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Home My WebLink About180-096 STATE OF ALASKA• RECEIVED ALASKA OIL AND GAS CONSERVATION COION REPORT OF SUNDRY WELL OPERWNS r 1. Operations Performed APR v 2018 Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdow ,4a ;4,0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change A •t'l .d❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number. 180-096 3. Address: P.O.Box 196612 Anchorage, Development II Exploratory 0 - AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20508-00-00 7. Property Designation(Lease Number): ADL 028331 8. Well Name and Number: PBU 17-05 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY.PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10210 feet Plugs measured None feet true vertical 9525 feet Junk measured 9605,9809 feet Effective Depth: measured 10163 feet Packer measured 8787,8862 feet true vertical 9488 feet Packer true vertical 8350.8412 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 76 20" 36-112 36-112 1530 520 Surface 2567 13-3/8" 35-2603 35-2603 5380 2670 Intermediate 9176 9-5/8" 33-9209 33-8702 8150/6870 5080/4760 Production Liner 1306 7" 8899-10205 8443-9521 8160 7020 Perforation Depth: Measured depth: 9328-9620 feet True vertical depth: 8803-9047 feet Tubing(size,grade,measured and true vertical depth) 4-1/2",12.6#,13Cr80 x 5-1/2",17#,L-80 31 -8868 31-8417 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 8787 8350 true vertical depth) 5-1/2"Baker SAB Packer 8862 8412 12.Stimulation or cement squeeze summary: Intervals treated(measured): /p� Treatment descriptions including volumes used and final pressure: SC'" 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 129 581 5388 1530 313 Subsequent to operation: 131 530 5503 1563 282 14.Attachments:(required per 20 AAC 25.07025.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development RI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Stechauner,Bernhard Contact Name: Stechauner,Bernhard Authorized Title: FS 2 --d PE Contact Email: StechaunerBernhard@bp.com Authorized Signature: Date: L ,/ 7 i g Contact Phone: +1 907 564 4594 Form 10-404 Revised 04/2017 VT L 417-6/1 S 1' 1 1 US Submit Original Only RBDMS /k PR • • Daily Report of Well Operations 17-05 ACTIVITYDATE SUMMARY T/I/O= 240/1000/0 Temp=Hot Freeze protect TBG & FL pre E-line, Pumped 2 bbls 60/40 spear followed with 36 bbls crude down TBG for FP, Pumped 5 bbls 60/40 spear followed with 79 bbls crude down FL for FP, Tags hung on well, Valve position @ departure- 3/8/2018 WV,SV,SSV,AL= Closed, MV= Open, IA&OA= OTG, FWHP=Vac/1000/0 ***JOB STARTED ON 08-MARCH-2018***(SLB ELINE PERF) WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 550/990/50 RU/PT, HPT= 3500 PSI GUN 1, RIH W/25'X 3-1/2" PJO HSD, 6 SPF, 72 DEG PHASE. PERFORATED INTERVAL= 9510' -9535', CCL TO TOP SHOT= 8.5', CCL STOP DEPTH = 9501.5'. PULL JEWELRY PASS OVER 9536' -8630', ALL PASSES TIED INTO DRESSER ATLAS ACOUSTIC CEMENT BOND LOG DATED 03- NOV-1980. 3/8/2018 ***JOB CONTINUED ON 09-MAR-2018*** ***JOB CONTINUED FROM 08-MARCH-2018***(SLB ELINE PERF) GUN 2, RIH W/20'X 3-1/2" PJO HSD, 6 SPF, 72 DEG PHASE. PERFORATED INTERVAL= 9490' -9510', CCL TO TOP SHOT= 7.4', CCL STOP DEPTH = 9482.6' GUN 3, RIH W/30'X 3-1/2" PJO HSD, 6 SPF, 72 DEG PHASE. PERFORATED INTERVAL= 9444' -9474', CCL TO TOP SHOT= 8.2', CCL STOP DEPTH = 9435.8' GUN 4, RIH W/20'X 3-1/2" PJO HSD, 6 SPF, 72 DEG PHASE. PERFORATED INTERVAL= 9328' -9348', CCL TO TOP SHOT= 7.5', CCL STOP DEPTH = 9320.5' ALL PASSES TIED INTO DRESSER ATLAS ACOUSTIC CEMENT BOND LOG DATED 03- NOV-1980. WELL SHUT IN ON DEPARTURE, FINAL T/I/O = 590/950/50 3/9/2018 ***JOB COMPLETE 09-MAR-2018*** 1f4EE= 41!16"CTW III 1 0 5 •FErYNoT : '"'4-1/2"CHROME TBG"'" .WR1 EAD= RNC ACTUATOR= BAKER C OKB.ELEV= 70' BF.ELEV= �• ,• KOP= ar • • Max Angie= 38° 10210 iii 1 , ►i 2120' --I41/2"HES X NP,D=3.813' Datum MD= 9408' ►• Datum ND= 8800'SS ►%i ►� ' �( ►� 2161 —19-5/8"HES ES CEMENTER ►�i i 20"CONDUCTOR„94#,H-40,D=19.124' -I 110' �►!� i� GAS LIFT MANDRELS 9-5/8'CSG,47#L-80 TO XO TO L-80 BTC — 2133' ST MD ND (DEV'TYPE t VLV LATCH I PORT DATE 9-5/8"CSG,47#,L-80 BTC,D=8.681" --I 2170' 4 3399 3399 1 MID DOME RK 16 12/16/13 3 5780 5752 22 MNG SO RK 24 12/16/13 13-3/8"CSG,72#,L-80,0=12.347" — 2603' 3 2 7567 7310 29 MMG DMY FK 0 12/16/13 x 1 8683 8265 35 MNG CM' RK 0 02/24!10 9-5/8"CSG,47#,L-80 XO TO RS-95 H8344' Minimum ID = 3.813" @ 2120' 4-112" HES X NIPPLE V 8754' —14-1/7 tis X NP,D x.813" ' I 8775' —9-5/8'X 4-1/2"BKR CR S-3 FKR,ID=3.870" X "� ' 8799" —141/2'HES X NP,D=3.813' 4-112"TBG,12.6#,13CR 80 VAM TOR —I 8811' 1-- .0152 bpf.D=3.958" 8816' -19-5/8"X 4-1/2"OVERSHOT GUIDE 512"TBG STUB — 8812' 8837' H5-1/2'BOT PBR ASSY,ID=4.938" 5-1/2"TBG-PC,17#,L-80,.0232 bpf,D=4.892" —{ 8856' 8857' H9-5/8"X 5-1/2"BKR SAB PKI,D=4.75" 8862' —17"MLLOUT EXTENSION,D=6.00" 4112"TBG PC,12.6#,N-80,.0152 bpf,D=3.958' — 886$' 8' Hr.x 4-1/2"xo,13=3 s58" TOP OF 7*L141 — 8899' 9-5/8'CSG,47#,RS-95,D=8.681" —I 9209' }- ' PERFORATION SUMMARY REF LOG:BHCS ON 10/29/80 ANGLE AT TOP PERE 33°n_ 9328' Note:Refer to Production DB for historical perf data I SIZE SPF IN1ERVAL Opn/Sqz SHOT SOZ 3-1/8" 4 9328-9350 0 08/09189 3-12' 6 9328-9348 0 03/09/18 I 1-11/16' 8 9444-9452 0 04/29/88 ' 3-1/2' 6 9444-9474 0 03/09/18 1-11/16" 12 9464-9474 0 04/29/88 I 1-11/16' 12 9490-9512 0 04/29/88 ' 3-1/2' 6 9490-9535 0 03/09/18 ' 1-11!16" 12 9519-9529 O 0429/88 9605' —RSH-TT w/NP 8 VVRP(TAGGED 05/03/07) 1-11!16" 8 9540-9560 O 0429/88 1-11/16' 8 9575-9590 0 04/29/88 1-4-1-1017-1-1 FISH-BKR TH2t1 TBG BRDGE RUG (07/20/90) 3-1/8" 4 9605-9620 0 0429/88 1111111, 10163' —IPBTD 7'LN,294,L-80,.0371 bpf,D=6.184" H 10205' .11111/11111111 11/1111 ID — 10210' ' DATE REV BY COM ENT'S DATE REV BY COMbAITS PRUDHOE BAY UNIT 11/05/80 ROWAN 35 ORIGINAL COMPLETION 03/16/10 SW/JMD MN D CORRECTION WELL: 17-05 04/20/07 N4ES RWO 04/22/10 JCM'SV GLV CIO(04/13/10) PB2 AT Na:'1800960 0620!07 G.F/PJC GLV C/O 1220!13 MSS/JIM GLV CIO(12/16/13) API No: 50-029-20508-00 05/12/08 CMC/PJC DRLG DRAFT CORRECTIONS 03/12/18 BTWJMO ADPERFS(03/09/18) SEC 22,T1 ON,R15E,425'FV&&2367'FI& 02/04/10 SCG/PJC GLV CORRECTION 02/27/10 DAV/PJC GLV CIO(0224/10) BP Exploration(Alaska) OPERABLE: 17-OS (PTD# 1800960) A Casing Pressure Manageable Page 1~ Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Sunday, July 25, 2010 5:43 AM ~ ~ ~~ ~~~ t~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); AK, OPS FS2 Facility OTL; AK, OP FS2 DS Ops Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; Schwartz, Guy L (DOA); Cismoski, Doug A; AK, OPS FS2 Facility OTL; AK, OPS FS2 OSM; AK, OPS FS2 OSS Cc: AK, D&C Well Integrity Coordinator; Janowski, Carrie; Longden, Kaity Subject: OPERABLE: 17-05 (PTD# 1800960) OA Casing Pressure Manageable All, Well 17-05 (PTD #1800960) has been confirmed to have hydrates in the OA after a gas sample taken on 07/08/10 showed methane levels ~95%. The OA pressure was bled on 07/11/10 and has since remained below MOASP. The well has been reclassified as Operable. Please notify Well Integrity if the OA pressure becomes unmanageable. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: Quy, Tiffany Sent: Wednesday, July 07, 2010 10:47 AM ~~~. +., 1 a K To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; AK, OPS FSl OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; guy.schwartz@alaska.gov; Cismoski, Doug A Cc: Quy, Tiffany; AK, D&C Well Integrity Coordinator; King, Whitney Subject: UNDER EVALUATION: 17-05 (PTD# 1800960) Sustained OA Casing Pressure All, Well 17-05 (PTD #1800960) has been confirmed to have sust ' ed Outer Annulus casing pressure. The OA was bled 07/05/10 and repressurized 970 psi overnigh he well was worked over and completed with the OA cemented to surface May 2007. The well h been reclassified as Under Evaluation and may continue to be online while further diagnostics are co ducted. The current plan forward is: 1. D: Bleed OA to 0 psi, monitor -DONE 2. D: Obtain IA & OA gas samples/ 3. W: PPPOT-IC Please let me know if you Thank you, Tiffany Tiffany Quy any questions. 8/10/2010 UNDER EVALUATION: 17-OS (PT~1800960) Sustained OA Casing Press Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Thursday, July 15, 2010 2:13 PM To: Regg, James B (DOA) Subject: UNDER EVALUATION: 17-05 (PTD# 1800960) Sustained OA Casing Pressure Attachments: 17-05 TIOs.doc; 17-05 WBS.pdf Jim, I have attached the TIO plot and wellbore schematic per your request. Torin From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, July 15, 2010 12:32 PM To: Quy, Tiffany Subject: RE: UNDER EVALUATION: 17-05 (PTD# 1800960) Sustained OA Casing Pressure TIO plot and Well schematic? Jim Regg ~~~= 53~Ps1 AOGCC Page 1 of 2 333 W.7th Avenue, Suite 100 t, '" ~ '' ~~~C ~~ ~ ' ~ ~~' ~'~ ~ '-"`~ Anchorage, AK 99501 a. ~~ k~ ~"''~ ~ 907-793-1236 ~~'~ Nt3hc~ ~k- ' J From: Quy, Tiffany [mailto:Tiffany.Quy@bp.com] Sent: Wednesday, July 07, 2010 10:47 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); AK, OPS FS1 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; Schwartz, Guy L (DOA); Cismoski, Doug A Cc: Quy, Tiffany; AK, D&C Well Integrity Coordinator; King, Whitney Subject: UNDER EVALUATION: 17-05 (PTD# 1800960) Sustained OA Casing Pressure All, Well 17-05 (PTD #1800960) has been confirmed to have sustained Outer Annulus casing pressure. The OA was bled 07/05/10 and repressurized 970 psi overnight. The well was wore over and competed with the OA cemented to surface Ma~~F a we I has been reclassified as Under Evaluation and may continue to be online while further diagnostics are conducted. The current plan forward is: 1. D: Bleed OA to 0 psi, monitor -DONE 2. D: Obtain IA & OA gas samples C 3. W: PPPOT-IC C--- Please let me know if you have any questions. Thank you, Tiffany Tiffany Quy 7/15/2010 UNDER EVALUATION: 17-OS (PT~1800960) Sustained OA Casing Press Page 2 of 2 (Filling in for Gerald Murphy/Torin Roschinger) Projects Well Integrity Engineer phone: (907) 659-5098 cell: (253) 576-6153 tiffg0@bp.com 7/15/2010 PBU 17-OS PTD #1800960 7/15/2010 TIO Pressures Plot Wet:17-05 6,000 ~ 3,000 1 2,000 - ~ uoo 07/18/09 09/01/09 OB/15/09 08/29/09 09/12/09 09/26/09 10/10/09 01/02/10 01!16!10 O1I30l1n 02!13!10 02/27/10 03/13!10 03/27!10 04.70!10 04!24/10 05/08/10 -~- Tbg -F IA -~- DA OOA • OOOA On eKCPe~S '-~P ~ ~.~ ~ ~u(r ~ rti,I, TREE= 4-1/16" CM/ WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 70' BF. ELEV = ~ 17-05 KOP = 5200' Max Angle = 38° @ 10210' Datum MD = 9408' Datum TV D = 8800' SS 20" CONDUCTOR, 94#, H-40 , ID = 19.124" 110' 9-518" CSG, 47# L-80 TCII XO TO L-80 BTC 2133' 9-518" CSG, 47#, L-80 BTC, ID = 8.681" 2170 13-3/8" CSG, 72#, L-80, ID = 12.347" 2603' r. 9-5/8" CSG, 47#, L-80 XO TO RS-95 8344' Minimum ID = 3.813" @ 2120' 4-112" HES X NIPPLE SAFET ES: ***4-1/2"CHROMETBG*** 2120' -~4-1/2" HES X NIP, ID =3.813" 216 1~ 9-5/8" HES ES CEMENTER GAS UFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 4 3399 3399 1 MMG DOME RK 12 04/13/10 3 5780 5752 22 MMG DOME RK 16 04/13/10 2 7567 7310 29 MMG SO RK 24 04/13110 1 8683 8265 35 MMG DMY RK 0 02(24!10 $754' --~ 4-1/2" HES X NIP, ID =3.813" $"~ ]'S' 9-518" X 4-112" BKR CR S-3 PKR, ID = 3.870" $799' ~-j 4-112" HES X NIP, ID =3.813" 4-112" TBG, 12.6#, 13CR-80 VAM TOP, $$11' .0152 bpf, ID = 3.958" 5-112" TBG STUB $$12' 5-112" TBG-FC, 17#, L-80, .0232 bpf, ID = 4.892" 8856' 4-112" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" ~-L 8868' TOP OF 7" LNR 8899' 9-5/8" CSG, 47#, RS-95, ID = 8.681" ~-~ 9209' PERFORATION SUMMARY REF LOG: BRCS ON 10129!80 ANGLE AT TOP PERF: 33° @ 9328' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-118" 4 9328 - 9350 O 08/09!89 1-11/16" 8 9444 - 9452 O 04/29/88 1-11116" 12 9464 - 9474 O 04129/88 1-11/16" 12 9490 - 9512 O 04129/88 1-11/16" 12 9519 - 9529 O 04129!88 1-11116" 8 9540 - 9560 O 04129!88 1-11116" 8 9575 - 9590 O 04/29188 3-1/8" 4 9605 - 9620 O 04!29(88 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" , 10205' 0 1oz1o' 8$16' ~-i9-5/8"X4-1/2"OVERSHOT GUIDE $$37' 5-1/2" BOT PBR ASSY, ID = 4.938" $857' 9-5/8" X 5-1/2" BKR SAB PKR, ID = 4.75" $$62' 7" MILLOUT EXTENSION, ID = 6.00" $$68~ 7" X 4-112" XO, ID = 3.958" 9605' -FISH - TT w /NIP & WRP (TAGGED 05/03!07) 9809' FISH - BKR THRU TBG BRIDGE PLUG (07/2C 10163' PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 11/05/80 ROWAN 35 ORIGINAL COMPLETION 03/16/10 SWIJMD MIN ID CORRECTON 04/20107 N4ES RWO 04/22/10 JCM/SV GLV CJO (04/13110) 06/20/07 GJFlPJC GLV C/O 05/12/08 CMCdPJC DRLG DRAFT CORRECTIONS 02104!10 SCG/PJC GLV CORRECTION 02/27!10 DAV/PJC GLV C/O (02/24!10) PRUDHOE BAY UNIT WELL: 17-05 PERMIT No: 1800960 API No: 50-029-20508-00 SEC 22, T10N, R15E, 425' FWL & 2367' FNL BP Exploration (Alaska} -- ~ ,~~~ ,_`e o~ ~~ nb t~rp~'e ~ Q? )(~-p!~ 04/21/10 $GhlUmh~rger ! ~~mj,~ C- I, O ~~E;""~~ NO. 5511 S~ r; +r~~. 9.+ /Sty'.'`-: 'a, ;~, Alaska Data & Consulting Services Company: State of Alaska ~t~~l 2525 Gamball Street, Suite 400 Alaska Oil & Gas COnS Comm ~ Anchorage, AK 9aso3-2ea8 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 89501 Well Job R Log Description Date BL Color CD F-30 12-14AL1 12-15 BBUO-00014 AYKP-00079 B3S0-00049 PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE 03/17/10 03/18/10 - 03/18/10 1 1 1 1 1 1 17-11 17-05 J-23A 07-18 B3S0-00053 8350-00052 BCUE-00010 BC72-00006 PRODUCTION PROFILE - PRODUCTION PROFILE MEM PRODUCTION PROFIL C FL DETERMINATIOWPERF LE 03/30/10 03/29!10 04/14/10 04/17/10 04/14/10 04/17/10 1 1 1 1 1 1 1 1 1 1 1 1 P2-31A B3S0-00046 _ CH EDIT PDC JUNK BASKET - 02/27/20 1 C-15A AWJI-00068 MCNL - L 01/27/10 1 y K-07E B2NJ-00054 MCNL 02/18/10 1 1 01-28A BAUJ-00004 MCNL 12/18/09 1 1 PLEASE Ar:KNr)WI Enr:E REl `EIOT wv clnu~u r nun oe~r„ownwv-..u~ n...,.. ,-..... ~.._ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2839 i t ~~;~~ 6~ V Sehlumb~rger Alaska Data & Consulting Services 2525 Gambell Street, Suke 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Alaska Data 8 Consulting Services 2525 Gambell Street, Sude 400 Anchomge, AK 99503-293e P2-31 A S-134 P2-31A BBKA-00014 AP3O-00083 B14B-00101 CEMENT BOND LOG INJECTION PROFB.E U USIT U - 03/16/10 03/26/10 03/27/10 1 1 Y 1 1 1 03-22 17-078 17-05 17-11 BSJN-00047 BD88-00007 63S0-00052 8350-OOD53 PRODUCTION PROFILE MEM PRODUCTION PROFILE / PRODUCTION PROFILE PRODUCTION PROFILE 03/28/10 03/28/10 03/28/10 03/30/10 1 1 1 1 1 1 1 1 03-22 14.32 85JN-00047 BAUJ-00012 RST/JEWELRY LOG MEM PRODUCTION PROFILE 03/30/10 03/31/10 1 1 1 1 W-25A AWYZ-00004 CH EDIT PDC DDL ~ 12/08/09 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. 04/05/10 ~.. ~.. ~~ NO. 5495 Company: State of Alaska Alaska Oil &Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD . ~ . STATE OF ALASKA _ ¿~-p; RECEIVED ALASKA OIL AND GAS CONSERVATION CO~SION REPORT OF SUNDRY WELL OPERATIONS JUN 0 7 2007 III__I,^ na 51, r...... rnn... 1. Operations Performed: Anchora~e o Abandon ~ Repair Well o Plug Perforations o Stimulate ORe-Enter Suspen ed Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 180-096 ~ 3. Address: o Service o Stratigraphic 6, API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20508-00-00 7. KB Elevation (ft): 70' , 9. Well Name and Number: PBU 17-05 , 8. Property Designation: 10. Field / Pool(s): ADL 028334 - Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10210 feet true vertical 9525 - feet Plugs (measured) None Effective depth: measured 10163 feet Junk (measured) Below 9605 true vertical 9488 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2603' 13-3/8" 2603' 2603' 4930 2670 Intermediate 9209' 9-518" 9209' 8702' 6870 4760 Production Liner 1306' 7" 8899' - 10205' 8443' - 9521' 8160 7020 SCANNED JUN 2 6 2007 Perforation Depth MD (ft): 9328' - 9620' Perforation Depth TVD (ft): 8803' - 9047' 4-1/2",12.6# x 5-1/2", 17#x 13Cr80 / L-80 / 8944' Tubing Size (size, grade, and measured depth): 4-1/?" 1? ß# N-RO 9-5/8" x 4-1/2" Baker 'S-3' packer ..' ~ 8775' Packers and SSSV (type and measured depth): 9-5/8" x 5-1/2" Baker 'SAB' packer 8857' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from -8808', Cut and pull 9-5/8" casing from -2168', Run 9-5/8" Tieback to surface (L-80, TC-II). Cement with 146 Bbls Class 'G' (820 cu ft /707 sx). Run new 4-1/2" Chrome tubina with overshot to 8816', 13. Representative Daily Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG DGINJ DWINJ o 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 David Reem, 564-5743 307 -011 Printed Name Terrie Hubble Title Technical Assistant Signature /fÓ J\!\iø ,~ O<07r. ' / {) 7' Prepared By Name/Number: Phone 564-4628 Date Dr. Terrie Hubble, 564-4628 ion Form 10-404 Revised 04/200j~) RIG N A L RBDMS BFL JUN 1 8 2007 ~ I..,,", Submit Original Only Digital Wellfile . Page 1 of 2 . Well: 17-05 Well Events for SurfaceWell - 17-05 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS2 -> 17 -> 17-05 Date Range: 18/Dec/2006 to 20/Apr/2007 Data Source(s): AWGRS Description PULL BPV , RIG MOVED OVER HOLE SET 5" FMC BPV PRE RIG WORK API VALVE SHOP WF WRP MONTHLY RENTAL FOR 02/02/07 - 04/02/07 MOs 7 & 8. NOTE: WRP SET ON 08/06/06 NOTE: WATCH FOR PLUG PULLED DURING RWO Cost Placeholder for Machine shop / Valve seats WF WRP MONTHLY RENTAL FOR 01/03/07 - 02/01/07 MOs 6. NOTE: WRP SET ON 08/06/06 NOTE: WATCH FOR PLUG PULLED DURING RWO T/IA/OA= 0/0/0 Well head repair. Backed out the other [5] bad LDS and left out. [4] one casing spool [1] on tubing spool. Drilled out [1] on casing spool and installed blanking plug. T/I/O=O/O/O. Temp=S1. AL spool removed and integral flange installed. LDS Drill out. (pre- RWO). Flow line pressure increased to 530 psi from 0 psi overnight. Bled Flowline from 530 psi to 0 psi in 60 minutes. TBG FL @ 54' «2 bbl). IA FL @ 27' «2 bbl). OA FL @ 66' «4 bbl). Cameron got 4 out of 5 LDS to function and drilled out the last one. LDS drill out complete. Final WHP's=O/O/O. PULLED BPV TO COMPLETE WELL WORK PRE RIG API VALVE SHOP T/IA/OA= Well head repair. repair LDS on FMC Gen II. Drill nose off [1] LDS and installed blank. Was able to back out [3] other LDS *** still in progress **** T/I/O=O/O/O. Temp=S1. AL spool removed and integral installed. LDS Drill out. (Pre-RWO). TBG FL @ 24' «1 bbl). IA FL @ 36' «2 bbl). OA FL @ 72' «5 bbl). Flow line increased 14 psi overnight to 22 psi, bled flow line from 22 psi to 0 psi in 1 hour. 10 stuck LDS, Cameron drilled out 1 and loosened 4 (so far). Job incomplete, to be continued. Final WHP's=O/O/O. 01/17/2007 T/IA/OA= Well head repair drill LDS, mechanical problems, ****still in progress **** 01/17/2007 T/I/O=O/Vac/O. Temp=S1. AL spool removed and integral flange installed. Drill LDS (Postponed). (Pre RWO). R/U open bleed on OA and Monitor Vac on IA. Flow line between wing valve and lateral valve @ 880 psi. Bled flow line from 880 psi to 400 psi in 20 minutes. Lateral valve leaking by. Called Valve crew to service valve. Bled Flow line from 400 psi to 0 psi in 45 minutes, 51 and monitor for 15 minutes. Flow line pressure increased 8 psi in 15 minutes. Final WHP's=O/Vac/O. T/I/O= O/Vac/O. Temp= 51. AL disconnected. WHP's & FL's. (Pre-LDS drill out).TBG FL @ 24' « 1 bbl). IA FL @ 36' « 2 bbls). OA FL @ 42' « 3 bbls). Tree well head repair: Prep for LDS drill out on tubing and casing spool. Well head repair: Work on stuck LDS {6} on tubing spool flats started twisting off. Others on tubing spool broke free, Upper flange on casing spool all but {4} broke free, lower flange on tubing spool still needs done. FMC gen II Well head MIT: Re-installed heater on well head to work LDS next day. Ordered air compressor. SET BPV T/I/O=O/O/O, Pre-Rig, PPPOT-T(PASS), PPPOT-IC (PASS). PPPOT-T. Sting into TBG hanger test void, 1200 psi, bled test void pressure to 0 psi (gas/fliud). Monitored for 15 min, no pressure build-up. Pumped through void untill clean fluid was achieved from off side test port. Pressured void to 5000 psi, lost 60 psi in first 15 min, 40 psi in second 15 min. PPPOT-IC. Sting into IC hanger test void, 50 psi, bled test void pressure to 0 psi. Monitored for 15 min, no pressure build-up. Pumped into void until clean fluid was achieved from off side test port. Pressured void to 3000 psi, held for 30 min with no loss of pressure. Attempt to torque LDS on FMC Gen II wellhead. LDS tight, flats started twisting. 12/31/2006 ***WSR continued from 12/30/06*** T/I/O= 200/150/20. CIRC OUT WELL (PRE RWO). Pump 5 bbls of meth, 873 bbls of 1 % KCL, and 150 bbls of diesel into the TBG while taking IA returns to the flowline. U-Tube the Tx IA. CMIT-Tx IA to 3500 psi. PASSED the first attempt. TBG and IA lost 40 psi / 1st 15 min and 40 psi / 2nd 15 min. MITOA PASSED to 3000 psi. Pressured OA to 3000 psi with 4.8 bbls of diesel. MITOA lost 100 psi 1st 15 minutes and 40 psi 2nd 15 minutes for a total of 140 psi during 30 minute test. Bled OA to 0 psi. Freeze protected flowline. FWHP's=O/O/O. 12/30/2006 T/I/0=200/150/20. CIRC OUT WELL All Fluid Totals on next days' WSR (PRE RWO) ***WSR continues on 12/31/06*** Events Source Well Date A'lýJ~.ßS 17-05 04/20/2007 AWGRS 17-05 04/06/2007 AWGRS 17-05 03/12/2007 AWGRS 17-05 02/18/2007 .f>...WGRS 17-05 02/06/2007 AWGRS 17-05 01/19/2007 AWGRS 17-05 01/19/2007 AWGßS 17-05 01/18/2007 AWGRS 17-05 01/18/2007 AWGRS 17-05 01/18/2007 AWfißS 17-05 AWGRS 17-05 AWGRS 17-05 01/17/2007 AWGRS 17-05 01/16/2007 AW~RS 17-05 01/11/2007 AWGRS 17-05 01/09/2007 AWGRS 17-05 01/08/2007 AWGRS 17-05 01/01/2007 AWGRS 17-05 AWGRS 17-05 http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 6/6/2007 Digital Wellfile AWGRS 17-05 12/21/2006 AWGRS 17-05 12/21/2006 AWGRS 17-05 12/21/2006 AWGRS 17-05 12/21/2006 AWgRS 17-05 12/18/2006 . Page 2 of2 ***WHP 500/300/0 PSI JEWELRY LOG - RIH TO 887.AX O.D. 1.6875" RIH WITH 4.150" POWER CUTTER TO 8858', CUT 5 1/2" AT 8814' FINAL WHP 500/300/0 PSI PAD OP NOTIFIED UPON DEPARTURE. ***Job complete*** ***WHP 500/300/0 PSI JEWELRY LOG - RIH TO 8878 , MAX O.D. 1.6875" RIH WITH 4.150" POWER CUTTER TO 8858', CUT 5 1/2" AT 8814' FINAL WHP 500/300/0 PSI PAD OP NOTIFIED UPON DEPARTURE. ***WHP 500/300/0 PSI JEWELRY LOG - RIH TO 8878 , MAX O.D. 1.6875" RIH WITH 4.150" POWER CUTTER TO 8858', CUT 5 1/2" AT 8814' FINAL WHP 500/300/0 PSI PAD OP NOTIFIED UPON DEPARTURE. WF WRP MONTHLY RENTAL FOR 10/05/06 - 01/02/07. MOs 3, 4 & 5. NOTE: WRP SET ON 08/06/06 *** WELL 5/1 ON ARRIVAL *** (Pre RWO) DUMPED (2) BAGS OF SLUGGITS ON TOP OF WRP @ 8881' SLM DRIFT TO 8865' SLM W/ 4.375" VARIABLE CENT FOR JET CUTTER ***WELL 5/1 ON DEPARTURE*** (Notify DSO) http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 6/6/2007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-05 1 7-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/18/2007 Rig Release: 5/9/2007 Rig Number: Spud Date: 10/13/1980 End: 5/9/2007 4/20/2007 00:00 - 11 :00 11,00 MOB P PRE 11 :00 - 15:00 4,00 RIGU P PRE 15:00 - 19:00 4,00 MOB P PRE 19:00 - 22:30 3,50 WHSUR P WHDTRE 22:30 - 23:30 1.00 WHSUR P WHDTRE 23:30 - 00:00 0,50 WHSUR P WHDTRE 4/21/2007 00:00 - 00:45 0,75 WHSUR P DECOMP 00:45 - 01 :45 1,00 WHSUR P DECOMP 01 :45 - 04:00 2.25 WHSUR P DECOMP 04:00 - 08:00 4,00 WHSUR P DECOMP 08:00 - 09:30 1,50 WHSUR N SFAL DECOMP 09:30 . 11 :30 2,00 WHSUR N SFAL DECOMP 11 :30 - 12:00 0,50 WHSUR N SFAL DECOMP 12:00 - 13:00 1,00 WHSUR N SFAL DECOMP 13:00 - 13:30 0,50 WHSUR N DECOMP 13:30 - 14:00 0,50 WHSUR N DECOMP 14:00 - 17:00 3,00 WHSUR N DECOMP 17:00 - 18:00 1,00 WHSUR N DECOMP 18:00 - 20:30 2,50 WHSUR P DECOMP 20:30 - 00:00 3,50 WHSUR P DECOMP 4/22/2007 00:00 - 01 :30 1,50 BOPSU P DECOMP 01 :30 - 03:00 1.50 BOPSU DECOMP 03:00 - 06:00 3,00 BOPSU DECOMP 06:00 - 06:30 0.50 BOPSU DECOMP 06:30 - 07:30 1,00 BOPSU DECOMP 07:30 - 08:00 0,50 BOPSU DECOMP 08:00 - 08:30 0,50 BOPSU DECOMP 08:30 - 10:00 1,50 BOPSU DECOMP 10:00 - 10:30 0,50 BOPSU DECOMP 10:30 - 13:00 2,50 PULL DECOMP Move from Pt Mac 2-59 to DS 17-05. Move was 17 miles. Spot Sub, Pits, pipe shed and Camp. Raise and scope derrick, r/u lines to pits, MIRU, Line-up to circulate well. ACCEPTED RIG @ 15:00 HOURS, Hold Pre-Spud meeting/PJSM: circulate/well kill. PT lines and circulate 600 bbls of 13 deg F Sea Water down tbg and out IA. Check well for flow: Well Dead, CMIT to 3500 psi for 15 minutes, Good test. Set ISA BPV, Test from below. Leaks. Call out Wells Support for lubricator and redressed BPV to pull and re-set BPV. Wait on Wells Support for Lubricator and BPV, Wait on Wells Support Lubricator. Wells Support on location, RU lubricator, pull BPV. Inspect- no damage, Run redressed BPV. PT to 1000 psi from below for 10 minutes, Good test. ND Tree, Inspect tbg hanger threads (Good) & count turns to MU: 7 turns LH Thread. Install test plug, NU BOPE. NU BOPE, Could not back-out alignment pin. attempt to test TWC, Would not hold pressure, leaking out annulus, Drain BOP stack. W/O FMC to pull blanking plug, Pull blanking plug, Inspect same no damage seen. Re-dress & Re·set plug, Attempt to tesUailed. Pull banking Plug. P/U lubricator & pull BPV, UD same. P/U kelly & test Upper kelly valve, LP 250 psi, HP 3500 psi. tested Ok, Drain & set back kelly. Hold PJSM & review plan to set WRP in 51/2" tubing. RlU slickline equip, Re·head wire, RIH w/ 4,6" drift on slickline. Drift to 2117' SLM, POOH & UD drift, MU 5/12" WRP on SWS setting tools, RIH and set @ 1440' MD, POOH and RD SL. Test BOPE. Test BOPE. Witness waived by Tom Maunder @ 02:00 4/21/2007 Hold PJSM: RU SL & RIH f/plug. Hitting Plug w/1500# OJ licks (.125 wire), Parted SL. Hold PJSM: pulling broken wire OOH, Clear all hands from floor notify all personnell onsite of hazards and POOH slowly. Wire apparently broken @ thimble on bottom. Cut wire sample and twist test (23 turns), Crew Change. Check PVT alarms. Inspect derrick. Re·head wireline. Re-dress tools, RIH w/ JU pulling tool. Recover tool string left in hole, UD same. Change out tools to recover WRP, RIH w/ GS pulling tool. Latch up on plug & equalize. Jar plug free. POOH. Plug hanging up & having to jar occasionally, POOH & UD GS tool & WRP, RID slick line equip, M/U double grapple spear on 1 jt of 31/2" DP. RIH & engage Printed: 5/14/2007 10:50:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-05 1 7-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/18/2007 Rig Release: 5/9/2007 Rig Number: Spud Date: 10/13/1980 End: 5/9/2007 4/22/2007 10:30 - 13:00 2,50 PULL P DECOMP Spear into 5 1/2" tbg, Bleed off control lines, BOLDS. LDS very tight & corroded. Much difficulty backing out. 13:00 - 14:30 1.50 PULL P DECOMP Pull hanger to floor. Work pipe from 175K to 250K. String started to move. Weight slowly dropped off to 190K, then to 160K, Dragging up to 195K while pulling to surface. 14:30 - 16:30 2,00 PULL P DECOMP Circulate bottoms up, pump 6 BPM @ 210 psi. Had small amount of gas to surface, String weight dropped off from 160K to 140K while circulating, 16:30 - 19:00 2,50 PULL P DECOMP POOH & UD 5 1/2" completion, Spool up control line, 19:00 - 21 :30 2,50 PULL P DECOMP Getting some flow thru the tbg @ 30 joints OOH. RU circulating head and circulate bottoms up, Get some gas back @ bottoms up. Circulate all the way around. SD and check tbg and still getting some flow. Circulate another bottoms up, SD for 15 minutes and monitor - no flow. Continue OOH 21 :30 - 00:00 2,50 PULL P DECOMP @ 54 jts OOH LD SSSV, RD spooler. 54 Bands OOH -looks like we got them all. Lost -10% of plastic sheathing over control lines, Continue OOH. 4/23/2007 00:00 - 06:00 6,00 PULL P DECOMP POOH w 5 1/2" completion tbg, Inspect hole in GLM #3 (was patched) & took pictures, Continue OOH w/ tbg. Recovered 54 SS control bands, 1 SSSV Assy, 10 GLM Assys, 1 Sliding Sleeve Assy, 217 Jts of 5 1/2" tubing, + 19,47' Cut Off Jt. Cut was belled to 6 1/16", Otherwise nice clean uniform cut. noted Hydrogen sulfite on outside of tubes, corroded pins & pitting on inside of tubes, 06:00 - 07:30 1,50 PULL P DECOMP Clear & clean rig floor, RID tubing handling tools. 07:30 - 08:30 1,00 CLEAN P DECOMP RlU floor to P/U BHA #1 & DP. 08:30 - 10:30 2,00 CLEAN P DECOMP Load, Tally & M/U BHA #1 as follows: Shoe, Ext, Dress off Mill, Boot Basket, PxP, Boot Basket, Csg Scraper, 2 . Boot Baskets, Bit, Sub, Bumper Sub, Jars, Xo, 3' 6 1/4" DCs, XO, XO. TL = 148,18' 10:30 - 17:00 6,50 CLEAN P DECOMP P/U 3 1/2" DP, 1 x 1 & RIH w/ BHA #1, P/U 274 jts, 17:00 - 17:30 0,50 CLEAN P DECOMP P/U kelly, break circulation. RIH & tag up on fill @ 8783'. P/U kelly wash & rotate from 8783 to 8808'. P/U & verify top of tbg stub @ 8808'. Rotate down over tbg stub to 8815' Mill & dress off l' to 8816'. P/U wt = 135K, S/O wt = 124K, Rot = 130K, 40·50 RPMs, 5 BPM @ 1000 psi. Torq = 2-5K ft-Ibs. 17:30 - 20:00 2.50 CLEAN P DECOMP Circulate & sweep hole w/32 bbl Hi-Vis pill. Pump 5 BPM @ 960 psi. 20:00 - 23:30 3.50 CLEAN P DECOMP Bottoms up and SI well. 150 psi on Drillpipe, CBU again. Get a little gas back, SD and monitor: no flow 23:30 - 00:00 0.50 PULL P DECOMP POOH, 4/24/2007 00:00 - 06:00 6.00 CASE P TIEB1 POOH, Started to flow -30 stds off-bottom. Circulate a few bbls and continue OOH, Having to circ every 10 stds or so due to out-of-balance fluid (9,8 ppg that was loadeed into IA before we showed up and probably never fully circed out due to hole in GLM). 06:00 - 07:00 1,00 CASE P TIEB1 LD BHA. Empty junk baskets, Recovered 5 gals. of Scale, hydogen sulfite & 1 SS Control Band. Mill had good 5 1/2" ring on mill face. 07:00 - 08:00 1.00 EVAL P TIEB1 N/D flow nipple, N/U Shooting Flange. 08:00 - 10:00 2,00 EVAL P TIEB1 RlU E-line equip. P/U US IT tools. 10:00·18:00 8,00 EVAL P TIEB1 RIH w/ USIT & log from 8790' to surface. Logged in cement and corrosion modes, Printed: 5/14/2007 10:50:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -05 17-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/18/2007 Rig Release: 5/9/2007 Rig Number: Spud Date: 10/13/1980 End: 5/9/2007 4/24/2007 18:00 - 20:30 2.50 EVAL P TIEB1 RD E-line service. RD shooting flange. Installed upper and lower air boots and flow riser. 20:30 - 22:00 1,50 DHB P TIEB1 PUMU RBP. RIH on 3-1/2" DP, Set RBP @ 3137' DPM. 22:00 - 22:30 0,50 DHB P TIEB1 RU, successfully tested RBP to 2000 psi for 15 min (charted). 22:30 - 00:00 1,50 DHB P TIEB1 Dumped 2200 Ib sand on RBP, Tagged sand @ 3110' DPM. 4/25/2007 00:00 - 01 :00 1,00 FISH P TIEB1 Held Weekly Safety Meeting with all rig personnel. 01 :00 - 03:00 2,00 FISH P TIEB1 Displaced well to 9.8 ppg brine, 03:00 - 04:00 1,00 FISH P TIEB1 POH, LD RBP running tool. 04:00 - 07:00 3.00 FISH P TIEB1 Held Fire Drill. Held PJSM, ND BOPE. 07:00 - 09:00 2.00 FISH P TIEB1 PJSM, Remove old tubing spool & pack off, install new tubing spool. 09:00 - 11 :30 2,50 FISH P TIEB1 PJSM. Nipple up BOPE, flow nipple, test breaks to 1000 psi, OK, 11 :30 - 12:30 1,00 FISH P TIEB1 PJSM. Pick up 9 5/8" multi string cutter BHA. 12:30 - 13:30 1,00 FISH P TIEB1 PJSM, RIH wI Multi string cutter on 22 stands 3 1/2" DP, 13:30 - 15:00 1.50 FISH P TIEB1 PJSM. Kelly up, establish parameters. 50K up wt, 50K down wt, 50K rotating wt, Bring on pump @ 3 1/2 bpm / 650 psi & slack off, take weight wI cutter blades @ 2195' DPM. Lay down single, kelly back up, locate blades @ 2170' DPM, engage rotary table @ 60 RPM & bring on pump @ 3 1/2 bpm I 650 psi. After 10 minutes observe torque climb to 10,000 ftIlbs at surface, almost stall & break free, Increase pump rate to 4 1/2 bpm I 950 psi. Observe torque climb again, almost stall & break free, continue wI cutting, Observe pressure drop to 550 psi @ 5 bpm & torque drop off, Observe OIA pressure climb to 300 psi, indicating good cut. 15:00 - 16:00 1.00 FISH P TIEB1 PJSM, Line up & circulate 80 bbls of 110 degree 9,8 ppg brine, seeing arctic pack returns, thru choke to open top tank. Not much gas in returns. Rig up Little Red. 16:00 - 22:30 6.50 FISH P TIEB1 PJSM, Line up Little Red & pump 50 bbls of 160 degree diesel, displace w/15 bbls of 9,8 ppg brine, Let soak for 30 minutes & pump another 50 bbls hot diesel & displace w/15 bbls of 9,8 ppg brine, Let soak for 30 minutes, Repeated for a total of three diesel I brine I soak sequences. 22:30 - 23:00 0,50 FISH P TIEB1 Circulated diesel from well bore. 23:00 - 00:00 1,00 FISH P TIEB1 Waited for brine delivery, 4/26/2007 00:00 - 01 :00 1,00 FISH P TIEB1 POH with casing cutting assembly, 01 :00 - 02:30 1.50 FISH P TIEB1 LD casing cutting assembly; cleared rig floor. 02:30 - 03:30 1.00 FISH P TIEB1 PU/MU casing spear assembly, RU to recover 9-5/8" casing, 03:30 - 04:00 0,50 FISH P TIEB1 Engaged casing with grapple, pulled hanger and 9-5/8" casing free with 105k Ib PU, 04:00 - 06:00 2.00 FISH P TIEB1 Held PJSM. BO and LD casing hanger. POH, LD 9-5/8" casing, 06:00 - 06:30 0,50 FISH P TIEB1 Servicde rig, check crown 0 matic, PVTs, OK, 06:30 - 14:30 8,00 FISH P TIEB1 PJSM. Continue to POOH & UD 9 5/8" casing. Laid down 52 jts plus 16,20' of cut off jt. Recovered 13 bow spring centralizers, missing 1/2 of (8) centralizers, 14:30 - 16:00 1,50 FISH P TIEB1 Clear I clean rig floor. 16:00 - 18:00 2,00 FISH P TIEB1 PJSM. Pick up & M/U burn shoe I wash pipe BHA to dress off 9 5/8" casing stub, Held crew change I handover, 18:00 - 19:00 1,00 FISH P TIEB1 Checked PVT alarms, inspected derrick, installed wear bushing, 19:00 - 21 :00 2,00 FISH P TIEB1 Continued MU dress-off BHA. RIH, PU kelly, tagged 9-5/8" Printed: 5/14/2007 10:50:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-05 1 7-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/18/2007 Rig Release: 5/9/2007 Rig Number: Spud Date: 10/13/1980 End: 5/9/2007 4/26/2007 19:00 - 21:00 2.00 FISH P TIEB1 casing stub @ 2170' DPM. 21 :00 - 22:00 1.00 FISH P TIEB1 Swallowed casing stub with OS to 2174' DPM, Milled to OS depth of 2175' DPM. Top of casing stub @ 2171' DPM, 22:00 - 23:30 1,50 FISH P TIEB1 Circulated 40 bbl high-vis sweep. Observed small amount of fine metal in returns, 23:30 - 00:00 0,50 FISH P TIEB1 Set back kelly, POOH, 4/27/2007 00:00 - 01 :00 1,00 FISH P TIEB1 POH with casing dress-off assembly, 01 :00 - 02:30 1,50 FISH P TIEB1 LD BHA, RD handling equipment, cleared rig floor. 02:30 - 04:00 1,50 CASE P TIEB1 Pulled wear bushing. RU to run 9-5/8" tieback, 04:00 - 06:00 2,00 CASE P TIEB1 Held PJSM, RIH with casing patch, baffle plate with plug, pup jt, ES cementer, XO, and 9-5/8" tieback casing. Filled casing with 9,8 ppg brine each 5 jts. 5 jts in hole @ 0530 hrs. 06:00 - 06:30 0.50 CASE P TIEB1 Service rig, check crown 0 matic, PVTs, OK. 06:30 - 12:00 5,50 CASE P TIEB1 PJSM, Continue to RIH w/9 5/8" L-80, TCII, 47# casing, filling casing every 5 jts wI 9.8 ppg brine, torque turning each connection to 17,500 ftllbs, using Jet Lube Seal Guard thread compound. Run (57 jts. 12:00 - 13:00 1,00 CASE P TIEB1 PJSM. Establish parameters. Up wt 97K, Down wt 97K, Run in jt #57 30' in, engage tongs & rotate 9 5/8" to the right, 1500 - 2500 ftllbs to turn pipe, slack off while rotating to get cut lip guide & casing patch I overshot over 9 5/8' stub. Make several attempts before successful, stack out 33 1/2' in on jt # 57. Pick up to 127K, (30K over up wt), OK, 13:00 - 14:00 1,00 CASE P TIEB1 PJSM. Pick up I make up cementing head, install plug, 14:00 - 15:00 1,00 CASE P TIEB1 PJSM, Pull to 250K to ensure patch is holding, OK, slack off to 150K. Pressure up 9 5/8" casing to 2000 psi 115 minutes I charted, good test. Pressure up to 3400 psi to open ES cementer & circulate thru same to verify, OK. 15:00 - 16:00 1,00 CASE P TIEB1 PJSM, Split BOP stack, install emergency slips, set same wI 250K, 16:00 - 18:00 2,00 CASE P TIEB1 PJSM, N/U Stack. 18:00 - 20:30 2,50 CEMT P TIEB1 Circulated 9,8 ppg brine to warm well bore to 80 deg F in preparation for cementing, 20:30 - 21 :00 0.50 CEMT P TIEB1 Held PJSM with all personnel involved in cementing operation. 21 :00 - 23:00 2,00 CEMT P TIEB1 Tested lines to 4000 psi. Cemented 9-5/8" tieback as follows: 5 bbls fresh water spacer, 146 bbls 15.8 ppg CI G cement plus additives, 167 bbls 9,8 ppg brine displacement. Had cement returns to surface, Bumped plug, increased pressure to 1900 psi to close ES cementer, CIP @ 22:45 hrs. Bled pressure, had no flow back, Obtained slurry samples for lab analysis. 23:00 - 00:00 1,00 CEMT P TIEB1 RD cementing equipment. Flushed and RD cement lines. 4/28/2007 00:00 - 01 :00 1,00 CEMT P TIEB1 RD cementing head, drained stack and casing. 01 :00 - 02:30 1.50 FISH P TIEB1 ND BOPE and raised stack. 02:30 - 03:30 1.00 FISH P TIEB1 RU Wachs cutter and cut 9-5/8" casing. LD 30,25' cut piece. 03:30 - 06:00 2.50 WHSUR P TIEB1 Set back BOPE. Removed tubing spool. Dressed casing cut. 06:00 - 09:00 3,00 WHSUR P TIEB1 PJSM, Install pack off & test @ 3800 psi I 30 minutes I witnessed, OK, 09:00 - 11 :00 2,00 WHSUR P TIEB1 PJSM, N/U BOPE, rig up test equipment. 11 :00 - 18:00 7,00 WHSUR P TIEB1 PJSM, Conduct weekly BOPE test of all components as per AOGCC requirements, Witnessing of test waived by AOGCC State Rep Jeff Jones, test witnessed by Nabors Toolpusher and BP Well Site Leader. 18:00 - 20:30 2,50 WHSUR N TIEB1 Pulled test plug, Recovered piece of one centralizer bow Printed: 5/14/2007 10:50:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-05 1 7-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/18/2007 Rig Release: 5/9/2007 Rig Number: Spud Date: 10/13/1980 End: 5/9/2007 4/28/2007 18:00 - 20:30 2.50 WHSUR N TIEB1 spring from top of test plug. Opened B/S ram cavity, recovered 2nd piece of bow spring from top of ram. 20:30 - 22:00 1.50 WHSUR N TIEB1 Resealed BIS ram cavity. RU, installed test plug. Retested ram body 250 psi low I 3500 psi high, 22:00 - 00:00 2,00 FISH P TIEB1 Pulled test plug. Installed wear ring, RU, PUMU milling BHA #4. 4/29/2007 00:00 - 01 :00 1,00 FISH P TIEB1 Continued PUMU BHA #4, 01 :00 - 02:00 1,00 FISH P TIEB1 RIH with mill on BHA #4. 02:00 - 06:00 4,00 FISH P TIEB1 Tagged contaminated cement @ 2108' DPM. Milled ratty cement to 2150', then hard cement to ES cementer @ 2160' DPM, 06:00 - 09:30 3.50 FISH P TIEB1 PJSM. Establish parameters, 49K up wt, 47K down wt, 49K rotating wt. Rotating @ 80 RPM, 1000 - 2000 ftllbs of torque, 10 -15K WOB, pumping 2 bpm 1200 psi. Continue milling on ES cementer @ 2161'. Unable to make any hole using various techniques, 09:30 - 10:30 1,00 FISH P TIEB1 PJSM, POOH w/3 1/2" DP & milling BHA. 10:30 - 12:30 2,00 FISH P TIEB1 PJSM, UD junk mill, junk subs empty, no metal, pick up (6) more 6 1/4" drill collars, M/U 8 1/2" medium tooth rock bit (BHA #5), 12:30 - 13:30 1.00 FISH P TIEB1 PJSM. RIH w/3 1/2" DP, (19 stands). 13:30 - 15:00 1,50 FISH P TIEB1 PJSM. Pick up (1) single, pick up kelly & run in 18', tag @ 2161'. Establish parameters, 70K up wt, 70K down wt, 70K rotating wt, Kick in rotary table @ 80 RPM, 2000 ftllbs off bottom torque, kick in pump @ 4 1/2 bpm 1200 psi. Mill @ 2161 w/10K WOB. Mill to 2168', Pump 20 bbls Hi Vis sweep, drill up baffle plate f/2168' - 2170'. Stand back kelly. 15:00 - 16:00 1,00 FISH P TIEB1 PJSM. RIH wI (29) stands total, kelly up & tag top of junk Isand @ 3092', (26' in on kelly), Mill 3' to 3095'. 16:00 - 17:30 1,50 FISH P TIEB1 PJSM, Pump 25 bbls Hi Vis sweep & chase wI seawater, Displace well bore to seawater, 5 1/2 bpm @ 350 psi. 17:30 - 18:00 0.50 FISH P TIEB1 POH with BHA #5 on 3-1/2" DP. 18:00 - 18:30 0.50 FISH P TIEB1 Held crew change, Performed pre-tour checks. 18:30 - 19:00 0.50 FISH P TIEB1 Continued POH with BHA #5, 19:00 - 20:30 1,50 FISH P TIEB1 LD BHA #5, Recovered approximately 3 gallons debris (cement, metal chunks) from boot baskets. 20:30 - 21 :30 1,00 FISH P TIEB1 RU, sucessfully tested 9-5/8" casing to 3500 psi for 30 minutes. 21 :30 - 23:00 1.50 FISH P TIEB1 PUMU BHA #6 (RCJB with casing scraper). 23:00 - 00:00 1.00 FISH P TIEB1 RIH with BHA #6. 4/30/2007 00:00 - 00:30 0.50 FISH P TIEB1 Continued RIH with BHA #6 to 3088'. 00:30 - 01 :00 0.50 FISH P TIEB1 MU kelly. Dropped ball to seat. Tagged sand @ 3094', Rotated and washed with RCJB to 3104'. 01 :00 - 02:30 1,50 FISH P TIEB1 Circulated until returns were sand-free. 02:30 - 04:30 2,00 FISH P TIEB1 POH with BHA #6, Held two D1 Drills, 04:30 - 06:00 1.50 FISH P TIEB1 LD BHA #6. 06:00 - 06:30 0.50 FISH P TIEB1 PJSM. Service rig, check crown 0 matic, PVT system, OK, 06:30 - 07:30 1,00 FISH P TIEB1 Reassemble Reverse circulating junk basket assembly (BHA #7), fingers approximately (2') from end of shoe, 07:30 - 09:00 1,50 FISH P TIEB1 PJSM. RIH wI 31 stands 3 1/2" DP. 09:00 - 10:00 1.00 FISH P TIEB1 PJSM, Kelly up, bring on pump @ 5 bpm I 500 psi to clear tool. Establish paramters. 60K up wt, 60K down wt, 61 K rotating wt, 2000 ftllbs of off bottom torque, Break kelly, drop l' ball, kelly Printed: 5/14/2007 10:50:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -05 1 7-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/18/2007 Rig Release: 5/9/2007 Rig Number: Spud Date: 10/13/1980 End: 5/9/2007 4/30/2007 09:00 - 10:00 1,00 FISH P TIEB1 up & pump ball on seat, see 1350 psi @ 4 1/2 bpm, Kill pump, RIH, tag top of sand I junk 20' in on kelly @ 3108', Pick up & engage rotary table @ 10 RPM, run back in & core about 2 1/2', kick on pump @ 4112 bpm 11400 psi, won't go down, pick up see 10K overpull, stop & let work free while circulating, pick up free, OK, go back down rotating slowly wI pump @ 4 1/2 bpm, chase sand junk to 3120' wI no resistance. 10:00 - 11 :00 1,00 FISH P TIEB1 PJSM, Circulate sand out @ 5 bpm 11700 psi. 11 :00 - 12:30 1,50 FISH P TIEB1 PJSM. Slip & cut 84' of drilling line. 12:30 - 14:00 1.50 FISH P TIEB1 PJSM. POOH w/3 1/2" DP, 14:00 - 15:30 1.50 FISH P TIEB1 PJSM. Break down BHA #7, empty junk subs & RCJB. Recovered ring & (3) bow springs wI some rubber & smaller debris, Make up RCJB *BHA #8) wI 4' extrension. 15:30 - 17:00 1,50 FISH P TIEB1 PJSM, RIH wI RCJB on 3 1/2" DP. 31 stands. 17:00 - 18:00 1,00 FISH P TIEB1 PJSM, Kelly up, bring on pump @ 5 bpm I 500 psi to clear tool. Establish paramters, 60K up wt, 60K down wt, 61 K rotating wt. 2000 ftIlbs of off bottom torque, Break kelly, drop l' ball, kelly up & pump ball on seat, see 1350 psi @ 4112 bpm, Kill pump, RIH, tag top of sand I junk 20' in on kelly @ 3118', Pick up & engage rotary table @ 10 RPM, run back in & core about 1 1/2', kick on pump @ 4112 bpm 11400 psi, won't go down, pick up see 10K overpull, stop & let work free while circulating, piick up free, OK, go back down rotating slowly wI pump @ 4 1/2 bpm, chase sand to top of RBP @ 3133'. 18:00 - 19:30 1,50 FISH P TIEB1 PJSM. Mix & pump 30 bbls Hi Vis sweep, Circ sweep to surface, small amount of sand in returns, 19:30 - 21 :00 1,50 FISH P TIEB1 Held PJSM, POH with BHA #8, 21 :00 - 22:30 1.50 FISH P TIEB1 LD BHA #8. Cleared junk baskets, recovered two small metal chunks and very small amount of other solid debris, 22:30 - 23:00 0,50 FISH P TIEB1 PUMU RBP retrieving assembly, 23:00 - 00:00 1,00 FISH P TIEB1 RIH with RBP retrieving ass'y. RU to circulate. 5/1/2007 00:00 - 01 :30 1,50 FISH P TIEB1 Latched RBP. Reverse circulated clean, PU and released RPB, 01 :30 - 03:00 1.50 FISH P TIEB1 POH with RBP, 03:00 - 04:00 1.00 FISH P TIEB1 LD RBP and retrieving assembly. Recovered approx 1/2 a centralizer spring, in various size pieces. 04:00 - 06:00 2.00 FISH P TIEB1 Cleared rig floor. PUMU 3-5/8" RCJB (BHA #9). 06:00 - 06:30 0,50 FISH P TIEB1 PJSM, Service rig, check crown 0 matic, PVT system, OK. 06:30 - 13:00 6,50 FISH P TIEB1 PJSM, RIH w/3 5/8" RCJB assembly on 3 1/2" DP. Tag fill @ 8800'. Attempt to cleanout fill. No-go. 13:00 - 19:30 6,50 FISH P TIEB1 POH UD BHA #9, Cutting surfaces completely worn off shoe. Emptied junk basket, recovered about 1-1/2 gal oily sand. Cleared rig floor. 19:30 - 21 :00 1,50 FISH P TIEB1 PUMU dress-off shoe (BHA #10), 21 :00 - 00:00 3,00 FISH P TIEB1 RIH with BHA #10. 5/2/2007 00:00 - 00:30 0.50 FISH P TIEB1 Continued RIH with BHA #10, 00:30 - 01 :30 1,00 FISH P TIEB1 Tagged fill @ 8794' DPM, Rotated and washed to 8806', Circulated 6 bpm. 01 :30 - 02:00 0,50 FISH P TIEB1 Reverse circulated @ 6 bpm, Had what appeared to be frac proppant and gas in returns, 02:00 - 03:30 1,50 FISH P TIEB1 Washed over tubing stump to 8821' while rotating. Made two passes over stump without rotation, PU, circulated clean, Set back kelly, Printed: 5/14/2007 10:50:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-05 17-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/18/2007 Rig Release: 5/9/2007 Rig Number: Spud Date: 10/13/1980 End: 5/9/2007 5/2/2007 03:30 - 06:30 3,00 FISH P TIEB1 Reverse circulated 25 bbl High-Vis sweep while reciprocating pipe above tubing stump, Tag up and swallow tubing stump with mill assembly to verify top of stump clean and able to get over with mill shoe, Outside of stump clean to 8821' leaving 12' of stump clear of obstructions, Top of stump @ 8809', 06:30 - 10:30 4,00 FISH P TIEB1 POH with BHA #10, 10:30 - 11 :30 1,00 FISH P TIEB1 BOILD BHA #10, Recovered -5-gals, carbolite in boot baskets, 11 :30 - 12:30 1,00 FISH P TIEB1 PJSM, PUMU BHA #11. 12:30 - 17:30 5,00 FISH P TIEB1 RIH wlBHA #11 to top of 5-1/2" tubing stump @ 8808'. Tag 5-1/2" tubing stump @ 8808', 17:30 - 18:00 0,50 FISH P TIEB1 Establish washing parameters: PUW = 130K, SOW = 120K, Reverse circulating @ 4,O-BPM @ 780-psi. carbolite proppant in returns, Sheared pins in shear pin guide and washed down to 8820', 18:00 - 20:30 2,50 FISH P TIEB1 Make connection and continued reverse circulating at 4 bpm, washing hole with carbolite in returns, Washed inside tubing stump with mule shoe to 8907', until No-Go; did not tag WRP at expected depth, XO sub above PAC pipe bottomed on shear guide (3 jts PAC pipe in BHA), limiting mule shoe depth, 20:30 - 00:00 3,50 FISH P TIEB1 LO 5 singles, POH with BHA #11. 5/3/2007 00:00 - 01 :00 1,00 FISH P TIEB1 Continued POH with BHA #11. 01 :00 - 02:30 1,50 FISH P TIEB1 Re-pinned shear guide. MU BHA #12 (includes 5 jts PAC DP). 02:30 - 05:30 3,00 FISH P TIEB1 RIH with BHA #12, 05:30 - 11 :00 5.50 FISH P TIEB1 Tag top of 5-1/2" tubing stump @ 8808', RIH and shear guide assembly w/10K downweight. Continue RIH and tag top of fill @ 8907'. Establish FCO parameters: PUW = 130K, SOW = 120K, 4,O-BPM @ 720-PSI wlannular preventer closed. Wash down to 8918' and experiencing plugging in DP. Bleed off pump pressure, open bag and continue FCO circulating long way. SID pump, Reestablish reverse circulation and wash down to 8945' with intermittent plugging of DP. DP plugged and pressured up IA to 1500+-psi @ 8945'. Recovered small amoutn of carbolite and traces of sluggits, Experienced sudden pressure decrease to 350-PSI and began losing fluid to well bore rapidly, RIH and tagged up on shear guide assy. with crossover from BHA to 2-7/8" PAC pipe placing muleshoe @ 8966' which is deeper by 21' than WLEG @ 8945'. All indications are that tubing tail is no longer intact. O,D. of fluted no-go on muleshoe is 3,875" and 1.0, of DB-6 landing nipple @ 8942' is 3,813", Left Weatherford 4-1/2" WRP in well. Fluid losses to well> 180-Bbls/hr. 11 :00 - 18:00 7,00 FISH P TIEB1 POH LODP 1x1 through pipeshed, Maintaining well control by filling hole with seawater @ double steel displacement plus an additional 40-Bbl. pill every hour, 18:00 - 20:00 2,00 FISH P TIEB1 LD BHA #12. 20:00 - 23:30 3,50 RUNCO RUNCMP Cleared rig floor. RU to run completion, 23:30 - 00:00 0.50 RUNCO RUNCMP Held pre-tour meeting, performed pre-tour rig checks, 5/4/2007 00:00 - 00:30 0,50 RUNCO RUNCMP Continued RU to run completion. 00:30 - 01 :00 0,50 RUNCO RUNCMP Held PJSM with all personnel. 01:00 -19:30 18.50 RUNCO RUNCMP RIH with 4-1/2", 12.6 #/ft, 13Cr80 Yam Top tubing with Baker S-3 packer per V AM and Baker reps on location, Running dope-free Cleanwell connections, MU each connection by Printed: 5/14/2007 10:50:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-05 1 7-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/18/2007 Rig Release: 5/9/2007 Rig Number: Spud Date: 10/13/1980 End: 5/9/2007 hand, then torque-turn connections to 4440 Ib-ft, Connections requiring 1-1/2 to 3 torque turns after hand MU. Maintaining well control wlseawater to well at about 50 bbl/hr. 165 jts. RIH @ 1445-hrs. Shot sonic fluid level @ 570' from surface @ 1600-hrs, Tagged 5-1/2" tbg stump @ 8816'. 19:30 - 21 :30 RUNCMP Made numerous unsuccessful attempts to slide 4-1/2" mule shoe into 5-1/2" tubing stump, Attempted to SO without rotation and attempted to SO with torque turn rotation (max 2500 Ib-ft rotating torque), Continued to tag @ 8816'. 21 :30 - 22:30 1,00 RUNCMP Contacted Howard West and determined plan forward. 22:30 - 00:00 1,50 RUNCMP LD 2 jts 4-1/2" Vam Top tubing, RD tubing handling equipment. 5/5/2007 00:00 - 01:30 1,50 RUNCMP Prepared for slickline operations, Cleared rig floor and location, 01 :30 - 12:00 10.50 RUNCMP Spotted slickline unit. Held PJSM, RU shooting flange, wireline BOPE, and lubricator. RU sheaves. Strung wire, Continued to maintain primary well control by adding approx 50 bbls sea water per hour to well. 12:00 - 14:00 2,00 RUNCMP Make up slickline tool string and RIH to pull RHC-M plug. 14:00 - 18:00 4,00 RUNCMP Make up slickline tool string and RIH w/3,805" O.D, gauge ring. Tagged @ 8824' SLM, Could not work into 5-1/2" tubing stump, POH, 18:00 - 22:00 RUNCMP LD gauge ring, PU lead impression block, RIH and tagged @ 8824'. POH with LIB, Had clear impression of 5-1/2" tubing stump, 22:00 - 23:00 1.00 RUNCMP RD slickline equipment. 23:00 - 00:00 1.00 RUNCMP ND shooting flange. 5/6/2007 00:00 - 00:30 0,50 RUNCMP NU flow nipple and riser. 00:30 - 01 :30 1.00 X DECOMP MU tubing landing joint. RU tubing handling equipment. 01 :30 - 02:00 0,50 X DECOMP Held PJSM on LD tubing. 02:00 - 05:00 3,00 X DECOMP Pulled and LD tubing hanger. POH, LD 4-1/2" Vam Top tubing with Cleanwell thread coating, per Vam representative, Continuing to add approx 50 bbllhr seawater to well. 29 jts LD @ 05:00 hrs, 05:00 - 16:00 11,00 PULL X DECOMP POH UD 4-1/2" completion tubing 1x1 through pipe shed using compensator equipment and inspecting each connection for nonconformity. 38 jts, POH @ 0600-hrs, 16:00 - 17:00 1,00 PULL X DECOMP Break out muleshoe jt. to inspect Baker-Lok'd connection for possibility of rerun. Dope and makeup connection to allow packer BHA to be stood back in derrick, 17:00 - 18:00 1,00 PULL DECOMP RD tubing handling equipment. 18:00 - 20:30 2,50 BOPSU RUNCMP PJSM - PUMU 9 x 6-1/4" DC's and 9-5/8" Halco RTTS packer and storm valve, RIH one jt and set RTTS @ 34', Tested RTTS to 1000 psi for 10 charted minutes. 20:30 - 21 :30 1,00 BOPSU RUNCMP Drained stack. PU, set BOPE test plug, RU test equipment. 21 :30 - 22:00 0.50 BOPSU RUNCMP Held PJSM, 22:00 - 00:00 2.00 BOPSU RUNCMP Tested all BOPE components to 250 psi low I 3500 psi high. Test witness waived by R. Noble, AOGCC, at 23:00 hrs, 5/5/2007, 5/7/2007 00:00 - 02:00 2.00 BOPSU RUNCMP Continued testing BOPE to 250 psi low I 3500 psi high, 02:00 - 04:00 2,00 BOPSU RUNCMP Retrieved RTTS, LD drill collars, 04:00 - 06:30 2,50 RUNCO RUNCMP Cleared rig floor. RU tubing handling equipment. 06:30 - 07:30 1.00 RUNCO RUNCMP PUMU Unique O/S to packer/profile nipple assy, standing in Printed: 5/14/2007 10:50:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-05 1 7-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/18/2007 Rig Release: 5/9/2007 Rig Number: Spud Date: 10/13/1980 End: 5/9/2007 derrick, Wait on slickline unit to arrive, Slickline unit on well pad @ 1230-hrs. 12:30 - 17:00 4.50 RUNCMP Wait on Nabors Rig 7ES to move past well so we can rig up slickline unit. Rig up slickline PJSM with all crew while waiting, DHD shot fluid level @ 1400-hrs, which indicated fluid level 570' from surface, 17:00 - 19:00 2,00 RUNCMP MIRU slickline unit. RU shooting flange, slickline BOPE, and lubricator. 19:00 - 19:30 0.50 RUNCMP Held PJSM with slickline relief crew, 19:30 - 21 :00 1,50 RUNCMP Continued to RU slickline. Hung sheaves, strung wire, 21 :00 - 22:00 1,00 RUNCMP Slickline RIH with 3,84" drift, Tagged @ 9625' sllickline measurement. This depth is equivalent to 9605', corrected to ELM tubing cut depth, Had to work drift through 5-1/2" tubing stump. No indication of DB-6landing nipple, reported as 8942'. 22:00 - 23:30 1.50 RUNCMP POH with slickline. 23:30 - 00:00 0,50 RUNCMP RD slickline unit. 5/8/2007 00:00 - 01 :00 1,00 RUNCMP Continued to RD slickline unit. 01 :00 - 02:00 1,00 RUNCMP Held PJSM, ND shooting flange, NU flow nipple and riser, At 01 :00 hrs DHD shot fluid level @ 588', Continued to add 25 bbls/hr seawater to well. 02:00 - 05:30 RUNCMP RU tubing handling equipment. LD muleshoe. Unsuccessfully attempted to break Bakerlocked connection in order to reset RHC plug, BO pup jt above packer, LD packer with pup jts and RHC attached, installed RHC plug with dry rod, 05:30 - 06:00 0,50 RUNCMP RU to run 4-1/2" tubing, 06:00 - 19:00 13,00 RUNCMP PUMU Unique Overshot. RIH w/4-1/2" 12.6# 13Cr80 completion tubing using torque turn equipment to make up connections to 4440 ft-Ibs optimum torque and compensator for picking up single joints, 50 jts RIH @ 0930-hrs, 170 jts RIH @ 1600-hrs, 204 jts RIH @ 1800-hrs, Shear Unique overshot set screws w/15k Ibs. Set down 8k Ibs on stump, PU weight = 105k & SO weight = 96k, PU to neutral weight + 2' for final landing depth. 19:00 - 19:30 0,50 RUNCMP MU 3 space-out pups below jt 204, 19:30 - 20:30 1,00 RUNCMP MU landing jt & tubing hanger. Land tubing & RILDS, LD landing jt. 20:30 - 00:00 3,50 RUNCMP Pump 250 bbls 140 F seawater down IA. Begin pumping 140 F seawater wi corrosion inhibitor down IA. 5/9/2007 00:00 - 03:30 3.50 RUNCMP Finish pumping 140 F seawater down IA. Pump 470 bbls 140 F seawater wI corrosion inhibitor down IA at 2-3 bpm, Reduced pump rate due to intermitant pump pressure increases to 2-2,5 bpm @ 1000 psi. 03:00 - 06:00 3.00 RUNCMP Drop ball & rod. Set packer, Test tubing to 3500 psi for 30 minutes, Test IA to 3500 psi for 30 minutes. Shear DCR valve. Circulate both ways through DCR valve, Recovered oil/diesel from tubing, Circulate surface to surface through DCR valve to ensure hole balanced before set TWC, 06:00 - 07:00 1.00 RUNCMP FMC wellhead technician dry rod set TWC, Tested TWC from above and below for 10 charted minutes at 1000-psi. 07:00 - 10:00 3,00 BOPSU P RUNCMP ND BOPE. 10:00 - 12:30 2.50 WHSUR P RUNCMP NU production tree, Test tubing hanger packoff and tree to 5000-psi. Printed: 5/14/2007 10:50:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-05 17-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/18/2007 Rig Release: 5/9/2007 Rig Number: Spud Date: 10/13/1980 End: 5/9/2007 20:00 - 20:30 20:30 - 21 :00 21 :00 - 21 :30 21 :30 - 23:00 0,50 0,50 0.50 1,50 PUMU lubricator. Veco Valve Shop tech pull TWC. Waited 3 hrs, for rig 2ES to get by before Valve Shop could arrive to pull TWC, RUNCMP PJSM, Rig up LRS and test lines to 3500-psi. Freeze protect well, Pumped 150-Bbls. diesel down IA @3,O-BPM. 2,0 BPM @ 1200 psi final pressure, Rig up lines and allow diesel to u-tube into tubing for 1-hr. RUNCMP Install SPV wI FMC technician. RUNCMP Test SPV to 1000 psi for 10 charted minuites with LRS, RUNCMP RD LRS. RUNCMP Install flanges, nipples, gauges and hand-wheels, Secure well and cellar, RELEASE RIG @ 23:00 HRS. 16:30 - 20:00 Printed: 5/14/2007 10:50:27 AM IIJELLHEAD : FMC !;"cTUA TOR - AXELSON Œ. ELEV : 70' 3F, ELEV : cop: 5200' Aax Angle: 38 @ 10210' )atum MD = 9408' )atum TVD : 8800' SS i:J"'r¡;;;;; I , I~V I c,..¡:). FROM DRLcJÞDRAFT 17 -0 5 I 9-5/8" CSG, 40#,TC-II,L-80 Tie-Bac~-/ 13-3/8" CSG, 72#, L-80, ID = 12,347" I 15-1/2" TBG-~, 17#, L-80, ,0232 bpf, ID = 4,892" I TOPOF 4-1/2" TBG-~ I I 7" CSG, 26#, BTC-M, L-80, ,0382 bpf, ID: 6.276" H 8897' I I TOP OF 7" LNR H 8899' 9-5/8" CSG, 47#, L-80, ID: 8,681" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 10/29/80 ANGLE AT TOP ÆRF: 33 @ 9328' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4 9328 - 9350 0 08/09/89 8 9444 - 9452 0 04/29/88 12 9464 - 9474 0 04/29/88 12 9490 - 9512 0 04/29/88 12 9519 - 9529 0 04/29/88 8 9540 - 9560 0 04/29/88 8 9575 - 9590 0 04/29/88 4 9605 - 9620 0 04/29/88 1-11116" 1-11/16" 1-11/16" 1-11/16" 1-11/16" 1-11/16" 3-118" I PBTD I 10163' 7" LNR, 29#, L-80, ,0371 bpf, ID = 6,184" H 10205' [Ð 10210' . --i 4-1/2" X-NIPID=3,813 GAS LIFT MANDRELS DEV TYPE VLV LATCH 1 CAMCO OCR RKP 22 CAMCO DMY RK 29 CA MCO DMY RK 35 CAMeO DMY RK PORT DATE o 05/08/07 o 05/08/07 o 05/08/07 o 05/08/07 MD 3399 5780 7567 8683 TVD 3399 5752 7310 8265 8754' 8775' 8799' H 4-1/2" X-NIP ID=3,813" I H 95/8" X 4-1/2" BAKER S-3 PKR I H 4-1/2" X-NIP ID=3,813" I 8810' -/9-5/8" X 5-112" BAKER SAB PKR I -/5-1/2" X 4-112" XO I 8942' -/4-1/2" CAMCO DB-6 LANDING NIP, ID: 3,813" 8944' H4-1/2" BAKER SHEA ROUT SUB 8945' -/4-1/2" TUBING TAIL I 8940' H ELMD IT LOGGED 06/04/81 I Below 96051-1 4-112" Weatherford WRP- 5/3/07 9809' ---f BAKER THROUGH TBG BRIDGE PLUG - 07/20/90 DATE REV BY COMMENTS DATE REV BY COMMENTS 11/05/80 ORIGINAL COM PLETION 03/19/03 DTRlKK PULL IBP 07/14/01 RNlTP CORRECTIONS 04/03/03 CAO/KK SET ECLIPSE PA TCH 09/21/02 DTRlKK GL V C/O 09/26/05 EZLlTLH WAr-JER SF1Y NOTE DELETED 10/07/02 JIWKAK GL V C/O 05/09/07 GMH As-Built RWO Completion 11/21/02 JB/TP SET IBP 05/09/07 GMHlPA G DRLG DRAFT CORRECTIONS 03/20/03 JIWKAK GL V C/O PRUDHOE BA Y UNrr WELL: 17-05 PERMrr No: "'1800960 API No: 50-029-20508-00 SEC22, T10N, R15E, 1669,18' FEL & 1133,31' FNl BP ExDloration (Alaska) Schlumbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 05/15/67 NO. 4024 /750 -Oc¿0 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnke'n 333 West 7th Ave, Suite, 100 Anchorage, AK 99501 Field: Prudhoe Bay . Well Job# Loa DescriDtion Date BL Color CD L3-22 11638627 PRODUCTION PROFILE 04/14/07 1 L3-30 11637115 PRODUCTION PROFILE 03/19/07 1 L4-10 11660529 MEM PROD PROFILE 04/04/07 1 L3-12 11686732 PRODUCTION PROFILE 04/08/07 1 02-29C N/A EMIT & CALIPER IMAGE 04/17/07 1 DS 02-36 11637141 MULTI-FINGER CALlPE 03/14/07 1 F-16A N/A SCMT 02/12/07 1 X-21A 11660531 MEM CBL 04/07/07 1 F-08A 11676934 SCMT 03/20/07 1 A-30A 11628762 MEM CBL 03/13/07 1 03-36A 11637326 US IT (CORROSION) 04/12/07 1 03-36A 11637326 USIT (CEMENT) 04/12/07 1 DS 17-05 11594492 USIT 04/24/07 1 DS 03-01 11630462 US IT 03/11/07 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E, Benson Blvd, Anchorage, Alaska 99508 Date Delivered: t1/\tf JI. 6 zuu7 \~ SCANNED MAY 1 ~ 2007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-2 38 ATTN: Beth Received by: . . SARAH PALIN, GOVERNOR AI.A~1iA. OILAlVD GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 SCANM~ JAN 1 9 2007 f-\.ioq(P \ ~\.J Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, Well Name: PBU 17-05 Sundry Number: 307-011 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field 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. DATED this I~day of January, 2007 Enel. rvÞ \ J,OV Itl \\\ Dfr 1~/1/[)1 ~ RECEIVED "5\sa'/7 STATE OF ALASKA I /~/~ð~ ALAsr'Á Oil AND GAS CONSERVATION COMM SION kl (r~ JAN 0 8 2007 APPLICATION FOR SUNDRY APPROVAL l~laska Oil & Gas Cons, Cmnmission 20 AAC 25 280 1. Type of Request: 0 Abandon o Suspend o Operation Shutdown o Perforate o Time Extension u o Alter Casing 181 Repair Well ' 0 Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing' 0 Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 180-096 f 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20508-00-00 .¡ 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 17-05 I Spacing Exception Required? DYes 181 No 9. Property Designation:O~ ¡¡~c:5' ~. 110. KB Elevation (ft): 11. Field / Pool(s): - ADL~ ~/~~? 70' / Prudhoe Bay Field / Prudhoe Bay Pool 1Z/bbi/ii!}< .... ····<i ii:; .... ,.·/b .....<.../.. ... VVIH f ii·. iiiibfib iiiTib iiii.i:· <i iiii'.' Total Depth MD (ft): Total Depth TVD (ft):/Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10210 ¡ 9525 ' 10163 9488 None 9809 Casina Lenath Size MD TVD Burst Collacse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2603' 13-3/8" 2603' 2603' 4930 2670 Intermediate 9209' 9-5/8" 9209' 8702' 6870 4760 Production Liner 1306' 7" 8899' - 10205' 8443' - 9521' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9328' - 9620' 8803' - 9047' 5-1/2",17# x 4-1/2",12.6# L-80 / N-80 8944' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'SAB' packer I Packers and SSSV MD (ft): 8857' 13. Attachments: 14. Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: CommencinQ Operations: January 15, 2007 181 Oil DGas D Plugged D Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Na»aVid Reem Title Ddlling Engineer Howard West, 564-5471 Prepared By Name/Number: Signature C ~ Phone 564-5743 Date I-Ç ---07 Terrie Hubble, 564-4628 Commission Use On Iv I Sundry Number: 3D ry - 0 \ Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance Other: ~5COr\ ~ç> ~~ \- Subsequent Form Required: ~QfZ 'fA~~~ COMMISSIONER APPROVED BY I-I', -,¡- Approved Bv: THE COMMISSION Date Form 10-403 Revised 06/2006 l/ -IJ "--'" Submit In Duplicate ORIGINAL TBEE= WELLHEAD = ACTUA TOR = KB. B..EV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = FMC GEN II FMC AXB..SON 70' . 5200' 38 @ 10210' 9408' 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12,347" I Minimum ID = 3.813" @ 8942' 4-1/2" CAMCO DB-6 LANDING NIP 15-112" TBG-PC, 17#, L-80. ,0232 bpf, ID = 4.892" H 8868' TOPOF 4-1/2" TBG-PC 1 8868' I TOP OF 7" LNR I 14-1/2" TBG-PC, 12.6#, N-80. .0152 bpf, ID= 3,958" 1-1 I 9-5/8" CSG, 47#, L-80, ID = 8,681" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 10/29/80 ANGLEATTOPÆRF: 33 @ 9328' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4 9328 - 9350 0 08/09/89 8 9444 - 9452 0 04/29/88 12 9464 - 9474 0 04/29/88 12 9490 - 9512 0 04/29/88 12 9519 - 9529 0 04/29/88 8 9540 - 9560 0 04/29/88 8 9575 - 9590 0 04/29/88 4 9605 - 9620 0 04/29/88 1-11/16" 1-11/16" 1-11/16" 1-11/16" 1-11/16" 1-11/16" 3-1/8" PBTD I 10163' 17" LNR, 29#, L-80, .0371 bpf, ID=6.184" I 10205' [J!?]- 10210' DATE 11/05/80 03/20/03 03/19/03 04/03/03 09/26/05 08/04/06 REV BY COMMENTS ORIGINAL COM PLETION Jrvv'KAK GLV C/O DTR/KK PULL IBP CAO/KK SET ECLIPSE PA TCH EZL/TLH WAIVER SFTY NOTE DB..ETED DRF/PJC PULL ECLIPSE PA TCH 17-05 . NOTES: DSSSV REQUIRED FOR TxlA NICA TION; FAILED BALANCE LINE. 2120' -15-1/2" CAMCO BAL-O SSSV NIP, ID = 4,562" I GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 2887 2887 1 MMG DOME RK 16 03/20/03 2 4791 4790 2 MMG DOME RK 16 03/20/03 3 6188 6122 27 MMG PATCH 04/03/03 4 7235 7020 31 MMG DOME RK 16 03/20/03 5 7838 7549 29 MMG DMY RK 0 6 7913 7615 28 MMG DMY RK 0 7 8282 7935 28 MMG DMY RK 0 8 8357 7997 29 MMG DMY RK 0 9 8645 8234 32 MMG DMY RK 0 10 8717 8293 33 MMG SO RK 24 03/20/03 I I 8777' -15-1/2" CAMCO DB-1 SLIDING SLV 8837' -15-1/2" BOT PBRASSY I 8857' -19-5/8" X 5-112" BA KER SA B A<R I 8868' -15-1/2" X 4-112" XO I 8942' -14-1/2" CAMCO DB-6 LANDING NIP, ID = 3,813" -14-1/2" BAKER SHEA ROUT SUB -14-1/2" TUBING TAIL I HELMDTT LOGGED 06/04/81 I 9809' -1 BKR THROUGH TBG BRIDGE PLUG (07/20/90) I DATE REV BY COMMENTS 08/04/06 DRF/PJC PULL ECLIPSE PATCH w / DMY GL PRUDHOE BA Y UNrT WB..L: 17-05 ÆRMrT No: '1800960 API No: 50-029-20508-00 SEC 22, T10N, R15E, 1669.18' FEL & 1133.31' FNL BP Exploration (Alaska) . . 17-05 Rig Workover Scope of Work: Pull 5-%" completion, cut and pull 9-5/8" casing above the surface casing shoe, run premium threaded 9-5/8" tieback and cement 9-5/8" x 13-3/8" annulus to surface, run 4-%" Chrome completion. MASP: 2440 psi Well Type: Producer Estimated Start Date: January, 2007 Pre-riQ prep work: S 1 Dum -10' of slu its on to of WRP. Drift 5-1/2" tubin for chem cutter. E 2 Chem cut tubing at 8814' md, referenced to the tubing tally dated 11/03/80. Note that this is in the middle of the first full 'oint above the roduction acker. F 3 Circulate well with seawater and diesel freeze protection thru the cut. CMIT TxlA to 3500 psi. Monitor OAP for signs of communication - note that this well has slow IA x OA communication to as. Bleed WHPs to zero. o 4 PPPOT-T & -IC. Set a BPV in the tubin han er. o 5 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5 W' tubing string to the cut. 3. Run a cement evaluation log to determine top of cement in 9-5/8" x 13-3/8" annulus. 4. Cut and pull 9-518" casing above TOC. 5. Tie back 9-5/8" casing with ES cementer. 6. Cement 9-5/8" x 13-3/8" annulus to surface. 7. Run new 4-112" Chrome tubing completion with packer at -8750'. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. posed RWO Com p 17 -05 ion WELLHEAD - ACTUATOR - KB. ELEV = BF. ELEV = KOP = 5200' Max Angle = 38 @ 10210' Datum MD = 9408' Datum lVD = 8800' SS I 9-5/8" CSG, 40#, TC-II I 13-3/8" CSG, 72#, L-80, ID = 12.347" I FMC AXELSON 70' 4-1/2" X-NIPID=3.813 GAS LIFT MANDRELS ST MD lVD DEV ìYÆ 1 TBD TBD MMG 2 TBD TBD MMG 3 TBD TBD MMG 4 TBD TBD MMG H 4-1/2" X-NIP 10=3.813" I H H H H 9 5/8" X 4-1/2" BAKER S-3 PKR I I 4-1/2" X-NIP 10=3,813" 4-1/2" XN-NIP 10=3.725"1 4-1/2" TUBING TAIL I .,9-5/8" X 5-1/2" BAKERSAB PKR I 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I TOPOF4-1/2"TBG-PC I I 7" CSG, 26#, BTC-M, L-80, .0382 bpf, ID = 6.276" H 1 TOP OF 7" LNR H .,4-1/2" CAMCO DB-6 LANDING NIP, ID = 3.813" 8942' H4-1/2" BAKER SHEA ROUT SUB -f4-1/2" TUBING TAIL I H ELMD TT LOGGED 06/04/81 I 8944' 8945' 8940' 9-5/8" CSG, 47#, L-80, ID = 8.681" I ÆRFORA TtON SUMMARY REF LOG: BHCS ON 10/29/80 ANGLEATTOPÆRF: 33 @ 9328' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 9328 - 9350 0 08/09/89 8 9444 - 9452 0 04/29/88 12 9464 - 9474 0 04/29/88 12 9490 - 9512 0 04/29/88 12 9519 - 9529 0 04/29/88 8 9540 - 9560 0 04/29/88 8 9575 - 9590 0 04/29/88 4 9605 - 9620 0 04/29/88 1-11/16" 1-11/16" 1-11/16" 1-11/16" 1-11/16" 1-11/16" 3-1/8" 9809' BAKER THROUGH TBG BRIDGE PLUG - 07/20/90 PBTD I 10163' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I., 10205' C§] 10210' DATE 11/05/80 07/14/01 09/21/02 10/07/02 11/21/02 03/20/03 REV BY COMMENTS ORIGINAL COM PLETION CORRECTIONS GL V C/O GL V C/O SET IBP GL V C/O DATE 03/19/03 04/03/03 09/26/05 01/03/07 REV BY COMMENTS DTRlKK PULL IBP CAO/KK SET ECLIPSE PATCH EZLITLH WAIVER SFlY NOTE DELETED HJW Proposed RWO Completion PRUDHOE BAY UNIT WELL: 17-05 ÆRMIT No: "1800960 API No: 50-029-20508-00 SEC 22, nON, R15E, 1669.18' FEL & 1133.31' FNL RNITP DTRlKK JIWKAK JBITP JIWKAK BP Exploration (Alaska) KEl,;EIVEU . STATE OF ALASKA. SEP 2 8 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commissior REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Plug PerforationsD Stimulate 0 OtherO Abandon 0 Repair WellŒ Alter CasingO Pull TubingD Perforate New PoolD WaiverO Time ExtensionO Change Approved ProgramO Operation ShutdownD Perforate 0 Re-enter Suspended WellO 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryO 180-096 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD Service 0 50-029-20508-00-00 7. KB Elevation (ft): 9. Well Name and Number: 70.00 17-05 8. Property Designation: 10. Field/Pool(s): ADL-028334 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10210 feet true vertical 9482.0 feet Plugs (measured) Effective Depth measured 10163 feet Junk (measured) BKR Thru TBG Bridge Plug @ 9809 (07/20/90) true vertical 9447.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20" 94# H-40 34 - 110 34.0 - 110.0 1530 520 SURFACE 2570 13-3/8" 72# L-80 33 - 2603 33.0 - 2603.0 4930 2670 PRODUCTION I 9177 9-5/8" 47# L-80 32 - 32.0 - 4930 2670 PRODUCTION 9-518" 47#! SOO-95 - 9209 - 8702.0 7210 4990 LINER 1306 7" 29# L-80 8899 - 10205 8443.0 - 9521.0 8160 7020 ~(-'~"'\ ,> "'j(' ~~~~~,i'"';;; Perforation depth: <J"'J¡~"\.ü ',..l. ""'"""-- Measured depth: 9328-9350,9444-9452,9464-9474,9490-9512, 9519-9529, 9540-9560, 9575-9590, 9605-9620 True vertical depth: 8803-8821,8900-8907,8915-8925,8938-8957, 8963-8971, 8980-8997, 9009-9021, 9034-9047 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 @ 28 - 8868 4-1/2" 12.6# N-80 @ 8868 - 8945 Packers & SSSV (type & measured depth): 9-5/8" Baker SAB PKR @ 8857 5-1/2" CAM BAL-O SSSV Nip @ 2120 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft OCT ~ 2006 Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averace Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure TubinQ Pressure Prior to well operation: SI 0 0 --- 257 Subsequent to operation: SI 0 0 --- 195 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ] ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ! OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 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 DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature ~~. ¿¡p ,j¿ }' ./ Phone 564-5174 Date 9/27/06 n Form 10-404 Revised 4/2004n D I (:: ! t\, fÔ . . 17-05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/09/2006 TII/O=720/420/0 CMIT TxlA PASSED @ 3000 psi. MIT OA PASSED@ 3000 psi. (Shut In) Pre RWO Screening) TxlA pressured up w/ 5 bbls Meth and 346 bbls Crude pumped. TxlA lost 40/50 psi in 15 min. w/ total loss of 80/100 psi in 30 min. (CMIT TxlA did not show stabilization but did pass per >50 psi parameters). OA perssured up w/ 7.6 bbls Crude pumped. OA lost 130 psi in 15 min. w/ total loss of psi in 30 min. 09/08/2006 T/I/O = 120/420/0 CMIT T x lA, MIT OA Prep to do job, TIO= 120/420/0 08/20/2006 TII/O= 770/1280/0. Temp= SI. ALP= 2030 psi (Spool piece removed). Bleed Tbg and lAP <500 psi (Pre CMIT). Initial FL's; Tbg FL @ 3738'(163.6 bbls). IA FL @ 5813' (254.6 bbls). Unable to rig up to tree cap to bleed TP. Grease crew were unable to get swab valve to seal (suspect swab valve is washed out). Bled lAP from 1280 psi to 330 psi in 3 hrs. During IA bleed TP decreased 150 psi (620 psi). Bled TP from 620 psi to 410 psi in 60 minutes. Monitor for 30 min. No changes. Tbg FL @ 5473' (127 bbls). IA FL @ 5195' (227.5 bbls). Final WHP's= 410/330/0. Note: Swab, Companion, Master and Inner casing valves all do not hold pressure. Notified DSO that all valves need to be serviced. 08/17/2006 TII/O= 840/1270/0. Temp= SI. Tbg & IA FL's (Pre-CMIT TxIA). Tbg FL @ 3738' (163.6 bbls). IA FL @ 5813' (254.6 bbls). IA has a 3" integral flange. 08/06/2006 (Waiver Compl.) COMPLETE CALIPER SURVEY SET WFD WRP PLUG @ 8,870' SLM -- MID ELEMENT @ 8,889' MD *** WELL LEFT SHUT IN *** NOTIFIED DSO OF WELL STATUS 08/05/2006 **** WELL SHUT IN**** (wi aver comp) DRIFTED WITH 33/8" DUMMY GUN AND 3.80" GAUGE RING TO 9,050' SLM. ****IN THE PROCESS OF LOGGING CALIPER UP HOLE**** 08/04/2006 (reg compl.) RECOVERED ENTIRE UPPER & LOWER SECTION OF ECLIPSE PATCH, DID NOT RECOVER SMALL BACK UP ELEMENT & LOWER SEALS *** WELL LEFT SHUT IN *** DSO NOTIFIED 08/03/2006 (reg. compl.) DRIFTED WITH 4.55" GAUGE RING TO TOP OF PATCH @ 6,128' SLM. PULLED APART 48" OF TOP OF ECLIPSE PATCH OOH (DUE TO CORROSION) RAN A 4.5" LIB TO TOP OF SEVERED PATCH. RAN A 3" PUMP BAILER! JUNK BOTTOM TO TOP OF SEVERED PATCH. (RECOVERED NOTHING) PLANTED A BAITED SPEAR IN SEVERED PATCH @ 6,128' SLM ****JOB STILL IN PROGRESS**** 08/02/2006 ***WELL SII ON ARRIVAL*** (waiver comp) RIGGED UP BRAIDED LINE. DRIFTED TO TOP OF DSSSV @2,086' SLM. ****IN THE PROCESS OF PULLING DSSSV**** 07/31/2006 T/I/O = 200/1340/0. Temp = SI. IA FL (post brine load). IA FL @ 5275' (between sta #2 & #3). 07/29/2006 TIIIO = 1900/2100/0 - Load IA with 9.8# Brine (Eval for TxlA waiver) - Pumped 5 bbl neat meth spear followed by 330 bbls 9.8# brine and 5 bbl meth cap. FWP's = 1900/450/0 Page 1 . . 17-05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 4 Diesel --- PT Surface Equipment 10 Neat Methanol 330 9.8# Brine 344 TOTAL Page 2 TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = Ffv1CGENII Ffv1C AXELSON 70' 5200' 38 @ 10210' 9408' 8800' SS 113-3/8" CSG, 72#, L-80, 10 = 12.347" I Minimum ID = 3.813" @ 8942' 4-1/2" CAMCO DB-6 LANDING NIP 1 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" H 8868' TOPOF 4-1/2" TBG-PC I 8868' I TOP OF 7" LNR I 14-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" 1-1 19-5/8" CSG, 47#, L-80, 10 = 8.681" 1 PERFORA IDN SUMMARY REF LOG: BHCS ON 10/29/80 ANGLE AT TOP PERF: 33 @ 9328' Note: Refer to Production DB for historieal perf data SIZE SPF INTERVAL Opn/Sqz OA TE 4 9328 - 9350 0 08/09/89 8 9444 - 9452 0 04/29/88 12 9464 - 9474 0 04/29/88 12 9490 - 9512 0 04/29/88 12 9519 - 9529 0 04/29/88 8 9540 - 9560 0 04/29/88 8 9575 - 9590 0 04/29/88 4 9605 - 9620 0 04/29/88 1-11/16" 1-11/16" 1-11/16" 1-11/16" 1-11/16" 1-11/16" 3-1/8" PBID H 10163' 17" LNR, 29#, L-80, .0371 bpf, 10=6.184" 1 10205' ~--I 10210' DATE 11/05/80 03/20/03 03/19/03 04/03/03 09/26/05 08/04/06 REV BY COtvfv1ENTS ORIGINAL COM PLETION JMlKAK GLV C/O DTRlKK PULL IBP CAO/KK SET ECLIPSE PA TCH EZUTLH WANER SF1Y NOTE DELETED ORF/PJC PULL ECLIPSE PA TCH 17-05 . I I SAFETY NOTES: DSSSV REQUIRED FOR TxlA COM M UNICA TION; FAILED BALANCE LINE. 2120' -i 5-1/2" CAfv1CO BAL-O SSSV NIP, 10 = 4.562" I GAS LIFT MANDRELS ST MO "NO DEV lYPE VLV LATCH PORT DATE 1 2887 2887 1 MMG DOME RK 16 03/20/03 2 4791 4790 2 MMG DOME RK 16 03/20/03 3 6188 6122 27 MMG PATCH 04/03/03 4 7235 7020 31 MMG DOME RK 16 03/20/03 5 7838 7549 29 MMG DMY RK 0 6 7913 7615 28 MMG DMY RK 0 7 8282 7935 28 MMG DMY RK 0 8 8357 7997 29 MMG DMY RK 0 9 8645 8234 32 MMG OMY RK 0 10 8717 8293 33 MMG SO RK 24 03/20/03 8777' -15-1/2" CAMCO OB-1 SLIDING SLV 8837' -15-1/2" BOT PBR ASSY I 8857' --19-5/8" X 5-1/2" BAKERSAB PKR I 8868' -15-1/2" X 4-1/2" XO I 8942' -14-1/2" CAMCO OB-6 LANDING NIP, 10 = 3.813" --14-1/2" BAKER SHEAROUT SUB -14-112" TUBING TAIL I H ELMO TT LOGGED 06/04/81 I 9809' --I BKR THROUGH TBG BRIDGE PLUG (07/20/90) I OA TE REV BY COMMENTS 08/04/06 DRF/PJC PULL ECLIPSE PATCH w / DMY GL PRUDHOE BA Y UNrr WELL: 17-05 ÆRMrr No: '1800960 API No: 50-029-20508-00 SEC22, T10N, R15E, 1669.18' FEL & 1133.31' FNL BP Exploration (Alaska) , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ SET TUBING PATCH Pull tubing _ Alter casing _ Repair well _X Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 70 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchora~le, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2370' FNL, 4885' FEL, Sec. 22, T10N, R15E, UM (asp's 708674, 5928258) 17-05 At top of productive interval ~'"'N 9. Permit number / approval number 1667' FNL, 1547' FEL, Sec. 21, T10N, R15E, UM (asp's 706682, 5928907) J 180-096 At effective depth 10. APl number 1529' FNL, 1176' FEL, Sec. 21, T1 ON, R15E, UM (asp's 707049, 5929055) 50-029-20508-00 At total depth 11. Field / Pool 1140' FNL, 1622' FEL, Sec. 21, T10N, R15E, UM (asp's 706592, 5929432) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10210 feet Plugs (measured) Fill @ 9688' (07/26/1992). true vertical 9482 feet Effective depth: measured 9688 feet Junk (measured) Fish - Baker Thru TBG BP @ 9809' (07/20/1990). true vertical 9095 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 300 sx PF 145' 145' 2300 sx Fondu & 400 sx PF Surface 2568' 13-3/8" 2603' 2603' II Production 9184' 9-5/8" 500 sx Class 'G' 9209' 8677' Liner 1306' 7" 500 sx Class 'G' 8899' - 10205' 8444' - 9521' Perforation depth: measured Open Perfs 9328'-9350', 9444'-9452', 9464'-9474', 9490'-9512', 9519'-9529', 9540'-9560', Open Perfs (continued) 9575'-9590', 96051-9620'. true vertical Open Perfs 8803'-8821', 8900'-8906', 8916'-8925', 8938'-8956', 8962'-8971', 8980'-8996', Open Perfs (continued) 9009'-9022', 9034'-9047'. ,ECEIVED Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 TBG-PC @ 8868'. 5-1/2" x 4-1/2" XO @ 8 4~1/2" 12.6# N-80 TBG-PC @ 8945'. j~PR ~ ~ 5003 Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker SAB Packer @ 8857'. 5-1/2" Camco BAL-O SSSV Nipple @ 2120'. At~,l~.~ Qit & Gas C0~$. C0mmi~si0i~ 13. Stimulation or cement squeeze summary Anchorage Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or I niection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation SHUT-IN Subsequent to operation 04/11/2003 719 2923 3786 234 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __~..?.__.,,_ ~ Daily Report of Well Operations _ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~~-~~J~ Title: TechnicalAssistant Date April 17, 2003 DeWayne R. Schnorr ?repared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 17-05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/27/2003 03/30/2003 04/03/2003 04/O3/2003 04/07/2003 O4/O8/2OO3 O4/O9/20O3 04/11/2003 PACKERS/B PACKERS/B PACKERS/B PACKERS/B ANN-COMM PACKERS/BRIDGE PLUGS/POGLMS: ANN-COMM (WAIVER COMPLIANCE) RIDGE PLUGS/POGLMS: RIDGE PLUGS/POGLMS: RIDGE PLUGS/POGLMS: RIDGE PLUGS/POGLMS: TESTEVENT LOAD WELL TO SECURE : AC-FLUID LEVEL PATCH TUBING / CASING PATCH TUBING / CASING SSSV C/O OR STROKE SSSV C/O OR STROKE (WAIVER COMPLIANCE): AC-TIFL --- BOPD: 719, BWPD: 3,786, MCFPD: 5,579, AL Rate: 2,656 04/12/2003 ANN-COMM (WAIVER COMPLIANCE): AC-NFl 04/13/2003 ANN-COMM (WAIVER COMPLIANCE): AC-NFT 04/14/2003 ANN-COMM (WAIVER COMPLIANCE): AC-MONITOR EVENT SUMMARY 03/27/03 LOAD WELL TO KILL WELL FOR WIRE LINE OPERATIONS. PUMPED 5 BBLS METHANOL, 300 BBLS SEA WATER, 130 BBLS CRUDE, 10 BBLS METHANOL 03/30/03 T/I/O=700/1100/0 (FOR CLARK) TBG FL @ SURFACE. 04/03/03 SET 5-1/2", ECLIPSE PATCH (WITH DGLV) CENTER OF ELEMENTS FROM 6176'- 6206', STRADDLE GLM #3, CORRELATE TO SWS LDL DATED 27-SEPT-02. RIH TAG, SET UPPER ASSEMBLY WHILE PUMPING 1.5 BPM, RIH TO ENGAGE LOWER PACKER, PULLED 800 LBS. OVERPULL, SET & TAGGED. UPPER ASSEMBLY IS 33' OAL, LOWER ASSEMBLY IS 5.57'. <<< SHUT-IN >>> 04/03/03 PUMP DOWN TBG TO ASSIST E-LINE IN SETTING TBG PATCH. 04/07/03 <<< WELL S/I ON ARRIVAL >>> RIG UP, RIH W/5 1/2 WIRE BRUSH. O4/O8/O3 BRUSH SSSVN @ 2098 WLM. SET D-SSSV @ 2098 WLM, 3 SETS PACKING, 2.78 ID. <<< NOTE, CONTROL LINE FROZEN. >>> <<< LEFT WELL SHUT IN 04/09/03 TIO:400/1620/900 TEMP = HOT. TIFL FAILED (EVAL T x IA). WELL FLOWING UPON ARRIVAL. SI WELL TO STACK OUT TBG WITH AL GAS. STARTING TIFL PRESSURES 1880/1950/900. INITIAL IA FL @ 8645 (373 BBLS). BLED IA FROM 1950 PSI TO 840 PSI IN I HOUR 35 MINUTES. FINAL IA FL WS INCONCLUSIVE. MONITORED FOR 30 MINUTES. lAP INCREASED 250 PSI. ALSO TBG PRESSURE DROPPED 200-PSI DURING MONITOR. FINAL WHP's ~1600/1090/400 ~ 04/11/03 TESTEVENT--- BOPD: 719, BWPD: 3,786, MCFPD: 5,579, AL Rate: 2,656 OANNEP 0 5 2003 Page 1 17-05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/12/O3 T/I/0=400/1580/1100 SI FOR lAP BUILD-UP EVALUATION. SI A/L AT 7:30 AM. DSO POP'd WELL AT APPROX. 2:00 PM FOR AOGCC TESTING. 04/13/O3 T/I/O=360/1720/1100 SI WELL FOR IA BUILD-UP (8:30 am). AT 5:15 pm SI TBG. WHPs= 210/1080/520. 04/14/O3 T/I/O=560/1080/380 MONITOR IA BUR. IA PRESSURE REMAINED UNCHANGED OVER NIGHT. TBG PRESSURE ROSE 350 PSI TO 560 PSI. OA PRESSURE DROPPED 140 PSI TO 380 PSI. Fluids Pumped BBLS 2 DIESEL USED FOR PRESSURE TESTING SURFACE EQUIPMENT. 15 METHANOL 139 CRUDE 3OO SEA WATER Page 2 TREE= FIVIC GEN II SAFETY NOTES: IAxOA COMM TO AL. DSSSV WELLHEAD = FMC REQUIRED FOR TxlA COMMUNICATION; FAILLE) BALANCE LINE BF. ELEV = KOP = 5200' I 2120' H 5-1/2"C~MCOBAL'OSSSVNIP'ID=4'562" I .... Max An§b = 38 @ 10210' ~ I Datum MD = 0408'~ GAS LIFT Da{~jmTVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE I 2887 2887 I IVlVIG DOIVE IRK 16 03/20/03 I 13-3/8"CSG, 72#,L-80,1D=12.347'H 2603' ~ ~k 2 4791 4790 2 rvlvlG DOIVE RK 16 03/20/03 ~, 3 6188 6122 27 IVIvlG PATCH 04/03/03 4 7235 7020 31 IVIVIG DOk/E F~ 16 03/20/03 5 7838 7549 29 IVIV1G DMY R~ 0 5-1/~'ECLIFSEPATCHW/DMYGLV ]--[6172'-6206'1 I I 6 7913 7615 28 IVlVIG DMY F~ 0 I 7 8282 7935 28 IVIVIG DMY RK 0 & BE LATCH, ID= 1.995"I ' 8 8357 7997 29 IVIMG DMY F~ 0 9 8645 8234 32 IVIVIG DMY F~ 0 10 8717 8293 33 IVIVIG SO ~ 24 03/20/03 Minimum ID = 1.995" @ 6172' 5-1/2" ECLIPSEPATCH I I i sz~' H ~-~,~,,o^~co ~-~ ~,,~,~ s~vI I I ~' H ~-~'~"~°~"~^~ I X )< J 8857' H 9-5/8" X 5-1/Z' BAKER SA B PKR J I ..5-1/2" TBG-PC, 17#, L-80, 0.0232 bpf, D = 4.892"H 8868' ~-... ~ I I-r°~°~',-,~"~-,"cH s~'i ~ ' a~' H 5-112,,x4-1/2,,xoj J " . · i 8942' ~ 4-1/2"CAMCO cB-eLANDHG NIP, ID= 3.813" I I 7" LNR 8899' I JTOPOF J--J I ~ ~ 8944' H 4'I/2"BAKERSFEAROUTSUB I 4-1/2" TBG-FC, 12.6/¢, N-80, 0.0152 bpf, D = 3.958" 8945' I / ¢ I 8945' 4-1/2" TUBING TAILI I PEF~:O RATION S UMM~ RY REF LOG: BI-~S ON 10129180 ANGLEAITOPPERF: 33 @ 9328' Note: Refer to Production BB for hb.todcal perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 9328 - 9350 = O 08~09~89 1-11/16" 8 9444 - 9452 O 04/29/88 1-11/16" 12 9464 - 9474 O 04/29/88 1-11/16" 12 9490 - 9512 O 04/29/88 1-11/16" 12 9519 - 9529 O 04/29/88 1-11/16" 8 9540 - 9560 , O 04/29/88 1-11/16" 8 , 9575 - 9590 O 04/29/88 I ~,, ~ 2~,,.~0, 0.03~ ~, ,~=~.~4,, ~ ~0~0~ DATE REV BY i CO~41~TS DATE i ~ BY COMI~NTS PRLIDHOEBAY 1111§/80 ORIGINAL COb/FI_ETlON 03/20/03 JMtKAK GLV C/O WELL: 17-05 07114101.._R_j,,I/'r~..P. iCORRECIIONS ,. 03/191031 DI'R/KK PU[_LIBP PEI~IINo: 1801Y360 00/21102- D-'IR/KK GLV C/O 04/03/03 CAO/KK SET I~LIPSEPATCH AFt No: 50-029-20508-00 10117102 JM/KAK GLV C/O SEC22, TION, R15E, 1669.18' FR & 1133.31' FNL 02119103 ~ID/IP DB_ETEWA~VER S~PEIY NOIE BP ~xploration {Alaska} PERFO RATION SUMMA RY REF LOG: BHCS ON 10/29/80 ANGLEATTOPPERF: 33 @ 9328' Note: Refer to Production DB for his.todcal perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 9328 - 9350 O 08~09~89 1-11/16" 8 9444 - 9452 O 04/29/88 1-11/16" 12 9464 - 9474 O 04/29/88 1-11/16" 12 9490 - 9512 O 04/29/88 1-11/16" 12 9519 - 9529 O 04/29/88 1-11/16" 8 9540 - 9560 O 04/29/88 1-11/16" 8 9575 - 9590 O 04/29/88 3-1/8" 4 9605 - 9620 O 04/29/88 BATE REV BY COIVlVlENTS DATE REV BY COMIVENTS 11/05/80 ORIGINAL COIVPLETION 03/20/03 JM/KAK GLV C/O 07/14/01. _ R_~N/T_...P. CORRECT_IONS o . 03/19/03 DTR/KK PULL IBP 09/21/02 DTPJKK GLV C/O 04/03/03 CAO/KK SET ECLIPSE PATCH 10/07/02 JM/KAK GLV C/O 11/21/02 JB/TP SETIBP 02/09/03 ~TD/TP DELETEWAIVER SAFETY NOTE SCANNED ~AY 0 5 2003 MEMORANDUM State of AlaSka Alaska Oil and Gas Conservation Commission TO: Julie HeusSer DATE: Commissioner December 15, 2000 THRU: Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests PrUdhoe Bay Unit Drill Site 17 Friday~ December 15~ 2000: I traveled to BPX's Drill Site 17 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnesSed the testing of 15 wells and 30 components with one failure. The Surface Safety Valve on' Well 17-4 Failed to close .on its initial test. After this valve was serviced and the - hyd lines flushed it operated properly and passed the retest. Mark Womble performed the testing today; he demonstrated good test procedures and was a pleasure to. work With. I also inspected the wellhouses on this location while witnessing SVS tests. All the wellhouses and associated equipment appeared clean and in good condition Summary: I witnessed SVS testing at BPX's PBU Drill Site 17. PBU DS17, 15 wells 30 components 1 failure 3.3% failure rate 19 Wellhouse inspections Attachment: SVS PBU DS17 12-15-00 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mark Womble AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Fielcl/Unit~ad: Prudhoe / PBU / DS 17 ' Separator psi: LPS 165 . HPS 12/15/00 Well Permit Separ Set L/P Test . Test Test Date · Oil, WAG, GIN J, NUmber· Number PSI PSI Trip Code Code Code Passed GAS or CYCIJ*, 17-01 1800550 165 150 130 P P OIL 17-02' ~ ~00700 165 150 100 P P ,, 'OILi 17-03A 1972160 165 150 110 P P OIL ~, , 17-04A 1960500 165 150 120 .P "~5 12/15/00 OIL 7-05 ii'i 00.9/ 0 · P P .on.l 17-06 1801320 17-07. ~ 1810660 165 150: .. 140 'P P ' " OIL 17-08 1810740 17-09 1810900 165 150 100 P P ~ " OIL 17-10A 19911001 ~7-11 1842440 165 150 . 120 'P: P OIL 17-12 1842450 165 150 1201 P P OIL 17-1'3 1841790 165 150 110 ~ P OIL 17-14 1841660 165 150 140 'P P OIL , 17-15A 1991310 17-16 1920910 165 150 , .130 P P OIL' 17'19A 1970550 . 165 150 130 P P OIL 17-20 1921150 165 150 1.20 P P OIL i 17,21 1921250 165 150 130 P. P OIL Wells: 15 Components: 30 Failures: 1 Failure Rate: 3;3% [300 var Remarks: Surface Safety on 17-4 failed to close, it was Serviced and retested. 12/19/00 Paee 1 of l SVS PBU DS17 12-15-00 CS.xls GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 9566 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 7/1 1/95 Well Job # Log Description Date Field: Prudhoe Bay Floppy BL RF Sepia DIR MWD Disk D.S. 3-22 ~r ~ I ~z~ PERF RECORD 9,5., 0618 I 1 D.S. 3-24 ~ ~ ~ ~_-~ IBP SETTING RECORD 950621 ' I 1 D.S. 4-48 ~ t,. ~ J (3") PROD PROFILE 95 06 2 2 I 1 !D's. 6-14A ..c~ ,)_ '3"'"/ PRODLOG 950623 I 1 D.S. 7-06 .-/'c~- J ~1' PERFRECORD 95061 9 I 1 D:S. 9-16 ~'~ ~'~' PERF RE, .. ,CORD 950620 1 1 D.S. 12-34 ~t / , .~ .~ JEWELRYLO,_GCOLLARLOCATOR 950619 I 1 D.S. 12-34 / "1 [-) ~ PERFRECORD 950.6.19 1, .... 1 ~D.S: 13-1 '7 ~ ~ O BAKER INFLAT BRIDGE PLUG 950623 I 1 D.S. 17-05 _~"(~ ~ ~, IBP SETTING RECORD 950618 I I .... ,,, ,,, SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: 1:1995 Alaska Oil & Gas Oons. Oommission Anchorage ARCO Alaska, inc. Date: Subject: From/Location: Telephone: To/Location: July 6, 1994 P.O. Box 100360, A~'~horage, AK Transmittal #: 94055 Kinley Caliper Survey's John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution 99510~g~ ~, Number of Records: 5 Well Number 09-07 09-47 16-12 17-03 17-05 Log Date Tool Type (M-D-Y) 06-24-94 /Caliper Survey 05-02-94 ljCaliper Survey 04-29-94 ~/'Caliper Survey 05-19-94 ! ,,-Caliper Survey 05-18-94 I/'Caliper Survey iContractor Kinley Kinle¥ Kinle¥ f Kinley i Kinley John E. DeGrey Distribution: Central Files BPX State of Alaska ANO-8 Geology Exxon Please acknowledg/e rece~ning and returning a copy of transmittal. By:~-2 ~ Date: D E',~ r", dUL 7 I 1994 ~Jaska oit & G~ Cons. Commission ~orage ARCO Ahu~u~, inc. Is a Subsidiary of A~l~n~lcRIchfleldComp~ny ,. ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: May 24, 1994 P.O. Box 100360,-~nchorage, AK Transmittal #: 94043 ARCO Static Pressure Surveys John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well i Log Datet Tool Type Number i (M-D-Y) 2-6 i 03-03-94 I Static Pressure 3-32A i 05-13-94 1 Static Pressure 4-5A i 05-18-94 I Static Pressure 6-16 i 05-13-94 t Static Pressure 1-24A ,~ 03-06-94i Static Pressure (~c~7..Iz~ i 16-15,i 04-01-94I Static Pressure 16-20 ,! 03-23-94 Static Pressure 16-24 ,I 03-24-94i Static Pressure 16-25 'i Static Static Static 03-24-94I Pressure 7-09/~ 03-24-94 I Pressure 7-05 ~r 03-23-94 I Pressure Run, Scale 1 5" Contractor i Sch Sch Sch Sch Sch Sch Sch · Sch I 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" Sch Sch Sch Number of RecOrds: 11 Distribution: Central Files -Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil D & M Please acknowledge receipt by signing and returning a copy of transmittal. Date: JUly ARCO Alaska, Inc. Is a Subsidiary of AIlantlcRIchfleldCompany ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 11-3'/)2 REFERENCE: ARCO CASED HOLE FINALS 10-3-92 Prod Profile Run 1, ~' Camco 9-28-92 Leak Detect (FleXstak) Run 1, ~' Camco 9-14-92 InJ Profile Run 1, ~' Camco 9-29-92 InJ Profile Run 1, ~' Camco 10-2-92 Prod-InJ (Flexstak) Run 1, I~' Camco 9-19-92 Leak Detect Run 1, ~' Camco 9-26-92 GR/Collar Run 1. ~' Camco 9-27-92 GR/Collar Run 1. ~' Camco 9-25-92 Prod Profile Run 1, ~* Camco 9-14-92 Prod Profile Run 1, ~' Camco 10-2-92 InJ Profile Run 1, ~* Camco 9-4-92 Prod Profile Run 1, ~' Camco 10-4-92 InJ Profile Run 1, ~' Camco 9-26-92 Prod Profile Run 1, ~' Camco 9-26-92 GR/Collar Run 1, ~' Camco 10-5-92 InJ Profile/PITS Run 1, ~' Camco 9-27-92 InJ Profile Run 1, ~' Camco 9-19-92 Leak Detect Run 1, ~' Camco 9-27-92 Prod Profile Run 1, ~' Camco 10-4-92 InJ/ahut-ln Tamp Run 1, ~' Camco 10-2-92 InJ Profile Run 1, ~' Camco 10-2-92 InJ Profile (Flexstak) Run 1, ~' Camco 10-1-92 , InJ Profile Run 1, f~' Camco 9-15-92 InJ PrOfile Run 1, ~' Camco 9-17-92 Prod Profile (Flexstak) Run 1, f~' Camco 10-1-92 Prod Profile Run 1, ~* Camco 9-28-92 GR/Collar Run 1, ~* Camco 9-28-92 Prod Profile Run 1, ~* Camco 9-15-92 Prod Profile ' Run 1, f~* Camco 10-1-92 Prod Profile Run 1, 1~* Camco Please siga and return ~le attac~e~d copy as receipt RECEIVED B~~~~-~ ' J~A~{ 0 9 ,99,~ # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHILLIPS PB WELL ~ # BPX # STATE OF ALASKA STATE OF ALASKA ALASKA~ '~"~AND GAS CONSERVATION C( ~'~'~IlSSION REPORT" SUNDRY WELL OPE ATIORS' 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2369' FNL, 425, FWL, Sec. 22, T10N, R15E, UM At top of productive interval 1667' FNL, 1547' FEL, Sec. 21, T10N, R15E, UM At effective depth At total depth 1453' FNL, 1960' FEL, Sec. 21, T10N, R15E, UM 5. Type of Well Development X Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 70' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-5 RECEIVED OCT - 6 lg92 Atask~ u~ ~ bas [;0ns, ~.~~ Anchorage feet 9. Permit number/approval number 80-96 10. APl number 50 - 029-20508 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10210 feet 9482 feet Plugs(measured) Fill @ 9688' MD (7/26/92) Effective depth: measured 9688 feet true vertical 9095 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 300 sx PF 110' 110' Sudace 2533' 13-3/8" 2300 sx Fondu & 400 sx PF II 2603' 2603' Production 9139' 9-5/8" 500 sx Cl G 9209' 8677' ,, Liner 1306' 7" 500 sx Cl G 10205' 9478' Perforation depth: measured 9328-9350'; 9444-9452'; 9464-9474'; 9490-9502'; 9502-9512'; 9519-9529'; 9540-9546'; 9546-9560'; 9575-9590'; 9605-9612'; 9612-9620' true vertical 8777-8795'; 8900-8907'; 8917-8925'; 8938-8948'; 8948-8956'; 8962-8971'; 8980-8985'; 8985-8997'; 9010-9022'; 9034-9040'; 9040-9045' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8868' MD; 4-1/2", 12.6#, N-80, PCT tail @ 8945' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8857' MD; 5-1/2", Camco Bal-0 SSSV @ 2120' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily Aver{~ge Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Prior to well operation 754 ~" 791 3541 -- Subsequent to operation 1210 J 2054 4914 -- Tubing Pressure 290 292 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x.~_ Gas..._ Suspended.._. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 892/11 RTT cc: SW, JWP Title Sr. Area Operations Engineer Date SUBMIT IN DUPLICATE 17-5 DESCRIPTION OF WORK COMPLETED ACID STIMULATION TREATMENT 7~23/92: RIH & tagged bottom at 9533' MD. 7/25/92: RIH w/CT & reversed proppant fill from the wellbore down to 9700' MD. Washed tubing down the CT x tubing annulus with 100 bbls 7.5% HCl/15% Xylene, and reciprocated 20 bbls 7.5% HCl / 15% Xylene through CT across the perforations located at: 9328 - 9350' MD (Sag) 9444 - 9452' MD (Z4) 9464 - 9474' MD (Z4) 9490 - 9502' MD (Z4) 9502 - 9512' MD (Z4) 9519 - 9529' MD (Z4) 9540 - 9546' MD (Z4) 9546 - 9560' MD (Z4) 9575 - 9590' MD (Z4) 9605- 9612' MD (Z4) 9612 - 9620' MD (Z4) Ref. Log: BHCS 10/29/80. POOH w/CT while pumping 320 bbls of 1% KCI Water down the annulus to flush acid into the formation. Made a final bottom tag at 9696' MD. Rigged down. 7/26/92: A fullbore Acid Stimulation was performed as follows: MIRU & PT equipment to 3500 psi. Pumped 897 bbls of 1% KCl Seawater w/scale inhibitor & surfactant, then treated the perforations (listed above). Pumped Stage #1: a) 50 bbls 6% HCI/15% Xylene, followed by b) 15 bbls 1% KCI Seawater spacer, followed by c) 50 bbls 2% Hydrogen Peroxide, followed by d) 15 bbls 1% KCl Seawater spacer followed by e) 50 bbls 6% HCl, followed by f) 15 bbls 1% KCl Seawater spacer followed by g) 65 bbls Foam Diverter w/Nitrogen @ 3000 scfm. Pumped stage ~2: h) repeated steps a through g (listed above). Pumped stage #3: i) repeated steps a through e (listed above), followed by j) 182 bbls 6% HCl - 0.5% HF, followed by k) 427 bbls 2% NH4 Cl Water overflush, followed by I) Shutdown. R'E EIVED OCT - 6 1992 Alaska 0il & Gas Cons. Comm'tss~On Anchorage Rigged down. Returned well to production with gaslift & obtained a valid production welltest. ~ ,- ~ ';.,. ~, ~. - .._ ~.. . . . ~ ..... ~. . ' - ..... ~"' ' ' . · ~ '"?::~-.~:S'- ~"~'~ ":' ....' :'-" ": -. ~ " : .- ; .;: :.~.~:~. ~ .... ~...~.-...- .... ~ -~ - .. · . -. ........ . . - ' - --' ',~ ' ?'~'~'4~,~S~-~ ~,'~~%'. -' L/~' ~"" "* ........ .,.... _ . . ...... ,~,~.~--,~7-?~S]7~ ................ ~ ~-,~W~ .................... ~ /~: --~- "Rp~-.'EREN~n~:: ............... ARCO CA~ED ~HOLE~"~:~'":";':'~FINALZ---' ..... '~" ' "":'~"?~'~..._ -~ . '"~" ' ' · ..:. -..:,-.,..1 -~ -. 4-1 e-~l..~,;,:~., ~ ERF.:.-~ECORD--,..; ....... , ....... -.:,' .-.-'z:;,:,,- RUN ,~ ~.'~,:'~ ,,:71.:: -""., ...' Lg '.'-.'-.. -.~ ~}.,.. ..... . .. ... .. · . ' ' ' ' "' ' ..... z~ ' .... %;' :'.;'-;.:':'"~-29 '?:~%2~Z9f.· -.. F ERF~:~;.C06 :;~..:.~ ...... --.' _ -.'..?.'- RUN '~ '75' -' . ' "HLZ . ~ ~ '7';'(~:~~"fW:.~.77" 'C 0 LL~ R'~E~.?7:'rr:~7.':~i~'~?~:~;7: .................. ~R UN 7t h T L'A X -' -'-~":~:.'?':YS-] '<:`'':?~'~:1'3~ i''L'~:'': ::"LEAK:}~:'~'~"~:~N~'"'~:'?~':?';-"'"":~?":"; r~:.::r:::%~. "~" 'RU'~ ~:'~' '2' &5" :':"CAMCO' ...... G AMM~ !'.~-A-Y~Z. CCI_'-'TAG . RUN '~, 5 · .................. CAMCO .... RUN -t,_.~· -$CH ".'.:.-'-~' .' ;~'i~:'~:~.'.'.~ '".. '.~ ....... - -.~.':~:, RECORD 'RUN . ~,,.,. ~,~ ..... STATE OF ALASKA .. ALASKA: ~AND GAS CONSERVATION C(. '~l~;~:)hG I N A [ ..~ REPORT'UF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well --... Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2369' FNL, 425' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 1667' FNL, 1547' FEL, Sec. 21, T10N, R15E, UM At effective depth At total depth 1453' FNL, 1960' FEL, Sec. 21, T10N, R15E, UM 5. Type of Well Development Exploratory StralJgraphic Service 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-5 9. Permit number/approval number 80-96/90-262 feet 10. APl number 50 - 029-20508 11. Field/Pool Prudhoe BaY Oil Pool 12. Present well condition summary Total depth: measured true vertical 10210 feet Plugs(measured) 9482 feet Effective depth: measured 10163 feet true vertical 9447 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 300 sx PF 110' 110' Sudace 2533' 13-3/8" 2300 sx Fondu & 400 sx PF II 2603' 2603' Production 9139' 9-5/8" 500 sx CI 'G' 9209' 8677' Liner 1306' 7" 500 sx CI 'G' 10205' 9478' Perforation depth: measured 9328-9350'; 9444-9452'; 9464-9474'; 9490-9502'; 9502-9512'; 9519-9529'; 9540-9546'; 9546-9560'; 9575-9590'; 9605-9612'; 9612-9620' true vertical 8777-8795'; 8900-8907'; 8917-8925'; 8938-8948'; 8948-8956'; 8962-8971'; 8980-8985'; 8985-8997'; 9010-9022'; 9034-9040'; 9040-9045' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8868' MD; 4-1/2", 12.6~, N-80, PCT tail @ 8945' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8857' MD; 5-1/2", Camco Bal-0 SSSV @ 2120' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See attached AUG ! 4 ]9,90 Treatment description including volumes used and final pressure J~lJa$~(.a .0~J.& Gas C0rl,.~ COlZli~$~0rI RePresentative Daily Averaae Production or Iniection Data Anchorage Prior to well operation OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 1425 5143 2058 -- 276 Subsequent to operation 1916 1747 4241 -- 283 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas .~.. Suspended Service, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Date Form 10-404 Rev 06/15/88 463 DRR c: J. Gruber, ATO-1478 SH SUBMIT IN DUPLICATE DS 17-5 DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF SAG RIVER & ZONE 4 4/25/90: RIH & changed out LGLV's w/DGLV's. PT 9-5/8" OK. Rigged down. 4/28/90: MIRU, & PT lines to 7500 psi. Began pumping Fracture Treatment through perforations interval at: 9328 - 9350' MD (,Sag River) Ref. Log: BHC$10/29/80. 9444 - 9620' MD (Zone 4) Ref. Log: BHCS 10/29/80. Pumped: a) 200 bbls Pre Pad Gel, at 45 bpm at 2800 psi. b) Shutdown for 20 minutes. ISIP at 1240 psi. Resumed pumping: c) 2000 bbls Cross Linked Pad, at 45 bpm at 3200 psi, followed by d) 943 bbls Sand Slurry, at 2-12 ppg at 54 bpm at 3100 psi, followed by e) Flush. Shutdown. Placed a total of 207,000 lbs of proppant into formation. Rigged down. 4/30/90: RIH & pulled DGLV's. Replaced w/LGLV's. Tagged bottom at 9292' MD. RD. 5/2/90: RIH & performed carbolite fill cleanout to 9805' MD. RD. Returned well to production and obtained a valid welltest. ARCO Alaska, Inc~ ') Prudhoe Bay ,:ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F, Scheve Operations Engineering Manager April 25, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-5, Permit No. 80-96 Dear Mr. Chatterton: Attached is the Application for Sundry Approval in triplicate detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DRR/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 17-5)W1-3 ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany AR3B--6132-C STATE OF ALASKA .... -- ,~ ALASK/ ~AND GAS CONSERVATION ¢ ~vllSSIONU ~ APPLICA'dON FOR SUNDRY APPROVALS IGIN/ L 1. Type of Request: Abandon ~ Suspend ,, Operation shutdown ~ Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Vadance Perforate Other -., ' ""1 5. Type of Well Development X Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2369' FNL, 425' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 1667' FNL, 1547' FEL, Sec. 21, T10N, R15E, UM At effective depth At total depth 1453' FNL, 1960' FEL, Sec. 21, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 10210 feet Plugs(measured) 9482 feet 6. Datum of elevation(DF or KB) 70 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-5 9. Permit number 80-96 10. APl number 50 - 029-20508 11. Field/Pool Prudhoe Bay Oil Pool RECEIVED Effective depth: measured 10163 feet ',,~P'R 2 5 1.99,n. true vertical 9447 feet Junk(measur :~ ~ 0,, & Gas Cons. Comm~lon Casing Length Size Cemented ~ ~!lglC~red depth True vertical depth Conductor 110' 20" 300 sx PF 11 O' 11 O' Surface 2533' 13-3/8" 2300 sx Fondu & 400 sx PF II 2603' 2603' Production 9139' 9-5/8" 500 sx CI 'G' 9209' 8677' Liner 1306' 7" 500 sx CI 'G' 10205' 9478' Perforation depth: measured 9328-9350'; 9444-9452'; 9464-9474'; 9490-9502'; 9502-9512'; 9519-9529'; 9540-9546' 9546-9560'; 9575-9590'; 9605-9612°; 9612-9620' true vertical 8777-8795'; 8900-8907'; 8917-8925'; 8938-8948'; 8948-8956'; 8962-8971'; 8980-8985'; 8985-8997'; 9010-9022'; 9034-9040'; 9040-9045' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8868' MD; 4-1/2", 12.6#, N-80, PCT tail @ 8945' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8857' MD; 5-1/2", Camco Bal-0 SSSV @ 2120' MD 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch x 14. Estimated date for commencing operation May 1990 16. If proposal was verbally approved Oil x Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-~ ~¢ ~ -~ ~" ,P.~-~e'.~-.- T'~le Operations Engineering Manager 15. Status of well classification as: Gas m Suspended Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- . Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY 361 D.R. Reimers Approval No. Returne6 SUBMIT IN TRIPLICATE ,5 4 2 BOP £Ou 1. 5000 PSI ?" WELLHEAD CONNECTOR FLAI~O£ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFINO BOX NIREL,,INE ,BOP EOUIPHENT 1. 5000 PSI '7" WELLHEAD CONNECIOR FLANOl 2. 5000 PSI WIRELIN[ RAkIS (VARIABLE SIZE) 3. 5000 PS1 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-Orr Drill Site 17-5 Sag River / Ivishak Formation Hydraulic Refracture Treatment PRELIMINARY PROCEDURE Arco Alaska intends to pump a hydraulic fracture treatment on well 17-5 as outlined below: . . . . . . Pull gas lift valves and replace with dummy valves. Pressure test tubing / casing annulus. Rig up fracturing service company. Pump propped fracture treatment at 45 BPM using a cross linked water system with approximately 211,000 lbs of 16-20 proppant. The intervals to be fracture stimulated is the Sag River from 9328-9350' and Zone 4 from 9444 - 9620'. The pump schedule is outlined as follows: A. 2800 Bbl cross linked water pad ' B. 131 Bbl 2 PPG proppant C. 141 Bbl 4 PPG " D. 152 Bbl 6 PPG " F_ 162Bbl 8PPG " F. 173 Bbl 10 PPG " G 184 Bbl 12 PPG " If necessary rig up CTU and cleanout to PBTD. Install gas lift valves. Open well to flow gradually increasing the drawdown to allow proper fracture healing. RECEIVED 'APR 2 519.a.n Alaska Oil & Gas Cons. Commission Anchora~ Prudhoe Bay ~., ineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 25, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-5, Approval No. 9-352 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DRR/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 17-5) W1-3 RECEIVED 0CT 2 6 Oil & ~a~ Cons, Co,~ssio~ Anct;orage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132~C STATE OFALASKA '~'~VIISSION 0 RIG IN ALASKA ~_ AND GAS CONSERVATION C~. REPORT OF SUNDRY WELL OPERATIONS 1 'Operations performed: Operation shutdown Stimulate , X Plugging Perforate ~ Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2369' FNL, 425' FWL, Sec. 22, T1 ON, R15E, UM At top of productive interval 1667' FNL, 1547' FEL, Sec. 21, T10N, R15E, UM At effective depth At total depth 1453' FNL, 1960' FEL, Sec. 21, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-5 9. Permit number/approval number 80-96/9-352 10. APl number 50 - 029-20508 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth' measured true vertical 10201 feet Plugs(measured) 9482 feet Effective depth: measured 10163 feet true vertical 9447 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 300 sx PF 110' 110' Surface 2533' 13-3/8" 2300 sx Fondu & 400 sx PF II 2603' 2603' Production , 9139' 9-5/8" 500 sx CI 'G' 9209' 8677' Liner 1306' 7" 500 sx 10205' 9486' Perforation depth: measured 9444-9452'; 9464-9474'; 9490-9502'; 9502-9512'; 9519-9529'; 9540-9546'; 9546-9560'; 9575-9590';9605-9612'; 9612-9620' true vertical 8874-8881'; 8891-8899'; 8912-8922'; 8922-8930'; 8936-8944'; 8954-8958'; 8958-8970'; 8982-8994'; 9007-9012'; 9012-9019' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8868' MD; 4-1/2", 12.6#, N-80, PCT tail @ 8945' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8857' MD; 5-1/2", Camco Bal-0 SSSV @ 2120' MD r ECE,,, 13. Stimulation or cementsqueeze summary J\ J~ V [~ ~ 14. Intervals treated(measured) See attachment OCT 2 Treatment description including volumes used and final pressure ~-~.~,SI(a 0JJ & 0as C0rls~ C0rlli~,issJot't Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Md Water-Bbl 1496 917 1086 2680 3095 2273 Casing Pressure Tubing Pressure -- 219 218 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x...~. Gas~ Suspended_._ Service 17. I hereby.,~ertify that the foregoing is true and correct to the best of my knowledge. # Signed Title Operations Engineering Manager Form 10-404 Rev 06/15/88 217 Dennis R. Reimers 263-6205 Date J~~/'~/~ SUBMIT IN DUPLICATE 17-5 ZONE 4 FRACTURE STIMULATION OUTLINE OF CONDUCTED WORK Arco Alaska Inc. pumped a hydraulic fracture treatment in Zone 4 as outlined below: June 1.) 22-25,1989 Replaced gas lift valves with dummy valves and pressure tested tubing casing annulus to 3000 psi. June 26, 1989 2.) Rigged up pump trucks and sand transports. 3.) Gelled water for fracture treatment. 4.) Pumped hydraulic fracture treatment in Zone 4 (9444'-9620'): 600 Bbls. 50 # gel w/ delayed borate crosslinker 54 B bls.2 ppg 16-20 Carbolite 59 Bbls. 4 ppg 16-20 Carbolite 63 Bbls. 6 ppg 16-20 Carbolite 68 Bbls. 8 ppg 16-20 Carbolite 72 Bbls. 10 ppg 16-20 Carbolite 96 Bbls. gelled water flush Well treated at an average rate of 40 BPM at an injection pressure of 4000 psi. The fracture treatment screened out after placing 29,500 lbs of proppant through the perforations. 5.) Cleaned out wellbore proppant with coil tubing. Replaced dummy valves with gas lift valves. 6.) Test well at rate of 2680 BOPD, 2273 BWPD, and GOR of 1155 SCF/STB. ARCO Alaska, InC. ) Prudhoe B;.-,*Igineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 5, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-5, Approval No. 9-535 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/TPA/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 17-5) Wl-3 RECEIVED OCT 1 !989 0ii & Gas Cons..Commlssi03 Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR39--6132-C STATE OF ALASKA G. .AS CONSERVATION C '~ISSION EuNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing . Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2369' FNL, 425' FWL, Sec. 22, T1 ON, R15E, UM At top of productive interval 1667' FNL, 1547' FEL, Sec. 21, T10N, R15E, UM At effective depth At total depth 1453' FNL, 1960' FEL, Sec. 21, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-5 9. Permit number/approval number 80-96/9-535 10. APl number 50 - 029-20508 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10210 feet Plugs(measured) 9482 feet Effective depth: measured 10163 feet true vertical 9447 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 300 sx PF 110' 110' Sudace 2533' 13-3/8" 2300 sx Fondu & 400 sx PF II 2603' 2603' Production 9139' 9-5/8" 500 sx CI 'G' 9209' 8677' Liner 1306' 7" 500 sx 10205' 9488' Perforation depth: measured 9328-9350'; 9444-9452'; 9464-9474'; 9490-9502'; 9502-9512'; 9519-9529'; 9540-9546'; 9546-9560'; 9575-9590'; 9605-9612'; 9612-9620' true vertical 8777-8795'; 8900-8907'; 8917-8925'; 8938-8948'; 8948-8956'; 8962-8971'; 8980-8985'; 8985-8997'; 9010-9022'; 9034-9040'; 9040-9045' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8868' MD; 4-1/2", 12.6#, N-80, PCT tail @ 8945' MD Packers and SSSV (type and measured depth)Baker SAB packer @ 8857' MD; Camco BaI-(~~lV E~ 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment Treatment description including volumes used and final pressure OCT ! 1989 0ii & Gas Cons, C0m~ssi0~ Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 2330 4849 1979 2922 6004 2036 Tubing Pressure 258 259 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /0~'~~ ~)~ Title Operations Engineering Manager Form 10-404 Rev 06/15/88 193 T. P. Allen, 263-4837 Date TREATMENT: OBJECTIVE: INTERVALS: TREATMENT DATE: 1. , , , J ,, , 0 , 10. 11. 12. Drill Site 17-5 Description of Work Performed Sag River Fracture Treatment To Stimulate the Sag River Formation 9328-9350' MD (Ref. BHCS 10/29/80) August 9 to September 1, 1989 Perforated Sag River interval from 9328-9350' MD.(ref. BHCS 10/29/80) Attempted to set CT bridge plug. Failed. Went to rathole. Attempted to fish. Failed to recover CT bridge plug. Isolated the Ivishak perforations with a second CT bridge plug. Bridge plug set at 9386' MD. MIRU fracturing service company Pressured annulus to 2500 psig. Pumped propped fracture treatment for Sag River interval using gelled water and Carbolite proppant at 20 bpm. a. 99 bbls Formation breakdown and shutdown for ISIP. b. 42 bbls pump-in/shut-in. c. 246 bbls Pad d. 197 bbls Slurry at 2-14 PPG (40,000# of proppant was pumped into the well and 19,000# was placed into the formation) e. 161 bbls Flush Screened-out occurred with 57 bbls of proppant slurry left in wellbore. RDMO fracturing service company. Tagged fill at 8165' MD. Cleaned-out excess proppant to top of bridge plug to 9388' MD with CTU. Retrieved top bridge plug. Attempted to pull bottom CT bridge plug. Bridge plug was left in rathole. Obtained a valid test. RECEIVED OCT 1 tftl 9 Alaska Oii& (~as Cons. Comrnissior~ Anchorage ARCO ALASKA, INC. F'.O. BOX ANCHORAGE, ALASKA 995i ,3 DATE- ~-9-89 REFERENCE: ARCO CASED HOLE 'FINALS t-7 9-27-89 F'ERF RECORD i-22 9-2'7-89 F'ERF RECORD 5-2i 9-3~-89 CBT 7-23 9-2~-89 PITS 9-24 9-24-89 LEAK DETECTION ti-8 9/24-25/89 INJECTION PROFILE ii-9 i0-i-89 F'ERF' RECORD i4-25 9-23-89 INJECTION PROFILE t4-27 9-23-89 INJECTION PROFILE t4-32 9-Je-89 LEAK DETECTION--REV i7-5 9-25-89 PRODUCTION PROFILE i8-24 9-28-89 COMPLETION RECORD NGI-i 9-28-89 INJECTION PROFILE NGt-8 9-29-89 INJECTION PROFILE RUN t, 5" RUN RUN t, RUN RUN i, t"&5" RUN t, 5" RUN t, 5' RUN 1, 5" RUN i, RUN i, t"&5" RUN i, RUN RUN i, 5' RUN t, PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 DISTRIBUTION ~- CENTRAL FILES ~ ,,- PHILLIPS ~- CHEVRON F'B WELL FILES D & M R & D ~' EXTENSION EXPLORATION ~'- BF'X ~ STATE OF ALASKA T EXXON ~ · 'l' MARATHON ~~ TEXACO ii ~ MOBIL SCH SCH CAMCO CAMCO CAMCO $CH CAIqCO CAHCO CAHCO CAMCO SCH $CH SCH . THE CORRECTED AF'I~ FOR ti-9 IS 5~-~,29-2i4-02. ARCO ALASKA, INC. P.O. BOX i00S6,3 ANCHORAGE, ALASKA DATE' ~8-22-89 REFERENCE: ARCO CASED HOLE FINALS 1 -t A 8-i 2-89 t -t A 8--t 2--89 i-t 9 8-i S-89 4-6 8- t 8'89 4-6 8-i 0-89 5-t t 8-t 4-89 5-i i 8-i 4-'89 ,.5-i 8 8-i G-89 9-iS 8-2.-89 ~-i8 8-~-8~ ~- t 9 8-4-8~ ~-25 8'-4'-8~ --i i -27 7-2-8e i 6- i 8-7-8e tT-S 8-~-89 i8-i8 8-5-8~ CET-THICKNESS CORR. PROTECTION EVAL. COLLAR/F'ERF COLLAR BRIDGE PLUG DIFF. TEMF' CNL-GAMMA CET INJECTION F'ROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE DUAL SPACED NEUTRON INJECTION PROFILE COLLAR/PERF I'EMP/WHU'F SURVEY PLEASE SIGN AND REI'URN THE ATTACHED COF'Y AS RECEIPT RUN i , 5' RUN t, 2' RUN t, 5' RUN RUN i , tS' RUN t , ]5' RUN i , 5 RUN i , 5" RUN t, 5· RUN t; 5' RUN i , 5' RUN i, 5' RUN i , 5" RUN RUN t , S' RUN t, 5' [)F' DAI'A. SCH SCH Al'LAS AI'I_AL{ Al'LAS ATLAS ATLAS SCH CAMCO CAMCO CAMCO CAMCO HLS CAMCO ATLAS CAMCO RECEIVED BY Alaska Oil & Ccn Commis i,'; DISTRIBUTION CENTRAL FILES ~ ~ PHILLIPS CHEVRON F'B WELL FILES D&M R&D EXTENSION EXPLORATION ~ ~ BF'X EXXON '~ ~ STATE OF ALASKA MARATHON ~ TEXACO MOBIL THE CORRECTED AF'I~. FOR 5-ti IS THE CORRECTED AF'I~ FOR 9-t9 IS ARCO Alaska, Inc. ) Prudhoe Bay~-,l~l' ineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 15, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-5 Permit No. 80-96 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/RAC/jp Attachment cc: T.B. Gray, BP J. Gruber, ATO-1478 PI(DS 17-5)W1-3 RECEIVED Ala~ Oil & Gas Cons. Anclmra~e ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK/ ~_AND GAS CONSERVATION C(' "~ISSION APPLICA,IION FOR SUNDRY AFr ROVALS '1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Operation shutdown Plugging Pull tubing Variance 5. Type of Well Development X Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate X Perforate Other 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 2369' FNL, 425' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 1667' FNI_, 1547' FEL, Sec. 21, T10N, R15E, UM At effective depth At total depth 1453' FNL, 1960' FEL, Sec. 21, T10N, R15E, UM 8. Well number 17-5 9. Permit number 80-96 10. APl number 50 - 029-20508 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary R E E IV E D Total depth: measured 10210 feet Plugs(measured) true vertical 9482 feet Effective depth: measured 10163 feet true vertical 9447 feet Junk(measured) AJaska 0ii & Gas Cons, Commission Casing Length Size Cemented Measdr'~J~t True vertical depth Conductor 110' 20" 300 sx PF 110' 110' Sudace 2533' 13-3/8" 2300 sx Fondu & 400 sx PF II 2603" 2603' Production 9139' 9-5/8" 500 sx 'G' 9209' 8677' Liner 1306' 7" 500 sx 10205' 9488' Perforation depth: measured 9444-9452'; 9464-9474'; 9490-9502'; 9502-9512'; 9519-9529'; 9540-9546'; 9546-9560'; 9575-9590'; 9605-9612'; 9612-9620' true vertical 8900-8907'; 8917-8925'; 8938-8948'; 8948-8956'; 8962-8971'; 8980-8985'; 8985-8997'; 9010-9022'; 9034-9040'; 9040-9045' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8868' MD; 4-1/2", 12.6#, N-80 PCT tail @ 8945' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8857' MD; Camco Bal-0 SSSV @ 2120' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation . June 1989 .. 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby,,~certify that thee forec:j_oing is true and correct to the best of my knowledge. // Signed 4ft/~~''//~ ~ Title Operations Engineering Manager FOR COMMIRRION LIS~I: ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner n.R!~i~AL SIGNED BY LONNIE C. SMITH : 15. Status of well classification as: Oil ~ Gas __ Suspended Form 10-403 Rev 06/15/88 059 R.A. Clausen, 263-4538 SUBMIT IN TRIPLICATE Drill Site 17-5 Sag River Formation Preliminary Hydraulic Fracture Treatment Procedure ARCO Alaska Inc. proposes the following hydraulic fracture procedure: 1. Perform Zone 4 fracture treatment as per previous sundry. 2. Perforate Sag River interval from 9328' to 9350' MD.(referenced to BHCS log dated 10/29/80) 3 Isolate Ivishak perforations. 4. MIRU fracturing service company 5. Pressure annulus to 2500 psig. 6. Pump propped fracture treatment for Sag River zone using gelled water and Carbolite proppant at 20 bpm. a. 100 bbl Formation breakdown and shutdown for ISIP. b. 25O bbl Pad c, 180 bbl Slurry at 2-14 PPG d. 218 bbl Flush 7. RDMO fracturing service company. 8. MIRU slickline unit and tag fill. 9. Cleanout excess proppant to 9770' MD with CTU. 10. Place well on production, Run spinner log to determine post frac production split between the Ivishak and the Sag River intervals. RECEIVED :JUN ! 9 t989 Alaska Oil & Gas Cons. Commission Anchorage ,5 4 2 COILED 1UB~Nt~ UNIT BOP EOU l PHEN~ 1. 5000 PSI ?" W£LLH[.AD CONNECTOR rLAI~GE; 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYD~LK~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. ~X)0 PSI 4 1/6" BLIND RAHS 6. 5000 PSI 4 1/16" STUFFING BOX 2 H]REL]NE BOP EOUIPMENT 1. 5000 PSI ?" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WIRELINE RANIS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO Alaska, Inc. ) Prudhoe Bay ~./gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager 0 R I§ 119 A'L~~' ~ May 8, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-5 Permit No. 80-96 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/DRR/jp Attachment cc: J. Dietz, BP 3. Gruber, AT0-1478 PI(DS 17-5)W1-3 WELLS3/133 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED MA~' -- 9 ~,~ Alaska Oil & ~ Con~, C~rnissi'on ~chorage AR3B--6132-C 1. Type of Request: -. STATE OF ALASKA '~ A ~ OIL AND GAS CONSERVATION COM~, ~ION APPLICATION FOR SUNDRY APPROVALS Pull tubing ~ Variance __ 5. Type oi Well: Development ~ Exploratory __ Stratigraphic ~ Service ..._ Abandon ~ Suspend m Alter casing _._ Repair well Change approved program ~ Operation shutclown ~ Re-enter suspended well ~ Plugging __ Time extension B Stimulate ~ Perforate ~ Other , 2. Name of Operator ~ (~ Rn.,z ll")Oc~F~(''). Anchorage. ~ g9~10 4[ ~a%n eT well at su~ace- 2 ' 25' F , Sec 22 T10N, R15E ~ ~¢~ ofgP~bct~e ,nte~ ' ' ' t~6~~ ~[, ~547~ ~[, Sec. 2t ~t0~, ~tS~, ~ effective depth ~ At total depth t453~ ~[~ t960' ~[~ Sec. 2t, ~t0~, ~tS~, ~ 12. Present well condition summaw Total depth: measured true vertic~ 6. Datum elevation (DF or KB) 7. Unit or Property name Prudhoe Ba7 Unit 8. Well number DS 17-5 9. Permit number Ro-q6 10. APl number 50-- 029-20508 11. Field/Pool Prudhoe Bay Oil Pool 10201 feet Plugs (measured) 9482 feet Effective depth: measured 10163 feet true vertical 9447 feet Casing Length Size Surface 110 ' 20" Intermediate 2533 ' 13-3/8" Production 9139 ' 9-5/8" Liner 1306 ' 7" Junk (measured) Cemented 300 sx PF 2300 sx Fondu & 400 sx PF II 500 sx 'G' 500 sx Measured depth 110' 2603' 9209' 10205' ~ueverticaldepth 110' 2603' 8677' 9488' feet Perforationdepth: measured 9444-9452'; 9464-9474'; 9490-9502'; 9540-9546'; 9546-9560'; 9575-9590'; 9605-9612'; 9612-9620' true vertical 8900-8907'; 8917-8925'; 8938-8948'; 8980-8985'; 8985-8997'; 9009-9022' Tubing (size, grade, and measured depth) 5½", 17#, L-80, PCT @ 8868' MD; 4~", 12.6#, N-80 PCT tail @ 8945' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 8857' MD; Camco Bal-0 SSSV @ 2120' MD 13. Attachments Description summary of proposal __ Detailed operations program __ 9502-9512'; 9519-9529' 8948-8956'' 8962-8971' .°.s,et -EEEi¥ Ei 14. Estimated date for commencing operation 15. Status of well classification as: ~v,~,l~/i AV _ Mmv 1 16. If I~roposal was verbally approved Oil ~ Gas B Suspended '~S~ 0il & Gas C011S. Name of approver Date approved Service N~ch0rage 17. I hereby ce~fy that the foregoing is true and correct to the best of my knowledge~ Signed ~-~f.~~~ T~eonerag~ons EnRineerin~ Manager Date ~~/~ , ,, FOR COMMISSION USE ONLY ' Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commissioner Form 10-403 Rev 06/15/88 WELLS3/133 ORIGINAL SIGNED BY LONNIE C. SMITH D. R. Reimers, 265-6205 Approved Copy Returned ,,~ Commissioner I Approva, NO. 9-' Date SUBMIT IN TRIPLICATE 5 4 3 2 COILED TUBINg UNIT BOP E0U ! PHEN'T 1. 5000 PSi ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYDRAUL lC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAJAS 6. 5000 PSI 4 1/16" STUFFING BOX 2 H]RELINE BOP EOUIPMENT _ ii 1. 5000 PSI ?" WELLHEAD CONN£C10R FLANGE 2. 5000 PSI WIRELIN£ R&IaS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-Orr Drill Site 17-5 Ivishak Formation ~Hydraulic Fracture Treatment PRELIMINARY PROCEDURE . . . . , . Pull gas lift valves and replace with dummy valves. Pressure test tubing / casing annulus. Rig up fracturing service company. Pump propped fracture treatment at 40-45 BPM using a dual cross linked water system (borate and delayed crosslinker)with approximately 63,000 lbs of 16-20 proppant. The maximum injection rate possible will be obtained following pressure limitations. The pump schedule is outlined as follows: A. 700 Bbl cross linked water pad B. 50 Bbl 2 PPG in cross linked water C. 50 Bbl 4 PPG in cross linked water D. 50 Bbl 6 PPG in cross linked water E. 50 Bbl 8 PPG in cross linked water F. 50 Bbl 10 PPG in cross linked water If necessary rig up CTU and cleanout to PBTD. Open well to flow gradually increasing the drawdown to allow proper fracture healing. Install gas~ lift valves. RECEIVED ~aska 0ii .& Gas Cons. C~missi0n Anchorage ARCO ALAS'KA, P.O, BOX ~00360 ANCHORAGE, ALA~'KA 995i DATE° 8-2~-88 REF:'ERENCE: ARCO F'RE...tT,S'URE DATA ~-5 7-4S-88 BHP--£'TATIC GRADIENi" CAMCO t-6 6-S0-88 · BHP--$TATIC GRADIENT CAMCO J-J.2 7-~8-88 BHF ....~TA'[IC GRADIENT CAMCO t-t6 7-i -.88 BHF: ..... STATIC GRADIENT - CAMCO ~-2~ 8-4-88 BHP--.~'I'ATIC GRADIENT CA~CO 6-7 8-t 2-88 BHP--STATIC GRADIENT CAMCO 7-5 8-~z88 BHF ....FLOWING GRADIENT CAMCO 7--i 4 8-t i -88 BHP ....PRE~;~'LJ~(E BU];LD-UP CAMCO PLEA;~E SIGN AND RETURN 'fl--liE Af'TACHED COI'"'r' A;S' RF'CEIF"¥ OF DATA, RECEIVED B'l'. ................................................ HAYE A NICE DAY! ~'ALLY HOFFECKER ATO- ~ 529 Alaska Oil & 8as Cons. Commissior! TRAN$ ~:8854'? .~ , Anchorage AF'F'ROV'ED ...... . .................................. ,. D I ~ 'I' R I BU'f' I ON CENI'RAL. F I LF.",; CHEVRON D & M EXTENS'ION IEXI':'L. ORAT iON EXXON M A R A T H 0 N MOB I L "-.-F:'I"I ILL I F'J3 WELL ~ R & D .;.~. .*m ...~ -.- ~ ;:':~ F' t., · ..3'TA'fE ElF: AL_A,S'KA -.- I'EXACO ARCO ALASKA, INC. P.O. BOX ANCHORAGE, ALASKA 995t DATE' 8-26-88 REFERFNCE' ARCO CA~ED HOLE FINAL t-~ S 7-~ ~--88 COLLAR/PERF RUN 2-tA 8-~7-88 PERF RECORD RUN ~ ~o 7-22-88 COLLAR/PERF RUN S-2 ~ 8- ~ 8-88 COLLAR/PERI= -- RUN 5-2 8-~ 6-88 COLLAR/TEMP RUN 5-6 8-~-88 PRODUCTION PROI=ILE RUN 7-t 5 7-9-'88 CC]LL. AR/PERF REiN t , 5" 7-28 8-20-88 PFC RtJN -tc~ 8-20'-88 PFC RUN i 9-t "?-"?-88 COLLAR/F'ERF' RUN t4--S 8-i~-88 LEAK DETECTION RUN i, t 5- ~ 4 7--'25--88 COLLAI~/F'ERF' - R~JN . t6-i'4 8/t2-i4/88 PRODUC'IiON PROF GAS LIF"I" RUN t 7-5 8-t ~'-88 GA.~ LIF'I' 'I'Ef'iF' .F:~JM t, 5" t7-'8 8-'t~-88 ~NJ PRO 'i'E~P F'LOW~E'fER RUN t '?-1 4 8--t I '-88 PRODUCTION i::'RUt::'.[LE RUN t 8'" ~'6 8-5-"88 F'~'FS RUN F'WDWt-i 7-t 8-88 COLLAR/PERF' RUN F'L.E:.A,,[:' SIGN AND RE ILF,,N 'fH'E A'i"I"ACHEI) COPY AS' RECEIP'I" OF DAi"A GEAR 5'CH GEAR ATLAS' CAMCO CAMCO GEAi~ Al LA~' &EAR CAMCO CAi".ICO ~r~cu CAMCO CAMCO GEAR I'¢E.,I:. I VEL) BY HAVE A NICE DAY! ("'~)/~j '~ SALLY HOFFIECKER ( EP APPROVED .~ . ..... : ...................................... ~ ~la~ka 011 & 0~ Oons. Oommission ~ohorag. D Z ~'i" R ~ ~U'I' I UN ~ CENTRAL F1LE~7 ~.~. PHi LL.I P,S' ,44. · .- CHEVRON F'L-~ WEI_L. I-':[LES' D & M R & D · $ EXTENS'ION EXF'LORA'f' iON :~ £'AF'C · -,,- [:XXON ~'" 5"fA'I'E OF:' ALA:~'I<A MARATH. ON ~' ~- I'EXACO · .- i"t 0 B I L R'I--FERFIgCE: 4R.P.O I~.~ A ,.~, i.. l~ HOLE £RI! AR'/PFRFCIf-;'AT I 0. N ..P. WI /¢.~ ' r:nl t. AR/PFRFrIR,,~'I'T. ni,~ .P. rl!. I A~ c.t.'!.l .1 ~R/PF;RFnRr~,"FTFIN !"i.1,.J I --- I.';. I:;.' FIl'!! ! AR/PFR'I::'F1R¢,T T r/H iS f'i ! I... A F.,: / F' F l:b F-" i'/R A T T i'1 N F:f'll I Cf'ti t. AI;:/F'FRF'F!RAT'fi]hl F'FF:I.. RFP. F'r VE~ T'4Y HAVE A txtll;E DAY' F'E6 ..F,Y ! ~.:. "'"FV Al-FR..} ED D.T...X'T R I Rt. IT T EENTR. AI...'. FILES. CHFVRDN MARATHON MOBIL '"' PH T !...I... T F'..~ F'~ ~.F.L i.. F%I. .. · ~"~<.~. T A T F..--~O F.~ Al_ASK ~- TFxAcn ANCHOF;.'~A(;E:.~ AI...A.?k' A l)~'r .'E.. · 4-7-88 I.~'I{!'F'EI:{'.E'.P-ICE!]' AR'CO CASED I..tf)l..l!E F'IENAI... · I .... ..~ .'..] ]'~-.. ~;] ii / ,? 4 -- ,c..~ [..-} !::' !;.' 01.) ! Il':; 'l' I ('1 N I::'R F) F I I.. I-? :::~ "- ;2 :'~ -'- 2 0 "" ~! ,(!! F:' F.' [i B ! lC 'T' '[ C) N !::' I:;.'. f'l I::' I !.. I::' ......... ,.':l,:l F:' I:;: CI !') !..I I'":. T T I"lt'.,I I::' l:;.: ('l l:: T I...I-7 7,., .... 'l .5 7., ..... ! ,':-'."¢.....,cji 8 F:' F:.' [) !~, I !f':'ir' '[ C! N !::' F:.' C)!::' '[ 15. Ii.'. :i~ .... 'i '7 ?; .... 'i e,- ~'- ---,..,,R o T N. I F!7 I.'. 'ir. ]' {'! 4-.- .1 ,?. ]J~ --- '...-'.). ".5: --- ~!! ~!.~ F:' !.'~'. C! r)!.! C: "(' T. 9 --- 'i 7', --.. ~ O -.- FI 8 F:' F;: CI t') ! .! t7.' T T f;.'l i,...! !::' !::,' ('! F." T [ I:'. · i 4 --. :i';,5 :~.--.-2 F~--.. ,q 8 I. IE r~ I,..'. ~"~ lie 'ir' · ~ 6-. 1 Z.,.-- .? .t .... ~!:~ F..:~ 71' N. tIFF' f":'l' T i;~ i',J !:' !:;: (.'). F:' :!' I. !::' ~ ~ .--..¥ 't .... ::q F~ F:' I;:.' C) !) ,. !::' F;.' I::'1 .. [!~ .... fl; I:;.' / "f' Ii!: i'd r.:, / id ¢'.,, T !!!: r.;., !-.I !... l) {.j F:' !:?. I:!i C; E I V I{E .'0 !:.'.' y HAVE A NTI;f:.'.l:."." DAY' Alaska Oil & Gas Cons. Commission F:'!::; g (; Y R E ?.~ N E T T Anchorage ~, T !).-- ~ 5 2 9 B T X"ir' I:.(' T RI l'l' T ('1 N f:IF' E'I!N ~ . !:;.'! Il'.,! t, I:;.'I.IN 'l., I~'!.lkl 'i. F.'I !K! 'i; RIIN ~. RI.IN '1. Rt.I~-J¢; ~. RI.tN ~, l)A'rn .. ~:.~ N 5" 5" '5" 5" I.'7';" 5" '5" 5" 5'" f': ~ H f': f'! (': A bi f': f'! r:nMf':f'! f". A M f",' [) r: A FI C. r) r: A H C: ltl r': ~ ~ f:: ARCO Alaska, In~ Prudhoe Bay ,_d'gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 23, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-5 Permit No. 7-352 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, DFS/JMV/jp At tachment cc: Standard Alaska Production Company Pi(DS 17-5)W1-3 .i 2 4 !987 Alaska Oil & Gas Cons. Commission WELLS/96 ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany ..... ~) STATE OF ALASKA ALA,.,. ~ OIL AND GAS CONSERVATION CO~, , SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate J~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Tnc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2369' FNL, 425' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 1667' FNL, 1547' FEL, Sec. 21, T10N, R15E, UM At effective depth At total depth 1453' FNL, 1960' FEL, Sec. 21, T10N, R15E, UM 5. Datum elevation (DF or KB) 70' RKB Feet 6. Unit or Property name Prudhoe Ba7 Unit 7. Well number 17-5 8. Approval number 7-352 9. APInumber 50-- 029-20508 10. Pool Prudhoe BaT Oil Pool 11. Present well condition summary Total depth: measured true vertical 10210' feet Plugs (measured) 9482 ' feet Effective depth: measured 10163' feet Junk (measured) true vertical 9447 ' feet Casing Length Size Cemented Structural Conductor 110' 20" 300 $× Surface 2603' 13-3/8" 2300 + 400 Intermediate Production 9209' 9-5/8" 500 Sx 'G' Liner 1306 ' 7" 500 Sx Perforation depth: measured 9444-9620' (8 intervals) true vertical 8873.7-9019' (8 intervals) Tubing (size, grade and measured depth) 5~", 17#, L-80 PCT, 4½", 12.6#, N-80 @ 8944' MD B P, acker~s and SS,SV (tyj~e and measured depth)~ ~ ,, a~er SAB Packer @ 8857' MD; Camco ~a±-u SSSV @ 2120' MD Measured depth 110' 2603' 9209' 10205' 12. Stimulation or cement squeeze summary ~ue Verticaldepth 110' 2602.9' 8677' 9488' Intervals treated (measured) See attached Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ~bing Pressure 1500 489 151 -- 227 3400 2500 735 -- 225 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys .R,,.u)n ? 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~c2.~-~"7 Title Operations Engineering Manager Date ~~,,~ Form 10-404 Rev. 12-1-85 WELLS/96 J. M. Vitucci, 265-6358 Submit in Duplicate DRILL SITE 17-5 POST JOB SUMMARY Scale Inhibition Treatment Date: 6/8/87 le me Obtained a valid well test. Performed emulsification/sludging tests with wellhead fluid sample and EDTA. 3. MIRU pump trucks and transports at DS 17-5. 0 e e Pumped the following fluids: a, c~ 48 bbls of EDTA w/additives 133 bbls of selected scale inhibitor blend with 0.2 gals/bbl of liquid diverter. 730 bbls of diesel 215 bbls of dead crude 5 bbls of diesel Shut in well for 12 hours. RD and released equipment. Obtained a valid well test and placed well on production on 6/9/87. JMV/323 ARC[) Alaska, I¥)c. F'.O. Box i0.0360 A)')chor age, A lm.skm 9951O ]DAI'E' Ju~e i5, i98'7 REFERENCE' ARCO Cam-ed Hole F'i'na[ 2 .... i6 5-.t4-87 CH CNL Run t, 5' 7-20 5-~3i-87 CEI' Run t, 5' 1t--.24 6/3-4/87 F'rod. Profi [e Rut, i, 5" 12-1 5-;¢-87 CI-t C/V~- 6un 1, 5" i5-'i2 5--'i7--87 CH CNL Ru~ t, 5' t7--5 6-~-8'7 F'rod, F'rofi le Ru~ t, 5' Dress Camco ]Dr ms $ Dress Came o Please sigl"~ and return ~he attached copy as receipt of data. DISTRIBUI'ION ~ F'hi tlips F'B Welt F:, l. es R & D ~ $oh i o ~.- State of Alaska ~-.- Texaco ARCO Alaska, Inc. -~. Prudhoe Ba.~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 26, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-5 Permit No. 80-96 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/3MV/jp Attachment ce: Standard Alaska Production Company PI(DS 17-5)W1-3 be WELLS/96 ARCO Alaska. Im¢. is a Subsidiary o! AHantieRich,ieldCompany ~ STATE OF ALASKA )~ ALAL ~JOIL AND GAS CONSERVATION COk SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska, Thc, 3. Address P.O. Box 100360, Anchora'~e, AK 99510 4. Location of well at surface 2369' FNL, 425' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 1667' FNL, 1547' FEL, Sec. 21, T10N, R15E, UM At effective depth At total depth 1453' FNL, 1960' FEL, Sec. 21, T10N, R15E, UM 11. Present well condition summary Total depth: measured 10210 ' feet true vertical 9482 ' feet 5. Datum elevation (DF or KB) 70' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number 17-5 8. Permit number 80-96 9. APl number 50-- N?q-?n~NR 10. Pool Prudhoe Bay Oil Pool Plugs (measured) Effective depth: measured 10163' feet ;Junk (measured) true vertical 9447 ' feet Casing Length Size Cemented Structural Conductor 110' 20" 300 Sx Surface 2603' 13-3/8" 2300 + 400 Xx ! ~tormed!at~ Production 9209' 9-5/8" 500 Sx 'G' Liner 1306 ' 7" 500 Sx Perforation depth: measured 9444-9620' (8 intervals) true vertical 8873.7-9019' (8 intervals) Tubing (size, grade and measured depth) 5~", 17#, L-80 PCT, 4½", 12.6#, N-80 @ 8944' MD Packers and SSSV (type and .measured depth) Baker SAB Packer @ 8857' MI); Camco Bal-0 SSSV @ 2120' MD Measured depth 110' 2603' 9209' 10205' True Vertical depth 110' 2602.9' 8677' 9488' 12.At t ac h me nts Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation June 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby c~tify that the f, preg..oing is true and correct to the best of my knowledge Signed ~/~~,,~"~ Title Operations Engineering Manager Conditions of approval Approved by Date Commission Use Only Notify commission so representative may witness I Approval No. _,, ,"-) ,-- ~.. Plug integrity ~ BOP Test [] Location clearance~~._.. ..~.~' ~; ~: [. ~'~'[[] ~~issioner by order of ~ ~,~'~ '~ the commission Date Form 10-403 Rev 124-85 WELLS/96 J. M. Vitucci, 265-6358 Submit in triplicate DRILL SITE 17-5 AMINE PHOSPHONATE SCALE INHIBITION TREATMENT PRELIMINARY PROCEDURE AFE 699012' PROPERTY CODE 2120658-17 · · · · · Obtain a valid well test. Perform emulsification/sludging tests with wellhead fluid sample and EDTA. MIRU pump trucks and transports at DS 17-5. Pump the following fluids: a· c· 48 bbls of EDTA w/additives 133 bbls of selected scale inhibitor blend with 0.2 gals/bbl of liquid diverter. 730 bbls of diesel 215 bbls of dead crude 5 bbls of diesel Shut' in well for 12 hours. RD and release equipment. Obtain a valid well test and place well on production. 3MV/323 ARCO ALask-a, I~c. F:~a. Box ~00360 Anchorage, A~m~km ~ -r-..---.,:: '~ -' ' ~" '~' ._:..-' i' i c t.,r a d i ,=n "r ,_. .._.. ~-. i ,_z,-Uo ... ~ "' _ "---._,~-3;'i ...... .-,..'"' -,4-:::i/., ,.,"-'.4'84'', ,. ; r bi'"' .=:'d.: J eli *,. ---~.-~c., 4-9-86 ~,~' * ic i;-'.,-ad i eni' ~ S-SS 4-2i -86 £ ,'t. a i: ~ c: f, rad I el-il' -'- 3-34 4--i5-86 ;"-',:a-l:,. ic Grad '"'-- 4-.4 -?'~-'~'*-96,:- = :.'.' t a *, i C Gl-ad .... i ~vi't' ~4--..;-~' 4-24-',--.':6 S'~.-.-~± ia F....;-,~H... "" ~-~6 4-'~'. .... ,' '-'c..:.'"' S'+a* ia [~rad i ~7-i5 4--27-86 S±atic: Gradie'n-:, :..--..- -4-26-86 ::tat i c Grad ;e'r,.'t. · --: I:" ."I ," ~ 9-6 4-.--_.'--0o S?a t,; c 5'.,- a''~,_, i e'nt -"'i i --i (.]., :- :~_o¢. . ..:. _. . .'.]: 4- ' · - ,_ .... atic .ad; ent ,.2- ~ ~-. ~ 8£ - '---ti-J3 _:. _:. ,,_, S'ta,'tic b'.,-.~dier~t ~'i4-i i 4-~-°': S* . _ G':-ad .... :a't' i r .... ... ~-i, 4-29 ..;.'=-"'; O-E:6 ,~ i ow lng C-fa d i.e'n-'-, ,- .~---,',-86 £'.'ta't. ~c '-'- "- ' _ . ,_.,., ~o :: 6'i], --i 6-i 3 4.-26-86 L-:' ai: i c Grad i ~-~ 4-2-z-o z- .S. $ a 4. ' ' "-i , _,- .., ,_.,_, , ~ c Gr..-~d (]: a ~',:i C O C ...'~ ir.,. c o C C'.' a .:ii C C) [.': a .,'~'~ c 0 Ca .;lie 0 [: & m C c; C:a mc 0 Camco Ca f~iC 0 C:@ mc o ['J .-3 i..g C 0 C a i,'~ c o Ca ~Y.,c o Ca mC o Ca ~'fic o PLease sign a;-,d r:=-:-'.-.u'rr~ fh~ .m??ach,=d ,-r,~:>, a:~' term pi of,~,~.ai'a -. ~ ......:? _ -. _- irma Ca,.-Lin ATO-i 529 A R '"'' 0 A ~ a .'!~.' k a, I n c P ~ O~ B o x i '?),.'.-} .3 6 0 Anchorage ~ :() I ,? T f:.'. :I: B U T ]: 0 N ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: July 8, 1985 Reference- ARCO Pressure Surveys 5-8 ' Static' Gradient 5-31-85 5-11 Static Gradient 5-31-85 /~156-16 PBU 5- 31-85 -6 PBU 6-16-85 16-11 PFO 6-8-85 5- 29/30-85 · · as receipt of data. Otis Otis ·Camco Otis Camco Camco Received by Pam Lambert ATO 1429C Trans 19 3 Alaska Oii& was ~,~,,~. [;ommission Anchcrage Chevron D & M Phillips Expl. Services PB Well Files Ext. Exploration R & D Exxon Sohio Marathon State of Alaska Mobil Texaco ARCO Alaska. Inc. -.~'~) Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date' June 21, 1985 Reference- ARCO Pressure Data 6-7/Static Gradient 4-28-85 Camco 9-6 ~PBU 5-24/25-85 DA 12-25'~PF0 5-22-85 Camco 14-35 q~BU 5-31-85 Camco 14-35~Flowing Gradient 5-30/31-85 Camco 15-/~~ PBU 9-11-84 sS 1577/PBU .9-11-84 SS 15-8/PBU' 2-29-84 SS 15-8/PBU 10-20-84 SS 15-8/PBU 10-20-84 SS ..... ~.~PBU 5-29-85 Camco sign as receipt~ data~" ._,.~ ~.~ ~ D~ .....,, Received by Alaska 011 & ~a~ Con~, ~ommission Anchorage pam Lambert ATO 1429C .Trans 176 Chevron Expl., Services Ext. 'Exploration Exxon Harathon ~obil Phillips PB Well Files R&D Sohio Sttte of Alaska Texaco ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: April 23, 1985 Reference: ARCO Pressure Surveys 12-26~/PBU 4-3-85 DA 16-9 Gradient Survey 4-4-85 16-14 ~,-Gradient Survey 4-4-85 17-1/ Gradient Survey 4-6-85 17-2~' Gradient Survey 4-6-85 17-5/ Gradient Survey 4-7-85 18-3 ~' PBU Camco Camco Camco Camco Camco 1-9/10-85 DA n and return the attached copy as recipt of data. Received by Ar~cnorag9 Pam Lambert ATO 1429C Trans 079 Chevron ~& M Exp1. Services Ext. Exploration Marathon Mobil Mobil E & P l~-llips - .~-Well Files State-of Alaska . . ARCO A La:;'t-::a, Inc,. F:',O, t--)c,x I£:,03;6(:) Anchorage, A Las'.ka o°""f DATE' December":'.1 i°E'4 REFERENCE · '" '"" _, tuRbO F:'re~ure Data D,,S', 9-6 16,-1I'-.84 PBU Sur ,..., '~2-4 11-..,..o-8-~ ..,'fa't- i c. I),,.., '~ , I .,.."~'-8B i i-26-84 St a't'i'c D S t o_o¢ '~ t-26-84 D. S , i ~"'~-":'°.,..~ I --.')-I -84 ,i?.. t' a t' i c D S t ":'--~= i 2-t -84 , ,.... .,-.. ,.., ,... ,. a q: i c D,,?, ~,-..-.~, ';--' .... 84 ,?l'al'ic D.,:..~"t~''-- n ?=. ..., f ...-.3;- 84 ~':.¢' t' a t' i c ' ¢" 4. 4. D $,. i.,.."':'-'-"°.,.. :. t .,.."~-'i-84 ~ ,.¢: i c D, ,..,'"" ,. i; ,.:, TM - =,.., i t -.i 7-84 ,S"t- a. -t: i c D,$., I 3-4 i i -'t 7-84 ,:?t'a't' i c D,. S,, I 3;-6 i i -'t °-84, Z..:'t a I' i c D.,,S, i 2;-'7 t I -! 7-84 .?'t'8i' D S i2;-IS il--i°-~* , , ,-o-, ,,tat i c T', ? i S-'l 4 i i -I o R.*, ,?'l'a 't' ir:. i), Z.,' i 4--i 2 ii-.4 :.-c:' :' "" . , ~.., ~..,-:. ,..~ 't.' · ' O~ --0..-2 D,S, t6-~ , i ,_,.. F'DD D,.S, i 6-6 9-22-84 F:'BU D, ,S', t6,-9 3-f9-84 S't'a .... o-84 D 5' t~--1i ~ .... ;,, il;: .. S ,. 9-26-84 F' T-': U i; , ..':,-i °-84,. , S+e. F'[ea-.'~:e sign and 're!'u'rn vey Grad i enl' g.r ad.i eh!' O r a cli e n 'f Grad i eh-I: Eradien~ Gracl ient' E r a d i e n 't Gradient Grad i eni' Grad i en~ Grad i ent' [~racl i en~ G r a d i e ni' [~rad i ent' G r a d i e n t' i'ic: Gradieni' ,~. Lll' vey .S'urvey 't i c: G. radien+. · l:ic: Gradien't ,S'urvey · t' i c C;.'~.ad i eh!' i',he a't:.'t'ached copy as re,:.:eip'f o'f.' da i'a., I<eLLy HcF'arLa'nd ¢.'-: ""' 0-4 429F .i ! .: 'f'RANS. ~'422 I) ! S'f' F.: I BUT I ON Ch ev:- F. xp[.ora't, ion Service:s E :,: ~: '-.._ :.=.'~ '- i r',_. n E x r:' L o r a 4., i r,_ n P_XXO1] Mob i L Hob il. E & F' Phi !.Lip~ F'rudhoe Bay We El R & i."t:. ;': O.t i 0 ,:.:a:e of ALa.?i<a Fi Les ARCO Alaska, Ir .... ~ Post Offic= dox'100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 13, 1984 Mr. Harold Hedlund State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 17-5 Dear Harold, The DS 17-5 incorrectly designation this change Well Completion Report, dated December 16, 1980, lists the ADL number as 28334. The correct lease for this well is ADL 28331. Could you please make to your records/files. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L05 XC: K. McFarland, ATO 1429 P. T. Willman, ATO 1069 Well File RECEIVED DEC 1 4 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany ARCO ALa:-'.:ka, Inc F:',.O, Box i Anchorage, A La.ska 99.5 ~ ~) DA'T'E' Oc:'t'ober 2('.'), t984 R E F:,... , ,..'::' ':' E N, C E · A R [": ...... 0 C a :~; e d H ,"~ L e F i n a L ':; C: a m c o GO C a m ¢: o [; 0 (:.;0 (:.;0 GO :ii: ,.':: I'1 C a hi C: 0 (;.0 T' e-I.' U. 'i" 1'i · t: h e a .1: -I: a c h ecl HAVE A NICE OAY! ':J'"~- L ,~::~ .......... ~.1 Ke I. I.y i"icF'ar i. and A 'T 0 -' ~-,,.... -'~ '') o: I::'. . . 'T' R A N,","., :~389 Ch e¥)' on D & M ExpLoration Service:~ Extens-ion ExpLoration Ex xon iq.ara t I",, o n Hob i L H o b i I. E & P Phi tLips I::'rudl'loe Bay t4eL L Fi Les R & D $ohio State of ALaska ARCO Alaska, Inc. '] Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer July 9, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 17-1 DS 17-2 DS 17-5 DS 17-7 DS 17-9 Permit No. 80-55 permit No. 80-70 Permit No. 80-96 Permit No. 81-66 Permit No. 81-90 Enclosed are the Completion Reports for work done on the above mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Enclosures cc: SOHIO Alaska Petroleum Co. File P1 (DS 17-1)W4-3 File PI(DS 17-2)W4-3 File P1 (DS 17-5)W4-3 File P1 (DS 17-7)W4-3 File Pi(DS 17-9)W4-3 RECEIVED J U L ! 6 ]984 Alaska Oil & Gas Cons. Commission Apchora~e ARCO Ala.ka, Inc. I$ a SubsIdl.ry of AlP, ntlcRIchfleldCompany ALASKA. LAND GAS CONSERVATION C. ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] SUSPENDED [] ABANDONED [] SERVICE [] OI L~] GAS 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-96 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50-029-20508 4. Location of well at surface 9. Unit or Lease Name 2369' FNL, 425' FWL, Sec 22, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1667' FNL, 1547' FEL, Sec 21, T10N, R15E, UM DS 17-5 At Total Depth 11. Field and Pool 1453' FNL, 1960' FEL, Sec 21, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 70' RKBI ADL 28334 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshOre 116. No. of Completions 10/13/80 10/31/80 11/5/80 feet MSL Single 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 10210'MD- 9482'TVD 10163'MD- 9447'TVD YES~ NO [] 2127 feet MD 1900' Approx, 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL, GR/CAL, Cyro/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94~ H-40 Surf. IICI ~" 13-3/8" 72~ L-80 Surf. 2603' 17~_" 2BDO .q~ Fnndt~ & /+00. SX Permafrost II 9-5/8" ~75~ ~00-95 Surf. 9209' 19~,, ~ sw Class G cm..t ~-80 7" t~ 8899' 10205' 8~" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number).New Perfs w/4spf SIZE DEPTH SET (MD) PACKER SET (MD) 9444- 9452'MD (8') 8900- 9047'TVD 5½" 8944' 8862' 9464- 9474'MD (10') ' ' *9490 - 9502'MD (12') 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9502 - 9512'~) (10') DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9519- 9529,~) (10') '. 9540- 9560'MD (20') N/A *9575 - 9590'MD (15') ' . " *qan5 - q~90,wn (15') ." , ,,; " 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 6/4/81 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 6/18/84 22.7 TEST PER lCD. I~ 3~,93 2548: 0 Flow Tu~oing Casing Pressure CALCULATED ~ OIL-BBL GAS~MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 460 24-HOUR RATE~ 3482 2694 0 26.7 28. CORE DATA ..... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED JUL 1 6 1984 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Submit 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,an,d time of each phase. Top Sadlerochit 9441' 8898 ' O/W Contact 9675' 9093' Base Sadlerochit 10107 ' 9444 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed . _ _ . Title Regional Engineer Date 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- lng 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 ARCO Alaska, In,., ; Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 July 13, 1984 Reference: ARCO Cased Hole Finals D.S. 1-26 5-30-84 D.S. 3-23~; 5-24-84 D.S. 13-29''~/ 6-1-84 D.S. 14-22 5-27-84 D.S. 14-23~';~ 5-17-84 D.S. 14-28 ~ 5-28-84 D.S. 17-5'~ 5-24-84 CFS/Flowmeter CFS / F1 owme te'r CFS/Flowmeter CFS/Spinner CFS / Sp inner CFS/Spinner Collar/Perf Log Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" GO ~se sign and return the attached copy as receipt of data. Friday the 13th is back again, have a safe one! Ke 11 y Mc Far 1 and ATO-1429F Trans. #268 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mobil ~_..= ' _.__ r Mob i 1 Phillips / Prudhoe Bay Well Files Carolyn Smith State of Alaska Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 25, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 17-1 DS 17-2 DS 17-5 DS 17-7 DS 17-9 Permit No. 80-55 Permit No. 80-70 Permit No. 80-96 Permit No. 81-66 Permit No. 81-90 Attached are "Subsequent Report" Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File P1 (DS 17-1)W1-3 Pi(DS 17-2)Wl-3 Pl (DS 17-5)W1-3 Pi(DS 17-7)W1-3 Pl (DS 17-9)Wl-3 RECEIVED JtJN Z 8 19 14 Alaska O~l & Gas Cons. C0mm/ssl0.~ Anchorage ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIchfleldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED W E L LlX~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-96 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 2369' FNL, 425' FWL, Sec. 22, T10N, R15E, UM (Producing Interval) 1667' FNL, 1547' FEL, Sec. 21, T10N, R15E, UM (Total Depth) 1453' FNL, 1960' FEL, Sec. 21, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 70' RKB I ADL 28334 12. 8. APl Number 50- 029-20508 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 17-5 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations X~] Altering Casing [] Stimu late [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 5/24/84. RU perforating unit, pressure tested equipment. RIH with gun #1, shot interval 9490 - 9502' MD (4spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun #2, shot interval 9575 - 9590' MD (4spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun 93, shot .interval 9605 - 9620' MD (4spf), flowed well to clean up. Shut-in well, POOH, all shots fired. Ran SSSV, secured well, RD. Ref: BHCS 10/29/80 RECEIVED JUN2 8 Alaska Oil & Gas Cons. Commi~lon Anchorage 14. I hereby c~,r.~ify that the foregoing is true and correct to the best of my knowledge. // The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc Prudhoe Bay ~-nglneering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 2, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 17-1 DS 17-2 "Ds 17-5 DS 17-7 DS 17-9 Permit No. 80-55 Permit No. 80-70 Permit No. 80-96 Permit No. 81-66 Permit No. 81-90 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments CC: Sohio Petroleum File Pi(DS 17-1)W1-3 Pi(DS 17-2)W1-3 P1 (DS 17-5)W1-3 Pi(DS 17-7) W1-3 P1 (DS 17-9)W1-3 RECEIVED APR 9 'i984 Alask~ Oil & Gas C~ns. C~mrnis~.ion A%h:,rage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASK AND GAS'CONSERVATION i MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WE.LL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-96 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20508 4. LocationofWell 2369' FNL, 425' FWL, Sec. 22, T10N, R15E, UM 9. Unit or Lease Name Prudhoe Bay Unit 1667' FNL, 1547' FEL, Sec. 21, T10N, R15E, UM 1453' FNL, 1960' FEL, Sec. 21, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 70' RKB 6. Lease Designation and Serial No. ADL 28334 10. Well Number DS 17-5 11..Field and Pool PrudhOe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARC0~Alaska, .Inc. proposes to add Perforations on DS 17-5 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 9575-9590' MD 9605-9620' MD Ref: BHCS 10/29/80 ^PF .... 9 t984 Subsequent Work Rep~ 14. I hereby Cl~itify that the foregoing is true and correct to the best of my knowledge. Signed--., .. _ __ Title Regional Engineer The space below for Commission use Date Conditions of Approval, if any: OliiG,NAL $1GIIF. D BY LBII#IE f,. $Iilll Approved by COMMISSIONER Approved Cop~ ~Re~rr~l~ By Order of the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office )~0 .~nchorage. , a 99510 Telephone 907 277 5637 December 8, 1983 Reference: Arco Pressure Data D.S. 13-30 11-20-83 Pressure Build-up Camco 11-20-83 Pressure Build-up Data Sheet D.S. 17-5 10-31-83 Static Survey Otis Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 646 Chevron D&M Dallas Drilling Exxcn Getty Marathon Mobil DISTRIBUTION North Geology Phillips Prudhoe Bay R & D Caroline 5mi;k Sohio State of Alaska ARCO Alaska, Inc. ~ Post Office Bo.-¢60 Anchorage. Alaska 99510 Telephone 907 ~.,, ~oo, June 10, 1983 Reference: Arco Pressure Data D.S. 1-13/ 5-30-83 D.S. 1-18 / 5-30-83 D.S. 6-18 × 5-11-83 D.S. 6-23 £ 5-1-83 D.S. 7-2 / 4-9-83 4-9-83 D.S. 12-11/ 5-.30-83 .D.S. 14-29J~ 4-2-83 4-2-83 D.S. 14 -30 × 4-1-83 4-1-83 D.S. 17-5 .f 5-19-83 D.S. 17-9/ 5-18-83 Static Survey Camco Static Survey Camco Static Survey Camco Static Survey DA Pressure Build-up Camco Pressure Build-up Data Sheet Static Survey Camco Pressure Build-up Camco Pressure Build-up Data Sheet. Pressure Build-up Camco Pressure Build-up Data Sheet Static Survey Camco Static Survey GO Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. ~ 381 DISTRIBUTION NORTH GEOLOGY DRILLING :~..SQHIO. ~ MARATHON - :..,. ':' !;'-c;'_~ ......... ' . :--D -& M · ~ :~-:-...- ~.~,..~ ~A~".~-...-:, ~ ..... DALLAS CHEVRON CAROLINE SMITH ARCO Alaska, Inc. ~% Prudhoe Bay Engrneering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 5, 1983 C. V. Chat Chatterson STATE OF ALASKA Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: · RE: Prudhoe Bay Unit DS 3-11 Permit No. 79-47 DS 16-10 Permit No. 80-04 DS 16-11 Permit No. 80-118 DS 16-14 Permit No. 81-32 ~~ermit No. 80-96 DS 17-9 Permit No. 81-90 Enclosed are Sundry Notices requesting permisSion to run static bottomhole pressure surveys on key wells 3-11, 16-11 and 17-5, and section wells 16-10, 16-14 and 17-9, in lieu of the pressure transient test prescribed in Conservation Order 165, Rules 6-c and 6-d. The six wells are shut-in for bottomhole pressure maintenance and are being monitore~ until, waterflood in June 1984. The static bottomhole pressure surveys should provide an accurate measurement of reservoir pressure. We are requesting permission to run static surveys on the key wells, DS 3-11, 16-11 and 17-5, to fulfill the requirements of Conservation Order 165, Rule 6-c for the first and second half of 1983, along with the first half of 1984. On section wells 16-10, 16-14 and 17-9, we are requesting permission to run static surveys to fulfill requirements of Conservation Order 165, Rule 6-d, for 1983. If you have' any questions concerning this request, please contact Jerry Schuyler, 263-4234. Very truly yours, D. F. Scheve DFS/RDC/lmi cc: J. W. Groth/E. W. Skaalure J. A. Rochon J. R. Schuyler ARCO Alilkl, Inc. II · Sublldliry of AtlinllcRIchlleldComplny STATE Of AlaSka ALASKA AND GAS CONSERVATION CO ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLT~3 OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-96 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20508 4. Location of Well 2369' FNL, 425' FWL, Sec. 22, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 70' RKB 6. Lease Designation and serial No. ADL 28334 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 17-5 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. requests permission to run a static bottomhole pressure survey on key well 17-5 in lieu of a pressure transient test. Conservation Order 165, Rule 6-c requires a semi-annual transient survey on key wells. ARCO Alaska, Inc. prefers to continue monitoring reservoir pressure with a static survey in the downstructure Flow Station 2 area at key well 17-5, until waterflood in June 1984. The static pressure survey should provide accurate reservoir pressure data. We are requesting permission to run a'static survey on the well to fulfill the requirements of Conservation Order 165, Rule 6-c for the first and second half of 1983, along with the first half of 1984. ~a Fo~rm No. ~ Dated ~/~ ~lasRa 0il & Gas Cons, Commissian 14. I hereby,~,~rtify that the foregoing is true and correct to the best of my knowledge. () Signed ... ..... ~. Title i{egional Knglneer /he space below for Commission use Date / / Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy By Order of the Commission Date Form 10403 Rev. 7-1-80 ~' Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Post Office Box 360 Anchorage. A' 99510 Telephone 96 5637 January 20, 1983 Reference: Arco Pressure Data D.S. 1-18 D.S.- 16-10 D.S. 16-14 .D. S. 17-5 D.S. 17-9 11-13/14-82 1-10-83 1-13-83 1-16-83 1-17-83 'Pressure Build-up Camco Pressure Build-Up Survey Report Static Pressure Survey GO Static PYessure Survey Data Static Pressure Survey GO Static Pressure Survey Data Static Pressure Survey Camco Static Pressure Survey Data Static Pressure Survey Camco Static Pressure Survey Data /Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 068 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS · SOHIO MARATHON CHEVRON MOBILE GE Y D&M STATE OF ALAS~ DALES ARCO Alaska lnc ~-~ a S~D~,~,'3~;~, ¢,{ AIlanf,¢~,chl,et~Cc~mD,3n, Post Office B~x 360 Anchorag{ '~ka 99510 Telephone = .,~E77 5637 December 16, 1982 RE: ARCO Pressure Surveys D.S. 3-8 11-20-82 D.S. 3-13 12-3-82 D.S. 3-15 11-21-82 D.S. 6-4 12-2-82 D.S. 6-11 11-11-82 D.S. 6-12 11-11-82 D~S. 11-6 11-7-82 D.S. 11-7 11-7-82 D.S. 13-1 10-22-82 D.S. 13-3 10-23-82 D.S. 13-5 10-29/31-82 D.S. 13-22 11-22-82 D.So 13-23A 10-12-82 D.S. 13-2.4 11-19-82 Stat i c Survey Pressure Bui ld-up Static Survey Pressure Bui 1 d-up Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Pressure Buil d-up Static Survey .Static Survey Static Survey Camco Gearhart Camco Otis Camco Dresser Camco Camco Camco Camco Camco Camco Camco CamCo B~$",'~'"~'T?~~ 11-18-82 Static Survey Camco 17-6 11-18-82 Static Survey Camco Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA- 403 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON Trans. #662 EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS Alaska Olt ~i~ :L~'s {]:.,,~'.,. ~]~:~:~i~$io:~ Ancho~ag~ ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldComD in.,' ARCO Alaska, Inc. Post Office j360 Anchorage, ,-,.Jska 99510 Telephone 907 277 5637 October 22, 1982 Reference: ARCO Pressure Data D.S. 17-5 10-14-82 D.S. 13-19 10-8-82 D.S. 16-3 10-26-81 D.S. 14-18 9-16-82 D.S. 18-2 9-26-82 Pressure Build-up Survey Pressure Build-up Survey Pressure Build-up Survey Static Survey Static Survey OTIS Gearhart OTIS D/A CAMCO ~41ease sign and return the attached copy as receipt of data. Becky Benedict AFA - 403 Trans. #576 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON GEOLOGY STATE OF ALASKA DALLAS ARCO Alaska, Inc. Post Office B~360 Anchorage, )ka 99510 Telephone 9L.. ~77 5637 October 8, 1982 Reference: Arco Pressure Data D.S. 17-5 9-8 -82 Static Survey Camco Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 540 DISTRIBUTION NORTH GEOLOGY R&D DRILLING GETT~ PHILLIPS D&M SOHIO GEOLOGY MARATHON CEEVRON , DALLAS MOBIL Naska 0ii & Gas Cons. Ccmmissi0n Anchorage ARCO Alaska, Inc. -\ Post O'~fice 5 )60 Anchorage, A,_,,~a 99510 Telephone .207 277 5637 August 12, 1982 Reference: Arco Cased Hole Finals D.S. 2-25" 7-11-82 CBL'/VD Run 1 5" D.S. 12-10 6-18-82 EPL Run 1 5" D.S. 12-10~? 6-18-82 TDT Run 1 5" D.S. 12-11 J 6-17-82 EPL Run 1 5" D~'. 17~/~ 10-7-81 CPL/TDT-M 5" Sch Sch Sch Sch Sch e sign and return the attached copy as receipt of data. Kelly McFarland Trans. # 379 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA DAL~ 'U,.~ska Oil ARCO Alaska, Inc. Post Office Bo~60 Anchorage. /; Jla 99510 Telephone ~0--"_~, 5637 May 3, 1982 Reference: ARCO PRESSURE DATA 3-16/17-82 Pressure Survey D.S.17-1 3/7/82 " " DS..2-11 2-14/15-82 " " D.S.7-11 10/23/81 " " D.S.2-2 2/13/82 " " D.S.2-5 2-3/4-82 " " D.S.17-2 10/11/81 " " se sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 141 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON ~~'~t21 CHEVRON Gas Cons. Com~ssion /~c~orao~e ALASKA OIL AND GAS CONSERVATION COMMISSION February 19, 1982 / JAY S. NAAf¥OND, GOVERNOR / / 3001 PORCUPINE DRIVE-ANCHORAGE, ALASKA 99~01 ADMINISTRATIVE APPROVAL NO. 1'65.3 Re: The application of ARCO Alaska, Inc., operator of the . : Eastern Operating Area, Prudhoe Bay Unit, to add two new key wells, DS 16-11 and~ in the pressure monitoring program set out in Ruler6 of Conservation Order No. 165. Mr. J. A. Rochon District Operations Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Dear.'Mr. Rochon: -_ The referenced application was received on February 17, 1982 and stated that ARCO Alaska, Inc. requests approval for the DS 16-11 and DS 17-5 wells as key-wells for Drill Site 16 and 17' in the pressur'e'monitoring program. The Alaska Oil and Gas Conservation Commission hereby authorizes DS 16-11 as the key well for Drill Site 16 and DS 17-5 as the key well for Drill Site 17 in the pressure monitoring program, pursuant to Rule 6 of Conservation Order 165. Yours very truly, -' : Harry W. I<ugler Commi s s i one r BY THE oRDER OF THE COMMISSION ARCO Alaska, Inc. '~ North Slope [ ~l~ct Post Office Box '350 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon ~District Operations Engineer February 11, 1982 C. D. Chat Chatterton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska .99501 Dear Mr. Chatterton' Re' P, rudhoe Bay Unit Conservation Order 165, Rule 6-g Key Well Designation ARCO Alaska, Inc. requests Commission approval of key well designations for Drill Sites 16 and 17. Conservation Order 165, Rule 6-g, states that the operator shall designate key wells for pressure surveys for newly developed-drill sites subject to Commission approval. We request an administrative order to designate the following key wells. · , Drill Site Requested Key Well 16 16-11 17 ~ If you. have any questions concerning this request, please contact Debra Hyde at 263-4297. Si n..qerely,, 4 JAR' DAH'ml c cc- R. A. Weaver R. K. Doughty M. A. Weber FEB t 7 1982 Nas~ 0it & Gas CoNs. Comml~sl0n ARCO Alaska, Inc. is a subsidiary of AllanticRlchfieldCompany ARCO Alaska, Inc. Post Office ~')360~' Anchorage, ~tiska 99510 ! Telephone 907 277 5637 October 28, 1981 Mr. Jim Trimble State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble' Subject- Sub-Surface Safety Valve Setting Attached please find the Sub-Surface Safety Valve (SSSV) set'ting depths for the wellS mentioned in our 10/22/81 phone conversation. Please note that all measurements are measured depths. If we can be of.any help in the future do not hesitate to call. Sincerely, Graham A1 vord Associate Engineer GA: 1 tc Attachment 17-1 '17-2 17-3 17-5 17-6 16-1 Sub-Surface Safety Valve, Setting'Depth Measured Depth (MD) ft. 2162' 2204' 2167' 2127' 2130' 2127' A!~ska Oil & Ga.q Cens. Cotiunisr;~al-~ Anc!)ora~e ARCO Oil and Gas Company North Alask"~)rict Post Office b,.,x 360 Anchorage, Alaska 99510 Telephone 907 277 5,537 Jerry A. Rochon District Operations Engineer November 13, 1981 Reference: ARCO CASED HOLE FINALS D.S.1-8 10/18/81 CNL Run 6 5" D.S.2-10~/ 9/26/81 Spinner 5" D.S.2-14~/ 10/14/81 EPL Run 1 5" D.So5-5'~/ 10/17/81 CNL Run 3 5" / D.S.5-7 ~/ 10/16/81 CNL Run 7 5" D.S.5-12~j 10/17/81 CNL Run 5 5" D.S.6-3 ~/ 9/'29/81 Spinner 5" D.S.6-3 ~ 10/16/81 CNL Run 5 5" D.S.9-4~/ 10/18/81 CNL Run 3 5" D.S.14-4 ~ 10/24/81 CBL/VD Run 1 5'" / D.S.17-S!I~/ 10/7/81 TDT Run 1 5" Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #741 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY .,,~.. O" F',: ,. SOHIO NOV] ~]~,~' - ~ NARATHON . CHEVRON ...... ARCO C)~1.1nd ~as Company ~s a OtwsiQ, n of AtlanhCfllchheldCompany ARCO Oil and Gas Company North Ala~ District Post Ott;~J[ ox 360 Anchoraqe', Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 4, 1981 Reference: ARCO MAGNETIC TAPES & LISTS D.S. 7-3 10/15/81 Tape #62236 ~ 10/7/81 Tape #62233 Please sign and return the attached copy as receipt of data. -Mary F. Kellis North Engi. neering Transmittal #715 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO ©d ,'lqd (:1 is C,.)mp,~ny ;s a Oi~,islg, n ol AtJa,H,cR~chf~etdCompany ARCO Oil and Gas ComPany North Alask~ ~.~rict Post Office B. ,, o Anchorage, Alaska .o9510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 26, 1981 Reference: ARCO Pressure Data D.S.17-1 10/5/81 Pressure Survey ~p. S'.l 7~5~!-!? 1,o/8/81 D.S.2-1A 9/13/81 Pressure Survey Pressure Survey sign and return the attached copy as receipt of data Mary F. Kellis North Engineering Transmittal #693 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON ,.. GETTY ' "~4~<' ~/' / ~""~ PHILLIP~ "; SOH I 0 " HARATHON CHEVRON ARCO 01| and G,~$ Company ;s a D~v,s~on o! A!lanhcR~chtlelc~Col~paF~y ARCO Alaska, Inc. North Slope ~],'{ct Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October '12, 19.81 Mr. Hoyle HamiltOn State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: D.S. 16-1 Permit No. 80-136 D.S. 16-2 Permit No. 80-150 D.S. 16-8 Permit No. 80-02 D.S. 16-9 Permit No. 81-19 D.S,.16-10 Permit No. 80-04 D.S. 16-11 Permit No. 80-118 D.S. 16-16 Permit No. 80-127 D.S. 17-1 Permit No. 80-55 D.S. 17-2 Permit No. 80-70 D.S. 17-3 Permit No. 80-77 D.S. 17-5 Permit No. 80-96 D.S. 17-6 Permit No. 80-132 Dear Mr. Hamilton' Enclosed are our Completion Reports for the above-mentioned wells. J. A. Rochon JAR: DAH: adri Attachments OCT 2 0 198! Oil & Gas Cons, Commfs.~for~ ARCO Alaska, Inc. is a subsidiary o! Atlant,cRichfieldCompany . . ALASKA ND GAS CONSERVATION CO, ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG · _ -1 ..Status of Well , Classification of Service Well · ~ , · t . OIL ~XX GAS [] SUSPENDED [] . ABANDO=NED [] SERVICE [] , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-96 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50- 029-20508 4, Location of well at surface 9. Unit or Lease Name 2369' FNL, 425' FWL, Sec.. 22, T10N, R15E, UM Prudhoe Bay Unit At'Top Producing Interval 10. Well Number 1667' FNL, 1547' FEL, Sec. 21, T10N, R15E, UM D.S. 17-5 At Total Depth 11. Field and Pool' 1453' FNL, 1960' FEL, Sec. 21, T10N, R15E, gM. Prudhoe Bay Field ~.5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No'. Prudhoe Oil Pool 70' RKB] ADL 28334 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10-13-80 10-31-80 11-5-80I feet MSL I ~'~ .17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. T~of Permafrost 10210'MD 9482'T~D 10163'MD'~ 9447'T~lfESx~ NO[]I feetMD I / "2'~2. Type Electric or Other Logs' Run I DIL/SP/BHCS/GR, FDC/CNL,GR/CAL, Gvro/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94{~ H-'40 sllrfjaoe ~ ll0.' 32" 300 sx permafrost to SurfaCe 13-3/8" 72~! L-80 Surface 2603' 17-1/2' 2300 sx Fondu & 400 sx Permafrost II '9-5/8" 47~ S00-95 sUrface .9209' ' 12"!/4' 500 sx. Class. G ~ . - L-80 ... 7" 8899 10205 500 Sacks of Cement '24. Perfora. tions open t.o Production (M.D+TVD of Top and Bottom and ,.. .25. TUBING RECORD , .interval, size andnumber) , sI.ZE DEPTH.SET (MD) PACKER SET (MD) 5 1/2" 8944' 8862' 9444-9452' M.D. , 9464-9474 ' M.D. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTE!~VAL(MD) AMOUNT& KIND OF MATERIAL USED 9502-9512' M~D.'~ ~' ~ .~. ., .. ~, 9519-9529' M.D. N/A · , . 9560-9540' M.D. 887R' T',V~D.-8952" T.V.D' ~ ~, ~, · 27. PRODUCTION TEST Date First Pr,0duction ~ [ Method of Operation (Flowing, gas lift, etc.) 6-4-81/ "" Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO 9-11q8l 12.3, TESTPERIOD ~ 1237 1340 0... 41 1084 Flow Tu?ing Cas ng ~4'essure CALCULATED .OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1'017 .,~. 24-HOUR RATE I~ 2413 . 2615 ' 0 26.7 .... 28. CORE DATA -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chil~s. : :. RECEIVED · OCT 2 0 ]~.~ - A!a. ska 0il & Gas Cons. C0mrnissi~,,~ - Anchorag~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .... · :.~ :.. ./ .,;,., , .. ... GEOLOGIC MARKERS " FORM~'~:i"oN 'TES'FS ,, · ' NAME Include interval tested, pressure data, all fluids recovered and gravity, -" ' . MEAS. DEPTH TRuE VERT. DEPTH GO.R, and time'of e.a. ch phase. : 12. Sadlerochit 9,441 ' 8871 ' N/A g. Sadlerochit 10,092' 9392' . · . 31. LISI OF ATIACHMENTS ' · . 32. I. hereby certify· that the foregoing is true and correct to the best of my knowledge Signed TitleDistrict Eng~flo~r Date . 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 cc~-npletion), 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- lng 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 10-40? ARCO Oil and Gas c~q~r!pany North Alask~ Jstrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer August 27, 1981 Reference: ARCO PRESSURE DATA D.S.17-5 6/6/81 Pressure Survey ~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #552 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY MARATHON A!2ska OiJ & Gas Cons. Commission CHEVRON Anchorage ARCO Oil and Gas Company is a Division of AllanticRichlieldCompany ARCO Alaska, Inc. f'.l orlh Slop~-~ · Post Office Jul.y-27, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine. Drive Anchorage, Alaska 99501 SUBJECT' D.S. ]7-1 Permit No. D.S. 17-2 Permit No. D.S. 17-3 Permit No. D.S. 17-6 Permit No. 80-55 80-70 80-77 80 -96 80-132 Dear Mr. Hamilton: Enclosed are our Sundry Notices of work completed on mentioned wells. Ver~.,.~ruly yours, · / '-J. A. Rochon JAR: DAH' ad r i Attachments the above- ARCO Oil an(~ Company North Slope District Post Office BOx 360 Aqchorage, Alaska 99510 Telephone 907 277 5637 January 5, 1981 Mr. Hoyle Hamilton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject. Lake State #l DS 17- 5 6 ~--~/- ~ ~-o ~ West Sak #12 DS 11-14 DS 2-18 DS 2-17 ~ ~c~o~ I I RcS ENG _L2 ENO I 3 I 4 -- I 2 .... ._~ ~ STypTiC 1 Dear Sir- Enclosed please find' l) 2) A Sundry Notice of intent detailing the work to be per- formed on Lake State #1. Two (2) copies of the gyroscopic survey for DS 17-5. 3) An updated completion report including production test data for West Sak .//12. 4) Two (2) copies each of the updated completion report and the gyroscopic survey for DS 11-14 and DS 2-18. 5) The gyroscopic survey for DS 2-17 is being rerun. The required updated completion report and gyroscopic survey will be submitted as soon as data becomes available. Very truly yours, P. A. VanDusen DJstrJct DrJ11Jng EngJneer RECEIVED PAV'sp Enclosures Alask~ Oil & Ge.s Cons. Commission Anchorago ARCO Oil and Gas Company is a Di',,i~ ¢~-d~,:-rtishfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~x× OTHER [] 2. Name of Operator ARCO .Alaska, Thc. 3. Address ?. O. :Bo× 360,' Anchorage, Alaska 99510 4. Location of Well 2369' FNL, 425' FWL, Sec. 22, T10N, R15E, UM 7. Permit No. 80-96 8. APl Number 50- 029-20508 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 17-5 11. Field and Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 70 KB I ADL 28334 Prudhoe Oil Po°l 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations :3~X Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perf operations 6-4-81. Tst tbg and annulus. Tst tree. NO and test perf. equipment. NU and test wireline BO? and lubricator. Run CN-log. ?err ~with 4 S?F. Unloaded to tanks. Flow to flow station. ?erf~ 9502-9512. Flowed and tested. Record BH?. RD unit 6-7-81. Secure well. Flow and test. RO unit 6-8-81 to complete operation. NO and test perf. equipment. NU and test wireline BOP and lubricator. Per'f. ~4, ~45~ with 4 SPF. Reperf 9560-40, 9519-29, 9502-9512, 9464-74, with 4 SPF. Reperf. 9444- 52, 4 SPF. Gun misfired. RD unit. Secure well 6-9-8!. Installed SSSV on 6-]4-8]. RECEIVED JUL A/M/. O, & G.s ,,:. 14. I hereby certi, f~that the foregoing i~"~rue and correct to the best of my knowledge. The space)~e~w for Commission use Condition~/of Approval, if any: 7-20-81 By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas ~ompany North Alasl. i .Strict Post Office ,., 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer July 9, 1981 Reference:ARCO Magnetic Tapes & Lists D.S. 11-14 (T-3) 6/10/81 6/18/81 Tape#NL 12300-12540 Tape#CN 8770-10150 Dresser Dresser n and return the attached copy as receipt of data. Mary ¥. Kel!is North Engineering Transmittal #422 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALAS~ EXXON MOB I L GETTY JUL 1 3 1981 MAR^THON Alaska Oil & Gas Cons. Commission CHEVRON . Anchorage ARCO Oil and Gas Company is a Division o! AtlanlicRichlieldCompany ARCO Oil and Gas C~ompany North Alas~ ~)istrict Post Office ~dx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer June 26, 1981 Reference; ARCO Cased Hole Final Prints D.S. 12-10 6-3-81 ACBL/VDL D.S. 14-19 6-1-81 ACBL/VDL D.S. 16-2 4-14/15-81 CCL D.S. 16-13 6-9-81 CNL ~ 6-4-81 D.S. 17-7 6.7-81 runl runl runl runl / 2" 5" L// CNL~ G~ Ray Multi-Spaced Neutron run 1 ACBL/VDL Ganma Ray run 1 5" ~/ Please sign and' return the attached copy as receipt of data. Kelly McFarland No~/~ Engineoring Transmittal # 375 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON RECEIVEI) JUN 0 1981 Nas~ 011 & Gas Cons. Commission /~chorage ARCO Oil and Gas Company is a Diw$,on ol AtlanlicR~chfieiclCompany ARCO Alaska; Inc. North Slot )istrict Post Office ~x'360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer April 30, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: D.S. 17-1 Permit No 80-55 D.S. 17-2 Permit No 80-70 D.S. 17-3 Permit No. 80-77 D.S. 17-4 Permit No. 80-85 D.S~. 17-5 Permit No. 80-96 D.S. 17-6 Permit No. 80-132 Enclosed are our Sundry Notices detailing the work to be done on the above mentioned wells. Very truly yours~7 District Operations Engineer JAR/HFB/kam Enclosures RE£E VED MAY - 6 198i 0ii & Gas Cons. Commisstor~ /mchorage ARCO Alaska, Inc. is a subsidiary of AtlanlicRichfieldCompany t STATE OF ALASKA ALASK L AND GAS CONSERVATION (., MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL :~] OTHER [] 2. Name of Operator ARCO Alaska 3. Address P. O. Box 360 Anchorage, AK 99510 4. Location of Well 2369' FNL, 425' FWL, Sec. 22, T10N, R15E, UM 7. Permit No. 80-96 8. APl Number S0--029-20508 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 17-5 11. Field and Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 70 KB I ADL 28334 Prudhoe Oil Pool 12. Check AppropriateBox Tolndicate NatureofNotice, Repo~,orOtherOata .NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Aba ndonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] [] [] [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of s~rting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay. Unit. Upon perforating the well will be flowed to the flow station for clean up and production. Should additional drawdown be necessary to unload the wells it may be flowed to a tank for initial clean up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of'the perforating and clean up operation. RE£E VED. MAY - 6 1981 Alaska 0ii & Bas Cons. Commissii Anchorage Signed_ )f-...L_ ~low for ~ommission use and correct to the best of my knowledge. Title District Operations Engineer Date 4-30-81 Conditions of Approval, if any: Approved by_.. ORI~ ii~L SIGI~[L1 BY LO~,E C. SlVllTtl Approved Zopy Returned -By-G~Jer of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas Company North Alask~.~?istrict Post Office j~ 36O Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer January 9, 1981 Reference: ARCO Cased Hole Finals D.S. 3-13 12/25/80 11/lO/8O Perf log Rut~, 1 5;'l.-' ! 3G'e6~L~'/- Collar log Run 1 5~ ~Pllase sign and ret.urn the attached copy as.receipt of datar Mary F. Kellis North Engineering ~ransmittal ~,n ,r~63 DISTRI BUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOB I L GETTY . "'? , E£EIVED JAN ! 4 1981 - -'-'-' SOHIO MARATHON Naska Oil & Gas Cons. Commissio~ Anchorage CHEVRON ARCO Oil and Gas Company is ~, Division ol AtlanticRichlieldCompany A,q~"q~,Oil and Gas Company North Alaska District Post Oflice 8ox 3,30 Anchorage, A~aska 99.510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer December 19,. 1980 Reference: ARCO Directional Surveys D.S. 17-6 D.S. i6-10 12/2/80 Multi-shot, 12/10/80 Gyroscopic 12/10/80 " " lease sign and return the attached:cOpy as receipt of data. Mary F. Kellis North"Engineering Transmittal #914 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA E~(XON MOB I L GETTY ,. "" SOHIO MARATHON ,.',... ,:,:,: :.. , CHEVRON · ARCO Od and Oas Company iS a Olvss~on of AllanlicR~chfieldComr,.'~,~v ..ARC(~ 'Oil and Gas North Slope ,,~trict Post Office BOx 360 Aqchora§e, Alaska 99510 Telephone 907 277 5637 December 16, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: D~17~5: DS 6-9 DS 17-6 DS 6-10 DS 16-10 DS 6-11 DS 2-17 DS 6-12 DS 11-14 DS 6-13 DS 15-21 DS 6-14 DS 15-10 DS 6-16 DS 14-10 Kuparuk DS 16-11 C-1 DS 2-9 B-1 DS 2-2 C-2 DS 6-15 E-5 Dear Sir: Enclosed please 'find: 1. A Completion Report, Drilling HistOry and a Gyroscopic multishot survey for wells DS 17-5, DS 17-6, DS 16-10, DS 2-17, DS 11-14 & C-1. (An updated Completion Report w/Gyro will be submitted for DS 2-17 & DS 11-14 and the gyro for DS 17-5, as soon as data becomes available.) 2. A Sundry Notice or subsequent report for wells DS 2-2, E-5, DS 6-9 thru DS 6-14 & DS 6-16. (An updated sub- sequent Sundry Notice will be filed for DS 6-9 thru DS 6-14, DS 6-16 and E-5 as soon as production test data becomes available. ) 3. A Monthly Report of drilling for wells DS 15-21, DS 15- 10, DS 14-10, DS 16-11, DS 2-9, DS 6-15, B-1 & C-2. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:sp Enclosures ARCO Oil and Gas Company is a Division ol AtlanticRichfielclCo:~;pany FQ~n --- SUBMIT IN DUFf_ E* STATE OF ALASKA (See other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* m b. TYPE OF COMPLETION: WELLI~I DRY ['--] Other NEW WORK DEEP- F--I PLUG I---I DIFF. WELL[] OVER r'~ EN I I BACKI I RESER. r"-] Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchoraqe, AK 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 2369' FNL, 425' FWL, At top prod. interval reported below 1667' FNL, 1547'FEL, At total depth Sec 22, TION, R15E, UM Sec 21, TION, R15E, UM 1453'FNL, 1960'FEL, Sec 21, TlO~, R15E, UM ]0/13/80 I 10/31/80 I 11/5/80 I ~i]i]i]"~'~'~]''" RKB~J 18 TOTAL DEPTH 'MD ~ TVD 119 PLUG BACK MD & TVDI20 IF MULTIPLE COMPL/' I / · ' I ' DEPTH I ' HOW MANY* '%,,...._..~¢qq~q~TARY TOOLS. 10210!MD. 9482'TVD[ lO163'MD 9447'TVDI single I all 22. PRODUCING INTERVAL(S), OF THIS COMPLETION - TOP, BOTTOM, NAME (MD & TVD)* Top 5. APt NUMERICAL CODE 50-029-20508 6. LEASE DESIGNATION AND SERIAL NO. ADL 2833t~/' 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME PrudAQ~ ~ay' uni t 9. ~'[NO. ". ' <~~"~iX--.21m -- 1 0-- 1 5 ) 10. FIELD AND POOL, OR WI'LI~CAT Prudhoe Bay Fiel d/Prudhoe O' 1. SEC., T., R., M., (BOTTOM HOLE Po( OBJECTIVE) Sec 21, TION, R15E, UM 12. PERMIT NO. 80-96 GR, ETC)* i17. ELEV. CASlNGHEAD INTERVALS DRILLED BY CABLE TOOLS 23. WAS D I R ECTIONA L I SURVEY MADE Sadlerochit 9441'MD 8871'TVD Base Sadlerochit lO,092'MD 9392'TVD I yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP/BHCS/GR, FDC/CNL/GR/CAL, 25. Gyro/CCL CASING RECO'~{D (Report all strings set in well) IGRADE I DEPTH SET (MD) HOLE SIZE H'40 I 110' 32" L-80 I 2603' .17~" S00-951 9209' 12~" L-80, I CASING SIZE WEIGHT, LB/FT. 2O" 94 13-3/8" 9-5/8" 72 47 . SIZE I 7" 8899 LINER RECORD TOP (MD) BOTTOM (MD) 28. PERFORATIONS OPEN TO PRODUCTION ISACKS.CEMENT* 10,205 500 (interval, size an~ number) n/a i I CEMENTING RECORD I AMOUNT PULLED 1300 sx Permafrost to suri~ace 12300 sx Fondu &'400 sx Pqrmafrost.II 1500 sx Cl a~s G / 'TUBING RECORD SCREEN (MD) DEPTH SET (MD) PACKER SET (MD) 8944' 8862' 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. AMOUNT AND KIND OF MATERIAL USED 27. SIZE DEPTH INTERVAL (MD) n/a PRODUCTION DATE FIRST PRODUCTION n/a DATE OF TEST. ~HOURS TESTED CHOKE SIZE ~ PROD'N FOR TEST PERIOD - ~ PREss.FLOW TUBING ICASlNG PRESSURE 24-HouRCALCULATEDRATE~ IOIL-BBL' 31. DISPOSITION OF GAS (Sold, used for fuel vented, etc.) IPRODUCTION METHOD (flowing, gas lift, pumping--size and type of pump) IWELL STATUS (Producing or I shut-In) OIL-BBL. GAS-MCF. WATER-BBb IGAS-Oi L RATIO I I IGI~(~'EJvEFATER-BBL', IOILGRAvlTY'API(CORR') DEC! 8 ]980 ITEsT W'TNEssED BY Alaska Oil& ~.a.s.C__ons. Commission 32. LIST OF ATTACHMENTS Drill inq History & Gyroscopic Survey 33. I hereby certify that the orego~ng andaattached in, f,~rmatlon is coynplete and correct as determme~:~¥r~ ./.~"/~'~ilable records. SIGNED . . _ ~ ~ TIT Engineer . *(See instructions and Spaces for Additional Data on Reverse Side) 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: 16: 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° . Items 2C, and 22: If'this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, tOp(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for'each additional interval to be separately produced, showing the additional data pertinent to such interval. _. Item 26: "Sacks Cement"' Attached supplemental records for this well should show the detail~ of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34, SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, ~ WATER AND MUD . 35. GEOLOGIC MARKERS ' , ,, NAME ,,, MEAS. ~)EPTH TRUE VERT. bEPT I. ' Top Sadlerochit 9,441' 8871 .'~ n/a Base Sadlerochit 10,092' 9392' ~' · - .i · , t'. : 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. · . · DRILLING HISTORY DS 17-5 Spud @ 0930 hrs 10/13/80. Drl 17½" hole to 2620'. RU & run 13-3/8" OD csg w/Baker FS & FC. Csg land @ 2603'. Cmt. 13-3/8" csg w/2300 sx Fondu cmt & 400 sx Permafrost II cmt. Displace w/27.5 bbls mud &.~.oo~retu:-- to surf. CIP 2300 hrs. Instl 13-3/8" csg hngr pkoff & csg spools. Press ~eals. Tst csg hngr pkoff to 2000 psi. NU & tst BOPE. PU BHA. RIH, tag cmt @ 2490'. Tst csg to 1500 psi. Tst form to 12.5 EMW. Drl & sur to PD. Drl 12¼" hole to 9235'. Cond hole & mud. RU & run 233 its 9-5/8" 47# S00-95 & L-80 BT&C csg to 9209' Circ csg w/full returns & cmt w/500 sx Class G cmt. CIP 0215 hrs 10/25~80. Instl pkoff & tst. Tag cmt @ 8950' & CO to 9010'. Tst csg to 3000 psi Drl FC & cmt to 9166' Tst csg to 3000 psi. Drl cmt, FS & new hole ~o 9245'. Tst form to 1~.5 ppg EMW. Drl 8~" hole to 10,210'. Run DIL/SP/BHCS/GR & logged 10,198' - g210'. Run FDC/CNL/GR/Cal & logged 10,202' - 2602'. *Instl 7" rams & tst. PU 33 its 7" 29# L-80 lnr & GIH. Cmt lnr w/500 sx Class G cmt. Recip lnr during cmtg. TOL @ 8899', shoe @ 10,205'. Drl 634' cmt to TOL. Drl landing collar @ 10,049' & 115' cmt to FC @ 10,163' PBTD. Tst csg 1 hr - ok. Displ csg & lnr to 9.7 ppg NaC1 brine. Tst csg & lnr to 3000 psi - ok. Run CBL. RU & run 5½" 17# 8-round AB modified completion assy w/shear sub @ 8944 , Baker SAB pkr @ 8862' & SSSV nipple @ 2127'. ND BOP's. NU & tst tree. Displace to diesel, drop ball & set pkr. Test tbg to 3500 psi & 5½" x 9-5/8" annulus to 200 p:i. Rig released @ 0600 hrs, 11/5/80. *Arctic Packed 9-5/8" x 13-3/8" annulus over permafrost zone as follows: Downsqueezed 300 bbls water, followed by 300 sx Permafrost type C cement, followed by 133 bbls ARCO Arctic Pak. Tested annulus to 1000 psi after 18 hrs. RECEIVED DEC ! 8 1580 · Alaska Oil & Gas Cons. Commission Anchorage 700 West 41st, Suite 101 Anchorage, Alaska 99502 Phone 272-2496 Telex: 25-364 World Leader in Service to the Oil Industry December lO, 1980 Job #4436 North Slope Drilling: Enclosed please find our Gyro Survey on Drillsite 17-5 along with our Vertical Section and Horizontal View maps. Also enclosed you will find the Gyro Film, Field Sheet and Calculations. If any other information is needed please call at 272-2496. Thank you for using Scientific Drilling International and please call again. Sincerely Manager CONPLETION REPORT ARCO OIL & GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY & ASSOC 10 DEC 80 WELL DS KB ELEV 70, FT, ~-- JOB NO 4436 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 0 0 0 0,00 100 0 20 99,99 200 0 15 199.99 300 0 15 299,99 400 0 30 399,99 500 0 30 499,99 600 0 20 599,98 700 O 20 699,98 800 0 20 799,98 900 0 20 899,98 1000 0 30 999.98 -70,00 N O.OOE 29,99 S45.41E 129,99 S42.73E 229,99 S38,38E 329,99 532,70E 429,99 S19,01E 529,98 S12.35E 629,98 S35,66E 729,98 S33,98E 829.98 S40,30E 929,98 S42,63E 1100 0 10 1099,97 1029,97 S46,95E 1200 0 20 1199.97 1129,97 S46.26E 1300 e 20 1299.97 1229.97 S31.88E 1400 0 20 1399,97 1329,97 S24,20E 1500 0 15 1499,97 1429,97 S 7.51E 1600 0 15 1599,97 1529.97 S15.33E 1700 0 15 1699,97 1629,97 S 5.16E 1800 1 0 1799,96 1729,96 S16,48E 1900 0 50 1899,95 1829,95 S72.80E 2000 0 50 1999,94 1929,94 N75,96E 2100 0 30 2099,93 2029,93 N38.75E 2200 0 30 2199,93 2129,93 N67,63E 2300 0 15 2299,92 2229.92 S47.48E 2400 0 30 2399,92 2329,92 N26.40E TOTAL COORDINATES 0,00 $ 0.00 W 0'08 N 0.21E 0.27 S 0.56 E 0,60 $ 0,84 E 1,1~ 'S 1,22 E 1,92 S~ "1.60 E 2-62 S 1,80 E 3.15 S 2'04 E 3,62 S 2,37 E 4,O9 S 2,72 E 4.63 S 3,20 E 5,05 S 3,61 E 5,35 S 3.93 E 5.80 S 4.29 E 6.31 S 4.57 E 6.80 S 4.70 E 7.22 S 4.79 E 7,65 S 4.87 E 8.72 S 5.07 E 9,82 S 6,15 E 9,86 S 7,59 E 9.24 S 8.55 E 8.72 S 9.24 E 8.83 S 9.85 E 8.73 S 10,41 E C L 0 S U R E $ DISTANCE ANGLE D M S 0.00 S 0 0 0 W 0.22 N 67 17 30 E 0.62 S 63 50 16 E 1.04 S 54 ZO 9 E 1.67 S 47 6 57 E 2.50 S 39 53 12 E 3.18 S 34 31 8 E 3.75 S 32 54 37 E 4,33 S 33 10 2 E 4.91 S 33 38 13 E 5.63 S 34 38 37 E 6,21 S 35 35 20 E .6.63 S 36 18 31 E 7.21 S 36 31 51 E 7.79 S 35 54 0 E 8.27 S 34 41 46 E 8.67 S 33 33 30 E 9.07 S 32 28 12 E 10,09 S 30 11 24 E 11.59 S 32 5 7 E 12.44 S 37 35 52 E 12.59 S 42 47 7 E 12,71 S 46 39 29 E 13,23 S 48 7 50 E 13.58 S 50 1 5 E DOG LEG SEVERITY DEG/IOOFT 0.000 0,333 0,083 0,019 0,250 0,119 0,167 0,135 0,010 0,037 0,167 0,333 0.167 0.083 0.045 0,083 0,034 0,044 0.750 0,167 0.449 0,333 0.249 0,250 0,250 SECTION DISTANCE 0.00 -0.16 -0.62 -1,0t -1,55 -2,19 -2,62 -3,03 -3,51 -5.18 -5.58 -6.09 -6.52 -6.83 -7.06 -7.29 -7.86 -9.26 -10.62 -11.29 -11.75 -12.36 -12.84 ARCO DS 17-5 GYROSCOPIC SURVEY JOB NO 4436 10 DEC 80 .o RECORD OF SURVEY TRUE MEAS. DRIFT VERTICAL- DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 2500 0 30 2600 0 40 2700 0 40 2800 0 40 2900 0 30 3O00 0 4O 3100 1 0 3200 1 0 33O0 1 0 3400 0 40 3500 1 0 3600 1 0 3700 0 50 38OO 0 30 3900 0 45 4000 0 40 4100 1 0 4200 1 19 4300 4400 2499.92 2429,92 S42.73E 2599.91 2529,91 S72.68E 2699.91 2629,91 S59.96E 2799.90 2729.90 S59.10E 2899.89 2829,89 S46.66E 2999.89 2929.89 S46.93E 3099.88 3029.88 S37.06E 3199.86 3129.86 S34.18E 3299,85 3229.85 S15.30E 3399.84 3329,84 S14,41E 3499.83 3429.83 S 7.555 3599.81 3529.81 S 7.685 3699.80 3629.80 S 3.86E 3799.79 3729.79 S 4.205 3899.78 3829.78 S 6.11W 3999.78 3929.78 S 2.555 4099.77 4029.77 S 1.715 4199.75 4129.75 S15.11W 1 40 4299.71 4229.71 S26.06W 1 19 4399,68 4329.68 SlO.91W 4500 4600 4700 4800 ~900 5OOO 5100 7 19 5098.38 5200 9 0 5197,36 5300 18 30 5294.39 1 19 4499~65 4429.65 S20.75W 1 45 4599.61 4529.61 S39.55W 2 0 4699,56 4629,56 S50.21W 2 49 4799,47 4729.47 S75,05W 3 39 4899,31 4829,31 S84.66W 5 19 4999,00 4929,00 N72.48W 5028.38 N67.70W 5127.36 N66.90W 5224.39 NSO.20W TOTAL COORDINATES 8.62 S 11.14 E 9.16 S 11.99 E 9.63 S 13.06 E 10.22 S 14.06 E 10.83 S 14.87 E 11,53 S 15.61 E 12.60 S 16.58 E 14,02 S 17.60 E 15.60 S 18.33 E 17.01 S 18,70 E 18.43 S 18-98 E 20.16 S 19.21 E 21,76 S 19-37 E 22,92 S 19.45 E 24.00 S 19.43 E 25.24 S 19.40 E 26.69 S 19.45 E 28.71 S 19.21 E 31.15 S 18.29 E 33.63 S 17,47 E 35.87 S 16.83 E 38.18 S 15.49 E 40.50 S 13.18 E 42.42 S 9.47 E 43.42 S 3.89 E 42.59 S 3,85 W 38.83 S 14.22 W 33.35 S 27.32 W 26.64 S 50.04 W CLOSURES DISTANCE. ANGLE D M 14.09 S 52 16 3 E 15.09 S 52 37 46 E 16.22 S 53 36 1 E 17.38 S 53 59 47 E 18.40 S 53 56 6 E 19,41 S 53 :33 43 E 20.83 S 52 45 41 E 22.51 S 51 27 9 E 24.07 S 49 35 38 E 25.28 S 47 42 56 E 26.46 S 45 49 59 E 27,85 S 43 36 43 E 29,13 S 41 40 55 E 30,06 S 40 19 39 E 30.89 S 38 59 40 E 31.83 S 37 32 33 E 33.03 S 36 4 51 E 34.55 S 33 47 43 E 36.13 S 30 25 27 E 37.90 S 27 26 55 Fi 39.62 S 25 8 39 E 41.20 S 22 4 53 E 42,59 S 18 2 1 E 43.46 S 12 35 2 E 43,59 S 5 7 40 E 42.76 S 5 10 8 W 41.36 S 20 6 39 W 43.12 S 39 19 24 W 56.69 S 61 57 48 W DOG LEG 5EVER I TY DEG/IOOFT 0.823 0.167 0,148 0.010 0.167 0.167 0.333 0.050 0.328 0.333 0,333 0.002 0.167 0.333 0.250 0,083 0,333 0.333 0.333 0.333 0.229 0.417 0.250 0,836 0.834 1.678 2,002 1.667 9,594 SECTION DISTANt'- -13.49 -14,48 -15.64 -16.79 -17.76 -18.71 -20.00 -21.46 -22,70 -23.55 -24.32 -25.16 -25.88 -26.37 -26 -27.72 -28.22 -28.24 -28.35 -28.56 -28.14 -26,81 -24.03 -19.19 -11.66 -0.63 13.56 37.17 ARCO DS 17-5 GYROSCOPIC SURVEY JOB NO 4436 10 DEC 80 RECORD OF SURVEY MEAS. DRIFT DEPTH ANGLE D M 5400 17 0 5500 20 0 5600 21 0 5700 21 30 5800 22 30 5900 23 3O 6000 25 0 6100 28 0 6200 31 0 6300 32 o 6400 32 0 6500 32 0 6600 32 0 6700 32 0 6800 32 0 6900 31 30 7000 31 0 7100 30 30 7200 30 30 7300 30 0 7400 30 0 7500 29 30 7600 28 0 7700 27 30 7800 27 0 7900 26 30 8000 20 0 8100 31 0 8200 32 30 TRUE VERTICAL. DEPTH 5389.62 5484.44 5578.11 5671,31 5764.03 5856.08 5947.25 6036.73 6123.76 6209.02 6293.83 6378-63 6463,44 6548,24 6633.05 6718.08 6803.57 6889.51 6975.68 7062.06 7148.66 7235.48 7323.15 7411.65 7500.55 7589.85 7678.34 7764,94 7849.97 SUB SEA 5319,62 5414,44 5508,11 5601,31 5694,03 5786,08 5877.25 5966,73 6053,76 6139.02 6223.83 6308.63 6393.44 6478.24 6563.05 6648.08 6733,57 6819.51 6905,68 6992,06 7078,66 7165.48 7253.15 7341.65 7430.55 7519.85 7608.34 7694,94 7779,97 DRIFT DIREC DEG, TOTAL COORDINATES N86,38W 23,09 S 80.30 W N74,g5w 17.95 S 111,56 W N72,18W 8,04 S 145,14 W N71,28W 3.31 N 179.56 W N67.80W 16.40 N 214,65 W N67,80W 31.16 N 250,83 W N67,46W 46,79 N 288.81 W N68,16W 63,64 N 330.12 W N68,OOW 82,01 N 375,80 W N68,46W 101,39 N 424',32 W N68,81W 120,69 N 473,68. W N68,75W 139,87 N' 523,08 W N69.lOW 158.92 -N 57'2"52`W N69,03W 177.85 N 622,02 W N65.18w 198.46 N 670.8'3 N66.78W 219.88 N 718. 9 W N67.53W 240.02 N 766.70 W N67.36W 278.75 N 860.93 W N67.68W 298.00 N 907.48 W N68.03w 316.85 N 953.80 w N69,03W 335.01 N 999,98 W N6T,33W 352,88 N 1044,63 W NTO,33W 369,69 N I088,04 W N70.30 385.12 X 1131.15 W NTO,51W 400,21 N 1173,56 W NTI,OlW 415.55 N 1217,52 W NTO,21W 432.14 N 1264.68 W N70.05w ,,50.02 N 1314.17 W CLOSURES DISTANCE ANGLE D M 83.56 S 73 57 30 W 112.99 S 80 51 27 W 145,37 S 86 49 85 W 179,59 N 88 56 35 W 215.28 N 85 37 47 W 252,76 N 82 55 1W 292.58 N 80 47 47 W 336.20 N 79 5 18 W 384,65 N 77 41 17 W 436.27 N 76 33 39 W 488.81 N 75 42 18 W 541.45 N 75 1 45 W 594.17 N 74 29 9 W 646.95 N 74 2 33 W 699.57 N 73 31 7 W 751.77 N 72 59 34 W 803.39 N 72 37 0 ~ 854.34 N 72 19 22 W 904.94 N 72 3 33 W 955,16 N 71 49 13 W 1005,05 N 71 37 24 W 1054,60 N 71 28 41 W 1102,62 N 71 20 4 W 1149,14 N 71 13 59 W 1194.92 N 71 11 52 W 1239,92 N 71 10 9 W 1286,48 N 71 9 17 W 1336,47 N 71 8 4 W 1389,09 N 71 5 48 W DOG LEG SEVERITY DEG/IOOFT 1,590 3.285 1,061 0,514 1.123 1,000 1,501 3,004 3.000 1,009 0.185 0.035 0,185 0.035 2.040 0.664 0.538 0.507 (3.254 0.506 0,175 0.556 1,546 0,812 0,500 0.502 2.503 2.011 1.501 SECTION DISTANC~ 66.70 97,72 132,63 168,83 ~06,28 245.35 286.41 331.01 380,24 432.49 485.48 538,47 591.46 644,45' 697, 749,~ 801.80 852.92 903.65 954,02 1004,00 1053,62 1101,71 1148.27 1194,05 1239.04 1285.58 1335,56 1388.17 ARCO DS 17-5 GYROSCOPIC SURVEY JOB NO 4436 1¸-0 DEC 80 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL' SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG, TOTAL COORDINATES 8300 37 30 7931,86 7861,86 NTl,O3W 469,12 N 1368,23 W 8400 36 0 8011,98 7941.98 N69,51W 489.31N 1424.55 W 8500 37 0 8092,37 8022,37 NTO,OOW 509.89 N 1480,36 W 8600 36 30 8172,49 8102,49 N68.61W 531.03 N 1536,33 'W 8700 35 0 8253,65 8183.65 N70,38W 551.49 N 1591.05 W 8800 34 30 8335,81 8265,81 N69.85W 570.88 N 1644.65 W 8900 34 0 8418,47 8348,47 N69,33W 590,50 N 1697.40 W 9000 33 30 8501,62 8431,62 N69,65W 609.97 N 1749.44 W 9100 33 0 8585.25 8515.25 N69.05W 629.30 N 1800.74 W 9200 32 0 8669,59 8599,59 N68,11W 648.92 N 1850,76 W 9300 33 30 8753,69 8683.69 N68,58W 668,88 N 1901.,04 W 9400 33 30 8837,08 8767,08 N63,13W 691,45 N 1951,39 W 9500 34 0 8920,22 8850,22 N63.05W 716.59 N 2000,93 W 9600 35 0 9002,63 8932,63 NGi,90W 742,76 N 2051.16 W 9700 36 0 9084,04 9014,04 NGO,36W 770,80 N 2102,01W 9800 37 30 9164,17 9094,17 N62,26W 799,51N 2154.50 W 9900 38 30 9242,97 9172,97 N63,18W 827,73 N 2209,22 W 10000 39 30 9320,68 9250.68 N63,28W 856,07 N 2265.40 W 10100 39 0 9398.12 9328.12 N62,75W 884.78 N 2321.79 W 10139 40 0 9421,27 9351,27 N63,55W 893.39 N 2338,81W THE FOLLOWING INFORMATION IS EXTRAPOLATED TO TD 10210 40 0 9482.55 9412,55 N63.55W 916.30 N 2384.85 W CLOSURES DISTANCE ANGLE D M 1446.42 N 71 4 29 W 1506.25 N 71 2 34 W 1565.71 N 70 59 39 W 1625.52 N 70 tiff 55 w 1683.92 N 70 52 56 W 1740,92 N 70 51 26 W 1797.18 N 70 49 3 W 1852.73 N 70 46 40 w 1907.54 N 70 44 13 W 1961,23 N 70 40 40 W 2015.28 N 70 36 55 W 2070.27 N 70 29 19 W 2125.38 N 70 17 A, 5 W 2181,50 N 70 5 36 W 2238,88 N 69 51 43 W 2298,06 N 69 38 25 W 2359,19 N 69 27 37 W 2421.76 N 69 17 56 W 2484.66 N 69 8 21 W 2503.64 N 69 5 37 w 2554.82 N 68 58 56 W DOG LEG SEVER I TY DEG/IOOFT 5,013 1.589 1,015 0,700 1,609 0,528 0,525 0.509 0.531 1,034 1.507 3.007 0.501 1,069 1,132 1.657 1,061 1,001 0,543 3,511 0,000 SECTION DISTANF- 1445,48 1505.30 1564.77 1624.60 1683.02 1740.01 1796.29 1851,84 1906.67 1960,40 2014.49 2069,58 2124.84 2181.]1 2238. 2297.' 'Z 2359.12 2421.73 2484.65 2503.63 2554.82 BOTTOM HOLE CLOSURE 2554,82 FEET AT N 68 58 56 W ARCO DS 17-5 CODE NAM E GYROSCOPIC SURVEY JOB NO 4436 INTERPOLATED TRuE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE MEASURED VERTICAL TOTAL COORDINATES C L 0 S U R E DEPTH DEPTH DISTANCE ANGLE D M $ DEC 80 SUB SEA T SAD 9441 8871.22 701.75 N 1971,61 W B SAD 10092 9391.90 882.92 N 2317.08 W PLUG BACK 10163 9446.55 903.02 N 2357.71 W TD 10210 9482.55 916.30 N 2384.85 W 2092.77 N 70 24 28 W 8801.22 2479.60 N 69 8 26 W 9321.90 2524.73 N 69 2 33 W 9376.55 2554.82 N 68 58 56 W 9412.55 ARCO DS 17-5 GYROSCOPIC SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET JOB NO 4436 OF SUB SEA DEPTH, 10 DEC 80 TRUE MEASURFD VERTICAL SUB MD-TVD DEPTH DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 170 170. 100 0 270 270. 200 0 370 370. 300 0 470 470. 400 0 570 570. 500 0 670 670, 600 0 770 770, 700 0 ~70 870. 800 0 970 970, 900 0 1070 1070, 1000 0 1170 1170. 1100 0 1270 1270. 1200 0 1370 1370. 1300 0 1470 1470. 1400 0 1570 1570. 1500 0 1670 1670. 1600 0 1770 1770. 1700 0 1870 1870. 1800 0 1970 1970. 1900 0 2070 2070. 2000 0 2170 2170. 2100 0 2270 2270. 2200 0 2770 2370. 2300 0 2470 2470. 2400 0 2570 2570. 2500 0 2670 2670. 2600 0 2770 2770. 2700 0 2870 2870. 2800 0 2970 2970, 2900 0 3070 3070. 3000 0 3170 3170. 3100 0 3270 3270. 3200 0 3370 3370. 3300 0 3470 3470. 3400 0 3570 3570, 3500 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O. 17 S 0.50 $ 0.94 S 1.68 S 2.44 S 3. O0 S 3.48 S 3,96 S 4.45 S 4.97 S 5.24 S 5.65 S 6.15 S 6.66 S 7.10 S 7.52 S 8.27 S 9.64 S 9.93 S 9.45 S 8.83 S 8.72 S 8.87 S 8,49 S 9.03 S 9.47 S 10.04 S 10,65 S 11.30 S 12.23 S 13.59 S 15.11 S 16.64 S 17.94 S 19,65 S 0,46 E 0.76 E 1.09 E 1.51 E 1.76 E 1.9'4 E 2.26 E 2.60 E 3,03 E 3.52 E 3.81 E 4.19 E 4.49 E 4.68 E 4,76 E 4.85 E 4.96 E 5,73 E 7.16 E 8.35 E 9.00 E 9.73 E 10.23 E 10.92 E 11.68 E 12.75 E 13.76 E 14.66 E 15.36 E 16.26 E 17.30 E 18.16 E 18.60 E 18.89 E 19.13 E ARCO DS MEASURED 17-5 GYROSCOPIC DEPTH AND OTHER DATA FOR EVERY SURVEY EVEN 100 FEET JOB NO 4436 OF SUB SEA DEPTH. 10 DEC 80 MEASURED .DEPTH TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 3670 3770 3870 3970 4070 4170 4270 4370 4470 4570 4670 4770 4871 4971 5071 5172 5274 5379 5485 5591 5699 5806 5915 6025 6138 6254 6372 6490 660~ 6726 6843 6961 7077 7193 7309 36~0. 3600 0 3770. 3700 0 3870. 3800 0 3970. 3900 0 4070, 4000 0 4170, 4100 0 4270. 4200 0 4370, 4300 0 4470, 4400 0 4570, 4500 0 4670. 4600 0 4770. 4700 0 4870. 4800 0 4970, 4900 0 5070. 5000 1 5170. 5100 2 5270. 5200 4 5370. 5300 9 5470. 5400 14 5570. 5500 21 5670. 5600 28 5770. 5700 36 5870. 5800 45 5970. 5900 55 6070. 6000 67 6170. 6100 84 6270. 6200 102 6370. 6300 120 6470. 6400 138 6570- 6500 156 6670. 6600 173 6770. 6700 191 6870. 6800 207 6970. 6900 223 7070. 7000 239 0 0 0 0 0 0 0 0 0 0 0 0 0 0 . 1 1 2 5 5 7 7 8 9 10 12 17 18 18 18 18 17 18 16 16 16 21.31S 22.63 S 23.63 S 24.88 S 26.20 S 28.04 S 30.37 S 32.92 S 35.19 S 37.47 S 39.83 S 41.94 S 43,20 S 43,19 S 40.06 S 34.90 S 28.19 S 23.43 S 13.90 S 8,70 S 3.28 N 17.30 N 33.51N 50.96 N 70.44 N 92.51 N 115.66 N 138.52 N 160.39 N 182.84 N 207.99 N 232.59 N 255.43 N 277,86 N 299.76 N 19.32 E 19.42 E 19.46 E 19.39 E 19,42 E 19.34 E 18.64 E 17.64 E 17.09 E 16.03 E 13.96 E 10.80 E 5,72 E 1.32 ~ 10.87 W 23.33 W 42.52 W 74.10 W 106,47 W 141.98 W 179,02 W 216.77 W 256,36 W 298,68 W 3'46,97 W 401.79 W 459.65 W 517.80 W 576,35 W 634.66 W 691.45 W 747.85 W 803.00 w 857.45 W 911.63 w ARCO DS MEASURED 17-5 DEPTH AND OTHER DATA GYROSCOPIC FOR EVERY SURVEY EVEN 100 JOB NO 4435 FEET OF SUB SEA DEPTH. 10 DEC 80 MEASURED DEPTH TRUE VERTICAL SUB DEPTH SEA MD-TVD DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 7a25 7539 7653 7766 7 P.,7 ,q 7090 8106 8224 8348 8472 8507 8720 8962 9082 9200 9319 9439 9560 9683 9807 9934 10064 lOlq3 7170. 7100 255 7270. 7200 269 7370. 7300 283 7470. 7400 296 7570. 7500 308 7670. 7600 320 7770. 7700 335 7870. 7800 353 7970. 7900 378 8070. 8000 402 8170. 8100 427 8270. 8200 450 8370. 8300 471 8470. 8400 492 8570. 8500 512 8670. 8600 530 8770. 8700 549 8870, 8800 569 8970. 8900 590 9070, 9000 612 9170. 9100 637 9270. 9200 664 9370. 9300 694 9470. 9400 723 16 14 14 13 12 12 15 18 25 24 25 23 21 21 20 18 19 20 21 22 25 27 30 29 321.43 N 341.95 N 362.24 N 380.01N 397.12 N 414.17 N 433.18 N 454.48 N 478.75 N 504,36 N 530.64 N 555.42 N 579.18 N 602.89 N 626.06 N 648.92 N 672.89 N 701.24 N 732.26 N 766.29 N 801.51N 837.37 N 874.62 N 911.78 N 965.20 W 1017.69 W 1067.56 W 1116.38 w 1154.12 w 1212.89 W 1267.54 W 1326,50 W 1395,46 W 1464,50 W 1534.50 w 1601.78 W 1666.28 W 1729,65 W 1791,36 W 1850.76 W 1910.73 W 1970.62 W 2030.89 W 2092,88 w 2158.26 W 2228.15 W 2301,32 W 2374.89 W ARCO DS 17-5 GYROSCOPIC SURVEY JOB 10 DEC 8O INTERPOLATED VALUES FOR EVEN TRUE MEASURED VERTICAL DEPTH DEPTH 1000 999, 2000 1999- 3000 2999- 4000 3999, 5000 4999. 6000 5947, 7000 6803, 8000 7678, 9000 8501. 10000 9320. 1000 FEET OF MEASURED DEPTH, SUB SEA TOTAL COORDINATES 929, 4.64 S 3.20 E 1929. 9.85 S 7.59 E 2929. 11.54 S 15.60 E 3929, 25,24 S 19,39 E 4929 · 42 · 61 S ]3 · 82 W 5877, 47,21 N 288.63 W 6733. 240.57 N 766.46 W 7608. 415.75 N 1217.44 W 8431. 610.41 N 1749.27 W 9250. 856,30 N 2265,29 W HORIZONTAL VIEW ARCO OIL 8~ GAS - DRILL SITE 17-5 RADIUS OF CURVATURE GYROSCOPIC SCALE; I" = I000' ........... DEC. 16~ 1980 TVD = 9483~ TMD = 10~210~ T I0 N~ R 15 E~ U.M. 16 21 15 ALL DEPTHS SHOWN ARE TVD SURFACE LOCATION IS 2569' SNL, 425' EWL~ SEC. 22 T I0 N, R 15 E~ U.M. 400 800- 12oo- 16oo- 2000- 2400. 2800 - 3200' 3600 68~ ' 72:00 ALL DEPTHS SHOWN ARE TVD TVD: 9483' TMD = 10,210' VERTICAL SECTION ARCO OIL I~ GAS DRILL SITE 17-5 RADIUS OF CURVATURE GYROSCOPIC SCALE= I": I000' DEC. 16, 1980 Eastman / A PETROLANE COMPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY o. Arco Oil & Gas COMPANY D.S. 17, Well No: 5 WELL NAME Prudhoe Bay~. North $1ope: Alask~ LOCATI ON JOB NUMBER A1080D0052 SURVEY BY Jerry Cook TYPE OF SURVEY Directional Single Shot DATE :L~./5/SO RECEIYEI) NOV 2 5 ]980 Eastm. an Whipstock A PETROLANE COMPANY P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 TWX 910-881-5066/Cable: EASTCO November 5, 1980 Arco Oil & Gas P.O. Box 1479 Anchorage, Alaska 99510 Well Number: D.S. 17, Well No: 5 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Directional Single Shot Date: November 5, 1980 Method of Computation: Radius of Curvature Surveyor: Jerry Cook Job Number A108ODO052 ATTN: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Directional Single Shot Survey run on the above mentioned well. We wish .to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, .,/~im Turnage District Operations Manager Alaska District cc: file eno. JT/cfw Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO OIL. AND GAS .......................................................................................................................................................................................................................................................................................................... · [iS 17, WEL. L. NO** 5 DSS JOB NO: A1080D0s'.,~ oL. UF E., F'I"'(LJDHOEi BAY, NORTH ~ ~"' ALASKA DSS, 0-'.10210 MD, DRII...L. ER~ J 'COOK · V E I-,.'~ ].CAi... DIRECTION, N .~,8 .......................... RECORD ~'OF' ' SURVEY A~,~GLE AVERAGING METI--IOI) ~RCO [)IL. AND GAS · :iS 17, WEL. L NO~' 5 DSS :'RLJDHOE BAY, NORTFi SLOF'E~ AI..ASKA ~ COMF'UTATION F'AGE NO, ~ I ~ ..... ~.., ..... ~ J- .. ~.~-) · JOE: NU, AiO~:Ot:O0,~,¢ TIME .......... DATE ~. i 18 05-NOV-80 ....... TRUE ................................................................................................................................................................................................................................................... l, SLJBSEA R E C T A N G U L. A R ~ OOGLEG tEASURED [RIFT DRIFT COURSE VERTICAL VERTICAL C L 0 ~ U R E ... i'"" ' SE DEF'TFI ANGI...E: DIREPTION LENGTH [E:.FIH CTION I'VD C 0 0 F< D I N A T E S DIS'FANCE DIREC'T'ION SEVERITY FEET D M D H FEET FEET- ...... FEET - -F'EET --- F'EE:T FEET D M -.DG/iOOFT . 500, 1000, 1500, 2715, 0 0 0 0 O, 0,00 0,00 -70,00 0,00 0,00 0,00 0 0 0,00 0 45 S 55 0 E 500, 499,99 ......... 3,26 ....... 429,99 ..... 1,88-S .-2,68.E ................ S.,.27 ........ S.--..55 0 E.- 0,15 1 0 S 40 0 E 500. 999.93 -10.75 929,93 7,04 S 8,31E 10.89 S 49 45 E 0.07 0 45 S :1.0 0 E 500, 1499,87 -17,08 1429,87 15,96 S 11.54 E 18,11 S 39 35 E 0.10 0 ,15 S 65 0 E 1~:1.5,~ ,.'~714,77 -31,.88 .....2644,//~-' ......... ~o-,..~'-'~ ~;'7.--~- ............ 2t.-.,~_'~?-..E ............... 34-,01 ....S-.38.---36.-E 0 , 3021, 1 0 S 60 0 IE 3518. 1 15 S 65 0 E: 3998, 1 30 S 65 0 E 4489, 1 45 S S0 0 W 306. 3020,73 -36,54 ~,¢0,73 28.73 S 25,36 E 38,32 S 41 "~' ~.6 E 0.09 497 3517,-64 ....... 46,.28 3447,.64 33-,--24.-S ........... ~4,.02-...E .................... 4?,56 ........ S..-45....40E. ~" ~c~ 55 480, 3997.50 -57,74 3927.50 38.10 S 44,46 E ~., S 49 24 E 0.05 491, 4a88,:10 4'~ ' . _ -co,17 4418.30 51.38 S 48.64 E 70,76 S 43 26 E 0.49 ;PERRY SUN S'f'EERING TOOL SURVEY STATIONS 7 t ,-.8~ ............ S.-...34... 4-~: E 0., 37 -27.~;":' 'R '*¢' ~ -4,66 ~:oo~ - ~..80 ~9.07 S 4800, '2 15 S 60 0 W 4903, 3 ~0 S 87 0 W 5087, 6 0 N 65 0 W 5242, 9 0 N 60 0 W 155, 5239,02 5363, 13 0 N 73 0 W 121, 5357,80 5516, 19 0 N 73 0 W -153, 5504,'88 3o,.-6 ...... .~4.34 88 26,74 S 70,43 S 30 45 E 1,76 61'~'35 ......... S'--20 5---E ........... t,82 3.11E 48.-'~o ~ ~" 41E 1.98 1'8.06 W 43.04 S 24 48 W 3.87 58,39--W ........... 64~-22 S-"-65-24 W 3.92 635, 20 0 N 65 0 W 5635 MD L. AST STEERING TOOL SURVEY STATION 5735, 22 0 N 64 0 W 100,- 5710',41 1"1-i'"~'05 ..... 56'40,'41 5823, 22 15 N 63 0 W 88, 5791.93 144,09 5721.93 6015, 25 0 N 63 0 W 192, 5967,84 220,84 5897,84 6109, ~.°7 0 N 62 0 W 94, 6052~32 119. 5617,05 75.~8 5547.05 12,50 S 95,47 W 96.29 S 82 32 W 2v92'N 127~82'""W ............ i27,85 ......N'88'41 .....W ....... 2'~03 17.71 N 157,48 W 158,47 N 83 35 W 0,51 52.64 N 226,04 W 232,09 N 76 53 W 1.43 261-,97 ~q~o 3~ ...... 71,'~7-'N ~,~9 W ~7~,19 -N 74 44-.W 18 ~--~-~. ~ · 0'0..~] ........... ~ " 2, 6204, 29 15 N 61 0 W -'6523, 31 45 N 61 0 W 7033. ~1 0 N 62 0 W '7500. 29 0 N 63 0 W - 7840, 27 15 N 62 0 W 95. 6136,10 306,71 6066.10 319, 6410i'96 ........ 468,52 ........ 6340+96 510, 6846,39 733,79 6776.39 467, 7250,83 966,85 7180,8~ 340. 7550,68 .... 1126,82 ..... 74'80,68 93,0'~ N 301,94 W 315,95 N 72 52 W 2,42 17'1,'53-N "443-~55"~W~ .......... 4'75,'56 ....... N'"68"51 W 0~78 298,23 N 676,90 W 739,68 N 66 13 W 0.18 406.05 N 884.01 W 972.81 N 65 20 W 0.44 480,06"N ..... 1026,"i8-W ...... i1'32'f'92 ....N'64 56 W 0.53 ~RCO OIL ANB GAS; ~ COMF'UTATION . PAGE NO, ' 2 )S 17, WELL NO; 5 BSS UOB'~NO~ .... AIO80DO052 TIME BATE ~ ....... ~'RUDHOE BAY, NORTH SLOPE, ALASKA 11~'~') ......... TRUE ' "~ · IEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N 0 U L A R C L 0 S U R E DOGLEG I..[~.~Nt.E DIRECTION SEVERITY DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R B I N A T E S 0 R' "~' ~ FEEl' D M D M FEET ~F'EET .... FEEl FEEl ................... FEET FEET D M DG/IOOF .... ~ , -' . , , , 38 W 1264,93 N 64 34 W 1,01 8116, ~0 0 N 61 0 W 276 x792,94 1258 92 7722 94 543 15 N 1142, 8432, 35 0 N 58 0 W 3160 8059,4o 14~70 7989~'46 629'~32 N 1288~'67"'W ....... I4~4TI3 ........ N"'6S""58'W .... i~66' 8744, Z~5 0 N 57 0 W :?~..35, 3'2 0 N ~35~, .,"~":~... 0 N 54 0 W 7683, 34 0 N 50 0 W 'I0210, 38 0 N 50 0 W 312, 8315o03 1607,59 8245+03 725,47 N 1439,60 W 1612+07 N 63 15 W 0,18 491, 8724,47 1878,23 8654~47 ' 877,02 N 1664~27 W 1881~21 N 62 13 W 0,65 124, 8829~'05 t944'~65 .... 8759~05 ..... 9i5~'Yi':"~ .... I?I8~'5I~W ....... I947~26 ..... N'~61 ....57'~'W 324, 9099,23 2122~15 9029~23 1025,80 N 1859,43 W 2123,62 N 61 7 W 0~75 · -~. · · ~,~, ~ ~'~,~' ~ t~ .- ~ ............. ~.~ .~ .... ~,~ ~ ........ ~ .~ ......... ..~ ....... ~. ~ 0210 MD IS TD ..~_-.~ . i ~ ~_~ &~AM-;~-~ i ~-;-L~Li-.~. ~ - ,~---m --~.-~ .... f-r---t-- ~ ~-~-~-T- -'-~ .... f--T ..... ~-t-~.r .... ~-.---, i'-r"T~-n--~-~-~-~-~'~ ....... -~-'*--~ --~--',-~-"---~ .... ?~--~-t.~ ' : '": : : . . , : : : : ~ ' ! i ~ , , : , .', , ~ , ' ' ~ ' ?~ ...... f --. ' ~ , ' · ' ~ ~'~, '-~.~' ........... ~ ' ' m~h --~ -4. '~7- -~ ~~' - . ~" -t .... ~-Z -t4~ .... r-r ....... ~ ........ ~4- ~- I ..... ~+ ..... ~-~ ........... ~ .... ~'- ~', ~~' ....... , ~~' ~-* ..... '?m- -~'t--~-~. m~'-t' ~'-~-'!- -~'I-~-'i F-T-~.; '-X-~e-~p ~' '-'?"t~ ....... ~'"'r"tl ..... f-"r-l'--~ .... .... +-'t--?t--~'-'-t--t-~T ...... +--~-m'-r ......... i'-i-'m" --F-fi-t--re-] -ff-l~ ...... ~?'-~ ............ ~-'-~-+-t .... ~.~--e-! ...... ~ .... ;-fi-iH- ..... t'-ff-'_ --~ - .~-~. ~-~- ~-~-,--~-~--,-- . , t ...... ~ ~ ~, t-t-~t' ~ ~ ~ . , ~ '- , ~tH ~ ...... . ~ ~ ..... ~ ~1 . ,~ ~-~ ....... ~ , I~ ...... ~[ ~ ~* ..... ~+ .~, -r~ ......: '~-~-~'--~-~.~_~.. .... _~_~r-r'--'r-'.~4._~]?- ~ ..... i..;-.;~_z~_~"~ ' 2 I i-~ ~ ~ ~..~u ' -:-~ -~-~-~ --L-i ~- _~_~_~ . '.._~_~_~. : ~, ~ ~ ~ ~ ',, r'r-', P ~ ,~ ~ i~ .. ' ~- ' - ..... ~- ~ ~ ' ~-~ ---~f-- '~~' .... ~ .... -~ r~~ --~? -~; ..... ...... ~-~ ~- -~~ ~ .... ~ __;-' ~-~ ~ . . _ff-~ __ ~- --, __;_~,. ~ --~ -~-~ .... ~ .... ~-~. ~ ........ ~ .... !--~- ~-~-~.--~.-~-~--~---~-~-.~.-+-~ .... ~--~--~-~--?-~-~-~ ..... ~-~ ............... ~+ ...... ~--i .... ~--~ ..... ~ .... ~_...__..~ ....... ~ ..... ?~ ......... ~__~._~__~_~_:~-.~ ~ t~ ..... ~--~-~ ...... ~-F,--~-~ .... ~.-.~-~ ........ ,-~ ..... --~ ..... ~ ...... ~ ....... ~ ..... ~ .... ~--~-- ........... ~ .... :-i-~--,.~: , . . : . .... ;4.4-4: ~ , , 4.~X.-~.-~.-;_~_~_~:. , , :, , ; , : , ... ~--~ --?~-~-j--?~-~. -;-~-. ~ .~ , -~-~- 4~-4-; .... ~-.~ ~-- ] ':: .... :.x_;._:_. ~~ ~'' ..]._] :_.~ ...~~ -L-~ ..... _.,..]_.:_ ~..~ : !'. ~ i i~ !ri: ~T- ;' . ' ',, i ~. : ~' ~ ~ : : ~ '. Check Form for timely compliance with our regulations. Operator, Wel 1 Name and Number Reports and Materials to be received by:~ /~-~-~ Date Completion Report Well History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run DigitiZed Log Data Required Yes Yes Date Received Remarks CALIPER SURVEY LOCATED IN THE APPENDIX AI~CO Oil and Gas Company North Alar ~pistrict Post offic~ ?~x 360 Anchoracje,' Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer December ll, 1980 Reference' ARCO Cased Hole Finals D.S. 14-9 11/3/80 D.S. 14-9 11/4/80 · 4-Arm Caliper Run 1 CBL Run 1 CBL Run 1 D.S. 7-5 9/28/80 CNL D.S. 7-4 8/25/80 Spinner D.S. 7-12 10/26/80 Spinner Run 2 ,...-,~e cign and return th~ - ,~ ......... ~ ..... pt of data. ii 5" 5" 5" 5II II . Mary F. Kellis North Engineering Transmittal #891 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oi~ and (;as Company is a Division o! AtlanticRichfieldCompany ARCO Oil and Gas '~mpany North Slop~ ~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 26, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 17-4 Permit #80-85 DS 5-2 Permit #74-36 DS 2-4 Permit #70-17 DS 17-5 Permit #80-96 DS 15-10 Permit #80-88 DS 15-21 Permit #80-91 DS 14-9 Permit #80-89 Kuparuk E-7 Permit #80-80 D-6 Permit #79-96 D-7 Permit #79-112 D-5 Permit #79-95 E-4 Permit #80-57 E-8 Permit #80-81 D-3 Permit #79-84 Dear Sir: Enclosed please find: 1. A completion report, drilling history and a gyroscopic multishot survey for wells; DS 17-4, E-7, D-6, D-7 & E-8. 2. A Sundry Notice of subsequent report for wells; DS 5-2, DS 2-4, D-3, D-5 & E-4. (An updated Completion Report will be filed,, for D-3, D-5 & E-4 as soon as produc- tion test data becomes available.) 3. A monthly report of drilling for wells; DS 17-5, DS 15-10, DS 15-21, DS 14-9;~ E-8 & D-7. Very truly yours~ , P. A. YanDusen Distr~ct Drillin§ [n~'ineer P^¥:sp Inclosures g£CEiV£D Alaska 0;I & ?: Cons Commission z~nchorag~ ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form No. 10-404 " REV. 3-1-70 SUBMIT IN DUPLICATE STATE 'OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20508 6. LEASE DESIGNATION AND SERIAL NO. ADL 28334 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9.WELL NO. P.O. Box 360 Anchorage, AK 99510 DS 17-5 (XX-21-10-15) 4. LOCATION OF WELL 2369'FNL, 425'FWL, Sec 22, TiON, R15E, UM 10. FIELD AI~D POOI~OR WI~.J~CA~ vruanoe pay tie/d/ 11. SErC'. ~. ~.'1~. ~O1~61~ HDLWE~'/ ' OBJECTIVE) Sec 21, TiON, R15E, UM 12. PERMIT NO. 80-96 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Spud @ 0930 hrs 10/13/80. Drl 17-1/2" hole to 2620'. RU & run 13-3/8" OD csg w/Baker FS & FC. Csg land @ 2603' Cmt 13-3/8" csg w/2300 sx Fondu cmt & 400 sx Permafrost II cmt. Displace w/27.5 bbls ~lud & circ 500+ sx cmt. CIP 2300 hrs. Instl 13-3/8" csg hngr pkoff & csg spools. Press tst seals. T-st csg hngr pkoff to 2000 psi. NU & tst BOPE. PU BHA. RIH, tag cmt @ 2490'. Tst csg to 1500 psi. Tst form to 12.5 EMW. Drl & sur to PD. Drl 12-1/4" hole to 9235. Cond hole & mud. RU & run 233 its 9-5/8" 47# S00-95 & L-80 BT&C csg to 9209' Circ csg w/full returns & cmt w/500 sx Class G cmt. CIP 0215 hrs 10/25/80. Instl p~off & tst. Tag cmt @ 8950' & CO to 9010' Tst csg to 3000 psi. Drl FC & cmt to 9166' Tst csg to 3000 psi. Drl cmt, FS & new hole to 9245' Tst form to 12.5 ppg EMW. Dr'l 8-1/2" hole to 10,210' Run DIL/SP/BHCS/GR & logge'd 10,198'- 9210'. Run FDC/CNL/GR/Cal & logged 10,202'-26(~2'. Instl 7" rams & tst. PU 33 its 7" 29# L-80 lnr & GIH 10/31/80. RECEIVED DEC- 1 1980 Alaska 0il & Gas Cons. Commission Anchorage 14. s:Gh~eDy_~~is~~ ~-- --~--.,..,_ LE District Drlg Engineer DAT"- 11/25,80 NOTE--Fleport on this form is required for each calendar month, regardless of the status of operatiom, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. ARCO Oil and Gas--'~mpany North Alasi~ )listrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 20, 1980 Reference: ARCO Directional Surveys D.S. 17-5 11/5/80 Single Shot ease sign and return the attached copy as receipt of data. Mary Kellis North Engineering Transmittal #829 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON RECEIVED NOV 2 5 1980 Alaska Oil & ha Cons. Commission ARCO Oil and Gas Company is a Division of AtlanticRichtieldCompany ARCO Oil and Gas ~C~ompany North Ala~ %~istric/ Post Office dox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 5, 1980 · Reference: ARCO Open Hole Finals ., D.S. 16-10 ./~10/27/80 D.S. 16-10 ~ 10/27/80 D.S. 16-10 ~!,/J 10/27/80 D.S. 16-10 10/27/80 FDC FDC/CNL DIL/SFL BHCS D.S. 16-10 10/27/80 Cyberlook · : 10/29/80 FDC D.S. 17-5 10/29/80 FDC/CNL Runl & 2 Run 1. & 2 Run 1, 2, & 3 Run 1 & 3 Runl Run 1 Run 3. Run 1 Run 1 Run 1 D.S. 17-5 10/29/80 BHCS D.S. 17-5 10/29/80 DIL/SFI, D.S. 17-5 10/29/80 Cyberlook m.s. 17-5 10/29/80 S~ dewall Run 1 . sign and return the attached, copy as re~ceipt of dtaa. Mary Kellis North Engineering DISTRIBUTION Transmittal #779 NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON Tf 2" & 5" 2" & 5" 5" 2,, & 5" 2" & 5" 5" . FtI. F: ARCO Oil and Gas Company is a Division of AllanlicRichhetdCompany ARCO Oil and Gas Cqmpany North Alas ~_'istrict Post Office ,~Ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November l0, 1980 Reference: ARCO Magnetic Tapes 10/29/80 D.S. 9-16 J ' 10/3/80 D.S. 16-10 Y10/27/80 Tape #61122 Run 1 Tape #61061 Run 2 Tape #61.120 Run 1 /Please sign and return the attached copy as receipt of data. Ma~y F Kellis . .. ,. North F~gineering Transmittal #786 NORTH GEoLoGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA '.DISTRIBUTION EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany · aska Oil & Gc~,~ C"n ~ A ',,, ' ~' Commission ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton Chairman/Commissioner Thru: Lonnie C. Smith ~-~ Commissioner Doug Amos ~ Petroleum Inspector October 24, 1980 Witness BOPE test on Arco's D.S. 17-5, Sec. 21, T10N, R15E, UM. Permit # 80-96 on Rowan Rig #35. ~.e.d.~esday. October 15,~1980: I departed Parker Rig 176 at 7:00 am and traveled to Rowan Rig 35. The BOPE test commenced at 1:30 pm and was concluded at 5:00 pm. I filled out an AOGCC BOPE Test Report which is attached. ~ In summary I witnessed a successful BOPE test on ArCo D.S. 17-5 well on Rowan Rig 35. I filled out an AOGCC BOPE TeSt Report which is attached. DA:mm O&G #4 "4/80 ~ ~ STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Date Well Operator ~F~C.O Representative ~ ~ ~ ~y~ Well T'~..G', lq- ~ Permit # ~-. ~ Location: Sec ~[ T[0~ R Iq~ M ~.~. [~/0Casing Set 0 ~~ ft. Drilling Contractor ~~ Rig ~ %~ Representative ~c~ ~:~O*~ Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves ~Check Valve Test Pres sure 500o 6000 Test Results: Failures t ~oo0 6o00 ACCUMULATOR SYSTEM Full Charge Pressure -_%000 psig Pressure After Closure !~0 psig 200 psig Above Precharge Attained: . Full Charge Pressure Attained: N2 ~O;~O0) ] ~ Controls: Master .~ Remote min 25~ sec min l ~ sec Blinds switch cover Kelly and Floor Safety Valves Upper Kelly' Lower Kelly Ball Type, I Inside BOP Choke Manifold No. Valves Test Pressure Test Pressure Test Pressur.e Test Pressure I Test Pressure %¥ No. flanges Adjustable Chokes Hydrauically operated choke _ Test Time,,, Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: days and Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector ARCO'Oil and Gas"~'-~mpany Post Te,ephone '.)0',; 27'7 :;~ '.' September 24, 1980 Mr. Hoyle Hamilton State of Al aska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: As-Built Survey Plats Dear Sir: . -'"'~ '~N~j _1 ~_' I..4 ENG '" t GEOL 3 OEOL" s'r^T T~C_ STAT TEC c,n~:~,~T ..... 'os/? In an effort to insure that your files are complete, we have attached copies of our well location as-built survey plats for all wells permitted thus far in 1980, excluding those included in our original drilling permit applications. Very truly yours, P. A. V~nDusen District Drilling Engineer PAV/JBK/jh Att achments 16~15 _ I I HEREBY CERTIFY THAT I AH '. PROPERLY REGISTERED AND LICENSED TO ~RACTICE LAND SURVEYING 1N THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS- D.S. 17 - CONDUCTORS 1 THRU 6 BUILT SURVEY HADE BY HE, AND THAT ALL D l HENS IONS AND OTHER AS-BUILT LOCATIONS DETAILS ARE CORRECT, AS OF: DATE STATE PLANE LAT & LONG ]. Y = 592779~.39~ ~. Y = ~928]~.]92 X = 708786.75~ X = 708702.5~6 ~~X~- - LAT = 70°12'21 846" tAT = 70°12'25.308'' ~~ OF~~ ' ~-,~.- ...... ..~.~ h '" LONG = 148o18'59.678'' LONG = 148°19'01.841'' ~,- ~ ,,~Jl ..... LAT = 70°12'22.995'l LAT = 70°12'26.464'' LONG = 148o19'00.'394" LONG = 148°19'02.574'' ~. y = s~2~02~.~ ~.'Y = s~28~.8~s~~/~~:~"7~~--~ LAT = 70°12'24.151'' LAT = 70o12' 27.6111~ LONG = 148°19'01.113'' LONG = 148°19'03.331'' Ill I Ill Ill I Ill l Illl I lll i I I J ]Il II II II ~ I II Atlantic~ichfieldCompany ~ DATE: DRAWING No: NORTH AMERICAN PRODUCING DIVISION ~.J~.~O ALASKA DISTRICT- PRUDHOE BAY I Ill II Il I I II I II I Illl I Illl Illl I Ill I September 12 1980 Mr. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 AnChorage, Alaska 99510 Prudhoe Bay Unit DS 17-5 Atlantic aichfield Company Permit No. 80-96 ~ur. Loc.= 2369'S, 425'E of NW cr Sec 22,'T10N, R15E, Botto~hoIe Loc..~ 1320~S, 1320~W of NE cr Se~ 21, T10N, R15E, Dear Mr. VanDusen: Enclosed is the approved application for permit to drill the above referenced well. Well samples, core chips and a mud log are not required. A directional survey is required. If available, a tape contain- ing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter 'surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS ' 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to cOmmencing operations you may be contacted by the Habitat Coordinator~s office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and. the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanD~sen Prudhoe Bay Unit DS 17-5 -2- September 12, 1980 commencing operations you may be contacted by a representative of the Department of ~vironmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit' to dril !. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the ~mission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandoD~ent, please give this office adequate advance notification so that .we may have a witness present. yours, Hoyle H- Hamilton Chairman of BY ORD,2 OF TH~ COMMiSSiON Alaska Oil & Gas Conservation Commission Enclosure cc: Department of Fish & Game, Habitat Section. w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor~ Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and Gas )tpany Alaska Region Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 9, 1980 Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 17-5 Permit to Drill Dear Sir: Enclosed please find the Application for Permit to Drill DS 17-5 and the required $100.00 filing fee. Attached to the application are: a drawing of the proposed well path, a plat showing the subject well's path in relation to DS 17-4, and a drawing and description of the BOP equipment including anticipated pre~ures. The requirement of using a surface hole diverter system on t~is well has been waived. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/MBW/jh Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-401 REV. 9-1-78 STATE OF ALASKA SUBMIT IN TRII 'A~'~ (Other instructio.. !gverse,. side).. ALASKA OIL AND GAS CONSERVATION COMMI ...~,.~.~,.(~.,. 9 ~9~ PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL [] b. TYPE OF WELL OIL GAS OTHER DEEPEN SINGLE MULTIPLE 2. NAME OF OPERATOR ..... Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF I/CELL At surface 2369'S & 425'E of NW cr Sec. 22, TION, R15E, UM At proposed prod. zone 1320'S & 1320'W of NE cr Sec. 21, TION, R15E, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 5 miles NE of Deadhorse, Alaska API #50-029-20508 5. 6. LEASE DESIGNATION AND SERIAL NO. ,,~,:~,,,~DL 28334 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 17-5 (xx-21-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil ii. SEC., T., R., M., (BOTTOM P 0 0 l HOLE OBJECTIVE) Sec. 21, TION, R15E, UM 12. 14. BOND INFORMATION: ~E Statewidesuretyand/orNo. Federal Insurance Co. #8011-38-40 Amount 100,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 1 3 2 0" (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2640 21. ELEVATIONS (Show whether DF, RT, CR, etc.) Pad Level - 30' RKB- 70' 23. 16. No. OF ACRES IN LEASE 2512' 19, PROPOSED DEPTH 10206 'MD PROPOSED CASING AND CEMENTING PROGRAM 17. NO,ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START September 1980 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 32" 20" 94 lb. H-40 80' 250 sx Permafrost II to surf. 17-1/2" 13:3/8" 72 lb. L-80 2700" Circ to sufr /'approx 25 sx)Fon plus 300sx Perm.afrost II 12-1/4'" 9-5/8" 47 lb. S-95 10206" (Approx. 1500sx) Class "G" Cemen Atlantic Richfield Company' proposes to di'rectionally drill this well to 10206'MD, 9548'TVD to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be used. I't will be pressure tested each week and operationall3 tested each trip. A stri'ng of 5-1/2'" 17# L-80 tubing, packer, and necessary provisions for subsurface safety equilpment will be run, The packer will be set above the Sadlerochit. A non-freezing li'quid will be left in all uncemented annuli within the permafrost interval. Selected intervals within the Sadlerochit interval will be perforated, and reported on subsequent report. 5000 psi WP wi'reli'ne lubricator, tested to working pressure, will be utilized wi'th all wireline work. Well will be flowed to production facilities during per- forating and testing. The downhole safety vel'Ye will be installed and tested upon conclusion of j o b. m ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is ,o deepen give data on present productive zone and proposed · new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. S,G D T'- -'V. - 8, 178o (This space for State offie~ use) CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND C-I)P.}~ CIIIPS REQUIRED [] ,ms ~'~.No DIRECTIONAL SURVEY REQUIRED ~ [] NO MUD LOG OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE PERMIT NO. ~ ~ - ?~ APPROVAL DATE APPROVED BY IITLE ~y O~D'-~F THE CO~MISSI~INe Instruction On Reverse Side Sept_~?~r 12,~.._ n don :' 09/12/80 DATE · .~ ' ~ ' - · ' .... { ' ' i, '~ ' ...............! OS ].'~.,,.: ~{ELL NO,' .~ ".~ROPO~EO' ! ~ ' ' ~,~..~D'~ .... ' .......... '~' Y'~'- - ' ' '~' ' ~ ......... 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L-A..--; ..... ~--!'-f-'t' -t~-t"ff--'?l'-'.~,.;*''+- --'T-,.'I--?'I '; ; ~ '--'~'-~-T'-~i'~ "-T- . , I . : ........ : .................... -~-~ ........ ~.-? .... I-? . ~---~-~?--. . ~. . ; · · ,., . . ....... 13-5/~_~,.B. OP STACK DIAGRAN PREVENTOR . , Accumulator Ca.p..acit. y' Test Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. BLIND RAMS . Observe time,then close all units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. e Record on IADC repOrt. (The acceptable lower limit is 45 seconds closing time and 1100 psi remain i ng pressure.) PIPE RRMS 13-5/8" BOP STACK TEST le Fill BOP stack and manifold with Arctic Diesel or Calcium Chloride Solution. SPOOL e Check that all hold down screws are fully retracted. Predetermine depth plug ~will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws i n head. PIPE RRMS 3~ . Close annular preventer and chokes and bYpass valves on manifold. Test all components to 250 psi and hold for 10 minutes. ~20_~.?Maximum anticipated bottom hole pressure. ,~/O?~<-Maximum preesure to which BOP's could be subjected. Calculated by allowing a gas bubble at reservoir pressure to rise without expanding but cooling to 80°F. 5~ . Increase pressure to 3000 p°si and hold for 10 minutes. Bleed pressure to 500 psi. Close top set of pipe rams and open annular r '~ p evente.~,; Increase, pressure to 5000 psi and hold for 10 minutes. Bleed pressure to 500 psi. Close bottom set of pipe rams and valves directly upstream of chokes, then open top set of pipe rams and chokes. Increase pressure to 5000 psi and hold for 10 minutes. 9~ Test' remaining untested manifold valves(if any) with 5000 psi uPstream of 'valve and zero pressure' downstream. 10. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for 10 min. 11. Bleed pressure off all equipment open bottom preventer. Make sure manifold & lines are full of Arctic Diesel and all valves are set in drilling position. 12. Te~t standpipe valves to 5000 psi. 13. Test Kelly cOcks .and inside BOP to 5000 psi with Koomey pump. 14.' Check operation of De Gasser. 15. Record test information on Blowout preventer test form. Sign and send to Drilling Supervisor. 16. Perform complete BOPE test once a.week and functional operate BOPE daily. 16~15 -2'F '- , IrJ, .. .. %\ I ! HEREBY CERTIFY THAT I AH PROPERLY REGISTERED AND LICENSED TO ~RACTICE LAND SURVEYING IN THE STATE OF ALAS~ AND THAT THIS PLAT REPRESENTS AN AS- D.S. 17 - CONDUCTORS ] THRU 6 BUILT SURVEY HADE BY HE, AND THAT ALL D I HENS IONS AND OTHER AS-BUILT LOCATIONS DETAILS ARE CORRECT, AS OF: STATE PLANE 'LAT 6 LONG 1. Y = 592779~.~9~ ~. Y = 59281~.192 x ~ 7o8786 75~ x = 7087o2 5~G ~z~-E~'~'~_ . . _~. ~- ~ ~ _"~ LAT = 70°]2~2],8h5'' LAT = 70°]2'2~.308'' LONG = 148o18'59.678'' LONG = 148°19'01.841'' ' C',) . 2 Y 5927910.bb5 5. Y 5928260 936 -- LAT = 70°12'22'.995'' LAT = 70°12'26.464'' LONG = 148019'00 394" LON~ = 148°19'02 574" ' ' ' ':~'~ :., 3 Y = 5928027 297 6 Y = 5928376 895 '~ ':'~ '"--~-":7~s:. "~'' ~ ~ ~- _ . . ~, _- x = 7o8730 871 x =. 7o8645 462 LAT = 70o12'24,151" LAT = 70°12~ 27,611~ ' LONG = 148°19'01,113'' LONG = 148°19'03.331'' I I i I AllanliaRi~htieldOompany ~ DATE: . DRAWING No: NORTH AMERICAN PRODUCING DIVISION ALASKA DISTRICT- PRUDHOE BAY L I II I ! i (1) Fee CHECK LIST FOR NEW WELL PERMITS Api0rove Date (2) Loc. Yes No 1. Is the permit fee attached .................................... 2. Is well to be located in a ~f'~ed ~ol..i ...... / 3. Is a registered survey plat attached ............................... 4. Is well located proper distance frcm property line ................. 5 Is well located proper distance frcm other wells .......... 6. Is sufficient undedicated acreage available in this pool. 7 Is well to ke deviated .................................. . (3) ktmin .~ ~ ~ -/'~;~o 8. Is operator the only affected party ................................. 9. Can permit be approved before ten-day wait .......................... 10. Does operator have a bond in force .................................. 11. Is a conservation order needed ...................................... (4) ~sg.~-~ 12. Is administrative approval needed ................................... 13. Is conductor string provided ....................................... .~ 14. Is enough cement used to circulate on conductor and surface ....... ~ ~~ 15. Will c~nent tie in surface and intermediate or production strings ...~ 16. Will cement cover all known productive horizons ..................... ~ 17. Will surface casing protect fresh water zones ....................... ~ 18. Will all casing give adequate safety in collapse, tension and burst. , ., 19. Does BOPE have sufficient pressure rating - Test to ~'0o o psig . ._Approval Rec cn~nended: Remarks t ? -j'"' Additional Requirements: Geology: Engineering: rev: 03/05/80 Well History 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. Caliper Specialists Since 1953 KINLEY CORPORATION 5815 Royalton, Houston, Texas 77081-2993 U.S.A. Phone (71 3) 664-4501 Telefax (71 3) 664-1037 SERVICE AVAILABLE WORLDWIOE WITH ALL KINLEY WIRELINE TOOLS Calipers · Tubing Perforators · Sand Line Cutters · Power JBrs · Measuring Line Cutters IOW TO READ T' ]E SURVEY ABBREVIATIONS' CU. = Lower Ul~set Corr. = Corrosion U.U. = Ul~e~ Ul=Set l~e=. - Oeoosits u.B.. - ul=p~ Body ScatcL = Scattered mB. =.middle Body' Shall. = Shallow LB. = lower 8ody NUMBERS AND LE'rTERS ON THE SURVEY All JOINTS in the tubing string are numbered, from the top down, starting with the first full Toint below the Christmas tree. PUP JOINTS are given decimal numbers. Example: 1.1 represents' the first pup joint below joint ~, SPECIAL TOOLS AND NIPPLES are identified by letters. Example: "El" is me sec=nd special'tool, or nipple~ ' down from the top. Gas Lift Mandrels am numbered from the top, as shown: GLM (1), GLM (2), GLM (3). etc. TABULATION SYM BO LS WHY iS THE CIRCLE OUR BASIC SYMBOL? The Kinley Caliper records the. action of ali its fifteen feelers simultaneously, instead of recording just the action of the one feelerthat is the f~rthest off-center. The Kinley Caliper Survey has fifteen Ii.nos, instead of just one line. These fifteen lines' o of information give us a circular view of the inside surface of the tubing. A complete circle on the tabulation sheets indicates that all fifteen feelers (or at. least fourteen), found tubing wall reductions at the same level in the well SYM BO LS showing N UMBER OF FEELERS indicating tubing wall reductions atthe same level 31=5 ~ 6to9 ~ 101= 13 ~ 14or15 ., (MP) MEASUREMENT and PERCENTAGE SURVEY symbols (also (MPM) MEASURE-.. MENT and PERCENTAGE MODIFIED symbols) · A PIT-A number alone represents the penetration, expressed in hundredths of.an inch, of the deepest pit. (In this example, the deepest penetration, probably due to corrosion, measures.O8".) A RI NG-A groove around the pipe, probably including corrosion, found by all (or at. least 14) of the 15 feelers. The number inside the circle represents the maximum penetration of the dng, ex- pressed in hundredths of an inch.(In this example, a complete pit rin~ reaches a maximum pone-.. tration of .10%) A PARTIAL RING-A groove, prc~bably including corrosion, found ~y at least 3 feelers, but no more than 13. (In this example, 10 feelers found penetration, reaching a maximum penetration of.O7"'.) r'~ MINOR DAMAGE--Indications of "minor" sufficiently severe corrosion not meas~remem. ["-'~ NO COMMENT--No indication of =ny damage is recorded in that Joint. Arco (Alaska), Inc. Pru~hoe Bay, AK #17-05 May 18, 1994 Survey No. 23883 T-30 Chart No. X1465 This is the first survey of this well to be made with the Kinley 30- Feeler Microscopic Caliper. The condition of the internal surface of the ~ 1/2". 17ff Buttress tubing in the well, from 0' to 8,750'(WLM), is covered in this report. The deepest penetration recorded in the survey is in an area of corrosion located in Joint #211. This penetration measures .12" or 39% of the tubing wall thickness. A cross-sectional drawing and a picture enlargement of the recordings for Jr. #211, at the location of the penetration, are included in the report. The condition of the tubing surveyed and analyzed ranges from good to fair with respect to corrosive damage. Indications of damage are recorded in the entire tubing in the forms of areas of corrosion and scattered pits. As illustrated in the Body Corrosion Profile, the damage is distributed throughout the tubing. Indications of damage are also recorded in the pup joints and flow couplings above and below the tool assemblies and GiMPs in the forms of areas and lines of corrosion. Picture enlargements of the recordings for some of the tool assemblies are included in the report. Many of the joints surveyed and analyzed appear to have an irregular or rough tubing I.D. As a result, the nominal I.D. in a number of the joints is unknown and the penetration values given may be slightly different from the actual wall loss. CALIPER TECHNICIAN Steve Adcock SURVEY ANALYST' Mina Tahtouh mt Distribution: ARCO (ALASKA), INC., ATTENTION: Records Processor, Room #AT0-1529, P. O. Box 10-3240, Anchorage, AK 99510-3240 (7R) ARCO (ALASKA), INC., ATTENTION: Mr. Jason Weaver, Room #AT0-1788, P. O. Box 10-3240, Anchorage, AK 99510-3240 (1R) Chart received: Report mailed: 05-25-94 06-09-94 NLEY CALIPER TALl. SHEET (Composite) #17-05 Survey # 23883 May 18, 1994 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Penetrations Over 85% (Possible Hole) # oils Penetrations 41 - 85% (Poor) Penetr~ions 21-40% (Fai0 JT.#'s 53.2 156.1 182.1 182.2 197.1' 198.1 208.2 45 47 70 86 93 130 131 136 149 151 153 158 162 164 168 170 171 176 177 179 182 18'3 184 187 188 189 190 .191 192 195 196 197 198 199 202 205 206 207 209 210 211 216 217 ., Penetrations 11 - 20% (Good) 207.1 208.1 108 127 154 157 172 175 185 186 193 194 203 204 212 213 66 154 Penetrations 1 - 10% (Very Good) 9 No Penetrations Recorded TOTAL JOINTS SURVEYED: 240 ( Includes 23 Pup Joints ) #17-05 PRUDHOE BA~ AK May 1~ I994 SURVEY # 23883 5 I/2~ 17# BUTTRESS CORROSIVE DAMAGE FREOL/ENCY DISTRIBUTIONS MAXTMUM PENETRA TiQN NUMBER OF JOINTS % WALL LOSS CONFIGURATION NUMBER OF JOINTS DESCRIPTION BODY PENETRAT/ONS 50 % WALL LOSS 20 40 6080 5 ~2 18 24 30 PiTDEPTH (l/ld~,2 inch] Z~TMY PIT DHPTH N.4?vK CH~4RT MEAN STATISTICAL DISTRIBUTION OF DEEPEST BODY PENETRATION PER JOINT # 17-05 PRUDHOE BA Y, AK May 18, 1994 Survey~ 23883 5 1/2" 17# BUTTRESS 304" Walt Thickness 0,3~ 0~2~ 0~26 O. 24 0.22 0.20 0,18 0,16 0,12 0,10 0,08 0.06 O. 04 Probability of a Hole 20 50 I00 O. I I !0 100 AVERAGE RANK MAXIMUM PROBABLE PENETR~A T/ON 38, 5 % F'I?4L E Y #17-05 Survey #23883 5 1/2" I7# BUTTRESS O.D = 5.500tn, LD, = 4,892 tn I4 0,05 15 O. 02 13 O, 04 t2 0.0I 11 O. 04 10 O, 04 9 8 0.06 0.04 7 & 04 6 0,04 5 O. 04 4 0.02 3 O, 02 2 0,02 16 U02 1 0.05 I7 0.06 18 0,12 19 O, 06 2O & O5 21 O. 05 22 23 24 O, 0,4 O, 04 25 0,00 26 O. 04 29 O. 04 28 0 03 27 0.02 4~38 Sq~/rL !~ Description: JL #211 CORROSION , 12'=39% Percent Area Reduction = 11 84 % Total Area Remaining = KINLEY( LIPER JOINT TABU[ TION SHEET 5 1/2" 17# BUTTRESS #17-05 Body: 0.304 PRUDHOE BAY, AK Upset: 0.304 Survey # 23883 Chart # X1465 May 18, 1994 Feeler Ratio I · I Run # 1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY DAMAGE JOINT PENEmATION PENETRATION n PROFILE NO % INCHES % INCHES COMMENTS - (% WALL) 0.] PapJL '. 1 10 0.03 Shallow corr.; 1st full length Jt. below Tree 2 10 0.03 Shallow corr. 3 10 0.03 Shallow corr. 4 13 0.04 Shallow corr. 5 13 0.04 :Shallow corr. 6 20 0.06 Shallow corr. 7 13 0.04 Shallow corr. 8 13 0.04 Shallow corr. 9 13 0.04 Shallow corr. 10 13 0.04 Shallow corr. 11 13 0,04 Shallow corr. . . 12 10 0.03 Shallow corr. 13 10 0.03 Shallow corr. 14 10 0.03 Shallow corr. 15 10 0.03 ShallOw corr. 16 10 0.03 Shallow corr. 17 10 0.03 $catd. shallow pits 18 7 0.02 Shallow con'. 19 10 0~03 Shallow corr. 20 13 0.04 Shallow corr. . 21 10 0.03 Shallow corr. . .... 22 10 0,03 Shallow corr. 23 10 0.03 Shallow corr. 24 13 0.04 Shallow corr. 25 10 0.03 Shallow corr. 26 10 0.~03 Shallow corr. 27 20 0.06 Shallow corr. . . 28 16 0.05 Line of shallow corr. 29 16 0.05 Shallow corr. .. 30 20 0.06 Shallow corr. 31 16 0'05 Shallow corr. .32 20 0.06 Shallow corr. 33 20 0'06 Shallow corr. 34 16 0.05 Shallow corr. 35 .. . 13 0.04 Shallow corr. 36 13 0.04 Shallow corr. 37 13 0.04 Shallow corr. 38 13 0.04 Shallow corr. 39 16 0.05 Shallow corr. 40 20 0.06 Shallow corr. 41 16 0.05 Shallow corr. 42 16 0.05 Shallow corr. 43 16 0.05 Shallow corr. 44 13 0.04 Shallow corr. 45 23 0.07 C°rr. 46 20 0.06 Shallow corr. . 47 23 0.07 Corr. 48 16 0.05 Shallow corr. 49 16 0.05 Shallow corr. 50 20 0.06 Shallow corr. BODY ~ - UPSET KINLEY ( iLIPER JOINT TABU( TION SHEET 5 1/2" 17# BUTTRESS #17-05 Body: 0.304 PRUDHOE BAY, AK Upset: 0.304 Survey # 23883 Chart # X1465 May 18, 1994 Feeler Ratio I · I Run # 1 MAX]MUM MAXIMUM UPSET/MAKEUP BODY DAMAGE JOINT PENETF~TION PENETRATION n PROFILE ~nn NO % INCHES % INCHES COMMENTS '{ (~ WAU.) 'T' 51 16 0.05 S~ow corr. 52 16 0.~ Shallow corr. 53 16 0.05 S~low corr. 53.1 10 0.03 Scatd. shallow pits; Upper Pup Jt.; Safety Valve Assembly (A) - 53.2 23 0.07 Line of corr.; Lower Pup Jt. 54 16 0.05 Shallow corr. 55 20 0.06 Shallow corr. ,, 56 .... 20 0.06 Shallow corr. " 57 20 0.06 Shallow corr. 58 20 0.06 Shallow corr. 59 20 0.06 Shallow corr. 60 20 0.06 Shallow corr. 61 20 0.06 Shallow corr. 62 20 0.06 Shallow corr. 63 20 0.06 Shallow corr. , .... 64 16 0.05 Scatd. shallow pits 65 20 0.06 Shallow corr. ', 66 16 0.05 scatd, shallow pits 67 20 0.06 Shallow corr. 68 20 0.06 Shallow corr ..... 69 ,,, 20 0.06 Shallow corr. 70 23 0.07 COrr. 71 16 0.05 Shallow corr. ,, 72 20 0.06 Shallow corr. 72.1 13 0.04 Shallow corr.; Upper Pup Jt. & Flow Coupling; GLM (1) 72.2 10 0.03 Scatd. shallow pits; Lower Pup Jt. 73 16 0.05 Shallow corr. 74 13 0.04 Shallow corr. , 75 13 0.04 Shallow corr. 76 13 0.04 Shallow corr. 77 13 0.04 Shallow corn 78 13 0.04 Shallow corr. 79 13 0.04 Shallow corr. 80 16 0.05 Shallow corr. 81 16 0.05 Shallow corr. 82 16 0.05 Shallow corr. 83 16 0.05 Shallow corr. 84 20 0.06 ShallOw corr. 85 16 0.05 Shallow corr. 86 23 0.07 Corr. 87 20 0.06 Shallow corr. 88 20 0.06 Shallow corr. 89 13 0.04 Shallow con'. 90 13 0.04 Shallow corr. 91 ,, 20 0.06 Shallow corr. 92 16 0.05 Shallow corr. 93 23 0.07 Corr. 94 ','"', 20 0.06 Shallow corr. 95 20 0.06 Shallow con'. 96 ,., 20 0.06 Shallow con'. 97 16 0.05 Shallow corr .... 98 16 0.05 Shallow corr. 99 16 0.05 Shallow corr. 100 16 0.05 Shallow corr. BODY I - UPSET § 1/2" 17~ BU~RESS ~17-05 ~: 0.3~ PRUDHOE BAY, AK Up.t: 0.304 Su~ey ~ 238~ Cha~ ~ X14~ May 18, 1994 Feeler Rat~ I · I Run ~ 1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY DAMAGE JOINT PENETRATION PENETRATION P~LE NO % INCHES % INCHES COMMENTS ~,,,., (%WALL) 1,.(I0 101 16 0.05 Shallow coif. 102 16 0.05 Shallow corr. 103 16 0.05 Shallow coif. 104 ..... 20 0.06 Shallow coif. 105 16 0.05 Shallow coif. 106 ,,16 0.05 i Scatd. shallow pits 107 16 0.05 i Shallow coif. 108 ..... 26 0.08 Corr. 109 16 0.05 Shallow corr. 110 20 0.06 Shallow corr. 111 16 0.05 Shallow corr. 112 ...... 20 0.06 Scatd. pits ,,,,'" 113 16 0.05 Shallow corr. 114 16 0.05 Shall°w corr. 115 20 0.06 Shallow corr. 116 16 0~05 Shall°w coif. 117 16 0.05 Shallow corr. 118 16 0.05 Shallow coif. 119 16 0.05 Shallow coif. 120 16 0.05 Shallow coif. 120.1 20 0.06 Scatd. shallow pits; Upper Pup Jt. & Flow Coupling; GLM (2) 120.2 13 0.04 Scatd. shallow pits; Lower Pup Jr. 121 I 16 0.05 Shallow corr. 122 20 0.06 Shallow corr. 123 20 0.06 Shallow corr. 124 16 0.05 Shallow corr. 125 13 0.04 Shallow coif. 126 20 0.06 Shallow coif. 127 23 0.07 Corr. 128 20 0.06 Shallow corr. 129 20 0.06 Shallow coif. 130 23 0.07 ~ Corr. 131 23 0.07 C°rrj ,, !32 , 20 0.06 Shallow coif. 133 16 0.05 Shallow coif. 134 20 0.06 Shallow coif. 135 20 0.06 Shallow com. 136 ,, 23 0.07 Corr. 137 16 0.05 Shallow corr. 138 20 0.06 Shallow com. 139 20 0.06 Shallow coif. ,,, 140 20 0.06 Shallow corr. 141 20 0.'06 Shallow coif. 142 20 0.06 Shallow corr. 143 ..... 20 0.06 Shallow coif. 144 20 0.06 Shallow corr. 145 20 0.06 Shallow con'. , 146 20 0.06 Shallow coif. 147 20 0.06 Shallow corr. 148 16 0.05 Shallow com. 149 23 0.07 Coif. 150 20 0'06 Shallow corr. BODY ~ - UPSET (' x 5 ~/W ~ 7# BU~I'RE$$ #~ Body: 0.304 PRUDHOE BAY, AK Upset: 0.304 Sun/ey # 23883 Chart # X1465 May 18, 1994 Feeler Ratio 1 · 1 Run # 1 MAXIMUM MAXIMUM BODY PENETRATION PENETRATION J(~gT UPSET/MAKEUP DAMAGE % INCHES % INCHES COMMENTS 0 PROFILE / 151 23 0.07 Corr. 152 16 0.05 Shallow corr. 153 23 0.07 Corr. ]54 23 0.07 Corr. 155 20 0.06 Shallow corr. 156 20 0.06 Shallow corr. . ...... 156.1 23 0.07 Corr.; Upper Pup Jr. & Flow Coupling & GLM (3) 156.2 13 0.04 Shallow corr.; Lower Pup Jt. 157 23 0.07 Corr. 158 23 0.07 Corr. 159 20 0.06 Shallow corr. 160 20 0.06 Shallow corr. 161 20 0.06 Shallow corr. 162 26 0.08 Corr. .. 163 20 0.06 Shallow corr. 164 23 0.07 Corr. 165 20 0.06 Shallow corr.'..' 166 20 0.06 Shallow corr. 167 20 0.06 Shallow corr. 168 26 0.08 Corr. 169 20 0.06 Shallow corr. 170 23 0.07 Corr. 171 23 0,07 Corr. . . 172 23 0.07 i Corr. 173 20 0.06 Shallow corr. .. . '. 174 16 0.05 Shallow corr. 175 23 0.07 Corr, .... 176 23 0.07 Corr. 177 23 0.07 ,Corr. 178 20 0.06 Shallow corr. 179 30 0.09 Corr~ 180 20 0.06 Shallow corr. 181 20 0.06 Shallow corr. 182 23 0.07 Corr. . 182.1 23 0.07 Corr.; Upper Pup Jr. & Flow Coupling & GLM (4) 182.2 23 0.07 Corr.; Lower Pup .lt. 183 26 0.08 Corr. 184 26 0.08 Corr. 185 23 ..... 0.07 Corr. 186 26 0.08 Corr. 187 26 0.08 Corr. 188 23 0.07 Corr. 189 23 0~07 Corr. 190 30 0.09 icom 191 :33 0.10 C°rr. 192 30 0.09 Corr. . 193 23 0.07 Corr. 194 26 0.08 Corr. 195 33 0.10 Corr. 196 23 0.07 Corr. 197 33 0.10 Corr. 197.1 23 0.07 Corr.; Upper Pup .it. & Flow Coupling; GLM (5) 197.2 20 0.06 Shallow corr.; Lower Pup .lt. 198 23 0.07 Corr. 198.1 23 0.07 Corr.; Upper Pup .it. & Flow Coupling; GLM (6) 198.2 20 0.06 Shallow corr.; Lower Pup Jt. 199 23 0.07 Corr. 200 20 0.06 Shallow corr. ~j~- BODY ~B - UPSET KINLEY ( SLIPER JOINT 5 1/2" 17# BU~RESS Sody: 0.304 Upset: 0.304 Chart# X1465 Feeler Ratio 1 · 1 TABUS' TION SHEET . #1 7-05 PRUDHOE BAY, AK Suwey # 238~ May 18, 1 994 Run # 1 ~MUM ~MUM IUPSET/MAKEUP BODY DAMAGE JOINT ~NE~ ~NE~ON PROFILE NO % I~HES % INC~8 COMMENTS ~ ~ WA~) 20! 20 0.06 S~Iow con'. 202 26 0.08 Con'. I 203 26 0.08 Con'. 204 23 0.07 Con.. 205 30 0.09 Con.. 206 26 0.08 Con.. 207 23 0.07 ~ Con.. 207.1 23 0.07 Con'.; Upper Pup Jt. & Flow Coupling; GLM (7) 207.2 20 0.06 Shallow con'.; Lower Pup Jt. 208 20 0.06 Shallow con'. 208.1 23 0.07 Corr.; Upper PUp Jt. & Flow Coupling; GLM (8) 208.2 23 0.07 Corr.; Lower Pup Jt. 209 . 23 0.07 Corr. 210 23 0.07 COn'. 211 39 0.12 Con'. 212 26 0.08 Con'. 213 30 0.09 Con'. 214 20 0.06 Shallow con'. 215 20 0.06 Shallow con'. 215.1 10 0.03 Shallow con'.; Upper PUp Jt. & Flow Coupling; GLM (9) 215~2 13 0.04 Shallow con'.; Lower PUp JL 216 23 0.07 Corr. 216.1 20 0.06 Shallow con.'; Uo~er Puo Jt. & Flow Coupling; GLM (10) 216.2 20 0.06 Shallow con'.; Lower Pup Jt. 217 26 0.08 Con'.; Survey ends in Jt. #217 @ 8,750' WLM ~ - ~DY I - UPSET -..- ............................. _- .... ...._* ..............;. .............. _*_' _. · .. , .. _.~' .... ~_.,-_.. ................ :..j_ ..................... _Z_' ....................... :.._L_ .......................... ~ ...... -', ........... : ..................... .:= ....... --'.~.-'-.: ............. ~.--:'-:- ........ :-1- ...... =.--: ........................... ............................. 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Z.....~.Z .... . · eo · . · d& ,. . o ~'_ ~m ~ .: : : LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Oil & Gas Co. Well DS I?-S Field Prudhoe Bay County,State North Slope, Alaska Date 6-18-81 Curve Name (Abbreviated) St.andard Curve Name Logs Used Scale GR Gamma Ray CN 07100 LSN Long Space Neutron CN 0-2000 SS Short Space CN 0-2000 NEU Compensated Neutron CN ~ . 60-0 , , , · ,, , °AGE I AR£O ALASKA,, IW£. .... D.S. m"-(l~:),~lOF BAY .... *jORTd SLOPE, ALASKd DATA E\I~RY 1 S,6, qmLES 1.7-5 20 67 8 ~,~5 8 &810.O0 18,35 805.01 27.96 $89.11 ~S,!'!.. O0 18.50 800.12 2°3.21 668.30 88!P.00 8S~,3 O0 ~81~ .00 18 ~81g O0 16 ~8!7.00 17.52 751,22 25.2q ~78.09 881~.00 !~.95 756.11 2~.%% 701.35 ~820.00 lq,.83 75%.89 25.06 690.35 8822.00 15.93 723.10 2~.16 652.~9 U¢~.O0 17.89 ~99.B8 26.k2 6~2.59 .~/tGE ? ~RC,q ,ALASKA, INC.----D.S. ~':-~.t~H~- R~Y .... NORTH SLOP.-_-, .~,~TA Ev£RY 1. SA~L£S 17-5 o,.~,'z.z 50 IM.7~ ~70 5q. ~ q'6 555,~,9 SS~ 50 8BZ7.50 8~S9.50 ~8~0.50 1~.!1 770 78 58 06 5~5.~8 12.75 $1 O0 5~ 59 571.60 12 1¸3 88~. 50 lq. ~q- 795 2,"5 55 5 609 55 :~q 50 1 5 ~g.50 1.2.~7 7~P, 8 ~2 37 58 ~9 ~S~-~ 50 13 q, 8 o8~ ~3 P9 03 58 ,3 ARCO ALASKA, TW£.----D.S. :i':~!ID.HOF.. BqY .... ~IORTH SLOP-_-, ALAS<fi EVERY 1 S A'q~LES !7-5 8B57.00 9.~ 8~.58 $?.1t G02.20 885~.00 ~O.R9 780.5~ ~.~G 5~1.~0 8859.00 15.20 GqG.Oq ~B.55 55B.1~ 8860.00 17.03 B09.~l ~6.79 ~861.,00 16.79 59~.7~ ~$,90 566,71 986~.00 17 8865 O0 5867 O0 19 SB6C}.O0 19.~%5 609,ql 27,7~ 566.71 88'70.00 2~.06 608.19 ~B.22 558.1q ~S71.00 23.90 BOO.BG 79.25 5BI.OO 887~..00 25.~+9 617.97 27,0o~ 578.95 887 O0 ~? t+3 61.7 97 ~7 569 p,r,~,~ ,~ ARCO AL~.~KA, ~W£.----O.S. 17-5 ~RU3HOE BAY .... NORTH SLOPE, AL~.SKA D~T~ EVERY 1 SA~i~LES ......... S.. BT ,S... 50 ...... 25_._Y=9. ......... £02_..0.8 ............. _~9...Z_6_ ...... 5_'-1:_~ ._~_.5_ .............. ,_$.:~ZZ., O.:O ............ 2. 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S..B_.~O._,._O_..O .............. ~_?.,_,.~_~. ........ 5,?_5.,__~.? ............ .?.__e_,,.7...? ....... 5_~_.Z,_!.2 ..................................................................................................................................................................... ....................... %S...i:'~, 0_,.,5._0 .................... ag.._d.~_7 ............... a.O...~_,_.:5....O. ....................... .P.,.,.?.,,_~_7 .......... 5..~_7_.,_1.2~ ........................................................................................................................................................ ................................ ~..8..~ :L.,_.O 0 ................. ~..8....,...0_..6 ................ 6.0_...5.,..7_..5 ..................... t.1_._6_.0_ ................ 5;~..1_-'_2~ ................................ .~..S,.~ 50 2.8 0 ~- 52~ 2 616 75 P9 .39 5~~ 57 BBa?. 50 2 69 649 7g 21.52 g2~ 08 27 .aSSO .50 8!. ~ 50 21 31. 01 550 BO BSeq.,50 2~,~7 ~98,65 36,59 557.33 88,9a.50 23.0~ 696.21 5B.B7 518.97 5897 50 22.79 70~ 77 37 77 537 8S!?~.50 ~2.67 70W.77 36 q8 a890.50 ~2,92 686,~3 36,00 537.33 11 11 1111 1111 11 11 11 11 11 11 11 1i 1111 1111 11 11 o000o0 O00000 O0 O0 00 O0 00 0000 00 0000 00 oo O0 O0 o0 O0 0000 O0 0000 OO 00 OO 00 00 000000 000000 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 000o0o 000000 OO O0 O0 O0 O0 000o O0 0000 O0 OO O0 O0 O0 OO 00o0 O0 0000 O0 O0 oo O0 O0 o00000 000000 7777777'777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 666666 11 666666 11 66 1111 66 1111 66 11 66 11 66666666 11 66666666 11 66 66 11 66 66 11 66 66 11 66 66 I1 666666 111111 666666 111111 11 222222 11 222222 1111 22 22 1111 22 22 11 22 i1 22 11 22 11 22 11 22 11 22 11 22 11 22 111111 2222222222 111111 2222222222 22 22 222222 222222 22 22 22 22 22 22 22 22 22 22 2222222222 2222222222 CCCC k K CK A C K K C KKK C K K C K A CCCC K ~ Y ~ PPPP RRRR P P R P P ~ PPPP RRRR P i~ R P R R P R O U R U U R 0 U U U U U U R UUUUU DDDD H H D D H H 0 O D O H H 0 0 O D HHfiHH O O D D H H 0 D D H H U 0 DDDD H H 000 g EEEE g E EEEEE *START* USER PCAL MONITOR 8~6 KLIOE40 *START* USER PCAL MONITOR SWS KLIOE40 [10707,611221 SEP-80. *START* [10707 611221 SEP-80[ *~TART* dOB dOB SHIP SHiP SEQ. 3603 DATE 01-NOV-80 3603 DATE OI-NOV-80 12:10:10 12:10:10 SSSSSSSS HH S$SSSSSS HH HH SS HH SSSSSS HHHHHHHHHH SSSSSS HHHHHHHHMH SS HH HH SS HH HH SS HH HH SS HH HH SSSSSSSS HH HH SSS$SSSS HH HH II II Ii II I1 II II I1 II I1 ii Ii II Ii I1 Ii II II I1 II ii 11 PPPPPPPP PPPPPPPP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PP PP TTTT TTTT TTTTTT OOOOOO TTTTTT OOOOOO TT OO TT O0 OO TT O0 TT OG OO TT OO OO TT O0 TT []O O0 TT OD O0 TT O0 TT 00 OO TT OOOO{]O TT *STAR'~$ USE~ PCAL [10707,61i22J dOB SHIP SEO. ~60.] MONITOR S~$ KLIOE40 SEP-80. ,START* FIL~: DS~H:SHIP TO<255>[10707 61122] CREATED: 31-OCT-80 PMINTEO: 01-NOV-80 l~:lO:2b ~UEUE $~l~CHg$: /FILE:FO~T /COPIES:I /SPACING:I tblMif:lJ0 /FOR~S:NURMAb DATE O1-NOV-80 17:08:50 12:10:10 SHI~ TO : 8HIPPING iNSTRUCTIONS ISSUED 3!-OCT-80 17:08 BY CKY PCCC PCCC THANKS...... VV VV VV VV VV VV VV VV VV VV VV VV VV VV VV YV VV EEEEEEEEEE RRRRRRRR VV EEEEEEEEEE RRRRRRRR VV EE BH RR VV EE B~ RR VV EE ~5 RR VV EEEEEEEE H~RRRRRH VV EEEEEEE~ ~HRRRR~R VV EE ~ RR VV EE R~ R~ EE R~ HH EE R~ ~H EEEEEEEEEE ~R RR EEEEEEEEEE BP RR I11III iIIIII II 11 II II II II 1I II lllIII IIIiII F Fi; I;'FFf' i; FF FF Fl~ YY YY YY YY ~Y YY YY YY YY 000000 000000 5555555555 O0000O 000000 5555555555 O0 O0 O0 O0 55 O0 O0 O0 O0 55 O0 0000 O0 0000 555555 O0 0000 O0 0000 555555 O0 O0 O0 O0 O0 O0 55 00 O0 O0 O0 O0 O0 55 0000 00 0000 00 55 0000 00 0000 00 55 O0 O0 O0 O0 55 55 O0 O0 O0 O0 55 55 000000 000000 555555 000000 000000 555555 9START* USER PCAL tlO707,61122J JOB SHIP SEO. MONITOR SWS KLIOE40 SEP'80. *START* ~ILE: DS~HlVERIF¥.O0~<05!>[10707.611221 CREATED: PRINTED: 0! NOV 80 12:10:34 OUEUE SWITCHES: /~16E:[ORT /CUPIES:I /SPACING:I /LIMiT:130 /FORMS:NORMAL 3603 DATE O1-NOV-80 O!-NOV-80 12:07:13 12:10:10 SCI~LU~BERGER COMPUTING CENTEI~ 10707,61129. REEL HEADER LENGTH: 112 BITES REEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CONTINUATION NUMBER: 01 PREVIOUS REEL NAME: COMMENTS: L1S ~'ORMAT CUSTOMER TAPE DATE: 80/10/31 TAPE HEADER LENGTD: 112 BYTES TAPE NAME: 61122 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O1 PREVIOUS TAPE NAME: COMMENTS: TAPE COMMENTS CASING DRILLER 9.625~9208/BiT SIZE 8.5/FLUID LOSS 5.1 DENS 9.9/VISC 19.O/PH II.O/FLUID TYPE 6IGNOSULFONAT~/ BM 1.29@58 F/RMF 1.1]~58 F/MAX REC TMP 185 F/ TAKEN FROM RUN#I. DID LOGGED 29GCTSO DATE: 80/10/31 ML/ EOF ~iLE HEADER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FIL~ NAMe: 1024 BXTES WELL SITE INFORMATION RECORD LENGTH: 182 B~TES COMPANY: W~LL: FIELD: RANGE: TOWN: SECTION: ATLANI1C HICHFIELD CO. 17-5 15E i0N 22 C [JU N'].' ~: STATL: N. ,S L,,(3 P ~J AL, ASKA DATA ~(]P, MAT SPRCIFiCATIUN I~E.NGT~t: 650 BYTES ~N'_PRY BLOCKS: TYPE 0 SIZE REP CODE 1 ~6 DEPTH 3700 o 000 3600.000 3500.000 3400.000 3300.000 3200.000 ]100.000 3000.OO0 2900.000 2800.000 2700.000 MNEMONIC 8P GR NPHI ~'CNL SP GR NPH1 FCNL SP NPHI FCNL SP NPHI FCNL NPHI FCNL SP GR NPHI ~CNL SP GR NPHi FCNL SP GR NPBI FCNL GR NPHI ~'CNL SP GR NPHi ~-CNL GR NPHi FCNL VALUE -999.250 -999.250 52.197 282.000 -999,250 -999.250 50,977 ]25.500 -999.250 -999.250 45.068 337.000 -999.250 -999.250 53,857 291.250 -999,250 -999.250 48,~28 339, O0 -999,250 -999,250 50,879 305.500 -999.25O -999.250 47.510 333.25O -999.250 -999,250 47.949 356.250 -999.250 -999,250 39.111 361,750 -999.250 -999.250 05,674 196.250 -999,250 -999.250 48,926 330.500 MNEMONIC lED GR RHOB GR lED GR RHOB GR ILD GR RHOB GR ILD GR RHOB GR ILD GR RHOB GR ILD GR RHOB GR GR ~.HOB GR ILD GR RHOB GR IBD GR RHOB iLD GR RHOB GR GR VALUE -999,250 48,125 -999,250-999,250 -999,250 34,094 -999,250-999,250 -999,25O 45,188 -999,250-999,25O -999,250 43,813 -999,250-999,250 -999,250 39,219 -999,250-999.250 -999,250 36.188 -999,250-999,25O -999.250 23,484 -999,250-999,250 -999,250 3~,625 -99 ,250-999.250 -999,250 i7.953 : 99. so 99,250 -999,250 3~.813 -99 ,250-999,250 -999.250 27.828 -999,250-999.250 MNWMONIC iLM CALl NRA~ DT CALl NRAT DT CALl NRAT DT CALk NRAT DT 1LM CALl NRAT DT CALl NRAT DT ILM CALl NRAI DT CALl NRAT DT ILM CALl NRA1 DT ibm CALl NRAI~ DT ibm CALl NRAT DT VALUE -999,2 -999,2 4.2 -999,2 -999,2 -999.2 4,1 -999,2 5O 5O 66 50 50 5O 99 5O -999.25 -999.25 3.87 -999.25 -999,25 -999,25 4,35 -999,25 -999,25 -999,25 4.07 -999,25 -999,25 -999,25 4.19 -999,25 -999,25 -999,25 4,00 -999,25 -999,25 '999,25 4,03 -999,25 -999,25 -999,25 3,54 -999,25 -999,25 -999,25 5,00 -999,25 -999,25 -999.25 4.08 -999,25 MNEMONIC St;'LU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb S~bO DRHU NCNb SFLU DRHO NCNb SFLU DRHO NCNb DRHO NCNb 8FbU DRHU NCNb 8FbU DRHU NCNb 8FLO DRHU NCNb DRHU NCNb VALUE -999.250 -999,250 1428,000 -999.250 -999.250 1521.000 -999,250 -999,250 1257.000 -999.250 -999,250 1400,000 ~999,250 -999,250 1388.000 -999,250 -999,250 1415.000 -999,250 -999,250 1422,000 -999,25O -999,250 1587,000 -999,250 -999,250 1431.000 -999.250 -999.250 1194.000 -999.250 -999.250 1297.000 D~ETD 4800,000 4700.000 4600.000 4500.000 4qO0.O00 4]00.000 4200.000 4100.000 4000.000 3900,000 3800.000 MNE~MON lC VAL SP -999 ' GR -999 NPHi 43 f'CNL 344 8P NPH1 ~CNL SP NPHI ~CNL SP GR NPHI FCNL SP GR NPHI SP GR NPHI ~CNL 8P NPHI ~'CNL SP GR NPHi FCNL BP GR NPHI FCNL SP GR NPHI PCNL SP GR NPHi FCNL UE .250 .250 .408 .750 -999.250 -999.250 48.145 295.000 -999. -999. 52. 30.3. -999. -999. 44. 403. -999. -999. 54. 293. -999. -999. 56. 274. -999. -999. 4b. 329. -999. -999. 52. 324. -999. -999. 51. 337. -999. -999. 57. 273. -999. -999. 49. 307. 250 250 783 750 250 250 922 250 25O 250 004 50O 250 250 543 250 250 250 875 500 250 250 588 750 250 250 563 250 25O 250 959 250 250 250 902 50O MN EMONIC ILD GR RHOB GR ILD GR RMOB GR ILO GR GH iLD GR RHOB GR ILD GR RHOB GR ILO GR RHOB GR ILD GR RHOB GR ILD GR RHOB GR iLD GR RHUB GR 1LD GR RHOB GR ILD GB RHOB GR VALUE -999,250 24.734 -999.250-999.250 -999.250 26,078 -999.250-999.250 -999.250 36.688 -999.250-999.250 -999. 250 4 750 -gg : so -999,250 -999.250 40,938 -999.250-999.250 -999.250 44.344 -999,250-999.250 -999.250 35.063 -999.250-999.250 -999. 250 49.563 .-~99,250 991250 -999.250 42,469 -999.250-999.250 -999,250 43.969 .-999,250 999.250 -999.250 39,156 -999.250-999.250 MNEMONIC CALl NRAT DT CALl NRAT DT IbM CALl NRAT DT ILM CALl DT iLM CALl NRAI DT IbM CALl NRAT DT CALl NRAI DT CALl NRAT DT IbM CALl NRAT DT CALl NRAT DT ILM CALl NRAT DT VALUE -999,250 -999.250 3.783 -999.250 -999.250 -99~ 250 ~043 -999.25O -999.250 -999.250 4.297 -999.250 ~999.250 999.250 3.867 -999.250 -999.250 -999.250 4.303 -999.250 [~99.250 99.250 4.504 -999.250 -999.250 -999.250 3.975 -999.250 -_~99.250 99.250 -99 250 -999.250 -999,250 4.230 -999.250 -999.250 -999.250 4.582 -999.250 -999.250 -999.250 4.137 -999.250 MNEMONIC SFbU DRHO NCNL SFLU DRHU NCNb SFLU DRHO NCNb SFLU DRHU NCNb SFLU DRHO NCNL SFLU DRHU NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFbO DRHO NCNb SFLU DRHO NCNb VALUE -999.250 -999.250 1396.000 -999.250 -999.250 1390.000 -999.250 -999.250 1451.000 -999.250 -999.250 1546.000 -999.250 -999.250 1408.000 ~999,250 9991250 1363.000 -999.250 -999,250 1475.000 -999.250 -999.250 1512.000 -999.250 -999 250 1599~000 -999.250 -999.250 1448.000 -999.250 -999.250 1493.000 2601,000 MNEMONIC GR NPH 1 I, CNL VALU~ -g99,250 -999.25o 63.428 246.625 MNEMONIC Ri~OB GR VALUE -999,250 16.531 -999.250-999.250 MNEMONIC CALl NRA~ DT VALUE -999,250 -999.250 4.883 -999.250 MNEMONIC DRHO NCNL VALUE -999.250 -999.250 1307.000 SUMMAM~ OF DATA ~ECORDg NUMBEB OP" RECORDS: i01/ LENG~£H O~' RECORDS: 966 BYTES LF~]NGTH []~- LAST ~ECORD: 966 BYIES FILE TRAILER LENGTH: 62 BYTES ?ILL NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: NEXI FiLE NAME: TAPE TRAiLEH LENGIH: 112 TAPE NAME: 61122 SERVICE NAME: EDIT TAPE CONTiNUATiON NUMBER: NEXT TAPE NAME: C~MMkNTS: 1024 BYTES DATE: 80/10/]1 DEPTH 5900.000 oo.o0o 5700,000 5600.000 5500.000 5400.000 5300.000 5200.000 5100.000 5000.OO0 4900.000 MNEMONIC bP NPH l FCNL SP G~ NPHI PCNL NPH1 ~CNL SP NPhI ~CNL SP NPHi FCNb 8P GR NPH! FCNL SP GR NPH1 FCNb NPHI SP GR NPHI FCNL SP NPH! FCNL 6P GR NPHI ~CNL VALUE -999,250 -999.250 39.45] 4]8.500 -999.250 -999.250 41.602 361.250 -999.250 -999.250 15.576 958.000 -999.250 -999.250 50,195 23b.375 -999.250 -999.250 46.973 300.500 -999.250 -999.250 54.736 252.000 -999.250 -999.250 53.369 274.50O -999.25O -999.25O 68.1i5 199.875 -999.250 -999.250 46.191 301.750 -999.250 -999.250 41.260 426.250 -999.250 -999.250 52.5]9 288.000 MN EMUNIC GR RHOB ILD GR GR ILD GR 1LD GR RHOB GR ILD GR RHOB GR ILD GR RHOB GR ILO GR RHI]B GR ILD RHOB GR ILD GR RHDB GR ILD GI~ RHOB GR ILD GR RHOB GR VALUE -999,250 33.469 -999,250-999.250 -999.250 45.656 -999.250-999.250 -999.250 25.750 -999.250-999.250 -999.250 28,344 -999.250-999.250 -999.250 27.359 -999.250-999.250 -999.250 29.750 -999.250-999.250 -999.25O 43.031 -999.250-999,250 -999.250 . 32.59~ 99:9.250 -999.250 -999.250 29.609 -999.250-999.250 -999.250 28.516 -999.250-999.250 -999.25O . 20.531 999.250 -999.250 MN LMON1C CALl NRA~ DT ILM CALl NRAT DT ibm CALl NRAT DT ILM CALl NRAT DT IbM CALl NRAT DT CALl NRAI DT CALl NRAT DT ILM CALl NRAT DT ILM CALl NRA~ DT CALl NRAT DT iLM CALl NRAT DT VALUE -999,250 -999.250 3.566 -999.250 -999.250 -999.250 3.684 -999.250 -999.250 -999.250 2.184 -999.250 -999.250 -999.250 4.156 -999.250 -999.250 -999.250 3.979 -999.250 -999.250 -999.250 4.406 -999.250 -999.250 -999.250 4.328 -999-250 -999.250 -999.250 5.137 -999.250 -999.250 25O -999.250 -999.250 -999.250 3.666 -999.250 -999.250 -999.250 4.285 -999.250 MNEMONIC SFLU DRHO NCNb SFLU DRHO NCNb SFbU DRHO NCNb ,SFbU DRHO NCNb SFLU DRHO NCNb SFI,U DRHO NCNb SFLU DRHO NCNb SFbU DRHO NCNb SFLU DRHU NCNb SFhU DRHO NCNb SFLU DRHO .NCNb -999.250 -999.25O 1843.000 -999.250 -999.250 1357.000 -999.250 -999.250 2192.000 -999.250 -999.250 1182.000 -999.250 -999.25O 1323.000 -999.250 -999.250 1308.000 -999.250 -999.250 1373.000 -999.250 -999.25O 1091.000 -999.250 -999.250 1266.000 -999.250 -999.250 1594.000 -999.250 -999.250 1398.000 Db.,PT H 7000.000 6qO0.O00 6~00.000 6700.000 6600.000 6500,000 6400.000 6300.000 6200.000 6100.000 6000.000 MNEMUNiC GR NPHI fCNL GR NPHI fCNh NPHi FCNL SP GR NPHI FCNL SP NPHI fCNL SP NPHi ~CNb SP GR NPHI f'CNb SP GR NPHI f~CNL GR NPHI FCNL GR NPHI fCNL GR NPHI PCNb VAL -999 -999 4O 376 -999 -999 43 350 -999 -999 36 4]8 -999 -999 44 329 -999 -999 38 347 -999 -999 38 423 -999 -999 39 342 -999 -999 38 449 -999 -999 37 415 -999 -999 38 431 -999 -999 42 328 UE .250 .250 .527 .750 ,250 ,250 ,994 ,250 .250 .250 .963 .500 .250 .250 .727 .000 .250 ,250 .086 .000 .250 .250 .379 .000 ,250 .250 ,844 ,750 ,250 .250 ,232 .250 .250 .250 .939 ,000 ,250 .250 .525 ,000 ,250 .250 ,969 .750 MNEMONIC GR GR ILO GH RHOB GR iLD GR HHOB GR iLO GR RHOB GR ILD GR RHOB GR ILD GR RHOB GH IbD G~ GR iLO GR RHOB GR ILD GR RHOB GR ILD GR RHOB GR ILD GR HHOB GR 'VALUE -999,250 38.531 -999.250-999,250 -999. 250 3 125 -999,250 -999.250 40.125 -999.250-999.250 -999.250 47.969 .-999.250 999.25O -999.250 42.188 -999.250-999.250 -999.250 36.813 =999.250 -999.250 -999.250 42.188 -999.250-999.250 -999.250 42,906 -999.250-999.250 -999.250 28.922 -999.250-999,250 -999.250 31.391 .-999.250 999.25O -999.250 19.219 -999,250-999.250 MNLMON1C CALl NRAT DT CALl NRAT DT iLM CALl NRAT DT iLM CALl NRAT OT IbM CALl NRAT DT ILM CALl NRAT DT ILM CALl NRAT DT IbM CALl NRAI DT IbM CALk NRAT DT CALl NRA1 DT ILM CALl NRAT OT VALUL -999.250 -999.250 3.627 -999.250 -999.250 -999.250 3.818 -999.250 -999.250 -999,250 3.430 -999,250 -999.250 -999,250 3.855 -999.250 -999.250 -999.250 3.492 -999,250 -999-250 -999.250 3,510 -999,250 -999,250 -999,250 3.588 -999.250 -999.250 -999.250 ],500 -999,250 -999.250 -999,250 ],484 -999,250 -999,250 -999.250 3.516 -999.250 -999.250 -999.250 3.760 -999.250 MNEMONIC SFbU DRHO NCNb SFbU DRHO NCNb SFbU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLO DRHO NCNb SFLU DRHO NCNb 8FLU DRHO NCNb SFLU DRHO NCNb SFLU ORHO NCNb SFLO DRHO NCNb VALU& -999.250 -999.250 1507,000 -999.250 -999.25O 1420.000 -999.250 -999.250 1698.000 -999.250 -999.250 155i.000 -999.250 -999.250 1397.000 -999.250 -999,250 1513.000 -999.25O -999.250 1542.000 -999.250 -999.250 1709.000 -999,250 -999,250 1652.000 -999.250 -999.250 1620.000 -999.250 -999.250 1249.000 DLP'I~H 8JO0.O00 8000,000 7900 o 000 7800.000 7700.000 7600.000 7500.000 7400.000 7300.000 7200.000 7100.000 MN EM Oi'q lC 6P NPhi fCNb 6P GR NPHI [~CNL 8P GH NPHI ~CNL SP GH NPHI $CNL SP GR NPHi FCNL GR NPHi ~CNL SP GR NPHI ~CNL SP GR ~CNL SP GR NPHI ~CNL SP GR NPH1 SP GR NPHI VAL -999 -999 4O 417 -999 -999 44 356 -999 -999 37 433 -999 -999 39 417 -999 -999 38 437 -999 -999 41 371 -999 -999 4O 428 -999 -999 42 375 -999 -999 305 -999 -999 42 376 -999 -999 3~ 442 UE .250 .250 .771 .000 .250 .250 .287 .750 .250 .250 .695 .250 .250 .250 .844 .000 .250 .250 .330 .750 ,25O .250 .064 .000 .250 .250 .b25 .750 .250 .250 .529 .500 .250 .250 .631 .250 .25O .25O .920 .250 .250 .250 .768 .250 MN EMON IC GR RB/]~ GR. ILD GR RHOB GR ILD GR GR ILD GR RHOB GR ILD GR RHOB GR ILD GR RHOB GR ILL GR RHOB GR 1nD GR RHUB GR ILD GR RHOB GR lED GR RHOB GR ILD GR RHUB GR VALUE -999,250 53.250 -999.250-999.250 -999.250 49.219 -999.250-999.250 -999.250 52.750 -999.250-999.250 -999.250 49.156 -999.250-999.250 -999.250 53.813 -999.250-999.250 -999.250 79.563 -999.250-999.250 -999.250 71.875 -999.250-999.250 -999.250 57.813 -999.250-999.250 -999.250 54.281 -999.250-999.250 -999,250 60.906 -999]2250 -999 50 -999.250 45.281 -999.250-999..250 MN CALl NRAI DT ibm CALl NRAT DT CALl NRAI DT ibm CALl NRAI DT iLM CALl NRAI DI~ 1EM CALl NRAT DT CALl NRAT DT CALl NRAT DT ILM CALk NRAT DT ILM CALl NRAI DT 1LM CALl NRAT DT VALUE -999,250 -999.250 3.639 -999.250 -999.250 -999.250 3.834 -999.250 -999.250 -999.250 3.471 -999.250 -999.250 -999.250 3.588 -999.250 -999.250 -999.250 3.506 -999.250 -999.250 -999.250 3.654 -999.250 -999 250 -999:250 3.633 -999.250 -999.250 -999.250 3.736 -999.250 2999.250 999.250 3.959 -999.250 .-99 250 9999:250 3.756 --999.250 -999.250 -999.250 3.420 -999.250 MNEMONIC 8FLU DRHO NCNb SFLU DRHU NCNL SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHU NCNb SFLU DRHO NCNJJ $FLU DRHO NCNb SFLU DRHO NCNb SFGU DRHO NCNb SFLU DRHO NCNb VALUE -999.250 -999.250 1612.000 -999.250 -999.250 1510.000 -999.250 -999.250 1607.000 -999.250 -999.250 1714.000 -999.250 -999.250 lOgb.000 -999.250 -999.250 1565.000 -999.250 -999.250 1715.000 -999.250 -999.250 1643.000 -999.250 -999.250 lbOi.O00 -999.250 -999.250 1647.000 -999.250 -999.250 1741.000 DEPTH 9200.OOO 9100,000 9000.000 8qO0.O00 8800.000 8700.000 8600.000 8500.000 8400.000 8300.000 8200.000 MNEMONIC GR NPHI PCNL SP GR NPHi PCNL SP GR NPMI FCNL SP GR NPHI fCNL GR NPHI FCNL SP GR NPH1 fCNL SP GR NPHI F'CNL SP GR NPHI FCN6 SP GR NPH1 fCNb SP NPHI FCNL SP GR NPHI fCNL VAL -999 -999 42 443 -999 -999 46 370 -999 -999 4b 373 -999 -999 49 329 -999 -999 36 435 -999 -999 39 411 -999 -999 42 406 -999 -999 52 342 -999 -999 44 443 -999, -999. 37. 443, -999. -999, 38. 409. UE .250 .250 ,920 .000 .250 .250 .484 .500 .25O .250 ,484 .500 ,250 ,250 .268 .25O .250 .250 .182 .000 .250 ,250 ,746 .500 .250 .250 ,969 .750 ,250 .250 .637 .500 .250 .250 ,824 .750 250 250 842 750 250 250 525 000 MNLMON lC ILD GR RHUB GR ILD RHOB GR iLO GR RHUB GR ILD HHOB ILO GR RHUB GR ILD GR RHOB GR lhD GR GR iLD HHUB GR ILO GR GR ILD GR GR ILD GR GR VAL -999 b6 -999-999 -999 78 -999-999 -999 109 :999 999 -999 112 -999-999 -999 69 2999 999 -999 85 999 -'999 -999 86 -999-999 -999 83 -999-999 -999 79 ~999 999 UE .250 .063 .250 .250 .250 .938 .250 .250 .250 .750 250 ~250 .250 .813 .250 .250 ,250 .313 ,250 .250 .250 .438 .250 .250 .250 .813 .250 .250 ,250 25O .250 .250 .375 .250 .250 -999.250 50.406 -999.250-999.250 -999, 50, -999.-999. 250 844 250 250 MNkMONIC ibm CALl NRA'I DT ILM CALl NRAT DT CALl NRAT DT ILM CALl NRAT 1LM CALl NRAT iLM CALl NRAT DT ILM CALl NRAI OT iLM CALl NRA~ OT ILM CALl NRAT DT CALl NRA~ DT ILM CALl NRAT DT VALUE -999.250 -999,250 3.758 -999.250 -999.250 -999.250 3.953 -999.250 -999.250 -999.250 3.953 -999,250 -999,250 -999,250 4.105 -999.250 2999.~50 999. 50 3.389 -999.250 -999,250 -999,250 3.582 -999,250 -999.250 -999,250 3.760 -999.250 -999,250 -999.250 4,289 -999,250 999 250 -' 9 225o 3.861 -999.250 -999.250 -999.250 3,480 -999.250 -999.250 -999.250 3.518 -999.250 MNEMONIC SFLO DRHO NCNb SFbU ORHO NCNb SFLO DRHO NCNb SFbU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb Sf'LU DRHO NCNL DRHO NCNb VALUE -999,250 -999.250 1695.000 -999.250 -999.250 1603.000 -999.250 -999,250 1461.000 -999.250 -999.250 1575.000 -999.250 -999.250 1642.000 -999.25O -999.250 1610.000 -999.250 -999.250 1762,000 -999.250 -999.250 1578.000 -999.250 -999,250 1993,000 -999.250 -999.250 1669.000 -999.250 -999,250 1754.000 DEPTH 10228,000 10200.000 10100.000 10000.000 9900.000 9800.000 9700.000 9600.000 9500.000 9400.000 9300.000 SP GR NPHI FCNL SP GR NPH1 FCNL SP GR NPH1 FCNL SP GR NPHI ~CNL GR NPHI ~CNL SP GE NPHI FCNb SP GR NPHi FCNL SP GR NPHI FCNL SP GR NPHI ~CNL SP GR NPHI FCNL SP OR NPHI FCNL VALUE -21.500 -406.250 26.221 949.000 -24.500 -40b.250 29.492 911.000 -31.000 108,06] 17.725 1610.000 . 4.o0'o 27.881 i196.000 -60.000 29.547 24.951 1302.000 -59.500 ]0.984 27.9]0 1179.000 -59.5OO 23.031 18.701 1971.000 -60.000 32.438 24.268 1441.000 '63.~00 21.435 1423.000 -20.500 82.563 4220.O00 34.50O 99;'750 35.889 535.5O0 MNEMONIC iLO GR RHOB GR GR RHOB GR GR RHUB GR ILD GR RHOB GR 1LD GR RHOB GR GR RHOB ILD RHOB GR ILD GR RHOB GR GR RHOB GR GR RHOB GR ILD GR RHOB GR VALUE 8.563 112.563 2.771 -406.250 8.523 676 -406.250 9.617 101.625 O63 2.727 25.219 2.242 33.500 2.637 26.438 2.328 29.547 2.256 27.609 2.297 30.984 3.793 21.969 2.387 23.031 18.422 27.641 2.]05 32.438 26.609 40.875 2.373 49. 188 77.563 72.563 2.670 82.563 1.804 100.938 2.578 99. 750 MN LMONIC CALl NRAT CALl NRAT CALl NRAT DT ILM CALl NRAT DT ILM CALl NRAT DT CALl NRAT DT iLM CALl NRAT DT CALl NRAT OT CALl NRAT DT CALl NRAT DT CALl NRAT DT VALUE 12.078 8.594 2.490 80.188 12.156 8.680 2.721 80.188 9.438 8.867 1.952 71.563 2.793 8.344 2.584 90.563 2.736 8.297 2.389 85.750 2.369 8.414 2.598 91.188 4.063 8.531 1.990 80.750 523 2. 359 88.000 18.438 8 81 86.188 70.438 9.844 1.319 60.000 1.793 14.164 3.350 98.750 MNEMONIC SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHU NCNb SFLU DRHO NCNb SFLO DRHO NCNL SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb DRHO NCNb VAbUL 13.048 0.104 2644.000 13.734 0.023 2714.000 11.695 0.019 3534.000 4.145 0.000 3804.000 4.016 0.029 3566.000 3.943 -0.000 3496.000 5.070 O.02b 4368.000 15.484 0.015 3520.000 25.219 0.004 3390.000 80.b88 0.005 5984.000 2.045 0.139 1931.000 DATUM SPECIFICATION ~bOC~8: ENTRY IC TOOL SVORD# UNITS APl API AP1 AP1 ~'IhE~ SIZE E×P PROC SAM REP DEPT ShifT 1 DEPT 2 SP DIL ] ILD DIL 4 ILM OiL 5 SFLU DIL O GR DiL 7 GH CNL 8 CALl CNL 9 ORHO CNL I0 NPHI CNU 11 ~HOBCNL 12 NRAT CNL 1 ] NCNL CNL 1 4 FCNL CNL 15 GR B HC 16 DT ~HC FT 0 0 0 0 0 4 0 0 1 08 0 0 MV 7 I 0 0 0 4 0 0 1 68 0 0 OHMM 7 12 46 0 0 4 0 0 I 68 0 0 OH~ 7 12 44 0 0 4 0 0 1 68 0 0 OHMM 7 22 1 0 0 4 0 0 1 68 0 0 GAPI 7 31 32 0 0 4 0 0 1 68 0 0 GAP1 42 31 32 0 0 4 0 0 1 68 0 0 IN 42 28 1 0 0 4 0 0 I b8 0 0 G/C] 42 44 0 0 0 4 0 0 1 58 0 0 PU 42 68 3 0 0 4 0 0 1 08 0 0 G/C3 42 35 1 0 0 4 0 0 1 68 0 0 C/C 42 42 1 0 0 4 0 0 1 08 0 0 CPS 42 .34 92 0 0 4 0 0 1 68 0 0 CPS 42 34 93 0 0 4 0 0 1 ~8 0 0 GAPI 60 31 32 0 0 4 0 0 1 ~8 0 0 US/F 60 52 32 0 0 4 0 0 1 b8 0 0 PAG~ DA'i:;, R£CURI] TYPE 047 t~:~iT TtPE CATE SiZE CODE OOO 000 012 065 ~'' ~10 065 OOO ~00 000 000 12 065 000 ~00 O0~ 065 000 v O0 00~ 065 u 0 002 065 000 000 012 065 000 000 006 065 000 000 006 065 UNIT TYPE CAT~ S~ZE CODE O00 uO 0 0 0 '1 O65 TYPE 047 ** BT~'~. ~!G I~'£CRVAI, TOP TYPE rbUiD ~N HOLE 9~50 9300 = CRooE CA6£~C ~iZ~ = 9.63 IN. $ORF. TO 92 09 PAGE iO ORDE:~ ~ DEF.;:' 9916.000 FITi:~ 134. 375 N I'T. D DEP:: 9~00. 000 F1To ] 22,500 DEP~i 9700.000 SIGN F1T;> "90~875 OEP:.[' 9500. 000 5IG~ F1TO 1~,500 NiTD D~'i 930U,000 F1Tu kTG.50U DEP'i' 9286,50U F1T~ 252,875 NITD 0 0 ri 0 0 I 'i 3 05 APl AP1 AP1 FIbE ~'YP~ C~A~S kOD 0 o O O ~O i 0 0 0 ~ 0 0 ~2 1 0 0 39 I 0 0 39 ~ o 0 31 32 0 0 I7 7i9 214.250 GR 19.750 FSiG 17g,bO0 206.250 17,000 19B.375 119.000 GR 16.5].6 F~IG 341.250 15.328 FSiG 285.500 34.~t FSIG 388.750 34~.250 i6o o SIZE PROCESS SAMPLE 0 4 0 4 0 X ,932 8.375 16.~8g TRAT 5.59q 13.857 T~AT ~4.78i 17,686 52.375 14.336 TRAT 5~.375 3 .262 TaAT 4.375 33.223 TRAT 10~.750 ,750 REPR 6U 68 68 3.938 4.309 4.i19 3,916 4,153 3.806 3,400 4,922 4.766 PAGE DAT~ : FiL~ 7 [UE ; 1024 u 1 (,6 SERVICE ID UROE}{ ~ $ IGr',- F61G TRAT ,,1 ~ F1Tu uo6 NI'ID Mbr!cK~ Oi~IT APl bOG o 0 CPS 0 CPS 0 GAPI 0 . N60 0 APl APl AP1 FILE 0 0 0 0 4 39 ~ 0 0 31 32 0 0 4 SIZE ~ROCES$ SA,~PbE REPR L~VEL CODE 0 i 68 0 ~ 68 0 68 68 I 68 X 68 9910,000 !12,43~ 9900,000 136,500 9POU,O00 120.438 9~uO.uO0 16.90~ FSiG 168.625 GR 20.5t6 FSIG 216.750 GR 17 .626 GR 16.906 ~SIG 176.625 GR 20.391 152.500 -A~ i~,482 TM ~ -999,250 43.875 t7,~80 TRAT 4,228 50.813 ~,523.438 TRAT ~.241 14.609 TRAT 3.966 38,18B 17,7~5 T~ 1 g 291 ~7.531 i~,~72 F6IG 273,000 GM 15,477 EGiG 200,750 GR 33.938 FS1G 377.b00 Gk 60.000 f'SiG 2000.O00 G~ EOF %3.770 T~AT 47.938 13.291 TRAY 99,938 33,516 TRAY ~5,063 0.406 PAGE 3.872 3.344 4.769 5.975 f'i Lr: ~ A,v! E ;SERVIC.O03 VERAIO.~ ~ : DAT~: : MAXIMO,~ LENGTH : 1024 FILg [[ IPE PI-Er' I[~U~ FILE TYPk, 4 9 0 DAi'U~', SP£CIflCATION BD[',CKS iD ORDER ~ D{r, PT FT big 013 FIT[: 007 CPS 0 0 7 G A P i 1 4 1 APi API ~OG TYPg 0 0 0 4O 0 0 0 42 0 39 0 39 0 31. .~PR APt API ~ASS ~i~D 0 0 0 1 0 1 0 32 0 66 ~ '13 60 65 .lin 66 0 0 ~ 0 0 4 0 CODE 68 FiT~.~ 1]9,500 FI T~) ilg,bOO Ni?D DEPT 9600, OOO Si{; FITo i35.37~ NiTS DEPY 9~O0,uOu FiTU 258,750 17.003 151.~75 20.391 i75,250 19.g38 i75.25U 16.953 175.250 22.~41 167,250 239.000 16.000 3~.'?19 -999.250 -99~.25u 15,205 TEAT -999,250 17 939 TEAT 492969 16.982 TEAT -&9.S9~ i ~.60~ TEAT 7.969 16.982 13,779 TEAT 5~.781 1~,01~ 9~,375 32.773 TEAT 103.563 60.O00 TEAT -999,250 PAGE 4,037 3,953 ~.194 3.931 4.109 3,894 3,369 4.875 -999.250 PAGE AFl Aki APl AP]. FiLE 0 0 u 0 0 0 ~ {.) ~ 0 0 O 0 ~ 0 0 0 &2 ~ 0 0 U ~9 1 0 0 v 39 ~ 0 0 0 31 32 0 0 E~TRY i 6 0 0 DEVEb 4 0 4 0 4 0 4 0 4 u 4 0 4 0 SAMPLE CODE 68 DEP'J: 9910.000 SiGa FiT. -9qg.25U D£F'I' 9~00.000 BiG/ FITO 126.~38 DEPT 9~00.000 SIGa F1TI~ 111,063 F1T~ 119,000 D£P~ 9590.000 F1Tu 1~6,625 DEPT 94o0,~0u FiT~ 119,000 F1Ti; 234. 125 M 1 'J'D DEP']> 9236.500 SiGM -999.250 FSIG -999.250 GM 20.188 FSIG 1,58.625 GR 19.719 FSIG 16~.b2b G~ 16.~59 FSI~ 190.375 GR ~9.359 F$IG 19~.375 GH 16.~25 PSib 293.500 GR 15.320 FSiG 238.000 GR 35.156 FSIG ~09.500 G~ 59.~75 ~S.G 2000.000 GR -999,250 TkAT 22.797 7 '13 T~A 17.344 TRAY 5~.59~ I5,557 TRAT 57.594 4.375 TRAY t3.66~ TRhT 10o.375 33.140 TRAY I09.18~ 59.7~7 TRAY 99,563 3.981 4.006 4.172 3,900 4.294 3.922 3.397 4.972 6,000 PAG~ TRAi N iT,; GR 10 OROE~ ~ ) :j g 4 1 .~i 0 O C CU 0 40 1 0 C 0 0 42 1 CPS O 39 i CPS 0 39 1 GAPi 0 3! 32 REPR CODE b 6 MOD NO. 0 0 0 0 0 0 0 0 0 0 O 0 ENTR~ , 0 SIZE PROCESS SAMPLE REPR bEVEL CODE 4 0 1 68 4 0 I 68 ~ 0 I 68 4 0 i 68 4 0 i 68 ~ 0 I 68 ~ 0 i 68 9~ 1 £ 97 90 1 10. 99 . 00. OC. Ok. 06. 69. 000 25O O 00 125 000 ~7~ uO0 '75O -999.250 -999.250 19.7!9 189.625 19.484 189.c25 189.625 2i.609 221.250 16.9~4 268.750 FSIG G~ FSiG GR FS!G GR FSiG GR FSIG ~'6IG GR -999,250 TRAT 99.563 6,152TRA~ 1.75b 17.939 TSAT 55.750 14 1=I THAT i7.100 65.6~ 13,779 67.3~2 -999,250 4.347 4.262 3,~84 4.109 3.800 PAGE D~P', 9300,000 8iG~ F1T~:~ ~o30.000 DAT~ : MAXi~*v'~ b~G2h : 1024 17,219 FSIG 221.25C G~ 59.750 F$I~ 37i,500 GR 59.750 FSlG 2000.00~ GR 14.0~4 112,312 i27.875 59.25~ 3,384 5.403 6.000 -~ ~:~ .... %~:COMPA~ ; kTbAN~I-C RICHFIEbD PAGF G A P ! G A P I G A P I G A P I C U g ~4.89 ~.~so.~ oo.4 ~5. ~ 43,9 44. 5B,O 51 .17 54 53 45. , , 5. 44.8 54.8 50. 95 14.93 4 2. 5~ 36 15.25 45,1 8 56, , 4 . 55. 16.76 ~250,8 54 ' 1 :43.1 46'7 50.0 69. ,,.o . ,4 62 64,6 75.2 78.8 75 66.6 71,2 72.8 74 65.8 65,2 75,6 70 ~67.9 63.6 73.6 62,6 63,2 71,2 67 ii~i 69 9 94.B 76. 71 9 78 ~ I 4 87 82 ~ 86 90 95 ~ ! 85 3 99 .9 99 77 6 9! 6 97' 80 9 95 9 97.9 93 8'0 94 4 94.8 89 761~ 84 8 91 84 756 BO 4 90'~ . 83 80 89 .2 89 i77 2 65 105, '68,7 74 84. 8, 77.~ 81 ~ 9968 97 2 8 · 79. 47 4 5 54. 8 68 ,73.9 71 75.2 90 4 7 2 17.15 17,22 16.48 41 17 64 9O ~7 35 52 63 06 17 29 50 18 30 35 ~9 24 88 20 90 02 22 93 75 25 37 09 31 O3 3O 88 8O ~2 ~2 32 77 92 O2 30 29 31 29 !0 26 48 73 26 43 63 24 41 47 20 72 23 16 13 35 14 73 DEPTH ~S_~ _P_AS,<S..2 .'~ ~:~3~ ~a4 PCTA~_~ ~I PA~M~_S2 PASS3GR PASS4GR PASS5GR SI~A SI~AAVE AVE, NEAR FAR I GAPI GAPI GAPI CU 8 76.8 85.9 102 4 86 20 79;3 85,6 t05 6 91: 61 ' 56 0 64 . · 8 44 4,. 7'I 3B'6 46 8 55 4~.0 44,4 59,~ 48.4 ' ·8 48.3 39; 8 46 0 56 35, 50 9, 8 56 58.460,0 66~:4 44, 40.76 54,4 54,4 51.2 61.6 36,6 48.0 54.4 46 32.1 50,8 47'6 44 35'8 56,8 37,0 54 43 * 9 56 4 47,9 57.9 66.~ 57 39~ 8 47,2 55,6 48 40 2 44,8 5~ 6 47: ¸38: 39 35 34 37 ~6 0 ~? 8,98 1 20 24 66 1,05 1~,76 I: 17, 59 15' 20 13 15. 05 15 75 17 16 84 16 t4 16 16, 22 16 46.8 47,6 52,0 50, , 53,2 53,0 17 15, 15.0 58 14,8 48 t4,7 , 44 16 ,0 52.8 46. 89 16 4~.2 54.8 47. ,95 16, 8 46,0 51.6 46. .]6 1 0 50.8 56.0 47.~ ~.91 17. 0 53.6 58.0 47. .49 17, 6 47, . : 04 . , .8 48 15 58 $ 47 4 38 0 ~ 57.6 5~.6 S2.4 8 54.4 50,0 48,8 46 ,0 46 ~4 PASS4 PASS5 GR GR GAP! GAP! 63 ~ 57,6 6! 51.6 54 ~ 48.6 52 46,0 51 ~ 51.0 5! 62.0 SO.O 52 46,4 56 ~ 49.2 49.8 51,6 51.2 60,4 68'8 62.3 71,6 6S.8 PAGE 3 AVE. AVE. SIGMA SIGMA NEAR FAR CU 47 11 16 ~7 17 17 :92 18 65 1'/ 30 0 16, 26 18 47 17 58;456.054'0 54.0 61.2 87 5:~':6 59.2 29 19 56.0 58,0 5:0 06 52.8 50,G 46 48 17 ,49 50'8 50'8 35 16. 5'5 51.0 !! ,52 X6. o 8~ ~ .6 46.8 64 17. ,8:52,0 51.5 :43 17. 9 52.0 58.0 50.7 21,86 18, 6 49'6 54'8 49'6 21'02 18. 6 46.4 53.6 46.4 20,47 47'6 53'2 49'2 21.84 19' 43 5 51.2 52,4 49.1 21.92 PAGE 4 52.4 50. 43. 46.~ 53. 0 52. 55,~ 41~4 55 ~ 54.4 41 o 5 .2 :3,8, 48 46'~ 57. 35 45 47. 53,2 0 50 53.2 o 6.o 53.6 48.4 6 50.0 51.6 0 50.8 49.6 36,~ 50 8 36, 8 37 5 8 9 45.2 54.8 5O ? 49, 8 38 2 54,0 50,0 435 55.2 54.0 51.5 20,42 17,63 40 6 55.2 5t'6 51.6 19'08 16,51 40 2 52,0 56,0 51.2 18.53 16,15 4~i 50'8 56,4 50'8 18'56 15'92 48'4 64.0 50'7 ,v.09 15'62 34 49.2 58.4 49,2 18. 9 15,5' tS' 15,54 48,8 48.8 5t'6 60t0 38 54,0 54,0 49,0 18,66 16.08 :39~ ~ 51.6 5 .6 50.3 i8. 15.62 44,0 54.0 44,7 18'89 16,16 6 44'4 53'6 47.2 18.52 15.74 86 0 15.26 ?i 15'13 15.06 14.91 15.09 ~ i5.68 44 16'52 03 17;18 16.98 ! 47 45 48 49. 47.7 45 46. I 17 Ii15.74 15.67 15.80 16.10 13 16,3§ ,62 16,51 ' ,02 ,08 15.18 .20 15.4' 20 15.~ 91 15. 97 15.3 PAS&2 PASS3 PASS4 PASS5 AVE AVE. GR GR GR GR SZG~A SIGMA NEAR [:'AR 8 36.6 51.2 48.8 4 47. 0 28 ' 9 42, 6 8 32, 50, , 4 31.3 54, 2 37 ' 0 51. 46.8 44.4 i~'2'2 47, 52. 32. 4 Io GAP! CU 44, 8 44 6 44 6 45 4 46 4 42 6 45.6 , 44 32;5 33'3 36'2 ,2 46 32.9 so 4 51:6 47. 37'0 49,2 50,4 48. 44,4 49:2 44. ? 44,4 48, 49.1 38 2 48. 48.0 366 50'~2 54 54 49. 2 34 5 53. 36 2 46.8 48.4 34 35 36 32 36 36 33 35 32 30 32 30 44'4 32 17 17 17 17 6' 6' 05 15 5 15 91 15 91 15 94 15 53 15 88 15 98 14,~ 63 14, 95 63 14. 66 14, I 94 1 46'0 51,2 46, , 14. 46.8 54.~ 46.~ I~,88 14, 44.0 54. 48. .34 14. 47. , 46'8 so.o 47'6 55.~ 48 48' 56.4 48 45 2 54.8 47 46:0 46.8 42.6 48.8 41.6 44.~ 43'6 48.4 43. 44,0 46,8 44.§ 46'8 53.2 45. 476 53.6 47 44 4 46,4 44 41 6 51.6 44 4 25 98 14 O? 65 13 60 89 77 14 14 23 14 65 32 4,25 23 ! 07 55 ! 84 95 1 37 41 1 61 N E A R r A a ;[ ¢ U U CU ~.,~ '~C',.U~.~.,~.. ~.~'' GA P ! GA P ! G A P :[ G A P :T G A P ! C U 35 8 43,~ 52 0 38 6 46, 60 4 69. 79 62.8 65 52,0 54 0 5O 745 142 30 ~ 63 67.~ 54 54'8 60'0 40 ~ 66,4 62.8 96.4 87. 72 7,5 ~ 83 78 87 82 ~ 96. . 73 6 93.9 9 4 72 89. 9 I 81,2 9 4 48 54 8 53 6 6 48 8 44 8 50.4 50.8 48.0 45.6 58 29 63 30 84.8 78.4 91.6 84 16 26 , 33 28 90, .95 36 84.2 39 47 36 80 .4 38 20 ,8 33 47 9 64,8 33 53 29 8O 49, ,38 8,4 , 8 15 16 04 67 17,81 8.6 ~ .83 I .o 44 64 82 49.~ 63 17,64 46. 48 16,20 45 84 14,61 45 57 13.88 42 76 13.38 42 28 12.87 43 88 12,45 44 79 I2'41 42 12 12,82 41 68 13;47 ,01 69 49 , 16,02 35 08 26,49 93 29 21 93 60 62 54 27 8 04 25 PAGE 7 PA$$3 GR - ~,,~;~? ~:~;~::CU .... ~ ~:CU~G~:~~ :~:?~:;~:,::.:~?:.~,~::::~:~:~:~:::.:. :~;~_ :: ~ ~,: _ GAPI GAP! GAPI 58, 50. 6. 3.62 50, 2 50 0 $I' ~ 43.6 50. 46~0 55. 5~,0 53i2 49. 49.2 56.1 45,6 52.~ 48.4 51, 9 50,0 5 50.4 48. 8 53.6 49.~ 5 51.6 56. 4 54.0 62.~ · 5 56.0 63.6 55.2 58,0 ' 62.8 54.8 62.0 47.2 54.4 56.8 56,8 85.9 79.2 PA$64 PA$$5 AVE. AVE GR GR SIGMA NEAR F'AR GAP]: GAP1 CU 74.9 65'2 60'0 5'6'8 54,0 46.8 44. 46.8 86.4 57.2 52. 56.4 53.2 51.~ 47.6 ' . 70 20 49 15 49 15 49 2 17.96 15 50] 19.I3 15 45.6 49°6 47,4 t6 59 58~ 13 56,8 t7 I 14 49.2 60°2 5, 74'6 57'2 2.6 48 46. 45,E 2.43 I9 23"7920 21.16 17 ~9.66 19'08 16 17,66 14 16.27 13 15 64 il: 05 45 09 80 84 07 01 90 O1 58 41 10 !0 75 61 PAGE 8 GR GAPI PA$$2 PASS3 PA$84 GR GR GAPI GAPI GAP! i32 32 4O 4O 13 45 6 35 5647 2 37 65 8 54, 9 55, 48 ,0 44 ,4 45 0 39 "0 4 '4 4~ .'2 48 4 48 8 45 6 56 4 46 40 4!4 44 40 6 35'S 59'8 73,9 46 44: 48, 49. 46, 50, 52, 54 ~ 50 68,4 72,4 65 ~ 59. 52,4 52.8 52,4 56,0 55,6 58,0 54.0 50,8 51,6 74 78,8 4 48,, 4 52. 77, 74, 6 64, 57, 57, 57, 60, 61, 57, 53 75 8~ 87, PA$$5 AVE. AVE, GR SIGMA SIGMA NEAR FAR GAP! CU 46 52 52 56, 5 50, 55,~ 8208 21 86 72 64 O~ 54 68 ~5 ,68 ~o 17 ~0 05 II 17,72 1 ,23 5~ 19 95 14,37 14,97 16,02 16,82 ,45 15 15 15,86] 16, 16 56 16 75 14 29 14 65 15 79 16 56 6, 6, 14,4 14,~ 14.2 GAP ! GAP 1: GAP ! PA$$5 AVE. AVE, GR ~IGMA SIGMA NEAR FAR GAPZ CU ~7 .70 ~ 74.4 70.~ ~9,91 16.98 3 6~ 65,2 61.8 21'73 I8'07 5 61i 62,0 58,8 22,55 %8,07 !~ ~ 58.4 53.2 t9,91 16104 2 50 ~5 69 82,0 17;46' 14'55 .9 72. 87,2 74,6 19,27 15"77 ~5 64, ~ 63.4 23'37 19,t2 67"6 ,3 52~¢ 62.8 56.0 24~2% 53.6 20.?0 55 2 61,6 55.2 %$,%4 ~5'32 52 0 60.2 63.~ 55.2 53 60'163' 60.4 56,8 -55' 53*6 50 4 4 55, 0 0 8 4 $0 67 94 38 91 63 85 8~ 17, 15,~ 16.6 ,9 66. 75 77;6 0 5 69.9 ~ 68~4 2 618 ~ 79.2 60. 58. 81 9 75.~ 68. 72' 68' 78,4 68,I 84'4 72. 85,4 79,~ 12 3 !8, PAGE 10 8 87..9 4 67,9 8 60 * 8 4 $6'0 672'4 8 67.9 8 73 * 9 874113.6 : PA$$3 PA$64 PA$S5 AVE. GR GR GR SZGMA NEAR GAPI GAPI GAP! CU AVE. $2Gt4A FAR 4 97,2 I00 0 881'4104 6 90,8 108 9 95'6 108 3 101.6 99 892*4 98 75 87, 81.4 99. 89,8 114,4 101,3 116.8 105.5 109,9 105.3 I ~01.2 101.2 86 19 79 63 2103 59 21,58 88 23;57 47 28.61 66 32,03 44 33,38 31 33,73 63 32.91 44 32.08 53 32,60 70 32.68 80 32.70 9t 32,90 36 31 69 98 27 29 802113 7518 55 63 17 39 67 16 97 69'2 78'~ 69 60,0 69,2 55*6 63'6 55'9 · IS 74 58.8 60,8 58.8 15 98 '56'4 57'6 56.4 116.27 7I'2 62;0 91 62,8' 44 14.81 70'47~ !75'6 ~ 05 I9, , 05 20' 67*9 62 39 19'89 18,00 99 86 15,85 I 14o 73' 15'44 ~8 97 ~6,08 Il Ilil ii:-] i[:f [;] i GR ::::::::::::::::::::: n'(:'~ :n:~ ======================== ii~ii!!~i ::~'iu~2~:::'~vt.;~'i'~:~:?(:::i~.~~'.' : .'~::ii.~hi'! :~[:[_:~t~:F:' [f~: ~i :: : · .:~ :: PAS$2 GAP! PASS] PA684 PAS$5 GR GR GR GAP! GAP! GAP! 8 g4.1 6 82.: 8 I 8 109.t 113.~ 4 110,8 8:: 2 113.6 .$ 99.9 96, O1 64 1 99 0I, ~0~¢ 12~ 4 147.9 108 99 104 94 86 100 I06 133 PAGE AVE AVE, SIGMA SIGMA NEAR FAR CU 5 18.12 0 t9.37 30 20.01 52 I9,91 06 16,84 68 17.99 54 17;70 19 20;19 91 20.7g 86 18,23 31 18.49 75 20.38 80 22.09 10 23.40 28,10 26.29 46 24 85 02 23 79 28 42 03 76 t5 1½ 3O 06 1 6~ NEAR N ~'R 'NE~'R' !N~E~R'~? ~<~!: F~R': ~ N E A R F A R 47 22 GAP! GAPI GAPI GAPI CU 99, 199, 179. ~54 19 ,, III~'I , . , ,61 9 140 34 31 2 14 , o 68 5 152 8 145 81. 4~ 47. i 69 26 44 179.6 199 93 98 .5 199.3 0 59 27 70 5 199, ~ ~ **.~ 93,6 3,6 , 27 9 9 2 96 96, 80 9 87,9 90,4 90 5 73.6 8~.2 87.6 85,~ ~ 27 23,1~ 09 0 76.8 82.8 79.~ ~ 51 17, 73,1 73,6 99,6 6 99 ! 9 ~23 , 98 143,9 153.3 163.9 186'8 ~64°6 ~ 56 21~ ' 179. I 13,99 . ,4 16.41 13'48 14,67 78.4 195. , 179 99. . ~ ~ I,o.~ 1'~,.~ ~'~. ~,'~~'~' 1~° '--P~.ss2 ~Ass~ ~ss~ GAP~ GAPI GAPZ PA$85 AVE, AVE, GR SZGMA SZGMA NEAR 'FAR:': GAP! CU 22 ! 4 NEAR FAR 0 107 ,4 lO0 ~ .~ [0000 26103 9 0 99 i12 t08 113 ~ 10 99 99 34,64 33, 34,50 33, 34,5933 34.59 33 46,28 45 46.~6 45 46,81 46 47,17 46 47,~1 46 59,22 52 ~4 99 6 100 59~75 58~ 100 i 59 4 99 6 59,88 9 996 99959,7559 60 55 76