BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: F-32 Common Well Name: F-32 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Start: 3/26/2009 Rig Release: 4/10/2009 Rig Number: Spud Date: 3/20/1989 End: Date From - To Hours Task ~ Code NPT ~' 4/2/2009 17:30 - 21:00 3.50 CLEAN P 21:00 - 00:00 3.00 CLEAN P 4/3/2009 00:00 - 00:30 0.50 CLEAN P 00:30 - 02:30 2.00 CLEAN P 02:30 - 03:30 I 1.001 CLEAN I P 03:30 - 04:30 1.00 CLEAN P 04:30 - 07:00 2.50 DHB P 07:00 - 08:00 1.00 DHB P 08:00 - 09:30 1.50 DHB P 09:30 - 13:30 4.00 CASE P 13:30 - 14:00 0.50 CASE P 14:00 - 15:00 1.00 CASE P 15:00 - 21:00 I 6.001 CASE I P 21:00 - 21:30 0.50 CASE P 21:30 - 00:00 2.50 CASE P 4/4/2009 100:00 - 03:00 I 3.001 CASE I P 03:00 - 04:30 1.50 CASE P 04:30 - 06:00 1.50 CASE P 06:00 - 06:30 I 0.501 CASE I P 06:30 - 10:00 I 3.501 CASE I P Phase Description of Operations DECOMP 1250-psi. Had small amount of gas to surface just before bottoms u .Pumped total of 675 bbls. Recovered small amount of scale & smoo. Swapped lines & reversed 2 bottoms up to insure good clean hole. 4 BPM @ 1000 psi. Pumped 130 bbls. Recorded losses of 3 bbls during circulation. DECOMP Blew down & set back kelly. POOH & stand back 3 1/2" DP. DECOMP Crew change. Service rig. Inspect derrick. Check PVT alarms. DECOMP Con't to POOH w/ BHA #1. Stopped at 3800' & scraped casing 4 times. Pulled & stood back 99 stands. DECOMP Stand back 3 stands of 4 3/4" DCs. Break out & UD BHA #1. Empty junk baskets. Had -15 Ibs of scale & metal filings. Mill had good dressing indication. DECOMP Clear & clean rig floor. DECOMP P/U 9-5/8" Halco RTTS & runnin tool. RIH on stands of 3 1/2" DP. Set packer at 3833' with 20K downweight. DECOMP Pressure tested 9-5/8" casing to 3500-psi for 30-charted DECOMP POH UD 9-5/8 Halco RTTS packer. TIE61 Rig up floor with 7" casin~_handling_tools and hydraulic tongs Prep 7" 26#, L-80 BTC-M liner and jewelry in pipe shed. TIEB1 PJSM -review liner running procedure and identify hazards and mitigations. Assign tasks and review running order with crew. TIEB1 RIH with 7" 26#, L-80 BTC-M liner shoe track as follows: 9-5/8" x 4-1/2" Unique Overshot Guide, 4-1/2" Baker Type 2 Landing Collar, 7" x 4-1/2" Ported XO, 7" HES Float Collar w/125# sand on ball and seat and 7" Insert Landing collar jt. Baker-Lok'd all connections below 7" Insert Landing collar joint including bottom of coupling on top of insert landing collar joint. made up all BTC-M connections of the mark. TIE61 RIH with 7" 26#, L-80 BTC-M casing 1 x 1 from pipe shed. Made up first 10 connections to mark and obtained an average torque value to use for running rest of casing in hole. Checked makeup every 5th joint to ensure BTC-M connections making up to mark. RIH w/ 70 jts. TIE61 Crew change. Service rig. Inspect derrick. Check PVT alarms. TIEB1 Con't to P/U &RIH w/ 7" 26#, L-80 BTC-M Scab Liner. M/U connections to triangle. I stalled 1 free floating centralizer on each jt. Used Best-O-Life thread compound on connections. Fill every 5 jts. RIH w/ 105 jts. TIEB1 Con't to RIH w/ 7" 26#, L-80, BTC-M liner. Installed 1 free floating centralizer per jt. Used Best-O-Life thread compound on all connections. Ran total of 153 its TIEB1 R/D casing tools. R/U DP handling tools. P/U, M/U & inspect liner hanger assy. P/U Wt = 140K, S/O Wt = 137K. TIEB1 Con't to RIH w/ 7" liner on stands of 3 1/2" DP. Fill DP every 5 stands. TIEB1 PTSM -crew change. Service rig, check PVT's and daily derrick inspection. TIEB1 Con't to RIH w/ 7" liner on stands of 3 1/2" DP. Fill DP every 5 stands. Established spaceout parameters: P/U wt. = 184K, S/O wt. = 155K. Tag 4-1/2" tubing stub with 37 stds. + 1 jt. + 33' of 3-1/2" DP RIH @ 9579'. Swallowed tubing stub with Unique overshot and observed both sets of pin shearing. Printed: 4/20/2009 12:11:02 PM • BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: F-32 Common Well Name: F-32 Spud Date: 3/20/1989 Event Name: WORKOVER Start: 3/26/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/10/2009 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours ~~ Task ~' C 4/4/2009 06:30 - 10:00 3.50 CASE P NPT ~ Phase Description of Operations 10:00 - 10:30 I 0.501 CASE I P 10:30 - 14:30 4.001 CEMT P TIEB1 Bottomed out overshot on No-Go. Picked up to 184K + 2' and caculated spaceout. POH layed 2 jts. DP down. RIH with 10' DP pup + 1 jt. DP. Made up Baker cementing swivel and connected rig circulating lines. Circulated well at 3.0-bpm to verify flow path and while rigging up Schlumberger cementers and spotting in vac trucks. Walked down cementing equipment rig up. TIEB1 PJSM -reviewed cementing and liner hanger/packer setting procedure with all rig crew, CH2MHill vac truck drivers and Schlumberger personnel. TIEB1 Schlumberger prime up their pump and pump 5-bbls of fresh water to warm and fill lines. Pressure test lines to 4500-psi. Perform low and high pressure stalls. Good tests. Begin pumping 15.8-ppg Class "G" cement at 1110-hrs. Schlumberger had trouble maintaining correct density initially but was able to troubleshoot the problem and was able to complete the job with a consistent density. Close choke while troubleshooting problem to prevent cement from falling while Schlumberger solved their issues. Pump a total of 176.5-bbls of cement at avera a rate of 5-BPM with -350- si av ressure. Cement yield = 1.16 cu ft/sk. Shut down and drop drill pipe wiper dart. Schlumberger displace cement using 9.8-ppg brine. Pump displacement at 5-BPM. Did not see DP der dart latch liner wiper plug (expected at 23-bbls disnlacedl. At 235-bbls displacement. use Super choke to hold 14:30 - 18:00 I 3.501 CEMT I P I ITIEBI 18:00 - 18:30 0.50 CEMT P TIEB1 18:30 - 19:00 0.50 CEMT P TIE61 19:00 - 19:30 0.50 WHSUR P TIEB1 19:30 - 00:00 4.50 WHSUR P TIEB1 At 246-bbls displacement, slow pump to 1-BPM. Bump plug at 258.3-bbls of displacement pumped with 3200-psi. CIP at 1330-hrs. Schlumberger pressure up to 3000-psi to set liner top hanger. Slack-off to ensure slips are engaged and no indication that they have engaged. Pressure up to 3200-psi and slack off again. Liner top hanger slips are engaged. Pressure up to 4000-psi to set liner top packer. Good indication of packer setting at surface. Bleed off pressure. Rotate 15-turns to the right to release running tool. Use Schlumberger to pressure up to 1000-psi and PU. When pressure began to bleed off, Schlumberger pump 20-bbls of brine at 6.0-BPM with 1035-psi.. When done pumping 20-bbls, RU and reverse at 5-BPM with 620-psi. Take and monitor returns in open-top tank. Got total of -40-bbls of cement returns with 30-Bbls. neat cement. Blow down all cementing lines. RDMO cementers and clean out open top tank. Laid down top joint DP with Baker swivel. POH w /37 stds. DP and liner running tools standing back in derrick. Breakout and lay down liner running tools. Pick up Baker swivel and joint DP. Break out swivel from joint and lay down. Crew change. Service rig. Inspect derrick. Check PVT alarms. Make service breaks on 7" running tool Pull wear ring Prepare cellar and wellhead; bleed ports; BOLDS; attempt to pull pack-off w/30-76K; steamed wellhead and worked pipe Printed: 4/20/2009 12:11:02 PM • • BP EXPLORATION Page 5 of 9 Operations Summary Report Legal Well Name: F-32 Common Well Name: F-32 Spud Date: 3/20/1989 Event Name: WORKOVER Start: 3/26/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/10/2009 Rig Name: NABOBS 4ES Rig Number: Date li, From - To Hours II Task `Code NPT ~ Phase Description of Operations _ I ____ __ 4/5/2009 100:00 - 01:30 1.501 WHSUR P TIE61 Con't to attempt to pull pack-off. Work pipe in attempt to free 01:30 - 03:00 I 1.501 WHSUR I P 03:00 - 04:00 I 1.001 WHSUR I P 04:00 - 04:30 0.50 WHSUR P 04:30 - 08:00 3.50 WHSUR P 08:00 - 09:30 1.50 WHSUR P 09:30 - 10:00 0.50 WHSUR P 10:00 - 12:00 2.00 BOPSU P 12:00 - 13:30 1.50 BOPSU P 13:30 - 15:00 1.50 CLEAN P 15:00 - 15:30 I 0.501 CLEAN I P 15:30 - 18:00 2.50 CLEAN P 18:00 - 18:30 0.50 CLEAN P 18:30 - 19:30 1.00 CLEAN P 19:30 - 20:30 1.00 CLEAN P 20:30 - 21:00 0.50 CLEAN P 21:00 - 23:00 ~ 2.00 ~ CLEAN ~ P 23:00 - 00:00 1.00 CLEAN P 4/6/2009 00:00 - 03:00 3.00 CLEAN P 03:00 - 04:00 I 1.001 CLEAN I P pack-off. P/U & hold pull for 20 min, no movement. No success. TIEB1 Notify RWO Superintendent & Engineer. Discuss plan forward. Plan to test cement & plug barrier, ND BOPE, & spool to get pack-off free. Order standby tbg spool. TIEB1 Monitor OA pressure = 0 psi. Attempt to pressure up to 3500 psi and at 2200 psi, pack-off leaking. Confirmed barrier policy w/RWO Superintendent and two barriers are as follows: 1) FasDril Plug at 9670' and 2) cement and float collar at 9537' w/kill weight fluid on top. Got approval for 1000 psi barrier test for 30 minutes. Pressure test 9 5/8" casing and cement barrier TIEB1 Monitor well & OA. Well static. TIEB1 ND BOP and ull tubing spool. Cement in profile on bottom of tubing spool. Pull 9-5/8" Csg packoff. Junk ring and primary seal were packed with cement and had to be removed after the pack off was pulled. Clean bottom of tubing spool, casing hanger and ring grooves. Install new casing packoff. TIEB1 NU tubing spool. Torque all studs and nuts using Sweeney wrench. TIEB1 Cameron tech test new 9-5/8" casing packoff to 5000-psi for 30-minutes. Good test. TIEB1 NU BOP stack._ Torque all studs and nuts using sweeney wrench. TIEB1 Set test plug. Test BOP break to 250-psi low and 3500-psi _ CLEAN Hold weekly safety meeting with day rig crew. Discuss care and inspection of all fall protection, recent incidents and driving safety. Hold PJSM on MU Drill out BHA and RIH with DP from derrick. CLEAN MU Cement drill out BHA. BHA consists of 6-1/8" tri-cone bit, 2-boot baskets, bit sub, bumper sub, oil jar, 9(ea) 4-3/4" DCs and pump-out sub. Total length = 306.83'. CLEAN RIH with Cement drill out BHA on 3-1/2" DP from derrick. CLEAN Perform pre-tour checks. Check PVT alarms. Service Rig. CLEAN Continue to RIH with Drill out BHA on 3-1/2" DP from derrick. CLEAN Cut & slip 84' of drilling line. CLEAN RIH w/3-1/2" DP; tag cement 9' in on jt #295 at 9461 ;stand back std #99 CLEAN M/U Kelly; drill cement (/9461' t/9523' - 160K up wt/116K down wt - 55 RPM C~ 4500 ft-Ibs. - 5/10K WOB - Pumping at 3 - 4 BPM at 390 - 820 PSI CLEAN Drill wi er lu sand landin float collars f/9523' t/9538 ;same parameters as above CLEAN Circulate and condition; pump 40 bbl hi-vis sweep - 4-5 BPM at 780/1350 PSI - Saw rubber from wiper plugs on shaker at 0215 hrs Pumped total of 540 bbls, No losses. Had cmt, rubber & metal cuttings in returns. CLEAN Blow down & set back kelly. L/D 2 singles. Printed: 4/20/2009 12:11:02 PM • BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: F-32 Common W ell Name: F-32 Spud Date: 3/20/1989 Event Nam e: WORKO VER Start : 3/26/2009 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 4/10/2009 Rig Name: NABOB S 4ES Rig Number: Date From - To Hours ' Task Code NPT Phase I Description of Operations 4/6/2009 03:00 - 04:00 1.00 CLEAN P CLEAN - PT 9 5/8" casing and 7" liner to 3500 psi for 30 charted minutes; tested good - Monitored open OA; no fluid flow noticed 04:00 - 06:30 2.50 CLEAN P CLEAN Pump 20-bbls spacer and displace well to 8.5-ppg seawater at 4-BPM with 980-psi. Monitor well -Static. 06:30 - 08:15 1.75 CLEAN P CLEAN Blow down. POH and LD 12-jts of DP. Then POH and rack back 24-stds. 08:15 - 09:00 0.75 CLEAN P CLEAN Discuss tagging 7" x 4-1/2" XO high with RWO engineers. Decide to RIH and confirm location of 7" x 4-1/2" XO. Rig crew services rig while discussing plan forward. 09:00 - 10:30 1.50 CLEAN P CLEAN RIH with cement drill out BHA on 3-1/2" DP from derrick. 10:30 - 16:30 6.00 CLEAN P CLEAN PU & MU Kelly. PU wt = 155K, SO wt = 122K (both with kelly). RIH and dry tag at 9540'. Bring pumps online at 2-BPM, 220-psi and RIH, tagging at 8540' again. Stage pumps up to 3-BPM with 400-psi. Rotate at 66-RPM with 160-rotating amps free torque. RIH while rotating and tag at~538'. Drill ahead with 5-7K WOB and 180-rotating amps torque. Increase WOB up to 15K to make progress. Drill through landing collar at 9540'. Drill ahead through cement to 9551'. PU single and Kelly up again. Drill ahead with same parameters. Through float collar at 9552' and tag 7" x 4-1/2" XO at 9553'. Shut off rotary and pumps and confirm tag at 9553'. 16:30 - 18:30 2.00 CLEAN P CLEAN PU and pump 40-bbl Hi Vis sweep and chase out of hole at 5-BPM with 1270-psi. 18:30 - 22:00 3.50 CLEAN P CLEAN Blow down & set back kelly. POOH & stand back 3 1/2" DP. 22:00 - 23:00 1.00 CLEAN P CLEAN Break out & UD BHA #2. Inspect bit & empty boot baskets. Recovered -10# of cmt & metal milling in junk basket. 23:00 - 00:00 1.00 CLEAN P CLEAN Hold Weekly Safety meeting w/ all hands. discuss recent incidents, Fall protection inspection & care, STOP cards & general safety on rig. 4/7/2009 00:00 - 02:00 2.00 CLEAN P CLEAN P/U & M/U BHA to clean out tailpipe as follows: 3 5/8" Bladed Junk Mill, Bit Sub, 6 -PAC DCs, XO, XO, 2-boot Baskets, 7" Scraper, Bit Sub, 9 -DCs, P/O Sub. TL = 514.96' 02:00 - 05:30 3.50 CLEAN P CLEAN RIH w/ BHA #3 to clean out Plug & tubing tailpipe. 05:30 - 09:30 4.00 CLEAN P CLEAN Ta XO at 9553'. LD single and PU Kelly. PU wt = 157K-Ibs, SO wt = 120K-Ibs. Turn pumps on at 2.9-BPM with 600-psi. Turn rotary on to 45-rpm with 170-rotating amps free torque. Rotating wt = 135K-Ibs. Mill ahead through sand with 5K-Ibs WOB and 180-rotating amps. Tag up on Ball Seat at 9663' and mill through with above parameters, increasing WOB to 7K-Ibs. Once through Ball Seat, PU and attempt to run through XO and all areas milled. Tag up on XO. Engage rotary and ream through 9553' (XO depth) 4-times. Attempt to pass through XO without rotating and still hanging up a little, probably due to being a flat bottomed mill catching a lip_. Continue in hole and tag up on tubin stub ? at 9580'. Mill ahead with above parameters and 5-7K-Ibs WOB. 09:30 - 11:30 2.00 CLEAN P CLEAN Get through top of stub and start milling on what appears to be hard cement with light cement returns over the shaker. Make 20' to 9601' at 1100-hrs. Call ADW engineer to discuss the impending BOP test scheduled for tomorrow, knowing that we still need to drill up the FasDrill Plug, L/D DP and start RIH with a completion. ADW engineer agreed to stop drilling and Printed: 4/20/2009 12:11:02 PM Start: 3/26/2009 Rig Release: 4/10/2009 Rig Number: BP EXPLORATION Operations Summary Report Legal Well Name: F-32 Common Well Name: F-32 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date From - To Hours ~~ Task I Code NPT 4/7/2009 09:30 - 11:30 11:30 - 13:30 13:30 - 14:30 14:30 - 15:30 15:30 - 19:30 19:30 - 00:00 2.00 I CLEAN P 2.001 CLEAN I P 1.001 CLEAN ~ P 1.00 ~ W HSUR ~ P 4.001 BOPSUFi P 4.501 BOPSURP 4/8/2009 00:00 - 02:30 02:30 - 03:00 03:00 - 04:30 04:30 - 07:00 07:00 - 09:00 09:00 - 11:00 2.501 BOPSUFiP 0.50 BOPSU P 1.50 BOPSU P 2.50 ~ CLEAN ~ P 2.001 CLEAN I P 2.001 CLEAN I P Phase. CLEAN • Page7of9~ Spud Date: 3/20/1989 End: Description of Operations a to oumo a 20-Bbl Hi-Vis sweep all the wav around to CLEAN Circulate 20-Bbls Hi-Vis sweep throughout wellbore (-440-Bbls) at 5.4 BPM, 1790-psi. A total of 588-Bbls were circulated before returns were clean. Contacted AOGCC at 1210-hours for notification of impending BOP test. Lou Grimaldi returned call at 1300-hours and asked for an update when we were ready to P/U the RTTS. CLEAN POH and S/B 2-stands of DP in derrick and prepare to P/U RTTS to RIH and prepare for weekly BOP test. CLEAN Spot RTTS in Pipe Shed and bring up to Rig Floor. Called AOGCC with update for impending BOP test and Lou Grimaldi returned call to waive the State's right to witness the 4ES weekly BOPE test. P/U RTTS and set one joint below Rio Floor. Test RTTS to 1000-psi for 10 recorded minutes. CLEAN Pull wear bushing and install test plug. Fluid leaking by test lu energize all lock down screws. Fluid is still leaking by. Pull test plug, cement cuttings on test plug. Flush BOP stack. Install second test plug and energize all lock down screws. Test lu is holding. CLEAN Test BOPE to 250 si low and 3 500 si hi h ressure_s. Hold each test for 5 minutes on the chart. Tested Blind Rams, 3-1/2"x 6" VBR's, Choke Manifold Valves, Manual Choke and Kill Valves, HCR Choke and Kill Valves, Floor and Dart Valves. Used 4-1/2" test joint. AOGCC witness of test was waived by Lou Grimaldi. Test was witness by Nabors Toolpusher and BP WSL. CLEAN Test BOPE to 250 psi low and 3,500 psi high pressures. Hold each test for 5 minutes on the chart. Tested 3-1/2"x 6" VBR's, Annular Preventer, Kelly valve, and Test spool valve used 3-1/2" test joint.2-1/16" valve on test spool failed. Replaced with new 2-1/16" valve and retest. AOGCC witness of test was waived by Lou Grimaldi. Test was witness by Nabors Toolpusher and BP WSL. CLEAN Pull test plug and install wear bushing. CLEAN P/U RTTS running tool and latch onto Halco RTTS, Release RTTS and pull to surface, UD RTTS and running tool. All slip segments and packer rubber on RTTS. CLEAN RIH 2 stands and drill cement from 9 601', WOB 5-7K, 60 rpm at 270 amps, 3 bpm at 800 psi. Up weight 167K, down weight 117K, rotating weight 135K. The torque dropped of and WOB disappeared with 5' remaining on joint #292. Bottom of the mill at 9,632' with Kelly down at 0630-hours. P/U and M/U joint #293 and resume milling operation, but see no WOB while slowly RIH at 60-RPM and 3-BPM. Stop at 9,647' to pump Hi-Vis sweep all the way around. P/U to 9,647' and park for sweep while rotating at 60-RPM. CLEAN Circulate Hi-Vis sweep at 5-BPM 1885-psi. Seeing cement anc some sand with a few chunks of rubber over the shaker when CLEAN Resume milling operations:,P/U wt 167K-Ibs, S/O wt 117K-Ibs, Rot wt 137K-Ibs, Torque 4.5K-Ib-ft, 4-BPM at 500-psi. Mill with faster penetration rate from 9,467' to 9,655' and WOB falls off. Printed: 4!2012009 12:11:02 PM s • BP EXPLORATION Operations Summary Report Legal Well Name: F-32 Common Well Name: F-32 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES i Date From - To I Hours Task 'Code NPT 4/8/2009 09:00 - 11:00 2.00 CLEAN P Start: 3/26/2009 I Rig Release: 4/10/2009 Rig Number: Page8of9~ Spud Date: 3/20/1989 End: Phase Description of Operations CLEAN Slowly continue in and tag more fill (at 0915-hrs) or FasDrill starts taking fluid. Start to P/U and string torques up. Stop rotating and drop back down to work torque out of string. Work pipe several times, then S/D pump after pum i~mq a total of 202-Bbls fluid downhole without returns and work pipe up to 20K over for 8-10 times and pipe comes free at 0945-hours. Start pump to see if fluid level will come to surface and catch inside th DP, P/U DP jt #294 and continue RIH with pump on, but without rotating, tag something at 9 668'. P/U start rotating at 60-RPM and RIH slowly and bit falls through or FasDrill starts movin with about 2-3K-Ibs WOB, then falls free. Get Kell with #294 all the way down: P/U, B/O Kelly, and P/U M/U #295 and RIH to 9,725' with Kelly down. Do not see any obstruction. P/U M/U #296 and RIH to 9,750' which is 18' out of TP at 9,732'. 11:00 - 12:00 1.00 CLEAN P CLEAN Start POH to wait for Fluid Level shots by DHD (Downhole Diagnostic) team. Yo-Yo Scrape with 7" scraper 3-times with scraper positioned from 9,509' to 9,321'., 12:00 - 13:00 1.00 CLEAN P CLEAN DHD team shoots 2 fluid levels 10 minutes a art at 1220-hrs (1506') and 1230-hours 1680'). Pump had been S/D for 40-minutes at time of first F/L shot. R/U to strait POH and UD DP through Pipe Shed. 13:00 - 18:00 5.00 CLEAN P CLEAN POH and UD DP through the Pipe Shed. Use constant hole fill of -60-BPH plus double pipe displacement while POH. DP joint #30 UD at 1415-hours. #60 UD at 1500-hours. #75 UD (~ 1510-hrs. 1300-hours, stop POH and hold short Safety discussion around DP and ask each crew for Safety input with respect to POH and UD DP. #150 UD @ 1700-hrs. Averaging 40+ jts/hr. 18:00 - 18:30 0.50 CLEAN P CLEAN Crew change, service rig, inspect derrick, set and test PVT's. 18:30 - 21:00 2.50 CLEAN P CLEAN POH and UD DP through the Pipe Shed. Use constant hole fill of -60-BPH plus double pipe displacement while POH. 21:00 - 22:30 1.50 CLEAN P CLEAN UD BHA, mill was in good condition with moderate wear, all carbide inserts were in place and there were no gouges on outer side of mill. Recovered 1 cup of pot metal and cement in boot basket. 22:30 - 23:00 0.50 CLEAN P CLEAN Pull wear bushing. 23:00 - 23:30 0.50 CLEAN P CLEAN Flush BOP stack, clear and clean rig floor. 23:30 - 00:00 0.50 BUNCO P RUNCMP Bring tubing handling equipment to rig floor. 4/9/2009 00:00 - 02:00 2.00 BUNCO P RUNCMP R/U handling equipment for 4-1/2" 13Cr-80, Vam Top Tubing. Compensator and Torque Turn Equipment. 02:00 - 03:00 1.00 BUNCO P RUNCMP Hold PJSM with involved personnel. P/U tubing jewelry. P/U WLEG, X-Nipple with RHC-M installed, Joint of 4-1/2", 12.6#, 13Cr-80, Vam Top tubing, 7"x 4-1/2" Baker S-3 Packer, and X-Nipple 3.813". BakerLok all connections below packer. Continue -60 bph holefill with seawater. 03:00 - 10:00 7.00 BUNCO P RUNCMP Run 4-1/2" 12.6#, 13Cr-80, Vam Top tubing, use compensator and Torque Turn each connection. Use Jet Lube Seal Guard pipe dope and M/U torque of 4,440-Ib-ft. Continue -60 bph hole fill + double displacement with seawater. Average loss rate is Printed: 4/20/2009 12:11:02 PM ! # BP EXPLORATION Page 9 of 9 Operations. Summary Report Legal Well Name: F-32 Common Well Name: F-32 Spud Date: 3/20/1989 Event Name: WORKOVER Start: 3/26/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/10/2009 Rig Name: NABOBS 4ES Rig Number: Date FromTo Hours Task Code NPT Phase Description of Operations 4/9/2009 103:00 - 10:00 7.00 BUNCO P RUNCMP 75-BPH over the last 12-hours. New tubing joint #68 RIH at 10:00 - 12:00 I 2.00 12:00 - 14:00 I 2.00 14:00 - 17:00 3.00 17:00 - 18:00 1.00 18:00 - 18:30 I 0.50 18:30 - 21:30 I 3.00 21:30 - 22:30 I 1.00 22:30 - 00:00 I 1.50 4/10/2009 100:00 - 01:30 I 1.50 01:30 - 04:00 I 2.50 0725-hours. RUNCMP Troubleshoot and repair the stabbing board control system. A contactor had shorted out. RUNCMP Resume RIH with new 4-1/2" Vam Top completion with jt #123. Joint #129 at 1230-hours. GLM #2 with DCK shear Valve at 1235-hrs. #150 C~ 1335-hrs. RUNCMP Repair the control box for the stabbing board. RUNCMP Run 4-1/2" 12.6#, 13Cr-80, Vam Top tubing, use compensator and Torque Turn each connection. Use Jet Lube Seal Guard pipe dope and M/U torque of 4,440-Ib-ft. Continue -60 bph hole fill + double displacement with seawater. RUNCMP Crew Change, service rig, inspect derrick and handling equipment, set and test PVT's RUNCMP Run 4-1/2" 12.6#, 13Cr-80, Vam Top tubing, use compensator and Torque Turn each connection. Use Jet Lube Seal Guard pipe dope and M/U torque of 4,440-Ib-ft. Continue -60 bph hole fill + double displacement with seawater. Run 221 joints of tubing. RUNCMP P/U tubin 'oint #222 and to out on 7"x 4-1/2" XO. Tag at 32' in on joint #222 = 9,572' tubing depth. UD joint #222, W LEG spaced out to land at 9,563', 8.60' above 7"x 4-1/2" XO. M/U Cameron 13"x 4-1/2" DX2 MS / CCL hanger. Land hanger and run in lock down screws torque to 600 ft/Ibs. Up weight 125K, down weight 93K. RUNCMP Reverse circulate in 160 bbls of 120 degree seawater followed by 320 bbls of 120 degree seawater with Nalco EC1124A inhibitor down IA taking returns out the tubing at 3 bpm with 60 psi pump pressure. RUNCMP Reverse circulate in 320 bbls of 120 degree seawater with Nalco EC1124A inhibitor down IA taking returns out the tubing at 3 bpm with 60 psi pump pressure. RUNCMP Drop 1-7/8" rod and ball, pressure up on the tubing to 3,500 psi down to 1,600 psi. Pressure up on the IA to 3,500 psi for 30 minutes on the chart, good test. Bleed tubin side off, DCK valve sheared at 1,100 si. 04:00 - 05:00 1.00 BUNCO P RUNCMP Install Cameron 4" Type H, TWC with Cameron wellhead tech. Test from below to 1.000 psi for 1'0 charted minutes, test from 05:00 - 07:30 2.50 BOPSU P WHDTRE Blowdown lines, N/D BOP stack and stand back on stand. 07:30 - 09:30 2.00 WHSUR P WHDTRE N/U Adaptor Spool and Tree. 09:30 - 11:00 1.50 WHSUR P WHDTRE Test Hanger void to 5000-psi for straight line. Test Tree to 5000-psi, charted for 10-minutes. Good Test. 11:00 - 12:00 1.00 WHSUR P WHDTRE P/U and install DSM lubricator and test to 500-psi. POH and UD TWC. R/D DSM lubricator. 12:00 - 15:30 3.50 WHSUR P WHDTRE R/U Lil' Red Hot Oilers to begin Freeze Protect with 160-Bbls of diesel. Circulate diesel, 1-BPM at 500-psi. 15:30 - 17:00 1.50 WHSUR P WHDTRE Realign valves and allow to U-tube. 17:00 - 18:00 1.00 WHSUR P WHDTRE Install Cameron 4" Type H, BPV with Cameron wellhead tech n 1 000 si for 10 minutes on the chart. Secure tree and cellar. Rig Released at 18:00 hours on 4/10/2009. Printed: 4/20/2009 12:11:02 PM 03/18/09 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~MRL~/ l N0.5133 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wull _1.,1, u ~,p~~ n, e t ~ ~l )e, ~~'~~~ ~w~" ~- ``'' •• A v° ~v~~ ~D ~i4- tc'd -~,~ ~.~°~ J-27A AY3J-00010 CBL _ j _-- 02/21!09 v iV~ t S-107 AWJB-26 MEM L L lJ ~ '~- 02/25/09 1 09-34A AZ4D-00005 USIT (REVISED) 02/07/09 1 1 V-210 AWJB-00025 INJECTION PROFILE _ 02/23/09 1 1 MPB-22A AXBD-00005 MEM SCMT & TEMP PROFILE _ (p ~ 12/23/08 1 1 V-219 12103700 USIT (REVISION #2) ._ ~ ( 11/21/08 1 1 11-18 BOCV-00006 PRODUCTION LOG f - C(- 03/02/09 1 1 B-25 AVYS-00023 USIT - / 't'- / ~ 03/06/09 1 1 N-18A AYKP-00013 PRODUCTION LOG `~- j~5 j - 03/11/09 1 1 F-18 AVY5-00022 USIT ~ ,- %~ _ '~- 03/04/09 1 1 3-19/R-28 AZ4D-00009 LDL ~/ ~ ( 03/06/09 1 1 V-117 BOOR-00003 MEM PRODUCTION PROFILE ~p - ( ~ 03/12/09 1 1 V-211 AY3J-00014 (PROF/RST WFL - ~ 03/16/09 1 1 V-214 AY3J-00013 (PROF/RST WFL - 03/15/09 1 1 K-06B AWJI-00017 MCNL ~ f 01/28/09 1 1 L5-15 12113027 RST . /O ''~ ! • 12/09/08 1 1 07-18 12071915 RST ~j 12/01/08 1 1 15-15C AWJI-00015 MCNL - j 01/02/09 1 1 W-218 40018337 OH MWD/LWD EDIT 12/07/08 2 1 R-41 40018496 OH MWD/LWD EDIT ( 01/04/09 2 1 H-18 11999064 RST ) - I U `~- 12/03/08 1 1 = q ~- ~ . ~.-r.v~ .+v ~...v.r~c~aac ncvc~r ~ o ~ a~~a~~nvaa '-~w nc 1 lJ tSrvllY~a VrvC LVYT CA1.17 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: °~ ~ -a l~S `I 5 0. ~ ~ ~- t~~ w Q- o ~ 8 vu ?J ~/a ~~~ i~ ~~ Alaska Data & Consulting Services 2525 Gambell ~ye~tyte,k~0 -.~ Anchorage, AK ;98;~(2~8 ATTN: Beth ~'""- Received by: t~ ~ ~ e, ,-, ~~frT <~~ • • • • COI~SEIt~~~lTI01~ ~ ~~+ I~ 333 W. 7th AVENUE, SUITE 100 Aii l~o~~`~~•~~~iii~~•iiiiii----777 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader t ~ , - BP Exploration Alaska Inc. ~'' ~~~1~`°' ~ ~ ~ ~ `~ ~ ~ ~ ~" PO Box 196612 Anchorage AK 99519-6612 ~ ~ ~~ `~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, Pt7LT F-32 Sundry Number: 309-072 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions oi' approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum Leld inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this2-? day of February, 2009 Encl. ~~ ~ 1~% STATE OF ALASKA ~~ ~~'/ ~'~ ALA OIL AND GAS CONSERVATION CONN~SION ~ Fj~ E8 ~~ APPLICATION FOR SUNDRY APPRO ~ q~rka 2 ~ 20pg 20 AAC 25.280 ~ ~~tr ®Il R n_ _ _ 1. Type of Request: ^ Abandon ^ Sus end ^ O eration Shutdown ^ Perforate ^ Time Extensio 0~, CO ~111s P P ~~~h Qf ® Alter Casing ®Repair Well • ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended ^ Change Approved Program ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Develo ment~ p ^ Exploratory 189-033 3. Address: ^ ServiC~ ~. ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21930-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU F-32 ° Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028278 ~ 65.3' - Prudhoe Bay Field / Prudhoe Bay Oil Pool t2, PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10975' 9171' 10187' 8753' 9665' None C sin L n h Siz MD TVD B rst Ila e Stru tural r 11 11 ' rf 2680' 1 - /8" 26 2 80' 49 0 2670 In erm i e 10031' 9-5/ " 100 1' 662' 6 70 4760 Pr i n Lin r 1223' -1/2" 752' - 1 975' 84 7' - 9171' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 10050' - Rosso' 8673' - 9006' 4-1/2", 12.6# L-80 9733' Packers and SSSV Type: 9-5/8" Otis packer Packers and SSSV MD (ft): 9649' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: March 1, 2009 ®Oil~ ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mackie Derrick, 564-5891 Printed Na David R em Title Engineering Team Leader Prepared By Name/Number. Signature Phone 564-5743 Date ,2~.~p p4 Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity 'BOP Test ^ Mechanical Integrity Test ^ Location Cl earan ce Q i Other: ~ SOS Qs \ ~s-`~ 5~ i a ~w l~S' ~ :T-~ ~ +~iuv. ~~ Gfii~il \G~'tE~ Subsequent Form Required: APPROVED BY Z, Z7 f A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Rev}s'ed 06/2006 I,I Submit In Duplicate DI/ by GP,~y F-32 Rig Workover • Scope of Work: Pull 4-~h" L-80 completion, Mill and Retrieve packer, Set RBP in 5-1/2" in liner and dump 30 feet of sand on top. Pressure test casing to 3500 psi and confirm LLR. Run new 7" L-80 casing from 9750' to 3500' and cement in place. Change out 9-5/8" casing packoffs. PT new casing to 3500 psi for 30 minutes. Mill out the 7" shoe track. Pull 5-1/2" RBP. Run 4-'h" 13Cr-80 Baker S-3 packer completion. MASP: 2400 psi Well Type: Ivishak Producer Estimated Start Date: March 1St, 2009 Production Engineer: Shawn Isakson Workover Engineer: Mackie Derrick Pre-riq prep work: F 1 Attempt infectivity test up to 3000 psi to determine production casing LLR. Perform CMIT-TxIA to 2000 si if ossible, to verif lu s are still holdin . E 2 Power 'et cut tubin ~ 9585' MD. Reference tubin tall dated 04-13-89 F 3 Circulate well with kill wei ht fluid and diesel thru the cut. Bleed WHPs to 0 si W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. O 5 Set a BPV in the tubin han er. O 6 .Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 3-'/z" x 6" VBR pipe rams. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-'/z" tubing string to the cut. a 3. Mill and retrieve Baker packer and remaining tubing ~'`~ ~iZ'C-C'S ~ f a~ 4. Set retrievable bridge plug in 5-1/2" liner, dump 30' of sand and pressure test to 1500 psi for 15 minutes, pressure up to 3500 psi and achieve LLR. 5. Run and cement 7" scab liner from 9750' to 3500' MD. Note: Pipe rams will not be changed to 7" for casing running as the barrier to the reservoir will be a tested 5-1/2" RBP at 9800' MD. 6. Change out 9-5/8" casing packoffs. 7. Pressure test new casing to 3500 psi for 30 minutes. 8. Mill out shoe track. 9. Pull 5-1/2" retrievable bridge plug 10. Run 4-'/z" 13Cr-80 completion with Baker S-3 packer. Position packer at 9625' MD. 11. Displace the IA to packer fluid and set the packer. 12. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 13. Set BPV. ND BOPE. NU and test tree. RDMO. I TREE= 4-1/16" FMC WELLHEAD= McEVOY ACTUATOR= BAKER KB° ELEV = 65.25' BF. ELEV = 37.22' KOP = 4300' Max Angle = 60 @ 10700' Datum MD = 10385' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" SAFETY NOTES: ~ F-32 2078' 4-1/2" OTIS HXO SSSV NIP, ID = 3.813" (04/14/89) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2970 2905 1 MACCO DMY RK 0 10/21/02 4 5217 5088 31 MACCO DMY RK 0 10/21/02 3 7688 6918 40 MACCO DMY RK 0 10/21/02 2 9406 8184 43 MACCO DMY RK 0 10/21/02 1 9547 8284 45 MACCO DMY RK 0 10/21/02 Minimum ID = 3.725" @ 9720' 4-1/2" OTIS XN NIPPLE ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I ~TOPOF5-1/2" LNR ~ 9-5l8" CSG, 47#, L-80, ID = 8.681" 9612' (--~4-1/2" OTIS X NIP, ID = 3.813" 9~2' I~TBG SEAL ASSY I 964$' 9-5/8" OTIS PKR, ID = 3.85" 9665' ELM 4-1/2" HES FASDRILL PLUG (12/26/07) 96$0' 4-1/2" HES FASDRILL PLUG (12/17/07) 9699' 9720' 4-1 /2" OTIS X NIP, ID = 3.813" 4-1/2" OTIS XN NIP, ID = 3.725" 91 732' I--~4-1/2" OTIS TBG TAIL ID = 3.958" 9730' ELMD TT LOGGED 04/25/89 PB2FORATION SUMMARY REF LOG: BRCS ON 04/04/89 ANGLE AT TOP PERF: 53 @ 10050' Note: Refer to Production DB for historical pert data S¢E SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10050 - 10080 C 10/19/94 3-3/8" 4 10610 - 10650 C 07/05/90 PBTD 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" TD DATE REV BY COMMENTS DATE REV BY COMMENTS 04/14/89 ORIGINAL COMPLETION 03/09/08 JINVTLH 2ND FASDRILL SET (12/26/07) 09/10/01 RNITP CORRECTIONS 11/04/03 ?/TLP ADD PERF JEWELRY TO DRWG 10/06/07 GJF/TLH PULL /RESET PLUG 12/19/07 TFA/PJC PULL PXN (12/13/07) 12/19/07 GJF/JPC SET FASDRILL (12/17/07) SANDBACK WffH CEMENT CAP I MARKER JOIM' PRUDHOE BAY UNff W~L: F-32 PERMff No: 1890330 API No: 50-029-21930-00 SEC 2, T11 N, R13E 2243' FNL 8~ 2869' FE1 BP Exploration (Alaska) I I TREE= 4-1/16" FMC WELLHEAD = McEVOY ACTUATOR= BAKER KB' ELEV = 65.25' BF. ELEV = 37.22' KOP = 4300' Max Angle = 60 @ 10700' Datum MD = 10385' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2680' Minimum ID = 3.725" ~ 9710' I/2" Tubing, 12.6#, 13G-80, .0152 bpf, ID = 3.958" ~ -9730 Cemented 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" -9750 TOPOFS-1/2"LNR 9751' 9-5/8" CSG, 47#, L-80, ID = 8.681" I-I 10031' PERFORATION SUMMARY REF LOG: BHCS ON 04/04/89 A NGLE AT TOP PERF: 53 @ 10050' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10050 - 10080 C 10/19/94 3-3/8" 4 10610 - 10650 C 07/05/90 PBTD 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" C ^2000 ~~ 5-1/2" X NIPPLE, ID = 4.562" -3500 ~ 9-5/8" x 7" G2 ZXP Baker I Liner top Packer GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 -9600 I~ 4-1 /2" X NIPPLE, ID = 3.813" 9625 7" X 4-1/2" BAKER S-3 PACKER -9650 4-1/2" X NIPPLE, ID = 3.813" ~9710 4-1/2" XN NIPPLE, ID = 3.725" -9730 4-1/2" WLEG -9751 7" x 5-112" XO, ID-4.982" 10187' -~SANDBACK WfTH CEMENT CAP 10227' MARKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 04/14/89 ORIGINAL COMPLETION 06/04/07 CJWPJC PULL /RESET PLUG 09/10/01 RN/TP CORRECTIONS 10/06/07 GJF/TLH PULL /RESET PLUG 10/21/02 MH/KAK GLV GO 07/13/03 CMO/TLP MAX ANGLE CORRECTION 11/04/03 ?/TLP ADD PERF JEWELRY TO DRWG 03/16/07 CJWPAG SET PX TT PLUG @ 9699' F X32 SAFETY NOTES: ~ PROPOSED PRUDHOE BAY UNrT WELL: F-32 PERMIT No: 1890330 API No: 50-029-21930-00 SEC 2, T11 N, R13E, 2243' FNL & 2869' FEL BP Exploration (Alaska) Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, February 26, 2009 2:15 PM To: 'Reem, David C' Cc: Derrick, George (Mackie) M Subject: RE: F-32 (189-033) l have my answer. Thanks. From: Reem, David C [mailto:ReemDC@BP.com] Sent: Thursday, February 26, 2009 2:08 PM To: Maunder, Thomas E (DOA) Cc: Derrick, George (Mackie) M Subject: RE: F-32 (189-033) Tom, you are spot on. We will set the RBP near the top of the existing 5-1/2" production #iner & cover with sand. Then we`ll pick up a 9-5/8" RTTS; set it a couple of stands above the liner top, PT below the RTTS to ensure the RBPlsand will act as a hard bottom (and as a barrier to the Ivishak); then pull the RTTS and set it °500' below our planned scab liner-top and PT the casing above that to surface to 3500 psi. Then we'll go about running and cementing our 7" scab liner. Hope this plan answers your question.. DCR From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, February 26, 2009 1:33 PM To: Reem, David C Cc: Derrick, George (Mackie) M Subject: RE: F-32 (189-033) Dave and Mackie, Returning to F-32, the intent is for the new RBP to substitute for the tested and then removed tubing tail plug. Will an RTTS be run with the RBP to allow positively testing the RBP? Thanks in advance. Tom Maunder, PE AOGCC From: Reem, David C [mailto:ReemDC@BP.com] Sent: Tuesday, February 24, 2009 10:02 AM To: Maunder, Thomas E (DOA) Ce: Derrick, George (Mackie) M Subject: RE: F-32 (189-033) Tom, the 1500 psi test will be a gamble for sure based on a failing casing test at 0.4 by at 3500 psi {11812009}, This pump-in was performed during a Peak detect logging excersize where the minor casing leak was identr~ed {the tbg tail plug is holding solid). We are looking to see if the leak manifests itself at 1500 psi. We will still seek single-barrier dispensation from BP management to D the tree and U the BOP stack wether or not the casing tests at 1500 psi (the single barrier consisting of the tbg hanger seals (which have passed in the past and will be re-tested sown, and the BP1t)). Should the casing pass the test at 1500 psi, we would consider the passing test as a "nice to know" level of safety as a casing string that passes at 1500 psi, fails at 3500 psi; SHOULD remain solid against a column of i<WF and no added pressure for the NDFNU operatian. 2/26/2009 Page 2 of 2 • A bit drawn out, but that is the reason for the testing. We wiil ask the rig to re-verify the CMIT {if it passed at 1500 psi) prior to D the tree. DCR From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, February 24, 2009 9:36 AM To: Derrick, George (Mackie) M Cc: Reem, David C Subject: F-32 (189-033) Mackie and Dave, What is the pressure test history of the IA on this well? Is it expected that you will be able to test successfully to 1500 psi? Following the determination of the injection (LLR) rate, will the validity of the 1500 psi value be reverified? Thanks in advance. I look forward to your reply. Tom Maunder, PE AOGCC 2/26/2009 01 /18/08 Schlumhergcr N0. 4560 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 ~~ ~~g®~ p Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~1:al+~:9~Bi7~ ~EU ~ .~. ~~~`> Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Pt. Mac, Orion, Borealis WP_II .Inh ~ Inn rln¢crintinn r1e}n RI C..In• CA L-219 11966240 MDT ~ ~}- ~ 12/22/07 1 L-114A 11970807 LDL 12/30/07 1 L-116 11962777 LDL (- ( 12/31/07 1 V-211 12021135 MEM INJECTION PROFILE ~- a (~ 12/29/07 1 V-216 12021136 MEM INJECTION PROFILE 12/30/07 1 L-219 12017479 ISOLATION SCANNER CBL _ ~, 01!02108 1 P2-16 11975750 INJECTION PROFILE 12/31/07 1 F32 11970707 LDL - 01/04108 1 15-04B 12005202 MEM CEMENT BOND LOG 12/28/07 1 G-31A 11962778 SCMT j - C 01101/08 1 S-26 11978425 USIT 12129107 1 02-16C 11628793 MCNL 'a- ~ 08128/07 1 1 G-046 11628765 MCNL - ~ sl 04/06/07 1 1 K-02D 11209613 MCNL ~ rE L 07/21/06 1 1 17-07B 11649940 MCNL - ?~ / '- 02/17107 1 1 L2-28 11975742 RST = 12/05/07 1 1 Z-06 11968821 RST ~ - 12/13/07 1 1 PLtASt AGKNOWIEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 t," ~ 1'I _' 900 E. Benson Blvd. ~~ ^ ~ - ' " `-°' ,~, , ~ t' Anchorage, Alaska 99508 Date Delivered: ~„i;~~'~ ~". ~, ~~(~~!~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: j~ F-32 (PTD #1890330) Classified as Problem Well . All, Well F-32 (PTD #1890330) has been found to have sustained casing pressure on the IA. The TIO pressures were 2160/2170/150 psi on 05/17/07. The well has known tubing holes and was secured with aTTP. The plan forward for this well is as follows: 1. S: Pull TTP and Set WRP 2. F: CMIT-TxIA to 2000 psi 3. D: Bleed WHPs < 500 psi sGANNED MAY· 2 9 2007 A wellbore schematic has been included for reference. «F-32.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: F-32.pdf F-32.pdf . Content-Type: application/octet-stream Content-Encoding: base64 PfD~ Cs á- ,- g s1<p ~ L -<öo 4 î.t ) -'> I~l(f':::: "g 70 fS; J-A =- z.. ( 70 fS'.Ç ~\J;<jP , £ ß W F>: J 3 t. ~/2() KYtt f òìL (X'- Co ('1 Z- I of I 5/21/20079:58 AM TREE"" WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= I'v'lax Angle = Datum MD = Datum NO = 4-1/16" FMC McEVOY BAKER 6525' 3722' 4300' 60 @ 10700' 10385' 8800' SS 113-3/8" eSG, 72#, L-80, 10= 12.347" I Minimum ID = 3.725" @ 9720' 4-1/2" OTIS XN NIPPLE F-32 . 14-1/2" TBG, 12.6#, L-80. .0152 bpf. 10 = 3.958" 9732' ITOP OF 5-1/2" LNR I 9-5/8" eSG, 47#. L-SO, 10 = 8.681" I ÆRFORA TION SUMI\I1ARY REF LOG: SHCS ON 04/04/89 ANGLE AT TOP ÆRF: 53 @ 10050' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/S" 6 1 0050 - 1 0080 C 10/19/94 3-3/S" 4 10610 - 10650 C 07/05/90 I PBTDI 15-112" LNR. 17#. L-80. .0232 bpf, !O = 4.892" I I TO I DATE 04114189 /10/01 10/21/02 07/13/03 11/04/03 03116107 REV BY COMMENTS ORIGINAL COMPLETION RNlTP CORRECTIONS MHiKAK GLV C/O CMOlTLP I\I1AX ANGLE CORRECTION ?/TLP ADD ÆRF JEWELRY TO DRWG CJNlPAG SET PX TI PLUG @ 9699' DATE REV BY COMMENTS ~TES: 2078' 4-1/2" OTIS HXO SSSV NIP, 10 = 3.813" (04/14/89) GAS LIFT MANDRELS ST I\:1D ND DEV TYÆ VLV LATCH PORT DATE 5 2970 2905 1 I\I1ACCO DMY RK 0 10/21102 4 5217 5088 31 MACCO DMY RK 0 10/21/02 3 7688 6918 40 I\I1A ceo DMY RK 0 10/21/02 2 9406 8184 43 I\I1A ceo DMY RK 0 10/21/02 1 9547 8284 45 I\I1A ceo DMY RK 0 10/21/02 9612' -14-112" OTIS X NIP, ID = 3.813" I 9632' - TBG SEAL ASSY I 9648' -/9-5/8" OTIS PKR, ID = 3,85" I -]4-1/2" OTIS X NIP, 10 = 3.813" I - 4-112" HES PX TI PLUG SET (03/16/07) 9720' - 4-1/2" OTIS XN NIP, !O = 3.725" I 9732' - 4-1/2" OTIS TBG TAIL ID = 3.958" I 9730' H ELMD TI LOGGED 04/25/89 I 10187' -1SANDBACK WITH CEMENT eAP 10227' - rv1ARKERJOINT I PRUDHOE SA Y UNIT WELL; F-32 ÆRMIT No: "1890330 API No: 50-029-21930-00 SEC 2, T11 N, R13E, 2243' FNL & 2869' FEL BP Exploration (Alaska) MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, ~~\ DATE: March 27, 2001 Commissioner i~ Tom Maunder, ~o~,t~.~._.~:~ ~,' P. I. SUpervisor FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit BPX / F-Pad March 2,7,,,2001: I traveled to BPX's F-Pad in the Prudhoe Bay Field to witness Safety Valve System tests. Merv Liddeiow, BPX representative in charge of testing, performed the tests in a safe and proficient manner. Ofthe 24 wells tested, 13 failures were witnessed. Wells F-01 and F-15 were shut in pending repairs. Mr. Liddelow indicated to me that all other failures had been corrected and successfully re-tested within 24 hours. The AOGCC test report is attached for reference. ! conducted 24 well house inspections concurrent with the SVS tests, with no exceptions noted, SUMMARY; I witnessed SVS tests and conducted well house inspections on BPX's F-Pad in the Prudh°e Bay Field. '24 wells, 48 components tested. 13 failures. 27.08% failure rote.. 24 well house inspections conducted. ,A,,ttac, hments, ,: SVS PBU F Pad 3-27-01 JJ ,cc.: NON-CONFIDENT~L. SVS PBU F Pad 3-27-01 JJ © Alaska Oil and Gas Conservation Commissmn Safety Valve System Test Report OperatOr: BPX Submitted By: Jeff Jones Date: Operator Rep: ,.Mer~ L~ddelo,~ ' ' Field/Unit/Pad: ,PBF/PBU~-Pad , AOGCC Rep: '"~ff Jones Separator psi: LPS 153 " 3/27/01 650 Well Perm~ Separ Set L/P Test Tut Test Date off, WAG, GIN& Number Number PSI PSI Trip ,Code Code Code Passed GASor,CYCLE 'F-'oi' '~700460 ........ 650 " '550' 490 P 5 .... OIL F-02 ' 170'0~60 "650 550 530' P P .... OiL , i ~ , , i , il, , i i. i i i i F-03 1700580 F-04 1710020 F-05 171'06901 650 .... ~50' ' ~30 i 4 ' ' ' OIL F.06 .... 17101~0 ................. F-07 1720230: i 11 ,,, ~ , , , i , , , , i F,08 1740110 F-09 i7607601 "650!" 550 '5~0 P 4' ' ' OIL F-'IOA 2000670!' " ......... F-!IA .,'2006620"' 6~01' 5~0 ' 510' p" '4 ........ OiL F-12 1791070 680.85053O P P oil F-13A' ' 19~i520 65o 550 '' 53o P "4 ..... OIL F-i4 1806120 ..................... F-15 '1811300 650 '550 480 '~'3 P ...... OIL i i i i ~ i i . i . Ill I ii i F-16A 1961600 650 550 410 P P OIL F-17A 1941630 153 '125 130' P 'P ........ oil F~,19 , 1811060 ................ F-21 " 1890560 1'53 " 125 " 115" P P " ' ' OIL F-22 1890620 650 550 0 2 P OIL · . , i , i l! i I II I , I l F-23A 1990740 153 125 0 2 P OIL I i ... II II I I I I I I II I I I I II I I F.24 1831540 !F.26A' ~' 1981890 ................. F227 i'861660 ........ i .......... F-28 1861590 i , , i i , i , i , , ~ i i i i i ~ i i F-29 1861330 I I i i i I i i I I I I I I I I F-30 1891100 F'31 1861570 650 550 ' 0 2 P ........... 0IL F1890330 650 550 530 P ' P OIL F-33 1960030' F~3~X 1961090 ...................... F-35 ' ' 1'880810! '650 550 480 ' P " P ........ OIL F-36 1951960 153 125 0 2 p OIL .F-37 ' 1890990 , 650 '~50 530 , ,P P ",' ' , .,' .....OIL RJF 1/16/01 Page 1 of 2 SVS PBU F Pad 3-27-01 JJ1 Well Permit Separ Set L/P · Test Test Test Date oik wxG, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE · ' . , , , , , , , , , , i , . 11 I , ~1 I i i1 I , , F-38 1901350 F-39 1901410 153 125 115 P P OIL F.40 1911170 " ii50 . 550 550 P P OIL F-41 1911040 650 550 490 P P OIL F-42 ..... i90i580 ' 650 550 '.536' '? ' 'P. ' ....... OiL I I Il [ . I , I I [ I I I. Illl [Il I I I I I F-43 1910750 153- 1-25 0 1 P OIL F-44 1910080 ' ' ........... F-45 1910280 ¥-46' 1901780' 650" 550 ~0 3 P .......... 0IL . , i , il i , , , , I , , , , , F-47A 2000350 '. F-48 i'910860 " '~ ........... - ' I Il I I , , I , il i il , ill 11 [ I I l i i i i . i i ii i i i i iii ii i I i iii i i i i i Wells: , , 24 Components: 48 Failures: 13 Failure Rate: '27.08~]9o oay .. Remarks: F-1, F71'5 shut-in, operator rep, orts t ,ha, t all ot ,13er failurgs repaired and PaS, sqd,rcte~!, RJF 1/16/01 Page 2 of 2 SVS PBU F Pad 3-27-01 JJ1 MEMORANDUM State of Alaska Alaska Oil. and Gas Conservation Commission TO: Julie. Heusser, ~' ' DATE: COmmissioner THRU: P. I. Supervisor ~-~-~, . December 7, 2000 FROM: Jeff Jones, SUBJECT: Petroleum Inspector` Safety Valve Tests. Prudhoe Bay Unit BPX / F-Pad ThUrsday,'December 7t 2000:. I traveled to BPX's F-Pad in the Prudhoe Bay Field to witness Safety Valve System tests. Merv Liddelow, BPX representative in charge of testing, performed the tests in a Safe and Proficient manner. Of the 28 wells tested, 10 failures were witnessed. For the. most part,, frozen contamin, ants (w. ater) in the block valves upstream of the pilots and in the SSV hydraulic control lines caused the failures. On 1218/00 Mr. Liddelow.indicated" to me th~at aii SVS-failures had been correcte,d and' successfully-re-tested. The 17.8% .SVS failure rate requires a 90-day test cycle for this' pad.. The. AOGCC test report is attached for reference. I conducted. 28' well house inspections concurrent With the SVS tests.. Due to recent high winds,, several well houses were drifted with. Snow inside, In addition, SVS hydraulic fluid leaks were noted on wells F-12 and F-13A. Mr,. Liddelow indicated that these items would be addressed. No other exceptions were noted. SUMMARY: I witnessed SVS'tests and-conducted well house inspections on BPX's F'Pad in the Prudhoe Bay Field'. 17.8% failure rate = 90 day test cycle. 28 wells, 56 components tested, t0 failures. 17.8% failure rate. 28 well house, inspections conducted." " .Attachments: SVS PBU F pad 12-7-00 JJ CC: NON-CONFIDENTIAL SVS PBU F Pad 12-7-00 JJ.doc Alaska Oil and Gas Conservation CommiSSion Safety Valve System Test RepOrt Operator: BPX ' SUbmitted By: Jeff Jones Date: 12/7/00 Operator Rep: Merv Liddelow Field/Unit/Pad: PBF/PBU~ Pad AOOCC Rep: Jeff:Jones ' ,,. Separator psi: 'LPS 156 .lIPS 828 · Well Perm~ Separ' .- S~ · ' L/P ' Test Test Test Date, Oil, WAG, GINJ, Number Number PSI ' PSI, · T~P COde Code Code Passed GAS or CYCLE i F-01 1700460 828 550 525 P P OIL · F-02 .... 1700560 828 550! 50b '.'P 'P ' oIL F-03 1700580 ... F-04 1710020 - 156 125!'' 125 P P ..... OIL F-05 ' 1710090 . .. ' ':' '-. F-06. 17101.20 . " .' F-07 1720230 F-08 1740110 ... , F-09 · 1790760 · ' F-10A 2000670 ' '- · F-11A 2000620 828 550 500. P P 0IL F-12 1791070 '828' 550' '550 P P "' ' ' 0IL F-!3A 1961520 ~28 550 "525 P P ' oIL F-14- -1800120 · F-I~' 1811300' 828 550 '. 490 P P OIL F-I~A.. 1961600 156 .125 "0 I ' P' ' ' OIL F-17A 194-1630 156 · 125 130i P P '. " OIL .. F-19 · ' 1811060 ' ' F-21 1890560 156 " 125 '125 P. P. ' OIL F-22 1890620' i56 ' 1'25 125 P P '" " OIL F-23A 1990740 '156 ' 125 125 P P ' ' OIL F-24 1831540 , · ·,,, ....... F-26A 1981890 '.156 '125 - 125 P 4 OIL F-27.' 1861690 828' .550 ' '0' 1 P " ' 0IL F'28 .' 1861590 828 ' 550 500 P P OIL F-29 . 1861330 828 550 '' 2~0 'i 3 '~ ',, OIL F_30 · 1891100 -'1861570 ...... F,32 ~ 828 550 520 P' P .... OIL ,, , F-33'. .1960030 F-34A 1961090 .. F-3~- ' 1880810 . 828 ' '550l' 525 P' P ' OIL F-36 .... 1951960 828' '550 02 ' 'P " ' OIL F-3~ 1890990! 828 550. 550 P P. OIL ~ ~ , ~ ~, ,, , 12/1'3/00 Page 1 of 2 SVS PBU F Pad 12-7-00 JJ.xls · Well Permit Separ - Set 'L~ ' ' iTest ! ' Test ' Test Date · Oil, WAG, Number Number "Pm .. ..PSI' ' · Trip ·Code Code Code Passed GAS or ~YC~E F-38 ' 1901350 -- . / .- F-39 1901410 156 125. 12'5 P . 'p '1 ' " . F-40 19.11170 . 828 550, - 0 ' 1. '5 F-41 1911040 ~828 ~50~ 530 P P " Om F-42 1901'580 F-43 '-'1910750 '156 125~ '125' P P ....... Om ,., F-44 1910080 · .- · F-45 ' 1910280 ' 828 550' ~0 1 P Om F-46. 1901780 ~ 828 550' 50' : 3 P' : Om . F-47A 2000350 156 125'130' P.. P' om ~48.. 1910860 '~'156 'i'25' 100 'P P- ' ' om · · . - .. . .. . . . Wells: 28 Components: 56' Failures: 10 Failure Rate: 17.8%ffl 90 oar · Remarks: 12/13/00 Page 2 of 2 SVS PBU F Pad 12-%00 JJ.xls ON .OR BEFORE OCTOBER 24 200,_______0_0 I!; E W C:LOP.?,MFILM.DOC M-X T ERIA L U N D -- STATE OF ALASKA ~IL AND GAS CONSERVATION COMM REPOR _SUNDRY WELL O HATION$ 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2243' SNL, 2869' WEL, SEC. 02, T11N, R13E. UPM At top of productive interval 4777' SNL, 2231869' WEL, SEC. 34, T12N, R13E. UPM At effective depth 2747' SNL, 1182'WEL, SEC. 16, T11N, R12E. UMI At total depth 4269' SNL, 576'WEL, SEC. 34, T11N, R13E. UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Stimulate Alter casing 10849 feet BKBg041 feet 10849 feet BKB 9041 feet Plugging Repair well 5. Type of Well: Development X Exploratory Stratigraphic Sewice Plugs (measured) Junk (measured) Perforate 3( Other._~_ 6. Datum elevation (DF or KB) KBE = 65.25 AMSL 7. Unit or Property name Prudhoe Bay Unit 8. Well number F-32 (44-34-12-13) PBU 9. Permit number/approval number 89-33 / 10. APl number 50- 029-21930 11. Field/Pool Prudhoe Oil Pool Casing Length Size Cemented Structural -- Conductor ~ 110 20 3723 c.f. Surface 2652. ~. i 13-3/8 2118 c.f. Intermediate 10003 9-5/8 476 c.f. Production -- Liner · '1098 5-1/2 10849 c.f. Perforation depth: measured 10610'-10650' true vertical subsea 8919'-8939' Measured depth True vertical depth BKB 110 138 2680 2680 1O031 8661 9764-10975 8495-9170 Tubing (size, grade, and measured depth)' 4-.1/2'" 12.6#/ft. L-80 surface - 9632' with 4-1/2' tailpipe to 9732' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 9-5/8" OTIS PBR/packer at 9648'; 4-1/2" SSS V at 20 78' RECEI 14. Intervals treated (measured) MAY - 9 1995 Treatment description including volumes used and final pressure Representative Daily Average Production or In!ection Data ' ~chora~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure feet Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1057 9040 1536 1340 126 51 16. Status of well classification as: Oil X Gas Suspended . 0 1493 0 273 Sewice I 17. I hereby cgrtify that the foreg'dT~g is true, and correct to the best of my knowledge. I .', Form 10-404 ATE 10119/94 WELL F-32(44-34-12-13) Add erf/Frac Oneration The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 10050 - 10080" MD 10~3/94 A Hydraulic Fracture (Sag) was performed using the following fluids: FF~C Sand Lead prop Tail prop Design total pumped, behind pipe, behind behind pipe, Liner Sand, Job was IM I~ piper M# M~ M~ Tailoffr M# Flush 20.8 16.8 - 16.8 4 2.1 Ft of Estimated Final .-: ISIP, psi ISIP Incr Actual TSO, TSO, sand in sand top STP,. over sand:ped design, rnin Nolte Pipe .psi datafrac ~. ratio Plot ~ 9743 ' ~2231 ............ 1500 '~ none 28 ............. 7 8 Operational problems Comments no treesaver rubber left in hole. FLUIDS PUMPED DOWNHOLE INJ TEST: 323 Bbls DATA FRAC: 211 Bbls FRAC: 273 Bbls - ' 807 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME '200 'TOtal Diesel FLUID ADDITIVES BJ SPECTRA FRAC G4000 FLUID SYSTEM with 15 PPT silica flour and 40 PPG adomite regain in pad. No ESL. RECEIVED MAY -9 1995 0il & Gas Cons. Commission "~chora~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 26 October 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: _WELL - (43-01-11-12) f~~F-32 (44-34-12-13) DESCRIPTION i pOL/ccL' ~INAL' BL I POL/CCL RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 CCL/CHEMCUT FINAL BL 1 CCL/CHEMCUT RF SEPIA ECC No. Run # 1 3060.04 Run # 1 Run # 1 4123.03 Run # 1 Run # 1 4473.02 Run ~ 1 Run # 1 6042.07 Run # 1 Run # 1 6285.01 Run # i 5600 B Street Suite 201 ~chorage, AK 99518 Attn. Rodney D. Paulson ' -- Or F~.to (907) 563-7803 Received by: ~~;~.d~., /~~.~/ D~- LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHOP~GE AK, 99501. Date= 27 September 1994 RE= ~ Transmittal of Data Sent by= U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below= WELL £.,~Q-07 (12-14-11-13) ' [ . ~:)W-22 (44-15-11-12). - (24-21-11-12) .~S-02 (32-11-14) DESCRIPTION I PL/PROFILE FINAL BL i PL/PROFILE RF SEPIA i PFC/PERF FINAL BL I PFC/PERF RF SEPIA I PFC/PERF FINAL BL I PFC/PERF RF SEPIA I PL/PROFILE FINAL BL i PL/PROFILE RF SEPIA i PFC/PERF FINAL BL I PFC/PERF RF SEPIA I PDK/BORAX FINAL BL i PDK/BORAX RF SEPIA i PFC/PERF FINAL BL i PFC/PERF RF SEPIA ECC No. Run $ i 1291.03 Run $ i Run $ i 1991.06 Run $ I Run ~ i 3598.02 Run # I Run $ i 4473.01 Run ~ i Run $ i 5010.04 Run ~. i Run $ I 5803.06 Run # i Run $ i 6275.00 Run # i Please sign and return to= Atlas ~ces BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 10/29/90 T#:81617 Information Control Well Records LR2-1 ,BP CA~ED HOLE FINALS FROM: SUBJECT: Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564.4445. -.~2 TDT-P BORAX 10/07/90 # 1 10350-10788 SCH X-16 COMPLETION 10/20/90 #1 ~ 10258-10592 $CH RECEIVED NOV 0 5 1990 Alaska 0il & Gas COns. Commission Anchorage 1, Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS ARCHIVES OIL AND GAS CONSERVATION COM REPORT OF SUNDRY WELL OPERATIONS 1' Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing 2, Name of oPerator - I BP Exploration (Alaska) Inc... I 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2243' SN~ 2869' WEL, SEC. 02, T11N, R13E. UPM At top of productive interval 4777' SNL, 2231869' WEL, SEC. 34, T12N, R13E. UPM At effective depth 2747' SNI., 1182' WEL, SEC. 16, T11N, R12E. UMI At total depth 4269' SNL, 576' WEL, SEC. 34, T11N, R13E. UPM 12: Present well condition summary Total depth: measured 10849feet true vertical BKB 9041feet Repair well S. Type of Well: Explorami~ Stratigraphio Plugs (measured) Other , , 6. Datum elevation (DF or KB) KBE - 66.26 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number F-32 (44-34-12-13) PBU 9. Permit number/approval number 89-33 / 90-503 10. APl number 50- O29.21930 11. Field/Pool Prudhoe 011 Pool Effective depth: measured 10849feet true vertical BKB 9041feet Junk (measured) Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 110 20 3723 c.f. 110 138 Surface 2652 13-3/8 2118 c.f. 2680 ' 2680 Intermediate 10003 9-5/8 476 c.f. 10031 8661 Production -- Liner 1098 5-1/2 10849 c.f. 9764-10975 8495-9170 Perforation depth: measured 10610'-10650' true vertical subsea 8919'-8939' Tubing (size, grade, and measured depth) 4-1/2'" 12.6fl/ft. L-80 surface- 9632' with 4-1/2' tailpipe to 9732' Packers and SSSV (type and measured depth) i3. Stimulation or cement squeeze summary Intervals treated (measured) See 9-5/8" OTIS PBR/packer at 9648;' 4-1/2" SSSV at 2078' Attachment Treatment description including volumes used and final pressure Representative Daily Average Production or Inia~tion Data ' OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation .... 15. Attachments Copies of Logs and Surveys run Daily Repqrt of Well Operations X 117.1 hereby~tify that th~or~/~ing is true and correct I .Signed ~ 7~,) r~/~ 'Fo~ lo-4o4 Rev 0{/15/88 ~ 2670 19.9 890 4240 9.0 637 16. Status of well classification as: Oil X Gas Suspended to the best of my knowledge. Title sup~rv/e~r ar~v~y Drainage 0 1736 0 248 Service Date SUBMIT IN DUPLICATE WELL F-~I2 144.~14-12'1~1~ PBU COILED TUBING SQUEEZE OPERATION A GSO/WSO squeeze was done on well F-32 on July 5, 1990. Perforation Intervals squeezed where: 10610-10650' MK BKB Ran in hole with 3.4" swirl nozzle. Uquid packed well with filtered produced water and surfactant. Cool sump and perfs. Pumped 15 BBLS latex cement. First 7 BBL$ tagged with R/A isotope AU-198 for post squeeze GR logging. Well on vacuum. Wellhead pressure responded after 8 BBL$ out nozzle. Held In!rial squeeze pressure of 800 psi until BBL/BBL returns, then walked up to 1600 psi. Well drinking cement so shutdown and hesitated for 15 minutas. Wellhead pressure dropped linearly from 1600 to 500. Pressure tested squeeze. Lost 350 psi in 5 minutes. Jetted across perfs and down to flag. Revised clean to 10788' MD. Returned well to production and tested. mr:l 0/11/90 . BP EXPLORATION BP Exploration (Alas~) Inc, 900 East 8enson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-6111 TO: DISTRIBUTION Date :07/19/90 T#:81410 FROM' Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If.you have any questions, please contact BP Well Records at (907) 564-4~.5. B-06 GR/CCL 07/16/90 #1 8830-9049 Atlas 5" B-06 PFC 07/15/90 # 1 8500-9060.5 Atlas 5" '~-2 CL 07/15/90 #1 10177-10710 Atlas 5" Y-16 CL 07/17/90 #1 9250-9453 Atlas 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS A~CHiVES Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6812 (907) 561.5111 TO: DISTRIBUTION Date:07/19/90 T#:81406 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the matedal listed below. Well Records at (907) 564-4445. If you have any questions, please contact BP F-03 TEMP 07/07/90' #1 F-15 PROD-F 07/03/90 #1 ~J;~'2-~ TEM P/GR 07/06/90 # 1 G-13 PROD-F 07/09/90 #1 N-14 PITS 07/04/90 #1 S- 16 PITS' 07/05/90 # 1 10850-11155 CAMCO 5" 9300-9742 CAMCO 5" 10300-10802 CAMCO 5" 9100-9420 CAMCO 5" 9500-10124 CAMCO 5" 10500-11019 CAMCO 5" Distribution: ARCO CHEVRON EXXON GEOSClENCES MOBIL PHILLIPS RE§~~ ~S3'~ATE ARCHIVES ^.o APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ..... Alter casing . Repair well Change approved program ... '~. Name of operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Locaiion of well at surface 2243' SNL, 2869' WEL, Sec. 02, T11N, R13E, UPM At top of productive interval 4777' SNL, 231' WEL, Sec. 34, T12N, R13E, UPM At effective depth 2747' SNL, 1182 WEL, Sec. 16, T11N, R12E, UM! At total depth 4269' SNL, 576' WEL, Sec. 34, T11N, R13E, UPM i 12. Present well condition summary Total depth: measured 10849 feet true vertical BKB 9041 feet operation Shutdown . Re-enter auepended well Plugging Time extension Stimulate . Pull tubing .... Variance Perforate ~( Other X ..... 6. 'Datum elevatio~ (DF or KB) " KBE = 65.25 AMSL feet 5. Type of Well: Development x Explorato~/ Straligraphic Service 7. Unit or Property name Prudhoe Bay Unit ' 8. Wall number '" ~44,-34-12-13) PBU 9. Permit number 89.33 10. APl number' 50- 029-2193O ;I 1. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 10849 feet true vertical BKB 9041 feet Junk (measured) Casing Length Size Structural -- Conductor 110 20 Surface 2652 13 3/8 Intermediate 10003 9 5/8 Production -- Liner 1098 Perforation depth: measured true vertical subsea Cemented Measured depth True vertical depth BKB 3723 c.f. 110 138 2118 c.f. 2680 2680 476 c.f. 10031 8681 5 1/2 10849 c.f. 9764 - 10975 8495. 9170 10610'- 10650 RECEIVED Tubing (size, grade, and measured depth) 4-1/2" 12.6/lift, L-80 surface- 9632' with 4-1/2" tailplpe to 9732' Alaslm Oil & Gas Gons. Gomm[', Packers and SSSV (type and measured depth) 9-5/8" OTIS PBR /packer at 9648;' 4-1/2" SSSV at 2078' ~tr, ttora~l~ 13.'Attachments Description Summary of proposal x 14. 'Estimated date for commencing operation I H June 1990 16. ff proposal Was verbally approved ' ' Oil X Gas Name of apj;~pver , ~ Date approved Service ' 7[I hereby c~ that the fo~;l°~g/s true and correct to the best of' my knowledge' Signed '~~t~~_~ '~6/~~t 'l-~tleSupervisorGrav~Draina~7e ' ( ' 8 FOR COMMI,~SION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test . SUbsequent form required 10-"',~, 4- · m Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY Detailed' operations program ,11, BOP sketch 15. Stat~s of well classificeti~n as: .... Commissioner Approved Copy Suspended I APp.=v,, No.?,O ~ ~ Date ~/~/~0 SUBMIT IN TRIPLICATE WELL F-32 ¢44-34-12-13} PBU CTU CEMENT SQUEEZE PROPOSAL A coiled tubing cement squeeze of existing perforation is proposed as follows: 1. Perform pre-workover surveillance and clean out wellbore. 2. Rig up CTU and support equipment and preSsure test BOP's to 4000 psi. 3. Perform perforation acid wash and sump cleanout. 4. Pump ~cement and squeeze existing perforations. 5. Reverse out cement after squeeze is obtained. Wait overnight, then test squeeze by performing inflow test. if squeeze fails, immediately resqueeze. 6. If squeeze is successful, reperforate the following interval' 10610' - 10650' MD BKB - Ail depths are. referenced to BHCS 4/4/89. 7. Return well to production and test. /Ik1:6/21/90 RECE /£D FLOW TUBES & PACKOFF (.~~~ BOWEN ~KOFF ~- HAND PUMP GREASE SEAL FLOWTUBE FLOWLINE GREASE LINE RISER GREASE MANIFOLD GREASE PUMP -.-GREASE RESERVOIR .BOP RECEIVED JUN 2 ? Alaska Oil & 6as (ions. Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: HOUSTON ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS ARCHIVES DATE: 09/20/89 T$: 80377 BP FINAL DATA - PRESSURE SURVEY DATA Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. F~32~<~ Static Gradient 09/11/89 Camco R-12 Flowing Gradient 08/21/89 Camco S-03 Flowing Gradient 09/12/89 Camco T-01 Static Gradient 09/05/89 Camco W-04 Flowing Gradient 08/26/89 Camco W-09 Static Gradient 09/05/89 Camco W-40 Static Gradient 09/08/89 Camco X-12 Flowing Gradient 08/31/89 Camco Y-01 Flowing Gradient 08/30/89 Camco Information Control Well Records LR 2-1 J. Dietz/S. McCurry BP ~(PLORATION BP Exo;oratson (Alaska) Inc. 900 East Benson Boulevarcl Re. Box 196612 · Ancl~orage, Alasl(a 99619-6612 (907) 561.5111 To: Distribution Date: 09/21/89 Transmittal: 80382 From: Information Control Well Records LR2-1. · i. Subject: BP CASED HOLE FINAL LOGS ~ . : . Enclosed is your copy of the material .liSted below. "If you have any questions, please contact ~'~Well Re~ordS at (907) 564-4445. C-14 C-15 C-16 GC-1E R-01 W-32 W-32 W-32 Leak De, 09/14/89 Noise/Temp 09/13/89' Leak De, 09/14/89 TDT-P 09/12/89 Tubing Cutter 09/14/89 Plug Setting Rec 09/15/89 CCL/GR 09/14/89 CBT 09/14/89 CET 09/14/89 .. 9900-11700 Sch 8050-8400 Sch 1"/5" 7800-8300 $ch 5" 10050-10801 .Sch 5" 2200-2570 Sch 5" 8990-9400 Sch 8800-9272 Sch 9375-10185 Sch 5' 9375-10185 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS RESERVOIR ARCHIVES Alaska Oil & Gas Cons, C, ommisslQo Anchorage O~ 03 CERTIFICATE OF SURVEYOR Date ! hereby certify that lam properly registered to practice land surveying in the State of Alaska and that this plat · '·presents a location survey of the wellpad shown and the wells thereon. This survey was made by me or under my supervision and all dimensions and other details are correct. Bottom hole locations are furnished by others. PAD DETAIL '~"' SCALE: I"= 500' PORTION Of PROTRACTED T. II 8~ 12 N., R. 13 E. ~mtllissi.~.8.o9 Oil & Sas Gons. ~-' 5-5-89 Anchorage c... C.- "~m. 5- 30-86 I0- 6 ,,, ~, PJR 7- I - 81 P,JR 7- I -81 4.- 11-80 I- 14-80 I- 7-80 IllSCALE: = I/2 MILE PROTRACTED SEC E, T. I! N.,R. ISE.t UMIAT MERIDIAN, ALASKA~ Surveyed for SOHIO PETROLEUM CO. II Surveyed by F.M. LINDSEY 8~ ASSOC. LAND ~ HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-~)81 Anchoraae Alaska ADDED SURFACE LOCATION F-$7 ADDED PROPOSED BHL F-37 . AODED PROPOSED BH:L ADDED PROPOSED BHL F-Z7 ADDED PROPOSED BHL F-SI, DELETE CHL REVISED SURFACE LOCATIONS F-20, F-28, F-29 8, F-;O ADDED SURFACE LOCATIONS F'8 8~ ;-9(ACTIJAL$ ADDED PROPOSED BHL F-?.O,F-2$ ~ F-~.9 AODED REFERENCE TO PAD F EXTENSION TWO AOOED PROPOSED BH' [-' o.F-16, F-17, F-18.8~ FolS. REVISED PAD DETAIL TO SHOW SE EXTENSION. REV*SED BHL F- I0 THRU F- t4 TO ACTUAL 8800' 3UB SEA ADDED BOTTOM HOLE LOCATION F- 14 (PROPOSED) ADDED BOTTOM HOLE LOCATION F-13 (PROPOSED) REVISEO BOTTOM HOLE LOCATION F- t2 (PROPOSEO) RECEI D , " SEP 1 ~ l~J~ PAD "F" E XTE NSION'"' {, Loculed in ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELl COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well ClaSsification of Service Well OIL [] GAS r'l SUSPI~DED [] ABANDOI~D [] SERVICE r'l 2. Name of Operator 7. Permit Number Bp Exploration, 89-33 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 . so- 029-21930 4~ Location of well at surface 9. Unit or LeaSe Name ~;-:: ":: _l, . 2243' SNL, 2869' WEL, SEC. 2, T11N, R13E ,~ !.OCA~ Prudhoe Bay Unit . At Top Producing Interval . ~-~II=I~D 10. Well Number 4777' SNL, 231' WEL, SEC. 34, T12N, R13E ~ : ~ _ F-32 (44-34-12-13) 11. Field and Pool At Total Depth ~'1 AN' , -~ ' i Prudhoe Bay Field/Prudhoe Bay Pool 4269' SNL, 576' WEL, SEC. 34, ~ R13E. 5. Elevation in feet (indicate KB, DF, etc.) p. Lease Designation and serial No. ' KBE = 65.25' I ADL 28278 '12. 0ate' Spudded 13. Date T.D. Reached .... 14.'"'Date Comp., Suep: or Aband. 'i15. Water Depth, if ollehore 116. No. el Completions 03/21/89 04/05/89 04/14/89I N/A feet MSL. I One i7: Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 1'9. Directional Survey 120. Depth where SSSV eet '121. Thicknase of Permafrost 10975' MD / 9170' TVD 10849' MD / 9106' TVD YEs [] NO []I 2078feet MD 12029' 22. Type Eleciric or Oiher Logs Run DIL/BCS/CNS/GR ,,, 23. CASING, ENER AND CEMENTINGI / SETTING DEPTH MD ' CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT.PULLED 20" Conductor Surface 110' . . . 13-3/8" 72# L-80 ~'~ ~- SurfaCe 2680' 17-1/2" 3723 cuft ~rctic Set"ll & III 9.~/8' '47# L-80 Surface 10031' 12-1/4" 2118 Cu ft ClaSs G ....... 5-1/2" 17# L-80 9764' 10975' 8-1/2" 476 cu fl Class (3 , · · 24. Perforat'ions open to Production (MD+TVD of Top and Bottom and 25. 'FUBING RECORD inlerval, size and number) SIZE DEPIH SET (MD) ' PACKER SET (MD) Schlumberger 3-3/8" ~ 4 spf 4-1/2" 12.6# 9733' 9649' L-80 w/tailpipe MD TVDss .,s. ACID, ,FRACTURE, CEMENT E~3UEEZE, ETC. 10610' - 10650' 8919' - 8939' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13-3/8"x 9-,5/8" Down squeezed A.nnulus w/'1'75 BBLS Dry Crude. , , , 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lilt, etc.) , ' ~ .... April 29, 1989 . I Flowing. Date of Test Hours Tested PRODUCTION FOR" 31L'BBL G/~'S-MCF WATER-BBL ' CHOKE~.~. IGAS-OIL RATIO TEST PERE)D I~ : ·I , Flow Tubing Casing Pressure CALCULATED 01L-BBL' ' GAs-MCF · WATER-BBL OIL GRAVITY-AP! (corr) 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'I 'iZEIVED ' UN 0 5 ]989 Form 10'407 in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. SAG 10036' 8664' SHUBLIK A 10111' 8708' ZONE 4 10253' 8791' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 © BP EXPLORATION Rig: NABORS 18E Well: F-32 (44-34-12-13) Daily Drilling Report-- Prudhoe Bay Unit March 21, 1989 at 0600 hrs AFE # 120809 API: 50-029-21930 0600 Depth: 0 Day: -1 24- Hour Ftg: 0 AFE Amount: Current Amount: Current Operation: RU. Accepted rig at 1800 hrs. on 3-20-89. Mud Type: SPUD MUD WT: 8.6 SURVEY MD ANGLE VIS:90 PV: 16 YP: 20 FL: 14 DIRECTION TVD SECTION Solids: 2 Temp: °F COORDINATES DLS 0 5 '11989 ,alaska 011 & Gas Cons. Commission Anchorage ~ PERIOD OF CONFIDENTIALITY WELL NAME ~. o~ co~~o~, COMMENTS ]~.RPC.02 (05/89) DATE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 31, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn' Mr. C. V. Chatterton Well F-32 (44-34-12-13) Enclosed, in duplicate, is form 10-407, our Report of Well Recompletion for the above named well. This information reflects the current condition and status of the well. Also enclosed are two copies each of daily drilling reports, directional and gyroscopic surveys, and open hole logs. Yours .very truly, Drilling Engineering Supervisor JGV/KTH Enclosures (4) J. Bragg (MB 9-4) Well Records w/10 Well File RECEIVED JUN o 51.989 Naska 011 & Gas Cons. t~ommissbn ,, N~chorage © © BP EXPLORATION Daily Drilling Report , Prudhoe Bay Unit March 22, 1989 at 0600 hrs' Pig: NABORS 18E Well: F-32 (44-34-12-13) AFE # 120809 API: 50~029-21930 0600 Depth: 1356' Day: -2 24- Hour Ftg: 1346' AFE Amount: Current Amount: 'Current Operation: Drilling 17-1/2" hole. Spudded well 1030 hrs. 3-21-89 Drilled 17-1/2" hole to 1346'. Mud Type: SPUD WT: 9.4 SURVEY MD. ANGLE VIS:90 PV:21 DIRECTION TVD YP: 24 FL: 12.6 Solids: 7 Temp: ~F COORDINATES DLS BP EXPLOR~N Rig: NABORS 18E .Well: F-32 (44-34-12-13) - ~ Daily Drilling Report -- Prudhoe Bay Unit March 23, 1989 at 0600 hrs AFE # 120809 APl: 50-029-21930 AFE Amount: Curr~nt Amount: 0600 Depth: 2680' Day: 2 24- Hour Ftg: 1324' 'Current Operation: Running 13-3/8" casing. Drilled 17-1/2" to TD of 2680'. Mud Type: SPUD WT: 9.6 SURVEY MD ANGLE VIS: 84 pV: 18 DIRECTION TVD YP: 21 FL: 12.2 SECTION Solids: 9 Temp: 68 °F ¢OORDrNATES DLS BP EXPLORKrlON 'Rig: NABORS 18E Well: F-32 (44-34-12-13) Daily Drilling Report -- Prudhoe Bay Unit March 27, 1989 at 0600 hrs AFE # 120809 API: 50-029-21930 AFE Amount: Current Amount: 0600 Depth: 5601' Day: 6 72- Hour Ftg: 1021' Current Operation: Drilling 12-1/4" hole. Cemented 13-3/8" casing at 2661'. Drilled · 12-1/4" hole to 5601'. Mud Type: LIT. DISP. ~,URVEY MD WT: 9.3 VIS: 36 PV: 9 ANGLE DIRECTION TV])_ YP: 6 FL: 9.2 SECTION Solids: 7.5 Tcmp: 78'F (~OORDINATES DLS RE 'EiVED 'JUN o 5 t9~9 Alaska 011 & Gas Cons. Commission Anchorage BP EXPLORATION © , © Daily Drilling Report-- Prudhoe Bay Unit March 28, 1989 at 0600 hrs Rig: NABORS 18E · Well: F-32 (44-34-12-13) AFE # 120809 APE 50-029-21930 AFE Amount: Current Amount: Current Operation: 0600 Depth: 6305' Day: 7 24- Hour Ftg: 704' POOH to mn Dyna Drill. Drilled 12-1/4" hole to 6195'. Mud Type: GEL/RESX SURVEY MD WT: 9.6 VIS: 46 PV: 8 ANGLE DIRECTION TVD YP: 10 FL: 6.0 SECTION Solids: 9.5 Temp: 82 °F COORDINATES DLS BP EXPLORATION Daily Drilling Report-- Prudhoe Bay Unit March 29, 1989 at 0600 hrs ?.ig: NABORS 18E ~ell: F-32 (44-34-12-13) AFE # 120809 API: 50-029-21930 2_re'rent Operation: 0600 Depth: 6695' Day: 8 24- Hour Ftg: .390' Drilling I2-1/4" hole. Run dyna drill. Drilled 390 feet to TD of 6695'. AFE Amount: Current Amount: Mud Type: GEL/RESX WT: 9.5 VIS: 43 PV: 8 ANGLE DIRECTION YP: 11 FL: 5.4 Solids: 9.5 Tcmp: 80°F COORDINATES DLS BP EXPLORATION ?dg: NABORS 18E Nell: F-32 (44-34-12-13) Daily Drilling Report -- Prudhoe Bay Unit March 30, 1989 at 0600 hrs AFE # 120809 API: 50-029-21930 AFE Amount: Current Amount: 0600 Depth: 7801' Day: 9 24- Hour Ftg: 11'06' _~m'rent OperatiOn: Drilling 12-1/4" hole. Drilling 12-1/4" hole at 7801'. .Vlud Type: GEL/RESX WT: 10.0 VIS:48 , PV:20 ANGLE DIRECTION ,TVD YP: 15 FL: 5.0 SECTION Solids: 9 Temp: 82 °F COORDINATES DLS BP EXPLOR~N Kig: NABORS 1SE '~ Welh F-32 (44-34-12-13) Daily Drilling Report -- Prudhoe Bay Unit March 31, 1989 at 0600 hrs AFE # 120809 API: 50-029-21930 AFE Amount: Current Amount: 0600 Depth: 8851' Day: 10 24- Hour Ftg: 1050' Current Operation: Drilling. Drilled 12-1/4" hole to 8851'. Mud Type: LIGNO WT: 9.8 VIS: 36 PV: 12 ANGLE DIRECTION TVD YP: 8 FL: 5.8 SoUds: 9 Tcmp: 81W COORDINATES DLS .,. JUN o 5 t9 9 ~laska 0~[ & (las ~$' Commi~aioa BP EXPLOR~N Daily Drilling Report .- Prudhoe Bay Unit April 3, 1989 at 0600 hrs Rig: NABORS 18E Well: F-32 (44-34-12-13) AFE # 120809 API: 50-029-21930 AFE Amount: Current Amount: 0600 Depth: Day: 72- Hour Ftg: ; · ~ Current Operation: Drilling out 9-5/8" casing shoe. 10040' 13 1185' Drilled 12-1/4" to TD of 10040'. Ran and cemented 9-5/8" casing. Tested BOP. Mud Type: LIGNO WT: 9.0 SURVEY MD ANGLE VIS: 33 PV: 5 YP: 1 FL: ,,,D, mECTtON TVD SEC'rtON Solids: T~mp: °F COORDINATES DLS BP E~"I. ORN~N Daily Drilling Report .- Prudhoe Bay Unit April 4, 1989 at 0600 hrs ig: NABORS 18E 7ell: F-32 (4~-34-12-13) AFE # 120809 API: 50-029-21930 AFE Amount: Current Amount: 2urrent Operation: Drilling 8-1/2" hole. 0600 Depth: 10685' Day: 14 24- Hour Ftg: 645' 'vlud Type: LIG 3URVE¥ MD, . . WT: 9.0 VIS: 36 PV: 7 YP: 5 ANGLE .DIRECTION FL: 6.0 SECTION Solids: 8.8 Temp: °F COORDINATES DLS © BP EXPLORNION }Zig: NABORS 18E Well: F-32 (44-34-12-13) Daily Drilling Report-- Prudhoe Bay Unit April 5, 1989 at 0600 hrs AFE # 120809 API: 50-029-21930 AFE Amount: Current AmOunt: Current Operation: 0600 Depth: 10900' Day: 15 24- Hour Ftg: 215' Logging 8-1/2" hole. , Drilled 8-1/2" to 10900'. RU logging co. Mud Type: LIGNO WT: 9.0 VIS: 38 PV: 8 /~NGLE DIRECTION TVD YP: 7 FL: 6.0 Solids: 9 Temp: COORDINATES .86~F ,JUN o 5 t9 9 Alaska Oil & Gas ConS, Commission Anchorage © BP EXPLOR,M'ION fig: NABORS 18E Well: F-32 (44-34-12-13) Daily Drilling Report -- Prudhoe Bay Unit April 6, 1989 at 0600 hrs AFE # 120809 API: 50-029-21930 APE Amount: Current Amount: 0600 Depth: 10975' Day: 16 24- Hour Ftg: 75' Current Operation: Cement 5-1/2" liner. Drilled to TD 10975'. RIH with 5-1/2" liner. Mud Type: :OGMP WT: 9.0 VIS: 39 PV: 10 ~ MD ANGLE DIRECTION TVD YP: 8 FL: 6 SECTION Solids: 9 Temp: COORDINATES BP EXPLOR~N Daily Drilling Report -- Prudhoe Bay April ?, 1989 at 0600 hrs Unit Rig: NABORS 18E Well: F-32 (44-34-12-13) ~ AFE # 120809 API: 50-029-21930 AFE Amount: Current Amount: 0600 Depth: 10975' Day: 17 24- Hour Ftg: 0 Current Operation: i Mud Type: LIGNO · : Clean out 5-1/2" liner. Cement 5-1/2" liner. WT:9.1 VIS: 35 PV: 8 DIRECTION TVD YP: 2 FL: 10.4 SECTION Solids: 9.5 Tcmp: 74~F COORDINATES DLS © Daily Drilling Report-- Prudhoe Bay Unit April 10, 1989 at 0600 hrs Rig: NABORS 18E :Well: F-32 (44-34-12-13) AFE # 120809 API: 50-029-21930 AFE Amount: Current Amount: Current Operation: 0600 Depth: . 10975' Day: 20 72- Hour Ftg: 0 Drill out cement in 5-1/2" liner. Tested liner lap to 3000 psi - OK. Drilled cement to 9769'.. Twisted off collar connection.. Trip in hole with fish assembly. Rec. fish. Mud Type: LIGNO WT: 9.3 VIS: 44 PV: 9 YP: 5 FL: 14.2 Solids: 9.5 Temp: ANGLE DIRECTION TVD ~ COORDINATES © BP EXPI.OR.41'ION Rig: NABORS 18E Well: F-32 (44-34-12-13) Daily Drilling Report -- Prudhoe Bay Unit April 11, 1989 at 0600 hrs AFE # 120809 API: 50-029-21930 AFE Amount: Current Amount: Current Operation: 0600 Depth: 10975' Day: 21 24- Hour Ftg: 0 Milling out 5-1/2" liner. Drilled cement to 10500'. Mill out top of liner hanger. Mud Type: LIGNO SURVEY MD, WT: 9.~4 VIS: 44 PV: 9 ANGLE DIRECTION TVD YP: 5 FL: 14.2 SECTION Solids: 9.5 Temp: °F COORDINATES DLS BP EXPLOR~N Daily Drilling Report .- Prudhoe Bay Unit April 12, 1989 at 0600 hrs I~dg: NABORS 18E Well: F-32 (44-34-12-13) . AFE # 12O809 API: 50-029-21930 0600 Depth: 10975' Day: 22 24- Hour Ftg: 0 AFE Amount: Current Amount: Current Operation: Drilling cement in 5-1/2" liner. Milled through liner hanger. Drilled cement to 10635'. Mud Type: LIGNO WT: 9.6 VIS: 46 PV: 11 YP: 6 FL: 15 ~ MD ANGLE DIRECTION TVD ~ Solids: 9.5 Temp: COORDINATES BP EXPI.OR.4rlON © © Daily Drilling Report -- Prudhoe Bay Unit April 13, 1989 at 0600 hrs Rig: NABORS 18E Well: F-32 (44-34-12-13) AFE # 120809 API: 50-029-21930 0600 Depth: 10849' Day: 23 24- Hour Ftg: 0 AFE Amount: Current Amount: Current Operation: Displacing with sea water. Drilled out cement to landing collar at 10849'. Tested liner lap to 3000 psi. - OK. Mud Type: LIGNO WT: 9.6 VIS: 45 PV: 11 YP: 6 FL: 15 Solids: 9.5 Temp: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS Daily Drilling Report-- Prudhoe Bay Unit April 14, 1989 at 0600 hrs Rig: NABORS 18E Well: F-32 (44-34-12-13) AFE # 120809 API: 50-029-21930 0600 Depth: 10849' Day: 24 24- Hour Ftg: 0 AFE Amount: Current Amount: Current Operation: Nipple down BOPE. Tested 5-1/2" liner, lap and 9-5/8" csg to 3000 # - OK. RU and nm 4-1/'2" tbg. Mud Type: SEAWATER WT: 8.5 ~ MD. ANGLE VIS: PV: YP: DIRECTION TVD FL: Solids: Temp: °F ~ COORDINATES DLS BP E~Qq.OR~N Rig: NABORS 18E Well: F-32 (44-34-12-13) Daily Drilling Report -- Prudhoe Bay Unit April 17, 1989 at 0600 hrs AFE # 120809 API: 50-029-21930 AFE Amount: Current Amount: Current Operation: Mud Type: SURVEY 0600 Depth: 10849' PBTD Day: 25 24- Hour Ftg: 0 Rig released @ 1200 hrs. 4-14-89. Installed and tested tree. Set packer. Displaced tubing to diesel. WT: VIS: PV: YP: FL: ANGLE DIRECTION TVD ~ECTION Solids: Temp: °F COORDINATES DLS BP EXPLORATION PAD F (44- 34-12-13) F $2 Controlled LES HENDERSON (907) 333-1552 Drilling Consultants, Inc. HORIZONTAL VIEW B.P. EXPLORATION WELL F-:~. (44- ~a1,-12 -15) RADIUS OF CURVATURE MAGNETIC SINGLE ~I'IOT ~5GALE: I"=!000' t~RIL '4~ · ! !. ~ . . , : . - ~-: · : ';'?', ........ : :'-~ i · B P. EXPLORATION HAGHETIC SINSLE SHOT SURVEY -..R..~D!U$ OF CURVATURE HETHOD ~n~PUTEn ~ne rnr ~¥ ~CTIC SLOPE-rnae~L-T-[~--GROUP ....... JOB NO ~0389019 WELL F-32 OF COMPU~T[ON ............................... KB ELEV 65,25 F~, SURVEY O~i-TE !9703/89 D!R H45-45g · TOTAL COORD!N~TE$ CL 0 SlJR~ S D M -S ~00 $ -- 2:56 N ! :49 ~..t ~.,93 E : 44 -1--. 77 -X- ....... 2,02 ~ 7:44 S 8-5~ 2,69 N 48 47 ~,79 N ~"~l 22 ~ 2.777 t7 ~ 48:83 N 48 3~ 40 a_ 2,84~ N45,SOi,J'.~~-.-]~ -.242:68 ~- 325:05 N 4R ~7 42 t,l 2,399 942 ~:r47 , O0 -2 , 27 2.3i · ~ 69_ c, 48,77 7 ~. R~ 99:99 t~.:~ ,9~, 199. g4 '"3a 05 279.9~ SOHIO WELL F-32 SIHGLE SHOT SURVEY dOB BIO A038~019 COMPUTER- 04 APP.. :39 KB ELEV 65 '~S FT DOG LEG C L 0 $ U R £ S D ! $ T.~.HCE ANGLE D H S SEYER!TY . DEG/!OeFT DISTANCE ,2~9 .:~e3 · :9!4 374,4 3 ~25. 986,94 !~07.27 456,6.4 ..L:.. 750 2 t 59 ,. 85 ,,g75 SOHIO WELL F-32 SINGLE SNOT SURVEY JO8 NO ~0~89019 COMPUTER- KB ELEV 04 RPR 65 2~ FT 99 __ DEPTH 265. 209 0 0 399 --~ 0 50~-- 0 0 ~0~ -- 0 ........................ 0 ~. Ft, ! ! 9e --4) 0 ! on,-, 0 n ~,, :q~ v ..................... v 0 29~5 29~5 , , , O-.O- N :97 1,36 J,72 2, ! 7- l,J 3,40 3,74 4,!9 4 7,37 8,23 8,~2 8: 3,,11 1 , ,49 t~... i. 74 J,99 2,40 2,9~ 7, ~.~ ,42 SOHIO WELL F-32 MEASURED DEPTH SINGLE SHOT SURVEY AND OTHER DATA FOR EVERY-EVEN !OO--EEErT--OF NO A0389013 SUB- SEA DEPTH: CONPUTER- K8 ELEV 04 65.25 APR 89 FT. .,~i VE~T!O~L SUB HD-TYD .................. ~ O,EPTN SEA D!FFERENCE-- CORRECT!ON ~!88 - 0 O --0 0 0 0 0 O ! -I 2 5 3- 4 6 4?,6.5; 47 O0 20 7!28 7395 7~27 59~5. 59 0 O 335 6265,., ~200 454 6~6~, 6~00 492 65~-5. ~SOO 563 6'~65. 6600 -597 6765, ~700 ~30 .8 9 !2 .-,2'0 27 37 38 39 35 34 ~3 32- 2:43 N 06 E 2:~.-_"2' H .88 W 2=27 N 5:60 W 7:76 H !!~54 W !7:_~2 N ~0,07, W' 29:08 H ~'_),79 iii 6!,78 H 71.g3 W 8_~:0! N 96;56 W ~_04~'81 N !23,20 W !3!:33 N J53:.00 U !62:00 H ~.86,0~ !96,68 N 222,45 >_36= 89 H ~63.,70 2_85:04 H 3!0,66 342,37 H ~6~9 408,:9~ N 4~.09 479;56 H 48~,09 55!,57 N 546:72 623,7! H 607,~6 696=57 H 667,~9 834,54 ,N 80~,9~ 896:09 N 880,80 955;!8 N 956:84 067-,26 N ' !!05:84 ~2!,06 N ~!78,60 ~74.3~ N, -~250:09 227,30 N '~320,24 278.84 N ~,388,92-' 330,82 N !456,72 SOHIO [~ELL F-32 -!'!E~SURED DEPTH SINGLE SNOT SURVEY JOB NO R0389019 AND OTHER DATA FOR EVERY EVEN I-OO.--FEET--OF--.SUB-~ DEPTH, CONPUTER- KB ELEV 04 APR 65,25 FT, 89 TRUE r 'DEPTH SUB ND-TVD VERT!CRL TOTAL COORDINATES ?200 ?92 32 33 34 3? 37 37 37 3~ -36 !449; ?fl__ N !59! !56_'3,47 N !?~_4,55,W ! 6'>_9: 4 !..N ! 764, !3 N ! ~. 896:66 N ! 962, ! 2!.60.69 N 2307,~3 W ~3~=42 N ~374:40. 23~6,89 N 2447~ 250!,~5 N 260'0~i5 34 36 55 SOHIO tJ£LL F-32 SINGLE SHOT SURVEY ,JOB NO R0389019 COMPUTER- KB ELEV 04 APR ~,5, '25 FT, ~PPTH DEPTH SE~ .........-TOT-WA.~ .... 6OORD !.I!AT-ES .n 3000 · 0, --65. 2000. !935. 3ee~. 2935. 496_3. 4897. 7222. 7!57. ?954. 8648. 8583, Mr. Michael D. Martin BP Exploration P.O. Box 196612 Anchorage, Alaska 99519-6612 May 15, 1989 Re: Our BOSS Gyroscopic Survey Job No. AK-BO-90044 Well: F-32 Prudhoe Bay Survey Date: April 29, 1989 Operator: D. Harger Mr. Martin: Please find enclosed the "Original" and sixteen (16) copies of our BOSS Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services Enclosures RE'EEiVED LIUN 0 5 t.9 9 Alaska 0il & Gas C, ons. Commission 8537 Corbin Drive (99507) · RO. Box 231649 · Anchorage, Alaska 99523 Anchorage (907) 267-0200 · Fax (907) 522-3432 A Baroid Company BP EXPLORATION INC. F-32 PRUDHOE BAY ALASKA COMPUTATION DATE: 5/ 3/1989 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA DOS :APRIL 29, 1989 BOSS GYROSCOPIC SURVEY JOB NUMBER AK-BO-90044 KELLY BUSHING ELEV. = 65.25 FT. OPERATOR: D. HARGER PAGE i TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DLS TOTAL RECTANGULAR COORDINATE VERTCAL DG/100 NORTH/SOUTH EAST/WEST SECTION 0 .00 100 100.00 200 200.00 300 300.00 400 400.00 -65.25 0 0 N 0. 0 E 34.75 0 11 S 3.19 W 134.75 0 10 S 13.10 W 234.75 0 15 S 16.60 W 334.75 0 33 S 30.10 W .00 .00 .00 .00 .19 .17 S .01 W -.12 .03 .48 S .05 W -.32 .07 .85 S .15 W -.52 · 32 1.48 S .46 W -.78 500 499.99 600 599.99 700 699.98 800 799.98 900 899.98 434.74 0 27 S 61.69 W 534.74 0 28 S 65.19 W 634.73 0 28 S 75.30 W 734.73 0 24 S 47.39 W 834.73 0 22 S 41.89 W .29 2.09 S 1.06 W -.82 .04 2.46 S 1.79 W -.60 .08 2.74 S 2.57 W -.28 · 22 3.08 S 3.23 W -.09 .06 3.57 S 3.71 W -.12 1000 999.98 934.73 0 19 S 57.10 W 1100 1099.98 1034.73 0 21 S 71.89 W 1200 1199.97 1134.72 0 23 S 74.50 W 1300 1299.97 1234.72 0 16 N 63.60 W 1400 1399.97 1334.72 0 19 N 78. 0 W .10 3.96 S 4.16 W -.10 .09 4.20 S 4.68 W .07 .04 4.39 S 5.30 W .35 .26 4.38 S 5.84 W .73 .09 4.21 S 6.32 W 1.17 1500 1499.97 1434.72 0 12 N 11.20 W 1600 1599.97 1534.72 0 10 N 31.29 W 1700 1699.97 1634.72 0 18 N 15.80 E 1800 1799.97 1734.72 0 27 N 53.59 E 1900 1899.96 1834.71 0 36 N 49. 9 E .31 3.98 S 6.63 W 1.56 .08 3.67 S 6.75 W 1.86 .22 3.29 S 6.75 W 2.14 · 28 2.81 S 6.36 W 2.24 .15 2.23 S 5.65 W 2.18 2000 1999.95 1934.70 1 9 N 53.20 E 2100 2099.93 2034.68 1 10 N 60.20 E 2200 2199.91 2134.66 0 58 N 62.59 E 2300 2299.90 2234.65 0 43 N 55.50 E 2400 2399.89 2334.64 0 39 N 48.79 E · 56 1.28 S 4.45 W 2.06 .14 .16 S 2.74 W 1.73 .21 .74 N 1.10 W 1.29 .27 1.48 N .17 E .98 .11 2.21 N 1.12 E .88 2500 2499.89 2434.64 0 33 N 48. 9 E 2600 2599.88 2534.63 0 45 N 27.70 E 2700 2699.87 2634.62 0 51 N 16.70 E 2800 2799.86 2734.61 0 39 N 33. 9 E 2900 2899.85 2834.60 0 43 N 26.89 E .09 2.91 N 1.91 E .86 .31 3.83 N 2.58 E 1.07 .18 5.13 N 3.10 E 1.68 .30 6.33 N 3.63 E 2.21 .11 7.37 N 4.23 E 2.57 3000 2999.85 2934.60 0 36 N 35.90 E 3100 3099.84 3034.59 0 24 N 22. 0 E 3200 3199.84 3134.59 0 24 N 29.70 E 3300 3299.84 3234.59 0 15 N 11.10 W 3400 3399.84 3334.59 0 10 N 64.10 W .17 8.36 N 4.82 E 2.90 .23 9.12 N 5.26 E 3.16 .06 9.75 N 5.57 E 3.42 .27 10.28 N 5.70 E 3.72 · 21 10.57 N 5.51 E 4.06 3500 3499.84 3434.59 0 7 N 5.70 W 3600 3599.84 3534.59 0 14 N 5.29 W 3700 3699.84 3634.59 0 18 N 50.10 W 3800 3799.83 3734.58 0 15 N 81.29 W 3900 3899.83 3834.58 0 12 N 66.79 W .16 10.74 N 5.36 E 4.29 .12 11.06 N 5.33 E 4.54 · 21 11.43 N 5.11 E 4.96 .16 11.63 N 4.70 E 5.39 .08 11.74 N 4.32 E 5.72 BP EXPLORATION INC. F-32 PRUDHOE BAY ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA DOS :APRIL 29, 1989 BOSS GYROSCOPIC SURVEY JOB NUMBERAK-BO-90044 5/ 3/1989 PAGE 2 KELLY BUSHING ELEV. ~ 65.25 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DLS TOTAL RECTANGULAR COORDINATE VERTCAL DG/100 NORTH/SOUTH EAST/WEST SECTION 4000 3999.81 3934.56 1 46 N 32.10 W 4100 4099.65 4034.40 4 27 N 33.26 W 4200 4199.15 4133.90 6 47 N 36.60 W 4300 4298.14 4232.89 9 27 N 43.29 W 4400 4396.34 4331.09 12 15 N 47.89 W 1.62 13.12 N 3.33 E 7.41 2.68 17.69 N .38 E 12.77 2.35 25.68 N 5.28 W 22.49 2.83 36.41 N 14.44 W 36.59 2.93 49.52 N 27.96 W 55.38 4500 4493.49 4428.24 15 7 N 47. 0 W 4600 4589.46 4524.21 17 26 N 48.20 W 4700 4684.55 4619.30 18 35 N 48.10 W 4800 4778.61 4713.36 21 1 N 47. 0 W 4900 4871.15 4805.90 23 27 N 46.10 W 5000 4962.03 4896.78 25 47 N 45.39 W 5100 5051.28 4986.03 27 48 N 44.79 W 5200 5138.43 5073.18 30 54 N 43.39 W 5300 5222.53 5157.28 34 33 N 41.89 W 5400 5303.41 5238.16 37 28 N 41.10 W 5500 5380.81 5315.56 41 4 N 40.39 W 5600 5454.95 5389.70 43 12 N 40.20 W 5700 5527.53 5462.28 43 43 N 40.10 W 5800 5599.90 5534.65 43 33 N 39.39 W 5900 5672.38 5607.13 43 31 N 39.29 W 6000 5745.07 5679.82 43 13 N 39.10 W 6100 5817.68 5752.43 43 39 N 38.79 W 6200 5889.91 5824.66 43 50 N 38.60 W 6300 5961.61 5896.36 44 32 N 40.10 W 6350 5997.06 5931.81 45 7 N 43.60 W 6400 6032.29 5967.04 45 17 N 47.50 W 6500 6103.13 6037.88 44 29 N 50.10 W 6600 6174.76 6109.51 44 0 N 50.50 W 6700 6246.98 6181.73 43 31 N 50.60 W 6800 6319.62 6254.37 43 18 N 50.79 W 6900 6392.65 6327.40 42 52 N 50.89 W 7000 6466.23 6400.98 42 22 N 51.10 W 7100 6540.12 6474.87 42 19 N 51.10 W 7200 6614.33 6549.08 41 51 N 51.29 W 7300 6689.08 6623.83 41 22 N 51.50 W 2.88 65.54 N 45.39 W 78.97 2.33 84.43 N 66.10 W 106.90 1.15 105.06 N 89.14 W 137.67 2.47 127.94 N 114.12 W 171.43 2.45 153.98 N 141.59 W 209.18 2.35 183.06 N 171.42 W 250.78 2.04 214.88 N 203.35 W 295.81 3.17 250.11 N 237.44 W 344.82 3.74 289.89 N 274.04 W 398.88 2.95 333.94 N 312.99 W 457.66 3.63 381.89 N 354.29 W 520.92 2.14 433.05 N 397.68 W 587.95 .51 485.63 N 442.03 W 656.68 .51 538.69 N 486.16 W 725.60 · 08 591.97 N 529.84 W 794.39 · 34 645.19 N .49 698.66 N · 23 752.63 N 1.26 806.52 N 5.07 832.77 N 573.25 W 862.95 616.47 W 931.57 659.71 W 1000.57 703.91 W 1070.16 727.42 W 1105.40 5.55 857.61 N 2.01 904.10 N .56 948.67 N · 49 992.62 N · 25 1036.15 N 752.75 W 1140.82 805.83 W 1210.97 859.52 W 1280.11 912.93 W 1348.60 966.11 W 1416.64 · 45 1079.28 N 1019.09 W 1484.24 .51 1121.90 N 1071.72 W 1551.22 .05 1164.21 N 1124.15 W 1617.85 .49 1206.21 N 1176.39 W 1684.12 .50 1247.65 N 1228.30 W 1749.75 7400 6764.23 6698.98 41 10 N 51.60 W 7500 6839.88 6774.63 40 30 N 51.89 W 7600 6915.96 6850.71 40 24 N 51.50 W 7700 6992.21 6926.96 40 13 N 50.79 W 7800 7068.05 7002.80 41 7 N 49.29 W .21 1288.67 N 1279.97 W 1814.91 .70 1329.16 N 1331.33 W 1879.47 · 28 1369.38 N 1382.25 W 1943.54 .49 1409.96 N 1432.64 W 2007.51 1.34 1451.82 N 1482.59 W 2072.12 BP EXPLORATION INC. F-32 PRUDHOE BAY ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA DOS :APRIL 29, 1989 BOSS GYROSCOPIC SURVEY JOB NUMBER AK-BO-90044 5/ 3/1989 PAGE 3 KELLY BUSHING ELEV. = 65.25 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DGMN DEGREES DLS TOTAL RECTANGULAR COORDINATE VERTCAL DG/100 NORTH/SOUTH EAST/WEST SECTION 7900 7143.35 7078.10 41 10 N 48.20 W 8000 7218.20 7152.95 41 53 N 47.20 W 8100 7292.25 7227.00 42 33 N 45.10 W 8200 7365.65 7300.40 43 0 N 43.50 W 8300 7438.43 7373.18 43 35 N 43.10 W .73 1495.21 N 1532.07 W 2137.55 .97 1539.83 N 1581.11 W 2203.58 1.56 1586.39 N 1629.56 W 2270.64 1.17 1634.99 N 1676.98 W 2338.52 .65 1684.90 N 1724.01 W 2407.09 8400 7510.86 7445.61 43 35 N 43.29 W 8500 7583.40 7518.15 43 24 N 43.39 W 8600 7656.29 7591.04 43 1 N 43.29 W 8700 7729.30 7664.05 43 11 N 43.39 W 8800 7802.36 7737.11 42 55 N 43.70 W .14 1735.16 N 1771.21 W 2476.04 .20 1785.21 N 1818.46 W 2544.86 .39 1835.00 N 1865.46 W 2613.32 .18 1884.69 N 1912.37 W 2681.65 .33 1934.18 N 1959.41 W 2749.91 8900 7875.56 7810.31 42 57 N 43.89 W 9000 7948.52 7883.27 43 20 N 43.60 W 9100 8021.76 7956.51 42 28 N 42.70 W 9200 8095.87 8030.62 41 52 N 41.70 W 9300 8170.44 8105.19 41 41 N 40.70 W .14 1983.35 N 2006.56 W 2818.03 .43 2032.75 N 2053.86 W 2886.40 1.06 2082.41 N 2100.42 W 2954.47 .89 2132.15 N 2145.51 W 3021.61 .69 2182.28 N 2189.40 W 3088.22 9400 8244.14 8178.89 43'19 N 40.89 W 9500 8315.80 8250.55 45 7 N 41.10 W 9600 8385.20 8319.95 46 58 N 41.29 W 9700 8452.42 8387.17 48 32 N 39.89 W 9800 8517.66 8452.41 49 59 N 39.29 W 1.65 2233.43 N 2233.55 W 3155.75 1.80 2286.06 N 2279.31 W 3225.47 1.86 2340.21 N 2326.72 W 3297.43 1.89 2396.42 N 2374.88 W 3371.40 1.51 2454.81 N 2423.18 W 3447.08 9900 8580.96 8515.71 51 27 N 38.10 W 10000 8642.49 8577.24 52 34 N 36.39 W 10100 8702.05 8636.80 54 17 N 36. 0 W 10200 8760.09 8694.84 54 45 N 35.79 W 10300 8817.24 8751.99 55 32 N 35.50 W 1.74 2515.22 N 2471.57 W 3524.30 1.75 2577.96 N 2519.26 W 3602.77 1.75 2642.77 N 2566.70 W 3682.59 .48 2708.74 N 2614.45 W 3763.48 .83 2775.42 N 2662.27 W 3844.94 10400 8872.97 8807.72 56 42 N 35. 0 W 10500 8927.07 8861.82 57 47 N 34.89 W 10600 8979.26 8914.01 59 16 N 34.10 W 10700 9030.18 8964.93 59 30 N 33.50 W 10800 9080.93 9015.68 59 30 N 33.50 W 1.24 2843.22 N 2710.19 W 3927.29 1.08 2912.15 N 2758.36 W 4010.65 1.64 2982.44 N 2806.67 W 4095.09 .56 3053.96 N 2854.54 W 4180.15 .00 3125.81 N 2902.10 W 4265.24 10900 9131.69 9066.44 59 30 N 33.50 W 10975 9169.75 9104.50 59 30 N 33.50 W .00 3197.66 N 2949.66 W 4350.33 .00 3251.55 N 2985.32 W 4414.15 HORIZONTAL DISPLACEMENT = 4414.15 FEET AT NORTH 42 DEG.33 MIN. WEST AT MD = 10975 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. BP EXPLORATION INC. F-32 PRUDHOE BAY ALASKA COMPUTATION DATE: 5/ 3/1989 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA DOS :APRIL 29, 1989 PAGE 4 JOB NUMBER AK-BO-90044 KELLY BUSHING ELEV. = 65.25 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -65.25 1000 999.98 934.73 2000 1999.95 1934.70 3000 2999.85 2934.60 4000 3999.81 3934.56 .00 .00 .00 3.96 S 4.16 W .02 .02 1.28 S 4.45 W .05 .03 8.36 N 4.82 E .15 .10 13.12 N 3.33 E .19 .04 5000 4962.03 4896.78 6000 5745.07 5679.82 7000 6466.23 6400.98 8000 7218.20 7152,95 9000 7948.52 7883.27 183.06 N 171.42 W 37.97 37.78 645.19 N 573.25 W 254.93 216.96 1121.90 N 1071.72 W 533.77 278.84 1539.83 N 1581.11 W 781.80 248.02 2032.75 N 2053.8~ W 1051.48 269.68 10000 8642.49 8577.24 10975 9169.75 9104.50 2577.96 N 2519.26 W 1357.51 306.02 3251.55 N 2985.32 W 1805.25 447.74 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. BP EXPLORATION INC. F-32 PRUDHOE BAY ALASKA COMPUTATION DATE: 5/ 3/1989 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA DOS :APRIL 29, 1989 PAGE 5 JOB NUMBER AK-BO-90044 KELLY BUSHING ELEV. = 65.25 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -65.25 .00 .00 .00 65 65.25 .00 .05 S .00 W .00 .00 165 165.25 100.00 .38 S .03 W .00 .00 265 265.25 200.00 .70 S .11 W .00 .00 365 365.25 300.00 1.18 S .29 W .00 .00 465 465.25 400.00 1.96 S .81 W .01 .01 565 565.25 500.00 2.34 S 1.53 W .01 .00 665 665.25 600.00 2.66 S 2.29 W .01 .00 765 765.25 700.00 2.91 S 3.05 W .02 .00 865 865.25 800.00 3.40 S 3.56 W .02 .00 965 965.25 900.00 1065 1065.25 1000.00 1165 1165.25 1100.00 1265 1265.25 1200.00 1365 1365.25 1300.00 3.85 S 3.99 W .02 .00 4.14 S 4.48 W .02 .00 4.33 S 5.07 W .03 .00 4.45 S 5.69 W .03 .00 4.25 S 6.13 W .03 .00 1465 1465.25 1400.00 1565 1565.25 1500.00 1665 1665.25 1600.00 1765 1765.25 1700.00 1865 1865.25 1800.00 4.10 S 6.61 W .03 .00 3.76 S 6.69 W .03 .00 3.47 S 6.80 W .03 .00 2.97 S 6.58 W .03 .00 2.47 S 5.93 W .04 .00 1965 1965.25 1900.00 2065 2065.25 2000.00 2165 2165.25 2100.00 2265 2265.25 2200.00 2365 2365.25 2300.00 1.70 S 5.01 W .04 .01 .52 S 3.36 W .06 .02 .47 N 1.62 W .08 .02 1.24 N .19 W .10 .01 1.95 N .82 E .11 .01 2465 2465.25 2400.00 2565 2565.25 2500.00 2665 2665.25 2600.00 2765 2765.25 2700.00 2865 2865.25 2800.00 2.69 N 1.66 E .11 .01 3.42 N 2.37 E .12 .01 4.64 N 2.95 E .13 .01 6.00 N 3.41 E .14 .01 6.98 N 4.03 E .14 .01 2965 2965.25 2900.00 3065 3065.25 3000.00 3165 3165.25 3100.00 3265 3265.25 3200.00 3365 3365.25 3300.00 8.07 N 4.61 E .15 .01 8.89 N 5.17 E .16 .01 9.54 N 5.45 E .16 .00 10.13 N 5.73 E .16~ .00 10.52 N 5.61 E .16 .00 3465 3465.25 3400.00 3565 3565.25 3500.00 3665 3665.25 3600.00 3765 3765.25 3700.00 3865 3865.25 3800.00 10.67 N 5.37 E .16 .00 10.91 N 5.35 E .16 .00 11.32 N 5.25 E .16 .00 11.61 N 4.85 E .17 .00 11.69 N 4.43 E .17 .00 BP EXPLORATION INC. F-32 PRUDHOE BAY ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA DOS :APRIL 29, 1989 5/ 3/1989 JOB NUMBER AK-BO-90044 KELLY BUSHING ELEV. = OPERATOR: D. HARGER PAGE 65.25 FT. MEASD DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3965 4065 4165 4266 4368 3965.25 3900.00 12.21 N 3.91 E .17 .01 4065.25 4000.00 15.69 N 1.68 E .26 .09 4165.25 4100.00 22.44 N 2.87 W .61 .35 4265.25 4200.00 32.58 N 10.94 W 1.45 .84 4365.25 4300.00 45.12 N 23.20 W 2.99 1.54 4470 4574 4679 4785 4893 4465.25 4400.00 60.51 N 39.97 W 5.56 2.57 4565.25 4500.00 79.36 N 60.43 W 9.38 3.82 4665.25 4600.00 100.72 N 84.31 W 14.39 5.01 4765.25 4700.00 124.44 N 110.37 W 20.44 6.05 4865.25 4800.00 152.21 N 139.74 W 28.32 7.89 5003 5115 5231 5352 5479 5614 5752 5890 6027 6165 6305 6446 6586 6725 6862 6998 7133 7268 7401 7533 4965.25 4900.00 184.15 N 172.53 W 38.32 10.00 5065.25 5000.00 220.20 N 208.59 W 50.59 12.27 5165.25 5100.00 262.13 N 248.69 W 66.23 15.63 5265.25 5200.00 312.53 N 294.19 W 87.13 20.90 5365.25 5300.00 371.71 N 345.60 W 114.22 27.10 5465.25 5400.00 440.44 N 403.92 W 148.88 34.66 5565.25 5500.00 513.24 N 465.21 W 186.92 38.04 5665.25 5600.00 586.72 N 525.55 W 224.91 37.99 5765.25 5700.00 659.90 N 585.21 W 262.44 37.53 5865.25 5800.00 734.12 N 644.93 W 300.55 38.11 5965.25 5900.00 809.26 N 706.22 W 339.86 39.30 6065.25 6000.00 879.98 N 777.32 W 381.56 41.70 6165.25 6100.00 942.83 N 852.43 W 421.53 39.97 6265.25 6200.00 1003.63 N 926.34 W 459.95 38.42 6365.25 '6300.00 1063.24 N 999.36 W 497.37 37.42 6465.25 6400.00 1121.34 N 1071.02 W 533.43 36.06 6565.25 6500.00 1178.58 N 1141.96 W 568.74 35.31 6665.25 6600.00 1234.58 N 1211.87 W 602.99 34.25 6765.25 6700.00 1289.23 N 1280.67 W 636.10 33.12 6865.25 6800.00 1342.54 N 1348.38 W 668.12 32.02 7664 7796 7929 8063 8199 8337 8475 8612 8749 8885 6965.25 6900.00 1395.55 N 1414.97 W 699.44 31.32 7065.25 7000.00 1450.22 N 1480.74 W 731.03 31.59 7165.25 7100.00 1507.98 N 1546.35 W 763.85 32.82 7265.25 7200.00 1568.89 N 1611.99 W 798.09 34.24 7365.25 7300.00 1634.73 N 1676.73 W 834.21 36.12 7465.25 7400.00 1703.54 N 1741.46 W 871.78 37.57 7565.25 7500.00 1772.74 N 1806.66 W 909.77 37.99 7665.25 7600.00 1841.09 N 1871.19 W 947.01 37.24 7765.25 7700.00 1909.18 N 1935.55 W 984.04 37.03 7865.25 7800.00 1976.43 N 1999.91 W 1020.66 36.62 BP EXPLORATION INC. F-32 PRUDHOE BAY ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA DOS :APRIL 29, 1989 PAGE 7 5/ 3/1989 JOB ~JMBERAK-BO-90044 KELLY BUSHING ELEV. = 65.25 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9023 7965.25 7900.00 9158 8065.25 8000.00 9293 8165.25 8100.00 9429 8265.25 8200.00 9570 8365.25 8300.00 2044.19 N 2064.74 W 1057.76 37.10 2111.65 N 2127.24 W 1093.62 35.86 2178.78 N 2186.39 W 1127.80 34.19 2248.47 N 2246.59 W 1163.76 35.96 2324.16 N 2312.62 W 1205.52 41.75 9719 8465.25 8400.00 9874 8565.25 8500.00 10037 8665.25 8600.00 10208 8765.25 8700.00 10385 8865.25 8800.00 2407.57 N 2384.21 W 1254.14 48.62 2499.70 N 2459.40 W 1309.54 55.40 2601.90 N 2536.91 W 1372.20 62.66 2714.66 N 2618.72 W 1443.69 71.50 2833.58 N 2703.44 W 1520.68 76.99 10572 8965.25 8900.00 10769 9065.25 9000.00 10975 9169.75 9104.50 2962.92 N 2793.45 W 1607.33 86.64 3103.61 N 2887.40 W 1703.85 96.53 3251.55 N 2985.32 W 1805.25 101.40 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY-G DRILLING F-32 PRUDHOE BAY ALASKA APRIL 29, 1989 HORIZONTAL PROJECTION FINISH SCALE IS START TVD = 1000 TVD - 0 9169.75 FEET/IN .6000 0975 3o~)o 2o~o ~o~)o DEPARTURE '5000 '4000 3000 2000 lOOO r-- .--t C I-ri SP LKK Y-~~N UI-( .1. LL 1 N ~r- I'~ v I t.,F_ ~ VERTICAL PROJECTION F-32 START TVD = 0 PRUDHOE BAY FZNISH TVB = 9169.75 ALASKA SCALE TS 1500 FEET/ZN APRZL 29, 1989 1500 3000 4500 6000 7500 9000 10500 1097 4414. 15 15~)0 3000 4.5~o 6oi3o VERTICAL SECTTON DIRECTION = 317.4.4- 7500 9o~o I TE£ECO] Teleco Oilfield S,,~ 6116 NielsOn Way~.~ ~- Anchorage, AK 99502 J (907) 562-2646 April 4, 1989 © of Alaska Inc. JOB #690 BP EXPLORATION (ALASKA) INC. WELL: F-32 PRUDHOE BAY RIG: NABORS 18E I i OFILr4ED Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to BP Exploration (Alaska) Inc. Teleco is committed to providing the highest quality MWD service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Dave Reimer Field Service Supervisor DR/el Enclosures , A ~ COMPANY TELECO OILFIELD SERVICES JOB 690 SURVEY CALCULATIONS **************************************** Date 04/04/89 Page 1 Company: B P EXPLORATION Well: F-32 Location: PRUDHOE BAY Rig: NABORS 18-E · TELECO Job # 690-TAK Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 30.80 degrees 30.80 degrees 314.25 degrees RADIUS OF CURVATURE CALCULATION **************************************** MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' GYRO SURVEY'TIE IN 2486.00 0.7 81.0 N 81 00 E 2485.85 -0.15 1.75S 1.49E 2.29 S 40.412E 0.000 TELECOMWD SURVEYS 2945.00 0.4 21.3 N 21 18 E 2944.82 -2.81 1.01N 4.91E 5.02 N 78.376E 0.141 3461.00 0.2 250.9 S 70 54 W 3460.81 -0.66 2.56N 3.42E 4.27 N 53.227E 0.107 3955.00 0.4 253.7 S 73 42 W 3954.81 0.54 1.77N 0.96E 2.02 N 28.599E 0.041 4107.O0 4.6 320.1 N 39 54 W 4106.63 6.11 3.59N 5.02W 6.18 N 54.396W 2.931 4202.00 6.9 319.1 N 40 54 W 4201.14 15.58 10.84N ll.19W 15.58 N 45.903W 2.423 TELECO Job # 690-TAK 04/04/89 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 4298.00 4393.00 4488.00 4593.00 9.3 313.8 N 46 12 W 4296.18 12.0 309.6 N 50 24 W 4389.53 15.0 310.3 N 49 42 W 4481.90 17.3 308.9 N 51 06 W 4582.75 4793.00. 20.7 311.0 N 49 00 W 4771.83 4986.00 5173.00 5363.00 5522.00 5745.'00 6195.00 6432.00 6874.00 7316.00 7726.00 8169.00 8421.00 25.2 313.1 N 46 54 W 4949.50 29.9 314.2 N 45 48- W 5115.25 36.3 317.3 N 42 42 W 5274.34 41.5 317.3 N 42 42 W 43.6 319.1 N 40 54 W 43.6 320.5 N 39 30 W 44.9 309.2 N 50 48 W 42.9 306.8 N 53 12 W 41.4 307.1 N 52 54 W 40.7 308.5 N 51 30 W 42.9 314.2 N 45 48 W 43.4 315.9 N 44 06 W 29.09 20.64N 20.50W 29.10 N 44.810W 2.616 46.63 32.32N 33.61W 46.63 N 46.123W 2.955 68.74 46.55N 50.61W 68.77 N 47.388W 3.163 97.84 65.17N 73.11W 97.94 N 48.286W 2.222 162.76 106.97N 237.94 157.36N 324.40 217.04N 428.06 291.32N 5398.03 527.73 364.71N 5562.31 678.16 477.12N 5888.18 987.03 714.14N 6057.94 1152.12 830.58N 6376.41 6704.10 7013.29 7343.52 7527.37 123.02W 163.02 N 48.990W .1.734 178.88W 238.25 N 48.662W 2.370 241.44W 324.66 N 48.046W 2.528 313.80W 428.18 N 47.128W 3.483 381.46W 527.76 N 46.286W 3.271 481.96W 678.18 N 45.290W 1.088 682.26W 987.66 N 43.692W 0.215 799.31W 1152.72 N 43.901W 3.369 1456.74 1019.25N 1040.79W 1456.75 N 45.599W 1750.94 1197.53N 1277.82W 1751.26 N 46.858W 2018.48 1362.56N 1490.56W 2019.49 N 47.569W 2313.23 1557.54N 1712.12W 2314.58 N 47.707W 2485.55 1679.51N 1833.87W 2486.73 N 47.516W 0.589 0.342 0.282 0.991 0.502 TELECO ~ob # 690-TAK 04/04/89 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 8865.00 43.0 314.9 N 45 06 W 7851.03 2789,43 1895.92N 2047.28W 2790.32 N 47.198W 0.179 9281.00 41.4 317.7 N 42 18 W 8159.19 3068.65 2097.92N 2240.31W 3069.25 N 46.880W 0.594 9492.00 45.2 318.0 N 42 00 W 8312.73, 3213.05 2205.18N 2337.41W 3213.46 N 46.667W 1.804 9841.00 50.7 320.1 N 39 54 W 8546.39 3471.18 2400.83N 2507.18W 3471.31 N 46.241W 1.638 9981.00 52.2 322.2 N 37 48 W 8633.63 3579.86 2486.09N 2575.85W 3579.90 N 46.016W 1.589 PROJECTED T.D. 10040.00 52.2 322.2 N 37 48 .W 8669.80 3626.03 2522.95N 2604.41W 3626.05 N 45.910W 0.095 TELECO Oil ield S rvice 'PLAN ViEW WEST (Ft) ~]~:.F,.; (El, J: .[]4~LDL.! ....... -J .... L. _L.L ~B!~: :'l:.~--~l.__i :: :'~ ! .... L · : , I, ,.' ! , I ' ,,T. - ~ . / ~. ! , ; ! ~ : ' Iii! i i i i l, i t,~lh i,,, 1~00!..F..mlm~l. 1,! : i i, i i .', i i , , ~. I ~ ,; ., I i , I : I : ! i ! ..' ] : , : : , _.~_.L_i__..,._. i i ~ i : ! !I !, i ; ~..}. ] . : ! i ! : : ! ~ i: , . . :. , : I,: - · i :, , i : - : ! ~ i . , : .: ~ : i :' ! I I ! i i" ~ : i i '"?T .... ' ' ~ " ! ' ' H : ~ i · I ! I : ,: '- ....... ~--~--~..-+-.4--F-?--.;--tr ....... H-'F-f--; .... t- :''' '',' :! ! !: :::tI, : ,L, : i ' : ; ; : ', ' i ; I ' ' · " ! , ! : . : , Ii,i! : : i : i ..1 :, i : : ': ' ! ! I ! I : i I ; i I i ~ i . : -: ' : :, I · i : [ ~ i ; ] ! · i i : ; ' I ! t : ~ ~ i~ :l~ I i ; : ------i----"~ :--' r"l'~"'?--""'"H' .... :'-"i--'i .... i"'--I : ' : ' ~ ' ~*;' "% : ' ~ ' : { ' ' : ' '~,' '; '"I' ' ! : . · , ; , ~ I , : ; .'. ! · , , .'--~: ""----~-'~ ~ q--'r--'r/--iR'~ '?-T-'.,'r'- --':--' ."-"~"'~ ....... '"t ........... ~ ..... ,.~,--;-...~ ~i.-.,,1. · , : ~ : i . i , I · i ; ! ; ; !. -.: !oao~.i-'~-....~...i.M-.-~ i ! ~ i ' : : --4--,4--'-- .... i :~ i ' ; : , : t I ,, ! --" '-'-'~-:, , .... -,"'~, .... ~'~-~, . .... "-; ..... q .... r: -'~--'"l t'-I · N..-T-t--I-.. -7-1--'~'-'!-"-I,--'~ ........ i--"i .... r"-:'--'! .il i. ~. ". ~.; ; ': '" '~, ._.._'~...k_.L_2_. d 2.: .~ ! ..i.---;.-4---~...4 ~--..r----4~-i~-.--;--.~--.-,t.-.-- '"-' ;. i ' ' ; ~ ~ i ..-" .i ! ! : i i , --~ ~ ,x. , ; ; , , , '-- t i I , i i I : ' ". I I , ; I : : \ ~ : i , I ' , I ' ~---. ~-,--.-m-~:-r-d,-- ~-.~-..--a t i'--'~l'l--i ..... "~N----~?--T--' t i i : i [ : I I : t I , I . - , , I : . , : .... , I t · ! I , i 6,~~! : ! I ~ f ,' ' ' -,.-.,--, . __ ,' ,. ~.: :~4.-~-.~-.~~.~~~_.~.~4._., . , , t , , I , : , -.' ; ( ! ! J , :: ! : I I ; : ! i ! i : I'~ i J I ' I : I i : ' : ; t ;fi ! i ] : · I I I ' i ! i ' t '-: ] I ! I I '. , t 1, .' '1, ,: --: ,i I ', / J ii I _! I : ! __,~,._[ ~ I l.l i t i i 4000 :~;~00 ~400 1800 800 0 6400 S6OO 4800 4000 :g200 '" 2400z 800 80O o 8O0 1 §OD - I 2000 TELECO O i 1 E i e id Serv ices VERT I CAL ?RDSECT I ON 1000 2000 3DOG ~.OOO 5000 3000 7000 10000 1 1000 VERTICAL SECTION (~t) BP EXPLORATION HOUSTON BP Exploration (Alaska) Inc. 900 ~ast Benson Boulevard P.O. Box 196~12 Anchorage, Alaska 99519-6612 (907) 561.5111 ARCO CEEVRON EXXON Date: 0 4 ' ~ 7 - 8 9 TEXACO MARATHON MOBIL TI:,, 79967 PHILLI~.S ' GEOSCIENCES '- REFERENCE: ARCHIVES BP'OPEN HOLE FINAL LOGS The following material Is belng submH-i'ed herewith. Please acknowledge receipt by signing a copy of ~'hls letter and returning It to this office= Hou/UNIT / STATE: ~ BHCS 04-04-89 #1 10021-10883 HLS 2"/5" CNL 04-04-89 #1 10021-10841 HLS DIL 04-04-89 #1 10021-10883 HLS 2F/5" % % STATE O~N-LY: DIRECTIONAL SURVEYS Magnetic Single Shot Directional Survey Date: GYr'dscopi. c Dir. ectional ':Survey" Date: : Rece I ved Da~e Job#: Job~: Shirley R. McCurry INFORMAT I.ON CONTROL We I I Records LR2-' I BP EXPLORATION HOUSTON ARCO ,, CHEVRON BP Exploration (Ala, ka) Inc. 900 ELK BonBon Boulevard F~. Box 196612 An(~horage. ~laska 99519.6612 (9o7) 661-6111 EXXON ,,, TEXACO MOBIL · , , , ,, , , PHILLIPS Date: 05-08-89 i i i Ill 80039 ,, GEOSCIENCES RESERVOIR REFERENCE: BP'CASED HOLE FINAL LOGS The following material is being submll~ed herewith. Please acknowledge receipt by signing a copy of this le4-fer and returning itt o this office: ' ' ~ PERF 04-29-89 #1 10200-t.07~, Sch J-03 SQZ PERF 05-01-89 #1 .9753-10040 Sch 5" C-22 TRACER 04-30-89 #1 9500-10083 Sch 5'~ B-01 PERF 04-27-89 #2 9250-9706 Sch 5" K-12 PERF 04-28-89 #2 8650-9353 Sch 5" F-07 PUNCHER 04-28-89 #1 9130-11240 Sch -' 5" Rece i ved Date · Nasl~. OU &~. ~ aQeGaS C0~s. commission · .- .o Shirley R. McCurry I NFORMAT i ON CONTROl. Well Records LR2-.I BP EXPLORATION HOUSTON ARCO CHEVRON TEIA~0 PHILLIPS STATE 0F ~, GEOSCIENCES ARCHIVES '- · 'BP'CASED m:)LE FrS'AL LOGS BP ~x;Ioraz~on (Alaska) Inc. 900 East Ben,on Boulev-rd P.O. Box lg6612 Anchorage. Alaska 99519-6612 Date: · r~: 80022 · The roi lo'wing materlal Is being submll-~ed herewl~h. Please acknowledge receipt by , signing a copy of this letter and returning It to this office.* D-05 D-05 D-29 W-20 ?-~-3:2~ q-05 CCL/GR 04-27-89 RF~..ERF-R 04-25-89 PROD-F 04-23-89 CNL (2½"Tool) 04-26-89 CBT 04-25-89 CET 04-25-89 PUNCHER & PLUG .04-26-89 #1 10100-10746 SCh #1 10550-10560 Sch 5" #1 9800-10050 Sch #i 9300-9850 Sch 5" #1 9532-10803 Sch #1 9532-10807 Sch .5"-' #1 9000-9317 Sch Rece i ved Date I Shirley R. McCurry I ~O~Ti ON CO~ ~11 ~eco~d~ BP EXPLORATION F_~XON PHILLIPS BP Exploration (Alaska) Inc. 900 East Benson Boulevard FO. Box 196612 Anchorage, Alaska 99519-6612 · (907) 581-5111 Dat~: 04-1 0-89 ~: 79949 SYSTEMS (Transmittal & Tape) ARCHIVES BP MAGNETIC LIS TAPES & LISTINGS The following material is ~being suhnitted herewith. signing a copy. of this letter and returning it to this office: F-32 OH W/LIS 04-04'89 HALLIBURTON API# 50 ~' 029-21930 800bpi Tape Please acknowledge receipt by Job# 135597 Pos# 06424 ARCHIVES ONLy. F-32 OH w/REPEAT SECTION INCLUDED 04-04-89 Halliburton ApI# 50-029-21930 800bpi Job# 135597 Tape Pos#06423 * E~ON: An Asterisk (*) next to a listing above means you should have received the Tape(s) and Listing(s) directly from the respecCive service company. Please confirm this. Date Shirley R. McCurry aeco~ ~-1 ~ar~h !7. ~989 Telecop~ ~ 276 75;42 ~lor~c-i. en (~aska) Ins. Pe~ .tis. 89-33 · Sur. ~e. ,.243-SHL.. 2869'~, See. 2, TilH, ~3g, OH. ~~h ~. ~672'~, ~'81'~, See. 34, T12H, l~13E, UM, Dear app~ovod application for permit to drill the 'well. _The.~-rm~c c~ ~~ does nec exeunt you ~-~,~Ca:Ln:l,ng addicional ~s',!~". ,'~ :'~ rE,om ~t aipnetes, and , equ~ :aa equine 8o C~t a ~ep~eeen~Ctve o~ 't~ ~a pr~C Co wi~es8 ceae~ of the ~~c b~ore the surface c.~:~ S:~e ia ~tli~. ~ere a dt~e~r ay-sC~ is required, Very cruty you.re, Chat~ o£ BY OI~E~ OF TH~ CO~SSION d!£ Enelosu.re cc, 'Deper~nc'of Fish & Game, Habitat 'Section v/o encl. Depar~nc of .~vtr~~al' COnservagton W/O: encl. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 14, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well F-32 (44-34-12-13) PBU Enclosed, in triplicate, is form 10-401, our Application for Permit to drill the above-named well. Also included are the attachments noted on the permit form and our check in the amount of $100.00 to cover the permit filing fee. The survey plat is not included in this permit package because it is presently underway. A copy of the plat for the F-32 well will be forwarded to you as soon as it is received by our office. Yours very truly, T. O. St~ag~~ PBU Drilling Engineering Supervisor TOS/KTH CC: Susan Leach Well File RECEIVED MAR 1 ~ 19'~e ~iaska 0il & Sas Cons. Commission Anchorage L STATE OF ALASKA ALASK ' AND GAS CONSERVATION C ISSION PERMIT TO DRILL 20 AAC 25.005 ia. Type of work Drill [] RedrillDIlb. Type of well. Exploratoryrl Stratigraphic Testr"l Development OilE] Re-Entry [] DeepenI-!I Service [] Development Gas: [] Single Zone [] Multiple Zone [] 2," Name of Operator 5. 'Datum Elevation (DF or KBi 10. Field and P001 ' BP Exoloration KBE = 64 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool p. o. Roy 1~fi12. Anchoraae_ Ala.~ka ~g51§-6812 ADL 4. Location of well at surf,.ce 7. Unit or property Name 11. Type Bond(.ee ~ sc 2s.o2s) 2243' SNL, 2869' WEL, SEC. 2, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 4900' SNL, 250' WEL, SEC. 34, T12N, R13E F-32 (44-34-12.13) 2S100302630-277 At total depth 9. Approximate spud date Amount 4672' SNL, 481' WEL, SEC. 34, T12N, R13E March 22, 1989 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in proPerty 15. Proposed depth(uoar~TVD) property line ADL 28277 481 feet F-11 ~ 21.2 feet 2560 10738'MD 9209'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (m ao ,~c ~.o~ (.)(2)) Kickoff depth 4000 feet Maximum hole angle 43.4o Maximum surface 3330 ~ At 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 20" Cond. 80' Surface 110' 110' 17-1/2". 13-3/8" 68# L-80 Butt 2650' Surfaqe 2680' 2680' 3723 cu fi Arctic Set II & III .1.2-1/4" 9-5/8" 47# NT80S NSCC 9980' Sudace 10010' 8680' ~118 ~ ft ~!~$ G 8-1/2" 5-1/2" 17# L-80 TC4S 978' 9760' 8498' 10738' 9209' 400 , i 9. To be completed for Redrill. Re-entry. and Deepen Operations. ' ' Present well condition summary Total depth' measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor REEEIVE'D Intermediate . Production Liner Perforation depth: measured true vertical Alaska 011 & Gas Cons. C0mmlsslon 20. 'Attachments Filing fee [] PropertY plat [] BOP Sketch [] Diverter Sketch [] Drilling pr~j~"a~l~r{gs Drillin~l fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25,050 requirements[] 21.1 hereby certify_~~~th~!~ t~oregoing is true and correct to the best of my knowledgee-~,~/--~ Signed ,3,_~~ Title PBU Drillin.q Engineering Supervisor Dat Commission Use Only Permit Number IAPI number IApproval date See cover letter ~--c~.. ~'.~ 15o- <::7.~..~-.2./,~..~4:~I~?,/17/89 for other requirements Cond|tiohs of approval Samples required [] Yes ~ Mud log required I-IYes/'E~ Hydrogen sulfide measures [] Yes ~.~"NO DirectiorLal,survey reqmrea /l~',Yes El-NO Other: order of Approved _ ~ me commission Dat _ by ~,._.',~/, (.. ~' ~~ ~ ' ~ Commissioner by -"orm 10-401 Rev. 12-1-85 Submit AFE No. 120809 PROPOSED DRILLING AND COMPLETION PROGRAM WELL F-32. f44-34-12-13] PBU Install and cement 80' of 20" conductor to surface. Install 20" Diverter. The Drilling fluid program will consist of an 8.5 - 9.5 ppg spud mud in the 17- 1/2" hole, a 9.0 - 9.7 ppg water base mud in the 12-1/4" hole and a 9.0 ppg water base mud in the 8-1/2" hole. Drill 17-1/2" hole to 2700' and cement 13-3/8" L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12-1/4" hole to the 9-5/8" casing point above the Sadlerochit Sandstone. Run 9-5/8" 47# NT80-S NSCC casing to within 5' of 12-1/4" TD and cement using Class G cement around the 9-5/8" shoe. The 13-3/8" x 9-5/8" annulus will be freeze protected with dry crude. Directionally drill 8-1/2" hole to TD. Run 5 1/2" liner from TD to 250' inside ~9-5/8" casing shoe and cement using Class G cement. Clean out to 5 1/2" float equipment. Change over to 9.0 ppg. NaCL completion fluid. Test casing and lap to 3000 psi. Run 9-5/8" production packer on tubing with a sliding sleeve. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. Shut down rig operations for perforating subsequent to rig release. The well will be perforated in accordance with normal practices. Tubing Size: 4-1/2", 12.6# L-80, TDS TBO with 5 GLM's. Tailpipe Size: 4-1/2" TAILPIPE SAL: 3-13-89 RECEi E,D MAR: ::1. laska Oil & Gas f,,on ,.Gommisslon PROPOSED DOWNHOLE DIAGRAM WELL F-32 [44-34-12-13] PB~ PROPOSED DEPTH BKB 20" Conductor 110 Ball Valve 13-3/8" Casing Shoe .17-1/2" Open Hole 2141 2680 2700 4-1/2" 12.6# L-80 TDSTubing with 5 GLM's 9-5/8" Packer 9710 5 1/2" Tieback Assembly 9760 9-5/8" Shoe 12-1/4" Open Hole 10010 10015 5 1/2" 17# L-80 TC4S 5 1/2" PBTD 5 1/2" Liner Shoe 8-1/2" Open Hole 'Alaska 0il & Gas ~ong ~/~mchorage 10698 10738 10738 SAL 3-13-89 B.O.P. STACK CONFIGURATION 1~3-5/8 IN. TRIPLE RAH STACK 5000 PSI WP DRILLING ANNULAR PREVENTER PIPE RAMS I 1 z IN. KILL LINE L BLIND RAhS ! I DRILLING SPOOL ! I PIPE RAILS I ,! 4 IN. CHOKE LINE HAND HYD. ASST. GATE GATE RE¢'EIVED A/as/ca Oil & Gas Cons, Anchorage SURFACE HOLE DIV. ERTER SYSTEM Two lines venting 90 deg. apart in directions that ensure safe down wind venting, and ex- tending to a point at least 100' from any potential source of ignition. 43' 10" Full Opening Valves "35' or as required Dresser Sleeve 10" Diverter Line 1. All pipe connections 150# ANSI Flanges or welded connections ' and secured to prevent movement. 2. Manual 10" butterfly valves mechanically connected to ensure that one valve is fail-safe open at all times. 3. All turns are 90 deg. and targeted. 10" Full opening ball valve w! Hydraulic Actuator Cellar RECEIVED MAR 1 20" Diverter Spool wi 10" Side Outlet JWB 2/20/89 _$45DUAl~4:[DRANOI3]F32_CLOSAP_SHORT7. LIS; & Search Radius= 200 7 DECREE LEAD LINE For proposed mell: F-32 [44-34-12-I3] Location = W-E S-N TVD(SBS) Top 651958,00 5974557.00 -64.00 Bottom 648687.66 5976968.64 '914~.06 13-MAR-1989 16:10 --- Closest Approach Analgsis --- Date: 13-MAR-8C2 Time: 16: 10:12 Note: All depths in Feet Belom KeIIu Bushing (BKB) Page 1 Closest Approach WELL IDENT /PROPOSED\ /NEARBY\ CLOSEST TVD DEPART TVD DEPART DISTANCE A0-~9--~008900 F-4 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW A029--~009500 F-5 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW A027-2009700 F-6 4112. ~ 3. 0 4100. 3 500. 9 AO~9-~O 11900 F-7 1564. 0 O. 0 1550. 3 184. 4 A0~9-~04 ~000 F-lO 0.0 0.0 ~.1 0.0 A0~9-~04~400 F-11 ~797. ~ O. 0 ~799. 9 15. ~ A0~9-~04~500 F-I~ ~797. 4 O. 0 ~799. 9 14. 8 A0~9-~043400 F-13 ~600. 4 O. 0 ~599. 9 17. 4 A0~9-~044000 F-14 ~897. ~ O. 0 ~899.9 18. 0 AO~9-~ 103000 F-~4 1364.0 O. 0 1363. I ~7. ~ AO~9-~ 16~700 F-~9 ( 0.0 0.0 3.~ · 0.0 A0~9-~164700 F-31 1097. 7 O. 0 1100.0 5. 9 Vertical Intersection /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART SUMMARY The well which comes closest to the proposed well is: A029-2042400 F-11 Closest approach distance = KICK OFF For this run = 21.2 ~eet 4000.0 Feet 105.4 4977.8 219.3 4307.8 683.0 408.8 7~.0 21.2 132.4 5022.2 241.2 3712.2 194.1 253.4 347.5 765.9 / 190.0 107.3 VERTICAL DISTANCE -661. -1312.5 PILL ~ro pIT TRIP TANK 75" 88L 2~0 ~L TO STN~ ~ " AAIO KI~ V~.UHE r~wK fflO 68L. t4UO eLEA~ER I~10 eel )/A~UUtl TY~ HUO Choke Hantfold Poor Boy Degasser · Brand t Vacuum.-Type Degasser Brand t Dual Tandem Shale Shaker Pioneer Hud Cleaners Pioneer HKI Centrifuge 1 - Rec0rdin$ drilling fluid, pit 'level indicat.0r v/th both visual and audio yarning de~tces at driller's console I - Trip Tank (75 BAL.) 1 - Drilling fluid flor sensor vith readout at driller's console 11 - 5 Hp AgitatOrs _$45DUA124: [DRANO13]F32_CLOSAP_SHORT, LIS; 8 Search Radius= 200 COURSE LINE For proposed well: F-32 £44-34-12-13] Location = W-E S-~ TVD(SBS) Top 651958.00 5974557.00 -64.00 Bottom 64900~.95 5977349.22 9143.06 13-MAR-1989 16:09 --- Closest Approach Analgsis --- Date: 13-MAR-89 Time: 16:09:25 Note: All depths in Peet Below ½ells Bushing (BRB) Page 1 Closest Approach WELL IDENT /PROPOSED% /NEARBY\ CLOSEST TVD DEPART TVD DEPART DISTANCE A029-2008900 F-4 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW A029-2009500 F-~ NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW A029-2009700 F-6 4110. 0 2. E1 4098.9 499. 9 A029-;2011900 F-7 1564. 0 O. 0 1550. 3 184, 4 A029-;2041000 F-10 O. 0 O. 0 2. I O. 0 A029-;204;2400 F-11 ;2797. 6 O. 0 ~'799.9 15. ;2 A029-2042500 F-12 ;2797. 4 O. 0 2799.9 14. 8 A029-2043400 F-13 ;2600. 4 O. 0 2599. 9 17. 4 AO:P9-2044000 F-14 2897. 2 O. 0 2899.9 18. 0 A029-;2103000 F-24 1364. 0 O. 0 1363. I 237.2 AO29-2162700 F-29 ( 0.0 0.0 3.2 0.0 A0::)9-2164700 F-31 1097.7 O. 0 1100.0 5. 9 105.7 408.8 75.0 ;21.2 132.4 233.4 347.5 765.9 190.0 107.3 SUMRARY The well which comes closest to the proposed well is: A0;29-;2042400 F-11 Closest approach distance = KICK OFF Foe this run = 21.2 Peet 4000.0 Feet Vertical Intersection /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART VERTICAL DISTANCE 5100.9 ;282.3 4375.8 75;2. ;2 -716.7 4940.8 ;202. 5 3593.2 147. ;2 -1350.1 .. MUD WEIGHT CALCULATIONS WELL F-32 (44-34-12-13] Mud Wt. (8-1/2" Hole): 9.0 ppg. P Sag River: P Sadlerochit: P Top Sadlerochit: 3900 psi. 3700 psi. at 8800' TVDSS 3693 psi. OB Sag River: OB Top Sadlerochit: Current GOC: 171 psi. 432 psi. 8869' TVDBKB 9-518" Casing Pt. Top Sag River Top Sadlerochit 8680' TVDBKB 8687' TVDBKB 8802' TVDBKB Cement. Calculations 13,-3/8" CASING Measured Depth: 2680' Basis: 2 X Annular volume Total Cement Vol: 3723. (¢u ft) Lead Slurry Vol: 1863 (cuft) 960 Sx Arcticset III @ 1.94 Cu ft/Sk Tail Slurry Vol: 1860 (cuft) 2000 Sx Arcticset II @ 0.93 Cu ft/Sk 9-5/8"CA'SING Measured Depth: 10018' Basis: 90% Annular Volume to 13-3/8" + 50 cuft Total Cement Vol: 2118 (cuft) Lead Slurry Vol: 1543 (cuft) 843 Sx 0+8% @ 1.83 Cu ft/Sk Tail Slurry Vol: 575(cu ft) 500 Sx Neat G @ 1.15 Cu ft/Sk 5,1/2" LINER Measured Depth: 9768' (Hanger)- 10746' (Shoe) Basis: 1.5 X Annular volume to 9-5/8" shoe 4- 150 cuft Total Cement Vol: 400 (cuft) 348 Sx Neat G @ 1.15 Cu ft/Sk SAL: 3-13-89 CHECK LIST FOR NEW WELL PERMITS Company ~ ;~J .~ Lease & Well No. · ITEM g/~ ~A~PROVE" ~ DATE ' ~ ~ NO _ (1) Fee 1..Is the permit fee attached .......................................... (2) Loc (8) (3) Admia '~ F( ------' (D -thru~ 10. (10 and 13) 12. 13. , (14 thru 22) (5) BOPE (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party,. ................................ 8. Can permit be approved before fifteen-day wait ....................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ,, Is administrative approval needed ................................... Is the lease number appropriate ........... .......................... ~2- Does the well have a unique name and number ......................... Is conductor string provided ........................................ ~ Will surface casing protect all zones reasonably expected to serve as an underground· source of drinking water ..................... ~ ,~, Is enough cement used to circulate on conductor and surface ......... .~ Will cement tie in surface and intermediate or production strings ... Will cement cover all known Productive horizons ..................... .~ Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams~and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~,~ ,,, psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. oma (29 thru 31) ' (6) A.d,,d: Ceolo gy: Engi~ee3~ing: DWJ />" LCS ~' BEW / rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. · aly Are seismic am sis data presented on shallow gas zones ............ ,,,, If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. Additional R~rks: ,, INITIAL CEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE dqo/ o /- 0)7 "9c) /)¢5o Well Histo.ry 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. ~LLLLLLLLLi. .,LLLLLLLLLL . IIIIIIIIII IiiiiiIIii ii II Ii ii ii ii Ii II iilIiiiiiI iiiIIiiiIi 3~ 00000000 0000000000 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 0 0 -'0 0 O0 O0 0000000000 00000000 SSSSSSSS 8SSSSSSSSS SS SS SS SS .':~': SSSSSSSSS SSSSSSSSS SS SS 88 SSSSSSSSSS SS$SSSSS DDDDDDDDD UU UU MM DDDDDDDDDD UU UU MMM M DD DD UU UU MMMM MM DD DD UU UU MM MM MM DD DD UU UU MN MHHM DD DD UU UU MM MM DD DD UU UU MM DD DD UU UU MM DD DD UU UU MM DD DD UU UU MM DDDDDDDDDD UUUUUUUUUUUU MN DDDDDDDDD UUUUUUUUUU MM ,,.. OFILE4ED ii iii ilii ii ii ii ii li ii ii iiiiiiiiii iiiililiii PPPPPPPPPPP PPPPPPPPPPPP PP PP PP PP PP PP PPPPPPPPPPPP PPPPPPPPPPPP PP PP PP PP PP 66 RRRRRRRRRRR RRRRRRRRRRRR RR RR RR RR RR RR RRRRRRRRRRRR RRRRRRRRRRR RR RR RR RR RR RR RR RR RR RR MM PPPPPPPPPPt PPPPPPPPPPi NH PP MN PP NM PP NM PPPPPPPPPP~ MN PPPPPPPPPP[ MN PP PP MN PP PP NH PP PPPPPPPPPPP PPPPPPPPPPPP PP PP PP PP PP PP PPPPPPPPPPPP PPPPPPPPPPPP PP PP PP PP PP 8888888888 888888888888 88 88 88 88 88 88 88888888 88888888 88 88 88 88 88 88 888888888888 MN HHH NMHN MNl MM NM MM I NM MNNM 1 MM NH i MM t MN i MM i MM I MM i MM l 999999999! 9999999999~ 99 99 99 9999999999' 9999999999' ! 99 9999999999' 999999999' :*~* REEL HEADER HEADER Servic~ name: &GSFOt Date: 89/04/t0 Origin Pl.'e:vi ou:s rea 1: Comments: RECORDS Reel name: Pag~ ij5597 Continuation ~*** TAPE HEADER ,: :~: *-~. $ $ ~:~: ,,ic$ :to ~ :~c .,it. ,$ Service name: &GSF.Ot Previous tape: Data: 89/04/10 Origin: Comment~: Tape name: 1 ~5597 Continuation #: O1 FiLE HEADER $ :.~.: $ $' :~ :Cc, ~ * :~. ~ File name.: .001 Sar. vice name: Version Data: Maximum lmngt, h: 1024 Film tppe: LO Previous MNEM CN WN FN COUN STAT CTRY APiN LATi LONG SECT TOWN RANG EK8 EDF EGL PD LMF DMF RUN TIME DATE LCC: LUN FL .LUL ENGi WITN DD DL CBD1 CBLi TL! BL! TCS TLA8 BHT MR '1' HT MSS DFO MVIS DFF'H DFL RM RHF HFST MFSS RMC INFORMAT I ON RECORDS CONTENTS UN I T B,P, EXPLORATION PRUDHOE BAY NORTH SLOPE HL. ASKA USA 21930 .000 ..... 0 Dcg 0 biin 0 Drag 0 MiD ~N ...... i3E ..... G5,250 ,, 64,250 , o~. 200 . MS 4/ 4/89. . 1 ~5597 .... NORTH SLOP~ NORTH SLOPE McKAY C, WHITE i 0900,000 ..... t 0890,000 1 00~1 , 000 ~ 002~ , 000 i 002t , 000 ...... t 0883,000 i 4,300 .......... 2~ ,130 i8i , 000 ................. 181 , 000 ............... LIGNOSULF, CIRCULATED 9.000 ............. 3~, 000 9.800 6.000 2,640 .... · 56. 000 ....... MEAS ...... DATE LOGGED 0 Smc AP1NUM: 50-029-2i930it, 04-04-89 41 41 · ,, m it 2.930 ..... TYPE L. HTG ~IZE CODE 0 0 40 b~'= 0 0 40 '~ 0 0 40 'S 0 0 20 b~'~ 0 0 20 ~5 0 0 20 65 0 0 4 68 0 O 34 6~.~ 0 0 ~4 65 0 0 '2 65 0 O ~ 65 0 0 ~ 65 FT 0 ~ 4 68 FT 0 ~ 4 68 FT 0 3 4 68 0 3 ~'~ 65 0 ~ 2 65 0 7 2 65 0 0 2 79 0 0 ,4 68 0 0 8 65 0 0 2 79 0 O 10 65 0 0 i0 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT O ~ 4 68 FT 0 ~ 4 68 FT 0 3 4 68 FT 0 3 4 G8 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 i 4 G8 DEGF 0 1 4 68 0 2 20 65 0 2 ~ ~0 65 LB/G 0 2 4 68 CP 0 2 4 68 0 2 4 68 0 2 4 68 OHMM 0 2 4 68 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 i2 65 OHMM O 2 4 68 Page ERROR MNEM MCST MCSS CS 8S I NFORMAT I ON RECORDS CONTENTS 56,000 ~EAS 8,500 ................................................... UN I T DEGF TYPE CATG SIZE 4 4 4 CODE 68 68 Pagm ERROR COMMENT RECORDo Well Locat Well Locat Wmll Locat Well Locat Well File Well File Well File Well File ion Comment 1: ion Comment 2: ion Comment 3: ion Comment 4: Comment 1: Comment 2: Comment 3: Comment 4: SURFACE: 2243' FNL & 2869" FEL CHLORIDES = 55'0 RRM. DiL?BCS?CNS TOOL STRING WAS RUN iN COMBINATION, MADE 2nd DIL RUN DUE TO ERRATIC TOOL RESPONSE. 2'00' OF FIRST DIL RUN PRESENTED TO SHOW DATA BELOW 10800'. FILL WAS ENCOUNTERED ON 2ND RUN INTO HOLE, DDLi SYSTEM USED. LIS tape written by: ANCHORAGE COMPUTING CENTER Ail curve and tool,. ~mnmmonics used are those which G~arhart curve and tool mnmmonicz. most closely match Page MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 8051,00 TEN DIL LBS TEN DIL LBS 10007.50 SP DILSCN MV SP DILSCN MV 10007.50 GR DIL AP1 GR OIL AP1 ;0007,50 ILD DIL OHMM ILD DiL OHMM 10007.50 ILH DIL OHMM ILM DIL OHMM 10007.50 RLL3 DIL OHMM RLL3 DIL OHMM 10007.50 TE~ql DILSCN LBS TEN D!LSCN LBS lO00?.5O SPi DILSCN MV SP DiLSCN MV i0007.50 GRi DILSCN AP1 GR DiLSCN AP1 i0007.50 0930. O0 0890. O0 0890. O0 0890, O0 0890 O0 0890 O0 0890 O0 0890 O0 0890 O0 0890 O0 GEARHART TO SCHLUMBERGER TOP BOTTOM DTi FCNL! NCNLi ClLM TTli TT2i TTSt TT4.1 CiLD NPSSi RATi DILSCN DILSCN DILSCN DIL DiLSCN DILSCN DILSCN DILSCN DIL DILSCN DILSCN US/F CPS CPS MMHO Uo, F US?F US/F US/F MHHO $SPU CPS DT FCNL NCNL ClLM TTi TT2 TT3 TT4 ClLD NPSS RAT DILSCN DILSCN DiLSCN DIL DILSCN DiLSCN DILSCN DILSCN DIL D I LSCN DILSCN US/F CPS CPS MMHO US?F US/F US/F US/F MMHO SSPU CPS 0007,50 0007,50 0007.50 0007.50 0007,50 i 0007,50 .0007,50 0007.50 i 0007.50 0007..50 0007.50 0890 O0 0890 O0 0890 O0 0890 O0 0890 O0 0890 O0 0890 O0 0890 O0 0890 OO 0890 O0 0890 O0 DATA ENTRY BLOCKS **** ENTRY FORMA T SPEC I F I CA TYPE SIZE CODE i 6 i 66 0 1 66 T IONS Page *** ENTRY BLOCK LEGEND **** TYPE DE~,CR I PT ION Datum zpeci¢'ication block sub-t~pe Ter, minator ( no more entries ) DATA FORMAT SPEC I F I CA T IONS Page ~*** DATUM 'SPECIFICATION BLOCKS ***~ SERVICE SERVICE MNEM iD ORDER ~ AP1 AP1 AP1 AP1 UNiT LOG TYPE CLASS MOD FILE SiZE PRC ~ LVL SMPL RC PROCESS iNDiCATORS DEPT 135597 FT 0 0 '0 0 TEN DiL 135597 LBS 94 635 0 i SP DILSCN 135597 MY 94 iO i i GR DiL i~5597 APl 94 3i0 i i ILD DIL 135597 OHMM 94 i2:0 46 i ILM DiL I35597 OHMM 94 i20 44 RLL3 DiL 135597 OHMM 94 220 6 i TEN DiLSCN t35597 LBS 94 635 0 i BP DiLSCN i35597 MV 94 iO i GR DtLSCN i35597 APl 94 3i0 i i DT DILSCN 135597 US/F ~4 5~O 32 i FCNL DILSCN i~5~97 CPS 94 334 NONL DILSCN 135597 CPS 94 334 30 i CILM DIL i35597 MMHO 94 ilo TTi DILSCN 135597 US/F ~4 522 3~ i TT~ DILSCN I35597 US/F 94 5~ 5~ i TT3 DILSCN 135597 US/F 94 522 32 i TT4 DIL$CN ~35597 US?F 94 430 52 ClLD DIL i35597 MMHO 94 ilo 46 NPSS DILSCN 135597 SSPU 94 890 3 RAT DILSCN 135597 CPS 94 420 i i 1 4 0 1 0 4 0 0 4 0 i 0 4 0 0 4 0 1 0 4 0 i 0 4 0 1 0 4 0 i 0 4 0 i 0 4 0 i 0 4 0 i 0 4 0 i 0 4 0 i 0 4 0 i 0 4 0 i 0 4 0 i' 0 4 0 i 0 4 0 i 0 4 0 i 0 4 0 i 0 4 0 1 68 G8 68 68 68 G8 68 G8 68 68 G8 G8 68 G8 G8 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000:000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 00000.0 000000 000000 000000 000000 000000 000000 000000 DATA RECORDS DEPT TEN SP GR ILD ILM RLL3 TEN SP GR DT FCNL NCNL CiLM TTi TT2 TT3 TT4 CILD NPSS RAT 1 0890, O, 000 I0800,000 -ii,GOO 51i.000 0700,000 i5,000 489,000 0600,000 46,300 487,000 10500,000 62,800 420,000 04'00,000 Gi .500 5:06. 000 0300,000 63,800 56t, 000 -999,25 0 .0,000 0. 000 4086. 000 i?, 1.00 5i 5,000 4I 07,000 24. 900 496. 000 4113.000 i8.600 492,000 4088,000 i6,400 426,.000 4036,000 i7. 000 5i i. 000 405i . 000 20. 700 566.000 4115,000 i95,500 40-4,000 3954.000 53.7'00 473.000 10200,000 64.500 395.000 lOlO0,O00 74,600 465,000 -999,250 0,000 -999,250 -ii,GOO 89,000 71,285 15,000 84,800 i 57.03{3 46,300 500 320 62,800 72,600 i5.668 61,500 88.i00 30,200 63.80.0 100.100 32,063 64.50'0 61.600 13,305 74.600 87,400 60.395 -g99,2~0 0.000 0,000 77,10.0 i82,300 25,670 22,5!00 23i, 600 20.9i0 17,700 264,700 19,202 15.600 365,600 13,972 19,2.'00 22i, 500 21.02 0 23,200 i 94. O0 0 23. 380 262.400 3i5,800 i5,222 48.900 i60,300 26.460 -999 ~..0 999 250 999,~50 3183,000 O,OOO -999,250 O,OOO 0.000 0,000 14,028 13,996 24,155 4086,000 359.80'0 7i , 450 329,000 338. 000 i , 995 6,368 6,745 i I ,695 4i 07,000 399,000 i 48. 252 324. 000 335,000 i ,652 5i 761 36 475 43 5.,i 4ii3 000 440,700 27,4i6 3i3,000 324.000 i,625 63. 826 44. 259 63,24i 4088. 000 497,000 22,594 272. 000 282. 000 i. 356 33,it3 25,410 29.377 4036.000 409,800 39,355 325,000 335.00.0 1 .699 31.i89 21.232 25.763 4051,000 379.400 47,098 358.000 365.000 1.883 75.162 73.282 297,167 4115.000 492,000 i3,646 260,000 27i,000 i.447 16.558 14,355 18.030 3954.000 337,000 69,663 29i,000 302,000 i,926 Page DATA RECORDS DEPT TEN SP OR ILD SP GR DT FCNL NCNL TT~ TT4 CiLD NPSS RAT ILM CiLN RLL3 TTi TEN Page *** FiLE TRAILER **** Maximum iength: ~024 TRAILER RECORDS File t.s, pe: LO Version Next f'iie: Date: Pmg~ FiLE HEADER **** File name: ,002 Version #: Maximum length: 1,024 File type~ LO Previous ~ile: MNEM CN WN FN COUN STAT CTRY APIN LATI LONG SECT TOWN RANG EK8 EDF EGL PD LMF DMF RUN TiME DATE LCC 80N LUN FL LUL. ENGi WITN DD DL CBDi CBL! TLI 8Li TCS TLA8 HRT MT MSS DFD MVlS DFPH DFL RM RMF HFST HFSS EHC CONTENTS B.P. EXPLORATION PRUDHOE BAY NORTH SLOPE ALASKA USA 2t'9.30. goo ..... 0. Deg. 0 Min 0 Dm~ 0 Min 13E ...... A5,250 ,. 64,250 .. ~b.200 .. i'iS ...... K~ ...... ~:~4.000 . . 4/ 4/89, ,. ..~0 .......... i ~5597 .... G-76i 2, ,, NORTH SLOPE NORTH SLOPE McKAY C, WHITE i 0900,000 .... i 0890,000 .... t OOS1 , 000 .... ~ 002t , 000 .... '~ 0021 , 000 .... ~ 0883,000 .... i4,300 ....... 21 ,i~O ....... 18i ,000 ...... i 8i , 000 ...... LlfiNOSULF. CiRCULATEQ 9,000 ......... 34,000 ........ 9.800 ......... 6,000 ......... 2,750 ......... 2,640 ......... 56,000 ........ MEAS .... '~ 9~0 ......... I N F 0 R M A AP1 HUM: DATE LOGGED: 50-029"2 i 930 04-.04-89 TION RECORDS UNIT FT FT FT FT FT FT FT FT . FT . HR HR DEGF . DEGF · . LS/G . CP · OHHM . OHHH DEGF . OHMM TYPE CATG SIZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 4 68 0 0 34 65 0 0 ,34 6,5 0 0 2 65 0 0 3 65 0 0 3 ~5 0 3 4 ~8 0 .3 4 68 0 3 4 68 0 3 2 65 0 3 2. 65 0 3 2 ~5 0 0 '2 79 0 0 4 ~8 0 0 8 ~5 0 0 2 79 0 0 i0 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 0 3 4 68 0 3 4 68 0 :3 4 68 0 3 4 68 0 3 4 68 0 3 4 68 0 2 4 68 0 4 4 68 0 i 4 68 0 i 4 68 0 2 20 65 0 2 20 65 0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 6,8 0 2 4 68 0 2 4 68 0 2 12 65 O 2 4 68 Page ERROR iO MNEM MCST MCSS INFORMATION RECORDS CONTENTS 56. 000 i'tEAS 8,500 UNIT DEGF TYPE CATG SIZE 4 i2 4 4 CODE 68 65 68 68 ERROR I1 COMMENT RECORDS Page.. Weli Location Commmnt I: Wmll t. ocmtion Commmnt 23 Well Location Comm~_nt J: Wmll Location Commmnt 4: Wmli Fitm Commmnt i: WmlI Film Comment 2: Well Fitm Commmnt 3: Wmll Film Comme. nt 4: SURFACE: ~243' FNL & ~869' FEL CHLORIDES = 550 PPM. DIL/BCS/CNS TOOL STRING WAS RUN IN COMBINATION, MADE 2nd DIL RUN DUE TO ERRATIC TOOL RESPONSE. 200' OF FIRST DIL RUN PRESENTED TO SHOW DATA BELOW 10800', FILL WAS ENCOUNTERED ON 2ND RUN INTO HOLE, DDL1 SYSTEM USED, [.IS t. ap~ writtmn b~: ANbH~RA~E ~OMP~TING CENTER All curvm and tool mnmmonics u~md arm those which most closml~ match G~aph~rt curvm and tool mnemonics, ~EARHART TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEF'TH FT DEPT FT 8051, O0 I 0930. O0 TEN4 DILSCN LBS TEN DILSCN LBS 10655,50 10890,50 SP4 DILSCN MV SP DILSCN MV ~ 0655,50 ~ 0890,50 GR4 DILSCN AP1 GR DILSCN APl ] 0655,50 ! 0890,50 tL[)4 DILSCN OHMM ILD DILSCN OHMM 1 0655,50 ] 0890,50 I Li'!4 DILSCN OHMM ILM DILSCN OHMM 10655,50 ! 0890,50 RLL 34 DILSCN OHMM RLL3 DILSCN OHMM 1 0655,50 ! 0890,50 CILD4 DILSCN MMHO CILD DILSCN MMHO 10655,50 10890,50 CILM4 DILSCN MMHO C!LM DILSCN MMHO I 0655,50 ! 0890 ~ 50 DATA ENTRY FORMA TYPE T SPEC I F I CA SIZE CODE 16 i 66 TIONS Pag~ ENTRY 'BLOCK LEQEND m:~m TYPE DESCRIPTION I6 Dm~.~Jm spmci¢'ication block subT.t~pe 0 T~rminator ( no more entrims FORMAT *** DATUM SPECIFICATION BLu;.;K~., **~* SPECIFICATIONS Page 14 SER~,,' I CE SERVICE APl MNEM iD' ORDER # UNIT LOG APl AP1 APl FILE TYPE CLASS MOD ~ PRC SIZE LVL SMPL RC PROCESS iNDiCATORS DEPT ij5597 FT O TEN DiLSCN 135597 LBS 94 :SP DiLSCN i'~5597 MV 94 ~R DiLSCN i~5597 APl 94 ILD DiLSCN i~5597 OHMM 94 ILM DiLSCN i35597 OHMM 94 RLL3 DiLSCN 1~5597 OHMM 94 ClLD DiLSCN i~5597 MMHO 94 ClLM DILloN 1~5597 MMHO 94 6,8 68 6,8 6,8 68 68 68 68 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT CiLH TEN SP GR ,500 5 ~ 0 ! 0800, 000 54~200 ! 0700, .000 i27.938 4025,000 4204. 000 4123.000 33,700 31 .600 30,800 0,000 J7,600 28.800 RECORDS ILD 17,061 7.015 ILM RLL. 3 CILD 2,301 4.498 176,6i6 18,450 24,717 58,6i4 7,}316 10.000 142.561 Pag~ i5 Ma×laura length: 1024 Service TRAILER RECORDS Vets i on ~: File t~pe:. LO Next f'iie: Date: Page FiLE HEADER Fiie r'~am~_.: , 003 Maximum length: ~024 Servi, ce name: : F,/~le tppe: LO Version #: Previous ?ile: Date: MNEM CN WN FN COUN STAT CTRY APIN LATt LONG SECT TOWN RANG EDF EGL PD LMF DMF RUN TiME DATE LCC SON LUN FL LUL ENGI WiTN DD DL ~CSDt C8L1 TLI · BLi TCS TLAB 8H T MRT MT MSS DFD Mv!S OFPH OFL RM RMF MFST MFSS RMC I NFORMAT I ON RE'CORDS CONTENTS F-S2 PRUDHOE 8AY NORTH SLOPE ALASKA USA 21930 0 Dcg 0 Drag ilN,, i SE., 64,250, 3{3,2.00, K9 ~234,0 O0, 4/ 4/89,, ~0 ....... ~35597 , G.-76~ 2 NORTH SLOPE NORTH SLOPE HcKAY C, WHi TE ~ 0900. OOO ...... ~ 0890,000 ...... ~ 003i , 000 ...... ~0021 , OOO ...... i002~ , 000 ...... ~0883,000 ..... -, 2~ ,t30 ~8~ , OOO ........ ~8~ , OOO ........ LiGNOSULF, CIRCULATE[) EXPLORATION AP1 DATE LOGGED: 0 Sec , , ! NUN: 50.-029-2~ 930 04-04-89 , . 9,000 ....................... 34,000 ...................... q. 800 ........................ 6.000 ................................................... 2.750 ................................................... £.640 ................................................... 56,000 .................................................. HEAS - 2,9S0 ................................................... UN I T TYPE CATG 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FT 0 .3 FT 0 3 FT 0 3 0 S 0 3 0 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FT 0 3 FT 0 S FT 0 3 FT O' 3 FT 0 3 FT 0 3 HR 0 2 HR 0 4 DEGF 0 1 DEGF 0 i 0 2 0 2 LB,"G 0 2 CP 0 2 0 2. 0 2 OHMM 0 2 OHMM 0 2 DEGF 0 2 0 2 OHMM 0 2 SIZE CODE 40 40 65 20 ~5 20 65 20 4 68 34 65 · 34 65 2 65 3 4 4 68 4 ~8 2 65 2 65 '" 65 2 79 4 68 8, 65 ,~ 79 i 0 65 iO 65 20 ~5 20 65 20 65 20 65 4 4 68 4 68 4 68 4 68 4 68 '. 4 68 4 4 68 4 68 20 65 20 65 4 68 4 68 4 68 4 68 4 68 4 68 4 68 i2 65 4 Page ERROR i7 M N E M MCST MCSS CS BS I NFORMAT I ON RECORDS CONTENTS 56,000 .................................................. MEAS ............................................. 9.625 ................................................... 81500 ................................................... UN I T DEGF TYPE CATG SIZE 4 4 4 CODE 68 65 68 Pag~ ERROR 18 COMMENT RECORDS Well Well Well Well Well Well Well Location Comment Location Comment Location Comment l: SURFACE: 2243' FNL & 2869' FEL 2: Lc, cation Comment 4: .~,._0 P M DtL./SC:~,-~N'.=, TOOL .~T~.iNG RUN IN ~.-ila ~J,,mmmnt ~ · CHLORIDE.~ =s p ' 'C' ~ '~ ~ 'l' ~ File Comment '2: COMBINATION, MADE 2nd DIL RUN DUE TO ERRATIC TOOL RESPONSE, Fi!~ Comment 3: 200' OF FIRST DIL RUN PRESENTED TO SHOW DATA BELOW l OSO0'. t.~!ell File Comment 4.: FILL i.,.;AS ENCOUNTERED ON ~ND RUN INTO HOLE, DDL1 SYSTEM USED, :'i". :~. >k. :'i~, ~."-:~, :~ :~ :i': ~, :'~-~.:~: :~, :~. ~', :~: :~:~-~-~-:'~: :~, :~ :'~: :~: :~, :~: ~::~ :'~-:~-:~:'B :~, :~-~k,:~: :~, ~, :~, ;'~: ~,:~. ~:'I~; ~,,9-:~:~ ~'$, :~, :~-:~, :+: ~, ~,:~ :~: :~, $~, :~,~, ~,:~, ~,:~, ~, · :~, ~ ~-:~: :~: ¢:~ LIS tape written bp: ANCHORAGE COMPUTING CENTER m,$ All curve and tool mnmmonics usmd acm those which most closml~ match ~::~: ~]aarhart curve and tool mnemonics, GEARHART TO SCHLUMBERGER TOP 80TTOM M~,iEbi SERVICE UNIT MNEM SERVICE UNIT DEPTH FT DEPT FT TE~5 DILSCN LBS TEN DILSCN LBS GR5 DILSCN APl GR DILSCN AP1 FCi',!L5 DiLSCN CPS FCNL DILSCN CPS r-~-~ ~ LSCN CPS ''~' CPS N~.~ .... Di NCNL DILLON RAT5 DiLSCN CPS RAT DILSCN CPS NPSS5 DILSCN SSPU NPSS DILSCN -~ I DEPTH DEPTH 805i . 00 8051 50 805i 50 8051 50 805i 50 8051 50 805i 50 0930, O0 0090, O0 0090, O0 0090, O0 0090, O0 0090. O0 0090, O0 i9 DRTR FORMA T i ONS ENTRY ~PECIFICA TYPE SIZE CODE 16 1 66 0 i 66 2O TYPE DE._,uRIPT ION 16 Dar. om spmci¢ication blo,zk sub-type O 'lrmr, minator ( no more mntr-ims ) D~TR FORMAT SPEC l F l C~T I OHS Page 2i ,:.,=R,,I~$~.. SERVICE APl APi API MHEM ID ORDER ~ UNiT LOG TYPE CLASS MOD FILE PRC ~ SiZE LYL SMPL RC PROCESS iNDi~TuRo DEPT 135597 FT 0 0 0 0 TEN DILSCN 135597 LBS 94 635 0 2 GR DiLSCN 135597 AP! 94 ~i'0 i 2 FCNL DiLSCN tj5597 CPS 94 334 3i 2 NCNL DiLSCN i35597 CPS. 94 334 30 2 RAT DiLSCN i35597 CPS 94 42:0 i 2 NPSS DILSCN i~5597 SSPU 94 890 ~ 2 3 4 0 t 2 4 0 i 2 4 0 i 2 4 0 i 2 4 0 i 2 4 0 i '-2 4 0 i 68 68 68 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 00000,0 000000 000000 000000 000000 000000 DEPT TEN 10090.000 iO000,O00 9900.000 9800.000 9700,000 9600.000 9500,000 9400,0.00 9300,000 9200,000 9100,000 9000,000 8900.000 8800.000 8700.000 8600.000 8500,000 3942 000 3864 000 3873 000 3835 000 3806 000 3803 000 3803 000 3807 000 3764.000 3721.000 3699.000 3654.000 3653.000 3601.000 3566,000 3530.000 3470.000 64,200 61.300 63,200 62,300 56,300 58,100 46,J00 50,900 50.800 63.00.0 57,800 44.500 40,400 53.400 54,200 60.700 DATA RECORDS FCNL NCNL RAT NPSS 50,000 317,800 2.089 55,500 i76.000 2.978 59. 000 176,700 3. i 34 49, .400 i 64,600 3,206 49.4-00 i 50,500 2,908 47,400 158.000 3,194 61.50'0 154,400 2,749 67.000 i89.700 2,666 58.i'00 i60,700 2,775 42,400 156,700 3,085 46,200 I47,700 3,381 49,2,00 i46,900 3,080 61.1:00 156.000 2,838 63,000 i60.600 2,598 45,400 t58,400 3,087 49,20.0 156,900 3,100 49,200 146,900 3,192 27.200 54 570 51 620 56 890 50 690 57 300 34 850 34 590 37 140 50.580 48.850 44.440 34,750 30,860 44.410 45,400 46.240 Page 22, DEP T TEN GR DATA FCNL RECORDS NCNL RAT NPSS Pag~ 8400.000 8200,000 8i00,000 3444.000 3425.000 3329,000 3335~000 50,600 49,300 91, JO0 I03,000 43,000 43,000 45,300 44.400 I47,600 t45,300 139,600 135,900 2,926 3,030 3.253 2,992 44.040 42, ?'50 46, 160 44, t80 File name!: &GSFO1 . 003 Maximum length: 1024 TRAILER RECORDS Version File t.ypm: LO Next ~ilm: Date: Pag~ 24 Service name: Date: 89d04710 Origin: R~el name: 3559? Continuation #: Oi Scr~i~e name: &GSFOi Date :' 89.."'04di 0 Origin: Tapa name.. 1~5597 Continuation ~: O1 Next t. mpm: Comments:
